Office ofEnergyProjects
May 2019

FERC/EIS – 0286F

FINAL ENVIRONMENTAL IMPACT STATEMENT
for thePlaquemines LNG and Gator Express
Pipeline Project

Venture Global Plaquemines LNG, LLC
Venture Global Gator Express, LLC

Docket Nos. CP17-66-000
CP17-67-000

Federal Energy Regulatory Commission
Office of Energy Projects
Washington, DC 20426

Cooperating Agencies:

U.S. Environmental
Protection Agency

U.S. Coast Guard
US Army Corpsof Engineers®

U.S. Army
Corps of Engineers

BUILDING STRONG®

Pipeline and Hazardous
Materials Safety
Administration

U.S. Departmentof Energy

FEDERAL ENERGY REGULATORY COMMISSIONWASHINGTON D.C. 20426

OFFICE OF ENERGY PROJECTSIn Reply Refer To:
OEP/DG2E/Gas Branch 2
Venture Global Plaquemines LNG,
LLC and Venture Global Gator
Express, LLC
Docket Nos. CP17-66-000 and
CP17-67-000

TO THE INTERESTED PARTY:
The staff of the Federal Energy Regulatory Commission (FERC or Commission)
has prepared a final environmental impact statement (EIS) for the Plaquemines LNG and
Gator Express Pipeline Project, proposed by Venture Global Plaquemines LNG, LLC and
Venture Global Gator Express, LLC in the above-referenced dockets. Venture Global
requests authorization to construct and operate a new liquefied natural gas (LNG) export
terminal and associated facilities along the west bank of the Mississippi River in
Plaquemines Parish, Louisiana (Terminal) and to construct and operate two new 42-inchdiameter natural gas pipeline laterals that would connect to the Terminal. The newliquefaction facilities would have a nameplate production capacity of 20.0 million metrictons per annum (MTPA) of LNG and peak production capacity of 24 MTPA.
The final EIS assesses the potential environmental effects of the construction andoperation of the Plaquemines LNG and Gator Express Pipeline Project in accordance withthe requirements of the National Environmental Policy Act (NEPA). The FERC staff
concludes that approval of the proposed project, with the mitigation measures
recommended in the EIS, would have some adverse environmental impacts. These impacts
would be reduced to less-than-significant levels with the implementation of Venture
Global’s proposed mitigation measures and the additional measures recommended in the
final EIS.
The U.S. Army Corps of Engineers, U.S. Coast Guard, U.S. Department of Energy,
U.S. Environmental Protection Agency, and U.S. Department of Transportation
participated as cooperating agencies in the preparation of the EIS. Cooperating agencies
have jurisdiction by law or special expertise with respect to resources potentially affectedby the proposal and participate in the NEPA analysis. Although the cooperating agencies
provided input to the conclusions and recommendations presented in the EIS, the agencies
will present their own conclusions and recommendations in their respective Records ofDecision for the project.
The final EIS addresses the potential environmental effects of the construction andoperation of the following project facilities:

• LNG Terminal: Construction and operation of various liquefaction, LNG
distribution, and appurtenant facilities within the boundaries of the site leased by
Venture Global on the Mississippi River, including:o six pretreatment facilities (three in each phase);o a liquefaction plant with 18 integrated single-mixed refrigerant blocks andsupport facilities (otherwise referred to as liquefaction blocks or blocks) tobe constructed in two phases (nine blocks in each phase);o four 200,000-cubic-meter aboveground LNG storage tanks;o three LNG loading docks within a common LNG berthing area; ando air-cooled electric power generation facilities.
• Pipeline System: Construction and operation of two parallel 42-inch-diameter
natural gas pipelines that share one right-of-way corridor for the majority of theirrespective routes and appurtenant aboveground facilities, including the following:o 15.1-mile-long Southwest Lateral Tennessee Gas Pipeline, LLC (TGP)
Pipeline;o 11.7-mile-long Southwest Lateral Texas Eastern Transmission, LP (TETCO)
Pipeline;o TGP metering and regulation station; ando TETCO metering and regulation station.
The Commission mailed a copy of the Notice of Availability to federal, state, andlocal government representatives and agencies; elected officials; environmental and public
interest groups; Native American tribes; potentially affected landowners and otherinterested individuals and groups; and newspapers and libraries in the project area. The
final EIS is only available in electronic format. It may be viewed and downloaded fromthe FERC’s website (www.ferc.gov), on the Environmental Documents page(https://www.ferc.gov/industries/gas/enviro/eis.asp). In addition, the final EIS may beaccessed by using the eLibrary link on the FERC’s website. Click on the eLibrary link
(https://www.ferc.gov/docs-filing/elibrary.asp), click on General Search, and enter the
docket number in the “Docket Number” field, excluding the last three digits (i.e., CP17-66
or CP17-67). Be sure you have selected an appropriate date range. For assistance, pleasecontact FERC Online Support at FercOnlineSupport@ferc.gov or toll free at (866) 2083676, or for TTY, contact (202) 502-8659.
Additional information about the project is available from the Commission’s Officeof External Affairs, at (866) 208-FERC, or on the FERC website (www.ferc.gov) usingthe eLibrary link. The eLibrary link also provides access to the texts of all formal
documents issued by the Commission, such as orders, notices, and rulemakings.
In addition, the Commission offers a free service called eSubscription that allows
you to keep track of all formal issuances and submittals in specific dockets. This can
reduce the amount of time you spend researching proceedings by automatically providing
you with notification of these filings, document summaries, and direct links to the
documents. Go to www.ferc.gov/docs-filing/esubscription.asp.

TABLE OF CONTENTS
Plaquemines LNG and Gator Express
Pipeline Project
Final Environmental Impact Statement

TABLE OF CONTENTS ............................................................................................................................... i
LIST OF APPENDICES .............................................................................................................................. ix
LIST OF TABLES ........................................................................................................................................ x
LIST OF FIGURES ................................................................................................................................... xiii
TECHNICAL ACRONYMS AND ABBREVIATIONS........................................................................... xiv
EXECUTIVE SUMMARY .................................................................................................................... ES-1

1.0

INTRODUCTION ........................................................................................................... 1-1
1.1

PROJECT PURPOSE AND NEED ..................................................................... 1-2

1.2

PURPOSE AND SCOPE OF THIS ENVIRONMENTAL IMPACT
STATEMENT ...................................................................................................... 1-3
1.2.1 Federal Energy Regulatory Commission ................................................. 1-4
1.2.2 U.S. Army Corps of Engineers ................................................................ 1-4
1.2.3 U.S. Coast Guard ..................................................................................... 1-5
1.2.4 U.S. Department of Energy...................................................................... 1-5
1.2.5 U.S. Department of Transportation .......................................................... 1-6
1.2.6 U.S. Environmental Protection Agency ................................................... 1-7

1.3

PUBLIC REVIEW AND COMMENT................................................................ 1-8
1.3.1 Pre-filing Process and Scoping ................................................................ 1-8
1.3.2 Public Review of the Draft EIS ............................................................. 1-12

1.4

NON-JURISDICTIONAL FACILITIES ........................................................... 1-13

1.5

PERMITS, APPROVALS, AND REGULATORY REVIEWS ........................ 1-14
1.5.1 Endangered Species Act ........................................................................ 1-14
1.5.2 Magnuson-Stevens Fishery Conservation Management Act ................. 1-15
1.5.3 Migratory Bird Treaty Act ..................................................................... 1-15
1.5.4 Bald and Golden Eagle Protection Act .................................................. 1-15
1.5.5 Marine Mammal Protection Act ............................................................ 1-16
1.5.6 Rivers and Harbors Act .......................................................................... 1-16
1.5.7 Clean Water Act ..................................................................................... 1-16
1.5.8 Clean Air Act ......................................................................................... 1-17
1.5.9 Federal Aviation Act .............................................................................. 1-17
1.5.10 Maritime Transportation Security Act ................................................... 1-17
1.5.11 National Historic Preservation Act ........................................................ 1-18
1.5.12 National Flood Insurance Act ................................................................ 1-18
1.5.13 Coastal Zone Management Act .............................................................. 1-18
1.5.13.1 U.S. Department of Defense ................................................... 1-18

i

2.0

PROPOSED ACTION ..................................................................................................... 2-1
2.1

PROPOSED FACILITIES ................................................................................... 2-1
2.1.1 LNG Terminal .......................................................................................... 2-3
2.1.1.1 Pretreatment .............................................................................. 2-5
2.1.1.2 Liquefaction .............................................................................. 2-7
2.1.1.3 LNG Tanks................................................................................ 2-8
2.1.1.4 LNG Loading and Ship Berthing Area ..................................... 2-9
2.1.1.5 Flare Stack ................................................................................ 2-9
2.1.1.6 Power Generation Facilities .................................................... 2-12
2.1.1.7 Construction Facilities ............................................................ 2-12
2.1.1.8 Support Facilities .................................................................... 2-13
2.1.1.9 LNG Carriers .......................................................................... 2-16
2.1.2 Pipeline System ...................................................................................... 2-16

2.2

LAND REQUIREMENTS................................................................................. 2-17
2.2.1 LNG Terminal ........................................................................................ 2-17
2.2.2 Pipeline System ...................................................................................... 2-18

2.3

CONSTRUCTION SCHEDULE ....................................................................... 2-20

2.4

ENVIRONMENTAL COMPLIANCE .............................................................. 2-20
2.4.1 Environmental Inspection ...................................................................... 2-21
2.4.2 Compliance Monitoring ......................................................................... 2-22
2.4.3 Environmental Training ......................................................................... 2-23

2.5

CONSTRUCTION PROCEDURES.................................................................. 2-23
2.5.1 LNG Terminal ........................................................................................ 2-24
2.5.1.1 Site Preparation ....................................................................... 2-24
2.5.1.2 Terminal Site........................................................................... 2-24
2.5.1.3 Marine Facilities ..................................................................... 2-25
2.5.1.4 Piping and Equipment Installation and Testing ...................... 2-25
2.5.2 Pipeline System ...................................................................................... 2-26
2.5.2.1 Surveying and Easement Acquisition ..................................... 2-26
2.5.2.2 General Construction Procedures ........................................... 2-26
2.5.2.3 Conventional Lay Construction .............................................. 2-27
2.5.2.4 Barge Lay Construction .......................................................... 2-27
2.5.2.5 Push Lay.................................................................................. 2-28
2.5.2.6 HDD Lay................................................................................. 2-28
2.5.2.7 Bore Lay.................................................................................. 2-30
2.5.2.8 Aboveground Facility Construction Procedures ..................... 2-30
2.5.3 Access Roads ......................................................................................... 2-30
2.5.4 Pipe Storage and Contractor Yard ......................................................... 2-31
2.5.5 Special Construction Procedures ........................................................... 2-31
2.5.5.1 Levee Crossing Construction Procedures ............................... 2-31
2.5.5.2 Wetland and Waterbody Construction Procedures ................. 2-31
2.5.5.3 HDD Construction .................................................................. 2-32
2.5.5.4 Proposed Modifications to the Federal Energy Regulatory
Commission’s Plan ................................................................. 2-32

ii

2.5.5.5
2.6

3.0

4

Proposed Modifications to the Federal Energy Regulatory
Commission’s Procedures....................................................... 2-32

OPERATION, MAINTENANCE, AND SAFETY PROCEDURES ................ 2-33
2.6.1 LNG Terminal ........................................................................................ 2-33
2.6.2 Pipeline System ...................................................................................... 2-34

ALTERNATIVES............................................................................................................ 3-1
3.1

NO ACTION ALTERNATIVE ........................................................................... 3-2

3.2

SYSTEM ALTERNATIVES ............................................................................... 3-3
3.2.1 LNG Project System Alternatives ............................................................ 3-3
3.2.2 Pipeline System Alternatives ................................................................... 3-7

3.3

ALTERNATIVE TERMINAL FACILITY SITES ............................................. 3-7
3.3.1 LNG Terminal Site Alternatives .............................................................. 3-7
3.3.1.1 Mississippi River Mile 55–West Bank (Proposed Site) ........... 3-8
3.3.1.2 Mississippi River Mile 56 ......................................................... 3-9
3.3.1.3 Mississippi River Mile 55–East Bank..................................... 3-10
3.3.1.4 Cutrone Property ..................................................................... 3-10
3.3.1.5 South Carlyss Site I................................................................. 3-10
3.3.1.6 South Carlyss Site II ............................................................... 3-11

3.4

ALTERNATIVE TERMINAL CONFIGURATIONS ...................................... 3-12

3.5

ALTERNATIVE PIPELINE ROUTES ............................................................. 3-12
3.5.1 Background ............................................................................................ 3-13
3.5.1.1 Northwest Lateral Pipeline Route ........................................... 3-13
3.5.1.2 Southeast Lateral Pipeline Route ............................................ 3-14
3.5.1.3 Southwest Laterals Pipeline Route ......................................... 3-14
3.5.2 Southwest Laterals Route (Proposed) .................................................... 3-14
3.5.2.1 Southwest Lateral TETCO Pipeline – Preferred Route .......... 3-15
3.5.2.2 Southwest Lateral TETCO Pipeline – Alternative 1............... 3-15
3.5.2.3 Southwest Lateral TETCO Pipeline – Alternative 2............... 3-15

3.6

ALTERNATIVE ABOVEGROUND FACILITIES SITES .............................. 3-16

ENVIRONMENTAL IMPACT ANALYSIS .................................................................. 4-1
4.1

GEOLOGY .......................................................................................................... 4-1
4.1.1 Geologic Setting....................................................................................... 4-1
4.1.2 Mineral Resources ................................................................................... 4-2
4.1.3 Geologic Hazards ..................................................................................... 4-3
4.1.3.1 Seismicity.................................................................................. 4-3
4.1.3.2 Shoreline Erosion and Landslides ............................................. 4-4
4.1.3.3 Land Subsidence and Sea Level Rise ....................................... 4-4
4.1.3.4 Flooding/Storm Damage/Tsunamis .......................................... 4-4
4.1.4 Blasting .................................................................................................... 4-5
4.1.5 Paleontology ............................................................................................ 4-5
4.1.6 Design and Construction of the LNG Terminal and Pipeline System ..... 4-5
4.1.7 General Impacts and Mitigation............................................................... 4-5
iii

4.2

SOILS .................................................................................................................. 4-6
4.2.1 Existing Soil Resources ........................................................................... 4-6
4.2.1.1 Soil Types and Limitations ....................................................... 4-6
4.2.1.2 Prime Farmland Soils ................................................................ 4-7
4.2.1.3 Hydric Soils .............................................................................. 4-9
4.2.1.4 Compaction Potential ................................................................ 4-9
4.2.1.5 Erosion .................................................................................... 4-10
4.2.1.6 Revegetation Potential ............................................................ 4-10
4.2.1.7 Stony/Rocky Soils ................................................................... 4-10
4.2.1.8 Shallow Bedrock ..................................................................... 4-11
4.2.2 Soil Contamination ................................................................................ 4-11
4.2.3 General Impacts and Mitigation............................................................. 4-11
4.2.3.1 LNG Terminal ......................................................................... 4-11
4.2.3.2 Pipeline System ....................................................................... 4-12

4.3

WATER RESOURCES ..................................................................................... 4-13
4.3.1 Groundwater Resources ......................................................................... 4-13
4.3.1.1 Sole Source Aquifers .............................................................. 4-14
4.3.1.2 Water Supply Wells ................................................................ 4-15
4.3.1.3 Contaminated Groundwater .................................................... 4-15
4.3.1.4 Groundwater Impacts and Mitigation ..................................... 4-16
4.3.2 Surface Water......................................................................................... 4-18
4.3.2.1 Existing Surface Water Resources .......................................... 4-19
4.3.2.2 Surface Water Impacts and Mitigation ................................... 4-26
4.3.2.3 Modifications to FERC Procedures ........................................ 4-34

4.4

WETLANDS...................................................................................................... 4-38
4.4.1 Existing Wetland Resources .................................................................. 4-39
4.4.2 Wetlands Impacts and Mitigation .......................................................... 4-40
4.4.2.1 LNG Terminal ......................................................................... 4-40
4.4.2.2 Pipeline System ....................................................................... 4-41
4.4.3 Modifications to the FERC Procedures ................................................. 4-45
4.4.3.1 Site-specific Justification for Right-of-way Greater than
75 Feet..................................................................................... 4-45
4.4.4 Compensatory Mitigation ...................................................................... 4-47

4.5

VEGETATION .................................................................................................. 4-49
4.5.1 Existing Vegetation Resources .............................................................. 4-49
4.5.1.1 LNG Terminal ......................................................................... 4-49
4.5.1.2 Pipeline System ....................................................................... 4-51
4.5.2 Construction and Operation Impacts and Mitigation ............................. 4-52
4.5.2.1 LNG Terminal ......................................................................... 4-52
4.5.2.2 Pipeline System ....................................................................... 4-53
4.5.3 Exotic or Invasive Plant Communities and Noxious Weeds ................. 4-54
4.5.4 Vegetative Communities of Special Concern ........................................ 4-55

4.6

WILDLIFE AND AQUATIC RESOURCES .................................................... 4-57
4.6.1 Wildlife Resources ................................................................................. 4-57
4.6.1.1 Existing Wildlife Habitats....................................................... 4-57
iv

4.6.2
4.6.3
4.6.4

4.6.1.2 Impacts and Mitigation ........................................................... 4-58
Unique and Sensitive Wildlife Species .................................................. 4-59
4.6.2.1 Migratory Birds ....................................................................... 4-59
4.6.2.2 Impacts and Mitigation ........................................................... 4-63
Aquatic Resources ................................................................................. 4-65
4.6.3.1 Existing Aquatic Resources .................................................... 4-65
4.6.3.2 Impacts and Mitigation ........................................................... 4-70
Essential Fish Habitat ............................................................................ 4-82
4.6.4.1 Existing Essential Fish Habitat ............................................... 4-83
4.6.4.2 Impacts and Mitigation ........................................................... 4-85

4.7

THREATENED, ENDANGERED, AND OTHER SPECIAL STATUS SPECIES............................................................................................................................ 4-89
4.7.1 Federally Listed Threatened and Endangered Species .......................... 4-92
4.7.1.1 Mammals................................................................................. 4-93
4.7.1.2 Birds ........................................................................................ 4-96
4.7.1.3 Fish.......................................................................................... 4-98
4.7.1.4 Reptiles ................................................................................. 4-101
4.7.2 State-listed Species .............................................................................. 4-104

4.8

LAND USE, RECREATION, AND VISUAL RESOURCES ........................ 4-106
4.8.1 Land Use .............................................................................................. 4-106
4.8.1.1 LNG Terminal ....................................................................... 4-109
4.8.1.2 Pipeline System ..................................................................... 4-109
4.8.1.3 Land Use Impacts and Mitigation ......................................... 4-112
4.8.2 Landowner and Easement Requirements ............................................. 4-114
4.8.2.1 LNG Terminal ....................................................................... 4-114
4.8.2.2 Pipeline System ..................................................................... 4-115
4.8.3 Planned Developments......................................................................... 4-115
4.8.3.1 LNG Terminal ....................................................................... 4-115
4.8.3.2 Pipeline System ..................................................................... 4-116
4.8.4 Recreation and Special Interest Areas ................................................. 4-116
4.8.5 Hazardous Waste Sites ......................................................................... 4-118
4.8.6 Visual Resources .................................................................................. 4-119
4.8.6.1 LNG Terminal ....................................................................... 4-119
4.8.6.2 Pipeline System ..................................................................... 4-122
4.8.7 Coastal Zone Management .................................................................. 4-123

4.9

SOCIOECONOMICS ...................................................................................... 4-124
4.9.1 Population ............................................................................................ 4-125
4.9.2 Economy and Employment .................................................................. 4-128
4.9.3 Commercial and Recreational Fishing ................................................. 4-130
4.9.3.1 Commercial Fishing .............................................................. 4-130
4.9.3.2 Recreational Fishing ............................................................. 4-132
4.9.4 Taxes and Revenues ............................................................................. 4-135
4.9.5 Housing ................................................................................................ 4-136
4.9.6 Property Values .................................................................................... 4-137
4.9.7 Public Services ..................................................................................... 4-140v

4.9.84.9.9

Transportation ...................................................................................... 4-143
4.9.8.1 Roadway Transportation ....................................................... 4-144
4.9.8.2 Marine Transportation .......................................................... 4-147
Environmental Justice .......................................................................... 4-149

4.10

CULTURAL RESOURCES ............................................................................ 4-155
4.10.1 Terminal Site........................................................................................ 4-156
4.10.2 Pipeline System .................................................................................... 4-157
4.10.3 Tribal Consultation .............................................................................. 4-158
4.10.4 Unanticipated Discovery Plan.............................................................. 4-161
4.10.5 Compliance with the National Historic Preservation Act .................... 4-161

4.11

AIR QUALITY AND NOISE ......................................................................... 4-162
4.11.1 Air Quality ........................................................................................... 4-162
4.11.1.1 Regional Climate .................................................................. 4-163
4.11.1.2 Existing Air Quality .............................................................. 4-163
4.11.1.3 Regulatory Requirements for Air Quality............................. 4-165
4.11.1.4 Construction Air Emissions, Impacts and Mitigation ........... 4-171
4.11.1.5 Operational Air Emissions, Impacts and Mitigation............. 4-176
4.11.1.6 Air Quality Impact Analysis ................................................. 4-182
4.11.1.7 Impacts on Ambient Ozone Concentrations ......................... 4-197
4.11.1.8 Summary Conclusion – Overall Air Quality ........................ 4-199
4.11.2 Noise 4-200
4.11.2.1 Noise Regulations ................................................................. 4-201
4.11.2.2 Existing Sound Levels and Noise-sensitive Areas................ 4-202
4.11.2.3 Construction Noise Impacts and Mitigation ......................... 4-204
4.11.2.4 Operational Noise Impacts and Mitigation ........................... 4-208

4.12

RELIABILITY AND SAFETY ....................................................................... 4-211
4.12.1 LNG Terminal Reliability, Safety and Security Regulatory
Oversight .............................................................................................. 4-211
4.12.2 DOT Safety Regulatory Requirements and 49 CFR 193 Subpart B
Determination ...................................................................................... 4-212
4.12.3 USCG Regulatory Requirements and Letter of Recommendation ...... 4-215
4.12.3.1 LNG Carrier Historical Record ............................................. 4-215
4.12.3.2 LNG Carrier Regulatory Oversight ...................................... 4-217
4.12.3.3 Plaquemines LNG’s Waterway Suitability Assessment ....... 4-221
4.12.3.4 LNG Carrier Routes and Hazard Analysis............................ 4-221
4.12.3.5 Coast Guard Letter of Recommendation and Analysis......... 4-221
4.12.3.6 LNG Terminal Security Regulatory Requirements .............. 4-225
4.12.4 FERC Engineering and Technical Review of the Preliminary
Engineering Designs ............................................................................ 4-227
4.12.4.1 LNG Facility Historical Record ............................................ 4-227
4.12.4.2 FERC Preliminary Engineering Review ............................... 4-228
4.12.4.3 Process Design ...................................................................... 4-230
4.12.4.4 Mechanical Design................................................................ 4-234
4.12.4.5 Hazard Mitigation Design ..................................................... 4-235
4.12.4.6 Geotechnical and Structural Design Review ........................ 4-248
vi

4.12.4.7 External Impact Review ........................................................ 4-259
4.12.4.8 Onsite and Offsite Emergency Response Plans .................... 4-266
4.12.5 Recommendations from FERC Preliminary Engineering andTechnical Review................................................................................. 4-267
4.12.6 Conclusions on LNG Reliability and LNG Carrier Reliability and
Safety 4-281
4.12.7 Pipeline System Safety ........................................................................ 4-282
4.12.7.1 Safety Standards.................................................................... 4-283
4.12.7.2 Pipeline Accident Data ......................................................... 4-286
4.12.7.3 Impact on Public Safety ........................................................ 4-288
4.13

5.0

CUMULATIVE IMPACTS ............................................................................. 4-291
4.13.1 Projects and Activities Considered ...................................................... 4-293
4.13.1.1 Non-jurisdictional Activities ................................................. 4-303
4.13.1.2 Major Transportation Projects .............................................. 4-303
4.13.1.3 Major Industrial Developments ............................................ 4-304
4.13.1.4 Drainage and Shoreline Protection Activities ....................... 4-304
4.13.1.5 Marsh and Wetland Mitigation Activities............................. 4-305
4.13.2 Potential Cumulative Impacts by Resource ......................................... 4-306
4.13.2.1 Geology and Soils ................................................................. 4-306
4.13.2.2 Groundwater ......................................................................... 4-306
4.13.2.3 Surface Waters and Aquatic Wildlife and Habitat ................ 4-307
4.13.2.4 Wetlands ............................................................................... 4-312
4.13.2.5 Vegetation and Wildlife ........................................................ 4-314
4.13.2.6 Land Use ............................................................................... 4-315
4.13.2.7 Visual Resources ................................................................... 4-317
4.13.2.8 Socioeconomics .................................................................... 4-318
4.13.2.9 Roadway and Vessel Traffic ................................................. 4-319
4.13.2.10 Cultural Resources ................................................................ 4-323
4.13.2.11 Air Quality ............................................................................ 4-323
4.13.2.12 Noise ..................................................................................... 4-328
4.13.2.13 Safety and Reliability............................................................ 4-330
4.13.2.14 Climate Change..................................................................... 4-330
4.13.3 Conclusion ........................................................................................... 4-333

CONCLUSIONS AND RECOMMENDATIONS .......................................................... 5-1
5.1

SUMMARY OF THE ENVIRONMENTAL ANALYSIS.................................. 5-1
5.1.1 Geologic Resources ................................................................................. 5-1
5.1.2 Soils.......................................................................................................... 5-2
5.1.3 Water Resources ...................................................................................... 5-3
5.1.3.1 Groundwater ............................................................................. 5-3
5.1.3.2 Surface Water............................................................................ 5-4
5.1.4 Wetlands .................................................................................................. 5-7
5.1.5 Vegetation ................................................................................................ 5-8
5.1.6 Wildlife and Aquatic Resources .............................................................. 5-8
5.1.6.1 Wildlife ..................................................................................... 5-8
5.1.6.2 Aquatic Resources .................................................................. 5-10vii

5.1.7 Threatened, Endangered, and Other Special Status Species .................. 5-13
5.1.8 Land Use, Recreation, and Visual Resources ........................................ 5-14
5.1.9 Socioeconomics ..................................................................................... 5-17
5.1.10 Cultural Resources ................................................................................. 5-19
5.1.11 Air Quality and Noise ............................................................................ 5-19
5.1.11.1 Air Quality .............................................................................. 5-19
5.1.11.2 Noise ....................................................................................... 5-21
5.1.12 Reliability and Safety............................................................................. 5-23
5.1.13 Cumulative Impacts ............................................................................... 5-23
5.1.14 Alternatives ............................................................................................ 5-25
5.2

FERC STAFF’S RECOMMENDED MITIGATION........................................ 5-27

viii

LIST OF APPENDICES
Appendix A
Appendix B
Appendix C
Appendix D
Appendix E
Appendix F
Appendix G
Appendix H
Appendix I
Appendix J

Distribution List for Notice of Availability
FiguresUpland Erosion Control, Revegetation, and Maintenance Plan; Wetland andWaterbody Construction and Mitigation Procedures; and Modifications to the Planand Procedures
Horizontal Directional Drilling Contingency Plan
Traffic Simulation Study
Air Permit BACT Summary
References
Responses to Comments on the Draft Environmental Impact Statement
List of Preparers
Index

ix

LIST OF TABLES
Table 1.3-1

Key Environmental Concerns Identified during the Scoping Process andDraft EIS Review for the Project ......................................................................... 1-9

Table 1.5-1Major Permits, Approvals, and Consultations for the Project ........................... 1-19

Table 2.1-1

Summary of Major Facility Components Constructed by Phase ......................... 2-5

Table 2.2-1

Summary of Land Requirements at the Terminal Sitea ..................................... 2-18

Table 2.2-2

Summary of Land Requirements for the Pipeline System and its
Aboveground Facilities ...................................................................................... 2-19

Table 3.3-1

Alternative Sites Selection Criteria Summary ..................................................... 3-9

Table 3.5-1

Summary of Selection Criteria for the Southwest Lateral TETCO Pipeline
Routes ................................................................................................................ 3-15

Table 4.2-1

Characteristics of Soils Associated with the Terminal Site and Pipeline
System .................................................................................................................. 4-8

Table 4.3-1

Estimated Water Usage During LNG Terminal Construction ........................... 4-17

Table 4.3-2

Designated Uses for Waterbodies Within the Project Area ............................... 4-21

Table 4.3-3

LNG Terminal Site Waterbodies ....................................................................... 4-22

Table 4.3-4

Waterbodies Affected by the Pipeline System................................................... 4-25

Table 4.3-5

Pipeline System Barge Access Channel Dredging Impacts ............................... 4-26

Table 4.3-6

Summary of Waterbody Impacts in Acres at the Terminal Site ........................ 4-30

Table 4.3-7

Proposed Locations of Additional Temporary Workspaces within
Waterbodies ....................................................................................................... 4-37

Table 4.4-1

LNG Terminal Wetland Impacts ....................................................................... 4-41

Table 4.4-2

Summary of Wetlands on the Pipeline System (acres), Pipeline System
Wetland Impacts ................................................................................................ 4-44

Table 4.4-3

Proposed Locations of Additional Temporary Workspace within Wetlands ....... 46

Table 4.5-1

Habitat Communities Affected by Construction and Operation of the LNG
Terminal and Pipeline System (in acres) .............................................................. 50

Table 4.6-1

Non-nesting Period for Nesting Colonial and Non-colonial Birds .................... 4-61

Table 4.6-2

Private Lease Areas in Barataria Bay Crossed by Pipeline System................... 4-67

Table 4.6-3

Pilings Sizes and Installation Methods for Project Facilities............................. 4-72

Table 4.6-4

Underwater Noise Thresholds for Fish During Pile Driving Activity ............... 4-73

Table 4.6-5

Threshold Distance for Injury and Disturbance to Fish for Different Pile
Diameters ........................................................................................................... 4-74

x

Table 4.6-6

Summary of Near-source (10-meter) Unattenuated Sound Pressures for Inwater Pile Driving .............................................................................................. 4-74

Table 4.6-7

Non-ESA Listed Marine Mammals Potentially Occurring Along the LNG
Transit Routes .................................................................................................... 4-88

Table 4.7-1

Federal and State Listed Species Potentially Occurring in the Vicinity of the
Project ................................................................................................................ 4-90

Table 4.7-2

Underwater Noise Thresholds for Marine Mammals During Pile Driving
Activity .............................................................................................................. 4-94

Table 4.7-3

Threshold Distance for Injury and Disturbance to Mid-Frequency Cetaceans
for Unmitigated Pile Driving ............................................................................. 4-95

Table 4.7-4

Threshold Distance for Injury and Disturbance to Sea Turtles for Different
Pile Types......................................................................................................... 4-103

Table 4.8-1

Land Use Requirements for the Projecta, b ....................................................... 4-107

Table 4.9-1

Population, Density, and Land Area Statistics in the Affected Area ............... 4-125

Table 4.9-2

LNG Terminal and Pipeline System Workforce and Duration ........................ 4-126

Table 4.9-3

Existing Economic Conditions in the Affected Area....................................... 4-128

Table 4.9-4

Housing and Accommodations in the Affected Area ...................................... 4-137

Table 4.9-5

Public Services in the Affected Area ............................................................... 4-141

Table 4.9-6

Minority and Income Statistics in the Affected Area, Census Tracts Below
the Terminal, the Parish, and the State, 2012-2016 Estimates a,b,c ................... 4-152

Table 4.10-1 Correspondence with Federally Recognized Tribes ........................................ 4-159
Table 4.11-1 Background Ambient Air Quality (2013 to 2015) ........................................... 4-165
Table 4.11-2 Construction Emissions (tons per year) ........................................................... 4-172
Table 4.11-3 Combined Construction and Operation Emissions Years 1 through 6 ............ 4-179
Table 4.11-4 Final Operational Emissionsa ........................................................................... 4-180
Table 4.11-5 Class I Area SIL Model Results....................................................................... 4-184
Table 4.11-6 Sulfur and Nitrogen Deposition Modeling Results.......................................... 4-185
Table 4.11-7 Visibility Analysis Results............................................................................... 4-186
Table 4.11-8 Preliminary Model Results – Stationary Sources ............................................ 4-191
Table 4.11-9 NAAQS Assessment Results – Project Stationary Sources and Off-Site
Cumulative Sources ......................................................................................... 4-193
Table 4.11-10 NAAQS Assessment Results – Project Stationary and Vessel Sources .......... 4-195
Table 4.11-11 Ammonia Model Results – LDEQ Toxic Air Pollutant Analysis.................... 4-197
Table 4.11-12 Sound Levels and Relative Loudness .............................................................. 4-201

xi

Table 4.11-13 Maximum Permissible Sound Levels by Receiving Land Use Category(Table 1) ........................................................................................................... 4-202
Table 4.11-14 Ambient Noise Level Survey Locations .......................................................... 4-203
Table 4.11-15 Ambient Noise Level Survey Results .............................................................. 4-203
Table 4.11-16 Predicted Noise Levels at NSAs During Pile Driving – Phase I ..................... 4-204
Table 4.11-17 Predicted Noise Levels at NSAs During Pile Driving and Applying 20
Percent Usage Factor ....................................................................................... 4-205
Table 4.11-18 Predicted Noise Level from Lake Hermitage Road HDD at NSA 2 ............... 4-206
Table 4.11-19 Predicted Noise Levels at NSAs from Terminal Operation............................. 4-209
Table 4.12-1 Natural Gas Transmission Pipeline Significant Incidents by Cause (19962015) a .............................................................................................................. 4-287
Table 4.12-2 Excavation, Natural Forces, and Outside Force Incidents by Cause (19962015) a .............................................................................................................. 4-288
Table 4.12-3 Injuries and Fatalities – Natural Gas Transmission Pipelines a ....................... 4-289
Table 4.12-4 Nationwide Accidental Fatalities by Cause ..................................................... 4-290
Table 4.13-1 Resource-Specific Geographic Scope and Temporal Extent of Project
Impacts ............................................................................................................. 4-292
Table 4.13-2 Present and Future Actions Considered in the Cumulative Impact Analysisa . 4-295
Table 4.13-3 Other Actions with the Potential to Cumulatively Impact Surface Waters
and Aquatic Wildlife and Habitat .................................................................... 4-308
Table 4.13-4 Other Actions with the Potential to Cumulatively Impact Wetlands ............... 4-313
Table 4.13-5 Other Actions with the Potential to Cumulatively Impact Vegetation and
Wildlife ............................................................................................................ 4-314
Table 4.13-6 Other Actions With Potential for Cumulatively Impact Land Use .................. 4-316
Table 4.13-7 Other Actions with the Potential to Cumulatively Impact Visual Resources .. 4-317
Table 4.13-8 Other Actions with the Potential to Contribute to a Cumulative Adverse
Effect on Socioeconomic Resources ................................................................ 4-319
Table 4.13-9 Other Actions with the Potential to Cumulatively Impact Roadway Traffic... 4-320
Table 4.13-10 Other Actions with the Potential to Cumulatively Impact Vessel Traffic on
the Mississippi River........................................................................................ 4-321
Table 4.13-11 Other Activities within the Geographic and Temporal Scope for Cumulative
Air Impacts during Operation .......................................................................... 4-326
Table 4.13-12 Other Activities within the Geographic Scope and Temporal Scope for
Cumulative Noise Impacts during Construction .............................................. 4-329

xii

LIST OF FIGURES
Figure 2.1-1

Proposed Project Facilities - Regional Location (Aerial Map) ............................ 2-2

Figure 2.1-2

Proposed Facilities at Terminal Site (Aerial Map................................................ 2-4

Figure 2.1-3

LNG Carrier Sea Routes .................................................................................... 2-10

Figure 2.1-4

Proposed Layout of LNG Loading Docks ......................................................... 2-11

Figure 4.6-1

Marshlands Crossed by the Project .................................................................... 4-62

Figure 4.6-2

Mapped Oyster Leases Crossed by the Proposed Pipeline System ................... 4-69

Figure 4.6-3

Mapped Essential Fish Habitat Crossed by the Project ..................................... 4-84

Figure 4.8-1

USGS Land Cover Types at the Terminal Site ................................................ 4-110

Figure 4.8-2

USGS Land Cover Types for the Pipeline System .......................................... 4-111

Figure 4.8-3

Recreational Use Areas within 5 miles of Proposed Project ........................... 4-117

Figure 4.12-1 Accidental Sandia "Zones of Concern" Along LNG Transit Route ................ 4-223
Figure 4.12-2 Intentional Sandia "Zones of Concern" Along LNG Transit Route ................ 4-224
Figure 4.13-1 Projects with Potential Cumulative Impacts .................................................... 4-302
Figure 4.13-2 Projects with Potential Cumulative Impacts .................................................... 4-325

xiii

TECHNICAL ACRONYMS AND ABBREVIATIONS

µg/m3
μPA
μPARMS
ACHP
AOI
APE
API
applicant
AQCR
AQRV
ASCE
ASME
ATWS
BA
BACT
BAHX
BCC
bcf/y
bcfd
BCR
b.e.g.
BGEPA
BLEVE
BMP
BOG
BPVC
BTU
Btu/ft2-hr
CAA
CAMx
CCGT
CEQ

micrograms per cubic meter
micropascal
micropascal root mean square
Advisory Council on Historic Preservation
area of influence
Area of Potential EffectAmerican Petroleum InstituteVenture Global Plaquemines LNG, LLC, and Venture Global
Gator Express, LLC; also Venture Global
Air Quality Control Regions
Air Quality Related Value
American Society of Civil Engineers
American Society of Mechanical Engineers
additional temporary workspacebiological assessment
Best Available Control Technology
brazed aluminum heat exchanger
Birds of Conservation Concern
billion cubic feet per year
billion cubic feet per day
Bird Conservation Region
below existing grade
Bald and Golden Eagle Protection Act
boiling liquid expanding vapor explosion
best management practiceboil-off gas
Boiler and Pressure Vessel Code
British thermal unit
British thermal units per square foot per hour
Clean Air Act of 1970
Comprehensive Air Quality Model with Extension
Combined cycle gas turbine
Council on Environmental QualityxivCertificate
CFR
CH4
CI ICE
CO
CO2
CO2e
COI
Commission
COTP
CPRA
CPT
CUP
CWA
CZMA
CZMP
DAT
dB
dBA
DE
DoD
DOE
DOT
DOTD
E1UB
EA
EDMS
EEM
EFH
EI
EIS
EPA
EPAct 2005
ERIC
ERP
ESA

Certificate of Public Convenience and Necessity
Code of Federal Regulations
methaneCompression Ignition Internal Combustion Engines
carbon monoxidecarbon dioxidecarbon dioxide equivalents
Certificate of Inspection
Federal Energy Regulatory Commission; also FERC
Captain of the Port
Coastal Protection Restoration Authority
cone penetration test
Coastal Use Permit
Clean Water Act
Coastal Zone Management Act of 1972
Coastal Zone Management Program
deposition analysis thresholddecibelA-weighted decibel
design earthquake
U.S. Department of Defense
U.S. Department of Energy
U.S. Department of Transportation
Louisiana Department of Transportation and Development
estuarine subtidal unconsolidated bottom (wetland)
environmental assessment
Electron Data Management Systemestuarine emergent (wetland)
essential fish habitat
Environmental Inspector
environmental impact statement
U.S. Environmental Protection Agency
Energy Policy Act of 2005
Emissions Reporting and Inventory Center
Emergency Response Plan
Endangered Species Act of 1973

xv

ESD
ESS
FAA
FE
FEED
FEMA
FERC
FLM
FLNGV
FSA
FSP
FTA
FWS
g
Gator Express Pipeline
GHG
GIS
GMD
GWP
H2S
HAP
HAZOP
HCA
HDD
HP
HRSG
HUC
HVAC
I-#
IBC
ICW
IMO
ISA
ITEP
JPA
KOP

emergency shutdown
estuarine scrub/shrub (wetland)Federal Aviation Administration
Office of Fossil Energy
front-end engineering and design
Federal Emergency Management Administration
Federal Energy Regulatory Commission; also Commission
Federal Land Manager
Floating Liquefaction and Storage Vessel
Facility Security Assessment
Facility Security Plan
Free Trade Agreement
United States Fish and Wildlife Service
factor of gravity
Venture Global Gator Express, LLC
greenhouse gas
geographic information systemgeomagnetic disturbances
global warming potential
hydrogen sulfide
hazardous air pollutant
hazard and operability review
high consequence area
horizontal directional drill
Brake horsepowerheat recovery steam generatorhydrologic unit codeheating, ventilating, and air conditioning
Interstate
International Building CodeIntracoastal Waterway
International Maritime Organization
International Society for Automation
Industrial Tax Exemption Program
Joint Permit Application
key observation point

xvi

LAC
LDEQ
Ldn
LDNR
LDWF
Leq
LNG
LNHP
LOD
LOI
LOR
LPDES
LRS
M&R
m/s
MAOP
MARAD
MBTA
MEOW
MCL
mg/L
MLV
MMBtu
MMPA
MOF
MOU
MP
mph
MSA
MSL
MTPA
MTSA
MW
N2O
NAAQS
NAVD88Louisiana Administrative CodeLouisiana Department of Environmental Quality
Day-Night Average Sound Level
Louisiana Department of Natural Resources
Louisiana Department of Wildlife and Fisheries
Equivalent Sound Levelliquefied natural gas
Louisiana Natural Heritage Program
Letter of Determination
Letter of Intent
Letter of Recommendation
Louisiana Pollutant Discharge Elimination System
Louisiana Revised Statutes
metering and regulation
meters per second
maximum allowable operating pressure
Maritime Administration
Migratory Bird Treaty Act of 1918
maximum envelope of water
Maximum Contaminant Level
milligrams per liter
mainline valve
million British thermal units
Marine Mammal Protection Act
material offloading facility
Memorandum of Understanding
milepost
miles per hour
Magnuson-Stevens Fishery Conservation and Management Act
mean sea level
million metric tons per annum
Maritime Transportation Security Act of 2002
megawatt
nitrous oxide
National Ambient Air Quality Standards
North American Vertical Datum of 1988

xvii

NEP
NEPA
NESHAP
NFIA
NFPA
NGA
NHPA
nm
NMFS
NOI
NOx
NPDES
NPS
NRCS
NRHP
NSA
NSPS
NSR
NVIC
NWI
NWR
O3
OBE
OCM
OEP
P&ID
Parish Plan
PEM
PFD
PFO
PGA
PHMSA
pipeline system
Plaquemines LNG

National Estuary Program
National Environmental Policy Act of 1969
National Emission Standards for Hazardous Air Pollutants
National Flood Insurance Act of 1968
National Fire Protection Association
Natural Gas Act
National Historical Preservation Act
nautical miles
National Marine Fisheries Service
Notice of Intent
oxides of nitrogen
National Pollutant Discharge Elimination System
National Park Service
Natural Resources Conservation Service
National Register of Historic Places
noise sensitive area
New Source Performance Standards
New Source Review
Navigation and Vessel Inspection Circular
National Wetland Inventory
National Wildlife Refuge
ozone
operating basis earthquake
Office of Coastal Management
Office of Energy Projects
piping and instrument diagram
Plaquemines Parish Comprehensive Master Planpalustrine emergent (wetland)
process flow diagrampalustrine forested (wetland)
peak ground acceleration
Pipeline and Hazardous Materials Safety Administration
Venture Global Gator Express, LLC’s lateral pipelines that willconnect the Venture Global Plaquemines LNG, LLC, terminal tothe existing U.S. natural gas transmission grid
Venture Global Plaquemines LNG, LLC

xviii

PM2.5
PM10
PNR
ppb
ppm
ppmv
ppt
Project
Project-specific Plan
Project-specificProcedures
PSD
psig
PSS
Q/D
RHA
RICE
RMP
RMS
ROI
RSRIS
RV
SAV
SCR
SCPT
SELcum
SH #
SHPO
SIL
SIP
SIS
SLOSH
SMC

particulate matter with an aerodynamic diameter less than or equal
to 2.5 microns
particulate matter with an aerodynamic diameter less than or equal
to 10 microns
potential noise receptor
parts per billion
parts per million
parts per million volume
parts per thousandthe combined Venture Global Plaquemines LNG, LLC, andVenture Global Gator Express, LLC, actions and facilities
project-specific Upland Erosion Control, Revegetation, andMaintenance Plan
Project-specific Wetland and Waterbody Construction and
Mitigation Procedures
Prevention of Significant Deterioration
pounds per square inch gauge
palustrine scrub-shrub (wetland)emission to distanceRivers and Harbors Act
Reciprocating Internal Combustion Engines
Risk Management Programroot-mean squareradius of influence
Road Safety and Reliability Impact Study
recreational vehicle
submerged aquatic vegetation
selective catalytic reduction
seismic cone penetration tests
cumulative sound exposure level
State Highway
State Historic Preservation OfficeSignificant Impact Level
State Implementation Plan
safety instrument systemSea, Lake, and Overland Surge from Hurricanes
significant monitoring concentration

xix

SO2
SOLAS
SONRISSPCC
SSE
SSURGO
SWEL
SWPPP
TAP
terminal
TETCO
TGP
tpy
TTS
TWIC
U.S.C.
US #
USACE
USCG
USDA
USGS
Venture Global
VOC
WEG
WSA

sulfur dioxide
Safety of Life at Sea
Strategic Online Natural Resources Information System
Spill Prevention, Control, and Countermeasuressafe shutdown earthquake
Soil Survey Geographic Databasestill water elevation
Stormwater Pollution Prevention Plan
toxic air pollutant
Venture Global Plaquemines LNG, LLC’s proposed liquefied
natural gas terminal on the west bank of the Mississippi River in
Plaquemines Parish, Louisiana
Texas Eastern Transmission, LP
Tennessee Gas Pipeline, LLC
tons per year
temporary threshold shift
Transportation Worker Identification Credential
United States Code
U.S. Highway
U.S. Army Corps of Engineers
U.S. Coast Guard
U.S. Department of Agriculture
U.S. Geological Survey
Venture Global Plaquemines LNG, LLC, and Venture Global
Gator Express, LLC; also applicantsvolatile organic compoundwind erodibility group
Waterway Suitability Assessmentxx

EXECUTIVE SUMMARYINTRODUCTIONOn February 28, 2017, Venture Global Plaquemines LNG, LLC (Plaquemines LNG) filed
an application with the Federal Energy Regulatory Commission (Commission, also FERC) for
authorization pursuant to section 3(a) of the Natural Gas Act (NGA) and part 153 of theCommission’s regulations. Also on February 28, 2017, Venture Global Gator Express, LLC(Gator Express Pipeline) filed an application with FERC for a Certificate of Public Convenienceand Necessity (Certificate) pursuant to section 7(c) of the NGA and part 157 of the Commission’s
regulations.
In Docket Nos. CP17-66-000 and CP17-67-000, Plaquemines LNG and Gator Express
Pipeline request authorization to site, construct, and operate natural gas liquefaction, storage, andexport facilities at a proposed liquefied natural gas (LNG) terminal on the west bank of theMississippi River, and authorization to construct and operate pipelines to transport feed gas to the
LNG terminal, all located in Plaquemines Parish, Louisiana. The combined Plaquemines LNG
and Gator Express Pipeline actions and facilities are referred to herein as the Project, and theapplicants are collectively referred to as Venture Global.
The purpose of the environmental impact statement (EIS) is to inform FERC decisionmakers, the public, and the permitting agencies about the potential adverse and beneficial
environmental impacts of the Project and its alternatives, and recommend mitigation measures thatwould reduce adverse impacts to the extent practicable. As part of the Commission’s considerationof these applications, we 1 prepared this EIS to assess the potential environmental impacts resulting
from the construction and operation of the Project in accordance with the requirements of the
National Environmental Policy Act of 1969 (NEPA). Our analysis was based on information
provided by Venture Global, and further developed from data requests; field investigations;scoping; literature research; communications with federal, state, and local agencies; and individual
members of the public.
FERC is the lead agency for the preparation of the EIS. The U.S. Army Corps of Engineers(USACE), U.S. Coast Guard (USCG), U.S. Department of Energy (DOE), U.S. Environmental
Protection Agency (EPA), and U.S. Department of Transportation (DOT) are participating in the
NEPA review as cooperating agencies and provided comment on this EIS.
PROPOSED ACTION
The Project consists of two main components: 1) the development of natural gas
liquefaction and LNG export capabilities through construction of a new facility (LNG terminal) in
Plaquemines Parish, Louisiana; and 2) the construction of facilities necessary to provide natural
gas supplies to the LNG terminal, including two new pipelines, six mainline valves, three pig
launchers, two pig receivers, and two metering and regulation stations. The Project is expected to
produce at a rate up to 24 million metric tons per annum of LNG for export.

1“We,” “us,” and “our” refer to the environmental and engineering staff of FERC’s Office of Energy Projects.

ES-1

The proposed LNG terminal would include six pretreatment facilities; a liquefaction plantwith 18 integrated single-mixed refrigerant blocks and support facilities to be constructed in twophases (nine blocks in each phase); four 200,000-cubic-meter aboveground LNG storage tanks;
three LNG loading docks within a common LNG berthing area; and air-cooled electric power
generation facilities. The proposed pipeline system would consist of two parallel 42-inch-diameter
natural gas pipelines with aboveground appurtenant facilities, the 15.1-mile-long Southwest
Lateral Pipeline (Southwest Lateral TGP) and the 11.7-mile-long Southwest Lateral Pipeline(Southwest Lateral TETCO) that share one right-of-way corridor for the majority of theirrespective routes.
PUBLIC INVOLVEMENTOn July 2, 2015, FERC began its pre-filing review of the Project and established pre-filingDocket No. PF15-27-000 to place information related to the Project into the public record. The
pre-filing process ended on February 28, 2017, when Venture Global filed its applications with
FERC. The pre-filing review process provides opportunities for interested stakeholders to become
involved early in Project planning, facilitates interagency cooperation, and assists in theidentification and resolution of issues prior to a formal application being filed with FERC.
On October 5, 2015, FERC issued a Notice of Intent to Prepare an Environmental Impact
Statement for the Planned Plaquemines Liquefied Natural Gas Project, Request for Comments on
Environmental Issues, and Notice of Public Scoping Meeting (NOI). This notice was sent to nearly
370 interested parties including federal, state, and local government representatives and agencies;
elected officials; environmental and public interest groups; federally recognized tribes (tribes);
affected property owners; other interested parties; and local libraries and newspapers. On
September 14, 2016, FERC issued a Supplemental Notice of Intent to Prepare an Environmental
Impact Statement for the Planned Plaquemines Liquefied Natural Gas Project. This Supplemental
NOI was sent to eight new landowners in the vicinity of Project facilities based on the revised
pipeline route. Publication of each NOI established a 30-day public comment period. We received
a total of eight comment letters in response to the NOIs. Substantive environmental issues
identified through this public review process are addressed in this EIS.
On November 13, 2018, we issued a Notice of Availability of the Draft Environmental
Impact Statement for the Proposed Plaquemines LNG and Gator Express Pipeline Project. This
notice, which was published in the Federal Register, listed the date and location of a publiccomment session and established a closing date of January 7, 2019 for receiving comments on thedraft EIS. Copies of the notice were mailed to 486 stakeholders. The EPA noticed the draft EIS
in the Federal Register on November 23, 2018.
During the public comment period for the draft EIS we received 91 comments. At thecomment session, the FERC received written and verbal comments from 11 individuals. The
verbal comments were recorded and transcribed by a court reporter. Transcripts and all writtencomments that we received on the draft EIS are part of the public record for the Project. In addition
to receiving written and verbal comments at the draft EIS comment sessions, the FERC received
six comment letters from various parties including federal, state, and local agencies; interested
parties; tribes; businesses; and elected officials. All comments directly pertaining to the draft EIS,
the transcripts of verbal comments presented at the draft EIS comment sessions, and responses tocomments are presented in appendix H.
ES-2

ENVIRONMENTAL IMPACTS AND MITIGATION
We evaluated the potential impacts of construction and operation of the Project on geology;
soils and sediments; water resources; wetlands; vegetation; wildlife and aquatic resources;
threatened, endangered, and other special status species; land use, recreation, and visual resources;
socioeconomics; cultural resources; air quality and noise; reliability and safety; cumulative
impacts, and alternatives. Where necessary, we recommend additional mitigation measures tominimize or avoid impacts. Sections 5.1 and 5.2 of the EIS contain our conclusions and acompilation of our recommended mitigation measures, respectively.
Construction of the LNG terminal facilities would disturb 648.1 acres of land, and80.6 acres of water. Of this total, 625.8 acres of land would be impacted by operation andmaintenance of the LNG terminal facilities, and 10.7 acres of water would be affected by operationand maintenance of the turning basin. The remaining 22.3 acres of land would be temporarily
affected during construction. An additional 77.0 acres would be leased by Venture Global at the
LNG terminal site, but would not be affected by construction.
The land requirements for the pipeline system and its aboveground facilities include 953.9
acres during construction and 137.3 acres during operation. An 80-foot-wide permanent easement
would be required where the two pipelines are collocated, and a 50-foot-wide permanent easement
would be required where the Southwest Lateral TGP would be located alone.
Based on our analysis, Project scoping, agency consultations, and public comments, themajor Project construction and operational issues are impacts on waterbody and wetlands;
vegetation; wildlife and aquatic resources; federally listed species; land use, recreation, and visual
resources; socioeconomics; air quality and noise; reliability and safety; and cumulative impacts.
WATER AND WETLAND RESOURCES
Construction of the pipeline system would primarily occur in open water and inundated
wetlands. The pipelines would be installed by the barge lay method in areas of open water and bydirect push in areas of inundated wetlands/marsh. Venture Global would conduct two horizontal
direction drilling (HDD) operations along the pipelines for installation under wetlands, a canal,
and the proposed floodwall. Use of the HDD method would avoid disturbance to wetlands near
the LNG terminal. In the event of an inadvertent release of drilling mud during an HDD crossing,
Venture Global would implement its HDD Contingency Plan that includes measures to minimize
drilling mud impacts. No active public or private drinking water supply wells are within 150 feetof the pipeline.
Construction of the LNG terminal would result in the permanent loss of 368.1 acres of
wetlands as a result of permanent fill placement. All permanent wetland loss would occur topalustrine emergent wetlands and are a result of construction at the terminal site. Additionally,
Venture Global would require 2.8 acres of wetland conversion from palustrine forested wetlands
at the LNG terminal to palustrine emergent wetlands. Venture Global designed the terminal
facilities to minimize wetland impacts and would follow its Project-specific Wetland andWaterbody Construction and Mitigation Procedures (Procedures) to further reduce impacts on
wetlands. To mitigate unavoidable impacts on wetlands, Venture Global would comply with its

ES-3

Compensatory Mitigation Plan (CMP) which would identify the acreage and type of mitigation as
required by the USACE for Section 404 compliance.
Construction of the pipeline facilities would affect a total of 70.8 acres of wetlands byconstruction of the pipeline, aboveground facilities (meter stations and mainline valves [MLV]),
additional temporary workspace (ATWS) areas, contractor yards, and access roads.
Approximately 0.4 acre of this impact would result in permanent wetland loss as a result of fillplacement for MLVs, permanent road to MLVs, and portions of the pipe trestle over the levee near
Lake Hermitage Road. Following construction, the remaining disturbed areas would be restored
and the permanent right-of-way maintained, in accordance with Venture Global’s Project-specificProcedures.
With implementation of the HDD method, HDD Contingency Plan, Venture Global’s
CMP, Project-specific Upland Erosion Control, Revegetation, and Maintenance Plan (Plan) andProcedures, and our recommendations, we conclude that impacts on water and wetland resources
due to construction and operation of the Project would be minimized to the extent practicable andwould not be significant.
VEGETATION
Construction and operation of the LNG terminal facilities would permanently affectapproximately 624.3 acres of vegetation, resulting in the loss or conversion to developed area of
palustrine emergent wetlands, palustrine forested wetlands, forested scrub/shrub uplands, andherbaceous uplands.
Construction of the pipeline system would affect about 74.9 acres of vegetation, of which
2.2 acres would be permanently lost as it would be associated with aboveground facility sites andpermanent access roads. The primary impacts on vegetation from construction would be thecutting and clearing of existing vegetation within the construction work areas. Impacts resulting
from operation of the facilities would include conversion of some scrub-shrub vegetation toherbaceous vegetation due to maintenance of the pipeline right-of-way, and conversion ofvegetation within new aboveground facilities to non-vegetated land. Impacts on vegetation within
the pipeline right-of-way and ATWS would be temporary and short-term because these areas
would revegetate within one to two growing seasons.
One vegetation community of special concern (Coastal Live Oak-Hackberry Forest naturalcommunity, also known as a Chenier) was identified by the Louisiana Department of Natural
Resources as potentially present in the Project area. During field surveys, 4.0 acres of Coastal
Live Oak-Hackberry Forest were found within the footprint of the pipeline system. Of the 4.0
acres, 1.6 acres would be avoided by HDD, 0.7 acre would eventually recover after construction,and 1.7 acres would be permanently converted from Coastal Live Oak-Hackberry Forest to
herbaceous uplands. This vegetation community is in proximity to the non-federal levee, and thenon-federal levee would be crossed with a pipe bridge. The location of the HDD entry site islimited by the proximity to the pipe bridge. Therefore, impacts on this vegetation community
cannot be avoided. This represents a relatively small percentage of the remnants of this naturalcommunity.

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To minimize impacts of the Project on vegetative communities, Venture Global would
construct and operate the LNG terminal and pipeline system in accordance with its Project-specificPlan and Procedures. With the implementation of the proposed mitigation measures we conclude
that construction and operation of the Project would not have a significant impact on vegetation
communities in the Project area.
WILDLIFE AND AQUATIC RESOURCES
Wildlife Resources
Although construction of the LNG terminal and pipeline system could cause displacement,
stress, and direct mortality of some individuals, construction and operation of the LNG terminal
would not have significant long-term impacts on wildlife species due to the degraded wildlife
habitat value provided at the site and the proposed mitigation for wetland impacts. Operation of
the LNG terminal would result in increased noise, lighting, and human activity that could disturb
wildlife in the area. However, due to the existing heavy ship traffic and other industrial uses along
the Mississippi River, most wildlife in the area are acclimated to the noise and artificial lighting
associated with these activities. In addition, the pipeline system operations require little lighting,activities, or other disturbances that would affect wildlife. We conclude that the LNG terminaland pipeline system’s operational impacts on wildlife would be minimized and not significant.
Venture Global would implement the Project-specific Plan and Procedures to restore habitat in thetemporary workspace following construction.
The vegetative communities in the Project area provide potential habitat for migratory bird
species, including songbirds, waterbirds, and raptors. Much of the approximately 650 acres ofhabitat associated with the LNG terminal site was previously disturbed by cattle grazing and past
fill activities that reduce nesting habitat value. However, the undisturbed areas contain higher
quality nesting habitat that would be more attractive to breeding bird species. Much of the habitat
along the pipeline system consists of wetlands, which provide habitat for waterfowl and othermigratory birds. At the LNG terminal site, and where practicable along the pipelines, Venture
Global would conduct clearing in potential nesting habitat outside the nesting season from March
1 to July 31, as recommended by U.S. Fish and Wildlife Service (FWS). Where clearing cannot
occur outside of the nesting window, Venture Global has committed to conduct preconstruction
surveys of the Project area and if active nests are detected, they would be avoided until young havefledged.
Colonial waterbird nesting colonies occur within the Project area, specifically within 600
to 1,800 feet of the pipelines. The Louisiana Department of Wildlife and Fisheries (LDWF) and
FWS provided guidelines for preconstruction site visits and, if warranted, distance and timing
restrictions. In the draft EIS, we recommended that Venture Global conduct surveys and consult
with the LDWF regarding nesting colony bird surveys and additional mitigation measures for rare
wildlife species with potential habitat in the LNG terminal and pipeline system area, and file that
information for review and approval prior to construction. Venture Global committed to theimplementation of the measures recommended by the FWS and LDWF and, therefore, we
conclude that impacts on wildlife, including migratory birds and colonial waterbirds, would beless than significant.

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Aquatic Resources and Essential Fish Habitat
Construction of the LNG terminal marine facilities, berthing area and turning basin would
not require dredging/excavation of the Mississippi River. However, marine facility construction
would require driving concrete pilings in water with vibratory and impact pile drivers to install
docks and berthing structures. Potential impacts from these activities include increased
sedimentation, turbidity, and noise levels, which could adversely affect aquatic resources. During
construction of the two meter stations along the pipeline system in Barataria Bay, multiple 12inch-diameter steel piles would be installed during construction, as well.
Impacts on aquatic resources due to increased turbidity and suspended sediment levels
would vary by species; however, the aquatic resources within the Project area are likely
accustomed to regular fluctuations in turbidity levels from industrial activity and regular
maintenance dredging within the Mississippi River. Substrates within the Mississippi River are
considered early successional due to frequent disturbance from maintenance dredging, propeller
wash, and vessel traffic. The soft bed substrates that characterize the Project vicinity are prone to
dynamic patterns of sediment scour and deposition, favoring organisms that are adapted to a
dynamic bed environment, and, therefore, would recover quickly after construction. We conclude
that sedimentation and turbidity impacts on aquatic resources from pile driving and other intrusive
activities would be localized, temporary, and minor.
Underwater noise impacts from pile driving may result in injury or trauma to fish, sea
turtles, and other aquatic species if measures are not implemented to avoid and minimize thesepotential impacts. Venture Global is implementing noise attenuation measures to substantiallyreduce underwater sound pressure levels produced by pile driving, thereby reducing the extent ofpotential behavioral and injury level effects on aquatic species. Venture Global has developed an
Underwater Noise Mitigation Plan through consultation with the National Marine FisheriesService (NMFS) and the FWS, which would reduce impacts to acceptable levels.
Venture Global would construct the majority of its pipelines using the barge lay and push
lay methods as well as the two HDDs (one for each pipeline lateral in the same location), to crosswetlands, a canal, and proposed floodwall. This would avoid or minimize impacts on fisheries,
fish habitat, and other aquatic resources. The majority of fish species present within thewaterbodies at the time of construction activities would likely be displaced to similar adjacent
habitats; however, stress, injury, or death of individual fish may occur. Increased suspended
sediment and turbidity levels may also cause degradation of benthic and spawning habitat anddecreased dissolved oxygen levels within the crossing location. Venture Global would implement
the measures outlined in its Project-specific Procedures to minimize impacts on waterbodies andaquatic resources during pipeline system construction. In addition, Venture Global has received
permission from LDWF to conduct year-round construction if necessary in regard to the agency’s
proposed in-water construction windows. Once construction of the pipeline system is complete,beds and banks would be restored to their preconstruction conditions and contours to the maximum
extent practicable. Operation of the pipeline system would not affect aquatic resources. With
implementation of the mitigation measures described above, we anticipate that the construction
and operation of the pipeline system would have minimal, localized, and no significant impacts onaquatic resources.

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NMFS concluded that the Project area is located along a portion of the Mississippi Riverthat does not provide essential fish habitat (EFH) and thus LNG terminal construction for themarine facilities would not affect EFH. Approximately 775.4 acres of estuarine open water
mapped as EFH and 423.9 acres of estuarine open water not mapped as EFH (in Lake Laurier,Barataria Bay, and Wilkinson Bay), along with approximately 64.5 acres of estuarine emergent
wetlands that can function as EFH, would be temporarily modified by dredging, excavation, andrelated activities within the workspace required for pipe installation, meter station construction,and barge access channels. However, no submerged aquatic vegetation was identified during
Venture Global’s field surveys at proposed dredging/excavation locations. Therefore, no impacts
on submerged aquatic vegetation are expected. Construction impacts of the pipeline system,
including increased turbidity, loss of benthic habitat, and habitat modification, are expected to beminor or of short duration, as populations of EFH species and their food sources would be expected
to recover quickly following construction. These impacts would also be minimized throughimplementation of the Project-specific Procedures, Venture Global’s Spill Prevention, Control,and Countermeasures (SPCC) Plan, and the HDD Contingency Plan. Therefore, we conclude that
construction of the pipeline system would adversely affect EFH, but these adverse effects would
be temporary.
THREATENED AND ENDANGERED SPECIESThe FWS Louisiana Ecological Services list of endangered, threatened, and candidate
species by county identified 10 species as potentially present in Plaquemines Parish, including theWest Indian manatee (Trichechus manatus), piping plover (Charadrius melodus), red knot
(Calidris canutus rufa), Gulf sturgeon (Acipenser oxyrinchus desotoi), pallid sturgeon(Scaphirhynchus albus), and five species of sea turtles. NMFS identified 12 federally listed
threatened and endangered species that may occur in the Project area, including three fish, five sea
turtles, and four whales. In October 2018, the FWS proposed the eastern black rail black rail
(Laterallus jamaicensis jamaicensis) for listing as threatened under the Endangered Species Act
of 1973, and there is appropriate habitat for the eastern black rail within the project area. Potential
impacts on aquatic and terrestrial habitats and species have been described above, and those same
impact types apply to threatened and endangered species. We determined that the Project is not
likely adversely affect federally listed threatened and endangered species is not likely to jeopardize
the continued existence of the proposed-threatened eastern black rail. As required by section 7 of
the Endangered Species Act of 1973, we request that the FWS and NMFS accept the information
provided in this EIS as the Biological Assessment for the Project. We also recommend that
Venture Global should not begin any Project construction until FERC staff completes Endangered
Species Act consultation for the Project.
LAND USE, RECREATION, AND VISUAL RESOURCES
The Project would be within the Louisiana Coastal Zone. All activities or developmentsthat may affect Louisiana’s coastal zone require a federal consistency review under the National
Coastal Zone Management Program and must obtain a Coastal Use Permit from the Louisiana
Department of Natural Resources. To ensure compliance with this federal requirement, werecommend that Venture Global file the consistency determination, prior to any LNG terminal andpipeline system construction.

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The majority of the LNG terminal facilities would be within cultivated crop land, which
encompasses active cropland, pasture, and hayfields. Forested land, wetlands, developed
commercial/industrial land, open water, herbaceous land, and scrub-shrub are the other U.S.
Geological Survey land use classifications that would be affected. The proposed LNG terminal isentirely on private lands, and no federal or state-managed public lands are within 0.25 mile of thesite. There are currently no existing or planned residential or commercial developments within
0.25 mile of the LNG terminal. There are both existing and planned industrial developments
within the vicinity of the LNG terminal.
The Plaquemines Parish developed a Comprehensive Master Plan in 2012 for the LNG
terminal site (as well as other lands within Plaquemines Parish). The Project would be consistent
with the Parish Plan for development because most of it would be constructed on properties
identified in the Parish Plan for “port/terminal” and “major industries.”
There are no wildlife refuges, preserves, or conservation areas located within 16 miles of
any Project workspace. The three wildlife refuges located in Plaquemines Parish—Breton
National Wildlife Refuge, Delta National Wildlife Refuge, and Pass A Loutre State Wildlife
Refuge—are all located over 35 miles from any Project workspace and would not be affected by
Project construction or operation activities. A private conservation area, Woodland Trail and Park,and a preserve, Jean Lafitte National Historic Park and Preserve, are both located over 16 miles
from any Project workspace and would not be affected by Project construction or operation.
The Barataria-Terrebonne National Estuary is located between the Mississippi andAtchafalaya Rivers in south Louisiana. The estuary’s watershed includes the LNG terminal siteand pipeline system right-of-way. Construction of the pipelines would require dredging ofchannels within the Barataria-Terrebonne estuary to provide temporary access for pipeline lay
barges and support vessels. Recreational boaters in the Barataria-Terrebonne estuary may be
temporarily prevented from using channels during these dredging operations. Users may also
observe a temporary increase in barge traffic during construction of the pipeline system. These
impacts on boaters would be temporary and minor.
Four restoration areas, Lake Hermitage Marsh Creation (BA-42), Fringe Marsh Repair,West Pointe a lá Hache Siphon Diversion, and Bayou Grande Cheniere Marsh and Ridge
Restoration are located between 3.0 miles and 7.7 miles from any Project component. No impacts
are anticipated at these restoration areas from either direct contact or indirect tidal influences.
West Pointe a lá Hache Marina is located 0.4 mile northeast of the terminal site. The
marina is located off of the Back Levee Canal that parallels the east bank of the Mississippi River.
Lake Hermitage Marina is located 1.8 miles to the east of the Southwest Lateral TGP. St. Jude
Hump Public Boat Launch is located 1.8 miles southeast of the LNG terminal site. Woodland
Plantation is located 2.8 miles east of the LNG terminal site. None of these facilities are expected
to be affected by the Project aside from alteration of the viewshed. We have determined the Project
would have some adverse impacts on recreation, including boating and fishing along theMississippi River and Barataria Bay.

ES-8

The presence of the LNG terminal and associated increased lighting from exterior plantlighting, air navigation lighting, LNG storage tanks, electric power generation facilities,
liquefaction heat exchangers, air coolers, and the flare stack would have a minor adverse influenceon visual resources. The location of the LNG terminal would be in the viewshed of local residents,
drivers, and visitors travelling along State Highway 23 and other nearby road. Therefore, the LNG
facility could have a minor adverse impact on the residents, drivers, and recreational/commercial
users of the area.
Construction and operation of the pipeline system may affect visual resources through theremoval or alteration of existing vegetation as well as earthwork and grading scars associated withheavy equipment tracks, trenching, and dredging. A pipe bridge over State Highway 23 and othernew aboveground facilities also would be built that would be visible to outside viewers. As muchof the pipeline system would be located in rural or industrial areas, the pipeline system would be
anticipated to cause minor impacts with regard to visual resources and permanent but minor
impacts from the meter stations. Existing vegetation would help to provide some visual buffersfrom the operation of the pipeline system. In areas where vegetation would be removed or altered,pre-Project conditions would be restored along the pipeline system according to the Projectspecific Plan and Procedures.
SOCIOECONOMICS
Construction of the Project would stimulate local economies by generating construction
jobs and sales and payroll taxes and increasing demand for local goods, services, and equipment,
including in the study area parishes of Plaquemines, Jefferson, and Orleans. The Project would
increase economic activity along supply chains and increase consumer spending throughworkforce compensation, contributing to a moderate or more substantial local benefit over the 4.5
years of construction and a year or two after construction ends. Venture Global estimates 10
percent of the total estimated Project cost of $8.5 billion would be spent locally or regionally.
Economic impacts and employment benefits during operation would be permanent as
Venture Global would hire 250 workers with average salaries of $75,000 to $90,000, excluding
benefits, with combined annual payroll of $21 million. It would spend approximately $20 million
annually on materials, land leases, and utilities (water, sewer, waste disposal). Initially, its
operational tax contributions would be a minor benefit at the local and state levels, consisting of
payroll, income, and sales taxes and ad valorem taxes on the pipeline system. Venture Global has
been awarded a Louisiana Industrial Tax Exemption Program waiver on ad valorem taxes on the
LNG terminal for up to 5 years with the opportunity to renew for an additional 5 years.
Neither construction nor operation would have significant adverse impacts on housing
supply or provision of community services, though effects on temporary housing could benoticeable and minor in specific locations within the study area. Neither construction nor operation
would have disproportionately high or adverse environmental and human health impacts on lowincome and/or minority populations.
Given the width of the Mississippi River and the volume of vessel traffic it handles
currently, the vessel traffic contributed by the Project during construction or operation would beunnoticeable. During construction, vehicle traffic congestion on State Highway 23 during peakcommute hours would be minimized through Venture Global’s multiple mitigation measures,
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including limiting worker parking passes to induce carpooling, constructing turning lanes along
State Highway 23 at its intersection with the terminal entrance, and stationing a police officer tocontrol traffic during rush hours.
AIR QUALITY AND NOISE
Air quality would be affected by construction and operation of the Project. Air pollutant
emissions would be generated by operation of equipment during construction of the Project
facilities, a combination of construction emissions and interim operating emissions would occur
for an approximately 4-year period, followed by long-term operational emissions. The highest
level of emissions associated with the Project would result from the combination of construction
and interim operation of the LNG terminal.
Plaquemines Parish is designated as
unclassifiable/attainment for all criteria pollutants (ozone [O3], particulate matter less than 2.5
microns in aerodynamic diameter, particulate matter less than 10 microns in aerodynamic
diameter, carbon monoxide and nitrogen dioxide).
The Project would not lead to impacts above standards or other thresholds on any special
national (Class I) or regional natural, scenic, recreational, or historic value areas for which thePrevention of Significant Deterioration regulations provide special protection. As a new facility,
the Project must obtain an air quality permit from the Louisiana Department of Environmental
Quality, who is the lead air permitting authority for the Project, prior to initiating construction.
Emissions from construction equipment would be temporary and depend on the durationand type of construction activity, together with the number and type of vehicles and equipment in
use at any point in time. Pipeline construction would have short-term and localized construction
emissions as equipment and activities move sequentially along the route, and would depend on theequipment being operated at any given time. Venture Global has identified the specific measures
it would implement to control fugitive dust emissions during construction at the LNG terminal andpipeline system in a Fugitive Dust Control Plan.
Operation of the Project would result in long-term air pollutant emissions from stationary
equipment at the LNG terminal site, including combustion turbines, duct burners, diesel engines
for backup generators, and fugitive emissions from various components. In addition, the LNG
terminal marine facility would be a source of emissions, as well as fugitive emissions from various
onshore components. Stationary emissions sources associated with the pipeline system would
include pig launcher/receivers, meter stations, mainline valves, and fugitive emissions fromvarious components.
Mobile sources of operational emissions would include cars, trucks, and marine vessels
associated with the LNG terminal facility. Marine vessels that would produce operationalemissions would include LNG carriers at berths, LNG carriers underway, escort tug boats, andsecurity vessels.

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Venture Global estimated ambient pollutant concentrations in the vicinity of the Project.
The analysis for all pollutants except O3 used the EPA’s AERMOD to predict maximum shortterm and annual concentrations. The modeling analysis and “culpability analysis” in the
cumulative modeling study showed that the Project would not significantly contribute to any ofthe modeled National Ambient Air Quality Standard (NAAQS) exceedances, and is shown to be
in compliance with the NAAQS.
Venture Global performed additional assessments, based on the results of the NAAQS, ofpotential impacts from air emissions on Class I areas (Breton National Wildlife Refuge); soils,
vegetation, and wildlife; and effects on development growth. The Project would not have asignificant impact on pollutant concentrations or visibility impairment in any Class I areas or resultin significant impacts on soils, vegetation, or wildlife as a result of air emissions.
Venture Global performed another air quality modeling analysis to quantify the potential
impact of the Project on O3 concentrations in the surrounding area, relative to the 8-hour O3
NAAQS. The analysis determined that the addition of the modeled Project impact on backgroundconcentrations would not exceed the 70 parts per billion 2015 O3 NAAQS. Therefore, the Project
would not cause or contribute to a violation of the O3 NAAQS.
During the construction period, residents in the vicinity of the Project would experience
local impacts on air quality. Concurrent emissions from staged construction, commissioning andstart-up, and operation of the LNG terminal would temporarily impact local air quality, and could
result in exceedances of the NAAQS in the immediate vicinity of the LNG terminal during these
construction years. These exceedances would not be persistent at any one time during these years
due to the dynamic and fluctuating nature of construction activities within a day, week, ormonth. During operation, extensive modeling has indicted that the Project would not havesignificant impacts on the local and regional air quality and Class I areas.
Pile driving, both land-based and marine-side, and internal combustion engines associatedwith LNG terminal construction would generate noise. Pile driving could produce peak soundlevels perceptible above the background sound levels at the nearest noise-sensitive areas (NSAs).
Construction operating hours would be from 7:00 a.m. to 7:00 p.m., Monday through Saturday.
Land-based and marine-side pile driving, which is the loudest construction activity, is expected toalso occur six days per week starting at 7:00 a.m., as well, but would end at 5:00 p.m. Pile driving
activities could occur for 16 months. Venture Global has committed to implementing mitigation
measures to reduce land-based and marine-side pile-driving noise impact on NSAs.
With implementation of the mitigation measures identified in the noise analysis, theresulting noise at the NSAs would meet our criteria of a day-night average sound level (Ldn) of 55
dBA. In order to ensure implementation of these measures, we recommend that Venture Global
file a noise survey after placing each phase of liquefaction blocks into service and after placing theentire LNG terminal into service to confirm that the criteria would be met.
With the exception of the HDD activities, normal pipeline construction would be limited
to daytime hours, minimizing any impacts on nearby residences. Construction noise from barge
access channel dredging would last approximately 1 month and would vary as dredging progresses
along the corridor. Twenty-five structures and potential residences are located near a barge access

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dredging location. Venture Global would engage owners of any occupied residences to implement
suitable mitigation if dredging activities increase noise at the potential NSAs to no greater than 10
dBA above ambient noise levels. Venture Global has also committed to implement a sound curtain
enclosure (height to be determined during installation) as necessary around the HDD drilling rig
and other stationary equipment to minimize noise impacts at NSAs to under 10 A-weighted scale(dBA) above ambient noise levels.
Impacts associated with pipeline HDD and dredging activities would be temporary andminor at NSAs and potential noise receptors. Further implementation of sound curtains or acoustic
barriers, as necessary, would further minimize this temporary impact.
Based on the analyses conducted and our recommendations, we conclude that operation of
the LNG terminal and pipeline system would not result in significant noise impacts on NSAs.
RELIABILITY AND SAFETY
As part of the NEPA review, Commission staff assesses the potential impact on the humanenvironment in terms of safety and assess whether the proposed facilities would be able to operatesafely, reliably, and securely.
As a cooperating agency, the DOT assists FERC staff in evaluating whether Venture
Global’s proposed design would meet the DOT’s 49 Code of Federal Regulations (CFR) 193
Subpart B siting requirements. The DOT provided a Letter of Determination confirming the
Project’s compliance with 49 CFR 193 Subpart B on April 3, 2019. This determination wasprovided to the Commission for its consideration on whether to authorize or deny the Project. If
the Project is authorized and constructed, the facility would be subject to the DOT’s inspectionand enforcement program and final determination of whether a facility is in compliance with therequirements of 49 CFR 193 would be made by the DOT staff.
As a cooperating agency, the USCG reviewed the proposed LNG terminal and theassociated LNG carrier traffic. The USCG reviewed a Water Suitability Assessment (WSA)
submitted by Venture Global that focused on the navigation safety and maritime security aspectsof LNG carrier transits along the affected waterway. On January 23, 2017, the USCG issued aLetter of Recommendation to FERC indicating the Lower Mississippi River would be considered
suitable for accommodating the type and frequency of LNG marine traffic associated with thisProject, based on the WSA and in accordance with the guidance in the USCG’s NVIC 01-11. If
the Project is authorized and constructed, the facility would be subject to the USCG’s inspectionand enforcement program to ensure compliance with the requirements of 33 CFR 105 and 33 CFR
127.
We conducted a preliminary engineering and technical review of the Venture Global
design, including potential external impacts based on the site location. Based on this review, we
recommend the Commission Order include a number of mitigation measures prior to initial site
preparation, prior to construction of final design, prior to commissioning, prior to introduction of
hazardous fluids, prior to commencement of service, and throughout life of the facility to enhance
the reliability and safety of the facility. With the incorporation of these mitigation measures, weconclude that the Venture Global Project design would include acceptable layers of protection or

ES-12

safeguards that would reduce the risk of a potentially hazardous scenario from developing into an
event that could impact the offsite public.
CUMULATIVE IMPACTS
During the cumulative impact analysis, we identified 16 permitted or proposed actions,
including the Project that warranted careful consideration based on geographic and temporal
criteria we established for each environmental resource. Six major industrial developments,
including the Project, planned on the banks of the Mississippi River in Plaquemines Parish
presented the highest potential for creating cumulative adverse effects. These industrial
developments, all within 21 miles of each other, include two methanol manufacturing facilities;
three LNG manufacturing facilities and export terminals, including the Project; an oil blending,storage, and distribution facility; and a container shipping terminal.
Based on our evaluations of resources affected by the Project and the proposed activities
associated with the other actions, the following resources would not sustain significant adverse
cumulative impacts: geology; soils; surface waters and aquatic wildlife and habitat; wetlands;
vegetation and wildlife; land use; visual resources; socioeconomics; vessel traffic; roadway traffic,
cultural resources; and the noise environment. Our analysis did consider in detail whether the
Project could result in cumulative impacts on air quality in the geographic area as discussed below.
The Clean Air Act and implementing regulations establish limits on pollutant emissions
from major industrial developments, among others. Venture Global prepared a modeling study of
the LNG terminal’s future effects on air quality that includes emissions from the permitted, as-yetunconstructed Braithwaite Methanol Manufacturing Plant and NOLA Oil Terminal anddemonstrated that their combined emissions would not exceed the NAAQS. Gulf Coast Methanol
Park was issued an air permit in January 2018, and Venture Global updated its cumulativemodeling to include Gulf Coast Methanol Park. Emissions from vessels, vehicles, and othermobile sources associated with operation of the foreseeable industrial facilities along theMississippi River could contribute to an adverse effect on air quality. Vessel emissions are notaddressed in Louisiana Department of Environmental Quality regulations and air permit
application requirements, but the International Maritime Organization, of which the U.S. is amember, promulgates emissions standards limiting sulfur oxides and nitrogen oxide. Also, the
EPA adopted emission standards on engines installed on U.S. vessels. Thus, the resulting
cumulative effect of vessel emissions on air quality in the geographic scope of the Project is not
likely to be significant. Although cumulative modeling showed the potential for NAAQS
exceedances, the modeling indicates that the Project would not contribute above significant levels
and therefore would not contribute to an adverse combined effect of the Project and other existing
and foreseeable actions.
ALTERNATIVES CONSIDERED
We evaluated several alternatives to the Project, including the No Action Alternative,
system alternatives for the proposed LNG terminal, alternative LNG terminal sites, alternative
LNG terminal configurations, alternative pipeline system routes, and alternative abovegroundfacility sites. While the No Action Alternative would eliminate the short- and long-term
environmental impacts identified in the EIS, the stated objectives of the proposed action would not
be met.
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System alternatives evaluated for the LNG terminal included 10 existing LNG
import/export terminals with approved, proposed, or planned expansions to provide liquefaction
capabilities and 12 approved, proposed, or planned stand-alone LNG Projects. We cannot
speculate or conclude that excess capacity would be available to accommodate the Project’s
purpose and need. Therefore, construction of this Project as part of another site would likely
require an expansion or new facilities similar to the proposed facilities, resulting in environmental
impacts similar to the Project. Therefore, these systems alternatives would not offer a significant
environmental advantage over the Project.
Using a set of selection criteria, six potential sites were evaluated by Venture Global todetermine the preferred location for the LNG terminal. Of the alternative terminal locations, weconclude that the proposed site (Mississippi River Mile 55-West Bank) represents an acceptablesite for the LNG terminal. The proposed site is currently zoned for heavy industrial use, issufficiently sized to allow optimal facility layout design, and has available the necessary water
frontage for three LNG carrier berths. The proposed site is also well separated from population
centers and most permanent residences. The proposed site is the only alternative that satisfies allof the selection criteria. From a visual impact perspective, the LNG terminal would be consistent
with existing and foreseeable industrial development along this portion of the Mississippi River.
We evaluated the proposed LNG terminal configuration and Project specifications relative
to impacts on wetlands and other sensitive resources. We did not find any alternative
configurations that would meet the required regulations, codes, and guidelines and at the sametime further avoid or reduce environmental impacts associated with the Project.
One alternative pipeline system design and two major route alternatives were evaluatedduring the early stages of the Project application process. Initially, at the start of the pre-filingprocess, the planned Venture Global pipeline system consisted of three pipelines on three routes
that would supply feed gas to the Venture Global terminal facility: the 21.2-mile-long Northwest
lateral, 12.1-mile-long Southeast lateral, and 11.1-mile-long Southwest lateral pipelines. During
the pre-filing process, Venture Global continued to evaluate and further its Project design. When
Venture Global filed its application for the proposed pipeline system with FERC, it had removed
the Northwest lateral and Southeast lateral from the Project. It also modified and renamed theSouthwest Lateral pipeline route so that it now includes two collocated pipelines identified asSouthwest Lateral TETCO and Southwest Lateral TGP. Venture Global proposes to construct andoperate these two parallel pipelines in one right-of-way corridor.
The two route alternatives for the pipeline system are both over 11 miles long and generally
trend in the same direction as the preferred route. These two alternatives did not offer any
environmental advantages over the preferred route.
Proposed aboveground facilities for the pipeline system would include six MLVs, three pig
launchers, two pig receivers, and two metering and regulation stations. All of these facilities
would occur within or adjacent to the Southwest laterals pipeline route right-of-way. Thesefacilities are small, would only affect environmentally sensitive areas to a minimal extent, are not
located near residences, and their locations are tied to the locations of the required interconnect
pipeline facilities. We did not identify any environmental concerns that require the need to identify
and evaluate alternative sites for these minor aboveground facilities, nor were any alternatives
ES-14

suggested during the public scoping period. Therefore, we concluded that the proposed
aboveground facility sites are the preferred alternative.
CONCLUSIONS
We determined that construction and operation of the Project would result in adverse
environmental impacts, but all of these impacts would be reduced to less-than-significant levels.
From a cumulative impact perspective, we determined, based on cumulative air quality modeling
results, that the Project would not contribute significantly to combined air quality impacts withother projects in the geographic scope that may result in exceedance of the NAAQS. This
determination is based on a review of the information provided by Venture Global and further
developed from data requests; field investigations; scoping; literature research; alternatives
analysis; and contacts with federal, state, and local agencies as well as Indian tribes and individual
members of the public.
Although many factors were considered in this determination, the principal reasons are:

The HDD method would be used for the installation of the pipeline system to avoid
direct affects to a canal and large wetland area and most of the pipelines would beinstalled in open water, which would minimize impacts on sensitive wetland resources.



Venture Global would mitigate wetland impacts associated with the construction andoperation of the proposed LNG terminal and the pipeline system with theimplementation of its CMP and in accordance with USACE permit regulations.



FERC staff would complete the process of complying with section 7 of the Endangered
Species Act prior to construction.



FERC staff would complete consultation under Section 106 of the National HistoricPreservation Act and its implementing regulations at 36 CFR 800 prior to construction.

Venture Global would minimize impacts on environmental resources during
construction and operation of the Project by implementing, as applicable, their Projectspecific Plan and Procedures; HDD Contingency Plan; and SPCC Plan.

The siting requirements of DOT for the LNG terminal, the Letter of Recommendation
issued by the USCG for the LNG marine traffic in the Mississippi River, FERC staff’s
preliminary engineering review and recommendations for the LNG terminal, and theregulatory requirements for the pipeline system and LNG terminal would avoid asignificant increase in public safety risks.

An environmental inspection program would be implemented to ensure compliancewith the mitigation measures that become conditions of FERC authorization.

We developed recommendations that Venture Global should implement to further reduce
the environmental impacts that would otherwise result from construction and operation of the
Project. We determined that these measures are necessary to reduce adverse impacts associatedES-15

with the Project and, in part, are basing our conclusions on implementation of these measures.
Therefore, we recommend that these mitigation measures be attached as conditions to any
authorization issued by the Commission. These recommended mitigation measures are presented
in section 5.2 of the EIS.

ES-16

1.0

INTRODUCTION

The staff of the Federal Energy Regulatory Commission (FERC or Commission) preparedthis environmental impact statement (EIS) to describe our assessment of the potential
environmental impacts that may occur from constructing and operating the projects proposed by
Venture Global Plaquemines LNG, LLC (Plaquemines LNG) and Venture Global Gator Express,
LLC (Gator Express Pipeline) in Plaquemines Parish, Louisiana.
On February 28, 2017, Plaquemines LNG filed an application with the Commission forauthorization pursuant to section 3(a) of the Natural Gas Act (NGA) and part 153 of theCommission’s regulations. In Docket No. CP17-66-000, Plaquemines LNG requests authorization
to site, construct, and operate natural gas liquefaction, storage, and export facilities at a liquefied
natural gas (LNG) terminal on the west bank of the Mississippi River in Plaquemines Parish,
Louisiana (the LNG terminal).
Also on February 28, 2017, Gator Express Pipeline filed an application with FERC for a
Certificate of Public Convenience and Necessity (Certificate) pursuant to section 7(c) of the NGA
and part 157 of the Commission’s regulations. In Docket No. CP17-67-000, Gator Express
Pipeline requests authorization to construct and operate associated lateral pipelines that would
connect the LNG terminal to the existing U.S. natural gas transmission grid (pipeline system). The
pipeline laterals would be located within Plaquemines Parish, Louisiana.
The combined Plaquemines LNG and Gator Express Pipeline actions and facilities arereferred to herein as the Project, and the applicants are collectively referred to as Venture Global.
As part of the Commission’s consideration of these applications, we 1 prepared this draft EIS toassess the potential environmental impacts resulting from the construction and operation of the
Project in accordance with the requirements of the National Environmental Policy Act of 1969
(NEPA).
The vertical line in the margin identifies text that is new or modified in the final EIS
and differs materially from corresponding text in the draft EIS. Changes were made to addresscomments from cooperating agencies and other stakeholders on the draft EIS, incorporate
modifications to the Project after publication of the draft EIS, update information included in
the draft EIS, and incorporate information filed by Venture Global in response to ourrecommendations in the draft EIS. As a result of the changes, nine of the recommendations
identified in the draft EIS are no longer applicable to the Project and do not appear in this final
EIS. In addition, eight recommendations identified in the draft EIS have been substantively
modified in the final EIS, and nine new recommendations have been added to the final EIS.

1

“We,” “us,” and “our” refer to the environmental and engineering staff of FERC’s Office of Energy Projects.

1-1

The LNG terminal would be located on an approximately 632-acre parcel of land on thewest bank of the Mississippi River, about 20 miles south of Belle Chasse, Louisiana. This would
be a new facility and would include 18 integrated single mixed-refrigerant blocks and support
facilities (otherwise referred to as liquefaction blocks or blocks) with a nameplate production
capacity of 20.0 million metric tons per annum (MTPA) of LNG and peak production capacity of
24 MTPA. Natural gas would be delivered to the LNG terminal via the pipeline system, which
would connect the terminal with two existing interstate pipeline systems. Specifically,
construction of the pipeline would consist of the Southwest Lateral Texas Eastern Transmission,
LP (TETCO) pipeline (11.7 miles) and the Southwest Lateral Tennessee Gas Pipeline, LLC (TGP)
pipeline (15.1 miles).
Subject to the receipt of FERC authorization and all other applicable permits,authorizations, and approvals, Venture Global anticipates it would commence a two-phased
construction approach for the liquefaction facility after receiving the FERC authorization. Phase
I is anticipated to last approximately 35 months. Phase II would commence 12 months after thestart of Phase I and also last 35 months. The Southwest Lateral TGP pipeline would be installed
during the Phase I construction process, while the Southwest Lateral TETCO pipeline would beconstructed concurrently with Phase II facilities.
Section 3 of the NGA, as amended, requires that authorization be obtained from the U.S.
Department of Energy (DOE) prior to importing or exporting natural gas, including LNG, from or
to a foreign country. For applicants that have, or intend to have, a signed gas purchase or sales
agreement/contract for a period of time longer than 2 years, long-term authorization is required.
Under section 3 of the NGA, FERC considers, as part of its decision to authorize natural gas
facilities, all factors bearing on the public interest. Specifically, regarding whether to authorize
natural gas facilities for importation or exportation, FERC shall authorize the proposal unless it
finds that the facilities will not be consistent with the public interest.
Under section 7 of the NGA, the Commission determines whether interstate natural gas
transportation facilities are in the public convenience and necessity and, if so, grants a Certificate
to construct and operate these facilities. The Commission bases its decisions on technicalcompetence, financing, rates, market demand, gas supply, environmental impact, long-term
feasibility, and other issues concerning a project.
1.1

PROJECT PURPOSE AND NEED

Venture Global states that the purpose of the Project would be to transport and liquefy
domestic natural gas in order to provide a cost-effective outlet for the domestic natural gas to theglobal market. This would be accomplished by constructing liquefaction blocks and a new pipeline
for feed gas at a new facility along the Mississippi River and loading LNG into vessels berthed at
the Venture Global marine facility to transport LNG to global markets. Any exports would beconsistent with authorizations from the DOE.

1-2

1.2

PURPOSE AND SCOPE OF THIS ENVIRONMENTAL IMPACT STATEMENT
The principal purposes in preparing an EIS include the following:•

identify and assess potential impacts on the human environment that would result from
implementation of a proposed action;•

identify and assess reasonable alternatives to a proposed action that would avoid or
minimize adverse effects on the human environment;•

facilitate public involvement in identifying significant environmental impacts; and•identify and recommend specific mitigation measures to avoid or minimize
environmental impacts.

This EIS focuses on the facilities that are under FERC’s jurisdiction (i.e., the new terminal
and liquefaction facility and the new pipelines). The topics addressed in this EIS include geology;
soils; water use and quality; wetlands; vegetation; wildlife; fisheries and essential fish habitat(EFH); threatened, endangered, and special status species; land use, recreation, and visual
resources; socioeconomics; cultural resources; air quality; noise; reliability and safety; cumulative
impacts; and alternatives. This EIS also presents our conclusions and recommended mitigation
measures.
The Energy Policy Act of 2005 (EPAct 2005) provides that FERC shall act as the leadagency for coordinating all applicable authorizations related to jurisdictional natural gas facilities
and for purposes of complying with NEPA. FERC, as the lead federal agency, is responsible forpreparation of this EIS. This effort was undertaken with the participation and assistance of the
U.S. Army Corps of Engineers (USACE), U.S. Coast Guard (USCG), DOE, U.S. Department ofTransportation (DOT) Pipeline and Hazardous Materials Safety Administration (PHMSA), and the
U.S. Environmental Protection Agency (EPA) as cooperating agencies under NEPA. Cooperating
agencies have jurisdiction by law or special expertise with respect to environmental impacts
involved with a project. The roles of FERC, the USACE, USCG, DOE, DOT/PHMSA, and EPA
in the project review process are described below. This EIS provides a basis for coordinatedfederal decision making in a single document, thereby avoiding duplication among federal
agencies in the NEPA environmental review processes. In addition to the lead and cooperating
agencies, other federal, state, or local agencies may use this EIS in approving or issuing permits
for all or part of the Project. Federal, state, and local permits, approvals, and consultations for the
Project are discussed in section 1.5.
During the draft EIS comment period, a commenter suggested the Project cannot proceedwithout “a regional programmatic EIS for all such economically connected actions for all across
New Orleans and Galveston Districts.” Because the Commission does not have a program to direct
the development of the natural gas industry’s infrastructure, either on a broad regional basis or in
the design of specific projects, and does not engage in regional planning exercises that would resultin the selection of one project over another, we have determined that it would not be appropriate
to prepare a programmatic EIS. This EIS analyzes the project-specific impacts of Plaquemines

1-3

LNG, and includes a discussion of cumulative impacts associated with other nearby actions
affecting the environment in the same geographic scope.
1.2.1

Federal Energy Regulatory Commission

Based on its authority under the NGA, FERC is the lead agency for preparation of this EIS
in compliance with the requirements of NEPA, the Council on Environmental Quality’s (CEQ)
regulations for implementing NEPA (40 Code of Federal Regulations [CFR] 1500-1508), andFERC regulations implementing NEPA (18 CFR 380).
As the lead federal agency for the Project, FERC is required to comply with the following:
section 7 of the Endangered Species Act of 1973 (ESA), as amended; the Magnuson-Stevens
Fishery Conservation and Management Act, commonly referred to as the Magnuson-Stevens Act(MSA); section 106 of the National Historic Preservation Act (NHPA); and section 307 of the
Coastal Zone Management Act of 1972 (CZMA). Each of these statutes has been taken into
account in the preparation of this EIS. FERC will use this document to consider the environmental
impacts that could result if it issues an authorization to Plaquemines LNG under section 3(a) of
the NGA and a Certificate to Gator Express Pipeline under section 7(c) of the NGA.
FERC consulted with cooperating agencies throughout the pre-filing and application
phases of the Project. The cooperating agencies provided input on the Project during several
conference calls. In addition, an interagency scoping meeting was held on December 9, 2015, inorder to solicit comments and concerns regarding the Project. Agency representatives also
participated in the public scoping meeting held on October 21, 2015. The cooperating agencies
had the opportunity to comment on both the draft and final EIS. FERC consulted with thoseagencies about their comments and concerns and have incorporated them into the final EIS.
1.2.2

U.S. Army Corps of Engineers

The USACE has jurisdictional authority pursuant to the following: section 404 of the
Clean Water Act (CWA) (33 United States Code [U.S.C.] 1344), which governs the discharge ofdredged material into waters of the United States; section 10 of the Rivers and Harbors Act (RHA)(33 U.S.C. 403), which regulates any work or structures that potentially affect the navigable
capacity of a waterbody; and section 14 of the RHA (33 U.S.C. 408), which grants permission for
the alteration, occupation, or use of a USACE civil works project if the activity will not be injurious
to the public interest or affect the USACE project’s ability to meet its authorized purpose. Because
the USACE would need to evaluate and approve several aspects of the Project and must comply
with the requirements of NEPA before issuing permits under the above statutes, it has elected toparticipate as a cooperating agency in the preparation of this EIS. The Project is within the New
Orleans District of the USACE’s Mississippi Valley Division. Staff from the New Orleans District
participated in the NEPA review and will evaluate USACE authorizations, as applicable.
The primary decisions to be addressed by the USACE include the following:•issuance of a section 404 permit for the placement or redistribution of dredged and/or
fill material within jurisdictional waters, to include wetlands, associated withconstruction of the terminal and pipeline;

1-4

•

issuance of a section 10 permit for construction activities within navigable waters of
the United States; and•section 14 (or section 408) permission for the alteration, occupation, or use of the
USACE-managed civil works projects, including USACE-maintained navigation
channels and federal levees associated with the construction and operation of theterminal and associated facilities.

As an element of its review, the USACE must consider whether a project strives to avoid,
minimize, and compensate for impacts on existing aquatic resources, including wetlands, in orderto achieve a goal of no overall net loss of values and functions. Additionally, the USACE reviews
applicable portions of a project that may impact USACE-managed civil works projects todetermine whether or not the project would be injurious to the public interest or would impair theusefulness of the federal civil works projects (e.g., a levee). The USACE must also evaluate
whether or not a project has a “water dependency.” The USACE would issue a Record of Decision
to formally document its decisions on a proposed action, including section 404(b)(1) analyses andrequired environmental mitigation commitments.
1.2.3

U.S. Coast Guard

The USCG is the federal agency responsible for determining the suitability of waterways
for LNG marine traffic. The USCG exercises regulatory authority over LNG facilities that affectthe safety and security of port areas and navigable waterways under Executive Order 10173, theMSA (50 U.S.C. 191), the Ports and Waterways Safety Act of 1972, as amended, and the Maritime
Transportation Security Act of 2002 (MTSA) (46 U.S.C. 701). The USCG is responsible formatters related to navigation safety, vessel engineering and safety standards, and all matterspertaining to the safety of facilities or equipment in or adjacent to navigable waters up to the lastvalve immediately before the receiving LNG tanks. As appropriate, the USCG (acting under theauthority in 33 U.S.C. 1221 et seq.) also would inform FERC of design- and construction-related
issues identified as part of safety and security assessments. If the Project is approved, constructed,
and operated, the USCG would continue to exercise regulatory oversight of the safety and securityof the LNG terminal facilities in compliance with 33 CFR 127.
As required by its regulations, the USCG is responsible for issuing a Letter ofRecommendation (LOR) as to the suitability of the waterway for LNG marine traffic following a
Waterway Suitability Assessment. The process of preparing the LOR begins when an applicant
submits a Letter of Intent to the local Captain of the Port. In a letter dated January 23, 2017, the
USCG issued a LOR for the Project. In the LOR, the USCG stated that, after reviewing theWaterway Suitability Assessment (WSA), they recommend that the Lower Mississippi River beconsidered suitable for accommodating the type and frequency of LNG marine traffic in
accordance with the guidance in the Coast Guard Navigation and Vessel Inspection Circular 012011.
1.2.4

U.S. Department of Energy

The DOE must meet its obligation under section 3 of the NGA to authorize the import andexport of natural gas, including LNG, unless it finds that the proposed import or export would not

1-5

be consistent with the public interest. On March 1, 2016, Plaquemines LNG submitted, in Fossil
Energy Docket No. 16-28-LNG, an application to the DOE/Office of Fossil Energy (FE) to export
up to a total of 24.0 MTPA of natural gas in the form of LNG to Free Trade Agreement (FTA) andnon-FTA nations over 25 years. Venture Global seeks to export LNG from the terminal to any
country: (1) with which the United States has, or in the future may have, a free trade agreement
requiring national treatment for trade in natural gas; (2) with which the United States does not havea FTA requiring national treatment for trade in natural gas; (3) that has, or in the future develops,
the capacity to import LNG via ocean-going carriers; and (4) with which trade is not prohibited byUnited States law or policy.
Section 3(c) of the NGA, as amended by section 201 of the Energy Policy Act of 1992
(Public Law 102-486), requires that applications to DOE requesting authorization of the import orexport of natural gas, including LNG, from or to a nation with which there is in effect an FTA
requiring national treatment for trade in natural gas, be deemed consistent with the public interest
and granted without modification or delay. On July 21, 2016, DOE/FE approved Venture Global
Plaquemines LNG, LLC’s application to export LNG to FTA nations in DOE/FE Order No. 3866.
In the case of applications to export LNG to non-FTA countries, section 3(a) of the NGA
requires DOE/FE to conduct a public interest review and grant the applications unless DOE/FE
finds that the proposed exports will not be consistent with the public interest. Additionally, NEPA
requires DOE/FE to consider the environmental impacts of its decisions regarding applications toexport natural gas to non-FTA nations. DOE/FE has not yet granted Venture Global export
authority to countries without an FTA. In accordance with 40 CFR 1506.3, after an independent
review of the EIS, DOE/FE may adopt the document prior to issuing a Record of Decision on the
Venture Global application for authority to export LNG to countries without an FTA.
1.2.5

U.S. Department of Transportation

The DOT has prescribed the minimum federal safety standards for LNG facilities incompliance with 49 U.S.C. 60101. Those standards are codified in 49 CFR 193 and apply to thesiting, design, construction, operation, maintenance, and security of LNG facilities. The National
Fire Protection Association (NFPA) Standard 59A (NFPA 59A), Standard for the Production,
Storage, and Handling of Liquefied Natural Gas, is incorporated into those requirements byreference, with regulatory preemption in the event of conflict. In February 2004, the USCG, theDOT, and the FERC entered into an Interagency Agreement to ensure greater coordination among
these three agencies in addressing the full range of safety and security issues at LNG terminals,
including terminal facilities and tanker operations, and maximizing the exchange of information
related to the safety and security aspects of the LNG facilities and related marine operations.
Under the Interagency Agreement, the FERC is the lead federal agency responsible for the
preparation of the analysis required under NEPA for impacts associated with terminal construction
and operation. The DOT and the USCG participate as cooperating agencies, but remain
responsible for enforcing their regulations covering LNG facilities. On August 31, 2018, FERC
and DOT signed a Memorandum of Understanding (MOU) to coordinate the siting and safety

1-6review of FERC-jurisdictional LNG facilities. 2 On April 3, 2019, the DOT issued a Letter ofDetermination (LOD), which provides PHMSA’s analysis and conclusions regarding 49 CFR 193,
Subpart B regulatory requirements for the Commission’s consideration in its decision to authorize,
with or without modification or conditions, or deny an application. 3
The DOT also houses the Federal Aviation Administration (FAA), which is a federal
agency responsible for regulating all aspects of civil aviation including management of airports,
air traffic control, and protection of the public, property, and the national security and foreign
policy interests of the U.S. during commercial space launch and reentry activities. In its mission
to safely manage U.S. airspace and air traffic, the FAA requires that certain elevated structureswith the potential to affect navigable airspace are placed on public notice (14 CFR 77). Due to theheight of facilities associated with the Project, on January 16, 2017 Venture Global submitted a
Notice of Proposed Construction or Alteration of Objects that may affect the Navigable Airspaceand ensure that marking and lighting of all elevated structures is in compliance with FAA
standards. On January 25, 2017, Venture Global received a DOT FAA Determination of No
Hazard to Air Navigation in accordance with 14 CFR Part 77.
1.2.6

U.S. Environmental Protection Agency

The EPA has delegated water quality certification (section 401 of the CWA) to thejurisdiction of individual state agencies; in Louisiana, jurisdictional authority under section 401 of
the CWA has been delegated to the Louisiana Department of Environmental Quality (LDEQ). The
EPA also oversees the issuance of a National Pollutant Discharge Elimination System (NPDES)
permit by the LDEQ for point-source discharge of used water into waterbodies (section 402 of theCWA). The EPA shares responsibility for administering and enforcing section 404 of the CWA
with the USACE and has authority to veto USACE permit decisions.
The EPA has jurisdictional authority under the Clean Air Act of 1970 (CAA) (42 U.S.C.
85) to control air pollution by developing and enforcing rules and regulations for all entities that
emit pollutants into the air. Under this authority, the EPA has developed regulations for major
sources of air pollution and certain source categories and has established general conformity
applicability thresholds. The EPA has delegated the following jurisdictional authority under the
CAA to the LDEQ, unless the source would be located within Native American lands:•

Title 1, Part A, Section 111 – New Source Performance Standards (NSPS);•

Title 1, Part A, Section 112 – National Emission Standards for Hazardous Air
Pollutants (NESHAP);•

Title I, Part C – Prevention of Significant Deterioration (PSD); andAugust 31, 2018 Memorandum of Understanding between the Department of Transportation and the Federal
Energy Regulatory Commission Regarding Liquefied Natural Gas Transportation Facilities,
https://www.ferc.gov/legal/mou/2018/FERC-PHMSA-MOU.pdf.
3April 3, 2019 letter “Re: Plaquemines LNG Project, Docket No. CP17-66-000, 49 CFR, Part 193, Subpart B,
Siting – Letter of Determination.” Filed in Docket Number CP17-66-000 on April 4, 2019. FERC eLibrary
accession number 20190404-3002.
2

1-7

•

Title V – Operating Permits.

Under section 309 of the CAA, the EPA is (1) required to review and publicly commenton the environmental impacts of major federal actions, including actions that are the subject ofdraft and final EISs, and (2) responsible for implementing certain procedural provisions of NEPA
(e.g., publishing the Notices of Availability of the draft and final EISs in the Federal Register) toestablish statutory timeframes for the environmental review process.
1.3

PUBLIC REVIEW AND COMMENT

1.3.1

Pre-filing Process and Scoping

On June 18, 2015, Venture Global filed a request with FERC to use our pre-filing review
process. This request was approved on July 2, 2015, and pre-filing Docket No. PF15-27-000 was
established in order to place information filed by Venture Global and related documents issued by
FERC into the public record. The pre-filing review process provides opportunities for interested
stakeholders to become involved early in Project planning, facilitates interagency cooperation, andassists in the identification and resolution of issues prior to a formal application being filed with
FERC.
Venture Global held an open house in Port Sulphur, Louisiana (Plaquemines Parish) and
Lafitte, Louisiana (Jefferson Parish) 4 on September 15 and 16, 2015, to provide information to the
public about the Project. FERC staff participated in the meeting by describing the FERC process
and providing those attending with information on how to file comments with FERC.
On October 5, 2015, FERC issued a Notice of Intent to Prepare an Environmental Impact
Statement for the Planned Plaquemines Liquefied Natural Gas Project, Request for Comments on
Environmental Issues, and Notice of Public Scoping Meeting (NOI). This notice was sent to about
370 interested parties, including federal, state, and local officials, agency representatives,conservation organizations, Native American tribes, local libraries and newspapers, and property
owners in the vicinity of planned Project facilities. Publication of the NOI for the Project
established a 30-day public comment period for the submission of comments, concerns, and issues
related to the environmental aspects of the Project.
On October 21, 2015, FERC conducted a public scoping meeting in Belle Chasse,Louisiana (Plaquemines Parish) to provide an opportunity for the public to learn more about the
Project and participate in our analysis by providing oral comments on environmental issues to be
included in the EIS. Five individuals elected to present oral comments at the scoping meeting in
support of the Project. A transcript of these comments is part of the public record for the Projectand is available for viewing on the FERC internet website (http://www.ferc.gov). We received
comments from three federal agencies, one federally recognized tribe (tribe), and two stateagencies in response to the NOI for the Project (EPA, National Marine Fisheries Service [NMFS],
the National Park Service [NPS], the Choctaw Nation of Oklahoma, Louisiana Department ofWildlife and Fisheries (LDWF), and Louisiana Department of Transportation and Development
4

Jefferson Parish was included in the initial open house because the original project scope included two additional
feed gas pipelines to be constructed in Jefferson Parish. Venture Global has since removed these pipelines within
Jefferson Parish from the project scope.

1-8

[DOTD]). The Commission also received written comments from elected officials, public
officials, and one citizen.
On December 9, 2015, a joint interagency meeting for the Project was conducted withrepresentatives of the EPA, NMFS, Louisiana Department of Natural Resources (LDNR), andLDWF to discuss coordination of agency review, permit requirements and status, impacts onnatural resources, and each agency’s interest in participating in our environmental review as acooperating agency. Following the interagency meeting, FERC staff visited the terminal site andpipeline routes. In addition, interagency conference calls were conducted bi-weekly with theagencies and Venture Global representatives throughout the pre-filing period.
On September 14, 2016, FERC issued a Supplemental Notice of Intent to Prepare an
Environmental Impact Statement for the Planned Plaquemines Liquefied Natural Gas Project.
This NOI was sent to eight new landowners in the vicinity of Project facilities based on the revised
pipeline route (see previously referenced footnote 2). Publication of the NOI for the Project
established a 30-day public comment period for the submission of comments, concerns, and issues
related to the environmental aspects of the Project.
Issues identified after the initial open house and during and after public scoping aresummarized in table 1.3-1, along with a listing of the EIS sections that address the comments.
Table 1.3-1
Key Environmental Concerns Identified during the Scoping Process and Draft EIS Review for the Project
Issue/Specific Comment

EIS Section
Addressing Comment

GeneralRight-of-way requirements and configurations

2.2.2

Project design

2.1

Improve Project map/include political boundaries

2.1.1

Quantity and location of fill material and excavation of native material

4.4

Relevant permits (air, water, transportation, etc.)

1.5.11

Need for a programmatic EIS for LNG terminals

1.2

Project timeline

2.1.1

Alternatives
Explore alternative pipeline routes and the use of existing pipeline systems

3.5

Provide a clear discussion of the reasons for the elimination of alternatives that are notevaluated in detail

3.3.1

Describe how each alternative was developed, how it addresses each Project objective, andhow it will be implemented

3.0 through 3.6

Describe the rationale used to determine whether impacts of an alternative are significant ornot

3.0 through 3.6

Describe the methodology and criteria used for determining Project siting
Evaluate Project alternatives to demonstrate the Project’s compliance with section 404(b)(1)
guidelines

1-9

3.3 and 3.5
3.3, 3.5, and 4.4

Table 1.3-1
Key Environmental Concerns Identified during the Scoping Process and Draft EIS Review for the Project
Issue/Specific Comment
Discuss alternatives to avoid or minimize dredged or fill material discharged into waters of theUnited States

EIS Section
Addressing Comment
4.4

Soils
4.2.3

Aquatic erosion/sediment control
Water Quality and Aquatic Resources
Altered hydrology

4.3.2.1

Dredged material may contain contaminants and should be tested prior to placement

4.3.2.2

Test sediments to be placed in waters of the United States for beneficial use for contaminationaccording to the USACE/EPA Inland Testing Manual to determine their suitability for open
water disposal

4.3.2.2

Test sediments for contamination using the USACE Upland Testing Manual in cases where
potentially contaminated dredged material is proposed for disposal in a Confined Disposal
Facility and there is potential for effluent to enter waters of the United States

4.3.2.2

4.6.2.1 through 4.6.4.2

Impacts on productivity of Barataria Bay estuary
Impacts on coastal restoration projects and sand/silt resources

4.8.4

Impacts on water supply and the adaptability of the Project to these changes

4.3.1.4

Effects of Project discharges on surface water quality

4.3.2.2

Discharges within affected waters

4.3.2.2

Water reliability for the Project4.3.1.4 and 4.3.2.2

Mitigation measures necessary or beneficial in reducing impacts on water quality and aquatic
resources

4.3.1.4 and 4.3.2.2

CWA section 303(d) Impaired Waters, restoration and ongoing protection efforts, andmitigation measures

4.3.2.1

Impacts on groundwater quality and quantity associated with construction and operation
activities

4.3.1.4

Mitigation measures to reduce impacts on groundwater resources

4.3.1.4

Work closely with state and local agencies that regulate the protection of groundwater
resources

4.3.1.4

Identify areas of the Project located in the 50- or 100-year floodplain

4.3.2.1

A stormwater discharge permit is required for 1 or more acres of land disturbance

4.3.2.2

Wetlands
Appendix C and 4.4

Wetland crossing methods

2.4.5.2

Right-of-way width in wetlands
Pipeline construction in the coastal zone will damage wetlands

4.4.3 and 4.8.7

Majority of wetlands within pipeline rights-of-way are categorized as EFH

4.6.4.1

Wetland delineation needed

4.4.2

Include a wetland mitigation plan to be reviewed by EPA, USACE, and other agencies, alongwith alternatives to show that potential impacts on wetlands have been addressed

4.4.2

Use of barge lay method in non-marsh areas

2.5.2.4

1-10

Table 1.3-1
Key Environmental Concerns Identified during the Scoping Process and Draft EIS Review for the Project
Issue/Specific Comment

EIS Section
Addressing Comment
4.4.2.2

Use of spoil that is sidecast during barge channel creation
Vegetation
Critically imperiled Coastal Live Oak-Hackberry Forest ecological community

4.5.1

Introduction of invasive and exotic plant species

4.5.3

Fish and Wildlife Resources
Habitat fragmentation

4.5.4 and 4.6.2.2

Mitigation plan to offset fish and wildlife resource impacts

4.6.1.2 and 4.6.2.2

Noise pollution

4.6.1.2 and 4.6.2.2

Light pollution

4.6.1.2 and 4.6.2.2

Listed threatened and endangered species with the potential to occur in Project area

4.6.2

Impacts on wildlife

4.6.2
Appendix C

Consistent surveying, monitoring, reporting protocols
Presence of aquatic species managed under the MSA by the Gulf of Mexico Fishery
Management Council (GMFMC) and the NMFS within wetlands

4.6.4

Compliance with 50 CFR 600.920(e) regarding EFH

4.6.4

Measures to minimize EFH impacts

4.6.4

Compensation lands and mitigation

4.4.2

Re-suspension of oiled sediments

4.7.1

Land Use
Impacts on viewshed from nearby residential areas and areas greater than 2 miles

4.8.6.1

Impacts on aesthetics and recreational opportunities

4.8.6

Light pollution

4.8.6

Noise pollution

4.11.2

Impacts on the Jean Lafitte National Historical Park and Preserve

4.8.4

Impacts on the Barataria Preserve

4.8.4

Socioeconomics/Environmental Justice
Property Values

4.9.6

Traffic impacts in Belle Chasse

4.9.8.1

Impacted communities within the geographic scope of the Project (i.e., minority and lowincome populations)—evaluation and outreach

4.9.1

Coordination with tribal governments

4.10

Impacts on charter and sport fishing

4.9.3

1-11

Table 1.3-1
Key Environmental Concerns Identified during the Scoping Process and Draft EIS Review for the Project
Issue/Specific Comment

EIS Section
Addressing Comment

Cultural Resources
Impacts on culturally and historically significant properties

4.10

Section 106 of NHPA compliance4.10.5

Air Quality
Evaluation of baseline conditions

4.11.1.2

Air pollution and emission sources

4.11.1.4

Greenhouse gas emissions from Project operation

4.11.1.4

Statement of Purpose and Need
Clearly identify the underlying purpose and need to which the FERC is responding in
proposing the alternatives

3.0

Discuss the Project in the context of the natural gas supply and the need for additional export
capabilities

1.1

Transportation
If the Project requires access to or use of state highway rights-of-way, then a driveway permit
or joint use agreement is required

2.1.1.8

Climate Change
Future climate scenarios; potential changes to the affected environment due to climate change

4.11.1

Climate adaptation measures in response to future climate scenario impacts on the Project

4.11.1

Greenhouse gas emissions associated with production, transport, and combustion of natural
gas proposed to be exported by the Project

4.11.1.4

Hazardous Materials
2.4

Hazardous waste from construction and operation

2.1.1.8

Methane leakage prevention

1.3.2

Public Review of the Draft EIS

The draft EIS was filed with the EPA and a Notice of Availability for the draft EIS was
mailed to federal, state, and local government agencies; elected officials; Native American tribes;
affected landowners; local libraries and newspapers; intervenors in the FERC’s proceeding; andother interested parties (i.e., miscellaneous individuals who provided scoping comments or asked
to be on the mailing list). The distribution list for the Notice of Availability was provided inappendix A of the draft EIS.
On November 13, 2018, we issued a Notice of Availability of the Draft Environmental
Impact Statement for the Proposed Plaquemines LNG and Gator Express Pipeline Project. This
notice, which was published in the Federal Register, listed the date and location of a publiccomment session and established a closing date of January 7, 2019, for receiving comments on thedraft EIS. Copies of the draft EIS were mailed to 486 stakeholders. The EPA noticed the draft
EIS in the Federal Register on November 23, 2018.
1-12

We held one public session in the Project area to solicit and receive comments on the draft
EIS. The meeting was held on December 11, 2018, in Belle Chase, Louisiana. The session
provided the public an opportunity to present oral comments to a court reporter on theenvironmental analysis described in the draft EIS. A total of 24 individuals attended this public
session, including 11 who provided oral comments. We also received six comment letters fromfederal and state agencies, companies/organization, and individuals in response to the draft EIS.
All comments received are included in our comment responses contained in appendix H.
Transcripts from the public session, as well as the written comment letters, were entered into the
public record and are available for viewing on the FERC’s eLibrary website (www.ferc.gov).
This EIS addresses all substantive comments submitted to FERC or made at the open
houses, scoping meetings, interagency meetings, and public comment session on the draft EIS.
Table 1.3-1 lists the environmental issues and concerns identified by commenters during the draft
EIS review as well as the scoping process and identifies the section of the EIS where the issue isaddressed.
The Commission mailed a copy of the Notice of Availability of the Final Environmental
Impact Statement for the Plaquemines LNG and Gator Express Pipeline Project to agencies,
individuals, organizations, and other parties identified in the distribution list provided as appendix
A. Additionally, this final EIS was filed with the EPA for issuance of a Notice of Availability in
the Federal Register.
In accordance with the Council on Environmental Quality’s (CEQ) regulations
implementing NEPA, no agency decision on a proposed action may be made until 30 days after
the EPA publishes a Notice of Availability of the final EIS in the Federal Register. However, the
CEQ regulations provide an exception to this rule when an agency decision is subject to a formalinternal appeal process that allows other agencies or the public to make their views known. In
such cases, the agency decision may be made at the same time the notice of the final EIS ispublished, allowing both periods to run concurrently. The Commission’s decision for this
proposed action is subject to a 30-day rehearing period.
1.4

NON-JURISDICTIONAL FACILITIESUnder section 7 of the NGA, FERC is required to consider, as part of a decision to authorize
a project, all facilities that are directly related to the project if there is sufficient federal control andresponsibility to warrant environmental analysis as part of the NEPA environmental review for the
project. Some projects have associated facilities that do not come under the jurisdiction of theCommission. These “non-jurisdictional” facilities may be integral to the need for the jurisdictional
facilities, or they may be merely minor components that would be constructed and operated as aresult of authorization of the jurisdictional facilities.
Non-jurisdictional facilities associated with the Project would include new utility service
connections to the local electric and water distribution systems within the temporary adjacentworkspace. These utility connections would be provided by the local electric and water utility
companies and would be authorized and regulated by state and/or local agencies. The utility
companies would conduct the necessary environmental reviews and obtain all necessary permits
for non-jurisdictional facilities.

1-13

The new electric utility connection that would be utilized during terminal construction
would be provided by Entergy Louisiana, LLC. The anticipated design calls for a tie-in withEntergy’s existing power line that runs along and inside the Project property line on the south sideof State Highway 23 (SH 23) at the terminal site. The land disruption at this tie-in location would
be minimal and localized, involving the installation of an electrical junction box, meters, andassociated equipment. The electric service agreement would determine the scope of each party’s
responsibilities for the connection facilities. All other land disruptions associated with provisionof electric services would be confined to the terminal site and, therefore, within the FERCpermitted workspace.
The Project may require a connection to an existing water line owned and operated by
Plaquemines Parish Water Works along SH 23. The design would call for an approximately 1,500foot-long water line from a tie-in with the existing line (owned by Plaquemines Parish Water
Works) to facilities at the terminal site. Although it is anticipated that service would be
disconnected after construction, if a permanent connection becomes necessary, any additional
environmental impacts would be minimal and confined to the existing utility corridor that runs
along and inside the Project property line on the south side of SH 23. Venture Global is also
exploring options to provide supporting water utilities via on-site groundwater wells andwithdrawal from the Mississippi River. None of these three options would require new workspace,
as all options would be available within the terminal site or adjacent to the terminal site (SH 23).
1.5

PERMITS, APPROVALS, AND REGULATORY REVIEWS

Federal agencies are required to comply with various federal environmental regulations
and laws. In addition, project applicants must comply with various federal environmental laws
and regulations for projects that may or may not impact the environment. These regulations
include, but are not limited to, the CZMA, ESA, MSA, Migratory Bird Treaty Act (MBTA), Baldand Golden Eagle (BGEPA), Marine Mammal Protection Act (MMPA), RHA, CWA, CAA,MTSA, and NHPA, the Federal Aviation Act of 1958, and the National Flood Insurance Act of1968 (NFIA). Each of these statutes, and others, has been taken into account in the preparation ofthis document. The major permits, approvals, and consultations for the Project are identified intable 1.5-1. Each federal environmental regulation and law directly relevant to this Project is
discussed in the following paragraphs.
1.5.1

Endangered Species Act

Under section 7 of the ESA, a project authorized, funded, or conducted by any federal
agency should not “jeopardize the continued existence of any endangered species or threatened
species or result in the destruction or adverse modification of habitat of such species which isdetermined… to be critical… ” (16 U.S.C. 1536(a)(2)(1988)). FERC is required to consult withother federal agencies to determine whether any federally listed endangered, threatened, or
proposed species, including their respective designated critical habitats, occur in the vicinity of a
project. If FERC determines that these species or habitats have the potential to be impacted by aproject, FERC is required to prepare a biological assessment (BA) to identify the extent of adverse
impact and recommend measures to avoid or mitigate probable impacts. If FERC determines thatno federally listed proposed, endangered, or threatened species or their designated critical habitat

1-14

would be impacted by the Project, no further action is necessary under the ESA. Section 4.7
provides information on the status of FERC’s compliance with section 7 of the ESA.
1.5.2

Magnuson-Stevens Fishery Conservation Management Act

The MSA, as amended by the Sustainable Fisheries Act of 1966 (Public Law 104-267),
established procedures designed to identify, conserve, and enhance EFH for those species
regulated under a federal fisheries management plan. The MSA requires federal agencies to
consult with NMFS on all actions or proposed actions authorized, funded, or undertaken by theagency that may adversely affect EFH (MSA section 305(b)(2)). No criteria have been establishedfor conducting EFH consultations. However, NMFS recommends combining EFH consultations
with interagency coordination procedures required by other statutes, such as NEPA, the Fish andWildlife Coordination Act, or the ESA (50 CFR 600.920(e)), to reduce duplication and improve
efficiency. As part of the consultation process, FERC has prepared an EFH assessment. This
assessment and the status of EFH consultation are provided in section 4.6.
1.5.3

Migratory Bird Treaty Act

Migratory birds are species that nest in the United States and Canada during the summer
and then migrate south to the tropical regions of Mexico, Central and South America, and the
Caribbean for the non-breeding season. Migratory birds are protected under the MBTA (16 U.S.C.
703–711). Birds protected under the MBTA include all common songbirds, waterfowl, shorebirds,
hawks, owls, eagles, ravens, crows, native doves and pigeons, swifts, martins, swallows, andothers, including their body parts (feathers, plumes, etc.), nests, and eggs. The act makes it
unlawful to pursue, hunt, take, capture, or kill, attempt to take, capture, or kill, possess, offer to or
sell, barter, purchase, deliver, or cause to be shipped, exported, imported, transported, carried, or
received any migratory bird, part, nest, egg, or product, manufactured or not, without a permit.
Executive Order 13186 (66 Federal Register 3853) directs federal agencies to identify
where unintentional take is likely to have a measurable negative effect on migratory bird
populations and to avoid or minimize adverse impacts on migratory birds through enhanced
collaboration with the U.S. Fish and Wildlife Service (FWS). Executive Order 13186 states thatemphasis should be placed on species of concern, priority habitats, and key risk factors, and thatparticular focus should be given to addressing population-level impacts. On March 30, 2011, theFWS and the Commission entered into a Memorandum of Understanding Between the Federal
Energy Regulatory Commission and the U.S. Department of the Interior United States Fish andWildlife Service Regarding Implementation of Executive Order 13186, “Responsibilities ofFederal Agencies to Protect Migratory Birds,” that focuses on avoiding or minimizing adverse
impacts on migratory birds and strengthening migratory bird conservation through enhanced
collaboration between the two agencies. This voluntary MOU does not waive legal requirements
under the MBTA or any other statutes and does not authorize the take of migratory birds. See
section 4.6.2.1 of this draft EIS for the status of our compliance with the MBTA.
1.5.4

Bald and Golden Eagle Protection Act

The BGEPA prohibits taking without a permit, or taking with wanton disregard for theconsequences of an activity, any bald or golden eagle or their body parts, nests, chicks, or eggs,

1-15

which includes collection, molestation, disturbance, or killing. The BGEPA protections include
provisions not included in the MBTA, such as the protection of unoccupied nests and prohibition
on disturbing eagles. The BGEPA includes limited exceptions to its prohibitions through apermitting process, including exceptions to take golden eagle nests that interfere with resource
development or recovery operations. This EIS discusses compliance with the BGEPA under thejurisdiction of the USFWS in section 4.6.2.1.
1.5.5

Marine Mammal Protection Act

All marine mammals are protected under the provisions of the MMPA (16 U.S.C 31).
While many marine mammal species are listed as threatened or endangered through ESA
protections, the MMPA provides additional protections for all marine mammals. The MMPA
prohibits, with certain exceptions, the “take” of marine mammals in U.S. waters and by U.S.
citizens on the high seas and the importation of marine mammals and marine mammal products
into the United States. “Take” is defined as “to hunt, harass, capture, or kill, or attempt to harass,hunt, capture or kill any marine mammal.” Harassment is strictly defined as “any pursuit, torment,or annoyance that has the potential to injure marine mammal stock in the wild, or has the potential
to disturb a marine mammal or marine mammal stock in the wild by disrupting behavioral patterns,
including migration, breathing, nursing, breeding, feeding or sheltering.” Actions that have the“potential to injure” are Level A harassment, and those actions that have the “potential to disturb”
are Level B harassment. NMFS administers the MMPA in protecting whales, dolphins, porpoises,
seals, and sea lions; the FWS protects walruses, manatees, dugongs, otters, and polar bears; andthe Animal and Plant Health Inspection Service, a part of the U.S. Department of Agriculture(USDA), is responsible for regulations managing marine mammals in captivity (NMFS, n.d.[d]).
1.5.6Rivers and Harbors Act

The RHA pertains to activities impacting navigable waters, including harbor and river
improvements. Section 10 of the RHA prohibits the unauthorized obstruction or alteration of any
navigable water. Construction of any structure or the accomplishment of any other work affecting
course, location, condition, or physical capacity of waters of the United States must be authorized
by the USACE. Section 14 of the RHA, also referred to as section 408, grants permission for thealteration, occupation, or use of a USACE civil works project if the activity will not be injurious
to the public interest or affect the USACE project’s ability to meet its authorized purpose. Section
4.3 provides the status of our compliance with the RHA.
1.5.7

Clean Water Act

The CWA, as amended, regulates the discharges of pollutants into waters of the UnitedStates and regulates quality standards for surface waters. Both the EPA and the USACE, alongwith a joint application with LDNR, Office of Coastal Management (OCM), have regulatory
authority under section 404 of the CWA. The EPA has implemented pollution control programs,
including setting wastewater standards for industry and creating water quality standards for allcontaminants in surface waters. Under the CWA, it is unlawful to discharge any pollutant from apoint source into waters of the United States without a permit. In accordance with section 402 of
the CWA, the EPA operates the NPDES permit program, which regulates discharges by industrial,
municipal, and other facilities that directly enter surface waters. Section 404 of the CWA regulates

1-16

the discharge of dredged or fill material into waters of the United States and is under thejurisdiction of the USACE. The status of NPDES and section 404 permitting requirements arefurther addressed in section 4.4 of this EIS.
Section 401 of the CWA requires that an application for a federal permit to conduct anactivity that may result in a discharge to waters of the United States must provide the federal
regulatory agency with a section 401 certification. Section 401 of the CWA certifications are madeby the state in which the discharge originates and declares that the discharge would comply withapplicable provisions of the act, including state water quality standards. The LDEQ is theregulatory authority responsible for section 401 water quality certification in Louisiana.
1.5.8

Clean Air Act

The CAA is the basic federal statute governing air pollution and was enacted by the U.S.
Congress to protect the health and welfare of the public from the adverse effects of air pollution.
Federal and state air quality regulations established as a result of the CAA include, but are notlimited to, title V operating permit requirements and PSD review. The EPA is the federal agency
responsible for regulating stationary sources of air pollutant emissions; however, in Louisiana, thefederal permitting process has been delegated to the LDEQ. A title V and PSD permit application,
along with Class I and Class II (including Louisiana Toxic Air Pollutants) air dispersion modelingprotocols and an ozone modeling protocol, for the project were initially submitted to the LDEQ on
September 15, 2015. The application included the LNG terminal and pipeline system. An
addendum to the application and updated modeling protocols were submitted to the LDEQ on June23, 2017. Class I, Class II, and Louisiana Toxic Air Pollutant dispersion modeling reports were
submitted to the LDEQ on September 15, 2017. Section 4.11 evaluates air quality impacts that
could occur as a result of construction and operation of the Project.
1.5.9

Federal Aviation Act

The FAA, under the Federal Aviation Act, oversees the safety, development, andregulations of civil aviation. The regulations associated with “the construction, alteration,
establishment, or expansion, or the construction, alteration, establishment, or expansion of astructure when notice would promote safety in air commerce and the efficient use and preservationof the navigable airspace and of airport traffic capacity at public-use airports” are outlined in 14
U.S.C. 44718, Structures Interfering with Air Commerce. In accordance with 49 CFR 77, Safe,
Efficient Use, and Preservation of the Navigable Airspace, the construction or alteration of
structures requires that adequate notice be provided to the FAA. Following notification to the
FAA, a public NOI would be issued for an aeronautical study of the obstruction to air navigational
facilities and the effect the obstruction would have on the safe and efficient use of navigable
airspace. Upon completion of the study, the FAA would issue a determination stating whether theconstruction or alteration would be a hazard to air navigation. Section 4.12 provides additional
information regarding safety associated with the flare stacks.
1.5.10 Maritime Transportation Security Act
The purpose of the MTSA is to protect the nation’s ports and waterways from a terrorist
attack. The MTSA requires vessels and port facilities to conduct vulnerability assessments,

1-17

develop security plans, and establish Area Maritime Security Committees at all of the nation’s
ports. These committees coordinate activities of all port stakeholders, including the maritime
industry, the boating public, and other federal, state, and local agencies. As a cooperating agency
with FERC, the USCG prepared a LOR to analyze the potential risks to navigation safety andmaritime security associated with the Project (see section 1.2.3). The USCG also has
responsibilities relating to LNG waterfront facilities under 33 CFR 127.
1.5.11 National Historic Preservation Act
Section 106 of the NHPA requires that FERC take into account the impacts of its
undertakings on properties listed, or eligible for listing, in the National Register of Historic Places(NRHP), including pre-contact or historic sites, districts, buildings, structures, objects, orproperties of traditional religious or cultural importance, and to afford the Advisory Council on
Historic Preservation (ACHP) an opportunity to comment on the undertaking. In Louisiana, theLouisiana State Historic Preservation Officer (SHPO), within the Department of Culture,
Recreation, and Tourism, reviews projects regarding section 106 of the NHPA. Venture Global,
as non-federal parties, assisted FERC in meeting its obligations under section 106 by preparing
information, analyses, and recommendations under the ACHP regulations in 36 CFR 800. Section
4.10 of this EIS provides information on the status of our compliance with section 106 of theNHPA.
1.5.12 National Flood Insurance Act
The National Flood Insurance Program is managed by the Federal Emergency Management
Administration (FEMA). The purpose of the National Flood Insurance Program under the NFIA
is to make flood insurance available, improve floodplain management, and develop maps of flood
hazard zones. Pursuant to the NFIA, state and local governments must implement floodplain
management regulations consistent with measures in 44 CFR 60, Criteria for Land Management
and Use. To reduce the risk of flooding, participating local governments in flood-prone areas, as
designated by FEMA, agree to adopt and enforce ordinances that meet or exceed FEMA
requirements. Section 4.3 provides additional information regarding flood risks and ourcompliance with the NFIA.
1.5.13 Coastal Zone Management Act
The CZMA calls for the “effective management, beneficial use, protection, anddevelopment” of the nation’s coastal zone and promotes active state involvement in achieving
those goals. As a means to reach those goals, the CZMA requires participating states to develop
management programs that demonstrate how those states will meet their obligations andresponsibilities in managing their coastal areas. In Louisiana, the LDNR administers the Coastal
Zone Management Program (CZMP). Venture Global consulted with and submitted an application
to the LDNR for a Coastal Use Permit (CUP) on June 8, 2017, with a revised application submitted
in March 2018. The CZMP is discussed further in section 4.8.
1.5.13.1 U.S. Department of Defense
EPAct 2005 and section 3 of the NGA require us to consult with the U.S. Department of
Defense (DoD) to determine whether there would be any impacts associated with the Project on
1-18

military training or activities on any military installations. FERC initiated informal consultation
with a letter to the DoD in January 2016. After conducting an informal review, the DoD responded
on February 23, 2016, requesting that Venture Global coordinate with the U.S. Department of theNavy, due to the proximity of the Project to Naval Air Station Joint Reserve Base New Orleans.
In January 2017, Naval Air Station Joint Reserve Base New Orleans identified in an email to the
FERC that the installation did not have any issues with the Project moving forward and would
only contribute a minor impact to operations.
Table 1.5-1Major Permits, Approvals, and Consultations for the Project
AgencyStatusPermit/Approval/
Consultation

Terminal

Pipelines

FederalFederal Energy
Regulatory Commission(FERC)

Authorization to Construct andOperate Facilities under sections 3(a)and 7(c) of the Natural Gas Act(NGA)

Application filed
February 28, 2017

Application filed February
28, 2017

U.S. Department ofEnergy, Office of Fossil
Energy (DOE/FE)

Authorization to export LNG by LNG
carrier to Free Trade Agreement(FTA) and non-FTA nations

FTA approval received
on July 21, 2016
(DOE/FE Order No.
3866)

NA

Non-FTA application
pending
U.S. Department ofHomeland Security, U.S.
Coast Guard (USCG)

Waterfront Facilities Handling
Liquefied Natural Gas and Liquefied
Hazardous Gas (33 Code of Federal
Regulations [CFR] 127), which
includes Letter of Intent (LOI)
submission (33 CFR 127.007),
Waterway Suitability Assessment
consultation, and Letter ofRecommendation from the USCG (18CFR 157.21)

Letter of
Recommendation
received on January 23,
2017

NA

U.S. Environmental
Protection Agency (EPA),
Region VI, Dallas, Texas

Consultation role to Louisiana
Department of Environmental Quality(LDEQ) on air emissions permitting

Planned Review of
LDEQ air permit
application in November
2018

NA

Floodplain management andprotection of wetlands (44 CFR 9)
Review of wetlands impacts for U.S.
Army Corps of Engineers (USACE)
Clean Water Act (CWA) section 404
permitCommented on USACE
Public Notice on April
12, 2018

Commented on USACE
Public Notice on April 12,
2018

CWA section 404 permit for impacts
on waters of the United States,
including wetlands (33 United States
Code [U.S.C.] 1344)
Rivers and Harbors Act (RHA) section
10 permit for construction andoperation of structures in and acrossApplication for sections
404/10 submitted
September 15, 2017

Application for sections
404/10 submitted
September 15, 2017

USACE, New Orleans
District

1-19

Table 1.5-1Major Permits, Approvals, and Consultations for the Project
AgencyStatusPermit/Approval/
Consultation

Terminal

Pipelines

Authorization request for
section 408 approvalsubmitted December
2017

Authorization request for
section 408 approvalsubmitted December 2017

All Pending

All Pending

ESA section 7 consultation (16 U.S.C.
35)

Concurrence Received
February 2017
Revision Pending

Concurrence Received
February 2017
Revision Pending

Migratory Bird Treaty Act
Consultation (16 U.S.C. 7, subchapter
II)

Pending

Pending

Fish and Wildlife Coordination Act
Consultation (16 U.S.C. Chapter 5a,subchapter I)

Pending

Pending

BGEPA consultation

Pending

Pending

Federal Aviation
Administration (FAA)

FAA’s regulations at 14 CFR 77

Received FAA clearance
determinations January
25, 2017, Extension
granted July 19, 2018

NA

U.S. Department ofTransportation – Pipelineand Hazardous Materials
Safety Administration(PHMSA)

49 CFR 193 Subpart B

Letter of Determination– received April 3, 2019

NA

Hydrostatic Test Water Discharge
General Permit (LRS 30:2001 et seq.)

Pending

Pendingfederally navigable waterways (33U.S.C. 403)
Section 408 authorization for work infederal project waters and federally
navigable waters (33 U.S.C. 408)
U.S. Department ofCommerce, National
Oceanic and Atmospheric
Administration, National
Marine Fisheries Service(NMFS)

Marine Mammal Protection Act
Consultation (16 U.S.C. 1382)
Endangered Species Act (ESA)
section 7 consultation (16 U.S.C. 1856
et seq.)Magnuson-Stevens FisheryConservation and Management Act(MSA) Consultation, Essential Fish
Habitat (EFH) Consultation (50 CFR
600)
Fish and Wildlife Coordination Act
Consultation (16 U.S.C. 5a,subchapter I)

U.S. Fish and Wildlife
Service (FWS), Southeast
Region 4

State – Louisiana
LDEQ, Water Permits
Division

Section 401 Water Quality
Certification (33 U.S.C. 26)

Received 401 Certification
October 1, 2018

1-20

Table 1.5-1Major Permits, Approvals, and Consultations for the Project
AgencyStatusPermit/Approval/
Consultation

TerminalLouisiana Pollutant Discharge
Elimination System (LPDES)
Construction Stormwater Discharge
General Permit LAR100000

Received 401
Certification October 1,
2018

Pipelines

Pending

Pending

LPDES Industrial Wastewater
Discharge Permit, section 402 (33U.S.C. 1342)

Pending
Pending

LDEQ, Office ofEnvironmental Quality

Title V and Prevention of
Deterioration of Significant (PSD) Air
Permits (40 CFR 70)

Amended application
submitted in July 23,
2017

NA

Louisiana Department of
Natural Resources(LDNR), Office of Coastal
Management (OCM)

Coastal Use Permit (CUP), a Joint
Permit Application with USACE (R.S.
49:214.25)

CUP application
submitted June 8, 2017

CUP application submitted
June 8, 2017

LDNR, Office ofConservation

Title 38, Section 3098 (R.S.
38:3098—Chapter 13-B: Subsurface
Water—Well Drillers)Application to besubmitted June 2019

NALouisiana Department ofWildlife and Fisheries(LDWF)

Threatened and Endangered Species
Consultation (16 U.S.C. 460 et seq.)

Pending

PendingLouisiana Department ofCulture, Recreation andTourism, Division ofArchaeology

National Historic Preservation Act(NHPA) Section 106 Consultation (36CFR 800) and Review

Concurrence from
SHPO: Terminal Site,
January 7, 2016;
Terminal Site Avoidance
Plan, August 22, 2016;
Terminal Site
Addendum, February 17,
2017; Unanticipated
Discovery Plan,
February 17, 2017

Concurrence from SHPO:
Pipeline System, February
8, 2016; Addendum
Report, October 12, 2016
Addendum, January 2017Louisiana Department ofTransportation andDevelopment (DOTD)

Driveway access, trestle crossing,temporary conveyor crossing

Application submitted in
January 2019

NALouisiana Office of State
Lands

Permit and lease for State Water
Bottoms (LRS 41:1701-1714)

Application submitted in
February 2019

Application submitted in
February 2019

West Bank Levee

Crossing authorization

See information for
section 408 authorization

See information for section
408 authorization

Plaquemines Parish
Council

Building permit (if required)

Pending

Pending

Local – Parish

1-21

2.0

PROPOSED ACTION

2.1

PROPOSED FACILITIESThe Venture Global Project consists of an LNG export terminal facility and a pipeline
system in Plaquemines Parish, Louisiana that would supply the necessary gas for export. A
description of these facilities is provided below.
•

LNG Terminal: Construction and operation of various liquefaction, LNG distribution,
and appurtenant facilities within the boundaries of the site leased by Venture Global on
the Mississippi River, including:o six pretreatment facilities (three in each phase);o a liquefaction plant with 18 integrated single-mixed refrigerant blocks and support
facilities (otherwise referred to as liquefaction blocks or blocks) to be constructedin two phases (nine blocks in each phase);o four 200,000-cubic-meter aboveground full-containment LNG storage tanks;o three LNG loading docks within a common LNG berthing area; ando air-cooled electric power generation facilities.

•

Pipeline System: Construction and operation of two parallel 42-inch-diameter natural
gas pipelines that share one right-of-way corridor for the majority of their respective
routes and appurtenant aboveground facilities, including the following:o 15.1-mile-long Southwest Lateral Pipeline (Southwest Lateral TGP);o 11.7-mile-long Southwest Lateral Pipeline (Southwest Lateral TETCO);
o TGP metering and regulation station; ando TETCO metering and regulation station.

Figure 2.1-1 shows the general location of the terminal site and pipeline routes.

2-1

New Orleans_^

Gretna_^Belle Chasse_^

Pointe à
la Hache_^Port Sulphur

_
^
TETCO

!
.

TGP

!
.
Louisiana

0

2.
5

5
Mi
les

T
erm i
n al SiteBo un dary
East
ern Wo rk
space

SW Lateral –TETCOSW Lateral –TGP!
. Intercon n ectan dMeter Station

This information is for environmental review purposes only.

p

Figure 2.1-1
Proposed Project Facilities - Regional Location (Aerial Map)
Plaquem in es LNG an dGato r Express Pipeli
n ePro jectPlaquem in es Parish,Lo ui
si
an a

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RR01\
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2.1.1

LNG Terminal

Venture Global proposes the development of an LNG terminal with a nameplateliquefaction capacity of 20.0 MTPA. The LNG liquefaction, storage, and export facilities would
be constructed on an approximately 632-acre site on the west bank of the Mississippi River, nearriver mile marker 55 in Plaquemines Parish, Louisiana (see figure 2.1-2). The terminal site isbordered by the Mississippi River to the north and private property, historically used for
agricultural purposes, to the south, east, and west. The terminal site has approximately 7,000 feetof frontage on the Mississippi River. The site is approximately 15 miles northwest of Port Sulfur,
Louisiana and is bisected by SH 23. This state highway is a north-south regional highway thatserves Plaquemines Parish. In addition, the terminal site extends across a federally maintained
Mississippi River levee. The levee is part of the Mississippi River Flood Control Program and isunder the regulatory and operational control of the USACE, New Orleans District.
The terminal site is located on “fastlands.” The State of Louisiana defines fastlands as
lands surrounded by publicly owned, maintained, or otherwise validly existing levees or naturalformations that normally prevent activities, not to include the pumping of water for drainage
purposes, within the surrounded area from having a direct and significant impact on coastal waters.
For descriptive purposes, the facilities at and adjacent to the terminal site are divided into
two groups: the “terminal facilities” are those facilities located south of the landward toe of theMississippi River levee and include the pretreatment, liquefaction, storage, and power generation
facilities; and the “marine facilities” are those facilities on, over, or north of the Mississippi Riverlevee and include the three LNG loading docks. The marine facilities are divided into land-based
and water-based facilities. The material offloading facility (MOF), bulk carrier mooring facility,and barge unloading facility each require temporary access roads across the levee for a total offour crossings (access road for the barge unloading facility is a loop necessitating two crossings).
At the location of the LNG loading docks on the Mississippi River (river mile marker 55),
the federal navigation channel is approximately 1,900 feet wide (USACE, 2016a) and does not
require regular maintenance since the depth is far greater than the required minimum depth of 45
feet Mean Low Gulf (USACE, 2016b). The existing channel depth would allow construction andoperation of the LNG loading docks without the need for any dredging beyond that alreadyperformed by the USACE to maintain the navigation channel.
The LNG terminal site would be constructed in two phases (table 2.1-1). Venture Global
anticipates initiating construction of Phase II approximately 12 months after initiating Phase I.
However, Phase II is predicated on Venture Global’s market outlook and the expected timeframe
for securing offtake contracts for Phase II. Initiation of Phase II could be delayed based on market
conditions and the status of offtake contracts.

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This information is for environmental review purposes only.

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Figure 2.1-2
Proposed Facilities at Terminal Site (Aerial Map)
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

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Venture Global plans to initiate construction of Phase I upon receipt of the Project’s
regulatory approvals required to begin construction. Venture Global anticipates that the fullconstruction of each the two phases would take approximately 35 months each. In both phases,
the construction, commissioning, and operational startup of the liquefaction facilities would beachieved in steps, with each of the nine blocks per phase brought on line as it is commissioned.
The Project’s construction plan and its sequencing would be designed to ensure that LNG can beproduced, stored, and loaded onto ships for export upon the commissioning of the first liquefaction
block. The phased startup would be implemented pursuant to a simultaneous operations plan to
be developed with the Project’s engineering, procurement, and construction contractors. For
Phase I, Venture Global anticipates commencing production of LNG as the first liquefaction block
is completed, approximately 24 months after receiving FERC’s authorization to commence
construction. LNG production would then steadily increase as more liquefaction blocks arecommissioned.
Table 2.1-1
Summary of Major Facility Components Constructed by Phase
Phase I

Phase II

9 Liquefaction Blocks

9 Liquefaction Blocks

3 Pre-treatment Facilities

3 Pre-treatment Facilities

2 LNG Storage Tanks(full containment type)2 LNG Storage Tanks(full containment type)2 LNG Loading Docks

1 LNG Loading Dock

Natural Gas-fired Power Plant (710 megawatt)

Natural Gas-fired Power Plant (710 megawatt)

Southwest Lateral TGP (15.1 miles)

Southwest Lateral TETCO (11.0 miles)

Southwest Lateral TETCO (0.7-mile segment)
TGP and TETCO Meter Stations

2.1.1.1

Pretreatment

Upon arrival at the terminal site, the natural gas would enter the gas gate station, which
would include isolation and emergency shutdown valves, filters/separators, metering systems,
connection to the fuel gas system, and a gas analyzer. At this stage, the gas would be split into
two streams, one for process feed to the liquefaction plant and the other for fuel gas supply1 to theelectric power generation facilities. The feed gas pressure would be boosted as necessary byelectric motor-driven compressors at the terminal site to achieve approximately 750 pounds per
square inch gauge (psig) before pretreatment and before the gas enters the liquefaction system.
Air-cooled heat exchangers would cool the gas to near ambient temperature to remove the heatcaused by compression.
The pipeline-quality gas delivered to the terminal site would be composed primarily of
methane but would also contain ethane, propane, butane, and other heavy end hydrocarbons(between 2 and 3 percent) in addition to small quantities of nitrogen, oxygen, carbon dioxide
1Natural gas feed for power generation would be supplemented with boil-off gas and other fuel gas streams
generated in the liquefaction plant.

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(CO2), and water. To ensure that the liquefaction plant can function properly, the process feed gas
would be treated to remove CO2, hydrogen sulfide (H2S), and water. The trace amounts of CO2
present in natural gas would freeze in the cryogenic liquefaction process and block the cryogenic
exchangers if not removed beforehand. H2S is also removed to lower sulfur dioxide emissions.
Each construction phase consists of a Hydrogen Sulfide Removal Unit, an Acid Gas
Removal Unit, and a Dehydration Unit. Each Hydrogen Sulfide Removal Unit includes six (6)Hydrogen Absorber Vessels while each Acid Gas Removal Unit includes three (3) parallel
treatment blocks. There would be three (3) Dehydration blocks, where one (1) Dehydration blockis dedicated to an Acid Gas Removal treatment block.
H2S Removal Unit
Feed gas from the gas gate station, containing up to 5 parts per million volume (ppmv)
H2S, would be fed to the non-regenerative H2S removal beds to remove H2S and, thereby, lower
sulfur dioxide emissions. The solid adsorbent is contained in multiple vessels in each of the six
H2S removal units. As the adsorbent is used up, individual vessels are isolated, and the adsorbent
is emptied and recharged while the rest of the units remain on line. The treated gas is sent to theacid gas removal unit for further treatment. Spent adsorbent would be placed in containers andtransported via truck to a processing facility.
Acid Gas Removal
The acid gas removal unit is designed to treat feed gas containing up to 2 percent mole CO2
and any remaining traces of H2S that remain after the H2S removal unit process. After treatmentin the acid gas removal unit, the feed gas would contain no more than 50 ppmv CO2 and no morethan 1 ppmv H2S. Activated methyldiethanolamine technology would be used primarily due to its
ability to remove CO2 to very low levels and, with respect to comparative technologies, fewer
corrosion issues and lower foaming tendencies. There would be three 50-percent capacity acidgas removal units for each phase. Antifoam injection would be provided, as well as amine andwater storage and makeup facilities. The low-pressure, CO2-rich acid gas stream with some H2S
and residual hydrocarbons content would be sent to the thermal oxidizer for destruction. The
amines collected in the solvent drain tank would be filtered and transferred to the solvent storagetank, then sent off-site for reprocessing.
Dehydration Unit
The dehydration unit would be located downstream of the acid gas removal unit and isdesigned to remove water from the water-saturated feed gas leaving the amine tower. The gas
dehydration system would consist of three 50-percent-capacity molecular sieve units for eachphase, each with four vessels (three operating, one regenerating). The process flow would berouted through a valve system to one of the operating vessels, while the other operating vessels’sieve material would be regenerated with a small flow of dry, hot gas.
At any given time, three molecular sieve beds would be in water adsorption mode, while
the other would be in regeneration mode. The regeneration gas is heated by a hot oil system. The
dried treated gas is filtered downstream of the molecular sieve vessel and then sent to the heavy

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hydrocarbon removal unit. The water content of the gas is reduced to about 0.5 ppmv. Finally,
the natural gas is further purified within the liquefaction trains to remove heavy hydrocarbons.
2.1.1.2

Liquefaction

The liquefaction plant would consist of 18 integrated single-mixed refrigerant blocks andsupport facilities (otherwise referred to as liquefaction blocks or blocks), which would be situatedin the central sector of the terminal site (see figure 2.1-2). Nine of the blocks would be constructedin Phase I and nine would be constructed in Phase II. One block would contain two liquefaction
trains, each consisting of a cold box, an electric-driven mixed-refrigerant compressor and a processmodule. Heavy hydrocarbon removal is integral to the cold box. Each train would also contain
conventional air coolers (fin fans) to provide cooling during the liquefaction process.
Each block would have a nameplate capacity of 1.1 MTPA of LNG (for a Project nameplate
capacity of 20.0 MTPA in aggregate) for export, which equates to a total liquefaction nameplate
capacity of approximately 1,033 standard billion cubic feet per year (bcf/y) of natural gas. The
Project’s peak liquefaction capability may, depending on a variety of factors, be as much as 24.0
MTPA. Under optimal conditions, this equates to a total peak liquefaction capacity of
approximately 1,240 bcf/y of natural gas.
The first step of the liquefaction process is to further purify the natural gas arriving fromthe pretreatment systems to remove heavy hydrocarbons that would freeze during the liquefaction
process if not removed beforehand. The pretreated feed gas enters the cold box where it is chilled
to a point at which most of the heavy components condense and are then separated in a distillation
process. The small quantities of products removed would be recovered and used by the LNG
terminal’s hot oil heaters for fuel.
After the heavy hydrocarbons have been removed, the pretreated gas continues through thecold box, is de-superheated, condensed to liquid, and then sub-cooled to near -260 degrees
Fahrenheit (°F) in aluminum plate-fin heat exchangers, which are enclosed and insulated withperlite powder in steel cold boxes. Refrigeration for this process is produced by a specificallydesigned single-loop, mixed-refrigerant system. The refrigerant, a mixture of hydrocarbon gases
and nitrogen, is pressurized by a multi-stage electric motor-driven compressor and then partiallycondensed in air-cooled heat exchangers. The resultant cooled and pressurized vapors and liquids
are separated into various streams and continue to be condensed and sub-cooled in the cold-box
plate-fin heat exchangers. The cooling source for these mixed-refrigerant streams and the natural
gas liquefaction stream is created by flashing cold mixed-refrigerant to lower pressures, thenpassing those colder mixed refrigerant streams in counter current to the streams to be cooled in theplate-fin heat exchangers. The lower-pressure, mixed-refrigerant is warmed to near ambient
temperature and returned to the suction of the compressors to complete the cycle.
Each liquefaction train would contain a refrigerant make-up system with gas analyzers andcontrols that maintains the refrigerant components in proper proportion. The refrigerant make-up
system is also designed to recover refrigerant during equipment shutdown. Distribution piping
would connect vessels in the common refrigerant storage area to each liquefaction train. Except
for certain safety systems, one distributed control system in the control building would be used for2-7

supervisory process and power control. Each liquefaction train would have its own processcontroller.
When the LNG exits the cold-box, it is depressurized to 100 psig and delivered sub-cooled
to the LNG storage tanks, where it is flashed into the container.
2.1.1.3

LNG Tanks

The LNG storage tanks would be located between the liquefaction blocks and the LNG
berthing area (see figure 2.1-2). Each tank would be approximately 300 feet in diameter and
180 feet in height from grade to the top of the dome roof, with a net usable capacity of 200,000
cubic meters. The four LNG tanks constructed during Phase I and Phase II (two during each Phase)would be full containment type.
Each full containment tank would consist of:•a pile supported at grade tank foundation system with electric heater, designed tosupport the tank;•an outer reinforced concrete tank with a carbon steel vapor barrier;•a 9 percent nickel steel inner tank;•a concrete ring beam, which supports the shell of the inner tank;•an aluminum suspended insulation deck supported by hangers from the roof;•

an insulation system with insulation on top of the suspended deck, between the outerconcrete tank and the 9 percent nickel steel inner tank, and between the outer tankbottom and the inner tank bottom;•

a tank settlement monitoring system;•a heating system in the concrete foundation to prevent frost heave of the soil below the
tank;

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submerged pumps, pump wells, internal piping, etc.;•

valves for pressure and vacuum protection;•

appurtenant equipment including roof platform, spill protection, stairs, walkways,
caged ladders, monorail, handrails, pressure relief and vacuum relief valves, pipe-racks,
equipment for various monitoring, fire detection and control system, etc.;•

electrical features including tank lighting, tank grounding and lightning protection; and•control and instrumentation systems.

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The Phase I tanks would be on the north side of the storage area, and the Phase II tanks
would be on the south side of the storage area. The storage tanks, like other LNG facilities at the
LNG terminal site, must be built to the requirements of NFPA Standard 59A (2001), as
incorporated by DOT/PHMSA regulations at 49 CFR 193. Venture Global will design andconstruct the LNG storage tanks to other applicable regulations, codes, and standards.
Prior to being placed into service, the LNG storage tanks would be hydrostatically tested
in accordance with the requirements of American Petroleum Institute (API) Standard 620, Q8.3.
The source of hydrostatic test water would be appropriated from the adjacent drainage canallocated at the southern edge of the LNG terminal site. In the event that this drainage canal does
not have enough available water, alternative plans would be to pull water from the Mississippi
River. Following any necessary treatment, the used test water would be discharged back to thecanal or river adjacent to the terminal site within the parameters of the LDEQ permit.
Liquefied natural gas from the liquefaction plant would be stored in the LNG tanks prior
to being transferred to ocean-going LNG carriers.
2.1.1.4

LNG Loading and Ship Berthing Area

The LNG carriers would access the LNG terminal from the Gulf of Mexico via the
Mississippi River. Figure 2.1-3 identifies the U.S. Exclusive Economic Zone; shipping fairways,
lanes, and zones; and potential LNG carrier sea routes.
Each LNG loading dock would feature a concrete platform, which would be constructedon steel piles. Each platform would support three marine loading arms and one marine vapor
return arm. LNG would be pumped from the LNG tanks through loading arms to ocean-going
LNG carriers. The design pumping rate from the LNG storage tanks would be 12,000 cubic meters
per hour. The vapor return arm is provided to route displaced/flash gas back to an LNG storagetank. Each loading and vapor return arm would have a powered emergency release coupling.
Figure 2.1-4 shows a more detailed view of the marine structures.
2.1.1.5

Flare StackA flare stack is a gas combustion device primarily used for burning off flammable gas
released by pressure relief valves. The purpose of a pressure relief and flare system is to safely
and reliably protect plant systems from overpressure during start-up, shutdown, plant upsets, andemergency conditions. Upset events that require flaring or depressurizing are not planned, and thecontrol system is designed to safely control the gas release and mitigate the air quality impacts ofa release. Planned flaring is usually associated with system start-up, planned maintenance andshutdown scenarios, and LNG carrier gas-up/cool-down operations.
Three separate flare structures would be installed at the LNG terminal: a warm/cold flarestructure containing two separate flare headers to handle cold relief fluids and wet/warm relief
fluids; a low-pressure vent flare structure for low-velocity marine loading; and a marine vapor
control structure for LNG carrier gas-up/cool-down operations.

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This information is for environmental review purposes only.

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Terminal Site

Economic Exclusion Zone
Boundary

Navigable Channel (Pilot)

Shipping Fairways, Lanes and
Zones

Safety Fairway (Ship Master)
Ship Master selects Open
Water Sea Routes (routes
shown are illustrative only)

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Figure 2.1-3
LNG Carrier Sea Routes
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
REVISED: 07/22/2016

DRAWN BY: GISMississippi
River

Levee

Area notbeing disturbed
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LNG Loading Docks
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Figure 2.1-4
Proposed Layout of LNG Loading Docks
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

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This information is for environmental review purposes only.

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After initial facility start-up, during which flaring of gas from process cool-down would
occur, the LNG terminal is designed to limit flaring events only to LNG carrier gas-up/cool-down,
which may occur up to forty times a year. Venture Global does not anticipate any otherflaring/venting during normal operating conditions.
2.1.1.6

Power Generation Facilities

During operations, electrical power would be generated on the LNG terminal site by two
combined-cycle gas turbine power generation facilities sized to reliably meet the LNG terminal’s
peak power demand of electricity in total for Phases I and II. A substation and transformer yard
would be located near the power generation facilities.
The main power load would be 36 electric motor drivers for compressors in the liquefaction
plant consisting of one driver for each of the two liquefaction trains in each of the 18 liquefaction
blocks. Other plant loads would include LNG pumps, boil-off gas and boost compressors, and themultiple fan motors that would be used for air cooling during the liquefaction process. The power
generation facilities would supply their own auxiliary electric loads, including fans in the aircooled steam condensers, and would have multiple diesel generators for black start capability.
Interconnection to the existing electrical transmission grid would not be necessary for Project
operation.
2.1.1.7

Construction Facilities

Temporary Marine Facilities
Venture Global intends to construct three temporary marine delivery facilities for use
during Project construction. These temporary marine delivery facilities include the MOF, bulk
carrier mooring facility, and barge mooring facility.
The MOF would be located in the Mississippi River, adjacent to the shoreline and east of
the LNG loading docks. The MOF would consist of a concrete platform (200 feet x 300 feet)supported by large-diameter steel pilings. The platform elevation would be +15.0 feet North
American Vertical Datum of 1988 (NAVD88). The primary use for the facility would beoffloading of the LNG modules, power plant components and equipment, and other heavy
lift/heavy haul (greater than 50 tons) material and equipment. The MOF would be used during
both Phase I and Phase II. Once construction of Phase II is complete, the MOF would be removed,
and the impact area would be restored to preconstruction conditions to the extent practicable.
The bulk carrier mooring facility would consist of five mooring piles at the proposed
location of the LNG loading dock farthest upstream on the Mississippi River. The primary use of
the bulk carrier mooring facility would be docking and unloading of bulk carriers, which would
use an onboard conveyor system to offload rock, structural fill, and cement to a receiving hopper
located on the channel side of the Mississippi River levee. The material would then be transported
across the levee and SH 23 to the LNG terminal construction area by an overhead conveyor system.
Mooring of deep-draft bulk carriers would require the use of two moored barges (approximately
250 feet long by 50 feet wide) to serve as spacers between the mooring dolphins and the bulk
carriers. The bulk carrier mooring facility would be used during Phase I and then removed before
construction of the third LNG loading dock at the same location during Phase II.
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The barge mooring facility would consist of six mooring dolphins located on theMississippi River, approximately 700 feet downstream from the MOF. The primary purpose of
the barge mooring facility would be to secure cargo barges (anticipated to be 250 feet long and
52 feet wide) for offloading of piles and other materials by a shore-based crane during constructionof the LNG terminal facilities. The materials would be transported by truck from the offloading
area to receiving areas on the LNG terminal site. Once construction of Phase II is complete, thebarge mooring facility would be removed, and the impact area would be restored to preconstruction conditions to the extent practicable.
Temporary Electric PowerThe local electric power provider, Entergy Louisiana, LLC, would provide a utility service
connection that would be used to provide electrical power during construction of the LNG
terminal. This would be a temporary electric utility connection that would be removed following
start-up of the LNG terminal’s power plant. The design calls for an approximately 1,500-footlong interconnect from the existing power line located along SH 23 heading southwest to atemporary construction electrical distribution center within the LNG terminal site. Continued
interconnection to the existing electrical transmission grid would not be necessary for Project
operation.
2.1.1.8

Support Facilities

Water Supply
Venture Global is evaluating three potential water supply sources for construction andoperation, including the following:•

connection to the public water supply;•

treated groundwater from on-site wells; and•treated surface water from the Mississippi River or other local waterbodies.

Pending discussions with the parish, Venture Global may connect to the Plaquemines
Parish Water District’s existing water line that is adjacent to SH 23 and install an aboveground
pipeline for approximately 1,500 feet to a distribution point at the LNG terminal site. Thisconnection could potentially provide potable water during construction and would possibly bemaintained for operational supply. Plaquemines LNG is also evaluating the feasibility of
constructing two or more groundwater supply wells that would supply water to the facility througha groundwater treatment system. The water supply system for the LNG terminal, regardless ofsource, is expected to include some volume of storage capacity in aboveground storage tanks.
During LNG terminal operations, the primary uses of potable water would include watersupply for administration buildings, control rooms, and maintenance buildings for potable andsanitary uses and makeup water for the power plant steam system. Potential uses of potable water
could include utility hose stations; indoor firewater sprinkler systems; initial fill and makeup forthe closed-loop tempered water system, acid gas removal unit, and turbine water wash; andfirewater system pressurization.
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For firewater system pressurization, Venture Global proposes to use potable water to fill afresh water storage tank. The firewater jockey pumps would draw from this tank to pressurize themain firewater ring header. Each jockey pump has a rated capacity of 132 gallons per minute. If
the firewater jockey pumps cannot maintain firewater header pressure, then the jetty firewater
pumps would draw water directly from the Mississippi River. Each jetty firewater pump has a
rated capacity of 4,000 gallons per minute.
The sanitary waste system used for LNG terminal operations would include holding tanks
on-site, which would be pumped out as necessary to be disposed at licensed facilities.
Safety and Security Communication
The LNG terminal would be designed to minimize the occurrence of events that could
result in unsafe conditions and to mitigate potential impacts on the public and facility personnel.
Proposed safety systems include the following:•

emergency shutdown (ESD) system – an automated system to prevent escalation of
hazards from accidents or equipment failure;•spill and leak containment and alarm systems for LNG and other hazardous liquids;•

flammable vapor detection systems;•

fire protection systems with:o heat detection;o ultra-violet radiation detection;o smoke detection;•

firewater delivery systems with seawater loop and hydrants; and•electronic monitoring and emergency messaging systems.

Fire and gas detection systems would provide the means to monitor for and alert operatorsof hazardous conditions throughout the LNG terminal site resulting from fire, gas leaks, and low
temperature LNG spills. The detection of these hazardous conditions would result in local audio
and visual (e.g., strobe lights) signals with various alarms and colors, depending on the detectedhazard. When appropriate, automatic emergency shutdown of specific equipment and systems
would occur and may activate a wider ESD system response.
Firewater and fire
suppression/extinguishing systems would be provided to protect personnel, the public, and facility
equipment in the event of a fire. Lightning arrestors would also be included in facility designs.
The terminal would be surrounded by perimeter fencing, with gated and monitored access,and would have 24-hour surveillance performed using a combination of electronic monitoring andfacility personnel, in accordance with all applicable maritime and critical energy infrastructure

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safety and security laws. Security features include an intrusion detection system with closedcircuit TV cameras, intrusion monitors, and low-intrusion plant perimeter lighting.
Access Roads
During operation, vehicular access to the LNG terminal site would be via existing local
public roadways. Venture Global indicates that access would require improvements such as
auxiliary turn lanes along southbound SH 23, new site entrances and exits on SH 23, and required
signage and lighting. All improvements would be designed in accordance with the American
Association of State Highway and Transportation Officials, “A Policy on Geometric Design of the
Highways and Streets” per DOTD recommendations.
Buildings
The LNG terminal site would also include the following systems and buildings necessary
for the safe and efficient operation of the LNG terminal:•

ship loading control rooms;•

main process and power plant control room;•administrative offices;•

workshop;•

warehouse; and•various ancillary equipment buildings and shelters.

Stormwater Drainage and Containment
LNG terminal site preparation activities would be designed to ensure efficient andenvironmentally protective stormwater drainage. The LNG terminal site would be designed todirect discharges towards perimeter outfalls through a system of ditches and, if necessary, holding
basins and filtration devices during construction, allowing sufficient retention time to preclude
high sediment loads from reaching receiving waters. Stormwater controls, including placement ofgravel or other suitable material to provide a stable, well-drained surface, would be installed.
Throughout construction, Venture Global would follow the erosion and sedimentation control
procedures described in its Project-specific Upland Erosion Control, Revegetation, andMaintenance Plan (Plan) and Wetland and Waterbody Construction and Mitigation Procedures(Procedures) based, respectively, on FERC’s Upland Erosion Control, Revegetation, andMaintenance Plan (FERC, 2013a) and Wetland and Waterbody Construction and Mitigation
Procedures (FERC, 2013b), and would also follow its construction Stormwater Pollution
Prevention Plan (SWPPP).

2-15

2.1.1.9

LNG Carriers

The marine facilities would be designed to accommodate LNG carriers with capacities
between 120,000 m3 and 185,000 m3. An LNG carrier’s transit to the LNG terminal would begin
outside the Mississippi River, where a river pilot would board the vessel when it enters the pilot
boarding area. The LNG carrier then would travel into the Mississippi River to mile marker 55
arriving at the LNG Terminal. Figure 2.1-3 identifies the U.S. Exclusive Economic Zone; shipping
fairways, lanes, and zones; and potential LNG carrier sea routes.
2.1.2

Pipeline System

The pipeline system includes two natural gas pipelines in Plaquemines Parish, Louisiana,
the Southwest Lateral TGP and the Southwest Lateral TETCO. These pipelines would connect
the LNG terminal to the existing transmission pipeline network and provide feed gas to theliquefaction and power generation facilities. Each pipeline would have a nominal gas supply
capability of 1.97 standard bcf/day, which includes a 20 percent contingency over the terminal
design case, delivered from TGP’s or TETCO’s existing pipeline system, assuming a battery limit
design pressure of approximately 500 to 900 psig at the gas gate station on the LNG terminal. The
major components of the pipeline system are described below.
The Southwest Lateral TGP would consist of approximately 15.1 miles of 42-inchdiameter steel pipeline extending to the LNG terminal from a proposed interconnection with TGP’s
interstate transmission pipeline system. For the TGP line, approximately 14.4 miles would beconcrete coated and 0.7 mile would not be concrete coated.
The Southwest Lateral TETCO would consist of approximately 11.7 miles of 42-inchdiameter steel pipeline extending to the LNG terminal from the proposed interconnection withTETCO’s interstate transmission system. For the TETCO line, approximately 11.1 miles would
be concrete coated and 0.6 mile would not be concrete coated.
One platform-mounted meter station with a pig launcher and pressure regulating valve
would be located in the vicinity of each of the two pipeline interconnections described above fora total of two meter stations for the pipeline system. A gas gate station with pig receivers andpressure regulating valves would be located at the LNG terminal and would interconnect with thetwo pipelines. It would also include filter/separators, custody transfer meters, emergency
shutdown valves, and gas analyzers.
Three mainline valves (MLVs) would be located on the Southwest Lateral TGP, and three
MLVs would be located on the Southwest Lateral TETCO. On the Southwest Lateral TGP and
the Southwest Lateral TETCO, one MLV would be located at the southwest end of each pipeline’s
pipe bridge crossing of the non-federal levee southwest of the LNG terminal (figure 2.1-2). A
permanent access road that would be approximately 50 feet in length would be constructed to allow
access to the MLV from Lake Hermitage Road.
One interconnect valve on the Southwest Lateral TETCO with a pig launcher and pressure
regulating valve would be located on the platform-mounted TETCO meter station, which includes
an approximately 300-foot-long, 42-inch-diameter pipe section. The valve and pipe section would

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connect to the Southwest Lateral TGP, allowing the Southwest Lateral TGP to transport gas fromeither the existing TGP system or the existing TETCO system at any given time.
One pipe bridge to provide an aerial crossing for the two pipelines would be installed overthe non-federal levee southwest of the LNG terminal and northeast of Lake Hermitage Road. Allother sections of the pipeline would be installed underground.
During construction, Venture Global would require water access to the construction site
for barges and other vessels involved in dredging, pipe laying, equipment and material deliveries,and spoil storage. Regional access to the area would be through the Intracoastal Waterway (ICW),
which runs into Barataria Bay about 6 miles northwest of the Southwest Lateral TETCO meterstation. From Barataria Bay, northwest access to the pipeline route would be through Wilkinson
Canal and Lake Laurier. All barge access to the work area would follow existing waterways, anda majority of the system is sufficiently deep (at least 8 feet) to allow free passage. However, somedredging would be required in four areas, totaling 8.9 miles, to increase the minimum water depth
to the required level. Venture Global would undertake this dredging as part of the Project and inaccordance with the necessary federal, state, and local permits and approvals.
2.2

LAND REQUIREMENTS

2.2.1

LNG Terminal

The LNG terminal site would occupy an approximately 632-acre property and an adjacentparcel for workspace. The property has been secured by Venture Global pursuant to a lease option
agreement that grants Venture Global the exclusive right to lease the LNG terminal site for up to
70 years. The lease agreement was approved by Plaquemines Parish Council on August 13, 2015,
and executed by Venture Global and the Port of Plaquemines on August 19, 2015. The LNG
terminal site would be utilized for permanent operational facilities. In addition, the majority of
infrastructure for the three LNG loading docks and three temporary marine delivery facilities
would be constructed and sited in the Mississippi River along the northern edge of the 632-acreproperty and would constitute an additional 14.6 acres of operational footprint. See figure B-1 inappendix B for workspaces within the terminal site.
For Phase I of the Project, adequate workspace would exist at the LNG terminal site toconstruct the facilities; however, temporary workspace beyond the LNG terminal site would beneeded to support construction during Phase II of the Project. The proposed temporary workspaceconsists of approximately 80 acres of land along SH 23, east of and adjacent to the LNG terminalsite. Venture Global currently has an option to lease this property from the Port of Plaquemines.
It shares the same land use characteristics as the LNG terminal site, namely agricultural pasturedesignated as “fastlands” by the State of Louisiana. Although this temporary workspace isnecessary only during construction, it would be permanently impacted by the ground preparation
and aggregate overlay needed to allow its use as an equipment storage and laydown area.
Table 2.2-1 provides a summary of the land requirements at the LNG terminal and waterbased marine facilities.

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Table 2.2-1
Summary of Land Requirements at the Terminal Sitea
Land
Impacted byConstruction(acres)Land
Impacted byOperation(acres)

Water
Impacted byConstruction(acres)

Water
Impacted byOperation(acres)Total Area
Impacted byConstruction(acres)Total Area
Impacted byOperation(acres)Terminal
Facilities

534.5

534.5

0.0

0.0

534.5

534.5

Land-BasedMarine Facility

7.4

7.4

0.0

0.0

7.4

7.4

TerminalWorkspaceb

13.1

0.0

0.0

0.0

13.1

0.0

Water-BasedMarine Facility

3.9

3.9

10.7

10.7

14.6

14.6

UtilityWorkspacec

6.4

0.0

0.0

0.0

6.4

0.0

Eastern
Workspace

80.0

80.0

0.0

0.0

80.0

80.0

MarineWorkspace

2.8

0.0

69.9

0.0

72.7

0.0

648.1

625.8

80.6

10.7

728.7

636.5

Terminal
Componenta Does not include undisturbed land (77.0 acres) at the LNG terminal site.
b Terminal workspace includes areas along the federal levee where workspace for the crossing of the levee would be required.
c Temporary terminal workspace includes areas located along SH 23 currently used for utilities.

2.2.2

Pipeline System

Venture Global would construct its pipeline system using either a barge lay, push lay, orconventional lay method. In the areas that require installation by barge lay, Venture Global would
require a 300-foot-wide construction right-of-way (temporary right-of-way plus permanent
easement).
During the draft EIS comment period, the LDWF recommended that the temporary rightsof-way not exceed 75 feet and permanent rights-of-way not exceed 30 feet in wetlands. However,wider rights-of-way are necessary for this Project given the large diameter pipeline (42-inchdiameter pipeline with a 6-inch-thick concrete coating), the unconsolidated soils along the pipeline
route, and the need for sufficient space to store spoil during trench excavations used for later
restoration. In areas where the push method is used to install the pipeline, including in wetlands,
a 130-foot-wide construction right-of-way is necessary due to the need for a relatively wide anddeep trench to ensure the required depth of cover and containment of the sidecast spoil. In areas
where the barge lay method is used to install the pipeline in open waters, a 300-foot-wide
construction right-of-way would be required to accommodate an approximately 100-foot-wide
flotation channel for lay barge and supply barge access, and up to about 100 feet on either side of
the flotation channel for construction workspace to deposit sidecast trench material. The
permanent operational easement width of 80 feet (where the two pipelines are collocated) reflects
the necessary access rights for inspection and maintenance during pipeline operation. Following
workspace restoration in wetlands, only 60 feet of this 80-foot width would be subject to any
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further disturbance through potential periodic vegetation maintenance (i.e., a 30-foot-wide corridor
centered over each pipeline). Of this, only a 10-foot-wide corridor centered on each pipeline would
be subject to the level of clearing necessary to ensure a continued herbaceous state to facilitate
aerial surveys of the pipeline corridor for safety purposes. The land requirements for the pipeline
system and its aboveground facilities are shown in table 2.2-2.
The use of temporary workspaces is required to safely cross atypical features, such as
wetlands, waterbodies, existing utilities, and road crossings. Temporary workspaces are used oneither side of these crossings, typically not in wetlands or waterbodies, and are used to stage
equipment and supplies and segregate topsoil or muck because workspaces are often a reduced
width within an actual road, utility, or sensitive environmental resource crossing.
Table 2.2-2
Summary of Land Requirements for the Pipeline System and its Aboveground Facilities
Area Impacted by Construction(acres)Area Impacted by Operation(acres)

Pipeline Facilities

447.7a128.0bAboveground Facilities (meter stations and
MLVs)

71.8

9.3

Additional Temporary Workspacec

46.4

0.0

Access Roads

0.7

<0.1

Barge Access Channelsd

322.6

0.0

889.2d137.3dPipeline Facilities

64.7a

0.0c

Aboveground Facilities (meter stations and
MLVs)

0.0

0.0

Additional Temporary Workspace

0.0

0.0

Access Roads

0.0

0.0

Barge Access Channelse

0.0

0.0

Southwest Lateral TETCO Total

64.7

0.0

Overall Pipeline System Total

953.9

137.3

FacilitySouthwest Lateral TGP (Phase I)c,d

Southwest Lateral TGP Total
Southwest Lateral TETCO (Phase II)e,f

a No construction workspace is required at horizontal directional drill (HDD) segments except for HDD entry and exit points and HDD pullback areas (both addressed as additional temporary workspace [ATWS]). No construction workspace is required for pipeline facilities atpipeline trestle crossings except for trestle construction and trestle supports (both addressed as ATWS and aboveground facilities,
respectively).
b Calculated on the basis of a 50-foot-wide (Southwest Lateral TGP) and 80-foot-wide (Southwest Lateral TGP collocated with Southwest
Lateral TETCO) permanent easement.
c Excludes 62.5 acres of temporary workspace associated with meter stations which is included within stated aboveground facilities impacts.
d Acreage totals include temporary dredging and dredge spoil placement impacts for channels providing worksite access for construction
barges and support vessels.
e To the extent that the temporary rights-of-way and workspace for the Southwest Lateral TETCO and Southwest Lateral TGP are shared, theoverlapping acreage is included in the Southwest Lateral TGP and Southwest Lateral TETCO (Phase I) total and excluded from theSouthwest Lateral TETCO (Phase II) total.
f. To the extent that the permanent easements for the Southwest Lateral TETCO and Southwest Lateral TGP are shared, the overlapping
acreage is included in the Southwest Lateral TGP and Southwest Lateral TETCO (Phase I) total and excluded from the Southwest Lateral
TETCO (Phase II) total.

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Venture Global is not planning to use pipe yards. Instead, Venture Global would receive
pipe joints at the workspaces that have been transported from the pipe-coating yard by truck for
upland and HDD construction, and transported by lay barge for open water and wetland pull
sections.
Venture Global would require one temporary and one permanent access road for the
pipeline system. Additionally, Venture Global would require barge access to the pipeline system.
Venture Global would utilize existing channels for barge access; however, three areas would
require deepening to accommodate construction vessels. See table 2.2-2 for land requirements forthese Project components.
2.3

CONSTRUCTION SCHEDULE

Construction of the Phase I facilities is anticipated to last for approximately 35 months.
Construction of the Phase II facilities is anticipated to commence approximately 12 months after
construction of the Phase I facilities is initiated and is scheduled to also last for 35 months, inwhich case the Project would be fully complete and operational by 2023. The Southwest Lateral
TGP and would be constructed concurrently with the LNG terminal’s Phase I facilities; theSouthwest Lateral TETCO would be constructed concurrently with the LNG terminal’s Phase II
facilities.
Each phase of the LNG terminal’s construction would require an average 1,400 workers
and up to 2,200 workers during a 6-month peak. The number of workers on-site would typicallybe higher during the 23 months of terminal construction phase overlap. During this 23-month
period, the total number of workers at the terminal site could range from 1,500 to 3,600, and would
average approximately 3,000 workers during the overlapping period.
The average workforce for each phase of construction is estimated to be 1,400 workers,
which would overlap for a period of approximately 12 months, during which the average combined
on-site workforce would be approximately 2,800 workers.
Construction of the pipeline system would require fewer workers than the LNG terminal
and for a shorter duration. As discussed in section 1.5.2.3, the Southwest Lateral TGP and a 0.7mile-long segment of the Southwest Lateral TETCO would be constructed during Phase I; theremaining 11.0 miles of the Southwest Lateral TETCO would be constructed during Phase II. For
both Phases I and II, estimates for pipeline construction include approximately 150 workers at the
beginning of construction to stake and prepare the work areas. Following the initial period,
construction activity would gradually increase to a peak of about 500 workers for a one-month
period and then gradually decrease as installation of the pipelines near completion. See Section
4.9, Socioeconomics, for further details regarding construction workforces.
2.4

ENVIRONMENTAL COMPLIANCE

FERC may impose conditions on any Certificate or authorization it grants for the Project.
These conditions generally include additional requirements and mitigation measures
recommended in this EIS to minimize the environmental impact that would result fromconstruction and operation of the facilities (see sections 4 and 5). We will recommend that these
additional requirements and mitigation measures (bold type in the text of the EIS) be included as
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specific conditions to any approving Certificate or authorization issued for the Project. We will
also recommend to the Commission that Venture Global be required to implement the mitigation
measures proposed as part of the Project unless specifically modified by other Certificate or
authorization conditions.
2.4.1

Environmental Inspection

Venture Global would be represented during construction by an environmental compliancemanager, hired by and reporting to Venture Global, who would have overall authority for quality
assurance and compliance with mitigation measures, other applicable regulatory requirements, andcompany specifications. The environmental compliance manager would be assisted by lead
Environmental Inspectors (EIs), who would report directly to the manager. Venture Global would
employ two to four EIs per construction spread based on the environmental and/or cultural
resources present on each spread. The EIs would be on-site during active construction and would
have peer status with all other activity inspectors.
The EI, as well as all Project contractors and company personnel, would have authority tostop construction activities that violate the measures set forth in the documents and permit
authorizations for the Project. The environmental inspection program weekly reports would besent to FERC for review and placed into the public record.
The EIs’ duties are described in detail in Venture Global’s Plan (see appendix B). At aminimum, the EI would be responsible for the following:•

identifying, documenting, and overseeing corrective actions as necessary to bring anactivity back into compliance;•

verifying that the limits of authorized construction work areas and locations of accessroads are properly marked before clearing and maintained throughout construction;•verifying the location of signs and highly visible flagging marking the boundaries ofsensitive resource areas, waterbodies, wetlands, or areas with special requirements
along the construction work area;•

identifying erosion/sediment control and stabilization needs in all areas;•

locating dewatering structures and slope breakers to ensure they would not direct water
into sensitive areas such as known cultural resource sites, wetlands, waterbodies, andsensitive species habitats;•verifying that trench dewatering activities do not result in the deposition of sand, silt,
and/or sediment near the point of discharge in a wetland or waterbody. If suchdeposition is occurring, the EI would stop the dewatering activity and take corrective
action to prevent a reoccurrence;

2-21

•

advising the environmental compliance manager and/or Chief Construction Inspector
when conditions (such as wet weather) make it advisable to restrict construction
activities to avoid excessive rutting, topsoil/subsoil mixing, or excessive compaction;•

approving imported soils and verifying that the soil is certified free of noxious weeds
and soil pests, unless otherwise specified by the landowner;•

ensuring that erosion controls are properly installed, as necessary, to prevent sedimentflow into wetlands, waterbodies, sensitive areas, and onto roads;•

inspecting and ensuring the maintenance of temporary erosion control measures at least
daily in areas of active construction or equipment operation, on a weekly basis in areas
with no construction or equipment operation, and within 24 hours of each 0.5 inch or
greater of rainfall;•ensuring restoration of contours and topsoil;•

ensuring the repair of all ineffective temporary erosion control measures as soon as
possible but not longer than 24 hours after identification, or as soon as conditions allow
if compliance with this time frame would result in greater environmental impacts;•

keeping records of compliance with conditions of all environmental permits andapprovals during active construction and restoration; and•identifying areas that should be given special attention to ensure stabilization andrestoration after the construction phase.

Additional inspection requirements would be included pending Venture Global’s
compliance with other permits, certifications, and approvals as shown in table 1.5-1 in section 1.5.
2.4.2

Compliance Monitoring

Venture Global would review Project-specific environmental conditions with prospective
contractors during pre-bid meetings and would incorporate such conditions into construction bid
documents. Contractors would be obligated to comply with all environmental conditions in the
Project’s permits. Venture Global would require that all contractors develop and train theirconstruction workers in spill prevention and cleanup, waste management, and incident managing
and reporting to support environmental compliance during construction.
For purposes of quality assurance and to support regulatory compliance, Venture Global
would be represented by one chief inspector for the LNG terminal site and one chief inspector forthe pipeline system. One or more craft inspectors and one or more EIs would assist each chief
inspector. In addition, craft inspectors would be used for inspection services at manufacturing andfabrication facilities handling process modules, equipment, and piping prior to delivery to the LNG
terminal site. All inspectors would have access to the compliance specifications and other relevantmaterial contained in the construction contracts.

2-22

FERC would also conduct field inspections during construction. Other federal and stateagencies may also conduct oversight or inspection to the extent determined necessary by theindividual agency. After construction, FERC would continue to conduct oversight inspection andmonitoring during operation of the Project to ensure successful restoration. Additionally, FERC
staff would conduct operations inspections of the LNG facility throughout its entire life.
2.4.3

Environmental Training

Venture Global would implement a training program designed to meet regulatory
requirements and to ensure all individuals receive training tailored to their particular role before
beginning on-site work. The program would also ensure that adequate training records aremaintained and refresher training is provided as needed.
2.5

CONSTRUCTION PROCEDURES

This section describes the general procedures proposed by Venture Global for construction
activities at the LNG terminal and pipeline system. Refer to section 4 for more detailed discussionsof proposed construction and restoration procedures, as well as additional measures that we arerecommending to avoid or reduce environmental impacts.
The Project must be constructed in accordance with DOT/PHMSA Federal Safety
Standards for LNG Facilities (49 CFR 193) and the incorporated NFPA 59A (2001), “Standard for
the Production, Storage and Handling of LNG” and would be incompliance with National
Electrical Code (NFPA 70) and applicable sections of the USCG’s regulations for Waterfront
Facilities Handling LNG (33 CFR 127 and Executive Order 10173). Specifically for the pipeline
system, safety requirements are embodied in, but are not limited to, the DOT/PHMSA regulationsin 49 CFR Part 192 and the LDNR Office of Conservation pipeline safety regulations found inLouisiana Administrative Code (LAC) 43:XIII.
Venture Global developed a Project-specific Plan and Procedures based, respectively, on
FERC’s Plan (FERC, 2013a) and Procedures (FERC, 2013b), which are available on the FERC
website at http://www.ferc.gov/industries/gas/enviro/guidelines.asp. Implementation of the
Project-specific Plan and Procedures during construction and post-construction monitoring would
help ensure that ground disturbance and restoration activities are implemented in anenvironmentally appropriate manner. See appendix C for the Project-specific Plan and Procedures
and Venture Global’s proposed modifications to the FERC Plan and FERC Procedures.
During construction, some potential exists for spills of hazardous materials, such as
hydraulic fluid and diesel fuel for equipment and vehicles. In addition, stormwater runoff fromthe construction workspace could carry unconfined debris and materials. To address these andrelated concerns for the LNG terminal site, Venture Global has developed and would adhere to a
construction-specific Spill Prevention, Controls, and Countermeasures (SPCC) Plan and a
SWPPP; likewise, the pipeline system has developed a comparable construction-specific SPCC
Plan and SWPPP.
The LNG terminal and pipeline system would be required to implement all conditions in
the Certificate or authorization issued by the Commission for the Project. Venture Global would

2-23

implement the Project-specific Plan and Procedures developed to avoid or minimize environmental
impacts during construction, which are discussed throughout this EIS.
2.5.1

LNG Terminal

Construction activities at the Project site would involve clearing and grading, placement offill, installation of foundations for the planned Project facilities, other equipment settings, ancillaryequipment, piping, and structures. Construction operating hours would be from 7:00 a.m. to 7:00
p.m., Monday through Saturday. Land-based and marine-side pile driving construction activity,
is expected to also occur 6 days per week starting at 7:00 a.m., as well, but would end at 5:00 p.m.
It is anticipated that the Project would require nighttime construction at the terminal site during
the initial 6 to 12 months.
2.5.1.1

Site Preparation

The LNG terminal site would require significant area-wide improvements, including
clearing, grubbing, grading, soil stabilization, and filling to increase ground elevation, some ofwhich must be performed prior to foundation development and plant construction. Existing groundelevations at the LNG terminal site range from -2 and -4 feet (NAVD88) and would be leveled toan elevation of -2 feet (NAVD88) by grading and import of fill materials. It is anticipated that theexisting soil at the LNG terminal site may require improvement and stabilization to provide a loadbearing surface during construction. Venture Global would employ commonly used stabilizers
such as crushed stone, sand, portland cement, and/or hydrated lime while aggregate materials (e.g.,gravel, oyster shell, and/or crushed stone) and geotextile layers would be used to level and finish
temporary workspace and operational areas, as necessary. Initially, aggregate materials would bedelivered to the LNG terminal site by truck to construct access roads and the crane pad for thebarge mooring facility. Following installation of three temporary marine delivery facilities,
aggregate materials would arrive by barge, bulk carrier, and truck.
Venture Global would install a floodwall around the portion of the LNG terminal site southof SH 23 to protect it from storm surge during construction and operations. At the outset of
construction, Venture Global would install a temporary facility area interior to the floodwall at the
LNG terminal site, which would include mobile offices, sanitary facilities, and a parking area.
This would support preliminary construction activities, which include access road construction,
preliminary site preparation, initial construction of the floodwall, a pile test program, anddevelopment of the three temporary marine transfer facilities. Once these temporary facilities are
established, the overall workspace would be expanded to include additional laydown areas forconstruction.
2.5.1.2

Terminal Site

Following site grading, soil stabilization, and road installation, LNG tank foundation
construction and floodwall installation would commence with the installation of piles. After thepile locations have been determined, precast or steel piles would be installed by vibratory orhammer methods; cast-in-place piles would be installed in pre-drilled holes. After the piles havebeen installed to design depths, caps would be constructed. Precast or steel piles would be

2-24

delivered to the site by barge and/or truck. Concrete for cast-in-place concrete piles would be
supplied by one or more on-site concrete batch plants.
The liquefaction trains would be connected with the gas gate station and LNG storage tanks
by aboveground piping interconnects on steel-framed support racks. Pipe spool fabrication would
be undertaken mainly off-site. Spools fabricated off-site would be delivered by truck and barge.
Where possible, pipe racks would be modularized to minimize site work. Pipe sections would be
painted, coated, and insulated, as necessary, after welds have been tested according to applicable
codes.
Process modules such as pretreatment systems, liquefaction cold-boxes, and refrigerant
compressors would be delivered by barge or truck. All equipment units necessary for the Project
would be constructed at existing commercial facilities, while larger modular units would be barged
to the LNG terminal MOF to be placed on their respective foundations.
Once foundations have been completed, work on the liquefaction blocks, piping
interconnects, and associated utility systems can occur within the same general timeframe, butwould be coordinated such that various inter-dependent systems (e.g., electrical andinstrumentation) can be installed and tested according to an appropriately sequenced schedule.
After the equipment and piping have been set in place, cable systems would be installed.
Ultimately, road finish, final site grading, seeding, and cleanup would be completed. Temporary
construction facilities would be disassembled and removed on a progressive basis when they are
no longer needed. Pipe sections would be either hydrostatically or pneumatically tested, dependingon the type and intended function of the pipe.
2.5.1.3

Marine Facilities

Venture Global does not anticipate that dredging would be required for installation of thethree LNG loading docks or for LNG carriers to operate in the berthing area. Three LNG loading
docks would be constructed in a collective berthing area and be supported by steel piles. The
loading docks would be constructed of concrete decking with a hydraulic gangway, lighting,control buildings, and cathodic protection. The LNG liquid loading arms, which would be locatedon the concrete decks, would be fully balanced in the empty condition by a counterweight system
and maneuvered by hydraulic cylinder drives.
The construction plan for the LNG loading docks and associated structures (cryogenic
piping, utility lines, and piping/utility line trestle) to cross the federal levee and SH 23 would be
developed in consultation with the USACE, DOT/PHMSA and DOTD.
2.5.1.4

Piping and Equipment Installation and Testing

All pipe would be fabricated according to American Society of Mechanical Engineers(ASME) standards by ASME section IX qualified welders. Once process equipment is set in placeon the foundations, roughly aligned, and secured to the foundations, pipe installation would begin.
Venture Global would coat all piping and equipment with a material that resists corrosion. When
all process equipment is installed and electrical, mechanical, and other instrumentation work
completed, the key pre-commissioning activities would commence.

2-25

After all pre-commissioning activities are complete, Venture Global would clean andhydrostatically or pneumatically test piping in compliance with the applicable codes that govern
pipe design, and purge the piping. In general, Venture Global would pneumatically test cryogenic
piping using dry air or nitrogen and hydrostatically test non-cryogenic piping using clean water.
All testing would be performed in accordance with ASME B31.3.
2.5.2

Pipeline System

The applicant would construct the pipeline system and associated facilities as described inthis section and in accordance with 49 CFR 192 and LDNR safety regulations (LAC 43:XIII). The
pipelines and associated appurtenances would be coated below grade with fusion-bonded epoxy,field-applied sleeves, or an equivalent protective coating and painted above grade; in some areas,
the pipeline may be coated with a layer of abrasive resistant coating over the fusion-bonded epoxy.
Additional cathodic protection systems must be installed in accordance with applicable DOT and
LDNR safety regulations. The pipeline sections in water-saturated or inundated areas would becoated with a 6-inch-thick layer of concrete over the fusion-bonded epoxy, providing negative
buoyancy to counteract the tendency of the pipeline to float. All pipe welds would be coated andapplied in the field. Venture Global would not conduct concrete coating in the field.
2.5.2.1

Surveying and Easement Acquisition

Prior to initiating construction-related activities, Venture Global would survey the routeand secure right-of-way easements from the appropriate landowners. The limits of construction
would be clearly marked in the field with various color-coded flagging to represent temporary
easement, centerlines, workspaces, environmentally sensitive features, etc. Venture Global would
notify landowners in advance of construction activities that could affect their property or business.
All landowners have granted Venture Global permission to conduct environmental andengineering surveys.
2.5.2.2

General Construction Procedures

Venture Global would construct the Southwest Lateral TGP during Phase I of the Project.
Additionally, to minimize construction disturbance in the area between Southwest Lateral TGP
milepost (MP) 14.3 and MP 15.1, the corresponding collocated segment of Southwest Lateral
TETCO (MP 11.0 to MP 11.7), would be installed concurrently in Phase I. The remainder ofSouthwest Lateral TETCO would be constructed in Phase II. Southwest Lateral TETCO would
be installed adjacent to Southwest Lateral TGP with 50 feet of separation between the twopipelines. An 80-foot-wide permanent easement would be retained where the two pipelines arecollocated.
Five installation methods would be used during construction of the two lateral pipelines:
conventional lay, barge lay, push lay, horizontal directional drill (HDD) lay, and bore lay. In
addition, Venture Global would construct a pipe bridge to cross the non-federal levee located northof Lake Hermitage Road.

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2.5.2.3

Conventional Lay Construction

Pipeline construction using conventional techniques typically involves the following
sequential activities: clearing; trenching; stringing, welding, and installation; backfilling and grade
restoration; hydrostatic testing and tie-ins; and cleanup and restoration. Venture Global proposes
to use conventional lay techniques in upland, non-saturated soil locations. The construction work
area would be cleared to remove trees, rocks, brush, and roots, and then leveled to allow operationof construction equipment. Trenching involves excavating a pipeline ditch and would beaccomplished with backhoes and/or similar excavation machinery. The trench would be excavatedto a sufficient depth to allow a minimum of 3 feet of cover over the pipeline. The 42-inch pipe
would require a minimum trench depth of 10 feet in order to allow 3 feet of cover. The bottom
width of the trench would be cut to accommodate the pipe to be installed. Stringing trucks would
lay, or string, the individual pipe sections on temporary supports (skids) along the working side of
the trench in preparation for subsequent welding, joint coating, lowering-in, backfilling, andassociated inspection activities. After the pipe is lowered into the trench, the trench would bebackfilled with previously excavated material. After the completion of backfilling all disturbed
areas would be graded, erosion controls installed, and restoration completed.
2.5.2.4

Barge Lay Construction

The barge lay method would be required for pipeline sections located in deeper water orchannels as it eliminates the need for land-based equipment and fill. In open waters, the pipeline
would be installed using shallow-draft spud barges. The use of spud barges 2 in open waters would
require the excavation of a flotation channel within a 300-foot-wide construction right-of-way.
Using barges with anchor spuds eliminates the need for an anchor spread and anchor-handlingboats, minimizing the area affected by construction operations.
The right-of-way centerline and boundaries would be staked with poles or floating buoys
ahead of excavation. The pipeline trench would be excavated using a barge-mounted clam-bucket(or equal) dredge. Within the construction right-of-way, it is anticipated that the dredge barge
would first excavate the flotation channel (where necessary) and then excavate the pipe trenchalong the bottom of the flotation channel. The dredge barge would cast the flotation channel andsidecast spoil to either side of the right-of-way centerline, keeping the spoil below the water
surface, where feasible, to minimize wave generated turbidity. The spoil piles would be placedparallel to the trench in 500-foot in lengths, with 50-foot-wide openings to allow the passage of
local watercraft.
The pipeline would be fabricated aboard a string of shallow-draft spud barges, connected
together in a line to form the lay barge. The pipe would first be offloaded from tugboat-towed
supply barges and then each pipe joint would then be aligned end-to-end with the previous joint.
The pipe joints would be assembled into one continuous pipeline by passing through multiple
welding, inspection, repair, and coating stations. To ensure that the assembled pipe meets orexceeds the design strength requirements, the welds would be visually inspected and examinedusing radiography (X-ray), ultrasound, or other approved methods, in accordance with ASME
2

A spud barge is a form of barge that can be moored through the use of through-deck pilings, known as spuds.
Spuds may be fabricated or made of commercially available pipe sections or logs.

2-27

standards. Once each weld has passed inspection and received its final coating, the pipe would belowered off the back end of the lay barge into the pipe trench by lifting the anchor spuds of the lay
barge and moving the lay barge forward the length of one pipe joint. The next pipe joint would berolled into position for welding and the process would be repeated.
From MP 8.1 to 8.5 (Southwest Lateral TGP) and MP 5.6 to 6.0 (Southwest Lateral
TETCO), which represents a relatively short crossing of marshland between two large bodies ofopen water (Upper Wilkinson Bay and Raquette Bay), Venture Global proposes to use the barge
lay method as this marsh area is too saturated to support equipment required to install the pipe via
push lay. To minimize disturbance in this area of open water, Venture Global would stockpile theestimated 89,500 cubic yards of spoil generated by trench excavation on several barges within thesouthern body of open water (Upper Wilkinson Bay). Instead of side-casting on the construction
right-of-way, Venture Global intends to load the material barges and temporarily moor the barges
in the barge staging area. The barge staging area was selected as it is the closest location in which
the open water was deep enough to accommodate the barges without requiring more excavation.
Venture Global would utilize the barge staging area for approximately 30 days during each phaseof construction.
2.5.2.5

Push LayFor the push method, a 130-foot-wide construction right-of-way with a 30-foot-wide trench
width would be required. Push lay techniques are typically used in saturated areas where soil
stability is efficient to support a trench and construction equipment. Trench spoil bank heights are
anticipated to be relatively low because the excavated material lacks adequate unconfinedcompressive strength. To accommodate the trench spoil placement storage, the need for two spoilbanks parallel to the push ditch is anticipated. A 50-foot-wide area would be required on bothsides of the push ditch for spoil banks, equipment travel, and reasonable buffer gaps. Thus, thepush construction technique would require a 130-foot-wide construction right-of-way due to the
combination of the 30-foot-wide push ditch and the two 50-foot-wide areas for spoil banks,
equipment travel, and reasonable buffer gaps between the edges of the right-of-way, spoil banks,and ditch.
Push sites in open-water areas would consist of several shallow-draft spud barges
connected together to provide a working platform. At the push site, various pipeline operations
would take place, including pipe make-up, welding, non-destructive testing, joint coating andcoating repairs, and installation of flotation apparatus. Where there is standing water, only enoughclearing and trenching would be done to accommodate installation of the pipe. Each excavator
used would have a lateral reach sufficient to place spoil within the 130-foot-wide construction
right-of-way. Pipe stringing and lowering in the push lay method would be similar to that
described in the conventional lay method.
2.5.2.6

HDD Lay

The HDD method is a trenchless method for installing underground pipe and is used to
avoid direct impacts on sensitive resources (e.g., waterbodies, wetlands) or infrastructure (e.g.,major roads, railroads). This method entails drilling relatively deep beneath the surface features

2-28

on a curved path. This method requires specialized equipment and personnel and has four general
steps:
1. placement of guide wires over the anticipated path of the drill;
2. drilling a pilot hole on an arc-shaped path that typically extends between 30 and 50 feetbeneath the waterbody or other sensitive feature;
3. enlarging the pilot hole with a series of reamers to accommodate the pipeline; and4. pulling a pre-fabricated section of pipe through the hole.
The HDD method involves an entry and exit pad on each side of the crossing. The initial
step of placing HDD guide wires over the path of the drill may require minor hand clearing. A
pilot hole is drilled under the feature. The head of the pilot drill string contains a pivoting headthat can be controlled by an operator as the drill progresses. Typically, the pilot hole would bedirected downward at an angle until the proper depth is achieved, then turned and directedhorizontally for the required distance, and finally angled upward back to the surface. Throughout
the process of drilling and enlarging the hole, mud slurry, consisting of bentonite and water, would
be pressurized and pumped through the drill stem to lubricate the drill bit, maintain the hole, andremove drill cuttings. Bentonite is the commercial name for a nontoxic mixture of naturallyoccurring clays and rock particles. This slurry, referred to as drilling mud or drilling fluid, has thepotential to be inadvertently released to the surface if fractures or fissures are encountered in thesubstrate during drilling.
The potential for an inadvertent release is generally greatest during drilling of the pilot holewhen the pressurized drilling mud is seeking the path of least resistance and near the drill entry orexit pits where the drills are at their shallowest depths. The path of least resistance is typicallyback along the path of the drilled pilot hole. However, if the drill path becomes temporarily
blocked or encounters areas such as large fractures or fissures that lead to the ground, then an
inadvertent release could occur. Venture Global developed a site-specific HDD plan for each drillsite and an HDD Contingency Plan to monitor for, contain, and clean up any inadvertent releasesof drilling fluid during HDD operations. The HDD Contingency Plan is included in appendix D
and would be utilized to:•provide procedures that will minimize the potential for release of drilling mud into
sensitive resource areas, such as wetlands and waterbodies, or onto adjacent uplandsurfaces;•

provide for timely detection of inadvertent returns;•

ensure the implementation of an organized, timely, and “minimum impact” response in
the event an inadvertent return of drilling fluid occurs;•

ensure that all appropriate notifications are made in a timely manner;•provide for an alternative plan in case of drill failure; and

2-29

•

establish the criteria by which Venture Global will determine when a proposed HDD
crossing is unsuccessful and must be abandoned.

Venture Global would install one 0.4-mile-long segment of pipe using the HDD method
for each of the two pipelines. Both drill segments would be at the same route location, extending
into the LNG terminal from just north of the pipe bridge crossing of the non-federal levee north ofLake Hermitage Road (MP 14.6 to MP 15.0 for the Southwest Lateral TGP, and MP 11.2 to 11.6
for the Southwest Lateral TETCO). Both HDDs would be undertaken during Phase I construction.
Additional information on the related geotechnical investigations is presented in section 4.1.1.
2.5.2.7

Bore Lay

The bore method is a process that allows for trenchless installation by drilling a horizontal
tunnel beneath a surface feature, such as road or utility, and installing a prefabricated segment ofpipeline through the hole. Similar to the HDD method, throughout the boring process, a fluid
mixture consisting of water and bentonite clay (a naturally occurring mineral) is pumped into thedrill hole to lubricate the bit, transport cuttings to the surface, and maintain the integrity of the holeduring installation of the prefabricated segment.
If a bore installation is successful, there is little to no impact on the surface feature being
crossed. However, if a natural fracture or weak area in the ground is encountered during drilling,
an inadvertent return of drilling fluid to the environment could occur. Venture Global’s HDD
Contingency Plan (appendix D) would also be applicable to bore construction methods and would
outline the procedures that would be followed to minimize the potential for an inadvertent releaseof drilling mud and to undertake effective cleanup should a release occur.
2.5.2.8

Aboveground Facility Construction Procedures

Two meter stations are required for the pipeline system. Each meter station would belocated in an open-water area; therefore, traditional site preparation, including clearing, grading,and compacting, would not occur. Construction would include the placement of a platform on
installation piles. The meter stations would be constructed atop these platforms.
All components in high-pressure natural gas service would be pressure tested prior toarrival or on site, and all controls and safety equipment and systems, emergency shutdown, relief
valves, and gas measurement and control equipment would be commissioned prior to being placed
in service.
2.5.3

Access Roads

During construction, vehicular access to the LNG terminal site would be via existing local
public roadways. Venture Global does not anticipate that such access would require any
improvements to these roadways, with the exception of new auxiliary turn lanes along southboundSH 23, new site entrances/exits on SH 23, and signage and lighting as required by DOTD.
Venture Global would construct one permanent access road to the two MLVs just west of
Lake Hermitage Road and one temporary access road to the pipe bridge area just east of Lake

2-30

Hermitage Road. Both access roads would be used during construction, and the permanent accessroad would also be used during operation.
2.5.4

Pipe Storage and Contractor Yard

Venture Global is not planning to use pipe yards. Instead, Venture Global would receive
pipe joints from the pipe-coating yard transported to the workspaces by truck for upland and HDD
construction, and transported by lay barge for open water and wetland pull sections. The LNG
terminal site would not require any additional pipe storage yards beyond the site’s own limits ofconstruction.
2.5.5
2.5.5.1

Special Construction Procedures
Levee Crossing Construction Procedures

On the pipeline system, Venture Global plans to use a pipe bridge to cross the non-federal
levee and adjacent canal south of the LNG terminal site. For the pipe bridge crossing, theconstruction process includes piling, pile cap installation, crane erection, setting vertical andhorizontal bridge assemblies, and piping installation. Installation of the piles would be completed
at the base of each bridge vertical assembly. Precast, steel, cast in-place, or concrete-driven piles
would be installed by either a ground-supported rig, a marsh buggy-supported rig, or a bargesupported rig. The piles would be driven or constructed to meet the design capacity and would betested to verify vertical and horizontal capacity of the piles in each group of piles. The concrete
foundation would be poured as a pile cap around the top of the trimmed piles to create a fixed
connection between the cap and the piles.
The bridge components would be trucked to the site in 20-foot to 130-foot-long
preassembled section lengths. The bridge vertical components would be set on the pile caps andwould support the horizontal components on top of the vertical components. All field connections
are planned to be bolted connections to reduce the amount of field labor, amount of equipment thatis required on site, and impact on the temporary workspace. The pipeline would be supported on
the bridge by temporary rollers during installation. The final pipe supports would be installed as
adjustable supports with clamping straps to allow axial thermal growth while resisting movement
due to wind and seismic loading. The piping would be transitioned from the top of the bridge
through piggable induction bends and connected to below-grade piping near the ends of the bridge
work area.
2.5.5.2

Wetland and Waterbody Construction Procedures

Crossings of waterbodies and wetlands would be undertaken in accordance with the
Project-specific Procedures. Because the Project involves use of the push method or barge lay
method for installation of large-diameter pipelines, Venture Global proposes to use construction
right-of-way widths greater than 75 feet, as described below.
In general, FERC requires wetland crossings to be accomplished using a maximum rightof-way width of 75 feet. Venture Global states in its application that this is not possible on thisProject. The route for the Southwest laterals is located in a region where consolidated soils
comprise less than 3 percent of the routes. Therefore, Venture Global’s implementation of the
2-31

push method is designed to minimize impacts on the vegetated wetland areas but does require
workspaces greater than 75 feet wide.
Given the poor cohesion and expected high water content/saturation of the wetland soils
along the route, Venture Global anticipates that the top-of-trench width would be a minimum of
30 feet and up to 50 feet to accommodate sloughing and resultant shallow side slopes. Further,because the material excavated from the trench would lack cohesion, the spoil banks are
anticipated to be relatively low in height (approximately 3 feet) and wide (approximately 45 feet).
2.5.5.3

HDD Construction

The HDD method is a trenchless crossing method used to avoid direct impacts on sensitive
resources (e.g., waterbodies, wetlands) or infrastructure (e.g., major roads, railroads) byconducting a deep bore beneath them. This method, described above in section 2.5.2.6, requires
specialized equipment and personnel.
Venture Global would install one 0.4-mile-long segment of pipe using the HDD method
for each of the two pipelines. Both drill segments would be at the same route location, extending
into the LNG terminal from just north of the pipe bridge crossing of the non-federal levee north ofLake Hermitage Road (MP 14.6 to MP 15.0 for the Southwest Lateral TGP, and MP 11.2 to 11.6
for the Southwest Lateral TETCO). Both HDDs would be undertaken during Phase I construction.
Additional information on waterbody crossings, including the use of the HDD method, is presented
in section 4.3.2.2.
2.5.5.4

Proposed Modifications to the Federal Energy Regulatory Commission’s Plan

Venture Global’s Project-specific Plan includes proposed modifications to FERC’s Plan(appendix C). FERC allows project sponsors to request modifications to its Plan. The FERC Plan
directs applicants to specify in their application any individual measures that they consider
unnecessary, technically infeasible, or unsuitable due to local conditions, and to describe thealternative measures they propose to use. They must also explain how their proposed alternative
measures would achieve a comparable level of mitigation as the FERC measures.
The Project-specific Plan includes numerous minor wording changes to specify the Projectsponsor and provide clarifications that do not require our specific approval. Those proposed
modifications that are substantive and for which we have determined that Venture Global provided
adequate justification are listed in appendix C, table 1. The table includes the original text from
FERC’s Plan, the modified text in the Project-specific Plan, and our determination regarding the
proposed modification.
2.5.5.5

Proposed Modifications to the Federal Energy Regulatory Commission’s
Procedures

Venture Global’s Project-specific Procedures regarding wetland and waterbody crossings
include certain proposed modifications to FERC’s Procedures (appendix C). Just as with our Plan,
FERC’s Procedures directs applicants to specify in their application any individual measures thatthey consider unnecessary, technically infeasible, or unsuitable due to local conditions, and to2-32

describe the alternative measures they propose to use. They must also explain how their proposed
alternative measures would achieve a level of mitigation comparable to the FERC measures.
The Project-specific Procedures include numerous minor wording changes to specify the
Project sponsor and provide clarifications that do not require our specific approval. Those
proposed modifications that are substantive and for which we have determined Venture Global
provided adequate justification are listed in appendix C, table 2. The table includes the originaltext from FERC’s Procedures, the modified text in the Project-specific Procedures, and ourdetermination regarding the proposed modification. One modification that was proposed by
Venture Global regarding the time-of-year for crossing waterbodies is already allowed by the
FERC Procedures and is not included in the following table; however, this is discussed further insection 4.3.2.3.
2.6

OPERATION, MAINTENANCE, AND SAFETY PROCEDURES

All facilities would be operated and maintained in accordance with government safety
standards and regulations that are intended to ensure adequate protection of the public and toprevent facility accidents and failures.
2.6.1

LNG Terminal

Operating procedures would be prepared for the Project after final design is completed.
These procedures would address safe startup, shutdown, cool down, purging, etc., as well as
routine operation and monitoring. Comprehensive training would be provided to ensure that all
facility personnel are familiar with and adhere to properly documented and recognized safety
procedures. The potential hazards of cryogenic LNG operation and proper equipment operation
would be two areas of focus. Operators would meet the applicable training requirements of the
USCG, DOTD, and other regulatory entities. Maintenance and safety procedures would be
developed to cover the proper disposal for all hazardous fluids generated by LNG terminal
operations. The procedures would include training of staff in the storage and handling of
hazardous material. Additionally, the terminal SPCC Plan discusses spill response procedures,materials, and training; mitigation measures/response; and hazardous liquids quantities, storage,
and disposal.
Maintenance of the LNG terminal and pipeline system must be conducted in accordancewith the provisions of 49 CFR 193, subpart G, and would be in compliance with all applicablelaws and regulations, and through procedures and programs developed by Venture Global. Fulltime staff would conduct routine maintenance and minor repairs, whereas major overhauls andnon-routine maintenance would be handled by specialty contractors. Both scheduled andunscheduled maintenance would be entered into a computerized maintenance management systemand disseminated to the appropriate personnel for follow-up. All operators and maintenancepersonnel would be trained in the use of the computerized maintenance management system.
Scheduled preventive and predictive routine maintenance would include equipment rotation andinspection of safety equipment, environmental equipment, and instrumentation. All maintenanceactivities would be implemented by trained maintenance technicians reporting to a MaintenanceSupervisor.

2-33

Prior to operations, Venture Global would develop a complete solid and hazardous waste
management plan that would describe procedures to ensure compliance with applicable state
regulations and federal requirements per 40 CFR 260, Hazardous Waste Management. Solid waste
typically generated during operations includes predominantly nonhazardous office waste androutine maintenance wastes such as paper, cardboard, scrap metal, wood, plastic, and small
equipment parts. Examples of hazardous waste materials typically generated during operations
include used oils, transmission and hydraulic fluids, antifreeze, absorbents, amines, greases, paints,
and cleaning agents.
Under Venture Global’s solid and hazardous waste management plan, recyclable materials
would be separated and recycled. Non-recyclable wastes would be stored in covered trash binsaccording to state and local requirements. Hazardous wastes would be stored in labeled 55-gallon
drums or other containers appropriate for the particular waste, equipped with secondary
containment if required. Hazardous and non-hazardous waste must be transported in accordancewith applicable DOT regulations for recycling, treatment, or disposal and in compliance withfederal, state, and local regulations.
2.6.2

Pipeline System

Operation activities for the pipelines would be limited to right-of-way maintenance andpipeline inspection and repair, as needed. Company personnel would perform periodic aerial andground inspections for exposed pipe, unauthorized encroachment on the right-of-way, activities inthe vicinity of the right-of-way, and other conditions that could present a safety hazard or requirepreventative maintenance or repairs. The pipeline cathodic protection system would also bemonitored and inspected periodically to ensure proper and adequate corrosion protection.
Appropriate corrective actions for conditions observed during inspection would be taken asnecessary.
The pipeline facilities would be clearly marked at line-of-sight intervals and at crossingsof foreign pipelines, marine channels, roads, and other key points. The markers would indicate
the presence of the pipelines and provide a telephone number and address where a company
representative can be reached in the event of an emergency or prior to any excavation in thepipeline vicinity by a third party.

2-34

3.0

ALTERNATIVES

To adhere to CEQ regulations for complying with NEPA (40 CFR 1502.14), an EIS mustevaluate reasonable alternatives. This EIS does so by comparing the environmental impacts of the
proposed action against a range of alternatives. Each of the cooperating agencies with obligations
under NEPA can use this alternatives analysis as part of their decision-making process. Individual
agencies would ensure consistency with their own administrative procedures prior to accepting therecommendations in this EIS.
In accordance with NEPA and Commission policy, we evaluated alternatives to the Project
to determine whether any would be reasonable and have significant environmental advantages
compared to the proposed action. The alternatives analyzed consisted of the No Action
Alternative, system alternatives for the LNG terminal and the pipeline system, alternative LNG
terminal site locations, alternative LNG terminal configurations, an alternative pipeline route, andalternative locations for aboveground facilities. In some cases, the analysis concluded thatconsideration of alternatives was not feasible or required, and this is indicated, where applicable.
As part of the No Action Alternative, this EIS considers the effects and actions that could
conceivably result if the proposed Venture Global Project were not constructed. The analysis ofsystem alternatives evaluates the ability of other existing, planned, or proposed (new or expanded)
LNG export terminals and pipeline systems to meet the Venture Global Project’s purpose andobjectives. The evaluation of alternative sites for the LNG terminal focuses on several locations.
The primary consideration of pipeline route alternatives is related to the proposed Southeast andSouthwest laterals.
We applied the following evaluation criteria when considering and weighing potentiallyreasonable and environmentally preferred alternatives to the Venture Global Project:•

The alternative must be technically and economically feasible and practical.

•

The alternative must offer significant environmental advantages over the proposed
Project or segment of the Project.

•

The alternative must meet Venture Global’s stated purpose of its proposed Project,specifically:o to provide a cost-effective outlet for domestic natural gas to the global market byconstructing liquefaction blocks and a new pipeline to transport LNG to global
markets; ando provide a peak liquefaction capability of 24.0 MTPA for export, consistent with
Venture Global’s DOE/FE authorization.

Venture Global participated in our pre-filing process during the preliminary design stageof the Project (see section 1.3). This process emphasized identification of stakeholder issues aswell as identification and evaluation of alternatives that could reduce environmental impacts. We
analyzed each alternative based on public comments and guidance received from federal, state,
and local regulatory agencies. Additional sources of information included Venture Global’s field
3-1

surveys, aerial photography, USGS topographic maps, the FWS’s National Wetland Inventory(NWI) maps, pipeline system maps, agency consultations, and publicly accessible databases. To
ensure equitable results, consistent data sources were used when comparing a feature acrossalternatives (e.g., NWI data were used for wetlands comparisons, rather than a combination of
NWI and field survey data). The following sections include a discussion of the scope,methodology, and results of our alternatives analysis.
The USACE assisted us in preparing this EIS and may use the document in its permit
decision-making process. When making a decision on whether to issue its permit, the USACE
must consider whether a proposed project represents the least environmentally damaging,practicable alternative pursuant to CWA section 404(b)(1) guidelines. The term “practicable”
means that the alternative is available and capable of being done after taking into consideration
cost, existing technology, and logistics in light of the overall purpose of the project. The USACE
may not permit the discharge of dredged or fill materials into waters of the United States if there
is a practicable alternative to the discharge that would result in less adverse impact on the aquatic
ecosystem, unless the alternative would result in other significant adverse environmental
consequences.
It is important to note that not all alternatives warrant the same degree of evaluation.
Through environmental comparison and exercise of our professional judgement, each alternative
was evaluated until it became clear that the alternative would: (1) be unable to meet the statedpurpose of the proposed Project; (2) be technically and/or economically infeasible or
impracticable; or (3) not offer a significant environmental advantage. The alternatives thatappeared to be reasonable with the potential for significantly less environmental impact are
reviewed in greater detail below. A detailed discussion of the environmental consequences of the
Project (both adverse and beneficial) is included in section 4.0.
3.1

NO ACTION ALTERNATIVE

If FERC denies the Venture Global application (the No Action Alternative), the resource
impacts (including short- and long-term and permanent impacts) identified in this EIS would notoccur. However, the No Action Alternative would prevent Venture Global from achieving its
stated purpose of transporting LNG to global markets. The No Action Alternative would alsopreclude the economic benefits of employment and tax revenues, as discussed in sections 4.9.1
and 4.9.2. Selecting the No Action Alternative could require potential end users to make different
arrangements to obtain LNG from other sources. This could result in the use or expansion of otherexisting or proposed LNG facilities and associated interstate natural gas pipeline systems, or in theconstruction of new infrastructure in the Project area or elsewhere in the United States, resulting
in both adverse and beneficial environmental impacts. LNG terminal developments and pipeline
system expansions of similar scope and magnitude to the proposed Project would likely result inenvironmental impacts of comparable significance, especially those projects in a similar regionalsetting. In section 3.2, we examine reasonable LNG system alternatives.
Commenters have suggested that LNG export projects could be replaced by renewableenergy resources alternatives such as wind power, solar power, tidal power, and hydropower. Allof these alternatives represent alternative means of producing electrical power. Because the3-2Project’s primary purpose is to prepare natural gas for export to foreign markets, development or
use of renewable energy technology would not be a reasonable alternative to the proposed action.
3.2

SYSTEM ALTERNATIVES

System alternatives would make use of other existing, modified, or proposed LNG facilities
and/or pipeline systems to meet the stated objectives of the Project. A system alternative would
make it unnecessary to construct all or part of the Project; however, some modifications oradditions to another existing system may be necessary. Such modifications or additions would
result in environmental impacts that could be less than, similar to, or greater than those associatedwith construction of the Project. The purpose of identifying and evaluating system alternatives isto determine whether potential environmental impacts associated with construction and operationof proposed facilities could be avoided or reduced while still meeting the purpose and basic
objectives of the Project. The analysis of the system alternatives for the LNG terminal is presented
in section 3.2.1, and the pipeline system alternatives are evaluated in section 3.2.2.
3.2.1

LNG Project System Alternatives

For a system alternative to be viable and recommended, it must meet the purpose and needof the project, be technically and economically feasible, and offer a significant environmental
advantage over the project as proposed. In the case of this Project, it must also be compatible with
Venture Global’s proposed export capacity, consistent with authorizations from the DOE/FE.
Venture Global is proposing to export LNG to FTA and non-FTA countries. The volume of gas(commodity) for FTA countries has already been approved by the DOE and, therefore, isdetermined to be in the public interest by the DOE. The DOE determination for non-FTA countries
is pending. There are other approved, proposed, or planned LNG export facilities along the Gulf
Coast that have also either obtained or applied for DOE approval for the export of LNG associatedwith the production capacity in the respective project plans/proposals. Each of the approved,
proposed, or planned projects considered as a potential system alternative (either to expand an
existing facility or new construction at a proposed terminal site to accommodate the Venture
Global’s Project objective) is listed in table 3.2-1. In order for Venture Global’s customers to
obtain LNG from any of these other facilities, these facilities would need to construct additionalliquefaction facilities to meet the export capacity proposed by Venture Global and as approved by
the DOE authorizations. We recognize that liquefaction capacity may not be fully subscribed at
all of these other facilities based on contracts executed as of the writing of this EIS. However,
because the DOE’s export approval is a determination that the export is in the public interest, we
will not speculate that any portion of other LNG terminals’ liquefaction capacity is in “excess” oravailable as an alternative for use by Venture Global to meet its Project objectives.

3-3

TABLE 3.2-1
System Alternatives – Summary of Approved, Proposed, and Planned LNG Export Projects
Project Name
(FERC Docket No.)a

Total
Capacity(MTPA)

Owner
Location

Project Status

Status of FTA/NonFTA Approvals

Approved LNG Export Terminals

Cheniere/Sabine Pass LNG
Terminal(CP11-72 and CP14-12)
Sabine Pass Expansion(CP13-552 and CP13-553)
Cameron LNG Terminal(CP13-25)
Cameron LNG Expansion(CP15-560)
Freeport LNG
Dev/Freeport LNG
Expansion/ FLNG
Liquefaction Terminal(CP12-29, CP12-509, andCP15-518)
Freeport LNG Expansion(CP17-470)
Corpus Christi
Liquefaction Project(CP12-507 and CP12-508)
Stage 3 Project(CP18-512 and CP18-513)

Lake Charles LNG
Terminal(CP14-120)

Magnolia LNG Terminal(CP14-347)
Golden Pass LNG
Terminal(CP14-517 and CP14-518)
Calcasieu Pass LNG
Export Terminal(CP15-550 and CP15-551)

Sabine Pass Liquefaction, LLC/ Sabine Pass Liquefaction
Expansion, LLC / Sabine Pass
LNG, L.P.

20.0

Trains 1-4: Operating
FTA: Authorized
Non-FTA:
Authorized

9.0

Train 5: Under
construction
Train 6: Under
construction

Cameron LNG, LLC

15.0

Under construction

Hackberry, Louisiana

10.0

Approved

Freeport Development, L.P./
FLNG Liquefaction, LLC/FLNG Liquefaction 2, LLC/FLNG Liquefaction 3,
LLC/FLNG Liquefaction 4,
LLC

15.3

Under construction

FTA: Authorized
Non-FTA:
Authorized

5.1

Application filed
06/29/2017

FTA: Authorized
Non-FTA: Pending

15.0

Train 1: Operating
Trains 2-3: Under
construction

FTA: Authorized
Non-FTA:
Authorized

11.45

Application filed
06/28/2018

FTA: Authorized
Non-FTA: Pending

16.45

Under construction

FTA: Authorized
Non-FTA:
Authorized

8.0

Approved

FTA: Authorized
Non-FTA:
Authorized

15.6

Approved

FTA: Authorized
Non-FTA:
Authorized

12.0

Under Construction

FTA: Authorized
Non-FTA: Authorized

10.0

Application filed on
06/19/2015

FTA: Authorized
Non-FTA: Pending

Sabine, Louisiana

Freeport, Texas
Corpus Christi Liquefaction,
LLC
Corpus Christi, Texas
Corpus Christi Liquefaction
Stage III, LLC
Corpus Christi, Texas
Lake Charles LNG Company,
LLC / Lake Charles LNG
Export Company, LLC /Trunkline Gas Company, LLC
Lake Charles, Louisiana
Magnolia Pipeline Company,
LLC / Magnolia LNG, LLC
Lake Charles, Louisiana
Golden Pass Products, LLC /Golden Pass Pipeline, LLC
Sabine Pass, Texas
Venture Global Calcasieu Pass,
LLC

Cameron Parish, Louisiana
Proposed LNG Export Terminals
Gulf LNG Liquefaction
Company, LLC / Gulf LNG
Gulf LNG Terminal
Energy, LLC(CP15-521)
Pascagoula, Mississippi

3-4

FTA: Authorized
Non-FTA:
AuthorizedTABLE 3.2-1
System Alternatives – Summary of Approved, Proposed, and Planned LNG Export Projects
Project Name
(FERC Docket No.)a

Driftwood LNG Project(CP17-118 and CP17-119)
Rio Grande LNG Project(CP16-454 and CP16-455)

Annova LNG Project(CP16-480)

Owner
Location

Driftwood LNG, LLC andDriftwood Pipeline, LLC

Total
Capacity(MTPA)

Project Status

Status of FTA/NonFTA Approvals

26.0

Approved

FTA: Authorized
Non-FTA: Pending

27.0

Application filed on
05/05/2016

FTA: Authorized
Non-FTA: Pending

7.0

Application filed on
07/13/2018

FTA: Authorized
Non-FTA: Not
requested

13.5

Approved

FTA: Authorized
Non-FTA: Pending

20.0

Application filed on
02/28/2017

FTA: Authorized
Non-FTA: Pending

Lake Charles, Louisiana
Rio Grande LNG, LLC / Rio
Bravo Pipeline Company, LLC
Brownsville, Texas
Annova LNG Common
Infrastructure, LLC / Annova
LNG Brownsville A, LLC/
Annova LNG Brownsville B,
LLC / Annova LNG
Brownsville C, LLC
Brownsville, Texas

Port Arthur LNG Project(CP17-20 and CP17-21)
Venture Global
Plaquemines LNG(CP17-66)

Port Arthur LNG, LLC / Port
Arthur Pipeline, LLC
Venture Global Plaquemines
LNG, LLC

Plaquemines Parish, Louisiana
Planned LNG Export Terminals
Commonwealth LNG, LLC /Commonwealth LNG
Commonwealth Projects, LLC
Pre-filing approved on
FTA: Authorized
Project
9.0
08/15/2017
Non-FTA: Pending(PF17-8)
Cameron Parish, Louisiana
Fourchon LNG Export
Fourchon LNG, LLC
Pre-filing approved on
FTA: Authorized
Facility
5.0
08/21/2017
Non-FTA: Pending(PF17-9)
Lafourche Parish, Louisiana
Galveston Bay LNG
Galveston Bay LNG, LLC
Pre-filing approved on
FTA: Authorized
Project
16.5
12/7/2018
Non-FTA: P ending(PF18-7)
Galveston, Texas
Pointe LNG, LLC
Pre-filing approved on
Pointe LNG Project6
Not submitted
10/16/2018(PF18-8)
Plaquemines Parish, Louisiana
Venture Global Delta LNG,
Pre-filing request
FTA and Non-FTA:
Delta LNG
LLC
24.0
submitted 04/17/2019
Pending(PF19-4)
Plaquemines Parish, Louisiana____________________a
To access the public record for this proceeding, go to FERC’s website (http://www.ferc.gov), click on “Documents
and Filings” and select the eLibrary feature. Click on “General Search” from the eLibrary menu and enter the
docket number.

An expansion of existing facilities to meet the export capacity proposed by Venture Global
would need to be of a similar scope of pre-treatment and liquefaction facilities and possibly
additional storage and marine transfer facilities, while any new facility would need a similar scopeof pre-treatment, liquefaction, storage, and marine transfer facilities to accommodate theobjectives of the proposed Project. Any expansion of an existing facility would result inenvironmental impacts that would likely be equal to or greater than the environmental impacts ofthe proposed action (depending on the environmental resource affected) and may not provide a
3-5

significant environmental advantage over the proposed Project. Our analysis of system
alternatives listed in table 3.2-1 assumes and/or considers whether the Project has an equal chanceof being constructed, has the onsite space required for an expansion to accommodate facilities
similar to those proposed for the Project, could be served by a pipeline system(s) for the export of
24.0 MTPA of LNG, and has a compatible in-service timeframe to meet the Project’s objective.
Meeting these criteria would qualify the system as a potential alternative. However, future
Commission review and market forces will ultimately decide which and how many of thesefacilities are built.
As identified in table 3.2-1, we reviewed the liquefaction terminals that have beenauthorized, proposed, or planned as an alternative to the Project. Our review of Venture Global’s
proposed LNG terminal site we find no significant impacts in section 4.0 when mitigation is
included, during the construction and operation of the LNG terminal or pipeline system.
Additionally, we did not receive any specific comments relating to the use of a specific liquefaction
terminal as a system alternative to the proposed LNG terminal. We note again that the Commission
does not design projects. If the Commission ultimately determines that another project would be
more appropriate, it could deny a proposal, but it could not force another entity to build a projectthat it has not proposed. Also, if the market support is not demonstrated for a project, and export
volumes proposed by one liquefaction terminal are met by another liquefaction terminal, a project
may not get built. However, we cannot speculate as to the future state of export markets or any
project that may ultimately meet the same market demands as Venture Global.
As mentioned, Venture Global’s export of LNG to FTA countries has already been foundin the public interest by the DOE. For our analysis, we are assuming that all projects havecontracted volumes and, as a result, these are not available as a direct “replacement” for the export
volumes proposed by Venture Global. Any of the potential system alternative terminals would
require additional volumes above and beyond what they have proposed or have been authorized inorder to replace the liquefaction facilities of Venture Global.
If another entity proposes replacement facilities for Venture Global’s facilities, they would
need to submit an application identifying exactly what the replacement facilities would entail,including their environmental impact, and conduct the corresponding safety and engineering
analysis. While this information is not available to Venture Global, it is likely that similar facilities
at other locations would have very similar impacts to Venture Global’s proposal, as they are also
in coastal areas. Each of these sites would include the permanent fill of wetlands and involve
impacts on waterways and fisheries. But, a simple one-to-one “placement” of the Venture Global
facilities at another location may not be an accurate representation of what would be required,especially if the additional LNG vessel traffic would require additional berths. Such an analysis
would be based on speculation and hypotheticals and would not provide the information necessary
to inform the decision makers of the associated environmental impact.
It should also be noted that unlike a pipeline under section 7 of the NGA, an authorization
granted under section 3 of the NGA does not grant the applicant eminent domain. As a result, wecannot speculate that a recommended alternative site would be available unless the landowner
would make it available for purchase or lease.

3-6Because none of the potential system alternatives would be able to design, engineer, permit,and construct a project within the timeframe proposed by Venture Global, and similar facilities atother coastal locations would have very similar impacts to Venture Global’s proposal, we find thatnone of the system alternatives are a viable replacement that meets Venture Global’s objectives.
In conclusion, no system alternative meets the criteria of being technically and economicallyfeasible, provides a significant environmental advantage, and meets the objectives of Venture
Global to permit and construct a project; therefore, we do not recommend any system alternative
to replace the proposed LNG terminal.
3.2.2

Pipeline System Alternatives

To serve as a viable pipeline system alternative to the proposed Venture Global pipeline
system, the system would need to: (1) transport all or a part of the volume of natural gas required
for liquefaction at the LNG terminal; and (2) cause significantly less impact on the environment
than the proposed Venture Global pipeline system. Gas provided by a system alternative must
connect to the Venture Global pipeline or directly to the LNG terminal.
We conducted a review of all existing natural gas pipeline systems in the Project area.
Following identification and evaluation of geographically proximate natural gas pipeline systems,
the delivery capacity of each system was considered. The proposed pipeline is designed to connect
the LNG terminal to TGP and TETCO, the two existing natural gas pipeline systems nearest to theterminal site with sufficient delivery capacity to serve Project needs. Because there is no existingor proposed pipeline that connects these systems to the LNG terminal, there is no reasonablesystem alternative to the Venture Global pipeline. Route alternatives for the Venture Global
pipeline are discussed in section 3.5.
3.3

ALTERNATIVE TERMINAL FACILITY SITES

3.3.1

LNG Terminal Site Alternatives

Based in part on the information provided by Venture Global, we evaluated site alternatives
identified by Venture Global in the general area of the proposed LNG terminal site.
Venture Global chose Louisiana as their preferred location based on the following three
attributes:•

ready access to the Gulf of Mexico and maritime transportation routes to both theeastern and western hemispheres;•availability of potential sites on major navigable waterways (Calcasieu River andMississippi River) that can accommodate LNG carriers and have a history of industrial
and commercial use; and•state and local government support for industrial commerce and development.

3-7Venture Global defined selection criteria to analyze site alternatives in southeast andsouthwest Louisiana. Venture Global identified sites based on whether they:•

provide direct access to a deep-draft shipping channel (40 feet or more below sea level)with sufficient water frontage for multiple LNG carriers;•

have compatible surrounding land use and are of sufficient size to construct and operate
the proposed LNG facility;•

are available for purchase or long-term lease arrangements;•

have a sufficient buffer between the site and residential neighborhoods;•

have suitable road access and proximity to one or more highways;•

are proximate to natural gas pipeline infrastructure;•are proximate to utilities (water and electrical); and•avoid/minimize wetland/waterbody impacts and have viable mitigation options.

Using the eight selection criteria described above, the six potential sites were evaluated by
Venture Global to determine the preferred location for the proposed LNG terminal. The generallocations of the six site alternatives are shown on figure B-2 in appendix B. A comparison of eachalternative site is presented in table 3.3-1 and discussed below.
3.3.1.1

Mississippi River Mile 55–West Bank (Proposed Site)

This parcel was the only site that meets all of the screening criteria established by Venture
Global; therefore, Venture Global selected this site as the proposed LNG terminal site. The parcel
has sufficient shoreline frontage (approximately 7,000 feet) on the Mississippi River toaccommodate three LNG loading docks in a location that would allow safe and efficient navigation
for both LNG carriers and existing marine traffic. The parcel is also of a suitable size, geometricshape, and topographic profile to optimize the layout design for plant infrastructure and bufferzones with respect to engineering feasibility, constructability, and safety. This site is available forlease and is located near existing utilities that would be required for operation. Louisiana Highway
23 bisects the proposed site, providing easy access.

3-8

Table 3.3-1
Alternative Sites Selection Criteria Summary
Mississippi
River Mile 55
West Bank(proposed)

Mississippi
River Mile 56

Mississippi
River Mile 55
East Bank

CutronePropertySouth Carlyss
Site I

South Carlyss
Site II

Deepwater
access/waterfront footage

Yes

No

No

No

No

No

Sufficient land area andcompatibility withsurrounding land use

Yes

No

No

Yes

No

No

Land available for leaseor purchase

Yes

No

No

No

Yes

Yes

Sufficiency of buffera

Yes

No

No

Yes

No

No

Road and highway access

Yes

Yes

Yes

Yes

Yes

Yes

Proximity to natural gas
pipelines

Yes

Yes

Yes

Yes

Yes

Yes

Proximity to utilities

Yes

Yes

Yes

Yes

Yes

Yes

Wetland/waterbody
avoidance/minimizationand viable mitigation
alternatives

Yes

Yes

Yes

Yes

No

No

Selection Criteria

Notes:
a The distance necessary in order to not create an LNG thermal dispersion hazard to surrounding residential areas, businesses or
public areas.

Natural gas pipelines to supply feed gas are in proximity to this site. In addition to meeting
the Venture Global selection criteria, the site is located within fastlands, so it is protected by levees
and pump systems to minimize flood risks. NWI wetland data indicated that riparian wetlands arelocated in the batture area within the Mississippi River levee, only small pockets of wetlands exist
within the site landward of the Mississippi River levee, and there is appropriate mitigation
available in the form of mitigation bank credits and potential restoration parcels in the vicinity ofthe site. For these reasons, Venture Global selected the Mississippi River Mile 55–West Bank as
its preferred site and proposed LNG terminal location.
3.3.1.2

Mississippi River Mile 56

The Mississippi River Mile 56 site is an approximately 297-acre land parcel on the eastbank of the Mississippi River at river mile 56. Currently, the property is used for agriculture. A
coal-handling facility (United Bulk Terminal) is located directly to the east, and a barge terminal(Associated Terminal) lies to the west. Louisiana State Highway 39 fringes the parcel’s northernboundary, and the Mississippi River marks the southern boundary. A small residential community
is located adjacent and directly to the north. A highway, natural gas pipelines, and utilities arelocated in proximity to the site. NWI wetland data indicated that riparian wetlands are located in
the batture area within the Mississippi River levee and only small pockets of wetlands exist within
the site landward of the Mississippi River levee. Appropriate mitigation is available in the formof mitigation bank credits and potential restoration parcels in the vicinity of the site.
3-9

The approximately 5,100 feet of water frontage along the Mississippi River Mile 56 site is
insufficient to support the three LNG loading docks for the proposed facility. Land use in thevicinity of the site, including the industrial facilities and residential community, is not compatible
with an LNG terminal. The parcel is corporately owned, which could lead to lengthy and uncertain
property negotiations; therefore, the availability of the property is uncertain. Sufficient buffersfrom incompatible land uses would not be available due to the residential community. For thesereasons, the Mississippi River Mile 56 site was not considered preferable to the proposed site.
3.3.1.3

Mississippi River Mile 55–East Bank

The Mississippi River Mile 55–East Bank site is an approximately 475-acre parcel on theeast bank of the Mississippi River at river mile 55. A coal-handling facility (United Bulk
Terminal) is located directly to the west. A highway, natural gas pipelines, and utilities are locatednear the site. NWI wetland data indicated that riparian wetlands are in the batture area within theMississippi River levee and only small pockets of wetlands exist within the site landward of theMississippi River levee. Appropriate mitigation is available in the form of mitigation bank credits
and potential restoration parcels in the vicinity of the site.
Like the Mississippi River Mile 56 site, the Mississippi River Mile 55–East Bank site water
frontage of approximately 5,600 feet is insufficient for the three LNG loading docks planned for
the LNG terminal, and its corporate ownership presents difficulties in securing the property. Thereis also one residence located on the parcel and several residences adjacent to the parcel to the east.
Therefore, the land use in the vicinity of the site, including the industrial facility and the residences,
is not compatible with an LNG terminal and the buffer is insufficient. For these reasons, theMississippi River Mile 55–East Bank site is not considered preferable to the proposed site.
3.3.1.4

Cutrone Property

The Cutrone Property site is located on the east bank of the Mississippi River at river mile
46. The parcel covers approximately 160 acres of agricultural land and has been cleared of trees.
A highway, natural gas pipelines, and utilities are located in proximity to the site. NWI wetland
data indicated that riparian wetlands are in the batture area within the Mississippi River levee andonly small pockets of wetlands exist within the site landward of the Mississippi River levee.
Appropriate mitigation is available in the form of mitigation bank credits and potential restoration
parcels in the vicinity of the site.
The Cutrone Property site has approximately 3,300 feet of water frontage on a straightstretch of the Mississippi River, where deep water and sufficient natural scour would preclude theneed for dredging. However, this 3,300 feet is insufficient for the marine terminal’s requirements.
Additionally, Venture Global was unable to secure a long-term lease for the site. For these reasons,the Cutrone Property site is not considered preferable to the proposed site.
3.3.1.5

South Carlyss Site I

South Carlyss Site I is an approximately 174-acre parcel of privately owned land bordered
to the south and west by Global Drive in Calcasieu Parish. Since the property is privately owned,
the property may be available for purchase or long-term lease. The area is zoned for heavy
industrial use. An access road and utilities are located near the site. There are natural gas pipelines
3-10

in the region; however, the length of a pipeline necessary to provide feed gas would be much
longer than what is required at the proposed site and is a primary factor in not choosing this site.
South Carlyss Site I has approximately 2,900 feet of water frontage access on the east sideof the site, which is insufficient for three LNG loading docks, which is also a primary reason thissite was not selected. There is approximately 1,900 feet of water frontage on the west side of thesite along the Intracoastal Waterway, which is also insufficient for three LNG loading docks.
Additionally, the Intracoastal Waterway is relatively narrow and is an area of high ship traffic,
which would present safety concerns for LNG ship maneuverability. While the land is zoned forheavy industrial use, the size of the site is insufficient and the configuration of the property isimpractical for constructing an LNG terminal. Although residential areas located approximately
0.5 mile to the southwest of the site, this is not among the primary reasons this site was not selected.
NWI wetland data indicate that the western portion of the site is wetland and could be offset bywetland banking credits. As the size of the property is insufficient the South Carlyss Site I is notconsidered preferable to the proposed site.
3.3.1.6

South Carlyss Site II

South Carlyss Site II is an approximately 550-acre parcel of privately owned land bordered
to the north by Burton Shipyard Road in Calcasieu Parish. The area is zoned for heavy industrial
use and has an accessible waterfront. An access road and utilities are located in proximity to thesite. There are natural gas pipelines in the region; however, the length of a pipeline necessary toprovide feed gas would be much longer than what is required at the proposed site and is a primaryfactor in not choosing this site. The site is available for purchase or long-term lease.
The site has approximately 3,300 feet of water frontage, which is insufficient for three
LNG loading docks, which is also a primary reason this site was not selected. Although residential
areas located approximately 0.5 mile to the southwest of the site, this is not among the primaryreasons this site was not selected. NWI wetland data indicate that a majority of the site is wetland
and avoidance and minimization of wetland impacts would not be feasible but could be offset bywetland banking credits. As the proximity to residences and the required length of feed gas
pipeline are limiting factors, we do not consider South Carlyss Site II site preferable to the
proposed site.
Conclusion
Of the alternative terminal locations, we conclude that the proposed site (Mississippi River
Mile 55-West Bank) represents an acceptable site for the LNG terminal. The proposed site iscurrently identified as port complex and industrial in the parish’s master plan and is sufficiently
sized to allow optimal facility layout design, and has the necessary water frontage available. The
proposed site is also well separated from area residences and population centers. The proposedsite is the only alternative that satisfies all of the tier two selection criteria. From a visual impact
perspective, the LNG terminal would be consistent with existing industrial development along thisportion of the Mississippi River.

3-11

3.4

ALTERNATIVE TERMINAL CONFIGURATIONS

In considering the arrangement of plant infrastructure, Venture Global determined that a
critical element involves placing the liquefaction facilities and LNG storage tanks at the proposed
locations within the LNG terminal site to ensure compliance with federal siting and safety
requirements. Aligning the major infrastructure components in sequence according to process
flow (pretreatment, liquefaction, storage, and export) minimizes the amount of cryogenic piping
required and optimizes the site layout for process efficiency. With these considerations in mind,layout arrangements need to allow simultaneous operations involving the construction of Phase II
infrastructure contemporaneously with the operation of Phase I infrastructure.
The proposed site layout provides the adequate minimum practical distance between the
LNG loading docks and the LNG storage tanks; the administrative offices, maintenance facilities,
and the central control room are well separated from the main plant. The proposed location ofeach of the components of the Terminal is in accordance with the applicable federal safety
requirements. We did not identify any alternative configurations that would meet the regulations,codes, and guidelines while avoiding or reducing impacts when compared to those of the proposed
terminal configuration. Therefore, we conclude that the proposed general configuration of the
Terminal site is the preferred alternative.
3.5

ALTERNATIVE PIPELINE ROUTESThe proposed action for the Venture Global pipeline includes two parallel 42-inch-diameter
natural gas pipelines sharing one right-of-way corridor for the majority of their routes. We
evaluated pipeline route alternatives that could minimize or avoid impacts on environmentallysensitive resources (e.g., population centers, special use areas, waterbodies, wetlands, existing orplanned residences, specific landowner concerns).
Typically, pipeline route alternatives are one of three types: major, minor, or variation.
Major route alternatives include those that deviate from the proposed route for a significant
distance and that provide a substantially different pathway from the source area to the delivery
area. Minor route alternatives are typically shorter in length than major route alternatives and areoften identified to avoid large environmental resources, engineering constraints, and/or developed
areas. Minor route alternatives typically remain within the same general area as the proposedroute. Route deviations are typically site-specific and may allow for avoidance of certain localizedfeatures such as a residence, wetland, or cultural resource site.
For the purposes of this Project, we reviewed only the proposed route and two major route
alternatives. Due to the majority of the pipeline system being located in open water/wetlands(relatively homogenous environments), minor route alternatives and variations that generally are
utilized to avoid sensitive resources or address constructability issues were not evaluated. The
major route alternatives were sited in open water, where feasible, to avoid wetland impacts andonly cross wetlands when necessary. The proposed route and the minor route alternatives areshown in figure B-3 in appendix B.

3-12

3.5.1

Background

Initially, at the start of the pre-filing process, the planned Venture Global pipeline system
consisted of three pipelines on three routes that would supply feed gas to the Venture Global
terminal facility: the 21.2-mile-long Northwest lateral, 12.1-mile-long Southeast lateral, and 11.1mile-long Southwest lateral pipelines. During the pre-filing process, Venture Global continued toevaluate and develop its Project design. When Venture Global filed with FERC its application forthe proposed pipeline system, it had removed the Northwest lateral and Southeast lateral from theProject. It also modified and renamed the Southwest lateral pipeline route so that it now includes
two collocated pipelines identified as Southwest Lateral TETCO and Southwest Lateral TGP. The
applicants propose to construct and operate these two pipelines in one route—the Southwest
laterals pipeline route.
During the draft EIS comment period, a commenter questioned why the Applicant could
not use an existing servitude for a future pipeline that would run within the non-federal levee andnot impact the marshes to the southwest along the Southwest laterals. After researching the future
pipeline and coordinating with the USACE we determined the commenter was referring to theApplicant’s Southeast lateral alternative. The Southeast lateral route was outside of the nonfederal levee and impacted marshes and open water similar to that of the preferred route and it wasapproximately 1 mile longer and thus was not preferred.
3.5.1.1

Northwest Lateral Pipeline RouteThe 22.8-mile-long Northwest lateral pipeline route was to provide an interconnect pointwith the existing Bridgeline Holdings, L.P. pipeline near the intersection of Bayou Road andIntracoastal Road, approximately 5 miles southwest of Belle Chasse in Plaquemines Parish. The
route crossed the Intracoastal Waterway and proceeded south-southeast toward the proposed LNG
terminal site. This pipeline was collocated with an existing pipeline right-of-way from MP 13.0
to MP 20.6. The route was designed to avoid crossing the Jean Lafitte National Park and Preserve,
as well as an EPA-designated section 404(c) wetland area.
After further evaluation, Venture Global decided to remove the Northwest lateral pipelinefrom the proposed action. The Northwest lateral pipeline route would have required a technicallydifficult crossing of a levee and adjacent waterbody. This route is approximately 6 miles longer
than the proposed Southwest Lateral TGP and 11 miles longer than the Southwest Lateral TETCO.
Because the Northwest lateral pipeline would have to be coupled with another pipeline to deliver
the volume of necessary gas, this longer route would have more potential environmental impacts
than the current proposed routes. The Northwest lateral would have crossed 34 National
Hydrography Dataset waterbodies, of which 14 of the crossings would be greater than 100 feet.
Additionally, the Northwest lateral pipeline route would have crossed approximately 17.8 miles of
wetlands. As a result, once Venture Global determined that sufficient feed gas supply could beobtained using just the TGP and TETCO tie-ins, they removed the Northwest lateral pipeline fromthe proposed Project.

3-13

3.5.1.2

Southeast Lateral Pipeline Route

Venture Global also considered the 12.0-mile-long Southeast lateral pipeline that begin ata tie-in with TGP near Port Sulphur in Plaquemines Parish. The route proceeded northwest andthen interconnected with a High Point Gas Transmission pipeline before proceeding to the
proposed LNG terminal site. The route was collocated with an existing 20-inch-diameter Shell
pipeline for 2.4 miles. Based on NWI mapping, the route would cross 3.1 miles of estuarine andfreshwater emergent wetland and 3.0 miles of open water. Approximately 1,000 feet of oyster
lease areas would also be crossed.
After further analysis, as with the Northwest lateral pipeline, Venture Global decided toremove the Southeast lateral pipeline from the proposed action once they determined that sufficient
feed gas supply could be obtained by using only two existing systems (TGP and TETCO). Also,
the tie-ins to the TGP and TETCO lines could be located in proximity, which would allow for thetwo pipelines to be collocated for a majority of their routes.
Because constructing the Southeast lateral and at least one of the other alternative pipelines
would result in more overall impacts when compared to the proposed pipeline systems’ collocatedalignment, Venture Global removed the Southeast lateral pipeline from the proposed Project.
3.5.1.3

Southwest Laterals Pipeline Route

The Southwest laterals pipeline route is the proposed route for the two proposed lateralpipelines. Initially, at the beginning of the pre-filing process, the Southwest lateral was a single
pipeline connecting TETCO to the LNG terminal site. After further design, Venture Global
decided to also connect to the existing TGP system with a 15-mile lateral pipeline. Due to theproximity of the TGP and TETCO interconnects, the applicants propose to collocate these twolaterals for the majority of the route. In its FERC application, Venture Global presented thecollocated the Southwest Lateral TGP and Southwest Lateral TETCO pipelines as one proposedroute—the Southwest laterals pipeline route.
3.5.2

Southwest Laterals Route (Proposed)

As discussed above, the Southwest laterals route consists of the 11.7-mile Southwest
Lateral TETCO pipeline and the 15.0-mile Southwest Lateral TGP pipeline. Two majoralternatives for the Southwest Lateral TETCO pipeline route were analyzed. As illustrated on
figure B-3 in appendix B, the route for the Southwest Lateral TGP pipeline is collocated for theentire length of the Southwest Lateral TETCO pipeline and (for the additional 3.3 miles) traverses
homogenous, open water habitat between the TETCO and TGP interconnects. As a result, we did
not identify the need to evaluate any route alternatives for the Southwest Lateral TGP pipeline
route and consider it the preferred route for that segment of the pipeline system. The alternatives
are discussed in the following sections. A comparison of the three Southwest Lateral TETCO
pipeline route alternatives is presented in table 3.5-1.

3-14

Table 3.5-1
Summary of Selection Criteria for the Southwest Lateral TETCO Pipeline Routes
Proposed

Alternative 1

Alternative 2

Length (miles)

11.7

11.0

11.1

Wetlands (miles)

3.5

6.6

3.6

Upland (miles)

0.6

0.4

0.2

Open Water (miles)

7.6

4.0

7.3

Oyster Leases Crossed (miles)

4.4

1.1

4.4

Collocation (miles)

0.0

0.0

0.0

3.5.2.1

Southwest Lateral TETCO Pipeline – Preferred RouteThis preferred alternative is the proposed route for the Southwest Lateral TETCO pipeline.
It is 11.7 miles long and located in the coastal marshes of the Mississippi River delta. The route
begins at an interconnect point with a TETCO pipeline near Bayou St. Denis in Plaquemines
Parish. It proceeds northeast across the wetlands and open water to the proposed LNG terminalsite. No utility corridors or other linear rights-of-way running in the same general direction areavailable for collocation.
Based on NWI information shown in table 3.5-1, the proposed Southwest Lateral TETCO
pipeline route crosses approximately 3.5 miles of estuarine emergent and freshwater forested/shrub
wetland and 7.6 miles of open water. Approximately 4.4 miles of the 11.7-mile-long route crossoyster leases. Although it is slightly longer than Alternatives 1 and 2, it was selected as the
proposed route based on its preferential location in open water, where practicable, to minimize
disturbance of marsh vegetation.
3.5.2.2

Southwest Lateral TETCO Pipeline – Alternative 1

Alternative 1 is 11.0 miles long and is the shortest of the three variations for the Southwest
Lateral TETCO pipeline route. Alternative 1 crosses 6.6 miles of estuarine emergent andfreshwater forested/shrub wetlands and 4.0 miles of open water. Approximately 1.1 miles of the
11.0-mile-long route cross oyster leases. This alternative was not selected because the wetland
crossing length is nearly double that of the other alternatives and the tie-in location presented
construction challenges due to the local terrain. This alternative did not offer any advantages overthe preferred route.
3.5.2.3

Southwest Lateral TETCO Pipeline – Alternative 2

Alternative 2 is 11.1 miles long. This alternative crosses 3.6 miles of estuarine emergent
and freshwater forested/shrub wetland and 7.3 miles of open water. Similar to the preferred route,approximately 4.4 miles of Alternative 2 cross oyster leases. Unlike Alternative 1, there is anacceptable location for a tie-in point. This alternative is nearly identical to the proposed route,deviating from the preferred route only at the extreme southern end of the route. The southern
2.5 miles of this alternative route would cross two marsh islands, resulting in an additional 0.1 mileof marsh impacts and habitat/marsh fragmentation. To avoid these marsh islands, the preferredroute is approximately 0.6 mile longer, with more open water impacts. However, the preferred
3-15

route was chosen over Alternative 2 since it would result in fewer wetland impacts and less habitat
fragmentation.
3.6

ALTERNATIVE ABOVEGROUND FACILITIES SITES

Proposed aboveground facilities for the pipeline system would include six MLVs, three pig
launchers, two pig receivers, and two metering and regulation (M&R) stations. All of thesefacilities would occur within or adjacent to the Southwest lateral pipeline route right-of-way.
These facilities are small, would only impact environmentally sensitive areas to a minimal extent,
are not located near residences, and their locations are tied to the locations of the required
interconnect pipeline facilities. We did not identify any environmental concerns that require theneed to identify and evaluate alternative sites for these minor aboveground facilities, nor were any
alternatives suggested during the public scoping period or draft EIS public comment period.
Therefore, we conclude that the proposed aboveground facility sites are the preferred alternative.

3-16

4

ENVIRONMENTAL IMPACT ANALYSISThe environmental consequences of constructing and operating the LNG terminal andpipeline system would vary in duration and significance. Four levels of impact duration wereconsidered: temporary, short term, long term, and permanent. Temporary impacts generally occur
during construction with the resource returning to pre-construction condition almost immediately
afterward. Short-term impacts could continue for up to 3 years following construction. Impacts
were considered long term if the resource would require more than 3 years to recover. A permanent
impact could occur as a result of any activity that modified a resource to the extent that it would
not return to pre-construction conditions during the life of the Project, such as the construction ofan aboveground facility. We considered an impact to be significant if it would result in a
substantial adverse change in the physical environment.
In this section, we discuss the affected environment, general construction and operational
impact, and proposed mitigation for each resource. Venture Global, as part of its application,agreed to implement certain measures to reduce impacts. We evaluated the proposed mitigation
measures to determine whether additional measures are necessary to reduce impacts. These
additional measures appear as bulleted, boldfaced paragraphs in the text. We will recommend thatthese measures be included as specific conditions to any authorization that the Commission may
issue. Conclusions in this EIS are based on our analysis of the environmental impacts and thefollowing assumptions:•

Venture Global would comply with all federal laws and regulations;•the proposed facilities would be constructed as described in section 2.0 of thisdocument; and•Venture Global would implement the mitigation measures as stated in its applicationand supplemental filings to FERC.

4.1

GEOLOGY

4.1.1

Geologic Setting

The Project would be located in the Mississippi Alluvial Plain section of the Coastal Plain
physiographic province. The Coastal Plain lies along the U.S. Gulf Coast, stretching 100 to
200 miles inland and 100 to 200 miles offshore to the edge of the Continental Shelf. It comprises
an elevated sea bottom with low topographic relief and extensive marsh lands, dipping gently
seaward from its highest elevations of about 500 feet. The Mississippi River Delta portion ofMississippi Alluvial Plain consists of Quaternary-period unconsolidated sands and clays, with
scattered salt diapirs overlain by anhydrite and sulfur deposits (Hunt, 1967). Surficial deposits
underlying the LNG terminal and the first 2 miles of the pipeline system are comprised of
Holocene-epoch deposits of the natural levee complex of the Plaquemines delta lobe, Mississippi
River, which are predominantly of silt, silty clay, and clay. Surficial deposits underlying theremainder of the pipeline system are Holocene-epoch deposits composed of cyclically interbedded
interdistributary peat and clay, natural levee silt and clay, distributary sand, and delta-front andprodelta mud and clay (LGS, 2011). The Holocene-epoch deposits are underlain by Pleistocene-

4-1epoch Mississippi River alluvial deposits of mudstones with interbedded sand beds between
500 feet and 2,000 feet below mean sea level (MSL) in the Project area (Ayrer, 2013).
Venture Global performed geotechnical studies to evaluate subsurface soil andgroundwater conditions within the proposed terminal site and marine facilities:•

86 geotechnical borings, ranging in depth from 60 to 200 feet;•

10 cone penetration tests, ranging in depth from 142 to 148 feet; and•two seismic cone penetration tests, each to a depth of 143 feet.

The investigations at the proposed terminal indicated that the materials withinapproximately 300 feet of the surface consist of three distinct strata:•

stratum 1: Cohesive soils consisting of clay, silt, and silty clay generally extend fromthe surface to a depth of about 150 feet below existing grade.

•stratum 2: Natural granular soils consisting of silty sand and clayey sand occur below
Stratum 1 to a depth of about 175 feet below existing grade.

•stratum 3: Cohesive soils consisting of clays and sandy clays occur below Stratum 2
to a depth of about 300 feet below existing grade, the maximum depth explored in thisarea.

Groundwater was at or very near the surface in the geotechnical borings. The potential for
corrosion of buried steel ranged from high to very high, based on resistivity and chloride ion
concentrations. The potential for degradation of concrete, based on sulfate ion concentrations, wasgenerally mild to moderate across the site (Fugro, 2016a).
A 2016 topographic survey undertaken by Venture Global indicated elevations at the LNG
terminal site range from -2 feet to -5 feet NAVD88 south of SH 23, and from -2 feet to 2 feet
NAVD88 between SH 23 and the toe of the federal flood protection levee. The crest of the flood
protection levee had a crest of 14 feet NAVD88 adjacent to the proposed terminal site. The nonfederal flood protection levee has an elevation of 9.5 feet NAVD88 at the pipeline system crossing.
The geotechnical investigation for the horizontal directional drill (HDD) between the LNG
terminal site and non-federal levee will be completed by Venture Global in 2019. The results ofthis geotechnical investigation would identify the likelihood of success, quantify the potential forhydraulic fracture, and include measures to minimize risk of HDD complications.
4.1.2

Mineral Resources

No non-fuel mineral resources occur within 0.25 mile of the Project. The nearest non-fuelmineral resources are two active surface river silt borrow pits, both operated by Woodland Borrow
Pits, LLC, and which are located approximately 3.0 miles southeast and 5.5 miles northwest of the
proposed terminal. No borrow pits were identified along the pipeline system. The Lake Hermitage
Dome sulphur mine is located 3.2 miles south of the LNG terminal, but this mine is not currently
4-2

in production (USGS, 2017). The outer edge of the Lake Hermitage salt dome is located about
0.9 mile east of the pipeline system (at MP 7.5 of the Southwest Lateral TETCO and MP 10.8 of
the Southwest Lateral TGP). An unnamed geothermal prospect is located 3,800 feet south of the
proposed Southwest Lateral TETCO temporary meter station at MP 0.0 (USGS, 2017).
Oil and gas production is prevalent throughout Louisiana and the surrounding region. The
proposed terminal would be proximate to various oil and gas fields, and the Lake Hermitage,
Manilla Village Southeast, Saturday Island, and Bay Batiste oil and gas fields underlie the pipeline
system (LDNR, 2017a) (figure B-4, appendix B). Active and producing wells drilled in thesefields have depths ranging from 11,900 to 19,000 feet. Based on a review of the LDNR’s Strategic
Online Natural Resources Information System (SONRIS), there are two plugged and abandoned
dry hole wells within the proposed terminal site and three plugged and abandoned former oil andgas wells within the pipeline system construction workspace (LDNR, 2017a). In addition to theaforementioned wells, there are 18 additional plugged and abandoned wells, one permitted well,and two producing wells (currently shut-in for future utility) within 0.25 mile of the Projectworkspace (LDNR, 2017a) (figure B-5, appendix B). To afford the owner(s) the opportunity tohave a representative on-site during construction activities, we recommend that:•

Gator Express Pipeline should provide 72 hours’ notice to the owner(s) of
producing oil and gas wells located within 0.25 mile from the pipeline workspacein order to allow the owner’s representative to be on-site during construction
activities.

The pipeline system crosses state mineral lease SL 707 from MP 10.0 to 11.8 on theSouthwest Lateral TGP and lease SL 21423 in the workspaces and meter site immediately
surrounding the Southwest Lateral TETCO meter station platform. Venture Global has indicatedthey would negotiate permanent easement rights and any necessary access restrictions with thelease owners.
4.1.3

Geologic Hazards

Geologic hazards are physical conditions, naturally occurring or induced, that can result indamage to land and structures or injury to people. Such hazards typically include seismicity (e.g.,
earthquakes, surface faults, soil liquefaction, and tsunamis), subsidence, shoreline erosion, andlandslides. Conditions necessary for the development of other geologic hazards, including
avalanches, volcanism, and karst terrain, are not present near the LNG terminal or pipeline
facilities. In general, the potential for these geologic hazards to markedly affect construction oroperation of the proposed terminal and pipeline facilities is low. Geologic hazards present at theterminal facility will be discussed in detail in section 4.12. As such, the following geologic
hazards, sections 4.1.3.1 through 4.1.3.4, discuss only the pipeline facilities.
4.1.3.1 Seismicity
The majority of significant seismic events are interplate earthquakes associated withmovement between two tectonic plates, either laterally along a transform fault where plates are
sliding past each other (such as in California) and rift separation zones, or vertically as one plateis subducted below another (such as in Alaska) where tectonic plates are converging (such as the

4-3New Madrid fault across the Missouri/Tennessee border). Relative to these highly active tectonic
regions, Louisiana and the surrounding areas are seismically quiet. Seismic events may also be
associated with volcanic activity, which is not present in the southeastern area of the continent,
and induced events, such as significant injection of fluids (potentially associated with recent
Oklahoma earthquakes) and initial filling of major reservoirs (such as Toledo Bend). Historically,
induced seismicity resulted in low-magnitude events.
The 2014 U.S. Geological Survey (USGS) Hazard Mapping Program probabilistic seismic
hazard analyses for peak ground acceleration (PGA) expected at the Project, expressed as a factor
of gravity (g), indicates a 10 percent probability of exceedance is 0.0184g within a 50-year period
and a 2-percent probability of exceedance is 0.0434g within a 50-year period due to seismic events(USGS, 2014). While the probabilistic PGA values are for rock, and the clay, silt, and sandunderlying the proposed terminal site would amplify short-period PGAs by a factor of 2, PGAs ofless than 0.039g would result in only light perceived shaking and no potential damage, and PGAs
of up to 0.092 would result in only moderate perceived shaking and very light potential damage(USGS, 2006). The pipelines would be designed for earthquake ground motions, and it is unlikely
they would be affected by the design earthquake(s).
4.1.3.2 Shoreline Erosion and Landslides
The flat topography associated with the pipeline system routes, which remains consistent
between the open water and terrestrial transitions, would not be subject to landslide hazards.
During construction and operation of the pipeline system, Venture Global would implement
measures outlined in its Project-specific Plan and Procedures to minimize shoreline erosion andoffsite transport of soil.
4.1.3.3 Land Subsidence and Sea Level Rise
Common causes of ground subsidence include the presence of karst terrain, undergroundmining, and substantial groundwater or fluid withdrawal. Underground mining poses risks toengineered structures due to the potential for the overlying strata to collapse into the voids formedby the extraction of minerals. While Louisiana and parts of adjoining states are underlain byevaporite rocks at various depths up to 7,000 feet, there are no karst or pseudokarst features
proximal to the pipeline facilities (Weary and Doctor, 2014). The closest mining activities
occurred at the Lake Hermitage Dome sulphur mine, located east of the pipeline system (USGS,
2017). Therefore, subsidence associated with these activities are not anticipated. Subsidence
could occur near the pipeline facilities due to oil and gas extraction. As discussed above, thesefacilities would be within active oil and gas fields. However, if subsidence does occur, the impacts
on the pipeline system are expected to be minor.
4.1.3.4 Flooding/Storm Damage/Tsunamis
FEMA produces flood insurance rate maps for municipalities across the nation. The maps
are divided into zones with assigned probabilities of experiencing a flood event during any 1-year
period. The 100-year flood represents a river channel water level that, based on an analysis of thehistoric record, is likely to be equaled or exceeded every 100 years, meaning that there is a
1 percent chance that the water level would be equaled or exceeded in any individual year during

4-4

a flood event. The lowest mapped probability of flooding is 0.2 percent, which would have an
average flooding recurrence interval of 500 years. Venture Global would raise the elevation of its
metering stations to the 500-year flood level to avoid minor flooding.
Venture Global conducted a tsunami hazard evaluation to assess the potential for a tsunami
or a seiche (standing wave) to impact the LNG terminal. Due to the low probability of strong
seismic events in the Gulf of Mexico, the tsunami hazard associated with seismic activity is low.
The primary tsunami hazard for the pipeline system area is associated with submarine landslides.
However, occurrences are rare (over 1,000 years between significant events) and estimated wave
height from modeled events (less than 13 feet for a 500-year return period) are less than predicted
storm surges (Fugro, 2016b). The tsunami hazard is inherently considered because the pipeline
system and its ancillary facilities are designed for storm surge and the maximum estimated run-up
values from potential tsunamis are substantially less than those from storm surge.
4.1.4

Blasting

Blasting is not expected to be necessary during construction. The Project areas at the LNG
terminal site and pipeline system are underlain by unconsolidated sediments to depths greater thanthe excavation depth needed to construct the proposed facilities. In the event that Venture Global
becomes aware of the need for blasting, Venture Global would prepare a Project-specific blastingplan in accordance with state and local regulations for the review and written approval of the
Director of the Office of Energy Projects prior to conducting any blasting activities.
4.1.5

Paleontology

The geologic materials in the Project area are generally young (Holocene to latePleistocene) and do not have a high potential to contain significant paleontological resources. The
LNG terminal and pipeline system facilities would not impact any older underlying geologic
formations or the fossils, if any, lay within them. The nearest fossiliferous strata, the Sicily Island
Loess and the Peoria Loess, which contain land and freshwater gastropods, freshwater pelecypods,
and vertebrate bones, outcrops over 100 miles northwest of the Project area (LGS, 2008).
Therefore, construction and operation of the LNG terminal would not likely affect paleontologicalresources.
4.1.6

Design and Construction of the LNG Terminal and Pipeline System

Discussion on issues such as site grading, foundations, and facility structure and design,
including wind design and seismic design, are addressed in section 4.12.
4.1.7

General Impacts and Mitigation

The LNG terminal and associated marine facilities would impact 728.7 acres forconstruction and 636.5 acres during operation. Existing ground elevations at the terminal site vary
between -2 and -5 feet NAVD88. The terminal site would be leveled to an elevation of -2 feet
NAVD88 by grading and with the import of fill materials to provide a level platform with sufficientspace to safely execute the work. As a result, the LNG terminal would permanently alter the
existing geologic conditions at the site. Final grade surfacing and landscape would consist of
gravel, asphalt, concrete, topsoil, and grass surface areas. Venture Global would drive precast
4-5concrete piles, steel piles, and/or cast-in-place concrete to support key onshore LNG terminal
components and structures. The actual types of piles employed, number, and location of piles
would be determined during final design stages following a pile test program. We would anticipate
installation of over 2,000 steel and concrete piles to a depth of between elevations -80 and -220
feet NAVD88 but no greater than -240 feet NAVD88. For the marine components of the LNG
terminal, Venture Global would install a combination of 72-inch-diameter, 66-inch-diameter, 48inch-diameter, 36-inch-diameter, and 24-inch-diameter steel piles for the LNG loading docks,
MOF, and temporary berthing structures (table 4.6-3). The impact on the existing geologic
conditions would be permanent and minor, dependent on the final number and location of piles.
Although there are oil and gas fields under the LNG terminal, active and producing wells
drilled in these fields have depths ranging from 11,900 to 19,000 feet. As stated in section 4.1.2,
the area has abandoned wells, plugged wells, and producing wells within 0.25 miles of the pipeline
system and LNG terminal workspaces. Despite the historic presence of oil and gas wells in thearea, we do not anticipate that there would be impacts on mineral resources in the Project area.
Based on the above discussion, and in consideration of Venture Global’s proposed
mitigation and design criteria, and our recommendation, the pipeline system would not
significantly affect or be affected by geological conditions in the area.
4.2

SOILS

4.2.1

Existing Soil Resources

The soils affected by the Project were identified and assessed using various data sources,
including digital soils data (e.g., the Soil Survey Geographic [SSURGO] database), published soil
surveys for Plaquemines Parish (USDA NRCS, 2000), and additional information about soils andassociated land uses from the Official Soil Series Descriptions (Soil Survey Staff, 2016a). The
SSURGO database is a digital version of the original county soil surveys developed by the U.S.
Department of Agriculture (USDA) Natural Resources Conservation Service (NRCS) for use withgeographic information systems (GIS). It provides the most detailed level of soils information for
natural resource planning and management. The attribute data within the SSURGO databaseprovides the proportionate extent of the component soils and their properties for each soil map
unit.
4.2.1.1 Soil Types and Limitations
The soils at the terminal site include Cancienne silt loams, Cancienne silty clay loams,
Carville, Cancienne, and Schriever soils, Harahan clays, and Westwego clays. These soils haveslopes ranging from 0 to 1 percent and do not contain bedrock or other root restrictive layers within
80 inches of the surface. Cancienne silt loams and Cancienne silty clay loams consist of somewhat
poorly drained mineral rich soils that formed in silty alluvium on alluvial plains or natural levees.
Carville, Cancienne, and Schriever soils consist of somewhat poorly drained mineral rich soil. The
Carville component occurs in loamy alluvium on delta plains or natural levees. The Cancienne
component occurs in silty alluvium on delta plains or natural levees. The Schriever component
occurs on clayey alluvium on backswamps or delta plains. Harahan clays and Westwego clays
consist of poorly drained mineral rich soils that formed in nonfluid over fluid clayey alluvium on

4-6

backswamps or delta plains. In addition to the five soil map units, the SSURGO database shows
portions of the terminal site as “water.” Soil characteristics are not applicable for the water areas,
but the acreages are included in impact totals. The terminal site has been extensively ditched anddrained, thereby likely altering the natural soil characteristics.
Soils types mapped within the pipeline system footprint consist of Bellpass muck, Clovelly
muck, Cancienne silty clay loam, Gentilly muck, Harahan clay, Lafitte muck, Schriever clay, andWestwego clay. Three of the five soil types (Cancienne silty clay loam, Harahan clay, andWestwego clay) found at the terminal site are also found within the construction workspace of thepipeline system. Bellpass muck is a very poorly drained organic soil found in decomposed organic
material overlying fluid clayey backswamp deposits on delta plains and marshes. Clovelly muckis a very poorly drained organic and slightly saline soil found in herbaceous organic material oververy fluid clayey alluvium on coastal plains and marshes. Gentilly muck is a very poorly drainedmineral soil found in thin herbaceous organic material over semifluid clayey over consolidated
clayey alluvium on marshes. Lafitte muck is an organic, very poorly drained, and slightly saline
soil found in herbaceous organic material on delta plains and marshes. Schriever clay consists ofpoorly drained mineral soils protected from most flooding by earthen levees, found in clayey
alluvium on backswamps and delta plains. In addition to the eight soil map units, the SSURGO
database shows portions of the pipeline system as “water.” Soil characteristics are not applicablefor these areas, but the acreages are included in impact totals.
The soils within the proposed terminal site and pipeline system were evaluated to identify
prime farmland and major soil characteristics that could affect construction or increase thepotential for adverse construction-related soil impacts. The soil characteristics evaluated include
erosion potential, the potential for compaction, and revegetation concerns. Table 4.2-1
summarizes the amount of prime farmland and soil characteristics within each component of the
Project.
4.2.1.2 Prime Farmland Soils
The USDA defines prime farmland as “land that has the best combination of physical andchemical characteristics for producing food, feed fiber, and oilseed crops” (Soil Science Division
Staff, 2017). The USDA advised that, since the Project would not receive federal funding, theProject is exempt from the rules and regulations of the Farmland Protection Policy Act – subtitle
I of title XV, section 1539-1549. This designation includes cultivated land, pasture, woodland, orother lands that are either used for food or fiber crops, or are available for these uses. Urbanized
land, built-up land, and open water cannot be designated as prime farmland. Prime farmland
typically contains few or no rocks, is permeable to water and air, is not excessively erodible orsaturated with water for long periods, and is not subject to frequent, prolonged flooding during thegrowing season. Soils that do not meet the above criteria may be considered prime farmland if thelimiting factor is mitigated (e.g., by draining or irrigating). Impacts on prime farmland are ofgeneral concern because of the potential for decreases in long-term agricultural productivity.

4-7

Table 4.2-1
Characteristics of Soils Associated with the Terminal Site and Pipeline System
Facility

Prime Farmlanda

Hydrica

Compaction Proneb

Terminal Site, Water & Land-based Marine
Facilities, and Adjacent Workspace (does notinclude 77.0 acres of undisturbed area within
the terminal site)d

146.4

457.6

625.8

Terminal Site Subtotale

146.4

457.6

625.8

Southwest Lateral TETCO and Southwest
Lateral TGP(Phase I)

6.4

80.4

7.8

Southwest Lateral TETCO (Phase II)f

0.1

17.6

0.1

Pipeline System Subtotal

6.5

98.0

7.9

PROJECT TOTAL

152.9

555.6

633.7

Terminal Sitec

Pipeline System

Sources: Soil Survey Staff, 2016a, 2016b; USDA NRCS, 2000a
As designated by the NRCS.
b
Includes soils in somewhat poor to very poor drainage classes with surface textures of sandy clay loam and finer.
c
Terminal workspace includes areas along the federal levee where workspace for the crossing of the levee would be required.
d
Temporary terminal workspace includes areas located along SH 23 currently used for utilities.
e
Does not include undisturbed land (77.0 acres) at the terminal site.
fOverlapping workspaces are included in the Southwest Lateral TETCO totals.

4-8Two of the soils at the terminal site are designated as prime farmland: Cancienne silt loam,
0 to 1 percent slopes; and Cancienne silty clay loam, 0 to 1 percent slopes. These soils make up
approximately 146.4 acres (20.1 percent) of the soils affected at the terminal site. The portion of
the terminal site south of SH 23 was historically used for sugar cane production and has been
extensively ditched and drained. Most of the terminal site is currently fallow agricultural land andused for cattle pasture.
Two of the eight soils along the pipeline system are designated as prime farmland:
Cancienne silty clay loam, 0 to 1 percent slopes; and Schriever clay, 0 to 1 percent slopes. Thesesoils make up approximately 6.5 acres (0.7 percent) of the soils that would be affected by pipeline
system construction and are considered prime farmland under all conditions. None of the soils
represent unique farmland or farmland of statewide importance.
4.2.1.3 Hydric Soils
Hydric soils are defined as “soils that formed under conditions of saturation, flooding, or
ponding long enough during the growing season to develop anaerobic conditions in the upper part”(Soil Survey Staff, 1994). Soils that are artificially drained or protected from flooding (e.g., bylevees) are still considered hydric if the soil in its undisturbed state would meet the definition of a
hydric soil. Generally, hydric soils are those soils that are classified as somewhat poorly drained,
poorly drained, or very poorly drained.
Due to extended periods of saturation, hydric soils can be prone to compaction and rutting,particularly during the operation of heavy equipment. Compaction can also occur in poorly
drained, fine-textured, non-hydric soils when the surface layers are wet. In addition, highgroundwater levels associated with hydric soils can create a buoyancy hazard for buried pipelines.
Three of the five soil map units at the terminal site are classified as hydric soils: Carville,
Cancienne, and Schriever soils; Harahan clay; and Westwego clay. These soils make up
approximately 62.8 percent of the soils affected at the terminal site.
Seven of the eight soils at the pipeline system are classified as hydric soil. The only nonhydric soil is Cancienne silty clay loam, 0 to 1 percent slopes. This soil makes up approximately
98.0 acres (10.4 percent) of the soils that would be affected by construction of the pipeline system.
4.2.1.4 Compaction Potential
Soil compaction modifies the structure and reduces the porosity and moisture-holding
capacity of soils. Construction equipment traveling over wet soils could disrupt soil structure,
reduce pore space, increase runoff potential, and cause rutting. The degree of compaction depends
on moisture content and soil texture. Fine-textured soils with poor internal drainage that are moist
or saturated are the most susceptible to compaction and rutting.
All five soils at the terminal site are prone to compaction. These soils make up
approximately 625.8 acres (98.3 percent) of the soils affected at the terminal site. The remaining
1.7 percent is associated with the marine facility within the Mississippi River.

4-9

Four of the eight soils along the pipeline system are prone to compaction: Cancienne silty
clay loam, 0 to 1 percent slopes; Harahan clay; Schriever clay, 0 to 1 percent slopes; and Westwego
clay. These soils make up approximately 7.9 acres (0.8 percent) of the soils that would be affectedby construction of the pipeline system.
4.2.1.5 Erosion
Highly erodible soils at the terminal site and within the construction workspace for the
pipeline system were identified based on SSURGO database parameters that are directly related tothe susceptibility of a soil to erosion by water or wind. The USDA has developed separate
groupings for water and wind erosion because management and construction mitigation techniques
used to minimize erosion hazards are different in each case.
For water erosion, attribute data were used that describe the land capability and slope classof each map unit. All map units with a land capability subclass designation of 4e through 8e, andmap units with an average slope class greater than or equal to 9 percent, were identified assusceptible to water erosion. Wind erodibility was assessed based on wind erodibility group(WEG) designations. A WEG is a grouping of soils that have similar surface layer properties that
affect their resistance to soil blowing. These properties include texture, organic matter content,
and aggregate stability. Soils in WEG 1 and WEG 2 include sandy-textured soils with poor
aggregation, which are particularly susceptible to wind erosion.
No soils at the terminal site or pipeline system are susceptible to high-water or winderosion.
4.2.1.6 Revegetation Potential
Successful restoration and revegetation are important for maintaining soil productivity andprotecting the underlying soil from potential damage, such as erosion. Droughty soils, whichcharacteristically have a coarse surface texture and are excessively drained or somewhat
excessively drained, may prove difficult to revegetate. The drier soils have less water to aid in thegermination and establishment of new vegetation. The coarser textured soils also have a lower
water holding capacity following precipitation, which could result in moisture deficiencies in theroot zone, thereby creating unfavorable conditions for many plants. In addition, steep slopes canmake the establishment of vegetation difficult. SSURGO data indicates that no soils at the terminalsite or the pipeline system have issues with revegetation.
4.2.1.7 Stony/Rocky Soils
Soils with significant quantities of stones in the surface layer were identified by querying
the SSURGO database. Stones may occur within each component soil series that have either: (1)a cobbley, stony, bouldery, shaly, very gravelly, or extremely gravelly modifier to the texturalclass of the surface layer; or (2) a surface layer for which more than 5 percent of total weight ismade up of stones larger than 3 inches.
No soils at the terminal site or the pipeline system overlay stony/rocky soils.

4-10

4.2.1.8 Shallow Bedrock
Soils potentially underlain by shallow bedrock were identified by querying the SSURGO
database for component soil series that have a bedrock contact listed at 60 inches or less in depth.
The Project is not underlain by any such soils exhibiting shallow bedrock.
4.2.2

Soil Contamination

During construction, some potential exists for spills of hazardous materials, such as
hydraulic fluid and diesel fuel for vehicles and equipment. In addition, stormwater runoff fromthe construction workspace could carry unconfined debris or other materials. To address theseconcerns, Venture Global would adhere to the Project-specific SPCC Plan and SWPPP for
construction activities, in accordance with applicable regulations and permit requirements.
4.2.3

General Impacts and Mitigation

4.2.3.1 LNG Terminal
The soil characteristics listed in table 4.2-1 would be of most concern in circumstanceswhere temporary land disturbance occurs and restoration to pre-construction conditions isrequired. At the terminal site, initial site preparation would require significant soil modifications
to soil properties and topography. These modifications would include soil stabilization throughthe addition of material such as cement or lime, deposition of fill to achieve a ground elevation
increase across the majority of the terminal site, and/or the installation of a surface layer toaggregate material to provide a safe and level work surface.
Given the modifications described above, drainage issues associated with hydric soils anderosion issues would not occur. With respect to soil compaction, readily compactible soils arefavored around facility foundations and piles.
During construction disturbance, when surface topography is altered and subsurface soil
may be left exposed, heightened erosion and sedimentation concerns are associated with potential
stormwater runoff. The Project would address these concerns by adherence to the Project-specificPlan and Procedures, Louisiana Pollutant Discharge Elimination System (LPDES) Stormwater
Construction General Permit requirements, and an SWPPP for construction activities at theterminal site.
To reduce impacts of construction on soils, Venture Global would implement measures
outlined in its Project-specific Plan and Procedures, which include measures to control erosion andsedimentation during construction and to ensure proper restoration of disturbed areas following
construction. Relevant mitigation measures specified in the Project-specific Plan and Procedures
include:•sediment barriers would be installed before ground-disturbing activities are initiated toprevent sediment flow from construction areas into waterbodies, wetlands, and roads;•

temporary erosion control measures (e.g., temporary slope breakers and mulch) would
be installed during construction;
4-11

•

permanent erosion control measures would be maintained following construction;•

erosion control fabric would be placed at dike and drainage swale outlets and adjacent
to roads and waterbodies, as necessary;•

dust suppression, via water application, would be used, as necessary, to control andminimize wind erosion;•

during periods of heavy rainfall or unusual soil saturation, rutting, and compaction
would be avoided, to the extent practicable, by utilizing low-ground weight
construction equipment and/or timber mats; and•an EI would monitor field conditions daily to ensure that the erosion and sedimentation
control measures are functional and adequate until the construction workspace is fullystabilized.

The majority of soil disturbed within the terminal site and associated facilities andworkspaces would be permanently impacted from the construction of paved or gravel plant roads,
or occupied by aboveground facilities and workspaces. The permanent footprint totals 625.8 acresof land and 10.7 acres within the Mississippi River. The remaining 92.2 acres within the terminalsite and associated facilities and workspaces consist of temporary workspaces.
To prevent contamination of soils within nearby wetlands, waterbodies, and other sensitive
resources during construction, Venture Global has stated that it would implement its Spill
Prevention Plan during construction and its SPCC Plan during operation of the LNG terminal.
These plans would outline potential sources of releases at the site, measures to prevent a release to
the environment, and initial responses in the event of a spill.
Given the impact minimization and mitigation measures described above, impacts on soils
due to construction and operation of the terminal site would be permanent, but minor.
4.2.3.2 Pipeline System
As shown in table 4.2-1, construction and operation of the pipeline system would affectprime farmland, hydric, and compaction prone soils.
Pipeline construction activities that have the potential to affect soil structure andrevegetation potential include clearing (brush hogging or mowing), topsoil removal, grading,trenching, backfilling, and restoration. Potential soil impacts include: loss to soil due to water orwind erosion, especially on steep slopes (greater than 9 percent) or fine sandy soils; reduction ofsoil quality by mixing topsoil with subsoil; soil compaction due to traffic by heavy construction
equipment; and disruption of surface and subsurface drainage systems. Most construction
disturbance within pipeline rights-of-way is considered temporary in nature, and the generalapproach is to restore pre-construction conditions, to the extent practicable. However, the presenceof certain soil conditions (e.g., droughty soils) can compromise vegetation.
Three of the soil types mapped within the pipeline system construction workspace are also
represented at the terminal site. Thus, the same soil characteristics (hydric soils, compaction, and4-12

water erosion) that were discussed in section 4.2.1 also bear consideration for construction of thepipeline system. However, given the temporary nature of disturbance and the intent to restore topre-construction conditions, to the extent practicable, these soil characteristics have greater
relevance for the selection of construction techniques and mitigation measures for the pipeline
system than for the LNG terminal.
As described in section 2.5.5.4 and appendix C, Venture Global has developed a Projectspecific Plan that includes some modifications to our Plan. Those proposed modifications that aresubstantive and for which we have determined Venture Global provided adequate justification arelisted in appendix C, table 1. One of those proposed modifications is to Section IV.F.3.c of ourPlan that requires the installation of sediment barriers along the edge of work areas where wetlands
or waterbodies are adjacent to and downslope to prevent sediment flow into the wetland or
waterbody. Venture Global states that although the soils in the Project area are of a type that tend
to slough when stacked, the terrain has limited elevation changes and yields few downslopes.
Venture Global contends that the workspace width (130 feet) is sufficient to limit sedimentmigration laterally off the construction right-of-way. As a result, Venture Global proposes to only
sediment barriers, as practicable, at upland and wetland/waterbody interfaces within theconstruction right-of-way.
FERC accepts that this proposed alternative measure will achieve a comparable level of
mitigation to the FERC Plan that requires the installation of these sediment barriers as necessary
to prevent sediment flow into a wetland or waterbody. In the Project-specific Plan, Venture Global
has committed that its EIs will ensure erosion control devices are installed to prevent sedimentflow into sensitive environmental areas, such as wetlands.
Soil impacts would be minimized through the implementation of the measures outlined in
the Project-specific Plan and Procedures. Further, Venture Global would implement its SPCC
Plan to reduce potential impacts on soils from spills of hazardous materials used during
construction and operation. We have reviewed the SPCC Plan and the Plan and Procedures andfound them to be acceptable. Given the impact minimization measures described in these plans,
impacts on soils due to construction and operation of the pipeline system would be permanent, but
minor.
4.3

WATER RESOURCES

The Project would be located in the Mississippi Alluvial Plain Deltaic Coastal Marshes andBarrier Islands Ecoregion (Daigle, 2006). In general, this ecoregion is a flat deltaic and coastal
plain with fresh water and saline marshes, rivers, lakes, bayous, tidal channels, canals, and barrier
islands. The geology of this area generally consists of alluvial, deltaic, interdeltaic, coastal, andshallow marine sediments of sand, silt, and clay of comparatively high organic content, including
peat deposits in places. The sand and clay layers are stratified, with the sand layers bearing waterand the clay acting as confining layers.
4.3.1

Groundwater Resources

Groundwater within Plaquemines Parish primarily consists of salt water with various
concentrations of dissolved salts (Ayrer, 2013; USGS, 2013a). Limited freshwater (water with a4-13

chloride concentration of 250 milligrams per liter or less) may be available in the shallow aquifer
system that contains point bar deposits and natural levees adjacent to the Mississippi River andthat are recharged by the Mississippi River (USGS, 2013a). The deep aquifer system is anextension of the New Orleans aquifer system, which extends from Iberville Parish east to theeastern portion of Orleans Parish and south the to the Gulf of Mexico (Ayrer, 2013; USGS, 1989).
Point bar deposits in the shallow aquifer system, which may contain limited amounts offresh water, consist of sand deposits that are hydraulically connected to the Mississippi River andsubject to infiltration of water from the river. There are no known wells screened in these deposits
within Plaquemines Parish from the state well registration records; however, wells drilled to 50 to
100 feet deep in point bar deposits in neighboring Orleans Parish have yielded small to moderatequantities of water (USGS, 2013a). In Orleans Parish, water from the point bar deposits is of poor
quality due to high iron concentration and very high hardness (USGS, 2013a), both of which cancontribute to problems with water collection and distribution systems.
As stated above, the deep aquifers beneath Plaquemines Parish are an extension of the New
Orleans aquifer system. The New Orleans aquifer system includes four major aquifers: Gramercy
aquifer; Norco aquifer; Gonzales-New Orleans aquifer; and the “1,200-foot” aquifer. Theseaquifers were formed by deposition of alternating beds of sands and clays that both thicken anddip southward (Ayrer, 2013). The alternating beds of sand function as aquifers, and the beds ofclay are confining units between aquifers. The confining layers between the surficial deposits andthe underlying aquifers gradually thicken southward, and the underlying aquifers become moredeeply buried (USGS, 1989).
According to USGS Water Resources Technical Report No. 46, the Gramercy and Norco
aquifers pinch out to the west of the terminal site. In the Project vicinity, the Gramercy aquifer islocated approximately 200 to 300 feet below the surface (USGS, 2013a).
Water within the Gramercy and Norco aquifers underlying Plaquemines Parish ismoderately saline, and withdrawal from the Gramercy aquifer accounts for less than 1 percent of
the total withdrawals in the parish (USGS, 2013a). Limited transmissivity data suggest that theGramercy aquifer, Norco aquifer, Gonzales-New Orleans aquifer, and the “1,200-foot” aquifer
will each have a transmissivity values greater than 10,000 square feet per day at the terminal site.
Aquifers with similar transmissivity values can typically yield greater than 300 gallons per minutefrom properly constructed supply wells.
4.3.1.1 Sole Source Aquifers
Sole source aquifers are designated by the EPA as aquifers that supply 50 percent or moreof the drinking water for an area, and for which there are no other reasonably available alternative
sources should the aquifer become contaminated (EPA, 2017a). There are no designated solesource aquifers in Plaquemines Parish. The closest sole source aquifers are the Southern Hills
Regional aquifer and the Chicot aquifer. The Southern Hills Regional aquifer system is located ineastern Louisiana and south Mississippi, with the southern edge of the aquifer system located morethan 50 miles from the Project. The Chicot aquifer is located in southwest Louisiana with theeastern edge more than 100 miles west of the Project area (EPA, 2017a).

4-14

4.3.1.2 Water Supply Wells
Louisiana’s Wellhead Protection Program is a component of the LDEQ’s Drinking Water
Protection Program and is designed to protect the quality of public drinking water supplies
obtained from community water wells. The LDEQ delineates a drinking water protection areaaround each well, ranging from a 1,000-foot radius to a 1-mile radius, depending on well screen
depth, construction date, or aquifer sources. The Project does not traverse any drinking water
protection areas for groundwater wells.
A review of the publicly available well location data available in SONRIS (LDNR, 2017b)
indicated that there are no active public water supply wells within 1 mile of the Project. There is
one private well documented within 1 mile of the Project. The well is located approximately 1 mileeast of the terminal site on the east bank of the Mississippi River. According to the data available
in SONRIS (LDNR, 2017b), the well was drilled to a depth of 30 feet and is listed as an active
domestic well. Due to the distance from the terminal site, and the fact that the shallow well(approximately 30 feet) is on the opposite bank of the Mississippi River, no short-term or longterm impacts are anticipated on groundwater in the vicinity of the well.
No wells are documented within 1 mile of the pipeline system. There are three wells
approximately 1.5 miles east of the pipeline system near the south end of Lake Hermitage Road.
These wells, two domestic supply wells and one commercial public supply well, are reported to be
between 410 feet and 450 feet deep (LDNR, 2017b). Two of these wells are reported to be in theGramercy aquifer.
In addition to the publicly available well data, Venture Global identified an artesian wellwithin the eastern workspace for the terminal. This well would be capped and abandoned during
construction.
4.3.1.3 Contaminated Groundwater
The LDEQ runs an Aquifer Sampling and Assessment Program to monitor the quality ofgroundwater produced in Louisiana’s major freshwater aquifers. The program samples about 200
wells across 14 aquifers every 3 years and presents the results in a triennial report. The aquifers
in Plaquemines Parish are not included in the program, likely because the aquifers in Plaquemines
Parish are primarily saline.
Under the Federal Safe Drinking Water Act, the EPA has established the Primary
Maximum Contaminant Level (MCL) for pollutants that may pose a health risk in public drinking
water. Secondary MCLs have also been set by the EPA, but are defined as non-enforceable
guidelines for taste, odor, or appearance. As stated above, groundwater is not a significant sourceof drinking water in Plaquemines Parish, and the aquifers in Plaquemines Parish are not part of the
LDEQ Aquifer Sampling and Assessment Program. Therefore, data regarding aquifer
contamination is limited.
Prior land use activities at the terminal site is understood to be agricultural in nature.
Venture Global conducted a Phase I Environmental Site Assessment at the terminal site that
included a review of federal, state, and local databases. No potential sources of groundwatercontamination were identified at or near the terminal site, and no known groundwater
4-15

contamination was identified at or near the terminal site. Additionally, Venture Global conducted
86 geotechnical borings at the terminal site. Although samples for contaminant analysis were notcollected, Venture Global did not observe any physical evidence (e.g., odor, sheen) of
contamination while conducting the geotechnical study.
4.3.1.4 Groundwater Impacts and Mitigation
Excavation
The majority of the construction activities associated with the LNG terminal and pipeline
system would involve shallow, temporary, and localized excavation, with the exception of concrete
and/or steel piles at the LNG terminal. Shallow aquifers could sustain minor, indirect impacts
from changes in overland water flow and recharge caused by clearing and grading of the work
areas. In addition, near-surface soil compaction caused by heavy construction vehicles could
reduce the soil’s ability to absorb water. During construction of the Project, local water table
elevation could be affected by excavation and backfill. In areas where groundwater is near thesurface, excavation may intersect the water table in low-lying areas.
Venture Global anticipates that surface water would be appropriated from the adjacentdrainage canal to be utilized for hydrostatic testing of the LNG storage tanks, piping, and non LNG
tanks. A new well or wells may be drilled at the LNG terminal site to supply water for use during
operation of the LNG terminal. If groundwater wells are to be installed, Venture Global anticipatesthat the Gramercy aquifer, Norco aquifer, Gonzales-New Orleans aquifer, and/or the “1,200-foot”
aquifer could yield sufficient quantities of water to satisfy the LNG terminal’s needs without
adverse impact. Supply wells would penetrate the targeted aquifer, and one or more wells would
produce up to a total of 600 gallons per minute for treatment and use. These aquifers would not
be adversely affected by the withdrawal of this quantity of water, this information would not be
adversely affected by the withdrawal of this quantity of water.
Venture Global would install thousands of steel or concrete piles to support the LNG
terminal and marine facilities, which would be driven to depths from -80 feet to -220 feet
NAVD88. The proposed piles would be driven to a depth above the confined aquifer underlying
the Project area. In addition, the proposed pile driving would not penetrate any aquifers supportingarea wells.
Approximately 615 12-inch piles would be required to support the meter stations associatedwith the pipeline; however, due to the relatively small size of these facilities, these piles would besignificantly shallower than the piles required for the LNG terminal. Therefore, we expect that thepile driving associated with the meter stations would not have a significant impact on groundwater.
Contamination
Shallow groundwater areas could be vulnerable to contamination caused by inadvertentsurface spills of hazardous materials used during construction and operation of the LNG terminaland pipeline system. Accidental spills and leaks of hazardous materials associated with equipment
trailers, the refueling or maintenance of vehicles, and the storage of fuel, oil, and other fluids posethe greatest risk to groundwater resources. If not cleaned up, contaminated soil could continue toleach and add pollutants to groundwater long after a spill has occurred.
4-16

Venture Global prepared a Project-specific SPCC Plan for both the terminal and thepipeline. We have reviewed the plan and found it acceptable. Implementation of the Projectspecific Plan and Procedures and SPCC Plan would minimize the potential for groundwater
impacts associated with an inadvertent spill of hazardous materials during construction andoperation. These plans identify preventive measures to reduce the likelihood of a spill and also
specify measures to contain and clean up a spill should one occur. In addition, these plans address
the storage and transfer of hazardous materials and petroleum products.
Groundwater Withdrawals
The Project would require fresh water during the construction at the terminal site. Venture
Global proposes to appropriate surface water from a drainage canal located along the southernedge of the terminal property for hydrostatic testing of the LNG tanks (26,200,000 gallons), plant
piping, and non-LNG storage tanks. Table 4.3-1 presents the anticipated water usage during LNG
terminal construction.
Table 4.3-1
Estimated Water Usage During LNG Terminal Construction
Water Source

Use

Quantity (gallons)

Plaquemines Parish Water District orgroundwater well

Personal and sanitary consumption

6,000,000

Concrete production, dust suppression,
miscellaneous construction uses

11,200,000

Surface water

Hydrostatic testing of LNG tanks

26,200,000

Hydrostatic testing of piping and nonLNG storage tanks

50,000As stated above, limited transmissivity data suggest that the Gramercy aquifer, Norco
aquifer, Gonzales-New Orleans aquifer, and the “1,200-foot” aquifer will each have atransmissivity values greater than 10,000 square feet per day at the terminal site. Aquifers withsimilar transmissivity values can typically yield greater than 300 gallons per minute for properly
constructed supply well. If new supply wells were to be installed at the terminal site, one or morewells would be installed in the targeted aquifer to produce 600 gallons per minute for treatment
and use. Since groundwater is not a significant source of industrial or potable water in
Plaquemines Parish, the groundwater withdrawals associated with terminal construction would nothave a significant effect on groundwater in the region.
Water necessary for construction of the pipeline system would primarily consist of water
for drilling mud (HDD make-up water) and water needed for hydrostatic testing of the pipeline
system. Venture Global plans to utilize surface water as the source for hydrostatic testing pipeline
construction needs (see section 4.3.2.2).
No wells in the immediate Project area are used for public or private use. No known
contaminated sites exist near the Project. Excavations and pile driving are not expected topenetrate to the depth of the deeper aquifers in the Project area. The majority of the water required
4-17

would be obtained from surface waters. Venture Global would implement its SPCC Plan during
construction, which contains measures to minimize the potential for spills to occur and clean-up
procedures in the event of a release of fuels or hazardous materials. Therefore, we conclude that
the Project would not have a significant impact on groundwater resources in the Project area.
4.3.2

Surface Water

Water quality standards are developed by states to enhance or maintain water quality,
protect the public health and welfare, and provide for the designated uses of the waters of the state.
In Louisiana, the surface water quality standards are codified in LAC 33:IX.11.
The LDEQ reports on water quality in the state by basin subsegment, which is a discretehydrologic unit or watershed (LDEQ, 2014). Subsegments describe the primary waterbody within
the watershed; however, the water quality standards and criteria apply to all tributaries andconnected waterbodies within the boundaries of a subsegment. There are seven designated uses
established for surface waters in Louisiana, including:
1. Primary Contact Recreation: Any recreational or other water contact use involving
prolonged or regular full-body contact with the water and in which the probability of ingesting
appreciable amounts of water is considerable;
2. Secondary Contact Recreation: Any recreational or other water contact activity in which
prolonged or regular full-body contact with the water is either incidental or accidental and theprobability of ingesting appreciable amounts of water is minimal;
3. Fish and Wildlife Propagation: The use of water for aquatic habitat, food, resting,reproduction, cover, and/or travel corridors for any indigenous wildlife and aquatic life species
associated with the aquatic environment;
4. Drinking Water Supply: The use of water for human consumption and general householduse;
5. Oyster Propagation: The use of water to maintain the biological systems that support
economically important species of oysters, clams, mussels, or other mollusks so that theirproductivity is preserved and the health of human consumers of these species is protected;
6. Agricultural: The use of water for crop spraying, irrigation, livestock watering, poultry
operations, and other farm purposes not related to human consumption; and7. Outstanding Natural Resource Waters: Waterbodies designated for preservation,
protection, reclamation, or enhancement of wilderness, aesthetic qualities, and ecologicalregimes.
Table 4.3-2 presents the basins where the LNG terminal and pipeline system are located,
as well as the LDEQ-designated uses for each basin.

4-18

4.3.2.1 Existing Surface Water Resources
The USGS uses a national standard hierarchical system to categorize surface water
resources of the United States into hydrologic unit codes (HUCs). Based on this tiered system, theUnited States is divided and sub-divided into successively smaller hydrologic units that areclassified into four levels: regions, sub-regions, accounting units, and cataloging units. The
hydrologic units are arranged or nested within each other, from the largest geographic area
(regions) to the smallest geographic are (cataloging units). The Project would be located in HUC
Region 08 – Lower Mississippi and HUC Sub-region 0809 – The Mississippi River below theBonnet Carre Floodway. With the only exception being the LNG terminal berths, the Project
would be within HUC Accounting Unit 080903 – Central Louisiana Coastal and would be divided
between HUC Cataloging Units 08090301 – East Central Louisiana Coastal and 08090302 – West
Central Louisiana Coastal. The LNG terminal berths would be located within HUC Accounting
Unit 080901 – Mississippi Delta Louisiana and HUC Cataloging Unit 08090100 – New Orleans.
These watersheds encompass the Mississippi River, agricultural lands, interconnected wetlands,
drainage ditches, man-made channels, fresh and brackish marshes, and open water.
The Mississippi River serves as the primary source of drinking water for the parish (USGS,
2013a), and there are five public drinking water intakes on the River. Two of the intakes are
upstream of the LNG terminal: Dalcour intake (25 miles upstream) and Belle Chasse (20 miles
upstream). The other three intakes are downstream from the terminal site: Pointe a lá Hache andPort Sulpher (both 4 miles downstream) and Boothville intake (35 miles downstream). The Pointea lá Hache intake is on the east bank of the Mississippi River, and the Port Sulphur and Boothvilleintakes are on the west bank of the Mississippi River. Water from the Mississippi River is high inmineral content (hardness) but, generally, does not exceed the EPA Secondary Maximum
Contaminant Levels for drinking water (USGS, 2013a). The portion of the terminal site locatedwithin the Mississippi River batture is within the Source Water Protection Area for the Pointe a lá
Hache water system and the Port Sulphur Water District.
In periods of low flow, the Mississippi River, both at and upstream of the terminal site, issubject to saline water intrusion, where dense, salty water (exceeding the secondary drinking water
standard of 500 milligrams per liter (mg/L) total dissolved solids and 250 mg/L chlorides) moves
upriver toward New Orleans. Because salt water has a greater density than fresh water, it moves
upstream in the form of a wedge in the lower portion of the water column. A highly stratified
wedge is common within deep rivers with high freshwater flows, such as the Mississippi River.
The leading edge, or “toe,” of the saltwater wedge is well defined. When freshwater flows increaseor decrease, the saltwater wedge retreats downstream or advances upstream, respectively.
LNG Terminal
The terminal site is located adjacent to the Mississippi River, with the terminal berthingareas located in the Mississippi River. The terminal would have 7,000 feet of river frontage
armored with rip-rap and a concrete revetment mattress to minimize erosion. At the terminal site,
the Mississippi River is approximately 2,500 feet wide, and the federal navigation channel width
ranges from 1,700 feet (River Mile Marker 54) to 1,900 feet (River Mile Marker 55). The federal
channel depth is authorized to -55 feet Mean Low Gulf and maintained to a depth of -45 feet Mean
Low Gulf. The LDEQ has established four designated uses for the Mississippi River at the
4-19

terminal site: primary contact recreation; secondary contact recreation; fish and wildlife
propagation; and drinking water supply (table 4.3-2). Based on the numerical criteria established
for these designated uses, water quality in the Mississippi River at the terminal site fully supports
all four designated uses (LDEQ, 2018a). In addition to the Mississippi River, the terminal site istransected by a series of man-made interconnected drainage ditches (table 4.3-3 and, figure B-6 inappendix B). These drainages ditches are part of a larger system of levees and drainage canals thatwere constructed to create over 5,000 acres of fastlands that prevent flooding and facilitate
agricultural use of the area. The drainage ditches connect to a series of canals that convey runoff
from the terminal site generally eastward to a pumping station adjacent to Lake Judge Perez,
approximately 2 miles east of the terminal site.

4-20

Table 4.3-2
Designated Uses for Waterbodies Within the Project Area
Subsegment Name (Subsegment No.)/
Description

Project Component within Basin
Subsegment

Milepost

Designated Usea

Water Quality
Impairment

Pipeline System

0.0-1.8

A, B, C, E

None

Barge Access Channels

NA

Pipeline System

1.8 to 10.8

A, B, C, Eb

Fecal Coliform

Barge Access Channels

NA

Terminal Site

NA

A, B, C, E

None

Barge Access Channels

NA

Pipeline System

10.8 to 15.1

Terminal Site

NA

A, B, C, D

None

Barataria Basin
Barataria Bay (021101)/Caminada Bay, Hackberry Bay, Bay
Batiste, and Bay Long
Wilkinson Canal and Wilkinson Bayou (020904)/Wilkinson Canaland Wilkinson Bayou
Bay Sansbois, Lake Judge Perez, and Bay De La Cheniere(020907)/Bay Sansbois, Lake Judge Perez, Lake Five, Oaks
Bayou, Lake Laurier, and Bay De La Cheniere
Mississippi Basin
Mississippi River (070301)/Monte Sano Bayou to Head of PassesaLouisiana State Water Quality Classifications (LDEQ, 2018a) designated uses include:
A = Primary Contact Recreation
B = Secondary Contact Recreation
C = Fish and Wildlife Propagation
D = Drinking Water Supply
E = Oyster Propagationb Designated use is not fully supported due to fecal coliform impairment.

4-21

Table 4.3-3
LNG Terminal Site Waterbodies

Acres of
Permanent
Fill

Acres of
Permanent
Modification
Other thanFill

Acres ofTemporary
Impacts

Flow
RegimeDescription

Acres
withinTerminal
Site

WB001

Perennial

Man-made Canal

1.9

0.0

0.0

0.0

WB002

Intermittent

Man-made Ditch

0.3

0.3

NA

NA

WB003

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB004

Intermittent

Man-made Ditch

0.2

0.2

NA

NA

WB005

Perennial

Man-made Canal

3.1

3.1

NA

NA

WB006

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB007

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB008

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB009

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB010

Intermittent

Man-made Ditch

0.2

0.2

NA

NA

WB011

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB012

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB013

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB014

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB015

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB016

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB017

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB018

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB019

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB020

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB021

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB022

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB023

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB024

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB025

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB026

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB027

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB028

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB029

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB030

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB031

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB032

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

Waterbody
LNG Terminal

4-22

Table 4.3-3
LNG Terminal Site Waterbodies

Acres of
Permanent
Fill

Acres of
Permanent
Modification
Other thanFill

Acres ofTemporary
Impacts

Waterbody

Flow
RegimeDescription

Acres
withinTerminal
Site

WB033

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB034

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB035

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB036

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB037

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB038

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB039

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB040

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB041

Ephemeral

Man-made Ditch

0.9

0.9

NA

NA

WB042

Perennial

Mississippi River

87.3

0.0

14.6

72.7

WB043

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB044

Ephemeral

Man-made Ditch

0.3

0.3

NA

NA

WB045

Perennial

Man-made Ditch

2.6

0.0

0.2

1.1

Eastern Workspace
WB101

Perennial

Man-made Canal

>0.1

0.0

0.0

0.0

WB102

Perennial

Man-made Canal

0.6

0.0

0.0

0.0

WB103

Perennial

Man-made Canal

2.6

0.0

1.2

0.0

WB104

Perennial

Man-made Canal

<0.1

<0.1

NA

NA

WB105

Ephemeral

Man-made Ditch

0.2

0.2

NA

NA

WB106

Ephemeral

Man-made Ditch

0.4

0.3

0.0

0.0

Sources: SWCA, 2015; Venture Global, 2017

Pipeline System
The pipeline system and barge access channels traverse wetlands, canals, and estuarine
open waters within the Barataria Basin (figure B-6 in appendix B). The Barataria Basin lies in theeastern coastal region of Louisiana and is bounded to the north and east by the Mississippi River,to the west by Bayou Lafourche, and to the south by the Gulf of Mexico. The basin isapproximately 120 miles long and ranges from 24 to 35 miles wide. Major features include naturaland artificial levees, a central marsh landmass, and a chain of barrier islands. Elevations range
from -2 feet to 4 feet above sea level. The USACE maintains several navigation channels in thebasin, which include: the Barataria Bay Waterway; the Gulf Intracoastal Waterway; and theEmpire-Gulf Waterway. Freshwater and sediment inputs into the Barataria Basin have been
diminished by the construction of levees along the Mississippi River and the closure of Bayou
Lafourche at Donaldsonville, Louisiana. The main source of freshwater for the basin is rainfall.

4-23

As presented in table 4.3-4, the pipeline system traverses the following LDEQ watershed
subsegments within the Barataria Basin: Barataria Bay; Wilkinson Canal and Wilkinson Bayou;
and Bay Sanbois, Lake Judge Perez, and Bay de la Cheniere (LDEQ, 2018a). The designated uses
established for all three of these subsegments are primary contact recreation, secondary contact
recreation, fish and wildlife propagation, and oyster propagation. Two of the three subsegments
fully support all four functions. Wilkinson Canal and Wilkinson Bayou do not fully support oyster
propagation due the presence of fecal coliform, but support the other three designated uses.
The pipeline system crosses approximately 12.1 miles of open water habitat. Table 4.3-4
presents the waterbodies traversed by the pipeline, aboveground facilities, and barge accesschannels (figure B-6 in appendix B). The table includes mileposts, description, type, and crossing
method.

4-24

Table 4.3-4
Waterbodies Affected by the Pipeline System
Crossing
Length(feet)TGP
Milepost

Type

Crossing Method/
Facility/Access
ChannelDescription

WBB00014,784

0.0 to 2.8

Bay Batiste

Open Water

Barge Lay

WBB0007,920

2.8 to 4.3

Wilkinson
Bayou

Open Water

Barge Lay

WBB00023,232

4.3 to 8.7b

Wilkinson
Bay/North
Wilkinson Bay

Open Water

Barge Lay

WBB0008,448

9.2b to 10.8

Raquette Bay

Open Water

Barge Lay

WBB0002,640

10.8 to 11.3

Wilkinson
Bayou

Open Water

Barge Lay

WBB000232

11.4 to 11.5

Hermitage
Bayou

Open Water

Push/Pull

WBB000430

11.7 to 12.1

Bayou Tambor

Open Water

Push/Pull

WBB00022012.2 to 12.3

Bayou Tambor

Open Water

Push/Pull

WBB0001,120

12.4 to 12.6

Bayou Tambor

Open Water

Push/Pull

WBB0007,920

12.7 to 14.2

Mix of unnamed
channels,
wetlandsc, andopen water

Open
Water/Wetlandc

Push/Pull

WBB01620

14.5 to 14.5

UnnamedChannel

Perennial Stream

Pipe Bridge

WBA05626

14.8 to 14.8

UnnamedChannel

Perennial Stream

HDD

WBB000NA

0.0

Bay Batiste

Open Water

TGP Meter Station

WBB000NA

3.3

Wilkinson
Bayou

Open Water

TETCO Meter Station

WBB00025,280NA

Bayou St. Denis
and Barataria
Bay

Open Water

Barge Access Channel
1

WBB00056,705NA

Barataria Bay,
Wilkinson
Canal, Oaks
Bayou, Lake
Laurier,
Wilkinson
Bayou

Open Water

Barge Access Channel
2

WBB00017,215NA

Barataria Bay,
Bay Batiste

Open Water

Barge Access Channel
3

Waterbodya

Aboveground Facilities

Barge Access Channels

a Field surveys conducted by Venture Global label all waters between TGP MP 00 and MP 14.8 as WBB000. This area is a mosaic of open
water and wetlands. For the purposes of this table, we have sub-dived waterbody WBB000 to describe the named waterbodies traversed by
the Project. The wetland portions of this area are discussed in section 4.4.1.
b The saturated marsh between MP 8.7 and MP 9.2 will also be crossed via barge lay as the soils are too saturated to support push lay equipment.
c The wetlands are discussed in section 4.4.1.

4-25

Venture Global has indicated that the channel depth for five portions of the barge accesschannels, totaling 9.1 miles, is not sufficient to allow for delivery of pipe and equipment to thepipeline construction right-of-way. These areas would require dredging to facilitate access fromthe Intracoastal Waterway via Barataria Bay and Wilkinson Canal. Venture Global proposes
dredging, with a mix of excavation and wheel washing (propeller wash agitation), to achieve thenecessary channel depth. Table 4.3-5 presents the proposed dredging areas, types of dredging, anddredging impacts.
Table 4.3-5
Pipeline System Barge Access Channel Dredging Impacts
Wheel
Washing(linear feet)

Excavation(linear feet)

Total Length(linear feet)

Area of
Disturbance(acres)Barataria Bay

1,200

11,913

13,113

86.3

Segment A

Barataria Bay

200

7,070

6,870

48.1

Segment B

Wilkinson Canal

1,095

550

1,095a7.5
66.8

Segment
Barge Channel 1

Waterbody
Name

Barge Channel 2

Segment C

Lake Laurier

875

9,724

10,399aBarge Channel 3

Barataria Bay

6,688

9,870

16,538113.9

10,05838,72748,015

322.6

Total

a Total length is not a sum of the wheel washing linear feet and the linear feet of excavation due to overlapping areas where wheel washingand excavation are both proposed.

4.3.2.2 Surface Water Impacts and Mitigation
Impacts on surface waters resulting from construction and operation of the LNG terminaland pipeline system and the measures proposed to avoid or minimize impacts on surface waters
are described below.
LNG Terminal
Table 4.3-3 describes the surface waters that would be affected as a result of construction
and operation of the LNG terminal. Potential impacts on surface waters during construction andoperation of the LNG terminal are associated with construction of the LNG ship berthing facilities,
vessel traffic, site modification and stormwater runoff, hydrostatic testing, and spills or leaks ofhazardous materials. Venture Global does not propose any dredging of the berthing facilities, as
the maintained depth and width of the Mississippi River is sufficient for LNG vessel operation.
Construction of the LNG Loading Docks and Ship Berthing Facilities
Construction of the LNG loading docks and ship berthing facilities would be conducted in
two phases. Phase I would consist of construction of three temporary marine delivery facilities
and two of the three LNG loading docks. Phase II would consist of constructing the last LNG

4-26

loading dock, removal of the temporary marine delivery facilities, and restoration of the area
affected by the temporary marine delivery facilities.
The marine facilities would consist of a LNG loading docks, MOF, and two temporary
berths (east and west). The number and size of piles required for each facility are shown in table
4.6-3. The MOF would consist of a concrete platform supported by large-diameter steel piles.
Each of the three LNG loading docks would feature a concrete platform that would be constructedon steel piles, four breasting dolphins, and six mooring dolphins. The proposed marine facilities
would occupy a portion of the approximately 7,000 feet of river frontage. The LNG loading docks
and temporary marine delivery facilities (bulk carrier mooring facility, barge mooring facility, andMOF) would occupy an approximately 14.6-acre footprint in the river channel and in wetlands
along the river bank. The loading docks would be connected to shore by pipe and access trestles.
A separate jetty substation, located on steel piles, would provide electricity to the loading docks.
Land-based access for each dock would be via a staircase, supported by a concrete and compacted
fill base.
Construction of the LNG loading and ship berthing facilities would require over-water andland-based equipment installation (e.g., LNG loading platform, pipe and roadway trestle, marine
gangway). A combination of conventional in-water marine construction equipment (e.g., barges,
cranes, pile driving equipment) and shore-based construction equipment (e.g., backhoes,
bulldozers) would be used to install the LNG loading docks, pilings, and over-water structures.
Construction of the marine facilities would require temporary workspace within the river channel
for anchoring of construction vessels, specifically barge mounted cranes for installation of thepiles.
Construction of the LNG loading and ship berthing facilities would result in localized,
temporary increases in turbidity and suspended sediment levels in the Mississippi River due to
excavation and pile driving. However, these impacts are expected to be temporary (i.e., confined
primarily to the period of in-water activity and shortly thereafter) and limited to the area within
and immediately adjacent to the LNG loading and ship berthing facilities. No long-term or
permanent water quality impacts are anticipated because there is no dredging required at theterminal.
Venture Global is required to obtain several permits that would address placement of the
LNG terminal marine structures within the Mississippi River, including permits under section 404
of the CWA and sections 10 and 14 of the RHA of 1899 from the USACE. In June 2017, two
Joint Permit Applications (JPAs) were submitted to the USACE and the LDNR; one for the LNG
terminal and one for the pipeline system. These applications were submitted under sections 404
and 401 of the CWA, sections 10 and 14 of the RHA, and the Coastal Use Permit regulations.
Revised applications were submitted in July 2016. In September 2017, a JPA was submitted to
the USACE that combined the applications for the terminal and the pipeline. Venture Global
received the section 401 Water Quality Certification from the LDNR for the LNG terminal andpipeline system on October 1, 2018. Venture Global anticipates receipt of the USACE permits inJuly 2019.

4-27

Vessel Traffic
Shoreline Erosion and Resuspension
The portion of the Mississippi River where the marine facilities are proposed has been
modified by placement of rip-rap and a concrete revetment mattress along the river bank. These
modifications are designed to minimize shoreline erosion along this major shipping lane. To
minimize impacts on the existing revetment, Venture Global would repair any damage to rip-rap
and concrete revetment mattress resulting from marine facility installation in accordance withnecessary permit requirements; however, Venture Global is not proposing additional placement of
rip-rap or revetment structures within the terminal marine facilities as the shoreline is alreadyarmored. Due to the previous armoring and Venture Global’s commitment to repair or replace riprap and concrete revetment mattress, the new facilities would not result in additional erosion of
the river bank.
To minimize erosion and sedimentation impacts on surface waters during construction,
Venture Global would conduct land-disturbing activities in compliance with the LPDES program(Construction General Permit for storm water discharges and a Project-specific SWPPP), as
required under the CWA and Louisiana law. Venture Global would install erosion control devices
after initial clearing, but before soil disturbance, and maintain all erosion control devices inaccordance with applicable permit conditions until restoration or surface stabilization is complete.
Temporary erosion and sediment control devices and measures may include sediment barriers,
storm water diversions, trench breakers, mulch applications, and revegetation.
The Mississippi River is maintained by the USACE to provide deep water access formaritime commerce. Ships calling on the LNG terminal during operations would be similar innature to other existing ship traffic along this portion of the Mississippi River. LNG carriers
transiting the Gulf of Mexico would use established shipping channels. As such, use of thewaterways by LNG carriers, barges, and support vessels during construction and operation of the
LNG terminal would be consistent with the planned purpose and use of active shipping channels,
and associated impacts on water quality within the shipping channel would be minor.
Ballast Water Discharge
LNG carriers serving the LNG terminal would likely arrive with empty cargo tanks to beloaded with LNG destined for export. Vessels with empty cargo tanks ride higher in the water andcan experience challenges associated with navigation due to the extra sail area (i.e., ship surface
area above the water line). Challenges include the vessel being more susceptible to windinfluences and less efficient as a result of reduced performance of the propeller, rudder, andpropulsion system. To reduce or eliminate the challenges of navigating the ship without cargoaboard, water is often taken in from the surrounding waters and placed in ballast tanks to provide
additional draft and improve navigation. To maintain a constant draft, ballast water is typicallydischarged below the water surface as the LNG cargo is loaded. The amount of ballast water
discharged during LNG cargo loading would vary depending on the size of the LNG carrier.
Venture Global estimates the ballast water discharge would not exceed 60,000 cubic meters(approximately 16 million gallons) per vessel.

4-28

As required by the USCG’s regulations (33 CFR 151.2026), vessels equipped with ballast
tanks must implement one of five specified options to control nonindigenous species in waters of
the United States, including the introduction of invasive aquatic organisms into local waters. The
International Maritime Organization (IMO) adopted this regulation and requires each vessel toinstall and operate a ballast water management system. These requirements would apply to all
LNG carriers serving the Project.
Carriers calling at the LNG terminal would be required to comply with the USCG ballast
water management regulations and procedures that establish a standard for the allowable
concentration of living organisms in ships’ ballast water discharged in waters of the United States.
The USCG has also established engineering equipment requirements and an approval process forballast water treatment systems installed on ships. All ships calling at U.S. ports and intending todischarge ballast water must either carry out open sea exchange of ballast water or ballast water
treatment, in addition to fouling and sediment management. Venture Global would include theserequirements in agreements for carriers calling at the LNG terminal. Therefore, any ballast water
introduced into the Mississippi River would be primarily composed of open ocean water collectedduring ballast water exchange.
Ballast water discharges at the LNG terminal could impact water quality by changing thesalinity, temperature, pH, and dissolved oxygen level of water within the vicinity of the LNG
terminal loading docks in the Mississippi River. The physiochemical composition of ballast waterin comparison to the water present within the Mississippi River would vary depending on the flowof the Mississippi River at the time of discharge.
The primary potential impact on water quality due to ballast water discharge would be atemporary increase in salinity level. As described above, the Mississippi River is usuallyfreshwater at the terminal site; however, during periods of low flow, saltwater can push up theMississippi River to the terminal site and beyond. Ballast water, which would generally consistof open ocean water, would have a salinity of approximately 35 parts per thousand (ppt) (NOAA,
2018). In general, ballast water would have a higher salinity than the surrounding water at the
LNG loading docks. Natural flow would rapidly dilute the ballast water discharge and increased
salinity would represent a temporary and minor impact on water quality within the Mississippi
River.
Ballast water is stored in the ship’s hull below the waterline; as a result, discharged watertemperatures are not expected to deviate markedly from ambient water temperatures. The pH of
the ballast water (reflective of sea water in open ocean conditions) is maintained in a fairly narrow
range (8.1 to 8.5). The pH within the Mississippi River ranges from 7.2 to 7.9, with a median of
7.7 at Belle Chasse (USGS, 2013a), which is lower than seawater. Although the pH of the ambient
water at the terminal site is anticipated to be lower than the ballast water, the difference in pH isminor and would be expected to quickly normalize.
Another water quality parameter that may be influenced by ballast water discharges is
dissolved oxygen level. Dissolved oxygen levels in water are dependent upon many factors
including temperature, rainfall, tidal magnitude, depth, currents, and phytoplankton activity.
Ballast water would contain low dissolved oxygen levels and could decrease existing dissolved
oxygen levels in the immediate vicinity of the discharge point. Although the dissolved oxygen of
4-29

the ambient water at the terminal site is anticipated to be higher than the ballast water, it is expectedthat the dissolved oxygen of the ballast water would quickly normalize.
The amount of ballast water discharged into the Mississippi River during each LNG carrier
visit to the LNG terminal would make up a small percentage of the water within the Mississippi
River, as the Mississippi River discharges, on average, nearly 400 billion gallons per day into theGulf of Mexico (NPS, 2018). Venture Global estimates that ballast water discharges would notexceed 16 million gallons per vessel, and Venture Global anticipates approximately 310 vessels
annually. At full capacity, the terminal could accommodate six carriers per week. Therefore,ballast water discharge events could occur up to six times per week. Due to the high volume ofwater that flows along the Mississippi River, we conclude that impacts on salinity, pH,temperature, and dissolved oxygen would be temporary and minor.
Site Modification and Stormwater Runoff
During site preparation at the LNG terminal, several drainages ditches would be filled. The
terminal site has a grid of drainage ditches that are part of the fastlands system formerly created tofacilitate agriculture and development in the Project area. This system of drainage ditches moves
water from the fastlands to a pumping station near Lake Judge Perez, where the water is pumped
into Lake Judge Perez. Table 4.3-4 presents all the waterbodies within the terminal site and theadjacent eastern workspace, as well as the proposed impacts on these waterbodies. Table 4.3-6
presents a summary of the temporary and permanent impacts on waterbodies at the terminal site,
including the landward terminal facilities, marine facilities, and the eastern workspace.
Table 4.3-6
Summary of Waterbody Impacts in Acres at the Terminal Site
Perennial
Facility

Intermittent

Ephemeral

Total

Temporary Permanent Temporary Permanent Temporary Permanent Temporary Permanent

Terminal Facilities

1.1

0.4

<0.1

0.8

0.1

13.1

1.2

14.2

Marine Facilities

72.7

14.6

0.0

0.0

0.0

0.0

72.7

14.6

Eastern Workspace

0.0

1.2

0.0

0.0

0.0

0.5

0.0

1.7

73.8

16.2

<0.1

0.8

0.1

13.6

73.9

30.5

Total

Since the landward terminal facilities south of SH 23 would be surrounded by a floodwallthat is 28 feet above proposed grade, stormwater inside the terminal facilities would be collected
through a series of ditches into a series of sumps. Sump pumps would pump the stormwater to thestormwater header, from which it would then be pumped to the Mississippi River. Sumps that
service LNG spill impoundment basins and other facilities where hazardous materials may bepresent would be equipped with automatic shutoffs that activate when LNG or other solvents arepresent. This would prevent contaminated stormwater from being pumped from the facility.
Stormwater from the LNG terminal marine facilities would be collected and processed throughoil/water separators prior to discharging to the Mississippi River.
As described in section 4.2.2, Venture Global indicated that are no contaminated soils
within the LNG terminal site. Therefore, construction activities are not expected to introduce
4-30contaminated sediments to adjacent surface waters or the Mississippi River. To minimize impacts
on water quality due to increased stormwater runoff during construction, land disturbing activities
would be conducted in compliance with: the LPDES General Permit for stormwater discharges
from construction activities of 5 acres or more; Venture Global’s Project-specific Construction
SWPPP; and Venture Global’s Plan and Procedures.
With implementation of the stormwater treatment system described above and adherence
to Venture Global’s SWPPP and LDEQ and EPA requirements, stormwater discharges resulting
from construction and operation of the LNG terminal would result in temporary and minor impacts
on surface waters.
Hydrostatic Testing
Venture Global proposes to appropriate surface water from a drainage canal located along
the southern edge of the terminal property for hydrostatic testing of the LNG tanks (26,200,000
gallons), plant piping, and non-LNG storage tanks (50,000 gallons). Water would be withdrawn
from the canal at a rate of 1,500 gallons per minute to minimize impingement of aquatic organisms
and debris. The intake structure would be fitted with 0.25-inch to 1.0-inch screens to minimize
entrainment of aquatic organisms and debris. Venture Global would utilize 26,200,000 gallons ofwater for hydrostatic testing of a single LNG storage tank. The water for LNG storage tankhydrostatic testing would be transferred between tanks to conserve water.
Small quantities of water used for hydrostatic testing may be discharged directly to theground in well-vegetated upland areas in accordance with Venture Global’s Procedures. Largedischarges of hydrostatic test water would be treated, as necessary, and discharged to theMississippi River, into adjacent drainage canals, or on-site in accordance with permit conditions.
Pumps and energy dissipation devices would be used to control the discharge rate and limit
scouring and erosion. Due to the large volumes of water needed, it would not be practical totransport this volume of water for disposal due to the limited capacity of tanker trucks.
Where water from the nearby drainage canal is used to hydrostatically test the LNG
facilities, chemical additives may be required during the testing process to neutralize bacteria andother components that can be corrosive. Before returning hydrostatic water to its surface water
source, Venture Global would pass the water through 25 to 50 micron filters and an active carbon
medium to remove suspended solids and neutralize or biodegrade the chemical additives.
Following completion of the hydrostatic testing and prior to discharge, the test water would beanalyzed for total suspended solids, oil and grease, and pH in accordance with LDEQ LPDES
general permit LAG670000. In accordance with general permit LAG670000, Venture Global willseek authorization from the LDEQ to use additives and would provide the specific additives andthe intended concentrations as part of the permitting process. The withdrawal, testing, anddischarge of hydrostatic test water would be conducted in accordance with LPDES permit
requirements. Therefore, we conclude that impacts on surface waters as a result of hydrostatic
testing would be negligible.

4-31

Spills
During construction and operation, hazardous materials resulting from spills or leaks
flushed into the Mississippi River with stormwater could have an adverse impact on water quality.
To prevent spills and leaks, Venture Global would implement its final Project-specific SPCC Plan
during operation of the LNG terminal, which outlines potential sources of releases at the site,measures to prevent a release, and initial responses in the event of a spill. Given the impact
minimization and mitigation measures described above, impacts on surface waters due to spills or
leaks during construction and operation of the LNG terminal would be temporary and minor.
Pipeline System
Pipeline
The majority of the pipeline system (approximately 12.1 miles) would be constructed inopen water, including bays, canals, bayous, and unnamed channels. Table 4.3-4 provides a list ofaffected waterbodies. In expansive open water areas, Venture Global would utilize a barge lay
method (as described in section 2.5.2.4). Where open water channels are intermingled withwetlands, Venture Global would utilize a push/pull construction method (as described in section
2.5.2.5). Venture Global proposes to utilize conventional lay techniques for approximately
475 feet of the pipeline system route from Southwest Lateral TGP MP 14.3 to Southwest Lateral
TGP MP 14.4, south of Lake Hermitage Road. North of Lake Hermitage road, the pipeline system
would cross a levee and a perennial canal (WBB016) with a pipe trestle. From the pipe trestle to
the LNG terminal, Venture Global would utilize HDD to cross a perennial canal (WBA056) andenter the terminal site.
The construction right-of-way for the barge lay construction technique would be 300 feetwide for each pipeline, with 250 feet of overlap, for a total construction right-of-way of 350 feetand 80 feet of permanent right-of-way. The construction right-of-way for the push/pull
construction technique would be 130 feet wide. In total, approximately 505.4 acres of waterbodies
would be temporarily affected by construction of the pipeline system. All impacts would be
temporary in nature, and the right-of-way would be restored post-construction.
The two primary methods for open water construction, barge lay and push/pull, require
excavating a trench to accommodate the pipeline. Additionally, some minimal vegetation clearing
and grading may be necessary along some portions of the push/pull installation. Vegetation
clearing and grading would occur along the 475 feet of conventional lay. Runoff from theconstruction right-of-way in the conventional lay areas could affect nearby surface waters.
Vegetation clearing and grading, trenching, and backfilling could increase sedimentation rates andturbidity levels. These activities could also reduce dissolved oxygen in the water column andrelease chemical or nutrient pollutants from sediments. In additional, refueling of vehicles over ornear open water and the storage of fuel, oil, and other hazardous materials near surface waters
could result in accidental spills that could contaminate surface waters.
Dredging through excavation and wheel washing would be necessary along some of thebarge access channel that would be utilized to transport pipe and equipment to the right-of-way.
Table 4.3-5 presents the location and quantities of dredge that would be required. These dredging

4-32

activities could increase sedimentation rates and turbidity levels. These activities could also
reduce dissolve oxygen in the water column and release chemical or nutrient pollutants fromsediments.
Venture Global would minimize potential impacts on surface waters by implementing the
Project-specific Procedures and the general and special conditions included in the USACE permit.
In order to minimize potential impacts associated with an accidental spill of fuel, oil, or otherhazardous materials, Venture Global would implement its Project-specific SPCC Plan, which
identifies potential sources of hazardous materials present during construction activities and themeasures that would be implemented to prevent, contain, and clean up accidental releases. With
the implementation of this plan and the Project-specific Procedures, impacts on water quality inthe event of a spill or leak are expected to be minor.
Impacts on surface waters are not expected during operation of the pipeline system because
no further in-stream activities are expected. Because the pipelines would be installed at a sufficientdepth below the beds of waterbodies, exposure of the pipe is not anticipated. In the event that apipeline anomaly (e.g., corrosion, dent, rupture) is detected during routine inspections that could
require pipeline excavation or replacement within a waterbody, impacts would be similar to thosedescribed above for construction.
Impacts on surface water resources due to construction and operation of the pipeline system
would be temporary and localized. Venture Global would implement the Project-specific Plan andProcedures and SPCC Plan and follow all permit requirements to minimize impacts on water
resources during construction and operation of the pipeline system. Therefore, we conclude that
impacts on surface waters from construction and operation of the pipeline system would be minor.
Aboveground Facilities
Construction of the aboveground facilities (meter stations and stand-alone mainline valves)
would affect waterbodies. The pipeline system would interconnect with existing TGP and TETCO
pipelines at two separate open water locations in Bay Batiste and Barataria Bay, respectively,
where the water depth averages 6 feet to 8 feet. A meter station would be constructed at each of
the two locations. Venture Global would elevate the meter stations on pilings at a sufficient height
above the water line to protect against storm surge. While the Southwest Lateral TGP platform
would encompass 1.1 acres and the Southwest Lateral TETCO platform would encompass 1.3
acres, they would be fully supported on piles and no fill would be required for construction ofeither meter station. Thus, for each meter station, the actual acreage of surface water impact would
be considerably less than the platform acreage.
Impacts on water quality associated with construction of the meter stations and mainline
valves would be similar to those described above and would be minimized through theimplementation of the Project-specific Procedures, the general and special conditions included in
the USACE’s permit, and Venture Global’s Project-specific SPCC Plan (see “Pipelines,” above).
Therefore, we conclude that the impacts on surface waters from aboveground facility construction
and operation would be minor.

4-33

Hydrostatic Testing
The lateral pipelines would be hydrostatically tested for structural integrity prior to being
placed in service. Testing would be completed by capping installed pipe segments with test
manifolds, filling these segments with available water, and pressurizing this water to levels beyond
the maximum operating pressure of the pipeline. The water would be maintained at these pressurelevels for a minimum of 8 hours. Hydrostatic testing must be conducted in a manner that meets orexceeds the DOT’s “Transportation of Natural and Other Gas by Pipeline: Minimum Federal
Safety Standards” (49 CFR 192). Venture Global estimates that 5,626,316 gallons of water would
be required for hydrostatic testing of the Southwest Lateral TGP pipeline, and 3,997,658 gallons
of water would be required for hydrostatic testing of the Southwest Lateral TETCO pipeline.
The Southwest Lateral TGP and Southwest Lateral TETCO HDD segments would behydrostatically tested prior to installation. Water from the existing drainage canal (WBA056)
along the south side of the LNG terminal (Southwest Lateral TGP MP 14.8) would be used as thetest water source. The withdrawal location would be in the construction right-of-way. Like thewater uptake for HDD mud preparation, the pumping rate would vary from 250 to 500 gallons per
minute and the water would be passed through a 0.25-inch to 1.0-inch mesh screen to minimize
uptake of various debris and aquatic biota. After testing, the water would be discharged back into
the canal through an energy dissipating structure.
Apart from the HDD segments mentioned above (which would both be constructed inPhase I), hydrostatic testing of the Southwest Lateral TGP and the Southwest Lateral TETCO
would occur during Phase I and Phase II, respectively. For each pipeline, water would be
withdrawn near the TGP (Phase I) and TETCO (Phase II) platforms. The pumping rate would be
up to 1,200 gallons per minute, and the suction end of the transfer hose would be equipped withscreens ranging from 0.25 inch to 1 inch to minimize the uptake of various debris and aquaticbiota. If necessary, a corrosion inhibitor would be added to protect the pipe. Prior to discharge,
the water would flow through 25 to 50 micron filters to remove any entrained solids and an active
carbon medium to remove chemical contaminants. The discharge location for Phase I would be
the drainage canal along the south side of the terminal site at Southwest Lateral TGP MP 14.8.
The discharge location for Phase II would be the mainline valve site at Southwest Lateral TGP MP
14.4 on the south side of Lake Hermitage Road.
Environmental impacts from the discharge of hydrostatic test water would be minimized
by adoption of the measures prescribed in the Project-specific Plan and Procedures. Venture
Global would locate hydrostatic test manifolds outside of wetlands and riparian areas, to the extent
practicable, and would comply with all appropriate requirements of LPDES general permit
LAG670000 for hydrostatic test wastewater discharges. By implementing the measures describedabove, we conclude that impacts on water resources as a result of hydrostatic testing would beminor.
4.3.2.3 Modifications to FERC Procedures
Venture Global developed Project-specific Procedures by modifying our Procedures asnecessary for this Project. We have reviewed these modifications as they relate to waterbodies(sections I to V) and have found the majority of them to be justified, particularly given the

4-34hydrology of the region. As we present in section 2.5.5.5, those proposed modifications that aresubstantive and for which we have determined Venture Global provided adequate justification arelisted in appendix C, table 2. Some of the requested modifications are discussed below.
Time Window for Construction
Section V.B.1 of our Procedures require that instream work within cool-water and warmwater fisheries must occur from June 1 to November 30, unless expressly permitted or further
restricted by the appropriate federal or state agency in writing on a site-specific basis. In the draft
EIS, we recommended that Gator Express Pipeline should consult with the LDWF regarding therequested construction time windows for waterbody crossings or confirm that it would adhere to
the warmwater fishery crossing time windows in the FERC Procedures. On January 24, 2019,
Venture Global received approval from the LDWF to conduct instream work within the warmwater
fisheries associated with the Project year-round.
Equipment Staging, Fueling, and Storage of Hazardous Materials
Section IV.A.1.d of our Procedures requires all equipment to be parked overnight and/or
fueled at least 100 feet from a waterbody or in an upland area at least 100 feet from a wetland
boundary. These activities can occur closer only if the EI determines that there is no reasonable
alternative and the Project sponsor and its contractors have taken appropriate steps (including
secondary containment structures) to prevent spills and provide for prompt cleanup in the event ofa spill. In construction locations where there is no reasonable alternative other than to locate
upland refueling sites less than 100 feet from wetlands or waterbodies, the Project would maintainat least a 10-foot setback. All refueling and equipment storage procedures, irrespective of
proximity to wetlands or waterbodies, would be undertaken in accordance with Venture Global’s
SPCC Plan to reduce the potential for spills during construction and to mitigate the environmental
impacts if a spill were to occur.
Section IV.A.1.e of our Procedures requires that hazardous materials, including chemicals,
fuels, and lubricating oils, be stored at least 100 feet from a wetland, waterbody, or designatedmunicipal watershed area, unless the location is designated for such use by an appropriate
governmental authority. This applies to storage of these materials and does not apply to normal
operation or use of equipment in these areas. Equipment used in wetlands and open water would
often operate at long distances (up to several miles) from the nearest upland refueling station. To
move the equipment out of the wetland or open water for refueling, possibly on multiple occasions,is logistically impractical and potentially more environmentally damaging than refueling in situ.
To minimize the environmental damage caused by excessive relocation of equipment, towed fuelbarges would accompany amphibious equipment as construction progresses. Equipment operators
would be fully trained in refueling procedures and Venture Global’s SPCC Plan.
Extra Work Space
Section V.B.2.A of our Procedures requires that additional temporary workspace (ATWS)
be at least 50 feet from the water’s edge except where the adjacent upland consists of cultivated or
rotated cropland or other disturbed land. For this Project area, several ATWSs are located withinwaterbodies. The in-water siting of these ATWSs is due to either standing water or the lack of

4-35

cohesiveness in the saturated soil within the pipeline construction right-of-way and the consequent
need for adjacent areas in which the additional volumes of loosely aggregated spoil generated atforeign pipeline crossings could be temporarily stored. These ATWSs would be used only forplacement of spoil, and any equipment used for this purpose would work from barges or othersimilar platforms and would be within a secondary containment structure to reduce the risk ofspills of fuels or other pollutants from entering the waterbody. The same secondary containment
provisions would apply for equipment operating within the ATWS located at the meter station
platforms and the barge staging area. Locations where Venture Global has proposed to place
ATWSs areas in or within 50 feet of waterbodies are presented in table 4.3-7.
We have reviewed these proposed ATWS locations and conclude this modification has
been adequately justified. Because the majority of the Project area consists of open water andcoastal marsh, siting these ATWS areas in upland areas is not feasible for this Project.

4-36

Table 4.3-7
Proposed Locations of Additional Temporary Workspaces within Waterbodies
TGP
Approximate
Milepost(direction from
centerline)a

ATWS
Dimensions(feet)

ATWS
Acreage

0.0

1,200 x 1,000

25.4

TGP Meter Station
Platform

3.4

1,400 x 1,400

37.1

7.0 (West)2,335 x 50 and
840 x 250

7.0 (East)

Project
Construction
Activity

WaterbodyType and ID
Number

Waterbody
ImpactAcreageBarataria Bay

Subtidal
WBB000

25.4

ATWS needed for placement of platform construction barge anchorsand maneuvering of equipment and material barges during
construction of meter station platform in open water.

TETCO Meter
Station Platform

Barataria Bay

Subtidal
WBB00037.1

ATWS needed for placement of platform construction barge anchorsand maneuvering of equipment and material barges during
construction of meter station platform in open water.

7.4

Foreign Pipeline
Crossing (Barge
Lay)

Wilkinson Bay

Subtidal
WBB000

7.4

ATWS needed for placement of additional spoil from new pipeline
facilities crossing an existing foreign 8-inch-diameter pipeline.

2,290 x 50 and
675 x 250

7.3

Foreign Pipeline
Crossing (Barge
Lay)

Wilkinson Bay

Subtidal
WBB000

7.3

ATWS needed for placement of additional spoil from new pipeline
facilities crossing an existing foreign 8-inch-diameter pipeline.

9.0 (West)250 x 137 –irregular shape

0.8

Foreign Pipeline
Crossing (Barge
Lay)

Upper
Wilkinson Bay

Subtidal
WBB0000.3

ATWS needed for placement of additional spoil from new pipeline
facilities crossing an existing foreign 6-inch-diameter pipeline.

9.0 (East)

250 x 338 –
irregular shape

1.9

Foreign Pipeline
Crossing (Barge
Lay)

Upper
Wilkinson Bay

Subtidal
WBB0000.1

ATWS needed for placement of additional spoil from new pipeline
facilities crossing an existing foreign 6-inch-diameter pipeline.

11.0 (West)500 x 1,788 –
irregular shape

20.5

Barge Staging
Area

Wilkinson Bay

Subtidal
WBB000

20.5

ATWS needed for temporary placement of pipe and material barges
during construction of pipeline segments in open water of Barataria
Bay and Wilkinson Bay.

14.2 (West)1,220 x 50 and
210 x 250

2.9

Foreign Pipeline
Crossing (Push)and Pipe Bend
Installation

Wilkinson Bay
Tidal Area

Subtidal
WBB000

1.1

ATWS needed for placement of additional spoil from new pipeline
facilities crossing an existing foreign 20-inch-diameter pipeline.

14.2 (East)

1,080 x 50 and
160 x 250

2.4

Foreign Pipeline
Crossing (Push)and Pipe Bend
Installation

Wilkinson Bay
Tidal Area

Subtidal
WBB0000.2

ATWS needed for placement of additional spoil from new pipeline
facilities crossing an existing foreign 20-inch-diameter pipeline.

WaterbodyNamea All listed ATWS are located within waterbodies.

4-37

Justification

4.4

WETLANDSThe USACE defines wetlands as those areas that are inundated or saturated by surface orgroundwater at a frequency and duration sufficient to support, and that under normal circumstances
do support, a prevalence of vegetation typically adapted for life in saturated soil conditions(Environmental Laboratory, 1987).
At the federal level, wetlands are regulated under section 404 of the CWA, which
establishes standards to evaluate and reduce total and net impacts on wetlands under thejurisdiction of the USACE. In general, wetland impacts need to be avoided, if possible. If
avoidance is not possible, impacts are to be minimized, rectified, reduced, and mitigated inaccordance with federal and state regulations, including our Procedures and the USACE’s section
404(b)1 guidelines, which restrict discharges of dredged or fill material where a lessenvironmentally damaging and practicable alternative exists. USACE jurisdictional wetlands
potentially affected by the Project are subject to review by the USACE to ensure that wetland
impacts are fully identified and that appropriate wetland restoration and mitigation measures are
identified. The Project is located in the USACE New Orleans District.
Wetland impacts authorized under section 404 of the CWA also require state water quality
certification under section of the CWA and a state-issued CUP from the LDNR Office of Coastal
Management (OCM) for impacts on coastal wetlands. Venture Global received the section 401
Water Quality Certification from the LDEQ on October 1, 2018, for the LNG terminal and thepipeline system. The State of Louisiana defines coastal wetlands as wetlands less than 5 feet
AMSL (roughly equivalent to 5 feet NAVD88) that occur within the designated coastal zone
(Louisiana Revised Statute 49:214.2), unless designated as “fastlands.” Coastal wetlands are under
the jurisdiction of the LDNR Office of Coastal Management and the USACE. The USACE does
not recognize the fastlands term. According to the revised June 7, 2012 Coastal Zone Inland
Boundary, all Project components are located within the designated coastal zone.
Once the OCM completes its preliminary review, and the JPA CUP is deemed complete, it
is forwarded to the USACE for concurrent review. In order to streamline the permit process, theprogram is executed jointly through an Interagency Joint Public Notice agreement with the
USACE. As part of the Interagency Joint Public Notice system, the OCM submits basic project
information to NMFS, FWS, EPA, LDWF, the Louisiana DOTD, SHPO, LDEQ Office ofEnvironmental Services, and the Louisiana State Land Office. Coordination with local parishes isalso required as part of the Louisiana Coastal Resources Program. Typically, these agencies
submit comments or letters of no objection on projects or issue specific requirements or conditions
that an applicant must comply with before the OCM will issue an authorization or permit.
In June 2017, two JPAs were submitted to the OCM: one by Plaquemines LNG for the
LNG terminal (Permit Application No. P20170545), and one by Gator Express Pipeline for the
pipeline system (Permit Application No. P20170543). Venture Global combined the two
applications and submitted a single JPA application to the USACE in September 2017. The permit
application is currently under review.

4-38

4.4.1

Existing Wetland Resources

Venture Global conducted wetland delineations at the terminal site in November 2015 andNovember 2016 (eastern workspace), and conducted delineations of the pipeline system in
December of 2015 (figure B-6 in appendix B). Field teams employed two approaches whendelineating wetlands within the Project boundary. For areas within the fastlands, the delineation
involved a pedestrian survey that followed the standard wetland delineation methodology
presented in the 1987 USACE Wetland Delineation Manual (Environmental Laboratory, 1987)
and further defined in the Regional Supplement to the USACE Wetland Delineation Manual:Atlantic and Gulf Coastal Plain Region (USACE, 2010). Outside of fastland areas, expansive
coastal marshes are interspersed with canals and open water. In these areas, a desktop review of
NWI maps and aerial imagery provided a baseline wetland map that the field teams used to fieldverify wetland types as well as the boundaries between wetlands and open water while aboard anairboat.
Venture Global classified the wetlands and waterbodies within the Project area according
to the Classification of Wetlands and Deepwater Habitats of the United States (Cowardin et al.,1979). Representative species for each wetland type are presented in sections 4.5.1.1 (terminal)and 4.5.1.2 (pipeline). Five wetland types and one open water type were identified within the
Project area, as described below.
•

Estuarine emergent (EEM) wetlands, which include all tidal wetlands dominated byerect, rooted, herbaceous hydrophytes (excluding mosses and lichens) and all such
wetlands that occur in tidal areas in which salinity due to ocean-derived salt is equal toor greater than 0.5 percent and that are present for most of the growing season in mostyears. Perennial plants usually dominate these wetlands.

•

Palustrine emergent (PEM) wetlands, which include all tidal and non-tidal wetlands
dominated by persistent, emergent, vascular plants, emergent moss or lichens, and allsuch wetlands that occur in tidal areas in which salinity due to ocean-derived salt is
below 0.5 percent. Plants generally remain standing until the next growing season.

•

Estuarine scrub/shrub (ESS) wetlands, which include all tidal wetlands dominatedby woody vegetation less than 5 meters (16 feet) in height, and all such wetlands that
occur in tidal areas in which salinity due to ocean-derived salt is equal to or greaterthan 0.5 percent. Total vegetation coverage in ESS wetlands is greater than 20 percent.

•

Palustrine scrub/shrub (PSS) wetlands, which include all non-tidal wetlands
dominated by woody plants less than 6 meters (20 feet) tall in which salinity due toocean-derived salt is below 0.5 percent.

•

Palustrine forested (PFO) wetlands, which include all non-tidal wetlands dominatedby woody vegetation greater than 6 meters (20 feet) tall, in which salinity due to oceanderived salt is below 0.5 percent.

4-39

•

Estuarine subtidal unconsolidated bottom (E1UB), which includes deepwater tidal
habitats with continuously submerged substrate. Venture Global defined these areas aswaterbodies (open water).

Three wetland areas were identified at the terminal site consisting of two PEM wetlands
located on the southwestern two-thirds of the site and one wetland area exhibiting a mixture of
PEM and PFO wetlands located on the eastern portion of the site parallel to the Mississippi River.
In addition to the wetlands at the terminal site, four PEM wetlands were mapped within the easternworkspace adjacent to the terminal site. Wetland acreages are shown in table 4.4-1.
For the pipeline system, field surveys were generally conducted within a 400-foot study
corridor to identify and map wetlands along the pipeline system routes. The width of the corridor
was established to accommodate ATWS and any subsequent route refinements for construction
rights-of-way. A reduced corridor width was used for portions of the pipeline system routes
collocated with foreign utilities. In these areas, the survey corridor was offset from the collocatedutility on the side along which the new pipeline would be installed. Within the construction
footprint of the pipeline system, table 4.4-2 identifies wetland acreages along the pipeline system.
4.4.2

Wetlands Impacts and Mitigation

4.4.2.1 LNG Terminal
Construction of the LNG terminal would result in the permanent filling of wetlands,
including impacts on wetlands within the eastern workspace as shown in table 4.4-1. All acres ofpermanent impacts as a result of permanent fill would be to PEM wetlands. In addition, PFO
wetlands would be permanently converted to PEM/PSS wetlands (see table 4.4-1).
In addition to permanent impacts at the terminal site, temporary impacts would be required
to construct the terminal facilities. These temporary impacts include PEM wetlands PFO wetlands.
Once construction is complete, these areas of temporary impacts would be restored. Venture
Global avoided impacts on 33.0 acres of on-site wetlands, including 18.5 acres of PEM wetlands
and 14.5 acres of PFO wetlands, as part of its site selection process.
Construction at the terminal site has the potential to have secondary and indirect impacts
on adjacent wetlands. Implementation of protective measures in the Project-specific Plan andProcedures, the SPCC Plan, and the SWPPP, including erosion and sediment controls, would
minimize the effects to adjacent wetlands.

4-40

Table 4.4-1
LNG Terminal Wetland Impacts
CowardinClassificationa

Permanent
Loss

Permanent
Conversion

Temporary Impacts

WET001

PEM

259.3

0.0

3.2

WET002

PEM

80.8

0.0

0.0

WET003

PFO

0.0

2.8

7.5

WET003

PEM

0.0

0.0

1.3

340.1

2.8

12.0

Wetland ID
Terminal

Subtotal
Eastern Workspace

a

wl101

PEM

18.6

0.0

0.0

wl102

PEM

4.0

0.0

0.0

wl103

PEM

2.4

0.0

0.0

wl104

PEM

3.0

0.0

0.0

Subtotal

28.0

0.0

0.0

TOTAL

368.1

2.8

12.0

PEM = Palustrine Emergent Wetland, PFO = Palustrine Forested Wetland

Construction of the LNG terminal would impact a substantial amount of wetlands. A
permanent loss of 368 acres of wetlands would occur due to the LNG terminal facilities. As
discussed below, Venture Global would be required to mitigate the impacts on wetlands throughthe USACE’s permitting process. In its September 2017 section 404/10 permit application,
Venture Global proposes to utilize the purchase of credits from mitigation banks as its mitigation
method, which would be finalized as part of the USACE permit. If sufficient mitigation bankcredits are not available to satisfy the mitigation requirements, Venture Global proposes to utilize
a combination of mitigation bank credits and in-lieu program fees to satisfy wetland mitigation
requirements. The permanent impacts would be primarily on wetlands within former pasture areas.
These wetlands have been ditched and drained to facilitate agriculture use. This alteration has
reduced the wetland function. These ditched wetlands are relatively common within fastland areasin the region. We conclude that wetland impacts would not be significant, and the impacts on
wetlands would be further reduced with Venture Global’s proposed wetland mitigation.
4.4.2.2 Pipeline System
Construction and operation of the pipeline system would result in the permanent filling of
ESS wetlands and PSS wetlands. These permanent impacts are necessary to construct the mainline
valves, permanent access road to the mainline valves, and portions of the pipe trestle over the leveenear Lake Hermitage Road, although some impacts are avoided by the HDD into the LNG terminalsite. Additionally, establishment of metering station platforms would encompass a total area of
2.4 acres within open waters. As these platforms would be installed on elevated piles, the actual
footprint of disturbance would be considerably less. In addition to the permanent impacts,
construction of the pipeline system would result in temporary impacts on wetlands and open water.
See table 4.4-2 for a breakdown of acreages by wetland type.

4-41

Although the FERC Procedures specify a maximum pipeline construction right-of-way
width of 75 feet in wetlands, an increase in the width can be approved if the applicant provides
site-specific justifications. Venture Global has requested and provided justification for a 130-footwide pipeline construction right-of-way for portions of the pipeline where direct push installation
would be utilized and a 300-foot-wide pipeline construction right-of-way for portions of thepipeline where the barge lay method would be utilized. We have reviewed the Project-specificProcedures and agree with Venture Global’s justification for an increased construction right-ofway width. No permanent disturbance or right-of-way clearing would occur between HDD entry
and exit pits. The FERC Procedures require Venture Global to restore preconstruction wetland
contours to maintain the original wetland hydrology and to return all waterbody banks topreconstruction contours or to a stable angle of repose as approved by the EI.
To avoid the creation of linear channels of open water within the marshes, the LDWF
requests that Venture Global install bank line stabilization material at the interface of marsh andopen water. Venture Global would coordinate with the LDWF, USACE, and LDNR to identify
bank stabilization specifications and the specific locations to be installed as part of the ongoing
review of the Project’s applications for a CWA Section 404 Permit and a CUP.
Ground-disturbing activities, including the clearing of temporary workspaces andexcavation of the pipeline trench and flotation canals, could temporarily affect the rate anddirection of water movement within wetlands. If contours and elevations are not properly restored,
these effects could adversely impact wetland hydrology and revegetation by creating soil
conditions that may not support wetland communities and hydrophytic vegetation at preconstruction levels. Mixing of soil layers could alter the biological components and affect thereestablishment of native wetland vegetation. The temporary stockpiling of soil and the movementof heavy machinery across wetlands could lead to inadvertent compaction and furrowing of soils,
which could alter natural hydrologic patterns, inhibit seed germination, and increase seeding
mortality. Heavy machinery could also introduce non-native and invasive species to the disturbed
soil. Altered surface water flow patterns, stormwater runoff, runoff from disturbed areas, andaccidental spills could also negatively affect wetland regeneration.
During the draft EIS comment period, the LDWF requested that Venture Global install a
culvert every 500 feet under access roads in wetlands. Venture Global would install one permanent
access road within wetlands to reach the mainline valve site located adjacent to Hermitage Road
and would install a culvert at this location per the LDWF’s request. The remainder of thepermanent access roads associated with the Project are located in upland areas; however, Venture
Global would install culverts where necessary to maintain existing drainage.
During and following construction, Venture Global would ensure that impacts areappropriately addressed through adherence to permit conditions and implementation of theprotective measures in the Project-specific Plan and Procedures, construction SWPPP, and SPCC
Plan. Protective measures include:•

minimizing vegetation clearing and disturbance;•

avoiding unnecessary vehicular traffic and equipment;

4-42

•

installing and maintaining erosion and sedimentation control devices;•

restricting the duration of construction, to the extent practicable;•using timber construction mats to create a temporary work surface in wet conditions; and•using low-pressure ground equipment in wet conditions to minimize vegetation damage,soil compaction, and rutting.

During the draft EIS comment period, the LDWF requested that Venture Global use dredged
material from the barge access channels to create/restore or nourish emergent marsh. However,the barge access channels would be constructed using a clam shell dredge, allowing the dredged
material to be sidecast adjacent to the channel and used to backfill the channel following
installation of the pipelines, as such, the spoil material would only be temporarily displaced. The
permanent displacement of dredged materials associated with the barge access channels where theprop-washing method would be employed would involve less than 25,000 cubic yards of dredged
material. This permanently displaced material would be spread out along the barge access channel
system. We conclude that this is not practical due to the relatively small volume of material andthe logistical challenges and increased environmental impacts of collecting and transporting thematerial.

4-43

Table 4.4-2
Summary of Wetlands on the Pipeline System (acres), Pipeline System Wetland Impacts
EEM

ESS

PEM

PSS

Open Water

Total

Temp

Perm

Temp

Perm

Temp

Perm

Temp

Perm

Temp

Perm

Temp

Perm

22.4

0.0

1.0

0.0

0.1

0.0

1.1

0.0

108.2

0.0

132.8

0.0

Aboveground Facilities

0.0

0.0

0.0

0.4

0.0

0.0

0.0

<0.1

0.0

2.4

0.0

2.8

ATWS

29.3

0.0

1.9

0.0

<0.1

0.0

1.2

0.0

394.8

0.0

427.2

0.0

Access Road

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

Access Channels

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

322.6

0.0

322.6

0.0

51.7

0.0

2.9

0.4

0.1

0.0

2.3

<0.1

825.6

2.4

882.6

2.8

Pipeline Facilities

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

ATWS

12.8

0.0

0.6

0.0

0.0

0.0

0.0

0.0

51.1

0.0

64.5

0.0

Subtotal

12.8

0.0

0.6

0.0

0.0

0.0

0.0

0.0

51.1

0.0

64.5

0.0

TOTAL

64.5

0.0

3.5

0.4

0.1

0.0

2.3

<0.1

876.7

2.4

947.1

2.8

Southwest Lateral TGP
Pipeline Facilities

SubtotalSouthwest Lateral TETCO

4-44

4.4.3Modifications to the FERC Procedures

As described above, Venture Global proposes to use its Project-specific Procedures bymodifying our Procedures as necessary for this Project. We have reviewed these modifications
and the site-specific justifications and have found the majority of them to be justified, particularly
given the hydrology of the region, and adequately protective of the environment (see appendix C,
table 2). Additional discussion on the most important of these modifications is presented below.
4.4.3.1 Site-specific Justification for Right-of-way Greater than 75 Feet
Section II.A.2 of our Procedures requires site-specific justifications for the use of aconstruction right-of-way greater than 75 feet wide in wetlands. Venture Global states that the
Project requires a 130-foot-wide construction right-of-way for pipeline installation where the pushmethod would be used, due to the need for a relatively wide and deep trench to ensure the required
depth of cover in the wet, poorly cohesive, and easily sloughed substrate, and the consequent needfor increased space to sidecast relatively high spoil volumes. Venture Global further states that
the Project requires a 300-foot-wide construction right-of-way for pipeline installation in open
waters, where the barge lay method would be used, to accommodate an approximately 100-footwide flotation channel for lay barge and supply barge access and up to approximately 100 feet on
either side of the flotation channel for construction workspace to deposit sidecast trench material
for later use in restoration. The 300-foot-wide construction right-of-way would allow for safe andwholly waterborne construction.
We accept that this proposed modification is necessary because the combination of pipe
size, the inundated or saturated soil conditions, and the pervasiveness and extent of wetlands andopen water in the Project area makes the 75-foot-wide right-of-way infeasible. Although therequirement to identify specific wetlands that require more than a 75-foot-wide right-of-way
remains, in this Project area the prevalence of wetlands results in a fairly uniform construction
footprint. As a result, Venture Global proposes to construct the pipelines in a 300-foot-wide rightof-way in open water from TGP MPs 0.0 to 11.3 and TETCO MPs 0.0 to 7.9. The construction
right-of-way width would be reduced to 130 feet when constructing in marshes from TGP MPs
11.3 to 14.3 and TETCO MPs 7.9 to 10.9.
Construction Equipment Staging and Storage of Hazardous Materials
Section IV.A.1.d of our Procedures requires all construction equipment to be parked(overnight) and fueled at least 100 feet from a wetland boundary. In construction locations where
there is no reasonable alternative other than to locate upland refueling sites less than 100 feet fromwetlands or waterbodies, the Project would maintain at least a 10-foot-wide setback. All refuelingand equipment storage procedures, irrespective of proximity to wetlands or waterbodies, would beundertaken in accordance with Venture Global’s SPCC Plan to reduce the potential for spills
during construction and to mitigate the environmental impacts if a spill were to occur.
Section IV.A.1.e of our Procedures requires all hazardous materials (e.g., fuels, oils) to be
stored at least 100 feet from a wetland boundary. Equipment used in wetlands and open water
would often operate at long distances (up to several miles) from the nearest upland refuelingstation. To track the equipment out of the wetland or open water for refueling, possibly on multiple

4-45

occasions, is logistically impractical and potentially more environmentally damaging than
refueling in situ. To minimize the environmental damage caused by excessive tracking, towed
fuel barges would accompany amphibious equipment as construction progresses. Equipment
operators would be fully trained in refueling procedures and Venture Global’s SPCC Plan.
Aboveground Facilities
Section VI.A.6 requires that aboveground facilities not be located in any wetland, except
where the location of such facilities outside of wetlands would prohibit compliance with DOT
regulations. Venture Global states that impacts on wetlands as a result of construction of the
Project’s aboveground facilities would be unavoidable and that all wetlands impacted would beappropriately mitigated. As a result, construction of the aboveground structures would result inno net loss of wetlands.
Extra Work Areas
Section VI.B.1.a requires applicants to locate all extra work areas (such as staging areas
and additional spoil storage areas) at least 50 feet away from wetland boundaries, except where
the adjacent upland consists of cultivated or rotated cropland or other disturbed land. Due to theprevalence of open water and marsh in the Project area, several ATWSs are necessarily located inwetlands and waterbodies. These include ATWSs required at the mainline valve sites and HDD
exit and/or entry locations, set-up sites for push method pipeline installations, bore exit and/or
entry locations, and crossing sites of multiple foreign pipelines. Most of the ATWSs are requiredfor HDD, push method pipeline installations, and bore crossings, methods that have been selected
to minimize or avoid greater environmental impacts elsewhere. Locations where Venture Global
has proposed to place ATWSs in or within 50 feet of wetlands are presented in table 4.4-3.
Table 4.4-3
Proposed Locations of Additional Temporary Workspace within Wetlands
TGP
Approximate
Mileposta

TETCO
Approximate
Milepost

Wetland
ID

ATWS
Size
(acres)8.9

5.6

wlb007e2.7Foreign line
crossing

Wetland expanse characterizes
area. No upland alternative
exists.

14.2

10.7

wlb002e,
wlb002s,
andwlb003s

5.4

Foreign line
crossing

Wetland expanse characterizes
area. No upland alternative
exists.

14.4

11.1

wlb003s
andwlb009s

1.4

Mainline Valve
Site and Lake
Hermitage Road
crossing

Wetland expanse characterizes
area. No upland alternative
exists.

ATWS
PurposeJustificationa All listed ATWS are located within wetlands.

We have reviewed these proposed ATWS locations and conclude this modification has
been adequately justified. Because the majority of the Project area consists of open water andcoastal marsh, siting these ATWS areas in upland areas is not feasible for this Project.
4-46

Access Roads
Section VI.B.1.C of our Procedures requires that all construction equipment, other thanthat needed to install the wetland crossing, shall use access roads located in upland areas. Where
access roads in upland areas do not provide reasonable access, all other construction equipment
shall be limited to one pass through the wetland using the construction right-of-way located inupland areas. Venture Global’s construction is primarily located within wetlands and waterbodies,and certain work areas may require access via the construction right-of-way across wetland areas
or waterbodies. The push method would be used to install portions of the lateral pipelines withlimited equipment traffic crossing the wetlands. At certain locations, such as tie-ins or foreign line
crossings, additional equipment would be required to complete the pipeline installation. To accessthese locations, multiple passes of construction equipment through the wetlands would be required,using the construction right-of-way. Access channels through open water would be used tomobilize construction equipment to install the majority length of the lateral pipelines using thebarge lay method.
Section VI.B.1.D of our Procedures states that the only access roads, other than theconstruction right-of-way, that can be used in wetlands are those existing roads that can be usedwith no modifications or improvements, other than routine repair, and no impact on the wetlands.
The Project would require one new permanent access road to access two mainline valve sites
during Project operation; this road would also be used during construction. The Project would
require one new temporary access road to access the pipe bridge and HDD sites during
construction. Both roads cross some wetlands, but they represent the shortest travel distance tothe sites and, given the extensive wetlands in their area, there are no practicable alternative routes
that would result in less impact on wetlands. All impacts would be appropriately permitted andmitigated in accordance with applicable regulatory requirements.
Section VI.B.2.D requires the applicant to minimize the length of time that topsoil issegregated and the trench is open, and the applicant should not trench the wetland until the pipeline
is assembled and ready for lowering in. The Project would use the push method for portions of
the Southwest laterals, requiring the excavation of the pipe trench prior to pipeline assembly inorder for the assembled pipeline segment to be floated and lowered into the open trench.
Sediment Barriers
Section VI.B.3 of our Procedures states that sediment barriers will be installed immediately
after initial disturbance of the wetland or adjacent upland. Venture Global proposes to install
sediment barriers prior to the initial disturbance of wetlands or adjacent uplands. Subsections A,
B, and C provide additional details regarding the construction of sediment barriers. Venture
Global has accepted these, except in areas where the push method would be used for pipeline
installation. In these areas, Venture Global would not install sediment barriers, as it would be
unnecessary in areas sufficiently inundated to allow push construction.
4.4.4

Compensatory Mitigation

The USACE has a goal of “no net loss” of wetland function in the United States. Thismeans that unavoidable wetland impacts must be offset by the creation, restoration, enhancement,

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or preservation of at least an equal amount of wetlands, which is referred to as compensatory
mitigation.
As discussed in section 4.4.2.1, construction and operation of the LNG terminal would
result in the permanent loss of 368.1 acres of PEM wetlands and the conversion of 2.8 acres of
PFO wetlands to PSS/PEM wetlands. Construction and operation of the pipeline system would
result in the permanent loss of 0.4 acre of wetland.
As required by 33 CFR 332.3, Venture Global proposes compensatory mitigation that iscommensurate with the amount and type of wetland impacts resulting from construction andoperation of the Project. There are three mechanisms for providing compensatory mitigation:
permittee-responsible compensatory mitigation, mitigation banks, and in-lieu fee mitigation. As
part of the section 10/404 process, Venture Global is developing a Compensatory Mitigation Plan
to mitigate unavoidable wetland impacts. Venture Global proposes to use mitigation banks, an inlieu fee program, permittee-responsible mitigation, or a combination of the three to mitigate forthe wetland impacts of the Project. The plan would be subject to the review and approval by the
USACE, New Orleans District, as part of the section 10/404 process. We would require that all
federal authorizations, including these permits, be received prior to construction of the Project.
Construction of the pipeline facilities would temporarily impact 947 acres of wetlands andopen water; however, only 2.8 acres would be permanently impacted by the pipeline. The pipeline
would be constructed according to Venture Global’s Procedures and any other applicable permit
conditions. Temporarily impacted wetlands would be restored and monitored until restoration is
successful. As discussed above, Venture Global would mitigate the impacts on wetlands throughthe USACE permitting process. We conclude that wetland impacts from pipeline construction
would not be significant, and would be further reduced with the proposed mitigation.

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4.5

VEGETATIONThe LNG terminal and the pipeline system would be situated in the Deltaic Coastal
Marshes and Barrier Islands Level IV Ecoregion, within the larger Mississippi Alluvial Plain(EPA, 2013). The Deltaic Coastal Marshes and Barrier Island Ecoregion is described as a mix ofbrackish and saline marshes and areas that are inundated by water.
The Louisiana Natural Heritage Program (LNHP) of the LDWF recognizes 68 naturalcommunities in Louisiana. Elements of the Project, specifically the LNG terminal berthingfacilities and the pipeline system, traverse habitats that exhibit characteristics that are consistent
with several of these natural communities, including batture, saltmarsh, brackish marsh, intertidal
mollusk reef, bay, tidal channel/creek, and coastal live oak-hackberry forest. In addition to thesenatural areas, the majority of the terminal site and portions of the pipeline system have beensignificantly altered by levees and drainage ditches/canals to create fastlands for agricultural use,and portions of the pipeline system traverse man-made navigation channels.
4.5.1

Existing Vegetation Resources

4.5.1.1 LNG Terminal
The terminal site is located on the western bank of the Mississippi River, with a majorityof the site located within fastlands. As defined by OCM, fastlands are lands surrounded by publicly
owned, maintained, or otherwise validly existing levees or natural formations that would normally
prevent activities within the surrounding area from having direct and significant impacts on coastal
waters.
The terminal site and properties bordering the site were historically used for agricultural
purposes, which is classified as cultivated crops in National Land Use Land Cover data. Currently,
the majority of the terminal site consists of fallow grassland and cattle pasture that is bisected bya series of man-made drainage ditches and drainage canals. These fallow grasslands and cattle
pasture fall within the cultivated crops National Land Use Land Cover data classification in section
4.8.1. The segments of the terminal site that are south of SH 23 consists of herbaceous vegetative
cover, and the area of the terminal site north of SH 23 consist of a mix of herbaceous areas,
scrub/shrub areas, and forested areas. The Mississippi River and coastal marsh are the primary
habitat types surrounding the fastlands (or fallow grassland and cattle pasture) where the terminalsite is located. Table 4.5-1 presents the habitat communities within the Project area based on fieldsurveys. Land use and land cover impacts are discussed in section 4.8.1 and table 4.8-1.

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Table 4.5-1
Habitat Communities Affected by Construction and Operation of the LNG Terminal and Pipeline System(in acres)
Habitat Community

Construction Impacts

Operational Impacts

LNG Terminal Site, Water-based Marine Facilities, and LNG Terminal Workspaces
Palustrine emergent wetland (pasture)

369.4

368.1

Palustrine forested wetland (batture)

10.3

4.1a

Forested/scrub-shrub upland

85.7

82.6

Herbaceous upland (pasture)

158.9

151.2

624.3

606.0b

Subtotal
Pipeline System
Palustrine emergent wetland

0.1

0.0

Palustrine scrub-shrub wetland

2.3

<0.1

Estuarine emergent wetland

64.6

0.0

Estuarine scrub-shrub wetland

3.9

0.4

Forested/scrub-shrub upland

0.0

0.0

Coastal live oak-hackberry forest (upland)

4.0

1.7

Subtotal

74.9

2.2c

TOTAL

699.2

608.1

a The 2.8 acres of operational impacts are conversion of the PFO habitat to PSS/PEM habitat and not permanent fill.
b The operational impact acreage of the terminal site is 636.5 acres; however, the entire operational area is not vegetated. Only 606.0 acresof the operational boundary are currently vegetated. The remaining 30.5 acres consists of open water or Mississippi River and developed
commercial/industrial land that is not vegetated.
c The operational impact acreage for the pipeline system only includes permanent impacts from aboveground facilities and 1.7 acres offorested habitat that would be converted to maintained right-of-way. The remainder of the pipeline system would either be in uplandherbaceous/scrub-shrub habitats, developed commercial/industrial land, or open water habitats.

Palustrine emergent wetland areas within the terminal site and adjacent workspace
primarily consists of fallow pasture. These areas are located in the southwestern two-thirds of the
Project area, south of SH 23. Venture Global suggests that the wetland hydrology for these areas
appears to be a result of poorly maintained drainage ditches within the fastlands drainage system.
According to Venture Global, the lack of maintenance has allowed these pasture areas to revert towetlands. Species observed in these areas during field surveys include bigpod sesbania (Sesbania
herbacea), eastern baccharis (Baccharis halimifolia), alligatorweed (Alternanthera philoxeroides),Bermuda grass (Cynodon dactylon), common rush (Juncus effuses), swamp smartweed (Persicaria
hydropiperoides), mountain spikerush (Eleocharis montana), salt meadow cord grass (Spartina
patens), great ragweed (Ambrosia trifida), coco yam (Colocasia esculenta), peppervine(Ampelopsis arborea), American buckwheat vine (Brunnichia ovata), and broadleaf cattail (Typha
latifolia).
Palustrine forested wetlands within the terminal site are adjacent to the Mississippi Riverand consist of batture. Batture is a riverfront pioneer forest that occurs on newly formed sand bars
and river margins between the natural levee crest and major streams/rivers. Canopy species
observed in these areas during field surveys include black willow (Salix nigra), hackberry (Celtis
laevigata), and American sycamore (Platanus occidentalis).

4-50Forested scrub-shrub uplands at the terminal site occur on the northeastern portion of thesite between SH 23 and the Mississippi River levee. The forested portions of this vegetation
community consist of a woody canopy of green ash (Fraxinus pennsylvanica) greater than 20 feetin height with an understory of winged sumac (Rhus copallinum), poison ivy (Toxicodendronradicans), hyssopleaf thoroughwort (Eupatorium hyssopifolium), peppervine, muscadine (Vitus
rotundifolia), southern dewberry (Rubus trivialis), and log fern (Dryopteris celsa). The scrubshrub portion of this vegetation community consisted of woody shrubs less than 20 feet in heightthat consisted of Chinese tallow (Triadica sebifera), winged sumac, American beautyberry, black
willow, green ash, and sawtooth blackberry (Rubus argutus) with a herbaceous understory thatconsisted of common carpet grass (Axonopus fissifolius), eastern woodland sedge (Carex blanda),
and giant goldenrod (Solidago gigantean).
Herbaceous uplands (pasture) at the terminal site are located in the southwestern portionof the terminal site (south of SH 23). The vegetation composition is similar to the palustrine
emergent wetlands described above. The dominant species observed consisted of rice button aster(Symphyotrichum dumosum), Bermuda grass, swamp smartweed, yellow foxtail (Setaria pumila),bahiagrass (Paspalum notatum), and great ragweed.
4.5.1.2 Pipeline System
The majority of the pipeline system is located in the Barataria Basin estuary system. Thisbasin is bounded on the north and east by the Mississippi River, on the west by Bayou Lafourche,and on the south by the Gulf of Mexico (Lester, 2005). The Barataria Basin largely consists ofbottomland hardwoods and fresh to brackish marshes. Vegetation communities crossed by thepipeline system include palustrine emergent wetlands (within fastlands near the LNG terminal),palustrine scrub-shrub wetlands (also within fastlands near the LNG terminal), estuarine emergent
wetlands, estuarine scrub-shrub wetlands, and coastal live oak-hackberry forest.
The palustrine emergent wetlands along the pipeline system route are located adjacent to
the terminal site within the fastlands system at Southwest Lateral TGP MP 14.4 and Southwest
Lateral TGP MP 14.6. The vegetation within these areas is primarily herbaceous species
consisting of Bermuda grass, bigpod sesbania, salt meadow cord grass, salt grass (Distichlis
spicata), and common spikerush (Eleocharis palustris). Hydrology in these areas has been alteredby ditching, pumping, and levees.
The palustrine scrub-shrub wetlands along the pipeline system route are within 0.5 mile of
LNG terminal within the fastlands system at Southwest Lateral TGP MP 14.8. The dominant
vegetation within these areas consists of maritime marsh elder (Iva frutescens), eastern baccharis,
rattlebush (Sesbania drummondii), and Chinese tallow.
The estuarine emergent wetlands along the pipeline system route frequently occur between
Southwest Lateral TGP MP 8.7 and Southwest Lateral TGP MP 14.3. This vegetative community
type includes areas of salt marsh and areas of brackish marsh, which are both considered naturalcommunities by the LDWF. The primary species observed in salt marsh areas include smooth
cord grass (Spartina alterniflora), salt meadow cord grass, salt grass, and black rush (Juncus
roemarianus). The primary species observed in brackish marsh areas include saltmarsh bulrush(Schoenplectus robustus), smooth cord grass, salt grass, and salt meadow cord grass.

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Estuarine scrub-shrub wetlands infrequently occur along the pipeline system route.
Estuarine scrub-shrub wetlands are located at Southwest Lateral TGP MP 12.0 and from Southwest
Lateral TGP MP 14.1 to Southwest Lateral TGP MP 14.3. This community consists of Jesuit’s
bark (Iva frutescens) and groundsel tree (Baccharis halimifolia). Other plants found to a lesser
degree in these systems include dwarf palmetto (Sabal minor), deciduous holly (Ilex decidua),
yaupon (I. vomitoria), and lantana (Lantana camara). In some instances, saplings and trees arefound in the estuarine scrub-shrub wetlands delineated within the survey area. These saplings andtrees include sugarberry (Celtis laevigata), live oak (Quercus virginiana), water oak (Q. nigra),
sweetgum (Liquidambar styraciflua), and Chinese tallow. There is one area of coastal live oakhackberry forest along the pipeline system route from approximately Southwest Lateral TGP MP
14.5 to Southwest Lateral TGP MP 14.6. This vegetation community is considered a naturalcommunity by the LDWF. The dominant canopy species include live oak (Quercus virginiana),
water oak (Quercus nigra), and hackberry, with an understory of dwarf palmetto (Sabal minor)
and eastern baccharis.
The majority of the pipeline system is located in estuarine open water, which occurs
frequently from Southwest Lateral TGP MP 0.0 to Southwest Lateral TGP MP 13.8. This
community is basically devoid of vegetation. Field surveys were conducted for submerged aquaticvegetation along the pipeline route and barge access channels; however, no submerged aquaticvegetation was encountered. The portions of the pipeline system mapped as estuary open waterconsist of intertidal mollusk reefs (oyster leases crossed by the pipeline system), bays, and tidal
channels/creeks, which are all considered natural communities by the LDWF, as well as man-madenavigation channels, canals, and existing pipeline rights-of-way.
4.5.2

Construction and Operation Impacts and Mitigation

As summarized in table 4.5-1, a total of 699.2 acres of vegetation would be cleared during
construction of the LNG terminal and pipeline system. In addition, there would be 104.4 acres ofimpacts on open water at the LNG terminal (Mississippi River, streams, and canals) and
879.1 acres of impacts on estuarine open water along the pipeline system; however, these would
not require any vegetation to be cleared and thus are not included in table 4.5-1. Following
construction, 606.0 1 acres at the LNG terminal and 2.2 acres along the pipeline system of formerly
vegetated areas would be converted to operational areas. About 18.3 acres of temporary impacts
on vegetative communities at the LNG terminal site would be restored following construction, andabout 72.2 acres of temporary impacts on vegetated communities within the pipeline system would
be restored following construction.
4.5.2.1 LNG Terminal
A total of 624.3 acres of vegetation would be cleared during construction at the terminalsite (see table 4.5-1). Following construction, the majority of the vegetation at the terminal(606.0 acres) would be permanently converted to industrial use associated with operation of the1

The operational impact acreage of the terminal site is 621.9 acres of land and 14.6 acres of water based facilities;
however, the entire operational area is not vegetated. Only 606.0 acres of the operational boundary are currently
vegetated. The remaining 30.5 acres consists of waterbodies or developed commercial/industrial land that is notvegetated.

4-52

facility, resulting in the permanent loss of wetland pasture, batture, shrub/shrub, forested upland,
and herbaceous upland pasture.
Construction at the terminal site would result in temporary impacts on 1.3 acres ofpalustrine emergent wetlands and 7.5 acres of palustrine forested wetlands. These areas would berestored post-construction according to Venture Global’s Project-specific Plan and Procedures.
The majority of impacts on wetlands would be permanent, resulting in the loss of 368.1 acres ofpalustrine emergent wetlands and 4.1 acres of palustrine forested wetlands (batture) conversion topalustrine scrub-shrub/palustrine emergent wetlands. Venture Global is coordinating with
USACE regarding the jurisdictional status of palustrine wetlands at the terminal site. It appears
that these wetlands are a result of poorly maintained drainage ditches and fastland pumping
systems. Mitigation for the loss of these palustrine emergent wetlands will be determined once
coordination with the USACE is complete and permits have been issued. The conversion of thepalustrine forested wetlands would be fully mitigated through implementation of Venture Global’sCompensatory Mitigation Plan, which will require review and approval by the USACE New
Orleans District. For a discussion of wetland mitigation, see section 4.4.4.
Venture Global’s implementation of its Project-specific Plan and Procedures, which
require the use of temporary and permanent erosion control measures, revegetation procedures,and post-construction monitoring, would further minimize impacts on vegetation communities
within and adjacent to the terminal. Due to the limited vegetation diversity within the terminalsite due to the nature of the land relative to the flood levee, we have determined that impacts onvegetation from construction and operation of the LNG terminal would be permanent, but minor.
4.5.2.2 Pipeline System
Wetland fragmentation would be minimized by routing the pipeline system through open
water, where feasible. In emergent wetlands, vegetation within the construction workspace would
be impacted during construction but would not be purposely cleared, other than through trench
excavation. In forested areas, trees that must be removed would be cut flush with the ground,leaving the root system intact to minimize erosion, except in areas where root removal is required
to create a safe and level work surface. Clearing and grading operations would incorporate
procedures to:•minimize vegetation removal from slopes, wetlands, and channel banks;•

prevent undue soil disturbance;•

restore ground contours to their original condition; and•prevent topsoil erosion.

The pipeline system’s permanent impacts on vegetation are associated with abovegroundfacilities and permanent access roads. The permanent pipeline right-of-way would be kept clearof trees in two 30-foot-wide corridors over each pipeline inside of the 80-foot-wide permanentright-of-way. Due to the operational needs of the pipeline system, <0.1 acre of palustrine emergent
wetlands, 0.4 acre of estuarine emergent scrub-shrub wetlands, 1.7 acres of coastal live oak-4-53

hackberry forest would be permanently impacted by aboveground facilities and/or converted to a
maintained herbaceous state as part of the operational right-of-way. Additionally, 2.4 acres ofopen water would be shaded by aboveground facilities.
Collocation of the pipelines would minimize impacts on vegetation communities during
construction and operation of the pipeline system. Venture Global would implement its Projectspecific Plan and Procedures, which require the use of temporary and permanent erosion control
measures, topsoil segregation in select areas, testing and mitigation for soil compaction, postconstruction monitoring, and limited routine vegetation maintenance. All disturbed areas would
be routinely monitored in accordance with the Project-specific Plan and Procedures until
restoration and revegetation are successful.
With the implementation of the minimization efforts described above, we conclude that
construction and operation of the pipeline system would have a permanent, but minor, impact onvegetation communities.
4.5.3

Exotic or Invasive Plant Communities and Noxious Weeds

Exotic plant communities, invasive species, and noxious weeds can out-compete anddisplace native plant species, thereby negatively altering the appearance, composition, and habitat
value of affected areas. In accordance with the Plant Protection Act of 2000 (7 U.S.C. 7701), 13
plants that could occur in Louisiana have been federally listed as noxious weeds (USDA NRCS,
2017), and one plant (Chinese tallow) has been designated as a noxious weed by the State ofLouisiana (Louisiana Revised Statutes 3:1791).
Aquatic invasive species have been identified in the Barataria Basin and may occur in the
Project area. These species include water hyacinth (Eichhornia crassipes), alligatorweed,common salivinia (Salvinia minima), and giant salvinia (Salvinia molesta) (LDWF, 2015a;
Tulane/Xavier Center for Bioenvironmental Research, 2010). Field surveys at the terminal site
and along the pipeline system route did not directly target invasive species; however, invasive
exotic species were identified during the wetlands and waterbody field surveys. Surveys at theterminal site identified alligatorweed and Chinese tallow, and surveys along the pipeline systemroute identified Chinese tallow and lantana.
Venture Global would implement the Project-specific Plan and Procedures during
construction and post-construction, which would include monitoring to ensure that ground
disturbance and restoration activities minimize the spread of invasive species and noxious weeds.
Section III.F.2 of the Project-specific Plan requires the development of specific procedures incoordination with the appropriate agencies to prevent the introduction or spread of invasive
species, noxious weeds, and soil pests resulting from construction and restoration activities.
Venture Global has submitted a draft Noxious Weed and Invasive Plant Species
Management Plan to the NRCS and LDWF for review. The Noxious Weed Plan was accepted by
the agencies and includes the following mitigation measures:•training EI and construction staff in the identification of noxious weeds andinvasive species;

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4.5.4•cleaning construction equipment of vegetative debris when mobilizing;•

identifying and field marking of noxious weed locations;•applying targeted herbicide or removal of noxious weeds;•

using weed-free materials for erosion control devices; and•monitoring restoration activities.

Vegetative Communities of Special Concern

Vegetation communities of special concern may include ecologically important naturalcommunities, threatened or endangered plant species, or other rare or imperiled plants in need of
special protection or minimal disturbance.
Existing LNHP data (LNHP, 2015a), indicate that the pipeline system route would traverse
an area of coastal live oak-hackberry forest. Observations during field surveys indicate that thepipeline system route traverses approximately 1,000 feet of this community (roughly between MPs
14.4 and 14.6 of the Southwest Lateral TGP). Coastal live oak-hackberry forest is consideredimperiled with a state ranking 2 of S1S2 (critically imperiled/imperiled) and a global ranking of G2(imperiled). This natural community is formed on abandoned beach ridges in coastal Louisiana.
These areas serve as important storm barriers and important wildlife habitat, providing vital resting
habitat for trans-gulf-migrating birds. Of the 100,000 to 500,000 acres in Louisiana, only 2,000
to 10,000 acres remain (2 percent to 10 percent of pre-settlement extent). Threats to thiscommunity include residential development, road and utility construction, overgrazing, and theintroduction of invasive exotic species (LDWF, n.d.[a]).
Field surveys mapped 4.0 acres of coastal live oak-hackberry forest within the footprint of
the pipeline system. Of the 4.0 acres, 1.6 acres would be avoided by HDD, 0.7 acre would have a
temporary impact and allowed to recover after construction, and 1.7 acres would be permanently
converted from coastal live oak-hackberry forest to herbaceous uplands. Impacts on thisvegetation community are unavoidable, as the non-federal levee immediately adjacent to the southof this community would be crossed via a pipe bridge to avoid impacts on the non-federal levee.
To allow space for the pipe bridge, the pipeline system would impact a small portion of the coastal
live oak-hackberry forest to establish an HDD site. From the HDD drill site to the LNG terminal,
the pipeline system would be installed beneath the remaining area of coastal live oak-hackberry
forest within the Project footprint via HDD. Traversing a portion of this community via HDD
minimizes impacts on this habitat type and reduces fragmentation of the community. While
1.7 acres would be permanently impacted, the impacts would be 1.4 percent of the coastal live
oak-hackberry stand traversed by the pipeline system.
In addition to the coastal live oak-hackberry natural community, six other naturalcommunities of Louisiana occur within the Project area. These include batture (terminal site),
saltmarsh (pipeline system), brackish marsh (pipeline system), intertidal mollusk reef (pipeline2

Based on NatureServe Conservation Status Ranks: S=State, G=Global, 1=Critically Imperiled, 2=Imperiled,
3=Vulnerable, 4=Apparently Secure, and 5=Secure.

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system), bay (pipeline system), and tidal channel/creek (pipeline system). The intertidal mollusk
reef, bay, and tidal channel/creek natural communities are mostly unvegetated and are discussed
further in section 4.6.1.
The batture habitat rarity rank for the state is S4S5 (apparently secure/secure), and theglobal ranking is G4/G5 (apparently secure/secure). This habitat type provides important wildlife
habitat and serves to minimize erosion along major river channels. While important, thiscommunity is not rare in the state or globally.
Salt marsh has a state rarity ranking of S3/S4 (vulnerable/apparently secure) and a global
ranking of G5 (secure). Brackish marsh has a state rarity ranking of S3S4 (vulnerable/apparently
secure) and a global ranking of G4 (apparently secure). While globally secure, these habitat types
are vulnerable in south Louisiana due to threats such as:•

shoreline erosion and subsidence;•commercial and industrial development;•

construction of roads, pipelines, and utilities;•hydrologic alteration (channelization, levee construction, and dredging);•

contamination from spills and industrial discharge;•

fire suppression; and•invasive exotic species.

The pre-settlement extent of marshland in Louisiana is estimated to be 500,000 to
1,000,000 acres. Currently, approximately 50 to 75 percent of the pre-settlement marsh remains(LDWF, n.d.[b], n.d.[c]). To minimize impacts on salt marsh and brackish marsh, Venture Global
routed the pipeline system in open water, where feasible (over 90 percent of the pipeline system
impacts are in open water). Additionally, to avoid the creation of linear channels of open water
within the marshes, the LDWF requests that Venture Global install bank line stabilization material
at the interface of marsh and open water. Venture Global would coordinate with the LDWF,
USACE, and LDNR to identify bank stabilization specifications and the specific locations to beinstalled as part of the ongoing review of the Project's applications for a CWA Section 404 Permit
and a CUP.

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4.6

WILDLIFE AND AQUATIC RESOURCES

4.6.1

Wildlife Resources

Wildlife species occurring in the vicinity of the LNG terminal and pipeline system arecharacteristic of the habitats provided by the vegetative communities that occur in these areas.
Section 4.5.1 provides detailed information on the vegetative communities present in the vicinityof the Project based on National Land Use Land Cover data. Habitat types were identified basedon aerial photography and field surveys. These habitat types are not the same as the National Land
Use Land Cover data described in sections 4.8.1, although some naming conventions overlap.
Aquatic resources and protected wildlife species are discussed in sections 4.6.3 and 4.7,
respectively.
4.6.1.1 Existing Wildlife Habitats
The wildlife habitat types present in the vicinity of the LNG terminal and pipeline system
include herbaceous wetlands, scrub-shrub wetlands, forested wetlands, herbaceous uplands(pasture), scrub-shrub uplands, forested uplands, and open water. Typical wildlife occurring
within these habitat types are described below.
Wetlands typically support a diverse ecosystem that provides nutrients, cover, shelter, andwater for a variety of terrestrial and aquatic wildlife species, including waterfowl, wading birds,
raptors, mammals, reptiles, and amphibians. Typical wildlife associated with palustrine wetlands
include white-tailed deer (Odocoileus virginianus), raccoon (Procyon lotor), river otter (Lutra
canadensis), rice rat (Oryzomys palustris), swamp rabbit (Sylivagus aquaticus), wood duck (Aixsponsa), least bittern (Ixobrychus exilis), green heron (Butorides striatus), red-winged blackbird(Agelains phoeniceus), southern leopard frog (Rana utricularia), bullfrog (Rana catesbeiana),
cottonmouth (Agkistrodon piscivorus), and mud snake (Farancia abacura). Typical wildlife
associated with estuarine emergent wetlands include raccoon, rice rat, nutria (Myocaster coypus),
brown pelican (Pelecanus occidentalis), great blue heron (Ardea herodias), green heron, fiddler
crab (Uca rapax), and salt marsh snake (Nerodia clarkia) (LDWF, 2014a, 2014b, 2014c; USGS,
2013b).
Herbaceous upland habitat is present at the LNG terminal site and consists of fallow pasturelands. No herbaceous uplands were identified along the pipeline system. Mammals typicallyassociated with herbaceous upland habitat include white-tailed deer, striped skunk, spotted skunk(Spilogale putorius), cotton mouse, armadillo (Dasypus novemcinctus), raccoon, and eastern
harvest mouse (Reithrodontomys humulis). Bird species include common yellowthroat(Geothlypis trichas), northern bobwhite, eastern bluebird (Sialia sialis), dickcissel (Spiza
americana), rusty blackbird (Euphagus carolinus), red-tailed hawk (Buteo jamaicensus), northernharrier (Circus cyaneus), American robin (Turdus migratorius), cattle egret (Bubulcus ibis), andred-winged black bird. Typical reptiles and amphibians include chorus frog (Psuedacris spp.),western rat snake (Pantherophis obsolete), and garter snake (LDWF, 2014a, 2014b, 2014c; USGS,
2013b).
Forested and scrub-shrub upland habitat is present at the LNG terminal site between SH 23
and the Mississippi River. Forested upland habitat is present along the pipeline system between

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approximately TGP MPs 14.4 and 14.7. Scrub-shrub wetland habitat is present along the pipeline
system at TGP MP 14.7 (small area) and from TGP MP 14.2 to TGP MP 14.4. Tree and shrub
layers provide shelter and foraging habitat for various bird species and larger mammals. Organic
material on the forest floor provides habitat for invertebrates, reptiles, smaller mammals, andamphibians. Mammals typically associated with forest habitat in the vicinity of the LNG terminaland pipeline system include white-tailed deer, gray fox (Urocyon cinereoargenteus), gray squirrel(Sciurus carolinensis), cotton mouse (Sigmodon hispidus), and striped skunk (Mephitis mephitis).
Typical bird species include prothonotary warbler (Protonotaria citrea), wood thrush (Hylocichla
mustelina), red-shouldered hawk (Buteo lineatus), Carolina chickadee (Parus carolinensis),loggerhead shrike (Lanius ludovicianus), eastern kingbird (Tyrannus tyrannus), brown-headed
nuthatch (Sitta pusilla), pine warbler (Dendroica pinus), Northern bobwhite (Colinus virginianus),
and tufted titmouse (Parus bicolor). Amphibians and reptiles include the green tree frog (Hylacinerea), garter snake (Thamnophis sirtalis sirtalis), racer (Coluber constrictor), and pigmy
rattlesnake (Sisstrurus miliarius) (LDWF, 2014a, 2014b, 2014c; USGS, 2013b).
Open water present within the LNG terminal site includes the Mississippi River and several
drainage ditches and canal that are part of the fastlands system. Estuarine open water present
within the pipeline system is extensive and consists of tidal channels, navigation channels, andbays. Typical wildlife associated with open water habitat includes wading birds, waterfowl, nutria,
and other wildlife species dependent on a water environment (see additional discussion in sections
4.6.1.1).
4.6.1.2 Impacts and Mitigation
Construction of the LNG terminal would require vegetation clearing, grading, and fillingto level the site. Construction of the LNG terminal would affect over 600 acres of vegetatedwildlife habitat and approximately 100 acres of open water habitat (see table 4.5-1), which would
result in a permanent reduction of these habitat types in the general vicinity of the LNG terminal.
Due to the site’s previous use as fallow pasture, vegetation species diversity is low, which lessens
its value as habitat for wildlife.
Impacts on wildlife from construction of the LNG terminal would include displacement,
stress, and direct mortality of some individuals. Vegetation clearing would potentially reduce
suitable cover, nesting, and foraging habitat for some ubiquitous wildlife species. More mobile
wildlife, such as birds and larger mammals, may relocate to similar habitats nearby whenconstruction activities commence. However, smaller, less mobile wildlife (e.g., reptiles andamphibians) could be inadvertently injured or killed by construction equipment. The permanent
reduction in available habitat within the LNG terminal, as well as the influx of individuals to othernearby areas, may increase population densities for certain species, resulting in increased interand intra-specific competition and reduced reproductive success of individuals.
Pilings would be installed during LNG terminal construction using impact hammer
methods. Noise from pile-driving activities has the potential to alter wildlife behavior, including
foraging and nesting activities within the Project area. Pile-driving noise would be intermittent
and temporary, and preparatory activities likely would encourage mobile species to leave theimmediate area prior to pile driving commencing. Less mobile species would be subject to noise
effects. During construction, Venture Global would implement noise mitigation measures to
4-58

reduce potential impacts on the human environment and wildlife from pile-driving activities.
These measures may include use of one or more of the following:•ramp-up procedures at the beginning of each pile installation or when a delay of
15 minutes or more has occurred; and/or•a cushioning system to reduce noise and maintain effectiveness of pile driving.

Throughout construction and operation of the LNG terminal, Venture Global would follow
its Project-specific Plan and Procedures and would implement protective measures for migratory
and colonial nesting bird species. With adherence to the proposed mitigation measures and given
the abundance of suitable habitat in adjacent areas, the impacts on wildlife habitats fromconstruction and operation of the LNG terminal would be adequately minimized.
Wetland habitats support diverse ecosystems that provides nutrients, cover, shelter, andwater for a variety of terrestrial and aquatic wildlife species. Construction and operation of the
LNG terminal would result in the permanent loss of 340 acres of wetlands on the LNG terminalsite. In addition, 28 acres of wetlands within the eastern workspace adjacent to the LNG terminalsite would be permanently filled.
Operation of the LNG terminal would result in increased noise, lighting, and humanactivity that could disturb wildlife in the area. However, due to current industrial activities at otherfacilities along the Mississippi River, wildlife species in the area are expected to be acclimated to
the noise and artificial lighting associated with these activities.
To minimize Project-related impacts on wildlife, Venture Global would implement its
Project-specific Plan and Procedures, as well as its Spill Prevention Plan during construction, andwould develop and implement an SPCC Plan for operations. Venture Global would also
implement best management practices (BMPs), which typically include a combination of silt
fencing, routine inspection, and good housekeeping techniques. A wetland compensatory
mitigation plan would be developed by Venture Global to offset wetland impacts and theirassociated wildlife impact connection. Thus, we believe that impacts on wildlife associated withnoise, light, and human activity would be expected to be minor.
4.6.2

Unique and Sensitive Wildlife Species

No public or conservation lands have been identified within or adjacent to the LNG
terminal or pipeline system. Migratory birds may utilize portions of the Project area and areas
adjacent to the Project area, as discussed below. Species protected under the ESA, the BGEPA,
the MMPA, and by state endangered and threatened species regulations are discussed in section
4.7.
4.6.2.1 Migratory Birds
Migratory birds follow broad routes called flyways between breeding grounds in Canada
and the United States and wintering grounds in Central and South America and the Caribbean.
Additionally, several species migrate from breeding grounds in the north to winter along the Gulf
Coast, where they remain throughout the non-breeding season. The LNG terminal and pipeline
4-59system are within the Mississippi Flyway, which terminates at the Gulf Coast. Of the 650 speciesof birds known to occur in the United States, nearly 400 species occur along the Gulf Coast (Wilson
and Esslinger, 2002). The Gulf Coast provides wintering and migration habitat for large numbersof continental duck and goose populations that use the Mississippi Flyway. The coastal marshes
of Louisiana, Alabama, and Mississippi regularly hold half of the wintering duck population of theMississippi Flyway (Wilson and Esslinger, 2002). For these reasons, the Gulf Coast is considered
one of the most important waterfowl areas in North America.
Migratory birds are federally protected under the MBTA (16 U.S.C. 703-712). The
MBTA, as amended, implements protection of many native migratory game and non-game birds,
with exceptions for the control of species that cause damage to agricultural or other interests. The
MBTA prohibits the take of any migratory bird, or their parts, active nests, and eggs, where to“take” means to “pursue, hunt, shoot, wound, trap, capture, or collect.”
Executive Order 13186 (January 2001) requires that all federal agencies undertaking
activities that may negatively affect migratory birds take a prescribed set of actions to further
implement the MBTA, and directs federal agencies to develop an MOU with the FWS that
promotes the conservation of migratory birds. FERC entered into an MOU with the FWS in March
2011. The focus of the MOU is avoiding or minimizing adverse impacts on migratory birds andstrengthening migratory bird conservation through enhanced collaboration between the two
agencies.
Though all migratory birds are afforded protection under the MBTA, both Executive Order
13186 and the MOU require that Birds of Conservation Concern (BCC) and federally listed species
be given priority when considering the effects on migratory birds. BCCs are a subset of migratory
MBTA-protected species identified by the FWS as those in greatest need of additional
conservation action to avoid future listing under the ESA. Executive Order 13186 states thatemphasis should be placed on species of concern, priority habitats, key risk factors, and thatparticular focus should be given to addressing population-level impacts.
Bird Conservation Regions (BCR) are regions that encompass landscapes with similar bird
communities, habitats, and resource management issues (North American Bird Conservation
Initiative, 2017). BCRs were established to facilitate a regional approach to bird conservation andidentify overlapping or conflicting conservation priorities. The terminal and pipeline system arewithin BCR 37 – Gulf Coastal Prairie (FWS, 2008). Typically 318 species of birds occur
frequently within BCR 37 while another 45 species have migration patterns through BCR 37.
Potential impacts on migratory birds that are also federally listed are described in section 4.7.1.2.
Colonial waterbirds, a subset of migratory birds, include a large variety of bird species thatshare two common characteristics: (1) they tend to gather in large assemblies, called colonies or
rookeries, during nesting season, and (2) they obtain all or most of their food from the water (FWS,
2002). Colonial waterbirds demonstrate nest fidelity, meaning they return to the same rookery
year after year. Rookeries are typically established in marshes or near the shores of ponds or
streams. Although some colonial waterbirds (e.g., least terns) will nest in developed areas, many
waterbirds (e.g., great blue heron, great egrets) are wary of human activity. Colonial nestingwaterbirds that occur in the Project area include various herons, egrets, ibises, terns, gulls, pelicans,and other species. To minimize disturbance to nesting waterbirds, the FWS restricts construction
4-60

activity within 1,000 feet of rookeries to the non-nesting season in Louisiana (table 4.6-1) (FWS,
2017a). A possible colonial-nesting waterbird area on an island in Barataria Bay occurs within a
2-mile radius of the pipeline system. The island is located between 600 and 1,800 feet from thepipeline system. Figure 4.6-1 shows the marshes that would be crossed by the pipeline system.
Table 4.6-1
Non-nesting Period for Nesting Colonial and Non-colonial Birds
Species

PeriodColonial Birds
Anhinga

July to March 1

Cormorant

July to March 1

Great Blue Heron

August 1 to February 15

Great Egret

August 1 to February 15

Snowy Egret

August 1 to March 1

Non-colonial Birds
Little Blue Heron

August 1 to March 1

Tricolored Heron

August 1 to March 1

Reddish Egret

August 1 to March 1

Cattle Egret

September 1 to April 1

Green-backed Heron

September 1 to March 15

Black-crowned Heron

September 1 to March 1

Yellow-crowned Heron

September 1 to March 15

Ibis

September 1 to April 1

Roseate Spoonbill

August 1 to April 1

In addition to the MBTA, the BGEPA provides additional protection to bald and golden
eagles. Bald eagles nest in large trees near coastlines, rivers, and lakes. The bald eagle could
winter or breed, and potential foraging and nesting habitat may exist, in areas near the LNG
terminal site and pipeline route. The LDWF has not collected bald eagle survey data since 2008.
However, during Venture Global’s habitat surveys in 2015, numerous bald eagles were observedin the Project area. One inactive, 3-foot-diameter nest was observed during the survey. This nest
could be from a bald eagle or other raptor species that occur in the Project area.

4-61

TETCO !
.
TGP

!
.

Louisiana
0

1.25

2.5
Miles

Gulf of
MexicoThis information is for environmental review purposes only.

Term inal Site Boundary
Eastern Workspace
SW Lateral TETCOSW Lateral TGP
Barge Access Channel
Barge Access Channel Dredging/Excavation Area!
. Interconnect and Meter Station
Intermediate Marsh
Brackish Marsh
Salt Marsh
Non-marsh/other
Water

p

Figure 4.6-1
Marshlands Crossed by the Project

Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

Source: Louisiana Department of Wildlife, Fur and Refuge Division, 2001,
Louisiana Coastal Marsh Vegetative Type (poly), Geographic NA D83, LDWF (2001), Lafayette, Louisiana, US.

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DRAWN BY: JMS

4.6.2.2 Impacts and Mitigation
The increased presence of humans, noise, and vibrations associated with Project activities
would likely cause sensory disturbances of migratory birds. The resulting negative effects are
expected to be intermittent and short term, occurring during work hours and ceasing after
construction activities have moved from a given area. Displacement and avoidance of the area are
direct responses to sensory disturbances. Birds may be injured or suffer mortality as an indirect
effect of fleeing an area of disturbance. Sensory disturbances to adults could also result in nest
abandonment, affecting egg-laying and potentially causing the mortality of young. In most cases,
Project activities would be short-term and episodic. As such, sensory disturbance effects
associated with these activities may affect individuals but would not likely have notable effects on
any local populations of migratory birds. Permanent aboveground structures, such as the LNG
terminal and meter stations would create potential localized sensory disturbances for theoperational life of the Project, and thus would have more permanent effects.
The vegetation communities within the LNG terminal and pipeline system facilities
provide potential habitat for migratory bird species, including songbirds, waterbirds, and raptors.
However, much of the vegetated land associated with the LNG terminal and pipeline systemfacilities is previously disturbed, within or adjacent to existing facilities, and/or composed ofagricultural land, all of which reduce bird nesting habitat value. Project construction would resultin one-time direct impacts on migratory bird habitat due to vegetation clearing for the LNG
terminal site. These construction activities could have indirect effects on migratory birds such as
egg and young survival and result in bird displacement impacts on bird migration, nesting,foraging, and mating behaviors. Construction could also reduce the amount of habitat available
for foraging and predator protection and would temporarily displace birds into adjacent habitats,which could increase the competition for food and other resources. The effect of clearing andgrading for the LNG terminal would be permanent because these areas may not be restored to theirpreconstruction condition. Given the proposed mitigation measures above, we conclude that
impacts on migratory birds from construction of the Project would largely be temporary and would
not be significant.
To further minimize impacts on migratory birds, Venture Global would implement thefollowing measures, where practicable, to avoid impacts on migratory birds:•

clear areas with potential nesting habitat outside of the approved nesting season fromMarch 1 through July 31, as recommended by the FWS;•

conduct pre-construction nesting surveys and avoid active nests if migratory birds areobserved;•

inspect construction equipment regularly for opportunistic wildlife species, including
nesting migratory birds;•

follow reseeding recommendations from the NRCS for restoration of temporarily
disturbed areas;

4-63

•

stabilize the right-of-way to protect soil resources and promote restoration of
temporarily disturbed areas; and•adhere to the measures in Venture Global’s Project-specific Plan and Procedures, aswell as the Venture Global SPCC Plan and SWPPP to minimize impacts on sensitive
habitats.

Many migratory birds use natural light from the sun, moon, and stars for navigation.
Artificial lighting can hide natural light sources, having unknown effects on birds at the populationlevel. Fatalities to avian species due to artificial light are well documented. Potential impacts
specific to migratory birds include injury or disorientation due to flaring and other artificial
illumination. Avian fatalities are associated with attraction to light sources, especially in low light,
fog, and when there is a low cloud ceiling (Orr et al., 2013). The terminal is designed to limit
flaring events only to LNG carrier gas up / cool down operations, which may occur up to forty
times a year. During operation of the LNG terminal, use of the marine and emergency flares would
only occur during process upset conditions. To the extent practical, use of the flares during initialfacility start-up would be limited to daylight hours, limiting potential impacts on birds, and, to theextent practical, would be planned to avoid inclement weather when the risk of bird mortalities
from attraction to the flares would be the highest. Given that flaring would be limited to the initialstart-up of the facility and LNG carrier gas up / cool down operations, we do not expect substantial
impacts on migratory birds.
The LNG terminal and pipeline facilities would require adequate lighting for operations
and safety. During construction, Venture Global would direct all nighttime lighting towards
construction activity and use the minimum light level necessary to ensure site safety and security.
Venture Global submitted a Facility Lighting Plan that included measures to reduce the impacts offacility lighting including downward-facing lights with shielding needed to meet regulatory
standards and minimize illumination specifications. Facility lighting would be chosen to minimize
the horizontal emission of light away from intended areas, and shielding would help minimize
impacts on birds and other wildlife while providing the illumination needed to ensure safe
operation of the facility. Venture Global conducted a visual assessment evaluating anticipatednighttime lighting conditions at the LNG terminal (see detailed discussion in section 4.8.6). Basedon our reviews of the Facility Lighting Plan and the visual assessment, we have determined thatthe overall increase in nighttime lighting during construction and operation of the LNG terminal
would result in impacts on migratory birds.
To minimize the effects of artificial lighting on migratory birds, outdoor lighting at theterminal and pipeline meter stations would be limited, shielded, and downward-facing to facilitate
safe operations at night or during inclement weather. This would include using only white or red
strobe lights at night, using the fewest number of lights as practicable, and using the minimum
intensity and number of flashes per minute allowable. Solid red or pulsating red warning lights
would be avoided when possible. Perimeter lighting at aboveground facilities would be turned off
at night and would be used only when necessary for work conducted at night. With theimplementation of the mitigation measures described above, we conclude that operational impacts
on migratory birds would not be significant.

4-64Due to the prevalence of suitable bald eagle habitat in the Project area, Venture Global has
committed to conducting pre-construction surveys to identify bald eagle nests in the Project area.
If a bald eagle nest is identified within 660 feet of Project activities, Venture Global would
implement the recommendations in the National Bald Eagle Management Guidelines (FWS,2007), which includes mitigation measures such as maintaining a specified distance between thenest and Project activities; maintaining natural areas between the nest and Project activities; andavoiding specific activities during the breeding season. Based on these proposed measures, weconclude that the Project would not impact bald eagles.
4.6.3

Aquatic Resources

4.6.3.1 Existing Aquatic Resources
LNG Terminal
Habitat for aquatic resources present within the LNG terminal site include the Mississippi
River and 43 man-made drainage ditches/canals that are part of the fastland system. Of the 43
man-made drainage ditches/canals delineated, 38 are ephemeral, three are intermittent, and two
are perennial. Additionally, six man-made drainage ditches/canals were delineated within theeastern workspace adjacent to the LNG terminal site and consisted of four perennial canals andtwo ephemeral drainage ditches. PEM and PFO wetlands are present at the terminal, and PEM
wetlands are present within the eastern workspace. The hydroperiod of these wetlands is not
sufficient to provide consistent habitat for finfish; however, these areas can support aquatic
invertebrates and amphibians.
Waterbodies within the LNG terminal site are contained within the fastlands levee system.
The primary connection to downstream waters is through a pumping station approximately 2 miles
east of the terminal site, adjacent to Lake Judge Perez.
The LNG terminal site has 7,000 feet of shoreline along the Mississippi River. The
Mississippi River has been designated by the LDEQ as supporting primary contact recreation,
secondary contact recreation, drinking water supply, and fish and wildlife propagation; the river
fully supports these designations with no impairments. The Mississippi River at the terminal site
typically consists of freshwater; however, a salt water wedge moves along the river bottom andadvances up the Mississippi River during periods of low flow. During periods of extreme low
flow, the salt water wedge can reach as far as New Orleans. As flows increase, the salt water
wedge is pushed back downstream.
The depth of the Mississippi River ranges from 0 feet at the shoreline to approximately
45 feet in the navigation channel, and the substrate are composed mainly of unconsolidated bottom
sediment. Unconsolidated sediments provide foraging habitat for benthic organisms and fish. Up
to 150 fish species have been found in the lower Mississippi River, and most are freshwater fishes.
Common game fish include black and white crappie (Pomoxis spp.), bluegill (Lepomis
macrochirus), catfish (Ictalurus spp., Pylodictus olivaris), largemouth bass (Micropterus
salmoides), white and striped bass (Morone spp.), red drum (Sciaenops ocellatus), and spotted sea
trout (Cynoscion nebulosus). Bait fish include skipjack herring (Alosa chrysochloris), gizzard

4-65

shad (Dorosoma cepedianum), and threadfin shad (Dorosoma petenense) (Lower Mississippi
River Conservation Committee, 2012).
Pipeline System
The pipeline system is located within the Barataria Basin and traverses 0.4 miles ofpalustrine wetlands and forested uplands from the LNG terminal to TGP MP 14.4, then from TGP
MP 14.4 south to TGP MP 0.0, the pipeline system traverses a mix of estuarine scrub-shrub
wetlands (brackish and salt marsh), estuarine emergent wetlands, and estuarine open water habitats
with unconsolidated bottoms. Over 90 percent of the pipeline system traverses shallow open
water.
The wetlands and open water habitats within the Barataria Basin traversed by the pipeline
system are separated into subsegments by the LDEQ, with the designated uses for each subsegment
defined individually. The subsegments crossed by the pipeline system include the following:•

Wilkinson Canal and Wilkinson Bayou;•

Bay Sanbois, Lake Judge Perez, and Bay De La Cheniere; and•Barataria Bay.

The designated uses for all segments crossed include primary contact recreation, secondary
contact recreation, fish and wildlife propagation, and oyster harvesting; the segments crossed by
the pipeline system fully support all designated uses with no impairment. The estuarine wetlands
and open waters provide appropriate habitat for many aquatic resources characteristic of south
Louisiana estuarine marshes and open waters.
In shallow coastal estuaries, benthos is a key component of the ecosystem, and theBarataria Basin has a robust and diverse benthic community. Ninety-four different benthic species
have been documented in Barataria Basin (Conner and Day, 1987). A commercially important
benthic species within the Barataria Basin is the oyster (Crassostrea virginica). Though large
oyster reefs are uncommon in the Barataria Basin, small oyster aggregations are common
throughout the basin. Culling oysters in Louisiana is allowed only in designated, open public areas
or private leased areas. The harvest season for oysters generally runs from the first Wednesday
after Labor Day through April 30; however, the owner of an oyster lease or his duly authorized
agents may harvest oysters during such times as are provided within the lease terms and conditions
and as approved by the LDWF and LDNR (LDWF, 2015b). The Barataria Basin contains public
oyster seed grounds and oyster leases as shown in figure 4.6-2. The pipeline system would notcross any public oyster areas but would traverse many private oyster leases. These private leases
are identified in table 4.6-2 below.

4-66

Table 4.6-2
Private Lease Areas in Barataria Bay Crossed by Pipeline System
Direct Impact
Acreage(Construction
acres)

Milepost Out

Lease ID

Oyster Lease
Crossed by
Pipeline (feet)

0.0

0.3

2801915

0

0.9

0.0

0.5

3361309

2,345

45.2

0.3

0.7

3463410

363

6.0

0.5

0.9

3253007

1,973

26.5

0.8

1.4

3463010

1,961

19.9

0.9

1.3

2790215

0

6.1

1.2

1.5

2668513

0

1.3

1.3

2.0

3316508

2,568

33.1

1.6

2.5

3330908

3,138

42.9

2.1

2.5

3187307

22

1.3

2.4

2.7

3330808

632

8.9

2.6

4.4

2843807

4,309

60.2

3.2

4.3

3222207 b

3,255

57.2

3.5

4.5

2805407

900

7.6

4.2

4.5

2760507

1,188

9.1

4.3

4.7

2883207

0

2.2

4.4

4.9

2989107

820

6.1

4.5

4.7

2901007

0

0.1

4.7

4.8

3003407

44

0.5

4.7

4.9

2989007

742

3.4

4.9

5.0

2989307

480

3.2

5.0

5.0

3210207

0

0.2

5.0

5.2

2904207

778

6.8

5.1

5.5

3003707

1,585

12.4

5.5

5.7

3003107

380

4.2

5.5

5.9

2747207

1,076

7.5

5.7

6.0

2997807

0

0.1

5.8

6.0

3002807

915

7.8

6.0

6.9

3133307

4,101

33.5

6.8

7.2

3003207

1,326

22.4

7.1

7.5

3522512

318

4.1

7.2

8.1

2872907

1,078

9.3

B0

B0.9

2732307 b

648

28.4

B0

B0.5

2829907

1,745

11.6

B0

B0.4

3366209

0

0.1

B0.7

B1.0

2814807 b

800

7.7

Milepost In
Southwest Laterals

Barge Access Routes

4-67

Table 4.6-2
Private Lease Areas in Barataria Bay Crossed by Pipeline System
Direct Impact
Acreage(Construction
acres)

Milepost In

Milepost Out

Lease ID

Oyster Lease
Crossed by
Pipeline (feet)

B1.1

B1.4

3369909

811

5.6

B1.4

B1.5

3384309

68

0.6

B1.5

B1.7

2874907

1,115

7.6

B1.6

B2.2

3495511

2,339

15.3

B2.1

B2.3

2801607570

4.3

BB10.0BB10.32852607278

1.9

BB10.1

BB10.32866507588

4.1

BB10.3

BB10.63345108
Total

4-68

941

6.5

46,199

543.6

.
!

TETCO

TGP

.
!

Louisiana

Gulf of
MexicoThis information is for environmental review purposes only.

Terminal Site Boundary
Oyster Leases.
!

Interconnect and Meter
StationSW Lateral TETCOSW Lateral TGP

Barge Access Channel
Excavation Area
0

0.5

p

1
Miles

Figure 4.6-2
Mapped Oyster Leases Crossed by the
Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

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Nektonic invertebrates such as shrimp and crabs are both ecologically and commercially
important species in the Barataria Basin, with shrimp being one of the most dominant species inboth numbers and biomass in the middle and lower Barataria Basin (Conner and Day, 1987) duringcertain periods of the year. Ecologically, these species are an important link in the estuarine foodchain. Commercially important species include brown shrimp (Penaeus aztecus), white shrimp(Penaeus setiferus), and blue crab (Callinectes sapidus). The pipeline system is in Shrimp Area
09, Barataria Inside, which indicates that this shrimping area is within the Barataria Bay andinshore waters. Commercial and recreational shrimping occur in the Barataria Basin, with thespring shrimping season usually beginning in early to mid-May and extending to July, and the fallseason usually beginning around mid-August and typically extending into December (LDWF,
2015c). The commercial crab season is open for most of the year. However, the LDWF has theauthority to prohibit the use of crab traps in state waters for a maximum 16-consecutive-day period
between February 1 and March 31 of each year and during a maximum 14-consecutive-day period,
which includes the opening day of the spring inshore shrimp season (May), for the purpose ofremoving derelict or abandoned crab traps (LDWF, 2016).
Ninety-seven percent of commercially important species in the Gulf of Mexico depend on
estuaries for some portion of their life cycle (Conner and Day, 1987). The Barataria Basin is an
important nursery for commercially harvested fish species in the Gulf of Mexico. A total of 237
species of fishes have been recorded from the deltaic plain estuaries in Louisiana, with theBarataria Basin being the most diverse of any estuary in Louisiana (Connor and Day, 1987) with
186 species recorded. The composition of species within the Barataria Basin changes seasonally
due to migratory patterns and life cycle of the species that inhabit the basin and prey availability.
Representative species of finfish in the Barataria Basin include bay anchovy (Anchoa mitchilli),Atlantic croaker (Micropogonias undulatus), Gulf menhaden (Brevoortia patronus), spot
(Leiostomus xanthurus), hardhead catfish (Ariopsis felis), sand seatrout (Cynoscion arenarius),
Atlantic threadfin (Polydactus octonemus), striped anchovy (Anchoa hepsetus), gafftopsail catfish(Bagre marinus), Gulf pipefish (Syngnathus scovelli), spotted sea trout (Cynoscion nebulosus), red
drum (Sciaenops ocellatus), and black drum (Pogonias cromis).
4.6.3.2 Impacts and Mitigation
LNG Terminal
Direct and indirect impacts on fishery resources in the Mississippi River from constructionof the LNG terminal and marine facilities loading docks and temporary berthing structures forconstruction delivery may include the following:•permanent alteration, addition, or removal of aquatic habitat (e.g., benthic habitat loss
from permanent pile placement, introduction of vertical substrate habitat from piles,
and shading or lighting at the LNG loading docks);•

temporary loss of food resources in the form of relatively immobile prey in the benthic
environment;•

temporary increases in sedimentation and water turbidity within and immediately
surrounding the construction work area;
4-70

River.

•temporary disturbance of normal activities (e.g., foraging) and increased stress during
in-water construction for Marine Facilities in the Mississippi River;•

introduction of pollutants; and•mortality to individuals due to contact with construction equipment or exposure toelevated sound pressure levels.

No shoreline excavation is expected to occur and no dredging is planned in the Mississippi

Construction of the marine facilities would result in a localized increase in turbidity andsuspended sediment levels. However, these impacts are expected to be temporary (i.e., confined
primarily to the period of in-water activity and shortly thereafter) and limited to the area within
and immediately adjacent to the LNG loading and marine facilities. No permanent or long-termwater quality impacts are anticipated. Impacts on fisheries resources and supporting habitat as aresult of construction and operation would occur in the Mississippi River from construction of themarine facilities.
The presence of the LNG loading docks would alter the existing aquatic habitat. The
loading docks would be raised approximately 25 feet above the water, creating shading effects
over the river substrate. Unconsolidated sediments within the river provide foraging habitat forbenthic (bottom-dwelling) organisms and fish and are designated as EFH for red drum, shrimp,
and reef fish (see discussion in section 4.6.4.1). Substrates within the Mississippi River are
considered early successional due to frequent disturbance from maintenance dredging, propeller
wash, and vessel traffic. Installation of almost 500 piles to support the LNG loading docks would
act both to reduce foraging and benthic habitat for fish and provide a vertical substrate for marine
life; thereby creating additional shelter and foraging opportunities for fish and mobile benthic
species.
Impacts on potential fish habitat would be associated with the permanent loss of excavateddrainage ditches that cross the LNG terminal site and the installation of the three permanent LNG
berthing docks in the Mississippi River. Due to hydrologic separation from natural drainage flows
in the fastland drainage ditches, which are often ephemeral, these features provide limited fisheries
habitat. Construction measures employed to protect water quality would minimize any impacts on
local fish resources that may remain at the LNG terminal site. The LNG loading dock platforms
would be fixed approximately 25 feet above the existing water level on pilings, which would
provide a substrate for algae, invertebrates, and other potential food sources for fish. The pilings
would provide shade and also an area of refuge and protection for fish and other motile biota. It
is expected that the LNG loading dock platforms would increase habitat diversity in the Mississippi
River and have a net beneficial effect on fisheries resources. No significant commercial orrecreational fisheries resources occur in the vicinity of the LNG terminal.
Pile Driving
Pile driving during construction of the marine facilities would temporarily increase
underwater noise levels within the Mississippi River. Venture Global would install a combination

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of 72-inch-diameter, 66-inch-diameter, 48-inch-diameter, 36-inch-diameter, and 24-inch-diameter
steel piles for the LNG loading docks, MOF, and temporary berthing structures (table 4.6-3). Piles
would primarily be installed using an impact hammer during daylight hours. It is assumed that
impact-driven piles would require approximately 4 hours of continuous driving for installation.
Pilings would also be required for construction of the metering stations in Barataria Bay and areshown in table 4.6-3.
Table 4.6-3
Pilings Sizes and Installation Methods for Project Facilities
Facility

NumberSize (inches)

Installation Method

250

48

impact hammer

66

36

impact hammer

183

24

impact hammer

215

36

impact hammer

55

48

impact hammer

472

impact hammer

866

impact hammer

Temporary Berth (east)

466

impact hammer

Metering Stations

615

12

Impact hammer/vibratory

LNG Loading Docka

Material Offloading Facility
Temporary Berth (west)a – LNG loading docks pile quantities include all piles located riverside of the federal levee.

Fish can be affected by noise both physiologically and behaviorally. The majority of
research involves studies of the physiological effect of impact pile driving on fish due to changes
in water pressure. Fish with swim bladders are more vulnerable to such pressure changes, which
can cause capillaries to rupture or the swim bladder to rapidly expand and contract (Caltrans,
2001). Temporary loss of hearing also may occur as a result of exposure to noise from impact piledriving (Popper and Hastings, 2009; Popper et al., 2005). When caged juvenile Coho salmon(Oncorhynchus kisutch) were placed as close as 6.6 feet (2 meters) to steel piles being impacted,
no fish mortality was observed (Ruggerone et al., 2008).
Potential effects on fish from exposure to continuous sound include temporary threshold
shift (TTS), physical damage to the ear region, physiological stress responses, and behavioral
responses such as startle response, alarm response, avoidance, and perhaps lack of response due tomasking of acoustic cues. Most of these effects appear to be either temporary or intermittent, andtherefore, probably do not significantly impact fish at a population level. Fish do react tounderwater noise from vessels and move out of the way, move to deeper depths, or change theirschooling behavior. The received levels at which fish react are not known and apparently are
somewhat variable, depending upon circumstances and species of fish. To assess the possible
effects of underwater project noise, it is best to examine project noise in relation to ambient
continuous noises routinely produced by other projects and activities, such as shipping and fishing,and pulsive noises produced by pile-driving activities.

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Existing underwater sound levels can serve as a baseline from which to measure potential
impacts associated with Project activities. Knowing the background noise of an area is importantto understanding the overall impact that the introduction of more noise could have on fishes. If
background noise levels in the vicinity of the Project exceed effects thresholds, then fish would
not be affected by any sound less than the already existing dominant noise levels. However, there
is no current information regarding measurements of background noise in the vicinity of the
Project area. Therefore, while it can be assumed that vessel noise associated with the Project
would not add greatly to the already existing background vessel noise in the region, it cannot beassumed that the sound produced by pile driving would be completely masked by vessel noise,
especially close to the hammer.
Table 4.6-4 provides the underwater noise thresholds for injury and behavioral disturbancefor fish during marine pile-driving activities. For purposes of this analysis, examples of injury
include permanent hearing loss and mortality. Noise impact thresholds for fish were determined
by Venture Global using a spreadsheet that NMFS developed to assess the potential effects on
fishes exposed to elevated levels of underwater sound during pile driving (Washington State
Department of Transportation, 2016). Table 4.6-5 provides the underwater noise thresholds forinjury and behavioral disturbance for fish during marine pile-driving activities. For purposes ofthis analysis, examples of injury include permanent hearing loss and mortality. Examples of
behavioral disturbance include increased vulnerability to predators, inability to communicate,movement away from feeding grounds, temporary injuries, and inability to sense the physicalenvironment.
Table 4.6-4
Underwater Noise Thresholds for Fish During Pile Driving Activity
Underwater Noise Thresholdsa
Functional Hearing Group

Impact Pile Driving Disturbance Threshold

Injury Threshold

Fish > 2 gramsb

Behavior effects threshold 150 dB RMS

187 dB SELcum

Fish < 2 gramsb

Behavior effects threshold 150 dB RMS

183 dB SELcum

Fish all sizesb

Behavior effects threshold 150 dB RMS

206 dB Peaka

From NMFS Technical Guidance for Assessing the Effects of Anthropogenic Noise on Marine Mammal Hearing: Underwater Acoustic
Thresholds for Onset of Permanent and Temporary Threshold Shifts.
b From Caltrans’ Technical Guidance for Assessment and Mitigation of the Hydroacoustic Effects of Pile Driving on Fish (Caltrans 2015).
Key:dB = decibel
Peak = peak sound pressure
RMS = root-mean-square sound pressure
SELcum = cumulative sound exposure level

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Table 4.6-5
Threshold Distance for Injury and Disturbance to Fish for Different Pile Diameters
Threshold Distance (feet/meters)
Physical Injury

Type of Pile and Installation
MethodBehavior Disturbance

Cumulative SEL dB re 1 µPA
PeakFish > 2g

Fish < 2g

RMS

72-inch-diameter Steel Pile - Impact
Driven112 / 34

13,058 / 3,981

13,058 / 3,981

60,609 / 18,478

66-inch-diameter Steel Pile – Impact
Driven82 / 25

9,607 / 2,929

9,607 / 2,929

44,587 / 13,594

48-inch-diameter Steel Pile – Impact
Drivena

59 / 18

6,865 / 2,093

7,065 / 2,154

32,800 / 10,000

36-inch-diameter Steel Pile – Impact
Drivena

59 / 18

5,051 / 1,540

5,199 / 1,585

24,129 / 7,356

24-inch-diameter Steel Pile – Impact
Drivena

39 / 121.935 / 590

2,414 / 736

28,132 / 8,577

12-inch-diameter Steel Pile – Impact
Drivena,b7/2

469 / 143

705 / 215

5,198 / 1,585

0.2 / <0.1

0.5 / 0.2

1.0 / 0.3

71 / 2212-inch-diameter Steel Pile –Vibratory Driven

a Distances calculated using the NMFS Pile Driving Calculator.
b 12-inch-diameter piles would be used for construction of meter stations in Barataria Bay.
c Distances calculated using a formula for underwater practical spreading loss, Lreceiver = Lsource – 15 log (Rreceiver/Rsource).
Key:
dB re 1 µPA = decibel re 1 micropascal
RMS = root-mean-square sound pressure
SEL = sound exposure level

Table 4.6-6 provides an estimate of near-source (10-meter) unattenuated sound pressures
for in-water pile driving. Since the average sound pressure levels for 48-inch-diameter piles were
not readily available, levels for 60-inch-diameter piles were used instead.
Table 4.6-6
Summary of Near-source (10-meter) Unattenuated Sound Pressures for In-water Pile Driving
Type of Pile and Installation Method

Average Sound Pressure Measured in dBa,b
Peak

RMS

SEL

60-inch-diameter Steel Pile – Impact Driven

120b

195c

185c

36-inch-diameter Steel Pile – Impact Driven

210

193

183

24-inch-diameter Steel Pile – Impact Driven

207

194

178

12-inch-diameter Steel Pile – Impact Drivend

195

183

170

12-inch-diameter Steel Pile – Vibratory Drivend

171

155

155

a Data obtained from “Compendium of Pile Driving Sound Data” (Caltrans, 2007).
b dB = decibel
Peak = peak sound pressure
RMS = root-mean-square sound pressure
SEL = sound exposure levelc No data are available for the 48-inch-diameter piles that are proposed for the Project, so levels for the 60-inch-diamater piles were usedinstead.
d 12-inch-diameter steel piles would be used for construction of meter stations in Barataria Bay.

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Venture Global primarily proposes to use an impact driven installation method, which hasa higher sound level than vibratory installation. Underwater noise from pile driving would exceed
the behavioral disturbance threshold for fish in the vicinity of the Project. If unmitigated, muchof the proposed pile driving would also exceed the injury threshold for fish and the Project would
have adverse impacts on aquatic resources in the Project area due to pile driving noise.
Venture Global has submitted a draft Underwater Noise Mitigation Plan to the FWS,
NMFS, and LDWF providing an updated analysis of underwater noise impacts due to pile driving,
including assumptions and supporting calculations. The specific noise mitigations that would be
implemented for underwater pile-driving as shown in this plan are as follows:•

adopting a 150-foot buffer around pile-driving locations for manatees, other marine
mammals, and sea turtles, when present and ceasing work until the marine mammal
or sea turtle moves outside of the buffer or had not been observed in the buffer for
30 minutes or sea turtles and manatees and 15 minutes for other marine mammals;
and•using soft starts at the beginning of each pile installation or when 15-minute ormore delay in pile driving has occurred by gradually increasing the intensity of piledriving to allow free-swimming aquatic life to leave the area.

Other Underwater Noise Sources
Natural sources of ambient/background noise include biological sources (i.e., various
biological species), wind, waves, water flow, and rain. Human-generated sources can include
vessel noise (e.g., commercial shipping/container vessels) and maritime activities. Various factors
contribute to the background noise within the Project area. One of the major contributors tobackground noise in the Project area is commercial shipping traffic associated with the Mississippi
River and the Port of New Orleans. Project construction activities would be temporary and would
occur in areas that currently experience underwater noise from commercial and recreational
boaters. During operation, the noise generation associated with visiting LNG carriers would beconsistent with that produced by the multiple large ships that travel though the heavily used sectionof the Mississippi River on which the LNG terminal site would be situated. Generally, it isexpected that the background noise within the Mississippi River is dominated by large vessels(e.g., tankers, container ships) that produce source levels of 180 to 190 decibel (dB) re
1 micropascal root-mean-square (μPARMS) at frequencies between 200 and 500 hertz (Jasney etal., 2005). We conclude that the noise from Project construction (excluding pile driving) and LNG
carriers during operations would not be excessive and would not result in negative noise impacts
on the biological community.
Stormwater Runoff
Construction activities at the LNG terminal would require the removal of vegetation coverat the site and exposing the underlying soils to wind and rain, which would increase the potential
for soil erosion and sedimentation of aquatic habitat. Similarly, during operation of the LNG
terminal, 606.0 acres of currently vegetated land would be converted to impervious or semipervious surfaces associated with aboveground facilities and plant roads, which would increase
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stormwater runoff into adjacent vegetated and open water habitats. Potential impacts fromstormwater runoff on aquatic resources include increased turbidity and levels of suspended solids.
To minimize impacts on aquatic resources due to stormwater runoff, Venture Global would
conduct land-disturbing activities in compliance with its LPDES General Permit for stormwater
discharges; Project-specific Construction SWPPP; and Project-specific Plan and Procedures.
Based on the inherent environmental protection afforded by these regulations and permits, indirect
impacts on aquatic species due to stormwater discharges are not expected to be significant.
Ballast Water
Ballast water would be discharged as an LNG carrier is loading cargo. The general use,discharge, and regulation of ballast water is discussed in section 4.3.2.2. Ballast water that would
be discharged in the LNG berthing area would be composed mainly of Gulf of Mexico water,which would exhibit water quality parameter concentrations different from those of the Mississippi
River. The effects of ballast water discharges on four ambient water quality parameters(temperature, pH, dissolved oxygen, and salinity) are described in section 4.3.2.2. Ballast water
is stored in the ship’s hull; as a result, the temperature of discharged water is not expected todeviate substantially from ambient water temperature. The pH of ballast water would be similar
to or slightly higher than ambient water within the river. However, this difference would not be
outside the tolerance range of resident species, and we believe impacts would be temporary andnegligible.
Surface water within the Mississippi River is generally considered fresh, although a saltwedge intrusion along the bottom can occur during periods of low rainfall and high tides. During
and immediately following ballast water discharges, benthic aquatic species may be affected byhigher salinity levels because the higher salinity ballast water would sink to the lower portion of
the river due to its higher specific gravity relative to the ambient water. However, ships moving
along the river near the berthing area would displace water, circulating it into, around, and out of
the berthing area. Therefore, any increased salinity levels resulting from ballast water discharges
would be temporary. Resident species within the river are euryhaline (able to live in waters witha wide range of salinity), and the salinity of seawater is well within their tolerance range.
Therefore, we have determined that increases in salinity from ballast water discharges would be
temporary and not likely to adversely affect aquatic resources.
Dissolved oxygen levels below 4 mg/L are generally considered unhealthy for aquatic life,and levels below 2 mg/L are considered hypoxic and inadequate to support most aquatic life. As
discussed in section 4.3.2.2, ballast water would contain low dissolved oxygen levels and could
decrease existing dissolved oxygen levels within the immediate vicinity of the discharge point.
Depending on the oxygen levels present in both the ballast and ambient water at the time ofdischarge, aquatic resources present in the vicinity of the discharge point could be exposed todissolved oxygen levels considered unhealthy for aquatic life. The adaptability of resident species
in the Mississippi River to natural spatio-temporal variation in oxygen levels, and the ability tomove over a short distance to more suitable conditions, would minimizes the adverse impacts
associated with ballast water discharges. Given that the amount of ballast water discharged into
the river during each LNG vessel visit to the LNG terminal would make up only a very small
percentage of the 400 billion gallons water flowing downstream, we conclude that impacts onaquatic resources from reduced dissolved oxygen would be temporary and minor.
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Due to the volumes of ballast water often collected by vessels, a possibility exists thatliving marine organisms may enter ballast tanks. The larger macroorganisms that may be collected
would likely die during transit; however, some of the smaller planktonic organisms could survive.
An environmental concern associated with ballast discharge includes the risk of introducing exotic
species in riverine and estuarine ecosystems. Loaded with water from the surrounding ports andcoastal waters throughout the world, vessels can carry a diverse assemblage of marine organisms
in ballast water that may be foreign and exotic to the ship’s port of destination. Invasive aquatic
species may cause algal blooms and hypoxic conditions, affecting all trophic levels and potentiallyresulting in a decline in biodiversity.
USCG regulations require that all vessels equipped with ballast water tanks that enter or
operate in U.S. waters maintain a vessel-specific ballast water management plan and assign
responsibility to the master or appropriate official to understand and execute the ballast water
management strategy for that vessel (33 CFR 151.2026). Under these requirements, vessels must
implement one of five strategies to prevent the spread of exotic aquatic nuisance species in U.S.
waters. The IMO has adopted this regulation and requires each vessel to install and operate aballast water management system (option 1 as currently defined).
Venture Global has stated that it would require LNG carriers to conduct complete ballast
water exchange at least 200 nautical miles from any shoreline (option 4 as currently defined),
except in extraordinary circumstances causing safety or stability concerns that would require aballast exchange less distant from the shoreline, which is authorized under 33 CFR 151.2040.
Venture Global has indicated that they adhere to all USCG ballast management regulations
throughout the life of the Project.
Artificial Lighting (including flaring)Temporary lighting would be installed and used during construction of the LNG terminal
to facilitate construction activities during evening hours and meet applicable safety requirements.
Construction of the LNG loading and ship berthing facilities would not require overwater lighting
during the construction period, as all work here would be conducted during daylight hours.
However, artificial light sources can have undesirable effects on aquatic resources, such as altering
foraging behavior and spatio-temporal patterns of species density. Artificial light emanating fromcoastal infrastructure has the potential to alter the feeding behavior of predatory fish and affectprey fish behavior, particularly schooling (Becker et al., 2012). Illumination of surface waters in
the vicinity could cause artificially induced aggregations of small organisms that rely on sun or
moonlight to determine movement patterns, resulting in increased predation by larger species.
Generally, impacts on aquatic species would be minor as these species may change their feeding
habits over time. Due to the industrial nature of the area surrounding the LNG terminal, aquatic
species within the Mississippi River are likely acclimated to ambient light from surrounding
industrial sources.
To minimize potential impacts on aquatic resources, Venture Global would direct allnighttime lighting towards the construction activity being conducted. Venture Global’s Facility
Lighting Plan indicates that lighting would be chosen to minimize the horizontal emission of lightaway from intended areas, and over-water lighting would be limited to the extent necessary to
carry out marine operations or facility maintenance and would be shielded. Based on the existing
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light conditions along relevant portions of the Mississippi River and the likelihood that aquatic
resources would acclimate over time to increased lighting at the LNG terminal, we havedetermined that impacts on aquatic resources from increased lighting during construction andoperation of the LNG terminal would be minimized.
Mississippi River Traffic
LNG carrier visits to the LNG terminal would represent only a minor increase to theexisting level of ship traffic in the Mississippi River; as such, operational impacts on fisheries
resources (including those associated with noise as discussed earlier) are not anticipated.
Water Withdrawal and Discharge
Venture Global anticipates that water for hydrostatic testing of the LNG tanks, otherstorage tanks, and plant piping would be appropriated from the drainage canal south of the LNG
terminal site. Water used for LNG terminal operations may be obtained from the Mississippi
River, the Plaquemines Parish Water District, or a new well or wells to be located at the LNG
terminal site.
The water withdrawal process could entrain fish eggs and juvenile fish present near theintake structures within the industrial canal. In accordance with its Project-specific Procedures,
Venture Global would screen (0.25- to 1-inch mesh) intake hoses to limit the entrainment of larvaeand pre-juvenile fish and invertebrates during water withdrawal. Venture Global would withdraw
water at a rate of 1,200 gallons per minute and would place screened intake structures at the lowest
possible elevation to reduce the impingement of biological organisms and debris on intake screens.
Water intakes would be placed above the channel bed to avoid sediment disturbance. Also, test
water would be transferred between LNG storage tanks to reduce the amount of water required fortesting. With the implementation of these measures, impacts on aquatic resources as a result ofwater intake would not be significant.
Impacts associated with water discharges include local erosion and bed scour. Test water
would be in accordance with the LPDES Hydrostatic Test Wastewater Discharge Permit
requirements and would follow the Project-specific Plan and Procedures. The water would betested for total suspended solids, oil and grease, and pH, and treated (if test results indicate that thewater would not meet LPDES requirements) prior to being discharged to the Mississippi River.
Therefore, we have determined that impacts on aquatic resources due to the discharge ofhydrostatic test water would be temporary and negligible.
Inadvertent Spills
During construction and operation, hazardous materials resulting from spills or leaks
entering the Mississippi River could have adverse impacts on aquatic resources. The impacts arecaused by either the physical nature of the material (e.g., physical contamination and smothering)or by its chemical components (e.g., toxic effects and bioaccumulation). These impacts would
depend on the depth and volume of the spill, as well as the properties of the material spilled. To
prevent spills and leaks, Venture Global would implement its Project-specific Spill Prevention
Plan during construction and its SPCC Plan during operation of the LNG terminal. These plansoutline potential sources of releases at the site, measures to prevent a release, and initial responses
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in the event of a spill (see detailed discussion in section 4.2.3). Given the impact minimizationand mitigation measures described above, we conclude that impacts on aquatic resources would
be temporary and minor.
Pipeline System
Waterbodies and wetlands that would be crossed by the pipeline system have the potential
to support fish and other aquatic biota. Larval and juvenile fish rely on wetlands as refuge andforaging habitats.
Pipeline construction impacts on fishery resources resulting fromexcavation/dredging for the pipeline and barge access routes would be temporary and may include
the following:•

temporary noise disturbance during in-water construction;•

temporary increased sedimentation and water turbidity within and immediately
surrounding the construction work area;•

direct mortality of individuals due to contact with construction equipment;•

temporary loss of food resources in the form of relatively immobile prey in the benthic
environment;•

temporary and permanent alteration, addition, or removal of aquatic habitat cover; and•introduction of pollutants.

Permanent impacts include the construction of the two meter stations in Barataria Bay. The
meter station platforms would be raised approximately 25 feet above the water, thereby reducing
shading effects to benthic habitat. The 12-inch-diameter piles supporting the platforms would act
to remove or reduce benthic habitat used by fish for foraging, but would also provide a verticalsubstrate for marine life, creating additional fish foraging opportunities and shelter. No otherimpacts on fisheries resources are expected during daily operations. Some of the impacts
mentioned above may occur during maintenance activities but would be infrequent, of limited
duration, and therefore insignificant.
Pipeline system construction impacts on fisheries resources and habitat would occur
primarily in estuarine wetlands and open water. Impacts would primarily be localized andtemporary, with disturbed areas returning to preconstruction conditions following pipeline
installation. The pipeline trench would be backfilled following construction, and the barge
channels would backfilled with sidecast material. The push method or barge lay method would be
used for trenched pipeline installation across most waterbodies and wetlands. These methods aredesigned to minimize equipment use and disturbance during pipeline construction, although thecrossing methods could result in temporary loss or modification of aquatic habitat, increases in
sedimentation and turbidity levels, and alteration of vegetative cover. The majority of fish present
within the waterbody at the time of construction activities would likely be displaced to similar
nearby habitats; however, stress, injury, or death of individual fish may occur. Increased
suspended sediment and turbidity levels may cause degradation of benthic and spawning habitat

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and decreased dissolved oxygen levels within and downstream of the crossing location.
Temporary increases in suspended solids would decrease rapidly following the completion of inwater activities.
Venture Global has developed Project-specific Procedures as initially discussed in section
2.5.5.5. FERC’s Procedure’s require seasonal restrictions on construction within waterbodies,
unless expressly permitted or further restricted in writing by the appropriate federal or state agency.
Venture Global states that it would not adopt the seasonal construction restriction for its pipelines
because of the length of the construction period and the need for an integrated schedule across themultiple Project facilities. In compliance with our Procedures, Venture Global obtained written
approval from the LDWF to conduct in-water activities without a seasonal restriction. As such,impacts on aquatic resources associated with construction activities is expected to be temporary,short-term, and localized to the immediate vicinity of construction activities. Although theconstruction of each pipeline and deepening of discrete segments of barge access channels would
take place over an extended duration, the construction activity at any single location along thepipeline route or barge access channels is likely to be limited to several days or weeks minimizing
potential impacts on aquatic resources and recreational fishing. Access to the construction rightof-way and barge access channels would not be prohibited for fishing/crabbing/shrimping, except
in the immediate vicinity of construction activities where necessary for safety reasons.
A PSS wetland, PEM wetland, and perennial stream (unnamed channel) would be crossedby the HDD method at the northern end of the pipeline route between MPs 11.3 and 11.5 of theSouthwest Lateral TETCO and MPs 14.6 to 14.8 of the Southwest Lateral TGP, thereby avoiding
direct impacts on these features. Venture Global estimates that HDD operations would requireapproximately 9.0 million gallons of water and hydrostatic testing of the pipelines would requireapproximately 9.5 million gallons of water (18.5 million gallons in total). Installing the pipelines
using the HDD method would avoid or minimize impacts on fisheries, fish habitat, and otheraquatic resources within and adjacent to waterbodies unless an inadvertent release of drilling mud
were to occur. An inadvertent release of drilling mud (bentonite clay) into a stream would affectwater quality and could impede fish movement, potentially resulting in stress, injury, and/or directmortality of fish present in the vicinity of the release. Bentonite clay is non-toxic to aquaticorganisms (Hair et al., 2002). However, bentonite clay sediment can interfere with oxygen
exchange by gills and adversely affect filter feeders. If an inadvertent release occurs, Venture
Global would implement the corrective action and cleanup measures outlined in its HDD
Contingency Plan. We have reviewed this HDD Contingency Plan and find it acceptable. The
HDD Contingency Plan would minimize potential impacts on aquatic resources, including the
installation of berms, silt fence, and/or hay bales to prevent silt-laden water from flowing into
waterbodies, or in the event of an in-water release, the use of temporary dams to isolate the drilling
fluid and vacuum trucks to remove the released drilling mud.
Venture Global prepared a report identifying shoreline areas within the Barataria Basin(i.e., those land/water interfaces with a hydrological connection to the open waters of the Gulf)
that have high re-oiling potential (i.e., areas that have experienced periodic remobilization of
weathered oil). The report indicates all of the Project’s shoreline crossings have a reoiling potential
classification of “no oil observed.” If weathered oil is encountered during construction, Venture
Global would take the appropriate precautions to prevent resuspension of contaminated media andnotify the appropriate authorities.
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Impacts on surface water and wetlands associated with construction of the pipeline
facilities during and following construction would be addressed through adherence to the USACE,New Orleans District/LDNR permit conditions, CWA section 401 water quality certification
requirements, and implementation of the protective measures in the Project-specific Plan andProcedures along with our recommendation. The applicant would minimize impacts bydeveloping site-specific crossing plans for major waterbodies and by adhering to the procedures
set forth in its final SPCC Plan, SWPPP, and HDD Contingency Plan. Surface water and wetland
impact avoidance, minimization, and mitigation measures are addressed in sections 4.3.2.2 and4.4.2.2, respectively.
Pile Driving
During construction of the two meter stations in Barataria Bay, 615 12-inch-diameter steel
piles would be installed during construction. Installation could result in noise impacts on fish
similar to those discussed for the marine facilities in the Mississippi River (see above for LNG
terminal). Currently, Venture Global plans to install the piles associated with the meter stations
using either the impact hammer pile driving method or the vibratory pile driving method.
Generally, vibratory pile driving takes much less time than impact-driven pile installation.
Underwater noise thresholds for injury and behavioral disturbance for fish and near-source(10-meter) unattenuated sound pressures for in-water pile driving are summarized in tables 4.6-5
and 4.6-6, respectively. Venture Global has submitted its Underwater Noise Mitigation Plan to
the FWS, NMFS, and LDWF as described in section 4.6.2.3 to minimize and avoid impacts frommarine pile driving.
Other Underwater Noise Sources
Underwater noise levels associated with barges and dredging/excavation in estuarine
wetlands and open water along the pipeline system would also increase in the Project area during
construction and intermittently during operation of the pipelines. Construction activities would be
temporary and would occur in areas that currently experience underwater noise from other oil andgas operations in the vicinity. The mobility of marine species and the ability to leave any area ofnoise disturbance would minimize impacts from barge traffic and construction of the pipeline andmeter stations.
Dredging of Barge Access Channels
Dredging within barge access areas would cross private oyster leases. According to the
LDWF, lessees must be notified as part of the Coastal Use permitting process about projects
occurring in their oyster lease. In addition, a water bottom assessment must be conducted on thoseportions of leases located within 1,500 feet of the pipeline system. Additional requirements tomitigate potential impacts on these oyster leases may be required by the LDWF as the permitting
process continues. Further, in the event that Venture Global cannot reach an agreement within an
affected oyster lease holder, Venture Global would seek a preliminary determination of damages
through an arbitration process with the LDNR – Oyster Lease Damage Evaluation Board. The
board would review the results of an initial biological survey of the area to be affected and would
determine the amount of a damage estimate deposit to be held by the board and paid by Venture

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Global prior to construction within the lease. The final damage payment to be made to each leaseholder would be made following the construction activities and completion of a final biologicalsurvey subject to review by the board.
Hydrostatic Testing - Water Withdrawal and Discharge
Venture Global anticipates that water for hydrostatic testing of the pipeline system would
be withdrawn from Barataria Bay near the TGP and TETCO meter stations. The two discharge
locations are the industrial canal south of the LNG terminal site and at the mainline valve site.
Impacts associated with water discharges include local erosion and bed scour. Hydrostatic testing
activities would be in accordance with the LPDES Hydrostatic Test Wastewater Discharge Permit
requirements and would follow the Project-specific Plan and Procedures. Water intakes would bescreened to reduce or eliminate the entrainment of fish and other aquatic organisms. The discharge
water would be tested for total suspended solids, oil and grease, and pH, and treated (if test results
indicate that the water would not meet LPDES requirements) prior to being discharged. Therefore,
we have determined that impacts on aquatic resources due to the intake and discharge ofhydrostatic test water would be temporary and negligible.
Vessel Traffic
Increased vessel traffic as a result of pipeline construction would represent a minor increase
to the existing level of commercial and recreation vessel traffic within Barrataria Bay; therefore,
impacts on fisheries resources as a result of construction vessel traffic (including those associatedwith noise as discussed earlier) are not anticipated. Once construction is complete, vessel traffic
associated with operation of the pipeline system would be related to maintenance and would be
negligible.
Inadvertent Spills
During construction of the pipeline system, a potential exists for the release of hazardous
materials into canals and Barataria Bay, which could have adverse impacts on aquatic resources.
These impacts would depend on the depth and volume of the spill, as well as the properties of thematerial spilled. To prevent spills and leaks during pipeline construction, Venture Global would
implement its Project-specific SPCC Plan. Given the impact minimization and mitigation
measures described above, we conclude that the probability of a spill of hazardous materials is
small and any resulting impacts on aquatic resources would be temporary and minor.
4.6.4

Essential Fish Habitat

The MSA (Public Law 94-265 as amended through January 12, 2007, was established,along with other goals, to promote the protection of EFH during the review of projects to be
conducted under federal permits, licenses, or other authorities that affect or have the potential toaffect such habitat. EFH is defined in the MSA as those waters and substrate necessary to fish forspawning, breeding, feeding, or growth to maturity. Federal agencies that authorize, fund, or
undertake activities that may adversely affect EFH must consult with NMFS. Although absolute
criteria have not been established for conducting EFH consultations, NMFS recommends
consolidated EFH consultations with interagency coordination procedures required by other4-82

statutes, such as NEPA, the Fish and Wildlife Coordination Act, and the ESA, to reduce
duplication and improve efficiency (50 CFR 600.920(e)). Generally, the EFH consultation processincludes the following steps:•

notification – The action agency should clearly state the process being used for EFH
consultation (e.g., incorporating EFH consultation into an EIS);•EFH Assessment – The action agency should prepare an EFH Assessment that includes
both identification of affected EFH and an assessment of impacts. Specifically, the
EFH Assessment should include the following:o a description of the proposed action;o an analysis of the effects (including cumulative effects) of the proposed action on
EFH, managed fish species, and major prey species;o the federal agency’s views regarding the effects of the action on EFH; ando proposed mitigation, if applicable.

•

EFH Conservation Recommendations – After reviewing the EFH Assessment, NMFS
should provide recommendations to the action agency regarding measures that can betaken by that agency to conserve EFH; and•agency response – Within 30 days of receiving the recommendations, the action agency
must respond to NMFS. The action agency may notify NMFS that a full response to
the conservation recommendations would be provided by a specified completion dateagreeable to all parties. The response must include a description of measures proposedby the agency to avoid, mitigate, or offset the impact of the activity on EFH. For eachconservation recommendation that is not adopted, the action agency must explain its
reason to NMFS for not following the recommendation.

As recommended by NMFS, we are incorporating EFH consultation for the Project into
our responsibilities under NEPA and this EIS.
4.6.4.1 Existing Essential Fish Habitat
The Project is in Gulf of Mexico Ecoregion 4: East Texas and West Louisiana, Mississippi
Delta to Freeport. NMFS mapping shows EFH within the Project area, including the Mississippi
River and portions of the Barataria Basin (NOAA, 2014a). Figure 4.6-3 shows the extent of EFH
relevant to the Project areas. Correspondence between Venture Global and NMFS (NMFS, 2017)indicate that the portion of the Mississippi River located in the Project area does not provide EFH
since managed fish species would not be common this far upriver (river mile 55). Therefore, we
conclude that the LNG terminal facilities located in the Mississippi River would not effect EFH.

4-83

Fastlands
Mi
ss

is s

ipp
iR
iv e

r

Lake
Laurier

Service Layer Credits: Sources: Esri, HERE,
DeLorme, USGS, Intermap, INCREMENT P,
NRCan,Plaquemi n eEsris Japan, METI, Esri China (HongKong), Esri Korea, Esri (Thailand),P a r iMapmyIndia,sh
NGCC, © OpenStreetMap
contributors, and the GIS User Community
Source: Esri, DigitalGlobe, GeoEye, Earthstar
Geographics, CNES/Airbus DS, USDA,
USGS, AeroGRID, IGN, and the GIS User
Community

Wilkinson Canal

Raquette
Bay

Wilkinson Bay

Bay Batiste
TETCO !
.

TGP

Barataria Bay!
.

Louisiana

Jefferson
ParishNational Oceanic and Atmospheric Administration. 2014a. Essential Fish Habitat Mapper v3.0.
NOAA National Marine Fisheries Service, Habitat Conservation. Available online at:
http://www.habitat.noaa.gov/protection/efh/efhmapper/index.html#.

This information is for environmental review purposes only.

Essential Fish Habitat
Terminal Site Boundary!
.

Interconnect and Meter
StationSW Lateral TETCO

Eastern Workspace

SW Lateral TGP

Barge Access Channel
Dredging/Excavation
Area

Barge Access Channel
0
1
Levee

1:126,720

p

2
Miles

Figure 4.6-3
Mapped Essential Fish Habitat Crossed by the Project
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR03\_Plaquemines_RR03_2_3_2.mxd | REVISED: 02/15/2017 | SCALE: 1:126,720

DRAWN BY: JMS

The remainder of the LNG terminal site lies adjacent to the Mississippi River on non-tidal
fastlands that are hydraulically separated from surrounding marsh habitats. Correspondence
between Venture Global and NMFS indicates that construction of the LNG terminal facility would
not likely adversely impact habitat supportive of marine fisheries resources (NMFS, 2015a). The
80-acre eastern workspace adjacent to the LNG terminal site, like the LNG terminal, is also on
non-tidal fastlands and, therefore, is not anticipated to affect EFH.
The pipeline system is in the Estuarine Zone, as defined by the Gulf Council (NMFS,
2015a). EFH in the region is designated by the Gulf Council and NMFS through Fishery
Management Plans. NMFS, in a letter to FERC (NMFS, 2015a), indicated that wetlands along the
majority of the pipeline system are categorized as EFH for post-larval and/or juvenile life stagesof white shrimp, brown shrimp, and lane snapper (Lutjanus synagris); all life stages of red drum;
and adult gray snapper. Additionally, primary categories of EFH within the Project area include
estuarine emergent wetlands, estuarine water column, and estuarine mud bottoms. Thoughsubmerged aquatic vegetation (SAV) occurs within the Barataria Basin, no SAV was observed
during field surveys for the pipeline system.
NMFS (NMFS, 2015a) indicated that wetlands in the vicinity of the pipeline systemprovide nursery and foraging habitats supportive of a variety of economically important marine
fishery species, including striped mullet (Mugil cephalus), Atlantic croaker, Gulf menhaden,spotted and sand sea trout, southern flounder (Paralichthys lethostigma), and blue crab. Some ofthese species serve as prey for other fish species managed under the MSA by the Gulf of Mexico
Fishery Management Council, such as mackerels, snappers, and groupers, as well as highly
migratory species managed by NMFS, such as billfish and sharks.
4.6.4.2 Impacts and Mitigation
Construction of the pipeline system would impact EFH for post-larval and juvenile life
stages of white shrimp, brown shrimp, and lane snapper, all life stages of red drum, and adult graysnapper. Affected EFH includes benthic substrates and/or water column habitats in estuarine open
water (collectively referred to in this assessment as estuarine open water) and estuarine emergent
wetlands. Potential adverse impacts on EFH would primarily be temporary, while some permanent
impacts may be beneficial. Temporary adverse impacts during construction would be minimized
through adherence to Venture Global’s Project-specific Procedures, SWPPP, and SPCC Plan.
Potential temporary and permanent impacts of pipeline system construction and operation on EFH
are described below.
Temporary Habitat Modification
Approximately 775.4 acres of estuarine open water mapped as EFH and 423.9 acres of
estuarine open water not mapped as EFH (in Lake Laurier, Barataria Bay, and Wilkinson Bay),
along with approximately 64.5 acres of EEM wetlands, that can function as EFH, would be
temporarily modified by dredging, excavation, and related activities within the workspace requiredfor pipe installation, meter station construction, and barge access channels. Portions of the barge
access channels would be dredged to increase the existing water depth (approximately 4 to 7 feet)to at least 8 feet to allow for passage of construction barges along the pipeline construction right-

4-85

of-way and in existing channels providing access to the right-of-way. Construction disturbancewould be temporary and localized to the construction area.
Spoil resulting from the excavation of the flotation channel and pipe trenches would be
temporarily placed on either side of the right-of-way centerline, keeping the spoil below the water
surface, where feasible, to minimize wave-generated turbidity. After the pipe is lowered into thetrench, the pipeline trench and flotation channel would be backfilled with previously excavatedmaterial. The trench and construction workspace would be returned to its previous contours tomatch the adjacent undisturbed portions of the wetland upon completion of restoration. The
applicant would also install bank line stabilization at the water/marsh interface to facilitate
restoration. Restoration of the temporarily impacted areas would be monitored and the successfulachievement of pre-construction conditions will be determined after one full growing season post
construction. For locations where pre-construction conditions are not achieved after one fullgrowing season, Venture Global would work with the USACE and LDNR to determine theappropriate follow-up measures to restore the construction right-of-way.
Potential impacts on EFH include sediment disturbance and temporary changes in water
depth from dredging/excavation, although the benthic substrate would offer fundamentally similar
habitat prior to and after dredging. Along the Louisiana coast, SAV is largely limited to depths nogreater than 3 to 4 feet (LDWF, 2012). Any increase in water depth beyond this level could
preclude the growth of SAV. However, no SAV was identified during Venture Global’s fieldsurveys at proposed dredging/excavation locations (ERM, 2017); therefore, no impacts on SAV
are expected. Given the type of sediments in estuarine open water environment, benthic
communities are expected to quickly recolonize after construction. Wetlands would be returnedto the previous grade and are expected to revegetate within one growing season. Therefore, wehave determined that any adverse impacts on EFH would be minor because of their temporary
nature and limited spatial extent.
Temporary Loss of Benthic Invertebrates
Dredging/excavation would have temporary and localized effects on benthic substrates inthe estuarine zone. Invertebrate food resources would be expected to recolonize to their former
status within a few seasons. Because the effects would be temporary and limited in spatial extent,
temporary loss of benthic invertebrates is expected to have a minor adverse impact.
Temporary Increased Turbidity
The Project has the potential to produce temporary turbidity plumes in the water column
during in-water work activities, including pipeline construction, barge channel excavation, andhydrostatic test water discharge. In-water work may cause localized increases of suspended
sediment and nutrient levels in the water column, and decreases in dissolved oxygen. Turbidity
effects would be temporary and limited in spatial extent and result in minor adverse impacts on
EFH.
Introduction of Pollutants
Potential surface water quality impacts associated with accidental spills or leaks ofhazardous liquids would be avoided or minimized by restricting the locations and use of refueling
4-86and storage facilities, and by requiring cleanup in the event of a spill or leak. Additionally,
shoreline crossings have a reoiling potential classification of “no oil observed.” Impacts on surface
waters during construction and operation would be mitigated by adherence to the Project-specificProcedures, SWPPP, and SPCC Plan. Through implementation of the BMPs, potential impacts on
EFH due to pollutants would be of short duration and minimal.
Permanent Habitat Modification
Approximately 2.4 acres of estuarine open water would be permanently modified throughthe construction of the two meter stations in Barataria Bay. The meter station platforms would be
fixed approximately 25 feet above the existing water level on pilings, which would provide asubstrate for marine algae, invertebrates, and other potential food sources for fish. The relatively
close proximity of multiple pilings may also provide an area of refuge and protection for fish andother motile biota, while the platforms may offer some shading. Because the meter station
platforms would increase habitat diversity in Barataria Bay, they would likely have a net beneficial
effect on EFH.
Based on the information provided above, EFH, including estuarine emergent wetlands,
benthic substrates, and water column habitats, would be affected by pipeline construction.
Adverse effects would be temporary, localized, and minimal. Pre- and post-construction EFH
acreage is not expected to change. Moreover, the pipelines have been routed through open water
to the extent practicable, and construction methods have been selected that minimize potential
degradation of EFH.
Following pipeline construction, affected wetlands and waterbodies would be returned topreconstruction conditions to the extent practicable, in accordance with the Project-specificProcedures and the conditions of USACE and LDNR permits. With the majority of wetlands inBarataria Bay being impacted by subsidence and erosion, complete restoration to pre-existing
conditions is of concern, as noted by NMFS (2015). As noted above, if full recovery is notachieved within one growing season, Venture Global would consult with the USACE and LDNR
to determine appropriate follow-up measures.
Marine Mammals
A total of 25 mammals protected under the MMPA may occur along the LNG transit routes
in the Gulf of Mexico. Three of the species are also listed under the ESA and are addressed in
section 4.7. The remaining 22 whale and dolphin species and their potential areas of occurrencealong the LNG transit routes are described in table 4.6-7.
All marine mammals are federally protected under the MMPA. The MMPA established,with limited exceptions, a moratorium on the “taking” of marine mammals in waters or on lands
under U.S. jurisdiction. “Take” is defined as the “harassing, hunting, capturing, or killing” ofmarine mammals. The 1994 Amendments to the MMPA define “harassment” as “any act of
pursuit, torment, or annoyance” which:•has the potential to injure a marine mammal or marine mammal stock in the wild (Level
A Harassment); or

4-87has the potential to disturb a marine mammal or marine mammal stock in the wild bycausing disruption of behavioral patterns, including, but not limited to, migration,breathing, nursing, breeding, feeding, or sheltering but which does not have thepotential to injure a marine mammal or marine mammal stock in the wild” (Level B
Harassment).

•

LNG terminal operations would include LNG carriers moving between the Mississippi
River and the Gulf of Mexico. As discussed for federally listed whales and sea turtles, there is thepotential for interaction and injury during LNG carrier transit in the Gulf of Mexico. There is alsoa potential for bottlenose dolphins to occur in the Mississippi River, and they have been
documented in Barataria Bay (Muth, 2016). Mitigation measures for non-listed marine mammals
will be the same as those for listed whales and those noted in section 4.7.1.1 for manatees.
Potential impacts on dolphins from pile driving during meter station construction would be similar
to those discussed in section 4.7.1.1 for manatees.
Table 4.6-7
Non-ESA Listed Marine Mammals Potentially Occurring Along the LNG Transit Routes
Common Name

Scientific Name

Area Where Mammal May Occur

Atlantic Spotted Dolphin

Stenella frontalis

Gulf of Mexico

Bottlenose Dolphin

Tursiops trunctus

Terminal, Pipeline System, Mississippi
River, Gulf of Mexico

Clymene Dolphin

Stenella clymene

Gulf of Mexico

False Killer Whale

Pseudorca crassidens

Gulf of Mexico

Frasier’s Dolphin

Lagenodelphis hosei

Gulf of Mexico

Orcinus orca

Gulf of Mexico

Peonocephala electra

Gulf of Mexico

Pantropical Spotted Dolphin

Stenella attenuate

Gulf of Mexico

Risso’s Dolphin

Grampus griseus

Gulf of Mexico

Rough-toothed Dolphin

Steno bredanensis

Gulf of Mexico

Short-finned Pilot Whale

Globicephala macrorhyncus

Gulf of Mexico

Spinner Dolphin

Stenella longirostris

Gulf of Mexico

Striped Dolphin

Stenella coeruleoalba

Gulf of Mexico

Mesoplodon densirostris

Gulf of Mexico

Bryde’s Whale

Balaenoptera edeni

Gulf of Mexico

Cuvier’s Beaked Whale

Ziphius cavirostris

Gulf of Mexico

Dwarf Sperm Whale

Kogia sima

Gulf of Mexico

Gervais’ Beaked Whale

Mesoplodon europaeus

Gulf of Mexico

Balaenoptera acutorostrata

Gulf of Mexico

Eubalaena glacialis

Gulf of Mexico

Kogia breviceps

Gulf of Mexico

Dolphins

Killer Whale
Melon-headed Whale

WhalesBlainville’s Beaked Whale

Minke Whale
North Atlantic Right Whale
Pygmy Sperm Whale

4-88

Table 4.6-7
Non-ESA Listed Marine Mammals Potentially Occurring Along the LNG Transit Routes
Common Name

Scientific Name

Area Where Mammal May Occur

Sowerby’s Beaked Whale

Mesoplodon bidens

Gulf of Mexico

Source: NMFS, 2012

4.7

THREATENED, ENDANGERED, AND OTHER SPECIAL STATUS SPECIESSpecial status species are those species for which state or federal agencies afford an
additional level of protection by law, regulation, or policy. Included in this category are: federally
listed and federally proposed species that are protected under the ESA, as amended; species thatare currently candidates for federal listing under the ESA; state listed threatened or endangered
species; and species otherwise granted special status at the federal or state level (e.g., protectedunder the MMPA).
Under section 7 of the ESA, as amended, federal agencies are required to ensure that any
actions authorized, funded, or carried out by the agency would not jeopardize the continued
existence of a federally listed threatened or endangered species, or result in the reduction or adverse
modification of the designated critical habitat of a federally listed species. As the lead federal
agency, FERC is required to coordinate with the FWS and NMFS to determine whether federally
listed threatened or endangered species or designated habitat are found in the vicinity of projects
and to determine potential effects on those species or critical habitats.
For actions involving major construction activities that may affect listed species ordesignated critical habitat, the lead federal agency must prepare a Biological Assessment andsubmit it to the FWS and/or NMFS. If the action would adversely impact a listed species, thefederal agency must also submit a request for formal consultation. In response, the FWS and/or
NMFS would issue a Biological Opinion as to whether or not the federal action would likely
jeopardize the continued existence of a listed species or result in the destruction or adverse
modification of designated critical habitat.
As required by section 7 of the ESA, we are requesting that the FWS and/or NMFS accept
the information provided in this EIS as the BA for the Project. Furthermore, we request
concurrence with our determinations of effect for the federally listed and proposed species in table
4.7-1.
Based upon our review of publicly available information, agency correspondence, and fieldsurveys, federally and/or state listed threatened or endangered species may occur in the vicinity ofthe terminal site and pipeline system. There is no critical habitat for federally listed species
designated within the limits of construction for the Project.

4-89

Table 4.7-1
Federal and State Listed Species Potentially Occurring in the Vicinity of the Project
Common Name
Scientific Name

Federal Status

State Status

Project
Component

West Indian Manatee
Trichechus manatus

Threatenedc

Endangered

Pipeline

May affect, not likely to adversely affectBlue Whale
Balaenoptera musculus

Endangeredc

Endangered

Terminald

May affect, not likely to adversely affectFin Whale
Balaenoptera physalus

Endangeredc

Endangered

Terminald

May affect, not likely to adversely affectSei Whale
Balaenoptera borealis

Endangeredc

Endangered

Terminald

May affect, not likely to adversely affect

Sperm Whale
Physeter microcephalus

Endangeredc

Endangered

Terminald

May affect, not likely to adversely affectBald Eagle
Haliaeetus leucocephalus

Delisteda,bEndangered

Terminal andPipeline

May affect, not likely to adversely affectBrown Pelican
Pelecanus occidentalis

Delisted

Endangered

Terminal andPipeline

May affect, not likely to adversely affect

Eastern Black Rail
Laterallus jamaicensis jamaicensis

Proposed

Not Listed

Terminal andPipeline

May affect, not likely to jeopardize thecontinued existence

Peregrine Falcon
Falco peregrinus

Delistedb

Threatened/
Endangered

Terminal andPipeline

May affect, not likely to adversely affect

Piping Plover
Charadrius melodus

Threatened

Threatened/
Endangered

Terminal andPipeline

May affect, not likely to adversely affect

Red KnotCalidris canufus rufa

Threatenedb

Not Listed

Terminal andPipeline

May affect, not likely to adversely affectGulf Sturgeon
Acipenser oxyrinchus desotoi

Threatened

Threatened

Terminal andPipeline

May affect, not likely to adversely affect

Pallid Sturgeon
Scaphirhynchus albus

Endangered

Endangered

Terminal andPipeline

May affect, not likely to adversely affect

Determination of EffectMammals

Birds

Fish

4-90

Table 4.7-1
Federal and State Listed Species Potentially Occurring in the Vicinity of the Project
Common Name
Scientific Name

Project
Component

Federal Status

State Status

Oceanic White-tip Shark
Carcharhinus longimanus

Threatened

Not Listed

Terminal andPipeline

May affect, not likely to adversely affect

Determination of Effect

Giant Manta Ray

Threatened

Not Listed

Terminal andPipeline

May affect, not likely to adversely affect

Loggerhead Sea Turtle
Caretta

Threatened

Threatened

Pipeline

May affect, not likely to adversely affect

Green Sea Turtle
Chelonia mydas

Threatened

Threatened

Pipeline

May affect, not likely to adversely affect

Hawksbill Sea Turtle
Eretmochelys imbricate

Endangered

Endangered

Pipeline

May affect, not likely to adversely affectKemp’s Ridley Sea Turtle
Lepidochelys kempii

Endangered

Endangered

Pipeline

May affect, not likely to adversely affect

Leatherback Sea Turtle
Dermochelys coriacea

Endangered

Endangered

Pipeline

May affect, not likely to adversely affect

ReptilesabcdSpecies protected under the BGEPA.
Species protected under the MBTA.
Species protected under the MMPA.
Potential impact on whales from carriers in the Gulf of Mexico

4-91

4.7.1

Federally Listed Threatened and Endangered Species

Review of the FWS Information for Planning and Conservation System database and the
FWS Louisiana Ecological Services list of endangered, threatened, and candidate species bycounty identified ten species as potentially present in Plaquemines Parish, including the West
Indian manatee, piping plover, red knot, Gulf and pallid sturgeon, and five species of sea turtles(FWS, 2018a). The NMFS Southeast Region lists 12 federally listed species as potentiallyoccurring in the Project area or along the LNG vessel transit route in the Gulf of Mexico, including
Gulf sturgeon, oceanic whitetip shark, giant manta ray, four species of whales, and five species ofsea turtles (NMFS, 2018). The FWS proposed the eastern black rail for listing as threatened under
the ESA in October 2018, and there is appropriate habitat for the eastern black rail within the
project area.
Both the Gulf sturgeon and federally listed sea turtles are managed jointly by FWS and
NMFS. The FWS jurisdiction over sea turtles is limited to their nesting habitat and there is nosuitable nesting habitat in the Project area; therefore, sea turtles only fall under NMFS jurisdiction
for the Project. Gulf sturgeon are under the FWS jurisdiction when in freshwater and NMFS whenin estuarine waters. The FWS confirmed in correspondence with Venture Global that because theMississippi River is freshwater at the LNG terminal site (river mile marker 55), it is under FWS
jurisdiction (Trahan, 2016). However, along the majority of the pipeline route, NMFS has
jurisdiction over Gulf sturgeon. Table 4.7-1 lists all of the federally listed species potentiallyoccurring in the Project area.
No federally listed plant species were identified as occurring within 50 miles of the Project.
A review of the FWS Environmental Conservation Online System indicated that designated critical
habitat under FWS jurisdiction does not occur in the Project area and would not be affected by the
Project (FWS, 2018b). In addition, the NMFS Southeast Region’s GIS data for critical habitat
only shows designated critical habitat for the loggerhead sea turtle in the vicinity of the Project
area (NOAA, 2014b); however, this critical habitat is 12 miles south of the pipeline system.
Venture Global, acting as a non-federal representative of FERC initiated informal
consultation with both the FWS and the NMFS. Based on correspondence with Venture Global(FWS, 2017b), the FWS indicated that the Project may affect four of the ten species identified
above (West Indian manatee, red knot, piping plover, and pallid sturgeon). Venture Global
submitted an informational and technical assistance request with the NMFS on September 24, 2015
and requested concurrence or additional comments from NMFS on January 18, 2017. Potential
impacts from Project construction and operation on these federally listed species are discussed
below.
During the draft EIS comment period, a commenter questioned the possibility of
reintroducing oiled sediments from oil spills during pipeline installation. Venture Global prepareda report identifying shoreline areas within the Barataria Basin (i.e., those land/water interfaces witha hydrological connection to the open waters of the Gulf) that have high re-oiling potential (i.e.,areas that have experienced periodic remobilization of weathered oil). The report indicates all of
the Project’s shoreline crossings have a re-oiling potential classification of “no oil observed.” If
weathered oil is encountered during construction, Venture Global would take the appropriate
precautions to prevent resuspension of contaminated media and notify the appropriate authorities.
4-92

Thus, no impacts on threatened or endangered species (federal and state) from re-oiled sediments
are expected.
4.7.1.1 Mammals
West Indian Manatee
The West Indian manatee is protected under both the ESA and the MMPA. In Louisiana,
the manatee is regularly found in Lakes Pontchartrain and Maurepas and their associated coastal
waters and streams (DOI, 2006). Manatees are found at depths ranging from approximately 5 feetto 20 feet in all types of coastal environments of the Gulf of Mexico and Atlantic Ocean (FWS,1999). This species typically occurs in Louisiana coastal areas when water temperatures are warm.
Fertl et al. (2005) reported that most manatee sightings in Louisiana occurred in June and July.
Manatees are known to travel long distances up coastal waterways from the Gulf of Mexico (FWS,2006). Year-round occurrence of manatees in the Project area is considered rare to uncommon,
including in the Mississippi River and the bays of the Barataria Basin (NOAA, 2014b). The causes
for the decline of manatees is generally related to human activity, entrapment in flood control
structures, boat and barge collisions, poaching, habitat loss, and pollution (FWS, 1999). However,manatee occurrences in Louisiana appear to be increasing, having been regularly reported insoutheastern Louisiana in the Amite, Blind, Tchefuncte, and Tickfaw rivers, as well as canals
within the adjacent coastal marshes (FWS, 2013).
Project-related activities that could cause temporary impacts on manatees include:•barge traffic associated with LNG terminal construction and operation of LNG carriers
in Gulf of Mexico and Mississippi River shipping channels;•

pile installation during dock and meter station construction; and•dredging/excavation associated with pipeline construction.

In areas of intense ship traffic, manatees can experience propeller or collision injuries;
however, most of these injuries are caused by small, fast moving vessels. Increased traffic within
the Mississippi River from LNG vessel transit to and from the LNG terminal could pose anincreased risk to manatees from vessel strikes. Barges and LNG carriers could collide withmanatees, which might cause injury or mortality, although such collisions would be unlikely on
the Mississippi River, where established, well-traveled, deep-water shipping lanes are used.
Although extremely rare in the general Project area, the manatee has been documented within local
waterbodies and could occur along the portion of the LNG transit routes in Plaquemines Parish
and the Gulf of Mexico. Even so, given the level of industrial activity and lack of foraging habitat
within the Mississippi River, their presence near the terminal site and pipeline system is unlikely.
Venture Global proposes to provide LNG ship captains with NOAA’s Vessel Strike Avoidance
Measures and Reporting for Mariners (NMFS, 2008), which outlines collision avoidance measuresin order to minimize impacts on manatees from vessel strikes.

4-93

Pipe laying in coastal wetlands requires the use of barges and other equipment. Excavation
and back-filling during pipeline construction through approximately 12 miles of open water could
impact the West Indian manatee. Water depths in these area range from approximately 5 feet to
25 feet and could provide suitable habitat for manatees. About 8.9 miles of the existing navigation
channel system in this area would be deepened by excavation/dredging to facilitate barge accessto the construction right-of-way. Barge operation, excavation/dredging, and other construction
activities could temporarily create disturbance and increase turbidity, which could displace
manatees (if present), increase stress, and disrupt normal activities. These activities would be
temporary, and conditions would return to normal shortly after construction. Operation of thepipeline system would not impact manatees.
Construction of the Project’s LNG loading docks and temporary berthing structures on theMississippi River, as well as meter station construction within Barataria Bay, would require pile
installation. Temporary increased underwater noise levels could affect manatees and other marine
mammals, including the bottlenose dolphin. Bottlenose dolphins, which are protected under the
MMPA and managed by NMFS, are discussed later in this section.
Acoustical modeling and analysis was conducted by Venture Global using NMFS’s
Technical Guidance for Assessing the Effects of Anthropogenic Sound on Marine Mammal
Hearing (NMFS, 2016). Under the NMFS guidance, marine mammals are categorized as lowfrequency cetaceans, mid-frequency cetaceans, high-frequency cetaceans, Phocid pinnipeds, orOtariid pinnipeds. Because the manatee’s hearing is most similar to mid-frequency cetaceans, forpurposes of the hydroacoustical analysis, they were assessed for that group.
The underwater noise thresholds for injury and behavioral disturbance for mid-frequency
cetaceans during pile driving activities are provided in table 4.7-2. For the purposes of thisanalysis, injury includes permanent hearing loss and mortality, and behavioral disturbances include
movement away from feeding grounds, temporary injuries, increased vulnerability to predators,
inability to communicate, and inability to sense the physical environment.
Table 4.7-2
Underwater Noise Thresholds for Marine Mammals During Pile Driving Activity
Underwater Noise Thresholdsb
Functional Hearing Group
Mid-Frequency Cetaceansa

Impact Pile Driving Disturbance Threshold

InjuryThreshold170 dB SELcum;
224 dB Peak

185 dB SELcum;
230 dB Peaka

From NMFS Technical Guidance for Assessing the Effects of Anthropogenic Noise on Marine Mammal Hearing: Underwater
Acoustic Thresholds for Onset of Permanent and Temporary Threshold Shifts.
b dB = decibel
Peak = peak sound pressure
RMS = root-mean-square sound pressure
SELcum = cumulative sound exposure level

The near-source (10-meter) unattenuated sound pressures for in-water pile driving basedon the impact pile driving method are provided previously in table 4.6-6. Table 4.7-3 provides asummary of the threshold distances for injury and disturbance of mid-frequency cetaceans during
unmitigated impact pile driving.
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Table 4.7-3
Threshold Distance for Injury and Disturbance to Mid-Frequency Cetaceans for Unmitigated Pile Driving
Threshold Distancea
Type of Pile and Installation Method

Injuryb(feet / meters)

Disturbancec(feet / meters)

60-inch-diameter Steel Pile – Impact Drivend

715 / 218

7,154 / 2,181

36-inch-diameter Steel Pile – Impact Driven

526 / 160.4

5,261 / 1,604

24-inch-diameter Steel Pile – Impact Driven

244 / 74.5

2,444 / 745

12-inch-diameter Steel Pile – Impact Drivene

71.5 / 21.8

715 / 218

12-inch-diameter Steel Pile – Vibratory Drivene

146.6 / 44.7

1,466 / 447aThreshold distance for injury is the distance to which noise could result in injury (e.g., mid-frequency cetaceans within 715 feet may
experience injury when 48-inch-diameter steel impact pile driving is occurring). Threshold distance for disturbance is the distance towhich noise could result in deviation from normal behavior (e.g., mid-frequency cetaceans from 715 feet to 7,154 feet may deviate fromnormal behavior when 48-inch-diameter steel impact pile driving is occurring).
b Distance calculated using the Companion User Spreadsheet to the NMFS Technical Guidance for Assessing the Effects of Anthropogenic
Noise on Marine Mammal Hearing: Underwater Acoustic Thresholds for Onset of Permanent and Temporary Threshold Shifts.
c Distances calculated by extrapolating the distance to permanent injury threshold according to the practical spreading loss equation,
Lreceiver = Lsource – 15 log (Rreceiver/Rsource).
d No data are readily available for the 48-inch-diameter piles that are proposed for the Project, so levels for 60-inch-diameter piles wereused instead.
e No information was provided by the applicant – Venture Global would be required to supply complete data prior to publication of the
final EIS.

Impacts expected on manatees from pile driving activities suggest thresholds for injury andbehavioral effects are possible if manatees are present in the Mississippi River or Barataria Bay.
However, historical information on manatee distributions and occurrence previously presented
supports the prediction that impacts would be highly unlikely from pile driving activities.
Historically, manatees have not been common in these waterbodies, and the probability of theiroccurrence in the future is considered low. Additionally, food resources for manatees are notcommon in the Mississippi River or Barataria Bay, and manatees typically would not travel on aheavily industrialized portion of the Mississippi River where background noise levels are expected
to be high. Also, in-stream noise at the terminal site is expected to attenuate to background levels
within shorter distances than those presented due to channel sinuosity and the terminal location
along the confined Mississippi River channel, which functions to attenuate the sound, resulting ina much more limited ensonified area. Where the meter stations are located in Barataria Bay,
ambient noise conditions from oil and gas exploration activities and infrastructure are common
and would likely mask pile driving noise levels.
The Underwater Noise Mitigation Plan submitted to the FWS, NMFS, and LDWF provides
an updated analysis of underwater noise impacts due to pile driving, including assumptions andsupporting calculations. The specific noise mitigations that would be implemented for underwaterpile-driving is discussed in section 4.6.2.3.
In accordance with the Underwater Noise Mitigation Plan, an EI with marine mammalmonitoring training and experience would be on-site during all pile-driving activities. The EI
would observe the Mississippi River and estuarine open waters for marine mammals for 20
minutes prior to the onset of, and continuously during, pile-driving activities. If a manatee is

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spotted within 150 feet of the active work area, work would not begin or would be halted until themanatee has moved out of this buffer zone.
Based on the manatee’s characteristics and habitat requirements, the lack of foraging
habitat along the LNG transit route, the rarity of manatees in the Project area, Venture Global’s
proposed avoidance and minimization measures (as referenced in the preceding paragraph),
implementation of the FWS-recommended measures (as referenced in FWS correspondence dated
February 2, 2017), and our recommendation in section 4.6.3.2, we conclude that the Project may
affect, but is not likely to adversely affect, the West Indian manatee.
Whales
The four federally listed whale species, blue whale, fin whale, sperm whale, and sei whale,
occur off the coast of Louisiana in the Gulf of Mexico (NMFS, 2018). Their distribution is limited
to the offshore ocean environment in depths greater than 200 meters (640 feet) (NOAA, 2012).
Because the terminal site and pipeline system are not offshore, there would be no impacts on
whales from Project construction. LNG carriers would travel through the Gulf of Mexico to theterminal site during Project operation, the potential for collisions between LNG vessels and whales
would be minimized by established measures and procedures, including Fisheries Southeast
Region Vessel Strike Avoidance Measures and Reporting for Mariners (NMFS, 2008), duringtransit. These are standard measures to be implemented to reduce the risk associated with vessel
strikes or disturbance of protected marine species. Measures include, but are not limited to:•maintaining watch for protected species;•

maintaining a buffer zone if species are sighted;•

reducing engine speed; and•reporting collisions or any sightings of injured or dead species protected under federal
law.

Venture Global would provide the NMFS (2008) document to LNG carrier captains andwould advocate compliance with the identified measures. Implementation of the above-mentioned
measures would minimize the risk of collisions with the four whale species protected under the
ESA, as well as with all marine mammals protected under the MMPA. Compliance with the
NMFS (2008) directive would result in minimal impacts on marine mammals. Based on thesefactors, the Project may affect, but is not likely adversely affect, the four federally listed whale
species.
4.7.1.2 Birds
Eastern Black RailThe eastern black rail is a subspecies of black rail that occurs in salt, brackish, andfreshwater wetlands in the eastern United States (east of the Rocky Mountains), Mexico, Central
America, and the Caribbean (FWS, 2018c). On October 9, 2018, the FWS proposed the eastern
black rail for listing as threatened under the ESA, with a final rule anticipated no later than October4-96

2019 (83 FR 50610). Under the ESA, federal agencies are required to confer with the FWS on
agency actions that may be likely to jeopardize a proposed species. The FWS would typically
finalize or withdraw the listing about 12 months after the proposal depending on comments
received; ESA protections become effective 30 days after the final listing rule is published.
Eastern black rails are found in a variety of salt, brackish, and freshwater marsh habitatsthat can be tidally or non-tidally influenced. Within these habitats, the birds occupy relatively highelevations along heavily vegetated wetland gradients, with soils that are moist or flooded to ashallow depth (83 FR 50610). Eastern black rails require dense vegetation cover that allows
movement underneath the canopy. Plant structure is considered more important than plant species
composition in predicting habitat suitability for the subspecies (83 FR 50610). Occupied habitat
tends to be primarily composed of fine-stemmed emergent plants (rushes, grasses, and sedges)
with high stem densities and dense canopy cover (83 FR 50610). However, when shrub densities
become too high, the habitat becomes less suitable for eastern black rails. Soils are moist to
saturated (occasionally dry) and interspersed with or adjacent to very shallow water (1 to 6
centimeters) (83 FR 50610).
Louisiana is not currently known to support a breeding black rail population (Watts, 2016).
There are no confirmed breeding records and historic observations during the breeding season are
rare. Most historic and recent records are from the Broussard Beach area of Cameron Parish(Watts, 2016), which is over 150 miles from the LNG facility site and the nearest point of thepipeline.
Primary threats to the eastern black rail include habitat loss due to continued alteration andloss of wetland habitats, land management practices that result in fire suppression (orinappropriately timed fire application that may cause direct mortalities), grazing, haying andmowing, and impounding of wetlands (FWS, 2018c). In addition, projected sea level rise andassociated tidal flooding, increased temperatures, decreased precipitation, increased drought andsevere weather events producing flooding or changes in wildfire frequency and intensity are all
likely to have significant impacts on eastern black rail populations and their habitat (FWS, 2018c).
The eastern black rail is proposed for listing as federally threatened and may become listed
prior to or during construction. Should the eastern black rail be listed, FERC staff would be
required to complete any necessary Section 7 consultation for the Project. Although there are no
known breeding black rail populations on Louisiana, there is potential habitat for the eastern black
rail in the Project area. However, the historic and recent records of this species are more than 150
miles from the proposed facilities. Therefore, we conclude that the Project may affect, but is not
likely to jeopardize the continued existence of the eastern black rail. .
Red KnotThe red knot, which is listed as threatened under the ESA, is a 9- to 11-inch medium-sized
shorebird. It has a long, sharp bill and long legs (NatureWorks, 2017). During the breeding season,
it has a rust colored face, chest, and undersides and dark brown wings. In winter, it has a grayhead, chest, and upperparts and a white belly. This bird has long greenish legs and a pointed black
bill. The red knot breeds in the central Canadian arctic but occurs in Louisiana during spring andfall migrations and winter months (generally September through March).

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No critical habitat has been designated for the red knot. Red knot breeding and roosting
habitat do not occur in the Project area. Outside of breeding season, it is primarily found inintertidal, marine habitats, especially near coastal inlets, estuaries, and bays. Additionally, theProject would not impact any beach foraging habitat. The Project would have temporary impacts
on potential salt and brackish marsh foraging habitat along the pipeline system right-of-way andbarge access channels (FWS, 2015). Construction disturbance could temporarily displace
individuals (if present) in marsh areas, resulting in increased stress and disruption of normal
activities. The locations of the Project’s aboveground facilities are not in areas that provide
suitable habitat for the red knot, and suitable foraging habitat is abundant outside of the Project
area. No permanent impacts on individuals of this species are anticipated.
No significant impacts on the red knot’s breeding or nesting activities are expected basedon temporary disturbance during pipeline system construction. As a result, we conclude that the
Project may affect, but is not likely to adversely affect the red knot.
Piping Plover
The piping plover is listed as threatened under the ESA. The piping plover is a small
shorebird approximately 7 inches long. These small, stocky shorebirds have a sand-colored upper
body, a white underside, and orange legs (FWS, 2018d). During the breeding season, adults havea black forehead, a black breast band, and an orange bill. Breeding birds have a single black
breastband, a black bar across the forehead, bright orange legs and bill, and a black tip on the bill.
The piping plover overwinters but does not breed in Louisiana, feeding at intertidal
beaches, mudflats, and sand flats with sparse emergent vegetation (FWS, 2018e). Piping plovers
typically move among sites as conditions change, but studies have indicated that they generally
remain within a 2-mile-long area along the beach (FWS, 2015). The main threat to piping plovers
is habitat loss. Development on beaches has reduced the amount of suitable wintering areas
available. Disturbance by humans and domestic animals forces wintering and migrating birds toincrease their energy expenditure and can also cause breeding plovers to abandon nests and young.
Other threats include predation from raccoons, skunks, and foxes (FWS, 2011).
The FWS has designated several areas as critical habitat for the piping plover on beachshorelines of barrier islands located near the Project. The nearest critical habitat for the piping
plover occurs on an unnamed island in the southern portion of Barataria Bay that is locatedapproximately 6.5 miles south of the pipeline system. This sandy beach habitat would not be
impacted by the Project, and the river bank at the terminal site is composed of rip-rap and concrete
mattresses; therefore, there is no foraging habitat at the terminal site. The pipeline system will not
impact areas of foraging habitat, such as intertidal beaches, mudflats, or sandflats. Based on thesefindings, we conclude that the Project may affect, but is not likely to adversely affect, the piping
plover and would have no effect on piping plover designated critical habitat.
4.7.1.3 Fish
Gulf Sturgeon
Historically, the Gulf sturgeon occurred from the Mississippi River to Charlotte Harbor,
Florida (TNC, 2018). The species was listed as federally threatened in 1991. Presently, this4-98

species’ range is limited to the Suwannee River in Florida and west to the Pearl River in
Mississippi and Louisiana. The FWS and NMFS share jurisdiction for the Atlantic sturgeon (Gulfsubspecies), with the FWS having sole responsibility in fresh waters and NMFS having sole
responsibility in marine waters. The two agencies share responsibility in estuarine waters basedon the lead agency for the federal action. NMFS is responsible for all consultations with FERC
for estuarine waters.
River systems supporting viable populations include the Pearl, Pascagoula, Escambia,
Yellow, Choctawhatchee, Apalachicola, and Suwannee rivers. The Gulf sturgeon rarely occurs in
the Mississippi River, due to the lack of spawning habitat (TNC, 2018). The best river habitat for
Gulf sturgeon is a long, spring-fed, free-flowing river with a hard bottom and steep banks. As
months get warmer, Gulf sturgeon migrate into brackish and salt water during the fall and feed inthese waters throughout the winter months. In the spring, they migrate into fresh water rivers andremain through the summer months (Wakeford, 2001). Gulf sturgeon move from the saltwater
estuaries and Gulf of Mexico bays to the upper reaches of their natal freshwater rivers to spawn.
After spawning, the sturgeon spends the summer in the lower reaches of the river before moving
back to the Gulf of Mexico in the fall.
Historically, the range of the subspecies included the Project area; however, currently, thespecies no longer occurs in the Mississippi River or in the Gulf of Mexico west of the Pearl River.
The Pearl River lies approximately 47 miles northeast of the Project area, and the nearest critical
habitat is approximately 22 miles east in Lake Borgne, Louisiana. Given that the Project is outside
the range for the Gulf sturgeon, construction of the LNG terminal and pipeline are not expected toaffect the Gulf sturgeon. Gulf sturgeon could occur in areas of the Gulf of Mexico traversed by
LNG vessels during operation. However, Gulf sturgeon are bottom feeders and tend to linger near
the bottom of the water column. Considering the low probability of occurrence and the bottomdwelling behavior of Gulf sturgeon, we conclude that the Project may affect, but is not likely toadversely affect, Gulf sturgeon.
Pallid Sturgeon
The pallid sturgeon was listed as endangered under the ESA on September 6, 1990 (55 FR
36641-36647). Since its listing, the status of the species has improved and is currently stable.
New information related to habitat extent and condition, abundance, and potential recruitment in
the Mississippi and Atchafalaya rivers has improved our understanding of the species in theseareas (FWS, 2014).
Pallid sturgeon are a bottom-oriented, large-river obligate fish inhabiting the Missouri andMississippi rivers and some of their tributaries from Montana to Louisiana (Kallemeyn, 1983).
Pallid sturgeon evolved in the diverse environments of the Missouri and Mississippi river systems.
Floodplains, backwaters, chutes, sloughs, islands, sandbars, and main channel waters formed thelarge-river ecosystem that met the habitat and life history requirements of pallid sturgeon. Pallid
sturgeon can be long-lived (15 to 20 years), with females reaching sexual maturity later than males(Keenlyne and Jenkins, 1993).
Habitat modification, including the construction of six Missouri River dams, as well aschannelization in the lower Missouri and Mississippi rivers, has been the primary threat to the

4-99pallid sturgeon (Krentz, 2004). The contemporary downstream extent of pallid sturgeon territory
ends near New Orleans, Louisiana, which is upstream of the Project area. Additionally, Kilgore
et al. (2014) reported that no pallid sturgeon have been collected below Mississippi River milemarker 81; this is approximately 25 river miles upstream of the Project area.
Impacts on the pallid sturgeon (if present) could include increased turbidity and noise
disturbance from pile driving during dock construction. Due to the low probability of pallid
sturgeon occurring within the Project area, and since no dredging would occur in upstream
spawning habitat, and per concurrence with the FWS (2017), we conclude that the Project may
affect, but is not likely to adversely affect, the pallid sturgeon.
Oceanic White-tip Shark
The oceanic white-tip shark, listed as threatened under the ESA, has a stocky build andcharacteristically rounded dorsal and pectoral fins that are white-tipped. The species is globally
distributed in temperate, subtropical, and tropical waters (Castro 1983). In the western Atlantic, it
occurs from Maine to Argentina, including the Caribbean and Gulf of Mexico (Young et al., 2018).
The oceanic white-tip shark is usually found offshore in the open ocean, on the outer continental
shelf, or around oceanic islands in water greater than 600 feet deep. It exhibits a strong preference
for the surface-mixed layer in warm waters above 68℉. However, it is capable of deep dives into
cooler waters for brief periods of time.
The primary threat to the oceanic white-tip shark is overutilization of the species forcommercial purposes (Young et al., 2018). It is harvested for its fins and suffers direct mortality
as by-catch as part of commercial fish-harvesting practices.
Since the oceanic white-tip shark is primarily found in deep ocean habitats, we anticipate
construction of the terminal and pipeline system would have no effect on the oceanic white-tip
shark. Additionally, operation of the pipeline system would have no effect on this species. Once
operational, LNG carriers that would call on the LNG terminal would traverse oceanic white-tip
shark habitat. The LNG carriers would not likely have a direct effect on individuals. However,the LNG carriers have the potential to indirectly affect individuals by temporarily disrupting
foraging. Therefore, we conclude that Project may affect, but is not likely to adversely affect, theoceanic white-tip shark.
Giant Manta Ray
The giant manta ray, listed as threatened under the ESA, is found worldwide in temperate,
subtropical, and tropical waters (Miller and Klimovich, 2016). The manta genus is distinctive due
to its size, terminal mouth, and long cephalic fins. There are two species in the manta genus—the
giant manta ray and the reef manta ray (Manta aflredi). The giant manta ray can reach a width of
22 feet and weigh up to 1.5 tons. Its range in the western Atlantic extends from New Jersey inNorth America to Uruguay in South America and includes the Caribbean and Gulf of Mexico(Miller and Klimovich, 2016). According to Miller and Klimovich (2018), sightings are, with afew exceptions, often sporadic despite its large range. The areas presented by Miller andKlimovich where sightings are more frequent do not include the northern Gulf of Mexico. The
giant manta ray is usually found offshore near productive coast lines within its range; however the

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giant manta ray has been observed in estuarine waters near ocean inlets (Miller and Klimovich,2018).
The primary threat to the giant manta ray is overutilization for of the species forcommercial purposes through direct harvest and as a result of by-catch. It is especially susceptible
to purse seines and gillnets.
Since the giant manta ray is primarily found offshore and occasionally in estuarine
environments, it is unlikely that construction of the terminal would affect this species. Since partof the pipeline system would be constructed in open, estuarine water, there is the potential that
construction of the pipeline could affect individuals. However, this is unlikely since the southern
extent of the pipeline system is over 7 miles from the nearest ocean inlet. We do not anticipate theoperation of the pipeline system to affect the giant manta ray. Once operational, LNG carriers thatwould call on the LNG terminal would traverse giant manta ray habitat. The LNG carriers would
not likely have a direct effect on individuals; however, the LNG carriers have the potential toindirectly affect individuals by temporarily disrupting foraging. Therefore, we conclude that
Project may affect, but is not likely to adversely affect, the giant manta ray.
4.7.1.4 Reptiles
Sea Turtles
The FWS and the NMFS share federal jurisdiction for sea turtles per a 1977 MOU
established joint jurisdictional authority for both the FWS and NMFS, with FWS responsible forsea turtles on land (nesting habitat) and the NMFS responsible for sea turtles in marine habitats(NMFS and FWS, 2015). Nesting in coastal Louisiana is extremely rare and has been observed atonly two locations in recent years. In the summer of 2015, two loggerhead sea turtles nested on
Grand Isle (Thibodeaux, 2016), which is over 10 miles from the Southwest Lateral TGP meterstation. The second closest nesting habitat is located east of the Mississippi River in the Breton
National Wildlife Refuge on the Chandeleur Islands (Dow et al., 2007). Based on the geographic
separation between the Project area and these locations, facility construction and operation is not
likely to impact adult nesting sea turtles. No critical habitat for nesting sea turtles occurs inLouisiana. The nearest critical habitat for the any sea turtle is LOGG-S-02 Sargassum forloggerhead sea turtles, which is a large section of the offshore Gulf of Mexico. This area occurs
approximately 12 miles south of the pipeline system (NMFS, 2014). Based on this information,
there would be no impacts on nesting sea turtles or nesting habitat. The discussion below concerns
the potential presence of, and impacts on, sea turtles in marine/estuarine habitat in the Project area.
All of the five federally listed sea turtles (leatherback sea turtle, Kemp’s ridley sea turtle,
loggerhead sea turtle, green sea turtle, and hawksbill sea turtle) are common to both estuarine andmarine environments along the southeastern coast of Louisiana. The presence of sea turtles in theMississippi River at the terminal site is not documented (NOAA, 2014b) and, because of theconsistent freshwater environment, their presence is considered unlikely and no impacts are
expected from construction at the LNG terminal site. All five species occur in portions of the
Project area that would be crossed by the two lateral pipelines (Southwest Lateral TGP andSouthwest Lateral TETCO), including Barataria Bay and Wilkinson Bay (NOAA, 2014b).

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The endangered leatherback sea turtle is named for its unique shell, which is composed ofa layer of thin, tough, rubbery skin strengthened by thousands of tiny bone plates that makes it
look “leathery.” The carapace is dark grey or black with white or pale spots, while the plastron is
whitish to black and marked by five ridges (Sea Turtle Conservancy, 2017). They are commonly
regarded as open-ocean, pelagic animals, but are also known to forage in coastal waters during
breeding. The leatherback sea turtle is highly migratory, preferring open ocean habitat outside ofbreeding season. The only known breeding sites identified in North America include southeast
Florida, Puerto Rico and the U.S. Virgin Islands. The species is considered rare along the Gulf
Coast; however, juveniles or adults can be present year-round (January through December)(NOAA, 2014b).
The endangered Kemp’s ridley sea turtle is one of the smallest of the sea turtles, with adults
reaching about 2 feet in carapace length and weighing up to 100 pounds. It has been documented
off the coast of Louisiana more than any other sea turtle. Nesting occurs from April to June, during
which time the turtles appear off the Tamaulipas and Veracruz coasts of Mexico. This species is
not known to nest on the Louisiana coast; however, it could utilize the estuarine and offshore
waters for foraging and migration during the non-nesting season. Juvenile Kemp’s ridley sea
turtles are common and considered abundant in the coastal waters of Barataria Bay and Wilkinson
Bay from April through September, and adults are common during the spring and summer near
the mouth of the Mississippi River (NOAA, 2014b; Fuller et al., 1987). This species’ foraging
habitat is the nearshore and coastal waters of the northern Gulf of Mexico (especially Louisiana
waters) as well as the Gulf of Campeche in the southern Gulf of Mexico. Kemp’s ridleys are often
found in salt marsh habitats.
The threatened loggerhead sea turtle prefers to feed in coastal bays and estuaries, as wellas in shallow waters of the continental shelf, and may occur in estuaries, coastal streams, salt
marshes, and river mouths. The distribution of loggerheads in Louisiana coastal waters is similar
to that of Kemp's ridley sea turtles; however, their abundance is greater west of Freeport, Texas.
Within Barataria Bay and Wilkinson Bay, both juveniles and adults are common, occurring fromMarch through November (NOAA, 2014b). Although designated critical habitat (LOGG-S-02)
for the loggerhead sea turtle occurs in waters just offshore of the Mississippi River delta, theProject would not impact this designated critical habitat.
Green sea turtle (threatened) adults are 3 to 4 feet in carapace length and the largest of the
Cheloniidae family. Green sea turtles are found in all temperate and tropical waters throughout
the world. In the Gulf of Mexico this species has been primarily documented in Texas embayments
where they frequent shallow water areas where marine grasses and algae occur. They are rare in
the open ocean and are not common to Louisiana coastal waters. Green sea turtles nest on open,
sloping beaches that have minimal disturbance. Adults and juveniles are occasionally found in
Barataria Bay and Wilkinson Bay between the months of March and November (NOAA, 2014b).
The endangered hawksbill sea turtle is one of the smaller sea turtles, with adults
approximately 2.5 to 3 feet in carapace length. Hawksbill sea turtles are widely distributed
throughout the Caribbean Sea and western Atlantic Ocean. They occur in shallow coastal areas,
oceanic islands, rocky areas, and coral reefs. This species is not common in both inshore or
offshore waters of Louisiana, and their occurrence in Barataria Bay and Wilkinson Bay isconsidered very rare. If present, they would occur from March through October (NOAA, 2014b).
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During construction of the pipeline system in estuarine open waters, temporary impacts on
sea turtles, including reduced water quality or interactions with barges and other vessels, could
result from pipe trenching and dredging/excavation for barge flotation channels. Pile driving
activities for meter station construction would increase in-water noise levels and could result in
potential injury or behavioral changes. If sea turtles are present at the time of construction, these
activities could temporarily cause displacement, increase stress, and/or disrupt foraging. The
meter stations are located in a portion of Barataria Bay where oil and gas exploration activities andinfrastructure are common and where operational maintenance regularly occurs. As a result,
impacts would be short term and minimal. The following provides information related to piledriving impacts on sea turtles based on Venture Global’s analysis.
Anthropogenic noise effects on sea turtles is largely unknown. Moein et al. (1995) and
McCauley et al. (2000) showed that sea turtles avoid seismic signals at levels between 166 dB
re 1 micropascal (μPA) and 179 dB re 1μPA. For this analysis, an un-weighted sound pressurelevel of 166 dB re 1 μPARMS has been used as the criterion for onset of behavioral effects. Per
Popper et al. (2014), sound pressure levels of 210 dB cumulative sound exposure level (SELcum)re 1 μPa2s and 207 peak sound pressure level (dB Peak) re 1 μPA are used as the criterion for
injury to sea turtles.
Sea turtle threshold distances for physical injury and behavior disturbance are based on thepile types and installation methods associated with the Project. The measured single-strike level
SELcum at 10 meters for vibratory-driven 12-inch-diameter piles has been adjusted to 196.6 dB
based on the equation,
SELcum = SELsingle strike + 10 ∗ log (14,400 seconds of driving per day).

Underwater noise levels expected to be generated from pile driving is provided in table 4.74. These noise levels are not expected to disturb sea turtles beyond the immediate vicinity of the
proposed activity. Venture Global has submitted an Underwater Noise Mitigation Plan to the
FWS, NMFS, and LDWF as discussed in section 4.6.2.3 including noise mitigation measures that
it would implement during pile-driving activities, which would minimize the impacts on all aquatic
resources, including sea turtles.
Table 4.7-4
Threshold Distance for Injury and Disturbance to Sea Turtles for Different Pile Types
Threshold Distance (feet / meters)a
Physical Injury

Behavior
DisturbanceType of Pile and Installation Method

Peak(207 dB)

Cumulative SEL(210 dB)

RMS(166 dB)

12-inch-diameter Steel Pile – Impact Drivenb

5.2 / 1.6

32.8 / 10

446 / 136

12-inch-diameter Steel Pile – Vibratory Drivenb

0.3 / 0.1

4.3 / 1.3

6.6 / 2adB = decibel
Peak = peak sound pressure
RMS = root-mean-square sound pressure
SEL = sound exposure levelb Distances calculated using a formula for underwater practical spreading loss, Lreceiver = Lsource – 15 log (Rreceiver/Rsource).

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Injury or mortality to sea turtles from dredging/excavation activities is not expected. The
barge-mounted clam-bucket (or equal) dredge proposed for pipeline construction is not known tocause sea turtle mortality because the slow speed of the barge allows sea turtles to disperse inadvance of construction activities (NMFS, 2015b). Dredging/excavation could have indirect
temporary impacts on foraging habitat by disturbing vegetation and increasing turbidity. Impacts
on sea turtles and their habitat would be insignificant given the abundant foraging habitat in
adjacent areas, the turtles’ ability to disperse to adjacent habitats, and the temporary nature of the
impacts.
Impacts on sea turtles from collisions with barges or other construction and operation
vessels could result in sea turtle injury or mortality. The relatively slow speed and sea turtle
maneuverability would make the chance of striking a sea turtle unlikely. Adoption of NMFS
guidance (NMFS, 2008) would minimize the potential for injury and mortality of sea turtles fromvessel strikes; therefore, we conclude that the Project may affect, but is not likely to adversely
affect leatherback, Kemp’s ridley, loggerhead, green and hawksbill sea turtles.
Although Venture Global has received concurrence from the FWS in a letter dated
February 3, 2017, this correspondence is more than 1-year old and needs to be updated to confirm
that no new species have been listed that could be present in the Project area.. In addition, theeastern black rail has been proposed for listing since the issuance of the draft EIS. We have also
not yet completed consultation with the NMFS. To ensure compliance with section 7 of the ESA,
we recommend that:•

Venture Global should not begin construction of the Project until:
a. FERC staff receives comments from the FWS and NMFS regarding the
proposed action;b. FERC staff completes formal consultation or conference with the FWS and
NMFS, if required; andc. Venture Global has received written notification from the Director of OEP
that construction or use of mitigation may begin.

4.7.2

State-listed Species

Based on information obtained from the LDWF, 16 state listed threatened or endangered
species are known to occur within Plaquemines Parish (LDWF, 2018a). Twelve of the 15 state
listed species (see table 4.7-1) are also federally listed and are discussed above in section 4.7.1.
No impacts on state listed species are expected from construction or operation of the Project.
Louisiana statutes governing wildlife species protection status are contained in Louisiana
Revised Statutes (LRS) 56 (Wildlife and Fisheries), while relevant rules and regulations adopted
by the Louisiana Wildlife and Fisheries Commission and the Secretary of the LDWF are found in
LAC 76.

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Take or harassment of wildlife species listed by the State of Louisiana as endangered or
endangered or under the federal ESA is a violation of state law. Three state-listed species are
known to occur in Plaquemines Parish:•bald eagle – state endangered;•brown pelican – state endangered; and•peregrine falcon – state threatened/endangered.

The potential presence of bald eagles in the Project area and potential impacts on thespecies, along with mitigation measures to be implemented, are discussed in sections 4.6.2.1 and4.6.2.2, respectively. The two remaining species, peregrine falcon and brown pelican, arediscussed below.
Peregrine Falcon
During migration periods, the peregrine falcon is present throughout Louisiana. The bird
may overwinter in coastal marshes and lakes, but is considered rare in the Barataria Basin. It is
most often observed over marshes, mudflats, and beaches during migration, where it feeds onshorebirds and waterfowl (Conner and Day, 1987). Peregrine falcons can be found overwinteringin areas with available prey, including farmland, marshes, lakeshores, river mouths, and tidal flats,
all of which could occur in the Project area. Peregrine falcons were observed during applicantdirected habitat surveys of the Project area in December 2015.
Potential impacts on peregrine falcon are similar to those discussed for other birds andwildlife in section 4.6, including temporary noise and other disturbance from construction
activities, temporarily altered foraging and roosting habitats, and permanent loss of foraging androosting habitats. Mitigation measures to reduce impacts on peregrine falcon are the same as thosedescribed in section 4.6.2.2 for birds and other wildlife.
Brown Pelican
The brown pelican was listed as endangered under the ESA in 1970, but was delisted in2008 due to recovery. The brown pelican is currently a state listed “rare” species. Today, thebrown pelican primarily occurs in coastal marine and estuarine environments along the Gulf of
Mexico coast from Mississippi to Texas, as well as along the Pacific Coast from Canada to SouthAmerica, and in the West Indies. Nesting colonies primarily occur on offshore islands away fromterrestrial mammal predation and human disturbance, and could occur on the island in Barataria
Bay where a colonial-nesting waterbird area has been documented by the LNHP (Venture Global,2017). Brown pelicans were observed during applicant-directed field surveys of the Project areain December 2015.
Potential impacts on brown pelicans are similar to those discussed for birds and otherwildlife in section 4.6.2.1, including temporary noise and other disturbance from construction
activities and temporarily altered marine and estuarine habitats from construction of the pipeline
system. There would be no permanent loss of marine and estuarine habitats. However, nesting

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colonies of brown pelicans could be affected should they occur adjacent to the Project area on theisland in Barataria Bay.
Mitigation measures to reduce impacts on brown pelican are the same as those describedin section 4.6.1.2 for birds and other wildlife and in section 4.6.2.2 regarding the colonial-nesting
bird area.
4.8

LAND USE, RECREATION, AND VISUAL RESOURCES

4.8.1

Land Use

Venture Global leases the terminal property and would construct its facilities on primarily
undeveloped land on the west side of the Mississippi River at mile marker 55. The LNG terminal
would be on land bounded by undeveloped land and coastal marshlands to the south and west andfastlands to the east.
The Project would affect seven general land use types based on the National Land Use
Land Cover (LULC) database (USGS, 2011). The definitions of each land use type is as follows:•

Cultivated Crops: Includes active cropland, pasture, and or hayfields;•

Developed Commercial/Industrial: Includes power or utility stations, manufacturing
or industrial plants, paved areas, commercial facilities, and roads;•

Herbaceous: Includes non-forested uplands;•

Open Water: Includes waterbodies such as bays, bayous, and streams;•

Wetlands: Includes emergent, scrub-shrub, and wooded wetlands;•

Shrub-Scrubland: Includes upland shrub-scrubland; and•Forest: Includes upland forest.

Table 4.8-1 summarizes the acreage of each land use type that would be affected by the
LNG terminal and pipeline system. For a discussion on habitat types and field surveys, see section
4.5.1.

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Table 4.8-1
Land Use Requirements for the Projecta, bCultivated Crops(acres)Developed
Commercial/
Industrial(acres)Herbaceous(acres)Open Water(acres)Wetland(acres)ScrubShrub(acres)Forested(acres)Total(acres)Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Terminal Facilities

0.0 / 438.9

0.0 / 10.1

0.0 / 2.0

0.0 / 0.0

0.0 / 6.0

0.0 / 1.3

0.0 / 76.2

0.0 / 534.5

Land-Based Marine
Facilities

0.0 / 0.0

0.0 / 1.1

0.0 / 0.0

0.0 / 0.0

0.0 / 6.3

0.0 / 0.0

0.0 / <0.1

0.0 / 7.4

TemporaryWorkspace

2.0 / 0.0

4.3 / 0.0

0.0 / 0.0

1.3 / 0.0

5.5 / 0.0

0.0 / 0.0

<0.1 / 0.0

13.1 / 0.0

Water-Based Marine
Facilities

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 10.7

0.0 / 3.9

0.0 / 0.0

0.0 / 0.0

0.0 / 14.6

Utility Workspace

4.1 / 0.0

2.3 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

6.4 / 0.0

Eastern Workspace

0.0 / 80.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 80.0

Marine Workspace

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

69.9 / 0.0

2.8 / 0.0

0.0 / 0.0

0.0 / 0.0

72.7 / 0.0

Terminal Total

6.1 / 518.9

6.6 / 11.2

0.0 / 2.0

71.2 / 10.7

8.3 / 16.2

0.0 / 1.3

<0.1 / 76.2

92.2 / 636.5

Pipeline

0.0 / 0.1

0.0 / 0.1

0.0 / 33.0

281.2 / 92.6

38.5 / 2.2

0.0 / 0.0

0.0 / 0.0

319.7 / 128.0

Meter Station, MLV
Site

0.0 / 0.0

0.0 / 0.3

0.0 / 0.0

62.5 / 8.9

0.0 / 0.1

0.0 / 0.0

0.0 / 0.0

62.5 / 9.3

ATWS

0.0 / 0.0

0.2 / 0.0

1.8 / 0.0

35.2 / 0.0

9.2 / 0.0

0.0 / 0.0

0.0 / 0.0

46.4 / 0.0

Access Road andBarge Channels

0.0 / 0.0

0.0 / <0.1

0.1 / 0.0

322.5 / 0.0

0.7 / 0.0

0.0 / 0.0

0.0 / 0.0

323.3 / <0.1

Pipeline

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

40.1 / 0.0

19.9 / 0.0

0.0 / 0.0

0.0 / 0.0

60.0 / 0.0

Meter Station, MLV
Site

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

Site Component
Terminal Site

Pipeline System
Southwest Lateral TGP

Southwest Lateral TETCO

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Table 4.8-1
Land Use Requirements for the Projecta, bCultivated Crops(acres)Developed
Commercial/
Industrial(acres)Herbaceous(acres)Open Water(acres)Wetland(acres)ScrubShrub(acres)Forested(acres)Total(acres)Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

Temp / Perm

ATWS

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

3.0 / 0.0

1.7 / 0.0

0.0 / 0.0

0.0 / 0.0

4.7 / 0.0

Access Road andBarge Channels

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

0.0 / 0.0

Pipeline Total

0.0 / 0.1

0.2 / 0.4

1.9 / 33.0

744.5 / 101.5

70.0 / 2.3

0.0 / 0.0

0.0 / 0.0816.6 / 137.2

PROJECT TOTAL

6.1 / 519.0

6.8 / 11.6

1.9 / 35.0

815.7 / 112.2

78.3 / 18.5

0.0 / 1.3

<0.1 / 76.2

908.8 / 773.8

Site Component

a An “undisturbed area” totaling 77.0 acres located within the LNG terminal site is not included in this table because it will not be impacted.
b Construction impacts acreages are the sum of the temporary and operational impact acreages.

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4.8.1.1 LNG Terminal
The LNG terminal, including adjacent workspaces, would permanently occupy 625.8 acresof land, the water-based marine facilities would permanently occupy 10.7 acres, and an additional
92.2 acres would be temporarily occupied by workspaces. The site is currently zoned as Heavy
Industrial and is primarily undeveloped. The majority of the permanent terminal site, including
adjacent workspaces (approximately 525.0 acres, or 82 percent), is cultivated cropland that
historically has been used for sugar cane production but currently used for cattle grazing and hay
production. The remainder of the terminal site, including adjacent workspaces, includes 76.2 acresof forested land, 17.8 acres of developed commercial/industrial land, 24.5 acres of wetland, 1.3
acres of scrub-shrubland, and 2.0 acres of herbaceous land. Figure 4.8-1 shows the detailed land
uses at the LNG terminal. Each of these detailed land uses fall within one of the seven generalcategories
Access Roads
The proposed terminal site would be accessed via SH 23 in addition to two permanent
access roads that would be constructed for the terminal site. The permanent access road impacts
are included in the previously provided terminal acreages and primarily consist of cultivatedcropland.
4.8.1.2 Pipeline System
The proposed 15.1-mile-long, Southwest Lateral TGP and 11.7-mile-long Southwest
Lateral TETCO would be collocated and constructed on newly created right-of-way. The pipelines
would generally require a total construction corridor ranging from 130 feet to 300 feet, dependingon the construction method used for a particular section. The conventional lay method and push
lay methods would require a construction corridor of 130 feet, consisting of a permanent right-ofway of 80 feet plus 50 feet of temporary construction workspace. The 300-foot-wide construction
right-of-way required for the barge lay sections of each collated pipeline would overlap by 250
feet, resulting in a total construction right-of-way width of 350 feet. The permanent right-of-way
at these locations would be 80 feet wide. Construction of the Southwest Lateral TETCO during
Phase II would disturb an 80-foot-wide portion of the same construction right-of-way used for theSouthwest Lateral TGP during Phase I for conventional lay and push lay segments. For barge lay
segments, construction of the Southwest Lateral TETCO during Phase II would disturb a 250-footwide portion of the same construction right-of-way used for the Southwest Lateral TGP during
Phase I.
The predominant land use types affected by construction of the pipeline, including theconstruction right-of-way, would be open water (846.0 acres), wetlands (72.3 acres), andherbaceous land (34.9 acres). Cultivated cropland and developed commercial/industrial land
would account for just 0.1 acre and 0.4 acre, respectively. Figure 4.8-2 shows the detailed land
uses along the pipeline system. Each of these detailed land uses fall within one of the seven generalcategories

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Open Water
Developed, Open Space
Developed, Low Intensity
Developed, Medium Intensity
Developed, High Intensity
Barren Land
Deciduous Forest
Evergreen Forest
Mixed Forest
Shrub/Scrub
Herbaceous
Hay/Pasture
Cultivated Crops
Woody Wetlands

M

isEmergent Herbaceous Wetlands

si

ss

ip

pi

Ri

ve

r

Louisiana

0

0.5

1
Miles
This information is for environmental review purposes only.

Terminal Site Boundary
Eastern Workspace
SW Lateral TETCOSW Lateral TGPp

Figure 4.8-1
USGS Land Cover Types at the Terminal Site
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

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Open Water
Developed, Open Space
Developed, Low Intensity
Developed, Medium Intensity
Developed, High Intensity
Barren Land
Deciduous Forest
Evergreen Forest
Mixed Forest
Shrub/Scrub
Herbaceous
Hay/Pasture

M

Cultivated Crops

issi

Woody Wetlands

ss

ip

pi

Emergent Herbaceous Wetlands

Ri

ve

r

TETCO
Interconnect

!
.

TGP
Interconnect!
.

Louisiana

0

2.5

5
Miles
This information is for environmental review purposes only.

Terminal Site Boundary
Eastern Workspace
SW Lateral TETCOSW Lateral TGP!
. InterconnectpFigure 4.8-2
USGS Land Cover Types for the Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

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Access RoadsThe Intracoastal Waterway would be used for delivery of coated pipe via barge to theProject area. Walker Road and SH 23 would likely serve as the primary routes to transport thejoints from the barge dock location to the pipe stringing areas. One temporary and one permanent
access road would be required for the pipeline system. The permanent access road would impact
less than 0.1 acre of land, while the temporary access road would impact 0.7 acre of land primarily
consisting of wetlands.
4.8.1.3 Land Use Impacts and Mitigation
Impacts on cultivated cropland, developed commercial/industrial, herbaceous land, andforest are discussed below. Impacts on open waters and wetlands are discussed in sections 4.3.2.2
and 4.4.2, respectively.
Cultivated Cropland
LNG Terminal
The LNG terminal would be located on cultivated croplands historically used for sugar
cane production and cattle grazing. Soils classified as prime farmland would be affected by the
Project (see section 4.2.1.2). However, no specialty crops would be affected during construction
or operation of the Project facilities.
Construction at the proposed terminal site would permanently affect approximately 518.9
acres of cultivated cropland, while 6.1 acres would be temporarily affected. Impacts on cultivatedcropland within the terminal site would include the permanent loss of production during
construction and after construction is completed. Impacts could also include soil rutting orcompaction due to construction equipment. Operation of the Project would result in the permanent
conversion of the 518.9 acres of agricultural lands to industrial/commercial use.
Although construction and operation of the LNG terminal represents a permanent loss ofcultivated cropland, the Project would be consistent with the Port of Plaquemines Master Plan as
being fully developed and not designated as future agricultural uses. Therefore, the Project would
not represent a significant impact on agricultural uses within the area.
Pipeline System
The Southwest Lateral TGP pipeline would affect approximately 0.1 acre of cultivatedcropland within the 130-foot-wide right-of-way. The Southwest Lateral TETCO would becollocated within the same right-of-way as the Southwest Lateral TGP and construction of theSouthwest Lateral TETCO would not affect any additional cultivated croplands. Impacts on 0.1
acre of cultivated cropland would include the permanent loss of production and could include soil
rutting or compaction due to construction equipment. Operation of the Project would result in theconversion of only 0.1 acre of agricultural land to industrial/commercial.
Although construction and operation of the pipelines represent a permanent loss ofagricultural land, the Project would be consistent with the Plaquemines Parish Master Plan for
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development. Therefore, the Project would not represent a significant impact on agricultural uses
within the area.
Developed Commercial/Industrial
LNG Terminal
Construction of the LNG terminal would affect 17.8 acres of developed
commercial/industrial lands. The majority of this land consists of roads and levees along theMississippi River. Construction impacts on these industrial/commercial areas during construction
would include increased dust from exposed soils, construction noise, and traffic congestion. Dust
and noise levels would be minimized, as described in section 4.11.1.4 and 4.11.2.3, respectively.
Impacts on traffic are discussed in section 4.9.8.1. Operation of the LNG terminal would
permanently affect 11.2 acres and would remain developed commercial/industrial use.
Pipeline System
Construction of the Southwest Lateral TGP would permanently affect 0.6 acre of developed
commercial/industrial land, consisting largely of roads.
No additional developed
commercial/industrial land would be affected by construction of the Southwest Lateral TETCO.
Impacts during construction could include increased dust from exposed soil, construction noise,
and impacts on traffic flow.
Herbaceous Lands
LNG Terminal
Herbaceous land at the terminal site primarily includes open herbaceous areas located northof SH 23. Herbaceous land totaling 2.0 acres would be affected by construction and operation of
the LNG terminal. Construction impacts would include clearing of vegetation, and the lands would
be permanently converted from open lands to industrial/commercial.
Pipeline System
Herbaceous lands affected by the pipelines would include 34.9 acres of open herbaceousarea to the south of Lake Hermitage Rd. The affected open herbaceous land would all be locatedwithin the right-of-way for the pipeline, temporary access roads, and ATWS. Construction-related
impacts on herbaceous open land would include the removal of vegetation and disturbance of soils.
However, following construction, the 33.0 acres within the permanent right-of-way used forpipeline construction and the 1.9 acres temporarily used for access and ATWS would be allowed
to revert to preconstruction condition.
Scrub-Shrub
LNG Terminal
One small patch of scrub-shrub land at the terminal site is located between the Mississippi
River levee and SH 23. This area is 1.3 acres in size and is located within the operational footprint
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of the LNG terminal. This would result in the scrub-shrub land being converted to herbaceous
land or developed commercial/industrial land.
Pipeline System
No scrub-shrub land would be affected during construction or operation of the pipeline
system.
Forest
LNG Terminal
Forest land at the terminal site is primarily located north of SH 23 and includes deciduous,
evergreen, and mixed forest. Construction and operation of the LNG terminal would affect 76.2
acres. An additional 12.0 acres of forest at the terminal site would remain undisturbed. All of theforest land within the liquefaction site would be permanently converted to developed
commercial/industrial land. Construction impacts on disturbed forest land would result in thepermanent removal of trees and other vegetation.
Pipeline System
No forest land would be affected during construction or operation of the pipeline system.
Residential
LNG Terminal
Some low-density residential areas are located approximately 0.2 mile off of Lake
Hermitage Road to the west and southwest of the terminal site. However, no residential land islocated within or adjacent to the terminal site.
Pipeline System
Similar to the terminal, the closest residential area is located off of Lake Hermitage Road.
Residential areas are not located within or adjacent to the pipeline system rights-of-way. Venture
Global is not anticipated to require any residential properties for construction access. Construction
impacts on these residential properties during construction would include construction noise andtraffic congestion. Dust and noise levels would be minimized, as described in section 4.11.1.4 and
4.11.2.3, respectively.
4.8.2

Landowner and Easement Requirements

4.8.2.1 LNG Terminal
Venture Global currently leases the 632-acre site for the proposed terminal site. The
property is owned by the Port of Plaquemines. A lease option agreement grants Venture Global
the exclusive right to lease the terminal site for up to 70 years. Additionally, a USACE maintained
levee along the Mississippi River is controlled by the federal government but resides within port

4-114

owned property. Aside from the Port of Plaquemines and the USACE, no lands owned or managed
by federal, state, or local agencies would be directly affected by the LNG terminal.
4.8.2.2 Pipeline System
Construction and operation of the Southwest Lateral TGP and Southwest Lateral TETCO
would require a total of 953.9 acres of land, with all but one parcel being privately owned land.
Venture Global would need to secure easements that convey temporary and permanent rights-ofway. For the aboveground facilities, Venture Global would obtain easement agreements orpurchase the land outright.
An easement agreement would specify compensation to a landowner for the right of
Venture Global to use the property during construction and operation of the pipeline system. The
easement agreement would address damages to property during construction, restrictions on
permitted uses within the permanent right-of-way, and post-construction restoration specifics.
If an easement cannot be negotiated with a landowner and the Project has been certified by
FERC, Venture Global could use its right to eminent domain under section 7(h) of the Natural Gas
Act and the procedure set forth under the Federal Rules of Civil Procedure (Rule 71A) to obtain
the right-of-way and construction areas. Venture Global would still be required to compensate thelandowner for the right-of-way and any damages incurred during construction. The level ofcompensation would be determined by a court according to state or federal law.
4.8.3

Planned Developments

4.8.3.1 LNG Terminal
There are no residential areas or subdivisions currently proposed within a 0.25-mile radiusof the terminal site according to the Plaquemines Parish Department of Permits, Zoning, andPlanning. There are also no commercial/industrial projects planned or announced within a 1-mileradius of the terminal site. The closest commercial/industrial facility planned near the terminalsite is the proposed Gulf Coast Methanol Complex, which would be located 2.2 miles northwest.
Upgrades to existing levees planned by USACE, as well as relocation of existing drainage canals
by the Plaquemines Parish Government, are adjacent to the terminal site. Each of these projects,
as well as other planned commercial/industrial development projects in the broader area, arediscussed in the cumulative impact analysis provided in section 4.13.
Plaquemines Parish published a draft, final Comprehensive Master Plan in 2012, which
designates future land uses on all developable properties within the parish. The plan’s future land
use maps are include in the “Land Use” technical addendum to the “Community Assessment.” The
LNG terminal site has three future land use designations on different portions of the site, including“port terminal complex,” “major industries,” and “business park.” The LNG terminal, a private
port terminal with a major industrial component, is largely consistent with the future land use
designations. The majority of the site is designated “port terminal complex” and “majorindustries,” while a minority portion is “business park,” itself a type of non-residential/ nonagricultural use.

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4.8.3.2 Pipeline System
There are no residential areas or subdivisions currently proposed within a 0.25-mile radiusof the pipeline system nor commercial/industrial projects planned or announced within a 1-mileradius of the pipeline system, according to the Plaquemines Parish Department of Permits, Zoning,and Planning. Upgrades to existing levees adjacent to the pipeline system are planned by the
USACE. Plaquemines Parish is relocating drainage canals adjacent to the pipeline system as aresult of the USACE levee project. These canals would not be affected by the Project. These
projects, as well as other planned commercial/industrial development projects in the broader area,
are discussed in the cumulative impact analysis provided in section 4.13.
4.8.4

Recreation and Special Interest Areas

Construction and operation of the LNG terminal and pipeline system would not directly
affect designated recreational areas or special interest areas. There are three wildlife refuges, aprivate conservation area, one historic park and preserve, five restoration areas, and three publicmarinas located in proximity to the Project. These recreational and special interest areas are
discussed below and shown in figure 4.8-3.
Wildlife Refuges and Preserves/Conservation Area
There are no wildlife refuges, preserves, or conservation areas located within 16 miles of
any Project workspace. The three wildlife refuges located in Plaquemines Parish Breton National
Wildlife Refuge, Delta National Wildlife Refuge, and Pass A Loutre State Wildlife Refuge, are all
located over 35 miles from any Project workspace and would not be impacted by Project
construction or operation activities. A private conservation area, Woodland Trail and Park, and apreserve, Jean Lafitte National Historic Park and Preserve are both located over 16 miles from any
Project workspace and would not be impacted by Project construction or operation.
National Estuary and Restoration Areas
The Barataria-Terrebonne National Estuary is located between the Mississippi andAtchafalaya Rivers in south Louisiana. The estuary’s watershed includes the terminal site andpipeline system right-of-way. The Barataria-Terrebonne estuarine complex became a National
Estuary in 1990, and the Barataria-Terrebonne National Estuary Program was created under the
EPA administered National Estuary Program (NEP). The goal of the NEP is the prevention ofactivities that: (1) threaten an estuary’s public water supply; (2) are harmful to shellfish, fish, andwildlife populations; and (3) negatively impact recreational opportunities for estuary residents.
Venture Global would be required to adhere to any NEP recommendations that have been adopted
by LDEQ, LDNR, and/or USACE as conditions to a permit.

4-116

(
!

Marina(!

Scenic Areas, Parks, & Historic Sites

MyrtleGrove
MarinaDavant Park(!

Woodland
Plantation

(
!
(
!

(
!

West Pointa la Hache
Marina(!
Lake
Hermitage
MarinaTETCO !
.

TGP

!
.

Louisiana

0

2.5

5
Miles
This information is for environmental review purposes only.

!
.

Terminal Site Boundary
SW Lateral TETCOSW Lateral TGP
Interconnect and Meter Stationp

Figure 4.8-3
Recreational Use Areas within 5 miles of
Proposed Project
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

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Construction of the pipelines would require dredging of channels within the BaratariaTerrebonne estuary to provide temporary access for pipeline lay barges and support vessels.
Trenching would also be required in areas where the pipeline would be located in open water.
Recreational boaters in the Barataria-Terrebonne estuary may be temporarily prevented from using
channels during dredging operations. Users may also observe a temporary increase in barge traffic
during construction of the pipeline system. Venture Global would mark construction areas withwarning signs and navigation lights to ensure the safety of recreational boaters. Impacts on boaters
would be temporary and minor.
Several existing and proposed restoration sites managed by the Louisiana Coastal
Protection and Restoration Authority are located in the Barataria Basin near the pipeline system.
Barataria-Terrebonne National Estuary Program Gulf Ecological Management Site is locatedapproximately 1.0 mile from the pipeline system. The Barataria-Terrebonne National Estuary
Program Gulf Ecological Management Site Program is an initiative of the Gulf of Mexico
Foundation, the EPA Gulf of Mexico Program, and five Gulf of Mexico states to restore lost or
damaged sensitive habitats. Impacts on the restoration area are expected to be minor andtemporary.
Lake Hermitage Marsh Creation (BA-42), Fringe Marsh Repair, West Pointe a lá Hache
Siphon Diversion, and Bayou Grande Cheniere Marsh and Ridge Restoration are four otherrestoration areas located between 3.0 miles and 7.7 miles from any Project component. No impacts
are anticipated at these restoration areas from either direct contact or indirect tidal influences.
Public Marinas
West Pointe a lá Hache Marina is located 0.4 mile northeast of the terminal site. The
marina is located off of the Back Levee Canal that parallels the east bank of the Mississippi River.
Lake Hermitage Marina is located 1.8 miles to the east of the Southwest Lateral TGP. The marina
consists of a boat launch off of West Bayou Lane in the Hermitate Bayou. St. Jude Hump Public
Boat Launch is located 1.8 miles southeast of the terminal site. Woodland Plantation is located
0.8 mile east of the terminal site. None of these facilities are expected to be impacted by the
Project.
Military Installations
The Military Aviation and Installation Assurance Siting Clearinghouse coordinated with
the DoD for an informal review of the Project. In correspondence sent to the Commission on June4, 2018, the Military Aviation and Installation Assurance Siting Clearinghouse concluded that the
Project would have a minimal impact on military training and operations conducted in the area.
No mitigation was recommended, but further communication with the Military Aviation andInstallation Assurance Siting Clearinghouse was requested. As such, we have continued to include
the Military Siting Clearinghouse in all notifications associated with the NEPA process.
4.8.5

Hazardous Waste Sites

Review of regulatory databases revealed two hazardous waste sites located within 5.0 milesof the terminal site. Both sites, Elmwood Marine Services and International Marine Terminals,
are located over 1 mile from the terminal site and are reported to be in compliance, with no4-118

violations. Although not anticipated, if hazardous waste is encountered during construction,
Venture Global would stop work in the vicinity of the hazardous waste and implement the Project’s
SPCC Plan outlining the steps to be taken, including reporting, coordination, and clean up.
4.8.6

Visual Resources“Visual resources” refers to the composite of basic terrain features, geologic features,hydrologic features, vegetation patterns, and anthropogenic features that influence the visualappeal of an area for residents or visitors. In general, impacts on visual resources may occur during
construction when large equipment, excavation activities, spoil piles, and materials are visible tolocal residents and visitors. During operation, impacts on visual resources would occur whenfacilities, or portions of facilities, and their lighting are visible to residents and visitors. The degreeof visual impact resulting from the Project would be highly variable among individuals, and would
typically be determined by the general character of the existing landscape and the visuallyprominent features of the Project facilities.
The region of influence for the evaluation of visual resources includes a 2-mile buffer
around the Project. This distance provides for the maximum distance at which the tallest Projectfeature would be visible and recognizable. This area also comprises the Project viewshed (i.e., thearea that would have visibility of the Project).
4.8.6.1 LNG Terminal
The area surrounding the LNG terminal site includes industrial operations, agricultural andundeveloped land, and a few residential communities. Traveling 6 miles north of the site on SH
23 viewers can see the largest existing industrial operation in the area, a petrochemical plant(Phillips 66 Alliance Refinery). Closer to the LNG terminal site, just over one mile north, is a coaltransfer facility, International Marine Terminals. Across the river is another coal transfer facility,
United Bulk Terminal, and a cargo handling terminal, Associated Terminals, both within two
miles. Visible on-site features at the coal transfer facilities include large coal stockpiles,
conveyance systems, permanent metal office buildings, temporary office buildings, docks,
berthing areas, and dirt or gravel piles. The cargo handling terminal on the other side of the river
specializes in the transfer of grain between barges and ocean vessels, and its most conspicuous
features are numerous rows of floating barges and a massive floating grain elevator. Although
Phillips 66 Alliance Refinery is 6 miles from the Project site, the visible facilities include
aboveground storage tanks, stacks, permanent metal and brick office buildings, temporary officebuildings, berthing areas, dock loading arms/cranes, and large graveled parking and laydown areas.
Directly across the Mississippi River from the LNG terminal site is fallow and unmaintained
agricultural land. The LNG terminal site, itself, is currently unmaintained agricultural, boundedby more agricultural land on both sides. The primary viewers within the terminal site viewshed
include local residents, drivers (including business owners and employees), visitors for the existing
industrial businesses along SH 23 and within the vicinity of the terminal site, and recreational andcommercial users of the Mississippi River and its local environs.
After completion of construction, the LNG terminal would include four LNG storage tanks(188 feet tall), as well as cold flare (280 feet tall), warm flare (280 feet tall), low-pressure flare

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(175 feet tall), and marine vapor control (100 feet tall) facilities. Lighting also would be used at
the terminal site during evening activities and for safety.
Venture Global conducted a visual assessment for the terminal site and pipeline system,
which included the review of views from ten key observation points (KOPs). The assessment
considered viewer sensitivity (i.e., expectations of the observed areas) and visual quality. Visual
impacts were described as minor, moderate, or significant utilizing the definitions provided below.
•

Minor Impact: The Project would be minimally visible to a low number of sensitive
viewers, and distance or compatibility with existing land uses would not make theProject stand out.

•

Moderate Impact: The Project would be minimally visible to a moderate number ofsensitive viewers; Project elements would result in an increase in the industrial
viewshed that is incompatible with existing land uses.

•

Significant Impact: The Project would be highly visible to a large number of sensitive
viewers and would negatively affect the quality of the visual landscape.

The ten KOP locations included the following:•

KOP-1 End of Squirrel Road – View to Northeast – Towards Terminal Site;•

KOP-2 Mainline Valve Site – View to Northwest – Towards Lake Hermitage Road;•

KOP-3 Lake Hermitage Road – View to Northeast – Towards Terminal Site;•

KOP-4 Lake Hermitage Road and East Shirley Road – View to East – Towards
Terminal Site;•

KOP-5 End of Suzie Street – View to Southeast – Towards Terminal Site;•

KOP-6 SH 23 – View to West – Towards Terminal Site;•

KOP-7 Shed off SH 23 – View to West – Towards Terminal Site;•

KOP-8 Griffen Community Center – View to South – Tree buffer;•

KOP-9 Davant Park – View to South – Tree buffer; and•

KOP-10 SH 15 Towards United Bulk Terminal – View to West - Existing Industrial
View.

Based on a review of these KOPs, visual impacts associated with the terminal site would
be experienced during construction, when the site landscape would be temporarily dominated byheavy equipment, materials storage, and infrastructure. These impacts would be at least partiallyvisible to local residents, drivers/visitors along SH 23, visitors to nearby marinas, and boaters on
the Mississippi River and on open waters south of the terminal site. Other potential viewers
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include users of those areas developed for industrial purposes along the Mississippi River north of
the terminal site. Viewers would not likely be present in the remaining areas surrounding theterminal site, as these areas largely consist of marsh and pasture land.
Residents would have views of the terminal site during construction. The closest residence
is 0.14 mile southwest of the site, and low-lying vegetation would not block the entirety of
construction activities especially when coupled with the elevated nature of most residential
structures in the area. Visual screening may be present for other residences at ground level withexisting scrub-shrub and tree cover.
Residential views of the facility would include the construction of the trestle bridgecrossing SH 23 and the federal levee on the Mississippi River. The temporary aerial conveyor
system would be visible, as well. This conveyor system would be situated approximately 370 feetnorth of the trestle bridge and would be supported on a similar trestle system. Construction lighting
also may be visible, as temporary light-emitting diode fixtures would be installed on buildings orwooden poles, and portable lighting would also be installed. Increased barge traffic during
construction also may be visible from some of the residential areas near the terminal site.
Drivers (including residents, commuters, business owners and employees, and/or visitors)
along SH 23 would be able to see the terminal site on either side of the highway. As previously
noted, SH 23 is a National Scenic Byway. While this area of the byway is dominated by industrial
views and zoned for future industrial projects, Project construction (and eventual operation) would
be visible. Among the features that would be visible would be the trestle bridge, the aerial
conveyor, the perimeter wall, and other infrastructure. The perimeter wall would provide somevisual buffer, although it would not shield the full view of the terminal site.
Two recreational use areas are within the 2-mile evaluation area for visual resources(Griffen Community Center and the Davant Community Center), and construction lighting may
be visible to recreational users in these locations. In addition, recreational boaters on theMississippi River would have views of the construction activities and equipment at the terminalsite as well as the progressing infrastructure. Some visual screening would be present due toexisting tree lines and the levee on the east bank of the river and the sunken grade of land north ofthe levee but would not fully conceal the LNG storage tanks.
In general, construction would be anticipated to generate minor impacts due to theindustrial nature of the terminal site and its surroundings, as well as the temporary nature of theactivities and presence of construction equipment. The primary land use and planned future use
is industrial, due to the presence of commercial shipping, oil and gas facilities, coal facilities, andagricultural industries. In this manner, the construction activities would not detract from theoverall industrial appeal of the area. While views of the terminal site from SH 23 are present, theexisting views are of industrial facilities and activities. The construction at the terminal site would
add to these occurrences, but the Project construction would not be inconsistent with thesurroundings (i.e., minor impact).
During operation, views of the operating LNG terminal may include exterior plant lighting,air navigation lighting, LNG storage tanks, electric power generation facilities, liquefaction heatexchangers, air coolers, and the flare stack. Exterior plant lighting would primarily consist of full

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cutoff types that would be directed toward the ground. Where possible, floodlight mast locations
would be directed to avoid light emissions on land and water. According to Venture Global, flaring
would be anticipated to occur twice a year for start-up and shutdown purposes, while marine flaring
would be estimated to occur up to 12 times per year. Views of the flaring would be visible to someviewers, but it also would be partially obscured by the floodwall. The floodwall crest is anticipatedto be +26 feet NAVD88 at the terminal site.
Other views during operation would include intermittent views of the LNG carriers thatwould be docked at the LNG terminal. These views would occur along the stretch of theMississippi River between the Gulf of Mexico and the terminal site. Residents and recreational
boaters may have views of these activities.
During operation, the facilities at the terminal site would be visible to residents, drivers,
and recreational/commercial users. As the terminal site is a greenfield location, additional lighting
and facilities would be added to the local environment. Although the area is considered industrial
in nature, there are presently no industrial facilities of this magnitude visible from the nearest
residences nor from other locations to the south of the terminal site such as Woodland Plantation.
Therefore, the LNG facility could have a minor adverse impact on the residents, drivers, andrecreational/commercial users of the area. Views from elevated residential structures and views
from large distances would not be afforded the benefit of vegetative mitigation and therefore
impacts at nearby elevated points of view would also be minor and permanent. Impacts at locationsof larger distances, such as Woodland Plantation, would also be minor and permanent although toa lesser degree than those of locations within 2 miles of the terminal site.
4.8.6.2 Pipeline System
As noted in section 4.8.6.1, a visual resource assessment was conducted to evaluate thepotential of the Project to impact visual resources. For this assessment, the pipeline system wasconsidered with regard to its construction and operation.
The study area for this assessment included portions of the 2-mile area used for the terminalsite as well as the footprint of the pipeline system and its immediate surroundings. The pipeline
system generally would be located in rural areas and, in some locations, areas previously disturbed
by other development. The viewer groups associated with these areas primarily would include
residents and recreational or commercial boaters. The closest local residences are located on Gator
Road, approximately 0.3 mile northwest of the HDD crossing of Lake Hermitage Road; anotherresidence is located approximately 0.8 mile from the pipeline system.
Visual impacts associated with construction of the pipeline system would be anticipated toinclude the removal or alteration of existing vegetation and the exposure of bare soils, as well as
earthwork and grading scars associated with heavy equipment tracks, trenching, and machineryand tool storage. These activities may be visible to observers, including residences located within
1.0 mile of the pipeline system. Existing vegetation outside of the workspaces may provide some
buffer, but noticeable changes would result from the changes within the footprint and workspacesof the pipeline system or the construction of the pipeline system.

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Barges associated with construction of the pipeline system would utilize open water areas
associated with the barge access channels. A short-term change in visual resources would benoticeable to recreational and commercial boaters in proximately to the workspaces due to theactivity. Occupants of other vessels traveling on the barge access channels would be able to seelarge equipment, pipe joints, and materials being transported to the active construction sites.
As part of pipeline system construction, a pipe bridge also would be built. This bridge
would be located approximately 80 feet north of Lake Hermitage Road and would be visible toresidents living in the Deer Range neighborhood and Suzie Bayou Campsites. These areneighborhoods with a mix of recreational camps and permanent residences. KOP 2 was used toevaluate the potential for impacts associated with this Project component. While the bridge would
be noticeable during construction and operation, the analysis showed that existing tree cover andvegetation offered effective screening, thereby preserving the mix of rural and industrial features
within the landscape.
Due to the temporary nature of construction and Venture Global’s plans to restore areas topre-construction conditions (following the Project-specific Plan and Procedures), impacts
associated with construction of the pipeline system on visual resources would be minor.
Operational impacts associated with the pipeline system would be anticipated to occur inlocations surrounding the permanent aboveground facilities, including the meter stations, mainline
valves, and the pipe bridge. The meter stations would be situated in open areas and would be seen
by recreational or commercial boaters. As shown by the description of the surrounding area,
similar aboveground pipeline infrastructure is common in this area of Louisiana; therefore, thepresence of these stations would not detract from the overall industrial nature of the area. The
mainline valve site located south of Hermitage Road would not be anticipated to create a visual
disturbance due to its relatively small size. While the pipe bridge would be noticeable, as
aforementioned for construction, existing vegetation would provide a small visual cover.
As much of the pipeline system is located in rural or industrial areas, the Project would be
anticipated to cause minor impacts with regard to visual resources. Existing vegetation would help
to provide some visual buffer from the operation of the pipeline system. In addition, for thoseareas where vegetation would be removed or altered, pre-Project conditions would be restored.
4.8.7

Coastal Zone Management

The CZMA calls for the “effective management, beneficial use, protection, anddevelopment” of the nation’s coastal zone and promotes active state involvement in achieving
those goals. As a means to reach those goals, the CZMA requires participating states to develop
management programs that demonstrate how those states will meet their obligations andresponsibilities in managing their coastal areas. In Louisiana, the OCM administers the state’s
Coastal Zone Management Program and is the lead state agency that performs federal consistency
reviews. As such, the LDNR evaluates activities or development affecting land within Louisiana’s
coastal zone for compliance with the CZMA through a process called a “federal consistency”
review.

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The Project is entirely located within the Louisiana Coastal Management Zone. A CUP
would be required from the LDNR for development activities taking place in the coastal zone. The
Project would be designed and built in compliance with conditions set forth in by the CZMA. On
June 8, 2017, Venture Global submitted an application to the LDNR for a CUP, which also seeksa consistency determination for CZMA. Venture Global agrees to construct and operate the projectin compliance with conditions that would be set forth in the FERC authorization, the USACE
section 404/10 and 408 permits, and the LDNR OCM’s CUP. Venture Global would be required
to obtain all relevant federal permits before receiving FERC authorization to proceed withconstruction including a determination of consistency with the Coastal Zone Management Plan
issued by LDNR. We recommend that:•

4.9

Venture Global should not begin construction of the Project until it files with theSecretary a copy of the determination of consistency with the Coastal Zone
Management Plan issued by the LDNR.

SOCIOECONOMICS

Construction and operation of the terminal site and the pipeline system could affectsocioeconomic conditions in the region. We estimate the duration of these effects—temporary,short term, long term, or permanent—and their intensity—negligible, minor, or significant. In thiscontext, short-term impacts could continue for up to 5 years following construction, and long-term
impacts could continue beyond 5 years but less than the operational life of the Project. These
definitions differ from those given in the introduction to section 4.0 because the timescale ofsocioeconomic conditions differs from that of natural environmental resources. We determined
intensity levels by reviewing quantitative and contextual data and making qualitative assessments.
Negligible indicates an impact would not be noticeable or measurable. A minor impact would bea noticeable change but would not affect the overall function or quality of the socioeconomic
resource (e.g., housing market, public service provision, economic activity, etc.) at the community
scale. A significant impact would change, either positively or negatively, the function or qualityof the socioeconomic resource at the community scale for the duration indicated. We also describe
impacts as direct or indirect, or beneficial or adverse, when the distinctions are appropriate orclarifying.
Given the scale of the Project, the affected area is defined as three contiguous parishes,
including Plaquemines (the location of the Project), Jefferson, and Orleans Parishes. Figure B-7
in appendix B, depicts the region of influence discussed in this document. While the emphasis of
this assessment is on Plaquemines Parish, the three parishes listed above all contain communities
within commuting distance of the Project, and, thus, are places where workers and workers’
families would seek housing and public services. While some of the benefits and pressures of the
Project may occur throughout the region, the strongest economic effects from increased demand
for workers, materials, and services along the supply chain would likely occur in the affected area.
These communities would likely capture most of the local tax revenues stemming from the Project,
but they would also take on new public service expenditures. In addition, the affected area could
experience transportation effects on roads and waterways.
We gave special consideration to the area referred to as the southern west bank ofPlaquemines Parish, directly south of the Project, which is composed of 26 named communities
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and an estimated 4,828 residents. These residents rely on SH 23 for conveyance outside thesouthern west bank, and are vulnerable if travel on SH 23 becomes blocked or restricted. The
Point a lá Hache ferry south of the terminal site provides transport between the east and west banks,
but only transports about 40 vehicles at a time. We also evaluated the potential for the Project todisproportionately affect nearby populations that qualify as environmental justice communities.
4.9.1

Population

Table 4.9-1 provides selected population, density, and land area statistics for the affectedarea and the state.
Table 4.9-1
Population, Density, and Land Area Statistics in the Affected Area
Population Density
2016, Estimate(persons per square
mile)

Land Areab(squaremiles)

Geographic Area

Population
2000a

Population
2010b

Population
2016,
Estimatec

Louisiana

4,438,976

4,533,372

4,645,670

108

43,204

Plaquemines Parish

26,75723,042

23,58430

780

Belle Chasse

9,848

12,67913,709

-

-

3,428

3,069

3,676

-

-

Southern WestBanke

10,456

3,013

4,828

-

-

Jefferson Parish

455,466

432,552

435,204

1,470

296

Orleans Parish

484,674

343,829

382,922

2,266

169

966,897

799,423

841,710

3,766

1,245

504d

Census Tract

Affected Area Total

a U.S. Census Bureau, 2000
b U.S. Census Bureau, 2010
c U.S. Census Bureau, 2017ad The terminal site and pipeline system are in Census Tract 504.
e In this assessment, the southern west bank of Plaquemines Parish refers to all of the land for the terminal site on the west bank of theMississippi River. It comprises partial territory in Census Tract 504 and Census Tracts 505 through 508, depicted in figure B-8, appendix B.

Plaquemines Parish is a peninsula in the Gulf of Mexico bisected by the Mississippi River.
Plaquemines Parish’s land area is almost twice as large as Jefferson and Orleans Parishes
combined, but its population is less than 25,000 people. Most parish lands are within a designatedfloodplain, and much of these are coastal wetlands (Plaquemines Parish, 2012). The parish
population is largely concentrated in communities along SHs 23 and 39, which follow the west
and east banks of the Mississippi River, respectively. Belle Chasse, approximately 20 miles northof the terminal site on the west bank, is the most populous community in Plaquemines Parish,
consisting of over half of the parish’s residents. All parish communities are unincorporated.
Plaquemines, Jefferson, and Orleans Parishes are part of the Greater New Orleans Region.
Many communities in Jefferson Parish are within 50 miles of the Project. The boundary of Orleans
Parish is coterminous with the limits of the city of New Orleans, and its closest boundary is about
35 miles north from the terminal site.
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The estimated 2016 population levels in all three parishes are lower than in 2000, chiefly
because so many people left the region after Hurricane Katrina in 2005. The 2016 population of
Belle Chasse, however, is larger than pre-Hurricane Katrina levels (i.e., before 2005), and so is the
population in Census Tract 504, the census tract that contains the terminal site. The southern westbank area, stretching from around Port Sulphur to the southern tip of Plaquemines Parish, did not
regain its population after Hurricane Katrina. For the purpose of this analysis, the southern westbank is defined as all parish land south of the terminal site on the west bank of the Mississippi
River. It comprises partial territory in Census Tract 504 and Census Tracts 505 through 508,
depicted in figure B-8 in appendix B.
As shown in table 4.9-2, Venture Global expects that construction of the terminal sitewould occur in two 35-month phases, with start dates spaced 12 months apart. Thus, construction
on the LNG terminal would be continuous for about 4 years. The pipeline system would also beconstructed in two phases, each less than a year in duration, overlapping with the LNG terminal
construction. Each phase of the LNG terminal’s construction would average 1,400 workers andrise to 2,200 workers for a 6-month peak. However, the number of workers on-site would typicallybe higher during the 23 months of terminal construction phase overlap. During this 23-month
period, the total number of workers at the terminal site could range from 1,500 to 3,600, and would
average approximately 3,000 workers during the overlapping period.
Table 4.9-2
LNG Terminal and Pipeline System Workforce and Duration
Workforce

Durationa

Phase I

Phase
II

Terminal Site
Phase Overlap

Phase I

Phase II

Average

1,400

1,400

3,000

35 months

35 months

Peak

2,200

2,200

1,500–3,600

6 months

6 months

Average

250

100

ND

9 months

7 months

ND

Peak

350

150

4,100

1 month

1 month

1 monthPhase/Facility

Terminal Site
Phase Overlap

Construction
Terminal Site
23 months

Pipeline System

Operation
Terminal Site

250

30 years (minimum)

Pipeline
SystembNA

50 years (minimum)aPhase II of the terminal site construction would overlap with Phase I for about 23 months, and the start-to-end construction period
would be 4 years.
b Pipeline system facilities would be maintained by staff who are based at the terminal site.
Key:
ND = Not determined
NA = Not applicable

The pipeline system construction workforce would be much smaller, ranging from 100 to
500 workers. Venture Global has not determined the specific timing of the pipeline system phases.

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Thus, to be conservative, they assume that peak construction of both pipeline laterals could
overlap, resulting in 500 workers on-site for 1 month. Moreover, they assume that LNG terminal
peak construction could overlap peak construction of both pipeline system laterals, requiring a
total workforce of 4,100 workers at the terminal and pipeline system sites for 1 month.
Given the existing oil and gas and port industries in the affected area, Venture Global
expects at least 50 percent of the construction workforce would be hired from people alreadyresiding within the affected area. These local workers would not affect the population. The
remaining workers, once hired, would increase the population temporarily for the duration of theiremployment. Because the LNG terminal has a multi-year construction period, some non-local
workers may bring householders, e.g., spouses, partners, and/or children, to the area. For thisevaluation, we assumed the average number of non-local workers associated with LNG terminal
construction would bring householders, each with 2.6 persons per household based on the state
average, to the area (U.S. Census Bureau, 2017b). Further, we assumed non-local pipeline systemconstruction workers would not bring householders to the area because of the short construction
periods, nor would additional LNG terminal employees hired during peak periods.
From these assumptions, we estimated that 1,820 non-local workers and householders
could relocate to the affected area to support each phase of LNG terminal construction. During
the period when the LNG terminal’s Phases I and II overlap, that number could rise to an averageof 3,900 non-local workers and householders, and 4,680 when the overlap construction workforce
is highest. If peak construction periods of the LNG terminal and pipeline system overlap, up to
5,330 non-local workers and householders could temporarily reside in the affected area at one time
during 1 month.
The affected area population is more than 840,000, so the non-local worker households
would increase the population by less than 1.0 percent, including during peak construction. Of
course, non-local workers would not evenly distribute through the affected area, and we expect
many non-local workers would seek residence in communities with rental housing within a 1-hourcommute or less. Belle Chasse, the largest community in Plaquemines Parish, is about a 30-minutecommute away. Several other communities in Jefferson Parish (e.g., Timberlane, Terrytown,
Gretna, Harvey, and Marrero) are within a 45-minute commute of the terminal site, as are several
neighborhoods in New Orleans, and we assume any could appeal to non-local workers.
Based on the comparison of workers and householders with the existing population, we
conclude that construction of the Project would have a minor, short-term effect on populationlevels in communities in the affected area. In forming this conclusion, we also considered theeffect of non-local worker households’ on housing and public services, which are evaluated in
sections that follow. We acknowledge that the population increase would be more apparent incommunities closest to the Project site with rental housing and amenities, especially in Belle
Chasse, which currently has a low estimated rental vacancy rate of less than 3 percent, though thisestimate has a wide margin of error (U.S. Census Bureau, 2017c). In the short term, the population
increase could increase demands for services and housing, but may also create economic benefits
in the affected area, which still has a smaller population than in 2000, pre-Hurricane Katrina.
During operation, the Project would require 250 full-time workers. Given the existing oil
and gas and industrial port economies in the region, we expect at least 50 percent of operations
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workers would be hired from within the affected area. The remaining 125 workers, with assumed
household sizes of 2.6 persons, would effectively translate into 325 new residents in the region.
We conclude that the non-local workers hired during operation, along with their householders,would have a minor, permanent impact on the affected area’s population.
4.9.2

Economy and Employment

The Greater New Orleans Region’s economy is deeply invested in the oil and gas industry,
and Plaquemines Parish has been on record as contributing 25 percent of annual state severance
revenues from local oil and gas production (Scott and Richardson, 2015; Greater New Orleans,
Inc., n.d.). The Plaquemines Port, Harbor, and Terminal District is one of the top ports by annualcargo tonnage in the country and was ranked 11th largest in 2016 (USACE, 2018). The port district
occupies the southernmost 70 miles of the Mississippi River, and its primary cargoes are oil- andgas-related products, chemicals, coal, and grains. Another major employer is Naval Air Station
Joint Reserve Base New Orleans in Belle Chasse, which employs over 5,000 people and provides$340 million to the local economy (Purpura, 2013; Plaquemines Port, Harbor, and Terminal
District, 2018). Commercial fishing is another defining industry in Plaquemines Parish, and isevaluated separately in section 4.9.3.
An estimated 88,000 jobs were lost in the aftermath of Hurricane Katrina in 2005.
However, southeast Louisiana had high job growth in the ensuing years, such that the NewOrleans-Metairie-Kenner metropolitan statistical area had the highest employment growth rate
among the 100 largest metropolitan statistical areas in the country between 2005 and 2011 (Rhoet al., 2012). Unemployment rates at the state and local levels are currently low at around 5
percent, reflecting the national trend of shrinking unemployment among workers actively seeking
jobs.
area.

Table 4.9-3 provides selected economic and employment information about the affected
Table 4.9-3
Existing Economic Conditions in the Affected Area

Geographic
Area

Louisiana

Plaquemines
ParishJefferson
ParishPer Capita
Income a$25,515$25,359$28,067

Civilian Labor
Force bTop Industry Sectors by
Employmenta

2016 Unemployment
Rateb (%)

2,112,320

•
•
•
•
•

Ed, Health, Social
Retail tradeArts, Accom, Food
Pro, Mngmt, Admin
Construction

5.1

10,149•••••Ed, Health, Social
Ag, Fish, Hunt, Mine
Arts, Accom, Food
Construction
Manufacturing

4.6

215,779•••••

Ed, Health, Social
Arts, Accom, Food
Pro. Mngmt, Admin
Retail Trade
Construction

4.5

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Table 4.9-3
Existing Economic Conditions in the Affected Area
Geographic
Area
Orleans
ParishPer Capita
Income a$28,444

Civilian Labor
Force b179,465

Top Industry Sectors by
Employmenta
•
•
•
•
•

2016 Unemployment
Rateb (%)

Ed, Health, Social
Arts, Accom, Food
Pro, Mngmt, Admin
Retail Trade
Construction

5.1

a U.S. Census Bureau, 2017db Bureau of Labor Statistics, 2018
Key:
Ed, Health, Social: Educational services, and health care and social assistanceArts, Accom, Food: Arts, entertainment, and recreation, and accommodation and food services
Pro, Mngmt, Admin: Professional, scientific, and management, and administrative and waste management services
Ag, Fish, Hunt, Mine: Agriculture, forestry, fishing and hunting, and mining

Per capita income in Plaquemines Parish and the state are roughly equivalent, while it ishigher in somewhat more affluent Jefferson and Orleans Parishes. The majority of the civilian
labor force in the affected area resides outside of Plaquemines Parish.
The combined industry sector of educational services and health care and social assistanceis the largest sector by employment in the U.S., and it is also the largest in the affected area (U.S.
Census Bureau, 2017d). Of the three parishes, Plaquemines Parish has the lowest concentrationin that sector, and it is also distinguished by having the second largest concentration of employment
in the agriculture, forestry, fishing and hunting, and mining sector. The mining category includes
oil and natural gas extraction, and both it and fishing are important industries in Plaquemines
Parish. Construction is the fourth largest employment sector in Plaquemines Parish and the fifthlargest in Jefferson and Orleans Parishes. This indicates some residents in the affected area haveconstruction experience and could potentially benefit from the job opportunities associated with
Project construction.
Venture Global estimates the Project’s total construction cost would be $8.5 billion,
including workforce salaries and material and equipment costs. Venture Global estimates
10 percent of Project costs would be spent locally or regionally, based on their analysis ofindustrial projects recently constructed in the Gulf Coast region and the local and regional
contractors they plan to hire. Venture Global would purchase permanent equipment locally andalso lease construction machinery like cranes, lifts, pump trucks, flatbed trucks, dump trucks,
excavators, and front end loaders. Locally procured services would include limited design andengineering services, waste disposal, sanitary services, food services, and security. In addition,
local distributors would supply fuel to operate the dredging equipment, pumps, earth-moving
equipment, trucks, and diesel generators for the Project.
The Project’s workforce needs are laid out in table 4.9-3, and at its peak, the workforce
could number up to 4,100, but only for a 1-month period. More typically, the workforce would
range from 1,400 to 3,000 on the terminal site, and an additional 100 to 250 persons would workon the pipeline system, depending on the construction phase. Project construction salaries are
estimated to be $70,000 per year, excluding benefits, though the duration of any one employee’s

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employment would vary widely from a few months or less to several years. The construction andrelated activities required would create short-term business opportunities for local suppliers andservice providers and likely boost revenues along their supply chain, supporting job growth inrelated industries. The Project may increase competition for local supplies, which would increase
costs for some market participants and increase revenues for others.
Overall, we conclude that construction of the Project would generate minor, short-term
economic benefits in the affected area, which consists of three parishes in the Greater New Orleans
Region. This benefit would accrue during the 4 years of construction and a year or two after while
Project-related dollars moved through the local economy. In Plaquemines Parish, a ruralcommunity compared with the other parishes in the affected area, the economic benefit could besignificant depending on the number of workers who lived in the parish and the amount of spendingthat occurred there. At its peak, the construction workforce would represent a 40-percent increasein the number of workers employed in Plaquemines Parish. The peak construction workforce
would represent just a 1-percent increase in the number of workers employed in the broader
affected area. We assume approximately half of construction workers would be hired from within
the affected area, given that construction is among the top five employing industries in the region.
This could be a substantial benefit to local workers and their communities.
Once hired, the construction workforce, ranging from 1,400 to 4,100 individuals, would
spend money in the local communities and induce economic benefits in other industries like retail,accommodations, and food service. The labor requirements of the Project would increase demand
for general and specialized workers during construction, which could increase labor costs generally
for construction projects and petrochemical-related developments in the region, creating a mix ofbenefits and consequences, depending on the market participant.
During operation, 250 workers would be hired permanently to operate the LNG terminal
and, as needed, the pipeline system, earning salaries of $75,000 to $90,000, excluding benefits.
We assume half of these workers would be hired locally, given the mature oil and gas industry in
the affected area and local workers with relevant experience. The operations workforce would
increase the number of employed workers in the affected area less than once percent, but at thelevel of Plaquemines Parish, the workforce would increase the employed workforce by three
percent. For the duration of the Project, at least 30 years, Venture Global expects to spend
approximately $20 million annually on local materials, land leases, and water, sewer, and waste
disposal utilities. We conclude that operation of the Project would have minor, permanent
beneficial impacts on local employment and the economy in the affected area. Depending on thenumber of workers who move to Plaquemines Parish and the vendor contracts established there,
the employment and economic benefit to the parish could be greater.
4.9.3

Commercial and Recreational Fishing

4.9.3.1 Commercial Fishing
The commercial fishing fleet in Plaquemines Parish is one of the largest in the lower 48
states and ranked the largest around 2010, per the Plaquemines Parish Comprehensive Master Plan
(Plaquemines Parish, 2012). The parish’s highest grossing species are shrimp, menhaden, andoysters; combined, their gross farm earnings valued $117 million in 2014 (Louisiana State

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University, 2017). The commercial fishing industry in Plaquemines Parish has experienced
substantial setbacks in the last two decades but has been able to rebound to some extent after each
event. Setbacks include Hurricane Katrina in 2005, the Deepwater Horizon drilling rig explosionin 2010, and recent freshwater diversion projects that adversely affected the oyster harvests in the
short term.
The highest concentration of commercial fishing ports and marinas in Plaquemines Parish
is south of the terminal site, especially in the communities of Empire, Buras, Triumph, andBoothville-Venice. Some commercial marinas exist closer to the terminal site (i.e., Myrtle Grove
Marina to the north), but the commercial fishing hub is several miles south of the terminal.
Likewise, the Mississippi Delta region and the river’s tributaries south of the terminal experience
the highest concentration of commercial fishing activity compared with river waters near theterminal and further north.
In this assessment, we considered whether construction or operation of the terminal sitewould restrict access to fishing grounds or impede commercial fishing boat traffic. (Section 4.6
addresses the Project’s potential ecological and/or biological impacts on fish species.) As
discussed in section 4.9.8.2, vessel traffic during construction would consist of bulk carrier vessels
and tugs and barges, and their peak trips combined would not exceed 16 per week. The various
origins of the tugs and barges and bulk carriers are not known at this time, but we assume they
could voyage from ports north or south along the Mississippi River, from inland bayous and canals
west of the west bank, or from the Gulf of Mexico. Nevertheless, the number of trips would be
too small to be noticeable to regional commercial fishermen compared with the existing traffic.
Moreover, the bulk carriers and tugs and barges are likely to transit established shipping routes
such that their transits are not likely to affect commercial fishing grounds differently from existing
commercial vessel traffic. Thus, we conclude that the effects from vessel traffic during terminal
construction would be negligible and temporary.
The frequency of LNG carrier traffic during operation of the terminal would be much lessthan the frequency of construction vessel traffic—an estimated one LNG carrier or less per day, or
six LNG carriers per week (see Section 4.9.8.2 Marine Transportation). However, these carrier
vessels would be much larger than construction vessels. The LNG carriers would originate fromthe Gulf of Mexico and travel established shipping lanes and routes transited by other commercial
cargo traffic. Because of the width of the Mississippi River, the LNG carrier would not prohibit
other vessels from traveling abreast or passing in the waterway north of the delta. However, thepasses through the delta region into the main body of the river are narrower, and commercial
fishing vessels that voyage through the Southwest Pass could be impacted during LNG carriers’
transits through the pass. Impacts could potentially include minor delays or minor increases infuel costs from increased idle time. We do not expect more than negligible effects on fishermen’scatch from these minor delays, especially because other passes provide access to the Gulf of
Mexico and because Local Notices to Mariners from the USCG would permit fishermen toschedule their voyage plans most efficiently. Moreover, large cargo vessel traffic already regularly
occurs in this region (see Section 4.9.8.2 Marine Transportation). We conclude that effects oncommercial fishing from near-daily LNG carrier transits would be permanent but minor.
In Louisiana, oysters are harvested from public oyster grounds and privately leased areas.
The pipeline system would cross private lease areas in Barataria Basin, as described in section
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4.6.3.1. LDWF and LDNR require water bottom assessments of lease areas within prescribed
distances of installation activities, not more than 2 years before the start of construction. Venture
Global has performed the necessary surveys (see section 4.6.3 for further discussion).
Furthermore, Venture Global intends to conduct financial impact evaluations on individual leases
and work with leaseholders and the state to determine compensation for leaseholders. Withconsideration of Venture Global’s commitments, we conclude that the pipeline systemconstruction would have short-term direct impacts on commercial fishing. However, to ensure thesuccessful implementation of these consultations, we recommend that:•

Prior to construction of the pipelines, Gator Express Pipeline should file with theSecretary documentation that consultation with the LDNR Oyster Lease Damage
Evaluation Board and/or the affected lease holder(s) has been completed.

4.9.3.2 Recreational Fishing
Recreational fishing is a vital part of Plaquemines Parish’s identity and local economy,
made possible by the abundant lakes, bayous, marshes, and canals within its boundaries and thelower Mississippi River that flows through the center of the parish landform and into the Gulf of
Mexico. The Louisiana Tourism Coastal Coalition promotes recreational fishing in Plaquemines
parish as “world-class,” and the Plaquemines Parish Tourism Commission’s website address iscatchingcapital.com (Louisiana Tourism Coastal Coalition 2019; Plaquemines Parish Tourism
Commission 2019a). The Plaquemines Parish Tourism Commission provides a map of eightmarinas in the parish out of which fishing guides operate; all but three are south of the Project area
(Plaquemines Parish Tourism Commission 2019b). The Tourism Commission also provides acomprehensive list of 68 fishing guides and charter outfits in the parish (Plaquemines Parish
Tourism Commission 2019c). A private website developed to facilitate booking fishing trips
around the world lists 65 fishing charters in Plaquemines Parish that have signed up to the listing
service to date (FishingBooker.com 2019). The same website lists 129 fishing charters for thestate of Louisiana, indicating that as many as 50 percent of all fishing charters in the state could
operate out of Plaquemines Parish (FishingBooker.com 2019).
Known as the LA Creel Program, the LDWF conducts dockside interviews and telephoneand email surveys of recreational anglers to estimate saltwater fishing effort and catch. From the
LA Creel survey 2016-2017, LDWF estimated that 2.1 million recreational saltwater fishing trips
occurred around the state during that season (LDWF, 2018b). Given the fishing access facilities
and abundance of waterbodies in and around Plaquemines Parish, some substantial percentage oftrips likely originated out of Plaquemines Parish. This indicates that the economic value ofrecreational fishing in the parish is substantial. The most recent economic benefits report preparedfor LDWF contains estimates of $1.7 billion (2006 dollars) in total economic effects, $114.1
million (2006 dollars) in state and local tax revenues, and 18,122 jobs generated by freshwater andsaltwater recreational fishing in the state (Southwick Associates, Inc. 2008). The percentage of
economic effects captured in Plaquemines Parish is unknown, but it is likely that the proportion
was substantial given the prevalence of recreational fishing in the parish.
Both freshwater and saltwater recreational fishing occur in the parish. Primary targeted
species in freshwater are largemouth bass, perch, catfish, sunfish, alligator gar, and bream(Plaquemines Parish Tourism Commission 2019b). Primary targeted species during inshore
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saltwater fishing trips are redfish (a.k.a. red drum) and trout (a.k.a. speckled sea trout), followedby flounder, sheepshead, and black drum. Recreational anglers fishing offshore seek yellowfin
tuna, wahoo, marlin, swordfish, amberjack, cobia, grouper, red snapper, tarpon, and triple tail.
Offshore fishing sites in the Gulf of Mexico are beyond the Project area, but recreational fishingvessels with offshore destinations could be affected by the Project during transits in and out ofparish marinas.
Section 4.6.3 provides a more thorough ecological discussion of fish species that occur in
the Project, as well as an assessment of potential ecological impacts, including impacts onabundance. Section 4.6.4 further discusses the ecological conditions and habitats that support
fisheries in the Project area and potential short- and long-term impacts. Just as in this section’scommercial fishing impact assessment, we focused our recreational fishing impact assessment on
how the Project might restrict access to recreational fishing grounds, impede recreational fishingvessel traffic, or otherwise limit the volume of recreational fishing trips or effort that would occur
otherwise in the absence of the Project.
Construction and operation of the terminal would not restrict access to significant
recreational fishery resources because none occur within or around the terminal’s footprint (seesection 4.6.3.2). Construction-related vessel traffic, primarily bulk carriers and tugs-and-barges,
carrying materials to and from the terminal site during the four years of construction has somepotential to affect recreational fishing by increasing vessel traffic levels along the lower
Mississippi River and/or in the canals through the west bank of the parish. However, the trips
would not exceed 16 trips per week, too low to cause greater than negligible effects on recreational
fishing vessels in the area. Construction vessel traffic’s primary effects, if any, would be delaying
intercepted recreational fishing vessels in transit or disturbing anchored recreational fishing vessels
whose passengers are actively fishing. Should instances of these occur, the collective effect would
be negligible and temporary.
During operation of the terminal, the LNG carrier traffic would not likely affectrecreational anglers or their vessel transits. LNG carrier vessel frequency would be less than one
per day through the Southwest Pass and along the lower Mississippi River to the terminal site. The
majority of the marinas in Plaquemines Parish from which recreational fishing vessels launch are
positioned along canals with direct access to the bayous, marshes, and other inshore waterbodies
adjacent to the east and west banks of the parish. The bayous provide access to the open water of
the Gulf of Mexico, so most recreational offshore fishers avoid the Mississippi River altogether
during their transits in and out minimizing any interaction with large commercial vessel traffic like
LNG carriers. For those recreational fishing vessels transiting the Mississippi River, interactions
with LNG carrier traffic would be negligible because the lower Mississippi River is wide andpermits transits of multiple vessels abreast or passing with negligible delays. As mentioned in thecommercial fishing discussion in section 4.9.3.1, the Southwest Pass in the river delta is narrower
and may restrict a fishing vessel from traveling abreast of or passing a piloted vessel like an LNG
carrier. However, other passes in the delta provide access for non-piloted vessels to the Gulf, andthese could be used to avoid an LNG carrier or other piloted vessel transiting Southwest Pass.
Local Notices to Mariners from the USCG would permit fishermen to schedule their voyage plansmost efficiently. Overall, the permanent addition of LNG carrier traffic on the lower Mississippi
River would have a negligible effect on recreational fishing.

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During construction of the pipeline system, barge deliveries averaging one every other day
during the 5- to 7-month construction period of each lateral would transport pipe directly from apipe-coating plant to the pipeline system right-of-way. Other construction barge vessels would
include rake-haul type barges and lay barges, though these would not make daily trips but rather
remain at the Project site for the duration of their use. These rake-haul and lay barges would use
Wilkinson Canal and Barataria Bay Waterway to access the pipeline right-of-way and workspaces.
Appendix E shows the Project barge access routes, some of which will be dredged to deepen themby approximately 4 to 7 feet to at least 8 feet deep.
The pipeline construction crew would be transported by crew boats from Myrtle Grove
Marina along Wilkinson Canal to lay barges along the pipeline construction site. Crew boat
frequency would average about 20 trips per day to and from positions along the right-of-way andpeak around 28 trips per day for a one-month peak period during construction of each lateral.
Recreational fishing vessels are docked in Myrtle Grove Marina as well as in the neighboring
Hermitage Marina, and these anglers may notice the barge and crew boat trips during the 5- and7-month construction periods of the pipeline laterals. However, pipeline system construction
traffic would not prevent recreational vessels from using the marinas or accessing the connectedcanals and waterways in Barataria Basin.
Although recreational fishing would be prohibited in the pipeline right-of-way during theperiod of construction, this is a minor area compared with the remainder of Barataria Basin andthe fishing grounds. During dredging of the barge access channels, recreational fishing would beprohibited in the active dredging locations, but this would only occur for a period of days or weeks.
The pipeline system right-of-way is in Shrimp Area 09, Barataria Inside, and blue crab are
known to occur throughout Barataria Basin (see section 4.6.3). No public oyster areas are traversedby the pipeline system right-of-way or barge access channels, so recreational oyster tonging would
not be affected (see section 4.6.3). Thus, recreational fishing in this area refers to finfish fishing,
shrimping, and crabbing. Shrimping is restricted to spring and fall seasons, whereas crabbing andfishing for finfish is generally permitted most of the year. Construction of either lateral may occur
during the limited spring or fall shrimping seasons; the schedule is not yet known.
Venture Global has obtained consent from the LDWF in order to conduct in water
construction activities without a seasonal restriction. As such, impacts on aquatic resources
associated with construction activities is expected to be temporary and short-term and localized tothe immediate vicinity of construction activities. Although the construction of each pipeline anddeepening of discrete segments of barge access channels would take place over an extended
duration, the construction activity at any single location along the pipeline route or barge accesschannels is likely to be limited to several days or weeks minimizing potential impacts on aquatic
resources and recreational fishing. Access to the construction right-of-way and barge accesschannels would not be prohibited for fishing/crabbing/shrimping, except in the immediate vicinityof construction activities where necessary for safety reasons.
Although the pipeline system construction traffic could be noticeable to some recreational
anglers and the right-of-way would be off-limits to fishing during construction, we conclude thatthe overall effect would be temporary and minor given the limited periods of construction (12months total) and the proportionately small area of Barataria Basin that would be affected.
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As soon as construction and restoration activities are complete on the pipelines, the pipeline
system’s associated vessel traffic would cease and any fishing access restrictions to the right-ofway would be lifted. Venture Global may periodically send staff via vessel to inspect the two
permanent meter stations associated with the pipeline system, but these visits would have anegligible impact on recreational fishing. The meter stations, themselves, could increase habitat
diversity in Barataria Bay and would likely have a net beneficial impact on fish habitat (see section
4.6.4.2). Thus, we conclude that during operation of the pipeline system, recreational fishingaccess and opportunity would not be adversely affected.
4.9.4

Taxes and Revenues

The Project would generate taxes and other revenues at the local and state levels during
construction and operation. During construction, the Project’s main contribution to parish
governments would be sales tax revenues. The majority of these revenue increases would beindirect effects of Project construction, as it stimulates activity along the supply chain and provides
businesses and workers with disposable income to spend locally. Venture Global estimatesconstruction workers would spend 40 to 60 percent of their wages locally, and at least some ofthose expenditures would be subject to sales tax. In the affected area, the average local sales tax
rate is 4.75 percent. As discussed in section 4.9.2, Venture Global estimates 10 percent of Project
costs would be paid to local and regional suppliers of materials, equipment, and services,
constituting some of the direct economic and tax benefits of the Project. Local procurement of
concrete, fuel supplies, permanent equipment, leased equipment, and miscellaneous consumablematerials would be taxed at the average local sales tax rate of 4.75 percent and the state sales tax
rate of 4.45. .In addition to state sales taxes, income taxes generated by the Project would increase
government revenues at the state level. The wages of Project workers would be subject toLouisiana state income tax, as would wages of other workers whose jobs or level of activity were
supported indirectly by the Project.
Louisiana Economic Development evaluated the potential tax impact from Project
construction activities, direct wages, indirect wages, and induced purchases, and estimated $131.3
million in state tax revenues and $34.8 million in local tax revenues, for a total of $166.1 million.
This translates into approximately $7 million in local tax revenues generated annually over the 4
years of construction, some or most of which would be captured in the affected area. In
Plaquemines Parish, general fund tax revenues were $23.7 million in 2017 (Plaquemines Parish,2018). In Jefferson and Orleans Parishes, general fund tax revenues were $355.3 million and$403.0 million, respectively, in 2017 (Jefferson Parish, 2018; Orleans Parish, 2018). We conclude
that Project construction would have a minor, beneficial, short-term effect on local government
revenues in the affected area and in Plaquemines Parish, given that the parish’s current tax
revenues are less than $25 million. Project construction would provide a minor, short-term boost
to state revenues.
During operation, the Project would pay sales and ad valorem taxes and generate income
taxes on its annual payroll of $21 million. Venture Global estimates spending several million
dollars annually on local materials and public utilities (water and sewer provided by Plaquemines
Parish Water Works District, and waste disposal partially facilitated by Plaquemines Parish). The
local material purchases would generate sales tax and the utility payments would support
Plaquemines Parish service providers. The 250 permanent employees, whose salaries would
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generate income tax, would spend money locally on housing and consumer goods and services,increasing ad valorem and sales tax revenues.
Typically, the largest local tax contribution during operation of a development this size isad valorem taxes. Louisiana’s Industrial Tax Exemption Program (ITEP) waives property taxes
on approved developments for 5 years, with a possible extension of another 5 years. At the timeof publication, the Louisiana Board of Commerce and Industry had approved Venture Global’s
application for the ITEP exemption for the LNG terminal; the Governor’s approval was still
pending. The pipeline system is not eligible for ITEP and would generate ad valorem taxes in year
one of operation. At least by the eleventh year of operation, Plaquemines Parish would begin
collecting ad valorem taxes from both the LNG terminal and the pipeline system, and these could
be substantial given the $8.5 billion estimated value of the Project.
We conclude that once operational, the Project would have a minor, permanent, beneficial
impact on local tax revenues in the affected area. If a substantial portion of local tax revenues
accrue in Plaquemines Parish because materials and services are purchased there or a large
percentage of the workforce resides there, the tax revenue increase in the parish could besubstantial relative to the general fund’s annual tax collection. Once the full value of ad valorem
taxes are assessed on the Project, the local tax revenue increase in Plaquemines Parish would
provide additional benefits to the local economy.
4.9.5

Housing
Table 4.9-4 provides information about housing and accommodations in the affected area.

points:To evaluate the impact of Project construction on housing, we considered two key data•

the average number of non-local workers employed during each 35-month phase of
LNG terminal construction: 700; and•the largest possible number of non-local workers employed by the Project at one time,
assuming peak construction of the LNG terminal and both pipeline system laterals
coincide: 2,050.

During construction, most non-local workers would seek rental housing or other temporary
accommodations like hotels and motels or recreational vehicle (RV) campgrounds. The U.S.
Census Bureau (2017e) estimates that 14,035 vacant units are currently for rent in the affected
area, and 9,341 more are seasonal, recreational, or occasional use units. In similar scenarios,
owners of seasonal use units have rented them to temporary workers when demand increases.
At least some construction workers would reside in hotels or RV campgrounds, dependingon their length of hire. The affected area has an abundance of hotel rooms because of the relatively
close proximity to New Orleans. RV campgrounds are less plentiful but could accommodate someminority percentage of workers, depending on how many spaces are unoccupied.

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Table 4.9-4
Housing and Accommodations in the Affected Area
Home-owner Vacancy
Rate(%) a

Rental Vacancy
Rate(%) a

Total Vacant

For Rent

Seasonal

HotelsHotel Rooms d

RVCampgrounds

RV Spaces

Accommodations c

Total Units a

Vacant Housing a, b

Plaquemines

9,866

1.4

2.9

1,222

79

540

15

450

2

133

Jefferson

189,170

2.1

8.4

19,978

6,044

2,529

27

3,400

5

297

Orleans

192,358

2.6

8.6

37,514

7,912

6,272

122

18,3008515

Affected
Area Total

391,394NANA

58,714

14,0359,341

164

22,15015

945

Parisha U.S. Census Bureau 2017cb U.S. Census Bureau 2017ec Louisiana Office of Tourism, 2015; Louisiana Travel, 2015; Jefferson Parish Convention and Visitors Bureau, 2015; New Orleans
Convention & Visitors Bureau, 2015; Plaquemines Parish Office of Tourism, 2015; Canal Street Beat, 2013; RVParking.com, 2015d For Orleans Parish, an estimate of 150 rooms per hotel was used.
Key:
Seasonal: Seasonal, Recreational, or Occasional Use Units
Hotels: Hotels, Motels, Inns, or Lodges
NA: Not applicable

In total, 23,376 for-rent and seasonal units are vacant in the affected area, and it has asupply of 23,095 hotel rooms and RV campground spaces. Some of the vacant units would be
infeasible options, and many of the hotel rooms and campground spaces would be unavailable.
However, given the supply compared with the Project workforce maximum, we conclude that the
housing and accommodations market would experience minor, short-term impacts. Effects would
be more noticeable in some communities than in others, though they would be short term. Nonlocal workers would increase demand, which would benefit proprietors and rental unit owners andincrease competition among tenants in the affected area. The rental vacancy rates in the region do
not reflect a remarkably competitive market, so we conclude that construction workers would not
create undo hardships for other individuals seeking temporary housing. Thus, any adverse impacts
would be temporary and minor.
During operation, the estimated 175 non-local workers hired permanently would not affecthousing in the affected area, though their purchase or rental of local housing would benefit someindividuals.
4.9.6

Property Values

For purposes of the property value analysis, we evaluated the terminal and pipe bridge as
one entity because they are aboveground features that are nearly adjacent and they would be

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expected to have a similar effect. The terminal and pipe bridge would be constructed on an
undeveloped site owned by the Plaquemines Port, Harbor, and Terminal District, the majority ofwhich was formerly a sugar cane agricultural field. The frontage on the river between SH 23 andthe waterfront has not been developed in recent history. The majority of the LNG terminal site isdesignated as “port terminal complex” and “major industries” according to the Parish’s Master
Plan as described in section 4.8.3.1.
The unique economic, fiscal, and environmental conditions in a community, as well as
mitigation measures associated with a project, lead to varying effects, including no effect, onneighboring property values (Gabe et al., 2005). To investigate potential effects from the terminalon the values of nearby properties, we identified studies that assessed similar kinds of industrial
development. In the case of Cove Point LNG, commissioned in 1978 in Maryland, 323 of 377
homes within 1 mile of the facility were built after commissioning (Maryland Department of
Natural Resources, 2014). This indicates that land in proximity to the LNG terminal maintained
value sufficient to encourage new development. In the case of Cove Point LNG, the terminal waspartially screened from residential properties by forest cover and topography.
In a study of fossil fuel power plants constructed in the 1990s in neighborhoods across theUnited States, housing units within 2 miles of newly commissioned power plants were found to
experience a minor decrease (3 to 5 percent) in rents and mortgages compared with housing 2 to 5
miles away (Davis, 2010). The transferability of this finding to the Plaquemines LNG terminal islimited because power plants may be perceived as more undesirable local land uses than LNG
storage facilities and terminals (Gabe et al., 2005).
One peer-reviewed study found that housing values were higher near LNG facilities thanelsewhere, all other variables being equal (Clark and Nieves, 1994). In yet another study preparedfor residents in the town of Harpswell, Maine, a consulting group interviewed local realtors andconcluded that proximity to a LNG terminal would depress residential property values up to 2
miles away from the Project boundary (Yellow Wood Associates, Inc., 2004). Finally, a composite
study that examined peer-reviewed studies of different types of industrial developments such as
landfills, Superfund sites, nuclear power plants, and large manufacturing facilities did not find aconsistent trend characterizing how these industrial uses impacted property values (Regional
Economic Studies Institute of Towson University, 2004).
Although studies to date are sometimes contradictory or inconclusive, one consensus seems
to be that properties beyond 2 miles are too far away to experience measurable property value
impacts from industrial facilities (e.g., Maryland Department of Natural Resources, 2014; Davis,
2010; Gabe et al., 2005; Yellow Wood Associates, 2004). Likewise, proximity is a chief factor
influencing whether a facility could impact residential property values (e.g., Davis, 2010, Yellow
Wood Associates, 2004). Two communities, the Deer Range neighborhood and Suzie BayouCampsites, are located off Lake Hermitage Road within one mile of the terminal site. According
to the Plaquemines Parish Comprehensive Master Plan maps, these are camp communities, definedas “residential communities built outside levee protection zones in marshland and swamp-likeareas with limited infrastructure, characterized by a part-time or seasonal resident population often
engaging in commercial fishing or recreational fishing and hunting” (Plaquemines Parish, 2012).
However, the Deer Range neighborhood and Suzie Bayou Campsites consist of both part-time orseasonal camps as well as permanent residences. Lots in the neighborhoods range from 750 feet4-138

to 3,000 feet (0.6 mile) from the terminal boundary. Another camp community on Lake Hermitage
Road is 2.6 miles southeast of the terminal, and occupants would drive past the terminal on their
way to and from SH 23. Like the other communities, the neighborhood consists of permanent
residences in addition to part-time or seasonal camp facilities.
Another nearby residential development is a subdivision around a canal approximately 2.3
miles northwest on SH 23. The parish’s Comprehensive Master Plan designates the future land
use of this subdivision as a marina/harbor complex, which permits a mix of commercial andresidential uses centered on the waterfront feature(s) (Plaquemines Parish, 2012). The closest
residential property on the east bank is the community of Davant, northeast of the terminal andapproximately 0.8 mile away. The future land use is designated as small community mixed use.
No new developments with a residential component are proposed within 0.25 mile of theterminal site. Moreover, the parish’s draft, final Comprehensive Master Plan does not designate
any future land use with residential components on west bank properties within several miles of
the terminal that do not already have residential uses.
Perception factors heavily into the effect new development has on nearby property values,
and so we considered the context of the terminal and pipeline system and their aesthetic and healthimpacts. In Plaquemines Parish, the oil and gas industry is mature, and related developments areprevalent. Thus, local perception of the Plaquemines LNG terminal would be influenced byresidents’ familiarity with other oil and gas-related infrastructure on the west and east banks.
Appearance and noise emitted from an industrial facility also influence perception, and thesefactors were evaluated in Section 4.10 Cultural Resources and Section 4.11 Air Quality and Noise.
We did not find that the terminal’s noise output would be significantly adverse, but rather would
comply with noise level requirements and avoid impacting noise-sensitive areas. Our evaluationof the terminal’s visual change of the landscape is discussed in section 4.8.6, and we acknowledge
that no other industrial facilities of similar scale are visible from the nearest residences. The
terminal would be surrounded by a 26-foot floodwall, partially screening facilities, but the storage
tanks, stacks, and other tall components would be visible above the floodwall. Perceived healthrisks could also factor into property values of nearby residences. We conducted rigorous
investigations of air emissions and safety, reported in sections 4.11 and 4.12, and found that
Venture Global has designed a project that meets state and federal air quality and safety standards.
Although we cannot predict the effects on any individual property, we assume effects on
the camp community 2.6 miles from the terminal would be minimal, as would effects on themarina/harbor complex community on SH 23 and the Davant community across the river. The
Deer Range neighborhood within 2 miles of the terminal is discussed below. In our evaluation,
we considered that Plaquemines Parish has a substantial existing oil and gas-related industry. For
example, International Marine Terminals’ coal terminal and Phillips 66 Alliance Refinery on SH
23 are 1.3 miles and 6.7 miles driving distance, respectively, from the terminal site. We consulted
the draft, final Comprehensive Master Plan for Plaquemines Parish and found that it designates a
mix of future land use types on the terminal site, i.e., “business park,” “port/terminal complex,”and “major industries” (Plaquemines Parish, 2012). The plan’s future land use map indicates aless intense use “business park” on the portion of the site closest to the Deer Range neighborhood,
but large tracts adjacent and southeast of the terminal are designated “major industries.”

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The Deer Range neighborhood consists of a substantial number of permanent residences.
Locally, it is also called “Lake Hermitage” for its main access road. The LNG terminal would nothave a public access road to Lake Hermitage Road. Most of the structures in Deer Range areoriented toward the interior canals, but some have views facing the LNG terminal. Some of thestructures are very close to the terminal site boundary.
We assume individual properties in the Deer Range neighborhood could experience a
property value change if the terminal is constructed; however, it would be similar to a change
accompanying any “port terminal complex” and “major industries” that could be constructedaccording to the Parish’s Master Plan.
The other components of the pipeline system are not expected to have more than negligible
effects on property value in the region. The aboveground meter and valve stations would be on
the terminal site behind the floodwall or else in Barataria Basin, out of sight of any residential orcommercial properties. With the exception of the pipe bridge, all segments of the pipe would beburied, largely under wetlands and open water but also under some undeveloped upland that isdesignated as agricultural in the parish’s draft, final Comprehensive Master Plan Future Land Use
Map. Pipeline easements do not prohibit agricultural activity directly above, so this would notaffect certain individual property owners’ agricultural activities.
Finally, several studies have found limited to no effects of natural gas pipelines on theproperty values of neighboring or nearby property values (e.g., Integra Reality Resources, 2016;
FERC, 2014; Diskin et al., 2011; PGP Valuation Inc., 2008; Allen, Williford, and Seal, Inc., 2001).
Thus, we conclude that the pipeline system (not including the pipe bridge), would have anegligible, permanent effect on the collective property value of the traversed land.
4.9.7

Public Services

Table 4.9-5 provides an inventory of selected public services in the affected area, including
public education, fire protection, law enforcement, and health care.

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Table 4.9-5
Public Services in the Affected Area

ParishPlaquemines
Southern West Bank
Jefferson
Orleans
Affected Area Total
a
b
c
d
e
f

PoliceDepartments,
Sheriff’s Offices cHospitals d,ePublic Schools aStudents a

Fire
Departments b

8

5,036

8

1

1

3

1,115

5

1

1

86

47,977

18

7

6
7
14

87

43,67094f

181

96,68335

9Plaquemines Parish School Board, 2015; Jefferson Parish School District, 2015; Tulane University, 2014
U.S. Fire Administration, 2016
USACOPS, 2016
Jefferson Parish Medical Society, 2016; Orleans Parish Medical Society, 2014; Plaquemines Parish Government, 2016
Totals do not include long-term extended care, psychiatric care, rehabilitation, or labor delivery and women’s services hospitals.
New Orleans Police Department is the public safety agency primarily responsible for patrol of the parish; the primary responsibility of Orleans
Parish Sheriff’s Office’s is correction facilities, and Crescent City Connection and Port of New Orleans Harbor Police Departments patrol thefacilities for which they are named.

In general, the parishes have school, public safety, and hospital services that arecommensurate with their populations. The reported number of police and sheriff’s departments
are not directly comparable because areas of responsibility differ—departments responsible forlarger areas have more deputies. For example, the New Orleans Police Department is a large police
force that patrols all of Orleans Parish, while Jefferson Parish policing is divided among several
municipal police departments and the sheriff’s office. Plaquemines Parish law enforcement isprovided by the Sheriff’s Office, with headquarters in Belle Chasse and additional offices on theeast and west banks.
Offsite: Given our finding that the population increase by non-local workers andhouseholders associated with the Project would be short term and minor, we conclude that theiradditional demand for fire, safety, and medical services would also be short term and minor. The
services are adequate in the affected area, and we do not find that relocated households associatedwith construction would place an undue burden on them. Moreover, local revenues and economic
stimulus generated by Project construction could indirectly increase funds available to public
safety departments and hospitals in the future. During operation, the needs of the 125 non-local
workers hired during operation would not affect the current level of service by local fire, safety,
and medical service providers.
To estimate the number of school-aged children that could accompany non-local
construction workers and increase enrollment at local schools, we assumed the non-local workers
associated with each LNG terminal construction phase’s average workforce were the workers most
likely to relocate children because of their duration of employment. Because the LNG terminal
phases overlap, we assumed up to 1,400 non-local workers could bring families (50 percent ofeach phase’s average workforce size of 1,400). The households of 1,400 non-local workers would
comprise 3,640 people, based on assumptions discussed in section 4.9.1. In Louisiana, theproportion of 5- to 17-year-olds is 17.4 percent, so assuming this proportion among the non-local
worker households, 633 school-aged children could move to the affected area. Given the

4-141comparatively large student body in the affected area, these additional children would have minor,
short-term effects on the public school system. During operation, we expect an even smaller
number of school-aged children to accompany non-local hires. Therefore, the Project’s effect onschools would be minor and permanent during operation.
On-site: During construction and operation, Venture Global would supply at least somesecurity, fire safety, and medical services on-site. According to Venture Global’s current plans,
the Plaquemines Parish Fire District would provide backup fire protection, to be described in the
Project’s final version of the Emergency Response Plan. To that effort, Venture Global would
provide specialized training to the Myrtle Grove and/or Lake Hermitage Volunteer Fire Stations,located 3.0 miles north and 4.4 miles southwest, respectively. If persons on-site needed medicalcare beyond that provided on-site, they could visit the Plaquemines Parish Medical Center, 13
miles south in Port Sulphur, or the Ochsner Medical Center, West Bank, 25 miles north in Jefferson
Parish. Plaquemines Parish Medical Center provides most medical services except major surgery,while Ochsner Medical Center, West Bank is a 180-bed full-service facility. The nearest law
enforcement office is the Plaquemines Parish Sheriff’s Office in Port Sulphur, and 20 patrol
deputies are assigned to the west bank region that includes the Project site. We conclude that onsite activities during construction and operation of the Project would have a minor effect on public
services at the level of the affected area.
Southern west bank: The communities in the southern west bank of Plaquemines Parish
could be vulnerable if an emergency or catastrophic event occurred at the LNG terminal andprohibited travel along SH 23. Therefore, we inventoried the public safety and medical services
that are present in the southern west bank to determine services locally available in the event of aroad closure. We also identified the Plaquemines Parish schools south of the terminal site toestablish whether school-aged children in the southern west bank typically commute past theterminal site to attend school.
During localized emergency incidents at the LNG terminal and other events that mightclose local highways, e.g., flooding, the Sheriff’s Office can direct traffic to the levee system of
the parish. Alongside the LNG terminal, this is the berm between SH 23 and the Mississippi River
with a narrow, gravel track road on top, so that travel would be limited to one-lane, one-way. Also
available for transportation is the Point a lá Hache ferry at West Pointe a lá Hache. The average
ferry vessel fits 40 vehicles, and typically runs every 30 minutes between the west and east banks.
Plaquemines Parish law enforcement is the Sheriff’s Office, with headquarters in Belle
Chasse. The Project facilities are within the Patrol Division’s 2nd District, which extends from
Myrtle Grove to Venice with approximately 20 deputies and an office in Port Sulphur. The
Sheriff’s Office Marine Search and Rescue team are also based in Port Sulphur and respond to
emergencies on the rivers and bayous, such as lost boaters and disabled vessels. In addition to its
60 patrol deputies and special division officers, the Sheriff’s Office has a Reserve Division ofaround 21 deputized volunteers that assist during special events and emergencies like road races
and hurricane evacuations (Plaquemines Parish Sheriff’s Office, n.d.).
Lake Hermitage Volunteer Fire Station in Port Sulphur and Boothville Volunteer Fire
Station are both in the southern west bank. Typically, volunteer firefighters are “on call,” so they
may or may not be in the southern west bank at the time of an incident. The firefighters at Lake
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Hermitage may receive specialized training sponsored by Venture Global to serve as backup
firefighters to aid incidents at the LNG terminal.
Described above, the Plaquemines Parish Medical Center in Port Sulphur serves all of
Plaquemines Parish and is located in the southern west bank. It provides emergency care, but not
major surgery. Plaquemines Parish has an ambulance service with a post in Port Sulphur,collocated with the volunteer fire department.
The southern west bank has two elementary schools, one combination middle school/highschool, and one learning center geared toward high school-aged children. Thus, local schools areavailable to school-aged residents of the southern west bank. In the event of a LNG terminal
emergency that necessitated closure of SH 23, students who commute north of the LNG terminal
to attend another school would be most vulnerable to disruptions- either because they could not
return home or drive to school. However, this vulnerability is minimized given the availability ofschools south of the LNG terminal.
In sum, the southern west bank has a sheriff’s office, a marine search and rescue team, twofire stations, a comprehensive medical center, an ambulance service post, and public schools forK-12 students. The presence of these services would reduce local residents’ vulnerability should
an emergency event occur at the terminal and require temporary closure of SH 23. Although wefind that, in general, the Project would not have a significant adverse impact on the availability of
public services in the southern west bank, we discuss the potential for a catastrophic event at theterminal blocking access on SH 23 as an issue of environmental justice (see Section 4.9.9
Environmental Justice).
4.9.8

Transportation

The Project would generate traffic on roads and waterways during construction andoperation. Within the affected area, major road corridors include Interstate 10 (I-10), Interstate310 (I-310), Interstate-610 (I-610), U.S. Highway 171 (US 171), and U.S. Highway 90 (US 90),
also referred to as the West Bank Expressway. Locally important road corridors in Plaquemines
Parish include SH 23, SH 39, and SH 406, but SH 23 is the only road that accesses the LNG
terminal and the parking area and workspace associated with the pipeline system. Thus, SH 23 is
the pinch point in the roadway network that would be used by Project-related vehicles; therefore,
the traffic analysis examines potential build-up on SH 23 to determine whether significant effects
would occur. The Project would generate vessel traffic on the Mississippi River throughconstruction and operation of the LNG terminal and would use canals in Barataria Basin tofacilitate construction of the pipeline system. Traffic in both waterbodies are evaluated in themarine transportation section that follows.

4-1434.9.8.1 Roadway Transportation
Because of the narrow geography of Plaquemines Parish, only one arterial road, SH 23,
directly serves the Project. SH 23 runs parallel to the Mississippi River on the west bank, and SH
39 runs along the east bank. Because the river is wide, river crossings are limited. The closest
bridge crossing to the terminal site is the US 90 crossing in New Orleans, approximately 30 miles
north. The closest ferry crossings are 22 miles north in Belle Chasse and 6.8 miles south in West
Pointe a lá Hache. The Point a lá Hache ferry runs every thirty minutes on weekdays and about
every hour on weekends, from 6:00 a.m. to 10:00 p.m. 7 days a week. The Point a lá Hache ferryvessel carries 40 vehicles, though the parish operates another ferry that transports 72 vehicles at atime.
DOTD characterizes SH 23 as a minor urban arterial in Belle Chasse and a minor ruralarterial south of Belle Chasse, to its terminus in Boothville-Venice (DOTD, 2014). DOTD traffic
counts near the terminal site range from 9,271 vehicle trips daily near Belle Chasse to 7,074 trips
near Port Sulphur (DOTD, 2015).
Venture Global prepared a Traffic Management Plan for Terminal Site Construction andan additional plan for pipeline system construction (appendix E). In the Traffic Management Plan
for Terminal Site Construction, Venture Global considered the traffic generated by all LNG
terminal and pipeline system construction workers because all would utilize SH 23 to access the
Project site. The plan assumes a construction workforce of 3,300, which is not as high as the peak
workforces presented in section 4.9.1. After the Traffic Management Plan was prepared, Venture
Global revised the construction schedule, resulting in a longer overlap period of Phase I and Phase
II and a higher peak workforce. Whereas the original schedule indicated the workforce would notexceed 3,200 during the overlap period, the revised schedule indicated a peak combined workforceof 3,600 for several months. In addition, if all peak periods of the terminal and pipelines overlap,
the workforce could rise to 4,100 for one month, though the likelihood of this occurring is low. In
spite of these differences, we determined that the Traffic Management Plan assumption of 3,300
workers was adequate, primarily because we believe the plan’s summary findings and proposed
mitigation measures would not change by increasing the workforce assumption to 3,600. We also
considered that during the majority of the construction period, the workforce would be less than
the assumed 3,300 - the average workforce at the LNG terminal site would be 3,000 during Phase
I and II overlap, and outside the overlap, the workforce would average 1,400.
In the Traffic Management Plan for Terminal Site Construction, a traffic simulation study
showed that, without mitigation, traffic on SH 23 would become heavily congested during themorning commute hour as vehicles backed up behind two construction entrances at the terminalsite. Heavy congestion was predicted during peak construction periods during the workers’
morning commute between 6 a.m. and 7 a.m., assuming one vehicle per person.
During the draft EIS comment period a commenter asked about the traffic increases along
SH 23, specifically in Belle Chasse. The applicant estimates that during peak construction 2,380
personnel would originate from locations north of the LNG terminal, passing through Belle
Chasse. DOTD traffic data at points located in the northern part of Belle Chasse and the southernpart of Belle Chasse along SH 23 indicate between 22,520 and 33,146 traffic counts per day,respectively. To estimate the potential increase in traffic as a result of construction activities, the
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DOTD recorded data were averaged for each point and used as the average daily traffic for thatpoint. Project-related traffic was then added to those daily counts and a percent increase wascalculated. Project-related traffic would result in an increase of 7.2 percent of daily trips at thesouthern location and 10.5 percent increase at the northern location in Belle Chasse. These
numbers represent the potential peak increase in traffic and would not be representative for theentire duration of construction activities.
Through multiple simulation runs, the simulation study identified a combined group of
mitigation measures that would eliminate traffic queues near the LNG terminal entrances andelsewhere on SH 23, including Belle Chasse, and maintain an acceptable level of service on SH
23. The mitigation measures captured in the Traffic Management Plan for Terminal Site
Construction are as follows:•

position personnel checkpoints at the entrances to construction sites from the on-siteparking lot, rather than at SH 23 access points;•

limit the number of available passenger car parking permits on the designated parking
lots to maintain carpooling of at least two people per vehicle;•

limit use of the LNG terminal’s secondary access point from SH 23 to construction
management only;•

construct auxiliary turning lanes along SH 23 at its intersection with the LNG
terminal’s main access point;•

minimize the use of external trucks by transporting most construction freight by water;•

station a police officer to control traffic at the proposed intersection of SH 23 and themain construction entrance during commuting rush hours; and•eliminate truck traffic to the Marine Facilities or any other Project site duringcommuting rush hours.

The plan also calls for providing a continuous on-site bus shuttle service from the terminal
parking lot to work locations. The parking lot is on-site and anywhere from 0.2 to 0.7 mile awayfrom various work locations, so this measure is intended to ensure terminal workers arrive at their
specific location on a timely basis. It would not affect traffic on SH 23. More information aboutpipeline employee parking and transport is provided later in this section.
Venture Global proposes to install a temporary bulk material conveyor and cement
handling equipment between the Bulk Carrier Mooring Facility on the Mississippi River and theterminal site south of SH 23. The conveyor and piping would be located overhead on a trestle
across SH 23. Transporting materials for terminal construction with this system would preclude
the need for the same materials to be trucked across SH 23, thereby avoiding associated traffic
congestion. Design efforts are currently underway.

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Implementation of the mitigation measures described above would limit the terminal site’sconstruction impacts on traffic to minor and short term. This Traffic Management Plan for
Terminal Site Construction is predicated on the current Construction Execution Plan, such that if
conditions are modified, the Traffic Management Plan may require further evaluation and potential
modification. Venture Global intends to implement these measures assuming the current
Construction Execution Plan remains substantively the same. If roadways are damaged becauseof construction-related traffic, Venture Global would repair or reconstruct the damaged roadway
to pre-construction condition.
Pipeline construction workers would commute to a designated parking area near Myrtle
Grove Marina off of SH 23, or to the selected contractor staging yard with frontage on SH 23 (seeappendix E). Based on their traffic management plans, Venture Global intends for somepercentage of pipeline workers to carpool, such that during peak construction of a single pipeline,
total employee vehicles would not exceed 100 vehicles. Commuter movements would occur
primarily between 5:00 a.m. and 6:00 a.m. and at 6:00 p.m., generally 6 days a week and up to 7
days a week. From Myrtle Grove Marina, 25-person capacity crew boats would transport pipeline
workers to contractor lay barges stationed along the pipeline right-of-way or to temporary
workspaces. Venture Global estimates that collective traffic on SH 23 associated with pipeline
construction would average 175 vehicles daily, including employee vehicles and heavy truck
deliveries.
Pipeline construction activities and semi-truck deliveries could cause traffic delays or otherimpacts, but adverse traffic effects are not expected to be severe or of long duration. Pipe segments
for both laterals would be transported by barge from a pipe coating plant directly to a lay barge
along the pipeline right-of-way or offloaded at a dock at the terminus of Walker Road. Delivering
pipe directly to construction lay barges would greatly reduce semi-truck transport on SH 23, andthe effects of this barge transport on inland waterways is discussed in Section 4.9.8.2 Marine
Transportation. Because of the location of the barge offloading dock, semi-trucks would travel
Walker Road frequently through the construction period.
The other local road that would experience noticeable traffic effects is Lake Hermitage
Road. Pipeline installation methods include two road bore crossings across Lake Hermitage Road
south of the terminal site—one for each lateral. If the road bore installation required a temporary
road closure, Venture Global would avoid closing it during peak traffic hours and would coordinate
with appropriate officials to minimize impacts.
The Traffic Management Plan for the Pipeline System identified several measures toreduce impacts from construction activities and heavy truck trips on public roads:•

provide road signage alerting drivers to pipeline system construction activities andpotential traffic delays;•utilize flagmen, as needed, when equipment is crossing a road or traveling along a
public roadway;•adhere to state and county vehicle weight limit regulations and removal of excess soilthat may be left on the road surface from construction equipment crossings;
4-146

•

implement dust control measures, as necessary, in dry weather, especially on roads withunpaved surfaces such as Walker Road and Lake Hermitage Road;•

place additional signage on Lake Hermitage Road where a variety of construction
activities would occur, including a bored road crossing operation, construction related
to the installation of a main line valve, and an aboveground pipe bridge used to crossan existing non-federal levee; and•should a temporary road closure be required, the contractor should avoid closing Lake
Hermitage Road during peak traffic hours and coordinate construction activities withappropriate local and state officials to avoid or minimize potential traffic
delays/impacts.

Venture Global intends to implement these mitigation measures assuming the current
Construction Execution Plan remains substantively the same. Assuming implementation of the
mitigation measures, we expect impacts on public roadways from pipeline system construction
activities would be minor and temporary. Construction of each pipeline would last less than 1
year, and the volume of traffic generated by construction would be under 400 trips per day. Finally,
installation would involve only two public road crossings.
4.9.8.2 Marine Transportation
The proposed terminal fronts the Lower Mississippi River at river mile marker 55.
Roughly defined as the river section from Baton Rouge to the Gulf of Mexico, the Lower
Mississippi River is flanked by four of the top 11 U.S. ports by tonnage, including the top port, thePort of South Louisiana, between Baton Rouge and New Orleans (USACE, 2018). As such, theLower Mississippi is heavily transited by tankers, cargo ships, and tugs and barges, in addition torecreational vessels, fishing vessels, and cruise ships. As discussed in section 4.9.2, thePlaquemines Port, Harbor, and Terminal District is the 11th largest port by tonnage and hosts
around 20 terminals, which receive vessels regularly (Plaquemines Port, Harbor, and Terminal
District, 2018). In addition to these vessels, ocean-going vessels that call on New Orleans, SouthLouisiana, or Baton Rouge also transit the river section in the Plaquemines Port, Harbor, andTerminal District. The Crescent River Pilots Association, whose members pilot foreign-flagged,
ocean-going vessels that transit between Pilottown near the southern tip of Plaquemines Parish and
New Orleans, pilot over 16,000 transits annually, an average of over 44 transits each day (CrescentRiver Pilots’ Association, n.d.). Considering that ocean-going vessels are a minority percentage
of total transits along the Lower Mississippi River, vessel transit numbers likely reach up to several
hundred daily in the vicinity of the LNG terminal. U.S. flagged cargo ships, Navy vessels, tugs
and barges, fishing vessels, recreational boats, and ferries are examples of other vessel types that
regularly transit the river. At river marker 55 near the terminal, the river width is nearly 0.5 mile,
permitting multiple vessels to travel abreast.
During terminal construction, bulk carriers and tugs and barges would deliver materials,
equipment, and modular plant components to three temporary marine delivery facilities
constructed along the terminal’s river waterfront, described in section 2.1.1.7. Bulk carrier vessels
would deliver rock, structural fill, and cement to the bulk carrier mooring facility. The other two
facilities, the MOF and barge mooring facility, would receive deliveries by tugs and barges,
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primarily. The MOF has been designed to offload LNG modules, power plant components andequipment, and other heavy lift/heavy haul (greater than 50 tons) material and equipment frombarges. The barge mooring facility is designed to dock and offload cargo barges carrying materials
like pipe piles, concrete piles, sheet piles, steel, and stone. At most, eight vessels per week would
call on the marine facilities during terminal construction. This peak estimate includes one bulk
carrier and seven tugboats pulling four-to-eight barges each. The terminal’s peak number of vesseltransits is limited by the utilization rate of each berth (e.g., the time necessary to unload each bulk
carrier vessel or set of barges). At most, the bulk carrier mooring facility could accommodate one
bulk carrier vessel per week, while the MOF and barge mooring facility could each accommodate
one delivery of barges every other day. Based on these berth utilization rates estimated by Venture
Global, the peak vessel transits would equal eight round trips, or 16 trips total, per week. Given
the daily traffic in the Mississippi River by existing commercial traffic and the width of the riverthat permits multiple vessels to travel abreast, the few daily trips added by Venture Global supply
vessels would constitute a negligible increase.
Venture Global estimates that upon full build-out, the terminal could receive a maximumof six LNG carriers per week transiting in from the Gulf of Mexico. State-commissioned riverpilots would board the LNG carriers during their voyage along the Mississippi River, per statutory
requirements designed to ensure persons with local knowledge of the waterway are onboard tominimize accidents. The Associated Branch Pilots board and direct navigation on foreign-flagged,
deep-draft vessels transiting between Southwest Pass at the mouth of the river and Pilottown, an
island in southern Plaquemines Parish. The Crescent River Port Pilots’ Association board foreignflagged, deep-draft vessels between Pilottown and New Orleans. Thus, during each voyage, an
LNG carrier calling at the terminal would be boarded by two pilots inbound and two pilots
outbound who would direct navigation along the 65-mile-long transits each way.
As part of the required Waterway Suitability Assessment process (33 CFR 127.009),
Venture Global met with the USCG from March 1–3, 2016, during a Waterway Suitability
Assessment workshop. Their final Waterway Suitability Assessment was submitted in October
2016, and on January 23, 2017, the USCG issued a Letter of Recommendation stating that theLower Mississippi River is suitable for LNG traffic associated with the Project in accordance withthe guidance in USCG’s Navigation and Vessel Inspection Circular (NVIC) 01-2011. Before theterminal is commissioned, the USCG would establish the maximum number of LNG carriers
allowed per year. To date, the Captain of the Port has not recommended establishing moving
safety and security zones around LNG carriers associated with the terminal. This is consistent
with current protocols for vessel carriers of liquefied hazardous gas on the Mississippi River near
the terminal, which transit without security zone restrictions.
Although the annual maximum number of LNG carrier calls has not been prescribed, we
assume an average of six to seven LNG carriers would call on the terminal weekly. The carriers
would not restrict the travel of other vessels in the river around them, and each would be undernavigation direction of a local, state-commissioned pilot. The vessel carriers would be consistent
with other large tankers and cargo ships that transit the river to the southern Louisiana port districts.
We assume current traffic in the vicinity of the terminal consists of several hundred transits perday, by vessels of all types and sizes. Given these factors, we conclude that the effect of terminal
operation on marine transportation would be permanent but minor.

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As mentioned in section 4.9.8.1, Roadway Transportation, Venture Global would use
barges to transport pipe directly from a pipe-coating plant, such as the Bayou Coating plant in New
Iberia, to lay barges in the pipeline construction workspace or an offloading dock at the terminusof Walker Road (see appendix E). These barge deliveries would average one every other day
during the 5- and 7-month construction periods of each lateral. In the event that pipeline
construction phases overlap at all, barge deliveries could increase to one per day, still a minimal
increase in vessel traffic. Rake-haul type barges and lay barges would use Wilkinson Canal andBarataria Bay Waterway to access the pipeline right-of-way and workspaces. These Project barge
access routes are shown in appendix E. Venture Global plans to dredge discrete portions along
the Wilkinson Canal and lateral routes connecting it and Barataria Bay Waterway to the pipeline
right-of-way, as discussed in section 4.3.2.2.
Crew boats carrying 25 persons each would transport pipeline workers from Myrtle Grove
Marina along Wilkinson Canal to lay barges along the pipeline construction site. In Phase I, crewboats would average 10 vessels per day and increase to 14 vessels per day during the 1-month peak
construction period. In the event that phase construction overlaps, crew boat traffic could average
14 vessels per day. The crew boats would remain on-site until they delivered workers back to
Myrtle Grove Marina at the end of the work period (see “proposed employee transport route” inappendix E).
Venture Global has met with Coastal Protection Restoration Authority (CPRA) to discuss
the pipeline construction plan and associated barge traffic, because CPRA is managing theBarataria Bay Rim Marsh Creation and Renourishment Project, a site with an access canal thatintersects one of the barge access channels (Allen et al., 2017). During the meeting, the parties
concluded that the barge access channel is sufficiently wide such that, even if construction
overlapped, the width of the barge access channel and the intermittent vessel movements
associated with both projects would preclude direct or indirect impacts on either project (Allen etal., 2017). Given this finding and the low average level barge traffic associated with pipeline
construction, we conclude that pipeline construction impacts on marine transportation would beminor and temporary. Crew boat traffic numbers would be higher than barge trips, but we do notfind that these would be more than a minor change.
4.9.9

Environmental Justice

Executive Order 12898 (59 Federal Register [FR] 7629) established a federal policy underwhich federal agencies must identify and address, as appropriate, disproportionately high andadverse human health or environmental effects of its programs, policies, and activities on minority
or low-income populations. Consistent with Executive Order 12898, the CEQ calls on federal
agencies to actively scrutinize the following issues with respect to environmental justice (CEQ,
1997):•

racial and economic composition of affected communities;•

health-related issues that may amplify project effects on minority or low-income
individuals; and

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•

public participation strategies, including community or tribal participation in theprocess.

The CEQ (1997) advises using demographic and poverty-level data published by the U.S.
Census Bureau to identify minority and low-income populations in affected areas. According tofederal guidance documents, minority populations are present in an affected area where racial andethnic minority groups exceed 50 percent or are “meaningfully greater” than in the general
population of the larger surrounding area, referred to as a reference area (CEQ, 1997; EPA, 1998).
A report by the Federal Interagency Working Group on Environmental Justice and NEPA
Committee (2016) states, “The meaningfully greater analysis requires the use of a reasonable,
subjective threshold (e.g., 10 or 20 percent greater than the reference community).”In this environmental justice analysis, we defined the affected area as the census blockgroup occupied by the Project facilities. The census block group, a statistical division of the census
tract which generally contains 600 and 3,000 residents, was selected based on guidance from the
EPA (1998) that each area under investigation should be an “appropriate unit of geographic
analysis” that does not “artificially dilute or inflate the affected minority population.” The census
block group is also one of the smallest units for which the U.S. Census Bureau provides
demographic and economic statistics. We established Plaquemines Parish as the reference area,
representing the general population with which minority percentages in the affected area (selected
block group) were compared. To determine whether minority percentages were “meaningfully
greater” in the affected area compared with the reference area, we assumed a difference of 10
percentage points indicated a meaningful difference.
As with minority populations, low-income populations in an affected area can be identified
as potential environmental justice communities by comparing the affected area to a reference
community (Federal Interagency Working Group on Environmental Justice and NEPA
Committee, 2016). We used poverty status statistics estimated by the U.S. Census Bureau toestimate the percentage of low-income individuals in the affected area. If the percentage ofindividuals below the poverty level was greater than the percentage in Plaquemines Parish, we
identified it as a potential environmental justice community.
We also considered from the perspective of environmental justice the remaining area southof the Project that depends on SH 23 for egress and ingress, because residents could be at risk if
access were cut off during a rare, unexpected event. For this subset of the parish, we used census
tract-level data, reasoning that the collective region would become vulnerable in the event of ahighway closure. The census tracts in this part of the southwest bank of Plaquemines Parish cover
all remaining territory south of the terminal. We performed the same demographic analysis on the
additional census tracts to evaluate whether their populations met the criteria for potential
environmental justice communities.
Table 4.9-6 provides the minority- and poverty-level percentages in the primary affected
area, the remainder of the southwest bank, the parish, and the state. Anywhere a census blockgroup or tract jurisdiction’s minority or poverty percentage exceeds the above-establishedthreshold is shaded in grey. Figure B-8 in appendix B depicts the boundaries of the affected census
block group and tracts in the southwest bank of Plaquemines Parish.

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The primary affected area is a potential environmental justice community based on thecriteria above. Of the census tracts that comprise the remainder of the southwest parish south of
the terminal, three have minority percentages that are at least 10 percent greater than the parish’s
overall minority percentage and poverty-level percentages that exceed the parish’s overall poverty
percentage. One other census tract, the tract at the southernmost tip of Plaquemines Parish, has apoverty-level percentage that exceeds the parish’s poverty percentage.
Under general construction and operation conditions, the Project would not have asignificant risk of impact to human health or environmental conditions in the southern west bankcensus tracts below the terminal because of their distance from Project activities—9.6 or more
miles away and the mitigation measures proposed or recommended. However, residents in these
census tracts would be vulnerable if a catastrophic incident or other more likely emergency
occurred on the terminal site that limited or restricted vehicle travel on SH 23.

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Table 4.9-6
Minority and Income Statistics in the Affected Area, Census Tracts Below the Terminal, the Parish, and the State, 2012-2016 Estimates a,b,c
Non-Hispanic Population

Asian
Alone
(%)

Pacific
Islander
Alone
(%)

Other
Race
Alone
(%)

Two orMore
Races
Alone(%)

Total
Hispanic,of any
race
(%)

Total
Minority
(%)

Total
Below
Poverty
Level(%)

Geographic
Area

Total
Population

White
Alone(%)

Black
Alone
(%)

AmericanIndianAlone(%)

Louisiana

4,645,670

59.3

31.9

0.5

1.7

0.0

0.2

1.6

4.8

40.7

19.7

Plaquemines
Parish23,584

66.2

20.5

0.8

3.6

0.0

0.1

2.6

6.2

33.8

17.2

Block Group 1,
CT 504 d

1,095

28.2

69.3

2.5

0.0

0.0

0.0

0.0

0.0

71.8

24.5

CT 505 e

1,432

23.9

66.7

2.5

0.6

0.0

0.0

5.7

0.6

76.1

48.8

CT 506 f

926

53.7

25.7

0.0

14.4

0.0

0.0

2.3

4.0

46.3

30.0

CT 507 g

1,264

83.1

0.0

0.0

13.6

0.0

1.8

1.4

0.0

16.9

16.4

CT 508 h

1,206

62.3

15.8

1.9

8.5

0.0

0.0

5.4

6.1

37.7

40.0

a U.S. Census Bureau, 2017fb U.S. Census Bureau, 2017gc Data for all geographic areas based on the U.S. Census Bureau 2012-2016 American Community Survey
d Includes Project LNG facility and pipeline system sites
e Includes Port Sulphur Census Designated Place (CDP)
f Includes Empire CDP
g Includes Buras-Triumph CDP
h Includes Boothville-Venice CDPKey:
CT: census tract
Grey highlighted value is a percentage that exceeds threshold defined in text, indicating a potential environmental justice population.

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Because the southwest bank is rural and sparsely populated, Block Group 1, Census Tract504, where the Project is located, stretches over 10 miles north and south, encompassing several
small scattered communities. The closest are the Deer Range neighborhood and the Suzie BayouCampsites. These neighborhoods are locally referred to as “Lake Hermitage,” because of theirmain access road of the same name. According to the Plaquemines Parish Comprehensive Master
Plan, camp communities are “residential communities built outside levee protection zones inmarshland and swamp-liked [sic] areas with limited infrastructure, characterized by a part-time orseasonal resident population often engaging in commercial fishing or recreational fishing andhunting” (Plaquemines Parish, 2012). Although these communities began as fishing and hunting
campsites, many site owners have constructed homes on permanent foundations and live there
year-round. Residential structures in these communities range from 750 feet to 3,000 feet (0.6
mile) from the terminal boundary. A vegetative buffer partially screens them from the terminalsite. A 26-foot-high floodwall would be erected around the perimeter, providing additional
screening, but the storage tanks, stacks, and other tall features would not be shielded.
Another similar community, consisting of recreational and permanent homes, is located
2.6 miles southeast (3 miles driving distance) on Lake Hermitage Road. Occupants would drive
past the terminal site on their way to and from SH 23. One other relatively close developmentwith residential property is 2.3 miles northwest on SH 23, designated as marina/harbor complex
in the Parish’s Draft Final Comprehensive Land Use Plan (Plaquemines Parish, 2012). The plan
defines this use as land area “around commercial and recreational marina and harbors, including
docks, with water-related commercial such as bait shops, seafood markets, small-scale seafood
processing, boat services, hotels, condominiums and other residential, restaurants, outdoor
recreation, water-related tourist services, and public uses.” A selection of street names in thisneighborhood are Pine Lane, Cypress Lane, and Pecan Lane. Myrtle Grove, another marina/harbor
complex in the area, is 3.7 miles northwest of the terminal on SH 23.
The residences closest to the pipeline workspace are 1,500 feet, or approximately 0.3 mile,away. Pipeline construction activities would last approximately one-half year for each phase, after
which the surface would be immediately restored and ongoing impacts during operation would be
negligible. No compressor stations would be built or augmented as part of the Project. Nearby
residents with recreational vessels may encounter construction barge vessels in inland waterways,
but these Project barges are not expected to impede traffic or have other significant impacts given
the estimated low traffic volume (see Section 4.9.8.2 Marine Transportation).
Air emissions from terminal construction and operations must comply with NAAQS,
established to protect human health and the health of flora and fauna, as well as the standards of
the Louisiana Toxic Air Pollutant Program Global has prepared an air permit application, withsummary results in Section 4.11, Air Quality and Noise, and submitted the application to the LDEQ
for review. The LDEQ review process will evaluate all proposed emission rates and control
technologies for compliance with applicable regulations. Venture Global is also required toprepare an air quality impact analysis to demonstrate that proposed emission rates on a short-term
and annual basis would not result in ambient pollutant concentrations that exceed ambient air
quality standards. An air permit to construct and operate the facility will not be issued unless the
Venture Global demonstrates the Project’s ability to meet all emission rates, control technology
requirements, and ambient air quality standards. During operation, Venture Global would use asite-specific program to detect leaks utilizing a combination of design and4-153

auditory/visual/olfactory leak detection methods. Any detected leak would be immediately
recorded and scheduled for repair in accordance with all applicable laws.
Noise produced onsite at the terminal would remain within applicable FERC limits.
Flaring would create negligible, intermittent impacts at the closest NSAs because of its lowfrequency occurrence and low exit velocity. Venture Global would implement several mitigation
measures, described in Section 4.11, Air Quality and Noise, e.g., liquefaction air coolers reduced
to sound power level of 88 dBA per fan, heat recovery steam generators equipped with silencers
to limit the sound power level to a maximum of 115 dBA during blowdown events. We haverecommended that Venture Global submit a full power load noise survey no later than 60 days
after commissioning, to ensure controls are sufficient to maintain a noise level below an Ldn of 55
dBA at each NSA.
Siting LNG facilities with regard to ensuring that the proposed site selection and location
would not pose an unacceptable level or risk to public safety is required by DOT’s regulations in
49 CFR 193, Subpart B. DOT reviews the information and criteria submitted by Plaquemines
LNG to demonstrate compliance with the safety standards prescribed in 49 CFR 193, Subpart B
and issues an LOD to the Commission on whether the proposed facilities would meet the DOT
siting standards. The LOD will serve as one of the considerations for the Commission to deliberate
in its decision to authorize, with or without conditions, or deny Venture Global’s application. All
safety concerns addressed in DOT’s review are summarized in Section 4.12.5, Reliability and
Safety. In addition, the USCG issued a Letter of Recommendation stating that the Lower
Mississippi River is suitable for LNG traffic associated with the Project in accordance with theguidance in USCG’s Navigation and Vessel Inspection Circular (NVIC) 01-2011, which considers
safety and security mitigation measures based on Zones of Concern from maximum credible
releases from accidental and intentional events as discussed in section 4.12.5. Furthermore, FERC
staff evaluated the preliminary engineering design to ensure that there were sufficient layers ofprotection to enhance the reliability and safety of the facility to mitigate the risk of impact on the
public. Based on our preliminary evaluations of the engineering design and with the incorporationof mitigation measures and oversight, we conclude that the Plaquemines LNG terminal design
would include acceptable layers of protection or safeguards that would reduce the risk of apotentially hazardous scenario from developing into an event that could impact the offsite public.
Because of the mitigation and project design features described above, we do not expect
residential communities closest to the Project to experience high and adverse impacts on their
human health or environment from normal construction and operation activities. Thus, weconclude that the Project would not disproportionately affect low-income or minority populationsin the primary affected area.
If a rare catastrophic event occurred at the terminal that limited or restricted vehicle travel
on SH 23, communities in the southern west bank that depend on access to SH 23 south of theterminal could be vulnerable. Certain residential subdivisions in Census Tract 504 access SH 23
south of the terminal, as do all other residences in Census Tracts 505, 506, and 508, which are theother tracts identified as potential environmental justice communities based on their percentagesof minority and low-income residents. We find this vulnerability in the southern west banknecessitates targeted outreach, and to some extent, this has occurred. CEQ (1997) environmental
justice guidelines emphasize public participation during the permitting and development of a4-154

project. Moreover, the EPA (2011a) environmental justice guidelines recommend enhancing
opportunities for residents to participate in the decision-making process.
Venture Global held two community open houses, one in Plaquemines Parish on September
15, 2015, and another in Jefferson Parish on September 16, 2015, with about 75 residents in
attendance, combined. Project staff representing multiple disciplines and FERC representatives
attended, and thus were available to answer questions and hear comments from the public. In
addition, FERC sponsored a Project scoping meeting on October 21, 2015, in Plaquemines Parish,in accordance with NEPA guidance. Beforehand, Project representatives were available to answer
questions from the public.
The DOT regulations require LNG operators to coordinate with appropriate local officials
in preparation of an emergency evacuation plan for the LNG terminal. In addition, USCG requires
the development of an emergency manual with certain information. Furthermore, under section
311 of the Energy Policy Act of 2005, FERC is required to review and approve an emergency
response plan and associated cost sharing plan prior to final approval to begin any construction.
As recommended in section 4.12.5, Venture Global would be required to work with local, state,
and federal agencies to develop its emergency response plan, and this plan will address potential
catastrophic events as required by DOT regulations at the terminal and other more likely
emergencies that could close SH 23 and/or impact surrounding communities. The emergency
response plan must be approved by FERC prior to initial site preparation, and Venture Global
states that it will continue its coordination with public agencies to complete the plan.
4.10

CULTURAL RESOURCES

Section 106 of the NHPA, as amended, requires that FERC take into account the effect of
its undertakings on properties listed, or eligible for listing, on the NRHP, as well as to afford the
ACHP an opportunity to comment on the undertaking. Venture Global, as a non-federal party, isassisting FERC in meeting its obligations under section 106 of the NHPA and the implementing
regulations in 36 CFR 800 by preparing the necessary information, analyses, andrecommendations, as authorized by 36 CFR 800.2(a)(3).
Construction and operation of the Project could have the potential to affect historic
properties (i.e., cultural resources listed or eligible for listing on the NRHP). Historic properties
include pre-contact or historic archaeological sites, districts, buildings, structures, and objects, aswell as locations with traditional value to tribes or other groups. Historic properties generally mustpossess integrity of location, design, setting, materials, workmanship, feeling, and association, andmust meet one or more of the criteria specified in 36 CFR 60.4. Based on these criteria, historic
properties are those properties:a) that are associated with events that have made a significant contribution to the broad
patterns of our history; orb) that are associated with the lives of persons significant in our past; orc) that embody the distinctive characteristics of a type, period, or method of construction,or that represent the work of a master, or that possess high artistic values, or that4-155

represent a significant and distinguishable entity whose components may lackindividual distinction; ord) that have yielded, or may be likely to yield, information important n pre-contact orhistory.
Venture Global completed a records review and cultural resources surveys of the terminalsite and pipeline system proposed route in Plaquemines Parish, Louisiana. The investigations
covered both archaeological and architectural resources.
4.10.1 Terminal Site
The area of potential effects (APE) for these investigations was defined as the 635-acretract and marine facilities where construction would take place and for which direct effects were
evaluated. An additional 100 acres that have been proposed for use as temporary workspace eastof the terminal site also were reviewed. The marine facilities, located on the Mississippi River,also are included in the APE. However, although there is dredge for barge access, no dredging
would be required for facility construction or for LNG carriers to access the berthing area.
To account for potential off-site viewshed impacts that the terminal facilities may have on
aboveground historic resources, the APE also includes areas to be evaluated for indirect effects.
This includes a 1.0-mile-wide buffer extending out from the terminal site boundary. No previously
recorded individual historic structures were identified within the 1.0-mile-wide buffer area as partof the records review.
No new archaeological sites were identified; however, the records review identified fivepreviously recorded archaeological sites partially or wholly within the APE. These sites are listed
below.
•

16PL173: This resource is a historic twentieth-century site consisting of a concrete
foundation.

•

16PL189: This archaeological site is a brick platform for a nineteenth-century steampowered water wheel.

•

16PL191: This resource consists of the remnants of a twentieth-century agricultural
bridge.

•16PL266: This archaeological site is a historic railroad; no remains of it were identified
within the terminal site.

•

16PL102: This resource contains surface and subsurface deposits, including buried
intact brick features, associated with a nineteenth-century industrial sugar mill locatedwithin the Deer Range Plantation.

No cultural materials were encountered at the location of 16PL173. 16PL189 was intact,
but the resource consisted of architectural remains that did not meet the NRHP criteria. It wasrecommended ineligible for the NRHP and that no further work was needed. 16PL191 consists of
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the remaining posts from a bridge across an agricultural canal in the floodplain of the Mississippi
River. The remaining materials of the bridge had deteriorated. 16PL266 is the New Orleans andLower Coastal Railroad, which parallels the river and runs through the terminal site. Within theterminal site, all aspects of the railroad were removed, and no associated artifacts or features wereidentified. These sites were recommended as ineligible for the NRHP, and the investigations
indicated that no further work was needed. The remaining components of these archaeologicalsites have the potential to be physically damaged by ground disturbance and associated activities
occurring at the terminal site.
16PL102, also known as the Deer Range Mill site, is an industrial site located on the southbank of the Mississippi River on either side of the levee. It was initially recorded in 1983 as partof an inventory conducted for the National Park Service’s comprehensive cultural resource
management plan for the USACE, focusing on the lower Mississippi Valley. A portion of the site
had been destroyed due to construction of the levee. The site was recommended for additional
testing. Venture Global has committed to avoiding the resource and to protecting the site by
fencing.
On June 22, 2015, prior to the initiation of fieldwork, a letter was submitted to the SHPO
to introduce the Project. A draft report documenting the cultural resource investigations for theterminal site was submitted to the SHPO on December 30, 2015. In a letter dated January 7, 2016,
the SHPO concurred that no historic properties would be affected by the facilities, provided
16PL102 would be avoided during construction and operation of the Project. On June 11, 2016, asite avoidance plan for 16PL102 was submitted to the SHPO for review and comment. The SHPO
concurred with this plan on August 22, 2016. An additional letter was submitted to the SHPO on
February 2, 2017, for the adjacent temporary workspace of about 100 acres. The SHPO responded
on February 17, 2017, with its concurrence that 16PL173 is not eligible for the NRHP and that noeffects on historic properties would occur at the terminal site and adjacent workspace. We agree.
The February 17, 2017, SHPO response letter indicated the need for the submittal of the
final report for No. 22-5141-1 and the site form for 16PL173. The final report for the Terminal
Site Addendum and updated site form for 16PL173 was provided to the SHPO on August 2, 2018.
The Final Phase I Cultural Resources Survey Report for the Project has been reviewed by the
SHPO and accepted on November 28, 2018.
The results of a remote sensing (sonar) survey for the marine facilities was submitted to
the SHPO on March 6, 2017. A large, rectangular-shaped anomaly, approximately 200 feet longby 27 feet wide, was encountered. The anomaly has a relief of 15 feet above the surrounding riverbottom and may be a sunken barge associated with recent commercial activity. The SHPO
concurred with no historic properties being affected on March 28, 2017. We agree.
4.10.2 Pipeline System
For the pipeline system, the direct APE includes three components: the construction
workspace for the pipelines, access roads, and appurtenant aboveground facilities; the dredged
portions of the barge access routes; and the barge staging area. To account for potential off-site
viewshed impacts that the pipeline system facilities may have on historic structures, the APE also
includes areas to be evaluated for indirect effects. This includes a 0.5-mile-wide buffer on either
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side of the mid-line of the pipelines and a 0.5-mile-wide buffer on either side of the barge accesschannels.
In order to determine if archaeological resources or historic structures were present within
the APE, an approximately 300-foot-wide survey corridor along the pipeline route wasinvestigated by airboat survey in open water and inundated marshland and by pedestrian and/or
shovel test surveys in areas that were not inundated. In areas where additional temporary
construction workspace would be required, the survey corridor was expanded.
No archaeological resources or historic structures were identified within the pipeline
construction rights-of-way, additional temporary workspace, or construction footprints of thetemporary and permanent access roads. Additionally, no historic structures were identified within
0.5 mile of the pipeline system or its associated workspaces. No known or previously identified
sites are present.
The areas not surveyed are primarily composed of saturated areas unlikely to yield cultural
artifacts. Venture Global consulted with the SHPO on January 12, 2017, regarding the proposedroute changes requesting clearance to construct without conducting additional archaeologicalinvestigations. The SHPO accepted this letter report as final and stated there would be no effects
on historic properties on January 27, 2017. We agree. Environmental Condition Number 23 in
the draft EIS has been addressed.
4.10.3 Tribal Consultation
As part of this Project, tribal consultation was conducted by Venture Global and FERC
with the following tribes:•

Alabama-Coushatta Tribe of Texas;•

Chitimacha Tribe of Louisiana;•

Choctaw Nation of Oklahoma;•

Coushatta Tribe of Louisiana;•

Jena Band of Choctaw Indians;•

Mississippi Band of Choctaw Indians;•

Seminole Nation of Oklahoma;•

Seminole Tribe of Florida; and•Tunica-Biloxi Indians of Louisiana.

Table 4.10-1 provides a summary of the correspondence, including information sent andreceived by FERC, the tribes, and Venture Global.

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Table 4.10-1
Correspondence with Federally Recognized Tribes
Date

Document/Topic

Action Taken

June 22, 2015

Introductory Letter

Letter from Venture Global to tribes

July 21, 2015

Request for cultural resources
survey reports

Email response from the Jena Band of Choctaw
Indians to Venture Global

August 3, 2015

Response noting that the Project islocated within their area of historicinterest and requesting Project
information

Email response from the Choctaw Nation of
Oklahoma to Venture Global

September 30, 2015

Information Update

Letter from Venture Global to tribes

November 17, 2015

Request for cultural resources
surveys

Email response from the Choctaw Nation of
Oklahoma to Venture Global

November 18, 2015

Request for consulting party statusunder Section 106, a map showing
the Project and all archaeologicalsites within 1.0 mile of the APE, a
copy of all survey reports, and a
copy of the EIS

Letter response from the Choctaw Nation of
Oklahoma to FERC

February 16, 2016

Provision of reports

Letter response from Venture Global to the
Choctaw Nation of Oklahoma and the Jena
Band of Choctaw Indians

April 13, 2016

Consultation Letter

Letter from FERC to tribes

October 21, 2016

Response to Information Request

Letter response from Venture Global to the
Choctaw Nation of Oklahoma and the Jena
Band of Choctaw Indians

November 22, 2016

Comments noting need to notify thetribe in case of inadvertent
discovery

Email response from the Choctaw Nation of
Oklahoma to Venture Global

January 12, 2017

Information Update

Letter from Venture Global to tribes

January 12, 2017

Introduction Letters

Letter from Venture Global to the Seminole
Nation of Oklahoma and the Seminole Tribe of
FloridaFebruary 8, 2017

Lack of presence of resources;
request for list of flora; anddeferring to other tribes

Response from the Seminole Nation of
Oklahoma to Venture Global

February 13, 2017

Response with reportaddendum(Phase I Cultural
Resources Report LNG Terminal
Site: 100 acre land Parcel report)
and a revised copy of theunanticipated discoveries plan

Response from Venture Global to the Choctaw
Nation of Oklahoma and the Jena Band of
Choctaw Indians

March 29, 2017

Comments to unanticipateddiscoveries plan and concurrence on
Phase I Cultural Resources Report
LNG Terminal Site: 100 acre land
Parcel report

Email response from the Choctaw Nation of
Oklahoma to Venture Global

4-159Table 4.10-1
Correspondence with Federally Recognized Tribes
Datetribes:Document/Topic

Action Taken

April 11, 2017

Concurrence with finding of noeffect and request for adherence tounanticipated discoveries
procedures

Email response from the Jena Band of Choctaw
Indians to Venture Global

June 22, 2017

Provision of flora list

Letter response from Venture Global to the
Seminole Nation of Oklahoma

June 23, 2017

Information summarizing remotesensing data

Email response from Venture Global to the
Choctaw Nation of Oklahoma

On June 22, 2015, Venture Global provided Project introduction letters to the following•

Alabama-Coushatta Tribe of Texas;•

Chitimacha Tribe of Louisiana;•

Choctaw Nation of Oklahoma;•

Coushatta Tribe of Louisiana;•

Jena Band of Choctaw Indians;•

Mississippi Band of Choctaw Indians; and•Tunica-Biloxi Indians of Louisiana.

Update letters and emails were provided to each of these tribes on September 30, 2015,
October 22, 2015, and January 12, 2017, by Venture Global. In addition, FERC sent consultation
letters to the tribes on April 13, 2016.
The Choctaw Nation of Oklahoma provided a response on August 3, 2015, noting that the
Project is located within their area of historic interest and requested Project information. After
receipt of the October 2015 follow-up, the tribe also responded on November 17, 2015, noting theneed for a cultural resources survey. In a letter to FERC dated November 18, 2015, the Choctaw
Nation of Oklahoma requested the following: consulting party status under Section 106, a map
showing the Project and all archaeological sites within 1.0 mile of the APE, a copy of all survey
reports, and a copy of the EIS. Venture Global provided cultural survey information to the tribe
on February 16, 2016, October 21, 2016, and February 13, 2017 (see Table 4.10-1). The EIS will
be made available to the tribes upon publication of the draft.
Additional information was provided to the Choctaw Nation of Oklahoma by Venture
Global on October 21, 2016. The tribe provided comments on November 22, 2016. Venture
Global then provided a report addendum and a revised unanticipated discoveries plan on February
13, 2017. The tribe responded on March 29, 2017, noting the need for tribal consultation if sites
4-160

are found. They concurred with the findings in the Phase I Cultural Resources Report for theterminal site’s 100-acre land parcel, and they requested to be notified in the event of an
unanticipated discovery. On June 23, 2017, Venture Global sent a letter report to the Nation
summarizing the remote-sensing survey data.
The Jena Band of Choctaw Indians responded on July 21, 2015, requesting the cultural
resources survey reports. Venture Global provided this information, consisting of the Phase I
Cultural Resource Report LNG Terminal Site, Plaquemines Parish, Louisiana and the Phase I
Cultural Resource Report Lateral Pipelines, Plaquemines Parish, Louisiana, on February 16,
2016. Additional information was then provided by Venture Global on October 21, 2016, with thesite avoidance plan, the Unanticipated Discovery Plan, and an addendum report. Venture Global
then provided a report on the 100-acre land parcel for the terminal site and a revised copy of the
Unanticipated Discovery Plan on February 13, 2017. The Jena Band of Choctaw Indians, on April
11, 2017, concurred with the finding of no effect on cultural and historic properties. The tribe
further requested that all inadvertent discovery procedures be followed in the event that an
unanticipated discovery occurs.
On January 12, 2017, a Project introduction letter also was provided to the Seminole Nationof Oklahoma and the Seminole Tribe of Florida. On February 8, 2017, the Seminole Nation of
Oklahoma responded that they were not aware of any historic resources that would be affected by
the Project and requested a list of flora within the Project area. The Seminole Nation of Oklahoma
deferred to another tribe and the SHPO recommendation. On June 22, 2017, Venture Global
provided a list of flora for the area to the Seminole Nation of Oklahoma.
4.10.4 Unanticipated Discovery Plan
Venture Global has prepared an Unanticipated Discovery Plan to be implemented in theevent that previously unreported cultural resources or human remains are encountered during
construction of the Project. This plan provides for the notification of interested parties, including
the SHPO, tribes, and appropriate officials. The plan was submitted to the Louisiana SHPO on
January 27, 2016. Comments were received on February 8, 2016. A copy of the final plan would
be kept on site during construction, and field management staff would be trained for the procedures
contained within it. A letter was sent to the SHPO on February 2, 2017, providing the revised
plan. Due to comments received by tribes, an update was provided to the Louisiana SHPO on June29, 2017. FERC staff has reviewed the Unanticipated Discovery Plan and find it acceptable.
4.10.5 Compliance with the National Historic Preservation Act
Venture Global investigated the Terminal site, 300-foot corridor for the proposed pipeline
route, and associated workspaces in Plaquemines Parish, Louisiana for cultural resources. The
survey reports and additional documentation were submitted to interested parties forcomments. The Louisiana SHPO did not disagree with the APE and stated that the Project would
have no effects on historic properties.
No traditional cultural properties or properties of religious or cultural importance to Indian
tribes have been identified by Venture Global, its consultants, the SHPO, or tribes. The FERC
staff agrees with the SHPO, and the Project would have no effects on historic properties.

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4.11

AIR QUALITY AND NOISE

4.11.1 Air Quality
This section describes the air quality conditions that would directly or indirectly be affectedby construction and operation of the Project. The section summarizes federal and state air quality
regulations that are applicable to the Project. The section also characterizes and quantifies theexisting air quality and describes potential impacts the construction and operation of Project
facilities may have on air quality.
The term “air quality” refers to the relative concentrations of pollutants in the ambient air.
The subsections below describe well-established air quality concepts that are applied tocharacterize air quality and to determine the significance of increases in air pollution. This
includes metrics for specific air pollutants known as criteria pollutants, in terms of ambient air
quality standards, regional designations to manage air quality known as Air Quality Control
Regions (AQCR), and the on-going monitoring of ambient air pollutant concentrations under stateand federal programs.
Combustion of natural gas would produce criteria air pollutants such as ozone (O3), carbon
monoxide (CO), sulfur dioxide (SO2), and inhalable particulate matter (PM2.5 and PM10). PM2.5
includes particles with an aerodynamic diameter less than or equal to 2.5 micrometers, and PM10
includes particles with an aerodynamic diameter less than or equal to 10 micrometers. Combustionof fossil fuels also produces volatile organic compounds (VOCs), a large group of organic
chemicals that have a high vapor pressure at room temperature; and oxides of nitrogen (NOX).
VOCs react with nitrogen oxides, typically on warm sunny summer days, to form ozone. Other
byproducts of combustion are greenhouse gases (GHGs) and hazardous air pollutants (HAPs).
HAPs are chemicals known to cause cancer and other serious health impacts.
GHGs produced by fossil-fuel combustion are CO2, methane (CH4), and nitrous oxide(N2O). The status of GHGs as a pollutant is not related to toxicity. GHGs are non-toxic and nonhazardous at normal ambient concentrations. GHGs are gases that absorb infrared radiation in theatmosphere are the primary cause of warming of the global climate system since the 1950s.
Emissions of GHGs are typically quantified, expressed and regulated in units of carbon dioxide
equivalents (CO2e), where the potential of each gas to increase heating in the atmosphere isexpressed as a multiple of the heating potential of CO2 over a specific timeframe, or its global
warming potential (GWP). The 100-year GWP of CO2 is 1, CH4 is 25 and N20 is 298. To obtain
the CO2e quantity, the mass of the particular GHG is multiplied by the corresponding GWP. The
CO2e value for each of the GHG compounds is summed to obtain the total CO2e GHG emissions.
Other pollutants, not produced by combustion, are fugitive dust and fugitive emissions.
Fugitive dust is a mix of PM2.5, PM10, and larger particles that become airborne by moving
vehicles, earth (soil) transport, or wind erosion. Fugitive emissions, in the context of this EIS,
would be fugitive emissions of methane from operational pipelines, the LNG terminal, and otheraboveground facilities.

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4.11.1.1 Regional Climate
Regional Climate
The Project would be located in Plaquemines Parish, Louisiana, where the climate is humid
and subtropical with long, hot summers and short, mild winters. The humidity in the Project area
is relatively high due to the proximity of the terminal site to the Gulf of Mexico and the Mississippi
River (NOAA, 2016). Wind direction in the Project area is primarily from the south from May
through December. During January and February, the prevailing winds are from the eastnortheast, and in March and April the prevailing winds are from the north. Over the course of theyear, mean wind speeds vary from 6 miles per hour (mph) to 10 mph, with peak gust winds ranging
from 44 to 66 mph, depending on the month. The highest average wind speed of 10 mph (moderate
breeze) occurs in February, March, and April. The lowest average wind speed of 6 mph (gentle
breeze) occurs in July and August (National Climatic Data Center, 1997). Historical windsummaries are substantiated by analysis of wind data from the New Orleans International Airport
meteorological station for 2010 through 2014. Analysis of this data reveals predominant winds
from the south and south-southeast as well as significant contributions from the north. The averagewind speed for the period is 3.8 meters per second (m/s) (or 8.6 mph) and calm winds (< 0.5 m/s)
(or 0.2 mph) occur 98 percent of the time.
The Project area receives an annual average of 62.5 inches of rain. October is typically thedriest month of the year, with a monthly mean of 3.5 inches, whereas June tends to be the wettest
month, with a monthly mean of 8.1 inches. Snow events are rare, with an annual mean of 0.2 inchof snow, and are most likely to occur in February or December. Temperatures range from amonthly average of 55.3°F in January to a monthly average of 88.3°F in July and August (Southern
Regional Climate Center, 2015).
4.11.1.2 Existing Air Quality
The LNG terminal and pipeline system would be located in the same general geographic
area; therefore, this existing air quality discussion pertains to both parts of the Project.
Background Air Quality and Designation Status
The EPA, as required by the CAA, has established National Ambient Air Quality Standards(NAAQS) to protect public health (primary standards) and welfare (secondary standards). Primary
standards are designed to protect human health, and secondary standards focus on the protectionof plant and animal life, buildings, and other features in the public interest. Louisiana has adopted
the federal primary and secondary NAAQS. The NAAQS reflect the relationship between
pollutant concentrations and health and welfare effects. The NAAQS are codified in 40 CFR 50.
The LDEQ has adopted the NAAQS.
Standards have been set for six principal pollutants that are called “criteria pollutants.”
These criteria pollutants are: ground-level ozone, CO, NO2, SO2, PM10, PM2.5, and airborne lead.
Ozone develops as a result of a chemical reaction between NOX and VOCs in the presence ofsunlight. Accordingly, NOX and VOCs are often referred to as ozone precursors. PM2.5 may bedirectly emitted and can also be secondarily formed in the atmosphere as a result of SO2 and NOX

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emissions. SO2 and NOX are also referred to as PM2.5 precursors. See the NAAQS standards athttps://www.epa.gov/criteria-air-pollutants/naaqs-table.
Air Quality Control Regions and Attainment Status
An air quality control region is defined under 42 U.S.C. 7407(c) as “any interstate area or
major intrastate area which the Administrator of the EPA deems necessary or appropriate for theattainment and maintenance of ambient air quality standards.” Each AQCR, or portion(s) of an
AQCR, is classified as either “attainment,” “nonattainment,” “unclassifiable,” or “maintenance,”with respect to the NAAQS.
Plaquemines Parish is located in the Southern Louisiana-Southeast Texas Interstate AQCR.
Plaquemines Parish is designated as unclassifiable (and treated as attainment) for ozone, PM2.5,
and NO2. For all other criteria pollutants, Plaquemines Parish is designated attainment.
Air Quality Monitoring and Existing Air Quality
The EPA, along with state and local agencies, created a network of ambient air quality
monitoring stations that collect data on background concentrations of priority pollutants across theUnited States. To characterize the existing ambient air quality for the Project, available data weregathered from air quality monitoring stations that are nearest to the Project. The most recent
validated data from these monitoring sites are presented in table 4.11-1, which compares thehighest monitored data with the appropriate NAAQS standard for each criteria pollutant. All
monitored data were below the NAAQS.
For ambient air monitoring in Louisiana, the LDEQ’s Air Quality Assessment Division has
developed a statewide network of stationary monitoring stations to collect direct measurements of
air pollutant concentrations. Ambient air quality concentrations from 2013 through 2015 for areas
near the Project are provided in table 4.11-1.
Data from the air monitoring sites are available through the EPA’s Air Data database,which collects monitoring data nationwide. Venture Global has, in consultation with LDEQ,
determined that ambient air quality at the following monitoring sites is representative of ambient
air quality at the terminal site:•

Kenner station (Site ID 220511001), Jefferson Parish, as appropriate for the NOx
background concentrations;•Thibodeaux station (Site ID 220570004), Lafourche Parish, as appropriate for theozone background concentrations;•

Chalmette station (Site ID 220870007), St. Bernard Parish, as appropriate for the PM10
background concentrations;•

Marrero station (Site ID 220512001), Jefferson Parish, as appropriate for the PM2.5
background concentrations;

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•

Meraux station (Site ID 220870004), St. Bernard Parish, as appropriate for the SO2
background concentration; and•Baton Rouge-Capitol station (Site ID 220330009), East Baton Rouge Parish, as
appropriate for the CO background concentration, since this is the only site where
information is available from EPA. Lead concentration is also measured at this station.
Table 4.11-1
Background Ambient Air Quality (2013 to 2015)

Air
Pollutant

Averaging
PeriodSulfurDioxide (SO2)

1-hourMonitorValuesStatistic (units)

2015

2014

2013

Monitor
Station

99th Percentile of daily
1-hour maximum (ppb)

16

17

24

Meraux, LA

2.1

5.0

2.1

1.6

1.4

2.0

CarbonMonoxide(CO)

1-hour8-hour

Not to be exceeded morethan once per year (ppm)

NitrogenDioxide(NO2)

1-hour98th percentile (ppb)

45

30

32

AnnualAnnual mean

N/A

N/A

N/A

Ozone (O3)8-hourAnnual fourth-highest daily
maximum 8-hour concentration
(ppb)

64

67

65

Thibodeaux, LA

Particulate
Matter (PM10)24-hour

Not to be exceeded morethan once per year on
average over 3 years (µg/m3)

75

50

52

Chalmette, LA

Particulate
Matter (PM2.5)

24-hour

98th percentile (µg/m3)

21

17

18

AnnualAnnual mean (µg/m3)

8.0

7.8

7.8

Lead
(Pb)

Rolling
3-monthNot to be exceeded (µg/m3)

0.012

0.007

0.006

Baton Rouge, LA

Kenner, LA

Marrero, LA
Baton Rouge, LAKey:µg/m3 = micrograms per cubic meter
LA = Louisiana
N/A = not available
NAAQS = National Ambient Air Quality Standards
ppb = parts per billion
ppm = parts per million
PM10 = particulate matter of 10 microns or less in diameter
PM2.5 = particulate matter of 2.5 microns or less in diameter ppm = parts per million

4.11.1.3 Regulatory Requirements for Air Quality
Federal
New Source Review/Prevention of Significant Deterioration
New Source Review (NSR) is a pre-construction permitting program to ensure that air
quality is not significantly degraded when a new source of air pollution is constructed, or an
existing source is modified such that air pollutant emissions increase. NSR permits are legal
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documents that authorize a permittee to construct a source of emissions. Federal pre-construction
review of certain large projects varies for attainment and nonattainment areas. Federal preconstruction review for major sources in nonattainment areas is referred to as “Nonattainment New
Source Review,” while federal pre-construction review for sources in attainment areas is formallyreferred to as “PSD.” A minor NSR permit is required as a pre-construction authorization for minor
sources whose emissions are below the major source thresholds. Major source emission thresholds
vary depending on the air quality designation, with lower thresholds applicable in nonattainment
areas. The LNG terminal would be permitted under the NSR PSD program.
If a new source or major modification of an existing source is subject to the PSD program
requirements and is within 62 miles (100 kilometer) of a Class I area designated as pristine naturalareas or areas of natural significance, the facility is required to notify the appropriate federal
officials and assess the impacts of the project on the Class I area. The closest designated Class I
area to the Project is the Breton National Wildlife Refuge, located about 95 kilometers east of the
Project site; therefore, a PSD Class I analysis is required.
The LNG terminal would be a PSD major source, as the projected emissions for NOx, CO,
PM10, PM2.5, GHG, and total HAPs are above the major stationary thresholds as listed in 40 CFRPart 52.21(b)(1)(i)(a and b). Venture Global submitted a major source air permit application to
the LDEQ for PSD review in September 2015; a PSD permit application addendum on June 23,
2017; and seven supplemental information packages between June 8, 2018, and October 15, 2018.
The air permit application, addendum and supplements are still under review. The permit
emissions limits for the permitted pollutants are enforceable, and Venture Global must stay under
the potential to emit annual limits.
GHG emissions from sources located at the terminal site would be minimized byapplication of EPA-approved BACT under the PSD permitting program. Venture Global prepareda BACT analysis for the proposed gas-fired turbines and associated duct burners, simple-cycle
aeroderivative gas turbines, hot oil heaters, acid gas thermal oxidizer, fugitive emissions, andflares/purges at the terminal site, which was submitted to the LDEQ and EPA for review. CO2eemissions from the turbines, hot oil heaters, and acid-gas thermal oxidizers would be minimized
by implementing the following BACT measures:•

exclusively combusting low-carbon fuel gas;•

implementing good combustion practices;•

implementing proper operations and maintenance practices; and•properly implementing insulation for surfaces above 120°F.

Use of gaseous combustion fuels, in preference over other fossil fuels such as fuel oil orcoal, results in lower GHG emissions per unit of energy output. The proposed BACT emission
limit for each turbine and associated duct burners is 520,455 tpy of CO2e emissions, based on anannual total; the proposed BACT emission limit for each smaller aeroderivative simple-cycle
combustion turbine is 134,901 tpy of CO2e emissions, based on annual total per turbine; theproposed BACT emission limit for each hot oil heater is 104,114 tpy of CO2e emissions, based on

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an annual total; and the proposed BACT emission limit for each acid-gas thermal oxidizer is384,350 tpy of CO2e emissions, based on an annual total (this limit includes emissions from the
combustion of fuel gas and acid gas as well as emissions from the high-purity CO2 inlet stream tothe oxidizer from the acid-gas removal unit).
BACT for equipment leaks would be achieved through proper piping design, and the
proposed BACT emission limit is 6,500 tpy of CO2e emissions, based on an annual total.
BACT for the cold, warm, and LP vent flare pilot operations would be achieved throughgood management practices and proper flare design. The proposed BACT emissions limit for
combined flare pilot operations is 3,916 tpy of CO2e emissions, based on an annual total.
BACT for the cold, warm, and LP vent flare maintenance, startup, and shutdown and purge
operations is also achieved through good management practices and proper flare design. The
proposed BACT CO2e emission limits for each flare are as follows: cold flare – 14,441 tpy; warm
flare – 14,826 tpy; and LP flare – 13,980 tpy.
BACT was also evaluated for the marine loading flare for vessel gassing-up operations.
The BACT selected is good management practices, proper flare design, and marine gas recovery
for loading return gas with methane content of 80 percent or greater. The proposed BACT
emission limit is 4,045 tpy of CO2e, based on an annual total.
Venture Global also evaluated BACT for the proposed large essential emergency generator
engines, smaller essential emergency generator engines, and firewater pump engines. The
proposed BACT for these engines is good combustion practices, good operations and maintenancepractices, properly implementing insulation for surfaces above 120°F, and limiting normal
operations to 100 hours per year for each generator engine and 52 hours per year for each firewater
pump engine. The proposed BACT emission limits are 2,411 tpy of CO2e for the large essential
emergency generator engines, 81 tpy of CO2e for the smaller essential emergency generator
engines, and 28 tpy of CO2e for the firewater pump engines.
Venture Global provided an assessment of the feasibility of a carbon capture and storage(CCS) system to the LDEQ as part of the permit application BACT analysis for GHG. Venture
Global provided information on the technical and economic feasibility of developing and using
CCS for the terminal site. This technology involves employing a method to capture carbon fromthe exhaust stream of the combustion units and then finding a method for permanent storage(injecting the recovered CO2 underground through various means, including enhanced oil
recovery, saline aquifers, and un-minable coal seams). In the GHG BACT analysis, Venture
Global indicates that there is no commercially available CCS of the scale that would be required
to control CO2 emissions from turbines, thermal oxidizers, and flares such as those typicallylocated at an LNG terminal. In addition, no long-term CO2 storage facilities are located near the
Project as the region does not have geological formations that support sequestration. Therefore,
Venture Global’s application determined that due to the costs and environmental impacts
associated with additional infrastructure to send the carbon to a region where it could be properly
stored or used for enhanced oil recovery, CCS is not a feasible or preferable alternative. Based on
the magnitude of the estimated capital and annualized costs, Venture Global demonstrated that
CCS is not economically feasible. Even if feasibility could be demonstrated, Venture Global noted

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that any CCS system would cause significant adverse energy and environmental impacts due tothe additional water and energy needs for system operation, with the associated generation of
additional GHGs and other criteria pollutants from natural gas firing in combustion units. CSS
can be retrofitted in the future, should a market or other need arise.
New Source Performance Standards
NSPS, codified in 40 CFR 60, regulate emission rates and provide requirements for newor significantly modified sources. NSPS requirements include emission limits, monitoring,
reporting, and record keeping. Applicable NSPS for the Project, based on the types of emission
units and the expected date of installation, would potentially include, but not be limited to, thefollowing:•

40 CFR 60 Subpart A – General Provisions. Subpart A contains the general
requirements applicable to all emission units subject to 40 CFR 60.

•

40 CFR 60 Subpart Db – Standards of Performance for Industrial-CommercialInstitutional Steam Generating Units. This subpart applies to the 12 hot oil heaters
at the LNG terminal.

•

40 CFR Subpart Kb – Standards of Performance for Volatile Organic Liquid
Storage Vessels (including Petroleum Liquid Storage Vessels). This subpart applies
to the iso-pentane storage tanks at the LNG terminal.

•

40 CFR 60 Subpart IIII – Standards of Performance for Stationary Compression
Ignition Internal Combustion Engines (CI ICE). This subpart sets emission
standards for oxides of nitrogen and nonmethane hydrocarbons, hydrocarbons, NOx,CO, and PM. This subpart applies to the diesel engine emergency generators and to
the diesel engine emergency fire pumps, since the latter would be manufactured as
certified National Fire Protection Association firewater pump engines after July 1,
2006.

•

40 CFR 60 Subpart KKKK – Standards of Performance for Stationary
Combustion Turbines. Subpart KKKK regulates emissions of NOX and SO2. The ten
turbines at the power generating facility would be subject to NSPS Subpart KKKK.
The turbines would meet the less than 42 parts per million (ppm) NOX emission limit
specified in 40 CFR 60.4320(a) and 40 CFR 60 Subpart KKKK, table 1, for a new
turbine with a heat input at peak load higher heating value in excess of 850
MMBtu/hour firing fuels other than natural gas. The turbines would also be subject to
SO2 emission limitations in Subpart KKKK.

National Emissions Standards for Hazardous Air Pollutants
NESHAPs codified in 40 CFR 61 and 63 regulate the emissions of HAPs from new andexisting sources. Part 61, promulgated before the 1990 CAA Amendments, regulates eight
hazardous substances: asbestos, benzene, beryllium, coke oven emissions, inorganic arsenic,
mercury, radionuclides, and vinyl chloride. The 1990 CAA Amendments established a list of 189

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HAPs, resulting in the promulgation of 40 CFR 63, which are also known as the Maximum
Achievable Control Technology standards. Part 63 regulates HAPs from major sources of HAPs
and specific source categories emitting HAPs. Some NESHAPs may apply to non-major sources(area sources) of HAPs. Major source thresholds for NESHAPs are 10 tons per year (tpy) of any
single HAP or 25 tpy of total HAPs.
Applicable NESHAPs for the Project, based on the types of emission units and the expected
date of installation, include the following:•

40 CFR 63 Subpart A – General Provisions. Subpart A contains the general
requirements applicable to all emission units subject to 40 CFR 63.

•

40 CFR 63 Subpart YYYY. The turbines must comply with the initial notification
requirements of 40 CFR 63.6145.

•

40 CFR 63 Subpart ZZZZ – NESHAPs for Stationary Reciprocating Internal
Combustion Engines (RICE). Subpart ZZZZ applies to any existing, new, orreconstructed stationary RICE located at a major or area source of HAP emissions.
Separate sections of the rule apply to engines rated greater than 500 horsepower andless than 500 horsepower. Engines greater than 500 horsepower used on-site will needto meet the initial notification requirement of 40 CFR 63.6645(f). For engines less than
500 horsepower used on-site, the Project would comply with NSPS Subpart IIII forthese emission units. No other requirements of 40 CFR 63 Subpart ZZZZ apply.

•

40 CFR 63 Subpart DDDDD – National Emission Standards for Hazardous Air
Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers
and Process Heaters. The Project must conduct a fuel specification analysis for
mercury.

The proposed hot oil heaters would be new process heaters, as defined in 40 CFR 63.7575,
and would be subject to requirements for new units from unit startup. These requirements include
an initial notification of startup. The heaters are required to have a tune-up every 5 years and anannual compliance report must be submitted.
In addition to the above, Venture Global would follow the record-keeping requirements
outlined in 40 CFR 63.7555 and 63.7560.
Title V Operating Permit
The required elements of title V operating permit programs are outlined in 40 CFR 70 and
40 CFR 71. Title V operating permits may be referred to as “part 70” or “part 71” permits, or as
title V permits. A title V permit should list all air pollution requirements that apply to the source,
including emissions limits and monitoring, record keeping, and reporting requirements.
Regulations also require that the permittee annually report the compliance status of its source withrespect to permit conditions to the corresponding regulatory agency. In this case, the EPA has
delegated to the LDEQ the authority to issue title V permits.

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The definition of a “major source” under title V varies according to which pollutants are
emitted from the source and the attainment designation of the area where the source is located. In
general, a source is considered major for title V if it emits or has the potential to emit 100 tpy or
more of any regulated pollutant, 10 tpy or more of any single HAP, 25 tpy or more total HAPs, or
100,000 tpy of CO2e and 100 tpy GHGs on a mass basis.
Total emissions from the LNG terminal would exceed title V thresholds for PM10, PM2.5,
NOX, SO2, VOC, CO and CO2e. The permit application submitted to the LDEQ serves as both an
NSR PSD application and a title V application.
General Conformity
The General Conformity Rule is designed to require federal agencies to ensure thatfederally funded or federally approved projects conform to the applicable State Implementation
Plan (SIP). Section 176(c) of the CAA requires that federal actions in nonattainment areas or air
quality areas subject to a maintenance plan conform to the SIP for the attainment and maintenanceof the NAAQS. General Conformity regulations do not apply to the Project because the Project islocated in an attainment area.
Greenhouse Gas Reporting RuleIn September 2009, the EPA issued the final Mandatory Reporting of Greenhouse Gases
Rule, requiring reporting of GHG emissions from: suppliers of fossil fuels; and facilities where
the aggregated maximum heat input from all combustion sources is greater than 30 MMBtu/hour
and that emit greater than or equal to 25,000 metric tpy of GHGs (reported as CO2e).
Venture Global would be required to report emissions in accordance with the reporting rule
as emissions are expected to be greater than 25,000 metric tons per year.
Applicable Louisiana Air Quality Requirements
The LDEQ is the lead air permitting authority for the Project. The LDEQ’s air quality
regulations are codified in LAC 33:III.1-59. The regulations incorporate the federal program
requirements listed in 40 CFR 50-99 and establish permit review procedures for all facilities thatcan emit pollutants to the ambient air. New facilities are required to obtain an air quality permit
prior to initiating construction. LAC 33:III.1-59, set forth the air quality regulations for emission
sources in Louisiana. In addition, LAC 33:III.1 delegates authority to the LDEQ to maintain air
quality resources in Louisiana and enforce LDEQ air quality regulations. The following
regulations may be applicable to the Project:•

Chapter 2 – Rules and Regulations for the Fee System of the Air Quality Control
Program;•

Chapter 5 – Permit Procedures;•

Chapter 9 – General Regulations on Control of Emissions and Emission Standards;•

Chapter 11 – Control of Air Pollution from Smoke;
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•

Chapter 13 – Emission Standards for Particulate Matter;•

Chapter 15 – Emission Standards for Sulfur Dioxide;•

Chapter 21 – Control of Emission of Organic Compounds;•

Chapter 51 – Comprehensive Toxic Air Pollutant Emission Control Program;•

Chapter 56 – Prevention of Air Pollution Emergency Episodes; and•Chapter 59 – Chemical Accident Prevention and Minimization of Consequences.

4.11.1.4 Construction Air Emissions, Impacts and Mitigation
Venture Global anticipates it would commence a two-phased construction approach for the
proposed liquefaction facility in 2019. Phase I is anticipated to last approximately 35 months, withservice of the first liquefaction train initiated in 2022. Construction of Phase II would commence
approximately 12 months after the construction of Phase I begins and would also takeapproximately 35 months to complete. The Southwest Lateral TGP pipeline would be installed
during the Phase I construction process, beginning in 2020, while the Southwest Lateral TETCO
pipeline would be constructed concurrently with Phase II facilities. The Project is anticipated to
be fully complete and operational by 2023.
Liquefaction Terminal Construction
Construction of the terminal site and pipelines would result in short-term increases inemissions of air pollutants due to the use of equipment powered by diesel fuel or gasoline engines
and the generation of fugitive dust due to the disturbance of soil and other dust-generating
activities. The following construction activities would generate emissions:•terminal site and pipeline route preparation (clearing, grading, trenching foundation
preparation, etc.);•

construction of a material unloading facility, a bulk carrier mooring facility, and a barge
mooring facility;•

installation of terminal site equipment;•

installation of the pipeline and associated interconnections, meter stations, etc.;•

operation of off-road equipment, vehicles, and trucks during construction;•

operation of a portable concrete batch plant;•

operation of on-road material delivery trucks;•

operation of marine vessels such as tug boat/barges to deliver bulk material; and

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•

construction workers’ commuting vehicles.

The construction phase of the Project also includes construction of three marine facilities
to receive materials to be used to construct the LNG terminal and pipeline system. Construction
emissions are not subject to air quality permitting but may be subject to certain Louisiana
regulations regarding prevention of general nuisance odors and dust. Construction equipment fuelmust be compliant with federal regulations for diesel and gasoline fuel.
Estimated construction emissions are shown in table 4.11-2. Although construction-related
emissions would cease after construction is completed, the quantity of pollutants emitted each year
for over 4 years would be substantial. The majority of the construction emissions would be
produced by off-road heavy equipment such as bulldozers, backhoes, trucks, etc., but someemissions would also be produced by on-road vehicles such as delivery trucks and construction
worker commuting vehicles. The quantity of emissions from construction equipment wasdetermined based on the duration of use, type of construction activity, and number and type of
vehicles and engine-powered equipment in use at any point in time. Earth-moving equipment andother mobile sources may be powered by diesel or gasoline engines, which are sources ofcombustion-related emissions that include CO, NOX, PM10, PM2.5, SO2, VOCs, GHGs, and HAPs.
Table 4.11-2
Construction Emissions (tons per year)
Construction Activity

NOX

CO

VOC

PM10

PM2.5

SO2

HAPs

CO2e

Year 1
TerminalaOff-road equipment

679.2

198.5

52.0

31.6

30.6

0.6

6.8

99,161On-road vehicles

107.3

937.6

19.5

2.4

2.2

0.8

5.3

120,576

Marine vessels

7.5

4.5

0.4

0.4

0.4

0.0

Na

571

Construction activity fugitive dustb

N/A

N/A

N/A

17.5

2.6

N/A

N/A

N/A

Concrete batch plants

0.6

5.2

0.3

0.8

0.8

0.3

0.03

1,022

Total year 1794.6

1,145.8

72.2

52.7

36.6

1.7

12.1

221,330

Year 2
Terminal
Off-road equipment

826.5

228.4

61.3

36.0

34.9

0.7

8.1

119,001

On-road vehicles

128.2

1,120.1

23.4

2.9

2.6

1.0

6.4

144,046

Marine vessels

8.0

4.9

0.4

0.4

0.4

0.0

Na

611

Construction activity fugitive dust

N/A

N/A

N/A

20.9

3.1

N/A

N/A

N/A

Concrete batch plants

1.4

12.4

0.7

1.6

1.5

0.8

0.1

2,452

Terminal subtotal

964.1

1,365.8

85.8

61.8

42.5

2.5

14.6

266,110

Pipeline (Southwest Lateral TGP Pipeline)c
Off-road equipment

17.2

45.7

3.1

1.2

1.2

0.0

0.4

3,493

On-road vehicles

11.4

90.5

1.9

0.3

0.2

0.1

0.5

11,909Marine vessels

13.6

6.9

0.7

1.0

1.0

0.0

Na

968

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Table 4.11-2
Construction Emissions (tons per year)
Construction Activity

NOX

CO

VOC

PM10

PM2.5

SO2

HAPs

CO2e

Construction activity fugitive dust

N/A

N/A

N/A

16.8

2.2

N/A

N/A

N/A

Roadway fugitive dust

N/A

N/A

N/A

0.2

0.0

N/A

N/A

N/A

Pipeline subtotal

42.2

143.1

5.7

19.5

4.6

0.1

0.9

16,370Total year 2

1,006.3

1,508.9

91.5

81.3

47.1

2.6

15.5

282,480

Year 3
Terminal
Off-road equipment

1,538.4

430.1

114.5

67.6

65.6

1.3

15.1

222,662

On-road vehicles

128.1

1,123.4

23.4

2.9

2.6

1.0

6.4

144,344

Marine vessels

11.1

6.3

0.6

0.7

0.6

0.0

Na

823

Construction activity fugitive dust

N/A

N/A

N/A

20.9

3.2

N/A

N/A

N/A

Concrete batch plants

0.8

7.3

0.4

0.8

0.7

0.5

0.0

1,430

1,678.4

1,567.1

138.9

92.9

72.7

2.8

21.5

369,259

Total year 3

Year 4
Terminal
Off-road equipment

865.4

239.8

64.2

37.7

36.5

0.8

8.4

126,268

On-road vehicles

128.6

1,123.7

23.4

2.9

2.6

1.0

6.4

144,507

Marine vessels

1.8

1.2

0.1

0.1

0.1

0.0

Na

142

Construction activity fugitive dust

N/A

N/A

N/A

21.0

3.2

N/A

N/A

N/A

Terminal subtotal

995.8

1,364.7

87.7

61.7

42.4

1.8

14.8

270,917

Pipeline (Southwest Lateral TETCO Pipeline)c
Off-road equipment

6.7

21.7

1.4

0.5

0.5

0.0

0.2

1,529

On-road vehicles

6.8

59.8

1.2

0.2

0.1

0.1

0.3

7,692

Marine vessels

7.9

4.0

0.4

0.6

0.6

0.0

Na

563

Construction activity fugitive dust

N/A

N/A

N/A

6.0

0.6

N/A

N/A

N/A

Pipeline subtotal

21.4

85.5

3.0

7.3

1.8

0.1

0.5

9,784

Total year 4

1,017.2

1,450.2

90.7

69.0

44.2

1.9

15.3

280,701

Year 5
Terminal
Off-road equipment

855.5

230.6

62.2

35.9

34.8

0.7

8.2

122,997

On-road vehicles

124.3

1,118.2

23.1

2.7

2.4

1.0

6.3

142,817

Marine vessels

4.1

2.1

0.2

0.3

0.3

0.0

Na

292

Construction activity fugitive dust

N/A

N/A

N/A

20.9

3.1

N/A

N/A

N/A

Total year 5983.9

1,350.9

85.5

59.8

40.6

1.7

14.5

266,106

5.2

3.0

2.9

0.1

0.7

12,078Year 6
Terminal
Off-road equipment

69.2

21.4

4-173

Table 4.11-2
Construction Emissions (tons per year)
Construction Activity

NOX

CO

VOC

PM10

PM2.5

SO2

HAPs

CO2e

On-road vehicles

10.3

92.9

1.9

0.2

0.2

0.1

0.5

11,860Construction activity fugitive dust

N/A

N/A

N/A

1.7

0.3

N/A

N/A

N/A

Total year 6

79.5

114.3

7.1

4.9

3.4

0.2

1.2

23,938a Includes construction of the three marine terminals.
b Includes handling of soil stabilization materials.
c Includes construction emissions from meter and regulator station construction.
Key:
CO = carbon monoxide
CO2e = carbon dioxide equivalent
HAPs = hazardous air pollutants
N/A = not applicablena = not available
NOX = nitrogen oxides
PM10 = particulate matter equal to or less than 10 micrometers in aerodynamic diameter
PM2.5 = particulate matter equal to or less than 2.5 micrometers in aerodynamic diameter
SO2 = sulfur dioxide
VOC = volatile organic compounds

Fugitive dust emissions are produced by off-road equipment travel on exposed soils,
working of soils (grading, trenching, earth moving, etc.) by off-road equipment, transport andhandling of bulk materials from dumping, unloading via conveyors, and temporary storage piles.
Fugitive dust may also be produced by native soil improvement and stabilization activities. This
activity would be required on approximately 520 acres near SH 23—across the easternworkspace—and on the three access roads leading to the temporary marine delivery facilities. Soil
improvement and stabilization would be undertaken in situ across all these areas by mixing one ormore commonly used stabilizers (e.g., crushed stone, sand, portland cement, and hydrated lime)
into the native soil.
Marine vessels consisting of bulk carriers and barges pushed by tug boats would deliver
bulk material (fill, soil stabilization materials, etc.), equipment, and other supplies needed forconstruction.
Pipeline Construction Emissions
As shown in table 4.11-2, pipeline construction emissions for Phase I are expected to occur
in year 2 of Project construction, and pipeline construction emissions for Phase II in year 4 ofconstruction. Pipeline site preparation and construction activities would generate fugitive dust
from clearing, trenching, backfilling, grading, and traffic on paved and unpaved areas, as well as
fuel combustion emissions from the construction equipment. The internal combustion engines
powering most of the pipeline construction equipment and vehicles would burn ultra-low-sulfur
diesel fuel, and the remaining vehicles would burn gasoline. Equipment used for the pipeline
construction activities would include various earthmoving equipment (bulldozers, backhoes,
trenchers, graders, and compactors), cranes, forklifts, compressors, pumps, trenchers, stringing
trucks, welding rigs, generators, and miscellaneous trucks.

4-174

Emissions from pipeline construction equipment are produced in the area of active pipeline
construction. These emission sources move as construction proceeds along the pipeline right-ofway and therefore are present only for a short time near any location along the pipeline route.
Mitigation - Construction Emissions
Construction equipment would be operated on an as-needed basis, depending on theconstruction task. Emissions would be minimized by maintaining the equipment in accordancewith the manufacturer’s recommendations, minimizing idling time of engines whenever feasible,
and using fuels compliant with current regulations.
Fugitive dust emissions during construction would be controlled in accordance with
LAC 33:III.13 and with a fugitive dust control plan prepared by Venture Global. The fugitive dust
control plan addresses dust emissions and control procedures for the following categories ofactivities:•

general guidelines for all areas and activities for controlling dust during high winds,
applying control measures around the clock as needed, locating temporary facilities toavoid dust impacts on public roads, monitoring dust control activities to determine
adequacy, and revising the plan as needed;•staging areas;•

stockpiles;•

earthmoving operations;•on-site bulk material handling;•

off-site bulk material handing;•

trackout prevention and cleaning;•

enclosed work areas;•

paved haul roads and public roads;•

unpaved parking lots; and•crushers and grinder mills.

In general, the control measures specified for each of these activities consist of limiting
vehicle speed, applying and maintaining dust suppressant (water, etc.), designing storage piles tominimize wind-blown dust generation, limiting the height of stockpiles and the drop distance ofmaterial, preventing spillage and cleaning up spilled material as soon as possible, covering loaded
haul trucks and limiting freeboard, and preventing track out.

4-175

Conclusion
Project construction would produce substantial emissions over a multi-year period.
Venture Global would fuel, operate, and maintain construction equipment and other vehicles usedduring construction in compliance with current federal fuel requirements and with manufacturers’
recommendations. Venture Global would also implement a fugitive dust control plan to reduce
production of fugitive dust. Nevertheless, construction would produce quantities of criteria
pollutant emissions over a multi-year period that would result in elevated levels of pollutants near
the Project area and potential intermittent exceedances of certain NAAQS. However, due to thelength of time, and dynamic intermittent nature of construction, we do not expect that these
construction emission impacts to result in significant local or regional impacts on air quality.
4.11.1.5 Operational Air Emissions, Impacts and Mitigation
The proposed facilities are described in detail in section 2.0. Relevant portions of the
Project description pertaining to potential operational air emission sources at the LNG terminal
include the following:•gas gate station where the gas stream would be split into two streams, one for process
feed to the liquefaction plant and the other for fuel gas supply 3 to the electric power
generation facilities;•

feed gas pretreatment to remove CO2, H2S, and water using an acid gas removal unit,
H2S removal unit and a dehydration unit. Emissions would occur from four thermaloxidizers that would be used to treat the CO2-rich acid gas stream;•

six hot oil heaters serving various heat needs throughout the LNG terminal;•

flares consisting of three separate flare structures: a warm/cold flare structure
containing two separate flare headers, a low pressure vent flare structure for low
velocity marine loading flaring, and a marine vapor control structure for LNG carrier
gas up/cool down operations;•combined cycle gas turbine (CCGT) driven power plant to be constructed in two equal
phases, ultimately reaching a generating capacity of 1,420 megawatts (MW) in
combined cycle mode. This facility would provide plant power and power to theelectric drive refrigerant compressors. Each phase would consist of five CCGTs withinitial operation in each phase consisting of two of the gas turbines operating in simple
cycle mode. When in combined cycle mode, duct burners combusting natural gas
would produce emissions in addition to the gas turbines. In addition, two simple cycle
aeroderivative combustion turbines would be used during facility start up events and toprovide supplemental power as needed;•

14 standby diesel engine electric power generator sets;

3 Natural gas feed for power generation would be supplemented with boil-off gas and other fuel gas streams
generated in the liquefaction plant.

4-176

•

two diesel-engine-driven firewater pumps; and•equipment and piping fugitive emissions and storage tank emissions.

The LNG terminal would utilize electric-motor-driven compressors to boost incoming gas
pressure and electric motor refrigeration compressors. No air pollutant emissions are directly
associated with this equipment.
The pipeline system would not require installation of compressors for natural gas transport.
Minor quantities of emissions would occur from pig launchers and receivers, meter stations, block
valves, and fugitive emissions from pipeline components.
The Project would be operated in two modes: interim and final. The interim mode would
consist of partial operation of the full capacity of the power generation facility and liquefaction
plant; as construction of the power plant and liquefaction blocks is completed, they would be
brought into operation. During the interim mode, operation and construction emissions would
occur simultaneously. The final operating mode would consist of full facility operation (Phases I
and II) after Phase II construction is completed.
During the interim operating mode, in each phase, up to two of the heavy-duty frame
combustion turbines would be operated in simple-cycle mode for up to 2 years. In addition, one
simple-cycle aeroderivative combustion turbine would be installed and operated. In the first 2
years during construction, a concrete batch plant would be operated. The batch plant would
produce emissions from diesel engine-powered electrical generators and fugitive particulate from
cement bin vents and other material-handling operations.
Operation of the Project in final operating mode would result in long-term air emissions
from the following stationary and mobile sources.
Terminal Site (Phases I and II combined)
Power Plant Facility:
Two power islands with a total generating capacity of 1,420 MW. Each island would
consist of:•five (80 MW each) combined-cycle heavy-duty frame combustion turbines with low
NOX combustion design;•

two aeroderivative combustion simple-cycle turbine (30 MW each) for black start
events and to provide supplemental power when needed, equipped with NOX reduction
measures consisting of dry low-NOX combustors and selective catalytic reduction(SCR);•

ten natural-gas-duct fired heat recovery steam generators (HRSGs) with low NOX
burner design;•

SCR utilized on the combined combustion turbine and duct burner system; and
4-177

•

fugitive emissions from pipe flanges, valves, and other components.

Liquefaction Facility:•

18 liquefaction blocks;•

four 200,000 m3 LNG storage tanks;•

six gas pretreatment systems, each containing equipment for hydrogen sulfide removal,
acid gas removal with an amine unit to remove CO2, and a dehydration unit;•

four acid gas thermal oxidizers;•

fourteen diesel-fired engines driving emergency electrical generators;•

six natural-gas-fired hot oil heaters;•

four total flares consisting of a cold flare, a warm flare, a low-pressure flare, and amarine loading flare;•

two diesel-engine-driven firewater pumps;•

two diesel fuel storage tanks (66,577 gallons each) for the power island emergency
generators. Other generators would utilize day tanks for diesel storage;•

refrigerant storage tanks, solvent surge tanks, and amine flash drums; and•fugitive emissions from piping components;

Pipeline•

pig launcher/receivers;•

small diesel-engine-driven emergency generator;•

meter stations;•block valves; and•fugitive emissions from piping components such as flanges and smaller valves.

Marine Vessels•

LNG carriers maneuvering in the safety zone and at berth (hoteling emissions);•

escort tug boats; and•security vessels.
4-178

Emissions Common to All Facilities•

vehicle travel emissions from fuel combustion and fugitive dust generation.

Interim Operating Period Emissions
As described more fully above, Venture Global proposes to develop the facility in twophases over a 6-year period, which includes construction and interim operating scenarios. In year
1, only construction is expected to occur. During years 2 through 6 of construction, heavy-duty
frame turbines in simple-cycle mode and liquefaction blocks would be commissioned and brought
online as they are completed. Thus, there would be concurrent construction and operationalemissions during this period. The interim period construction and operational emissions are shownin table 4.11-3.
Table 4.11-3
Combined Construction and Operation Emissions Years 1 through 6
Facility
Scenario

NOX

CO

VOC

SO2

PM10

PM2.5

Total
HAPs

CO2e

1

Const Phase I

794.6

1,145.8

72.2

1.7

52.7

36.5

12.2

221,330

2

Const Phase I

1,006.1

1,508.9

91.4

2.6

81.4

47.1

15.4

282,480

Operating
Scenario 1

527.3

961.2

48.6

49.2

94.0

93.7

7.8

2,444,841

1,533.4

2,470.1

140.0

51.8

175.4

140.8

23.2

2,948,651

Const Phase I

1,678.4

1,567.1

138.9

2.8

92.9

72.7

21.5

369,260

Operating
Scenario 1

527.3

961.2

48.6

49.2

94.0

93.7

7.8

2,444,841

2,205.7

2,528.3

187.5

52.0

186.9

166.4

29.3

2,814,101

Const Phase II

1,017.2

1,450.2

90.8

1.8

68.8

44.2

15.3

280,701

Operating
Scenario 2

462.1

739.9

71.5

57.5

187.1

187.1

15.3

4,093,901

1,479.3

2190.1

162.3

59.3

255.9

231.3

30.6

4,374,602

Const Phase II

984.0

1,350.9

85.5

1.7

59.8

40.6

14.5

266,105

Operating
Scenario 3

966.0

1,590.0

110.3

105.6

276.1

276.1

22.2

6,492,951

1,950.0

2,940.9

195.8

107.3

335.9

316.7

36.7

6,759,056

Const Phase II

79.6

114.3

7.1

0.2

5.0

3.4

1.2

23,938Operating
Scenario 3

966.0

1,590.0

110.3

105.6

276.1

276.1

22.2

6,492,951

1,045.6

1,704.3

117.4

105.8

281.1

279.5

23.4

6,516,889

902.3

1,381.0

133.9

114.7

371.8

371.8

29.9

8,144,463

Year

Total
3

Total
4

Total
5

Total
6

Total
7

Operating
Scenario 4

Scenario 1: Phase I turbine interim operating mode plus concrete batch plant operations
Scenario 2: Phase I turbine final operating mode
Scenario 3: Phase I turbine final operating mode plus Phase II turbine interim operating model
Scenario 4: Phases I and II turbine final operating mode (full facility operational).
Key:
CO = carbon monoxide

4-179

Table 4.11-3
Combined Construction and Operation Emissions Years 1 through 6
Year

Facility
Scenario

NOX

CO

VOC

SO2

PM10

PM2.5

Total
HAPs

CO2e

CO2e = carbon dioxide equivalent
HAPs = hazardous air pollutants
NOX = nitrogen oxides
PM10 = particulate matter equal to or less than 10 micrometers in aerodynamic diameter
PM2.5 = particulate matter equal to or less than 2.5 micrometers in aerodynamic diameter
SO2 = sulfur dioxide
VOC = volatile organic compounds

Final Operational Emissions
Final (full facility) operational emissions are presented in table 4.11-4. Stationary
combustion sources primarily include emergency use engines, gas turbines, hot oil heaters, thermaloxidizers, and flares. Mobile source emissions would be produced by LNG carriers and tug/escort
vessels, worker commuting, and routine deliveries to the terminal by truck. Non-combustion
sources include storage tanks, LNG loading and transfer operations, and fugitive emissions frompipeline and equipment leaks. Non-combustion emissions would occur from the LNG terminal
facilities, pipeline, and meter stations, as well as from up to six pipeline pigging events per year.
Table 4.11-4
Final Operational Emissionsa
Tons Per Year
NOx

CO

VOC

PM10

PM2.5

SO2

HAPs

Louisiana
TAPs

CO2e

Terminal

902

1,381

134

372

372

115

30

354

8,144,463

Pipelineb

0.02

0.04

0.01

0.00

0.00

0.00

0.00

3.1

0.1

6,525

SourceFugitivec

2.3

Marine Vessels

140

72

22

7.4

6.7

12.6

Mobile Sourcesd

31,942

15.3

147.6

3.0

0.3

0.3

0.1

0.8

Total

1,057

1,601

161.3

379.7

379.0

127.7

30.9

18,541354

a Emissions shown for the terminal represent Scenario 4, final operating mode of Phases I and II.
b Emissions shown for the pipeline include emissions for the TGP and Tetco laterals and associated meter and regulator stations.
c Fugitive emissions include the terminal, TGP lateral, Tetco later, and associated meter and regulator stations combined.
d Mobile source emissions represent tail pipe exhaust emissions.
Key:
CO = carbon monoxide
CO2e = carbon dioxide equivalent
HAPs = hazardous air pollutants
NOX = nitrogen oxides
PM10 = particulate matter equal to or less than 10 micrometers in aerodynamic diameter
PM2.5 = particulate matter equal to or less than 2.5 micrometers in aerodynamic diameter
SO2 = sulfur dioxide
TAPs = toxic air pollutants per Louisiana Code 33:III Chapter 51
VOC = volatile organic compounds

4-180

8,201,474

Mitigation Measures
Venture Global has prepared an air permit application and submitted the application to the
LDEQ for review. The application review process will evaluate all proposed emission rates andcontrol technologies for compliance with applicable regulations. Venture Global is also required
to prepare an air quality impact analysis to demonstrate that proposed emission rates on a shortterm and annual basis would not result in ambient pollutant concentrations that exceed ambient air
quality standards. An air permit to construct and operate the facility will not be issued unless theapplicant demonstrates the Project’s ability to meet all emission rates, control technology
requirements, and ambient air quality standards.
Venture Global has prepared a Best Available Control Technology (BACT) analysis forthe stationary emission sources at the terminal. A BACT analysis is used to identify the maximum
degree of emission reduction for air pollutants, taking into account technical feasibility, energy,
other environmental, and economic impacts. A summary of the Project’s proposed BACT as
submitted in the air permit application to LDEQ is provided in appendix F.
In general, most of the Project’s combustion sources other than emergency equipment
would utilize natural gas fuel. Use of natural gas as fuel results in lower emissions of particulatematter and SO2 from combustion sources. Additional BACT measures to be used on all
combustion devices include good combustion practices, proper operation and maintenance, andproper equipment design. Diesel-fueled emergency equipment would use ultra-low sulfur diesel
with a fuel sulfur content equal to or less than 15 ppm in compliance with regulatory requirements.
In the power generation portion of the terminal during the interim operating mode, thesimple-cycle, heavy-duty frame combustion turbines would use dry low NOX combustor design;in the final operating mode, the combined-cycle, heavy-duty frame combustion turbines and ductburners would use low NOX burner designs, and the combined exhaust would be treated by SCR
to reduce NOX emissions. The two aeroderivative turbines would utilize dry low NOX and SCR
to reduce emissions of oxides of nitrogen. However, normal use of SCR results in some of theammonia used in the SCR process to pass unreacted through the SCR and emitted to theatmosphere. According to the BACT analysis, catalytic oxidation would be used on the combinedcycle gas turbines/duct burner exhaust to reduce emissions of carbon monoxide and volatileorganic compounds.
Thermal oxidizers would be used to treat the sour gas from the acid gas removal units toconvert hydrogen sulfide to SO2. These units would use low NOX burners to lower emissions of
NOX.
In order to identify leaking equipment such as valves, flanges, and seals, Venture Global
would use a site-specific program utilizing a combination of design and auditory/visual/olfactoryleak detection methods. Auditory/visual/olfactory leak detection would involve control systemmonitoring and routine visual inspections and observations (such as fluids dripping, spraying,
misting, or clouding from or around components), sound (such as hissing), and smell. Leaks
detected in this manner would be immediately recorded and scheduled for repair in accordancewith all applicable laws.

4-181

4.11.1.6 Air Quality Impact Analysis
Breton NWR Class I Area Air Quality Modeling
Venture Global followed the Federal Land Managers’ Air Quality Related Values WorkGroup’s Phase I Report – Revised (NPS, 2010) to determine the Project’s air quality impacts on
Class I areas to support the air permit application for the Project.
If a new source or major modification of an existing source is subject to PSD review andis (1) within 62 miles (100 kilometers) of a Class I area; or (2) farther than 31 miles (50 kilometers)from a Class I area, and the emission to distance (Q/D) ratio is greater than 10, the facility isrequired to notify the appropriate federal officials and assess the impacts of the proposed Projecton the Class I area. The emission value used in the Q/D ratio prescribed by the NPS 2010 guidanceis the sum of emissions of SO2, PM10, NOX, and sulfuric acid mist in tons, and where D is distancein kilometers between the source and the Class I area. Venture Global’s emission estimates
included SO2, PM10, and NOX for the Q/D analysis.
The Breton National Wildlife Refuge (NWR) Class I area is approximately 95 kilometersfrom the Project; the Q/D value is 19.6; therefore, a Class I air quality impact analysis is required.
The next closest Class I area is the Sipsey Wilderness Area in Alabama, which is 567 kilometers
to the northeast of the Project site. The Q/D value for the Sipsey Wilderness area is 3.3, which isless than the threshold value of 10; therefore, a refined Class I area air quality analysis is not
required for the Sipsey Wilderness area.
The Federal Land Manager (FLM) for the Breton NWR is the FWS. Class I air quality
modeling was performed to evaluate compliance with the Class I area Significant Impact Levels(SILs) and Class I area Air Quality Related Values (AQRVs) for Breton NWR. The AQRVs
evaluated for Breton NWR are nitrogen and sulfur deposition and visibility degradation. The FLM
reviewed the procedures and protocol used to conduct the modeling, reviewed the modeling
results, and concluded that, based on the report reviewed, the Project would not have significant
additional impact on air quality-related values at the Breton NWR and did not request additional
analyses.
Models Used
The AERMOD model and the CALPUFF model were used for the analysis. AERMOD
was used to evaluate impacts compared to the Class I area PSD SIL; CALPUFF was used toevaluate AQRVs (deposition and visibility).
AERMOD is EPA’s preferred regulatory air quality dispersion model for source to receptor
distance of up to 50 kilometers. Five years (2011 through 2015) of hourly meteorological datafrom New Orleans and upper air data from Slidell, Louisiana, were used. Receptor locations(points where the model calculated concentration values) were located along an arc 50 kilometersfrom the Project in the direction of the Breton NWR. This analysis was used to determine whether
further air quality standard (NAAQS) analyses and PSD air quality concentration increment
analysis with a long-range transport model at receptors at the Class I area boundary were necessary.

4-182

CALPUFF Version 5.8.5, the current model version approved by the EPA, is a long-range(beyond 50 kilometers) air pollutant transport, deposition, and chemical transformation model.
CALPUFF uses a sophisticated meteorological data set that consists of a gridded network of
meteorological data points spaced 4 kilometers apart over a regional area of the southeast UnitedStates. The meteorological data set was obtained from previous modeling studies conducted in
the region and covered a 3-year period from 2001 to 2003. Receptor locations for the Breton NWR
were obtained from the National Park Service Air Resource Division.
Emission Rates
Venture Global performed the Class I area modeling using the stationary source emission
rates and source parameters used in the Class II area modeling study. The following separate
emission scenarios, reflecting the phased development of the Project and their corresponding
emission rates, were modeled:•interim operating emission scenario 1, consisting of the Phase I turbine interim
operating mode and Phase I concrete batch plant operations;•interim operating emission scenario 3, consisting of full operation of Phase I and Phase
II turbine interim operating mode; and•final operating scenario 4, consisting of full operation of the Project.

For the Class I area SIL analysis using AERMOD, maximum hourly emission rates were
input to the model for the 1-hour, 3-hour, and 24-hour averaging periods. Annual average emission
rates were used for the annual SIL analysis.
Mobile source emissions were not included in any of the scenario analyses. Also,
concurrent construction emissions occurring during interim emission scenario 1 and interim
emission scenario 3 were not included in the modeling. These mobile source emissions andconstruction emissions are not required to be included in Class I modeling for air permitting
purposes. However, they can be considered for NEPA evaluation purposes.
Significant Impact Level (SIL) Modeling Results
Table 4.11-5 summarizes the Class I SIL modeling results. All modeled concentrations at
a 50-kilometer distance from the Project in the direction of Breton NWR were found to be lessthan the SIL value. Based on these results, no further analysis for Class I area increments isrequired.
However, scenario 1 and scenario 3 results do not include emissions associated withconstruction, and none of the scenarios include emissions from mobile sources associated with the
Project. These emissions (primarily construction emissions) add significantly to the emission ratefrom the Project during the 5 years of concurrent construction and operation. Addition of theseemissions to the model input would increase the maximum modeled results to values that may
approach the SIL.

4-183

Table 4.11-5
Class I Area SIL Model Results

Pollutant

Averaging Period

Maximum Result
over Five Years(µg/m3)

SIL (µg/m3)

Annual0.01

0.124-hour

0.08

0.3

Annual<0.0050.224-hour

0.08

0.27

Annual<0.005

0.05

3-hour0.42

1.024-hour

0.08

0.2

Annual<0.0050.1

Annual0.02

0.1

24-hour

0.16

0.3

Annual0.01

0.224-hour

0.16

0.27

Annual0.01

0.05

3-hour0.83

1.0

24-hour

0.16

0.2

Annual<0.0050.1

Annual0.02

0.1

24-hour

0.23

0.3

Annual0.01

0.224-hour

0.23

0.27

Annual0.01

0.05

3-hour0.85

1.0

24-hour

0.16

0.2

Annual<0.0050.1

Scenario 1
NO2
PM10
PM2.5

SO2
Scenario 3
NO2
PM10
PM2.5

SO2
Scenario 4
NO2
PM10
PM2.5

SO2

Key:
µg/m3 = micrograms per cubic meter
NO2 = nitrogen dioxide
PM10 = particulate matter equal to or less than 10 micrometers in aerodynamic diameter
PM2.5 = particulate matter equal to or less than 2.5 micrometers in aerodynamic diameter
SIL = Significant Impact Level
SO2 = sulfur dioxide

4-184Deposition Model Results
Deposition analyses for sulfur and nitrogen in the Breton NWR were performed using the
CALPUFF model. Deposition results were compared to deposition analysis thresholds (DATs)
established by the FLM’s guidance report for Nitrogen and Sulfur Deposition Analyses. The DAT
values for eastern U.S. Class I areas are 0.01 kilograms per hectare per year for sulfates andnitrates.
The sulfate deposition analysis included wet and dry fluxes of SO2 and sulfate to surface
receptors to determine total sulfur loading at receptor locations in the Breton NWR. The nitratedeposition analysis included wet and dry fluxes of nitrates and nitric acid and dry flux of oxides
of nitrogen to determine total nitrogen loading at the receptor location in the Breton NWR. Resultsof the modeling are shown in table 4.11-6. All results are below the DAT values for eastern U.S.
Class I areas; therefore, Project emissions as modeled are not expected to affect sulfur and nitrogen
deposition at the Breton NWR. However, scenario 1 and scenario 3 results do not include
emissions associated with construction, and none of the scenarios include emissions from mobile
sources associated with the Project. Although these emissions add significantly to the emission
rate from the Project during construction, addition of these emissions to the model input is not
likely to increase deposition rates that would exceed the DAT values shown in table 4.11-6.
Table 4.11-6
Sulfur and Nitrogen Deposition Modeling Results

Meteorological
Data Year

Deposition
Species

Scenario 1(kg/ha/yr)

Scenario 3(kg/ha/yr)

Scenario 4(kg/ha/yr)

Deposition
Analysis
Threshold(kg/ha/yr)

2001

Nitrates

0.00110.00200.00200.01

Sulfates

0.00120.00240.00250.01

Nitrates

0.00090.00160.00160.01

Sulfates

0.00080.00170.00180.01

Nitrates

0.00110.00200.00190.01

Sulfates

0.00110.00230.0024

0.01

2002
2003

Key:
kg/ha/yr = kilograms per hectare per year

Visibility Analysis Results
Visibility at the Breton NWR could be affected by a plume from the Project or the Project’s
contribution to regional haze. Typically, the direct effect of a plume on a Class I area causes acolor or contrast difference with the background sky or terrain such that the plume is visible anddetracts from viewing the background sky or terrain. This visibility impairment is typically ofconcern when an emission source is within 50 kilometers of a Class I area. Beyond this distance,
the plume has dispersed such that its effect is not discernible as a plume against a backgroundview. However, beyond 50 kilometers, the particulates in the plume may contribute to regionalhaze. The separation distance between the Project and the Breton NWR is greater than
50 kilometers; therefore, the Project analysis only considered impacts on regional haze.
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The amount of visibility reduction is determined by the increase in light extinction. An
increase in light extinction describes the increase in the amount of ambient light that is scatteredby an increase in particles and gases in the atmosphere. As more light is scattered, visibility of a
distant object is reduced. The FLM generally accepts a 5 percent increase in light extinction on a
24-hour average period basis as a visibility reduction threshold. If the increase in light extinctionis less than 5 percent, no further analysis is needed. The EPA recommends using the 98th percentile
value of the modeled 24-hour visibility values to account for the CALPUFF model’s tendency toconservatively estimate actual visibility effects.
The visibility analysis used a background light extinction value calculated according toprocedures contained in the 2010 FLAG report (NPS, 2010). This value is used in conjunction
with the predicted visibility impacts from Project emission to determine whether the Project would
contribute to a greater than 5 percent increase in light extinction and hence a reduction in visibility.
The visibility analysis results are shown in table 4.11-7.
Similar to the other Class I area analyses, scenario 1 and scenario 3 results do not include
the effects of emissions associated with construction, and none of the scenarios include emissions
from mobile sources associated with the Project. These emissions (primarily construction
emissions) add significantly to the emission rate from the Project during the 4.5 years of concurrent
construction and operation. Addition of these emissions to the visibility model input would
increase the percentage change in visibility to values that approach the 5 percent daily thresholdchange value. Additional modeling would be required to determine whether visibility thresholds
would be exceeded.
Table 4.11-7
Visibility Analysis Results

Year

Scenario 1(% change)

Scenario 3(% change)

Scenario 4(% change)

Visibility %Change Daily
Value Threshold

2001

0.65

1.66

2.30

5

2002

0.65

1.47

1.85

5

2003

0.80

1.86

2.38

5

Class II Area Modeling – Stationary and Mobile (Vessel) Sources
Impacts on Ambient Criteria Pollutant Concentrations
Venture Global conducted an air quality dispersion modeling analysis for stationary
sources to estimate ambient criteria pollutant concentrations in the vicinity of the Project forpollutants subject to PSD. The analysis followed EPA PSD modeling procedures. A preliminary
impact analysis, known as a SIL analysis, was performed, followed by a full impact analysis and
PSD increment analysis. The analysis used the EPA’s AERMOD, version 15181, to predict
maximum short-term and annual concentrations within a 50-kilometer radius of the Project. The
50-kilometer radius is the distance approved for modeling compliance demonstrations forregulatory purposes.

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The preliminary impact, full NAAQS, and PSD increment analyses used 5 years of hourly
meteorological data, and land use and terrain height data. Existing ambient background pollutant
concentration data were used in the full NAAQS analysis. Locations (receptors) where pollutant
concentrations were calculated by AERMOD were distributed throughout the analysis area using
either a grid of points or specific locations known as discrete receptors. The number anddistribution of receptors varied depending on the requirements of the analysis being conducted.
Meteorological Data
The stations selected to represent the Project site conditions were New OrleansInternational Airport for surface meteorological conditions and Slidell, Louisiana, for upper air
conditions. These stations are the closest to the Project site. The meteorological data covered theJanuary 1, 2011, to December 31, 2015, time period. The meteorological data were processed foruse in the model according to PSD modeling guideline procedures. The meteorological data wereused in the SIL analysis, the full NAAQS analysis, and the PSD increment analysis.
Land Use and Terrain
The Project site is mainly rural with a relatively small amount of industrial development.
Terrain elevations do not vary much throughout the Project area. Terrain elevation data from the
USGS’s National Elevation Dataset were processed using the AERMAP version 11103 terrain
processor so that the data could be used by AERMOD. These data were used to assign elevations
to each receptor.
Modeling Scenarios
Venture Global developed four emission scenarios to describe the emissions fromsuccessive phases of development and operation of the Project. These scenarios are as follows:•

Scenario 1: simple-cycle turbine interim operations plus Phase I concrete batch plant
operations;•

Scenario 2: final turbine operating model (combined-cycle operation) for Phase I ofdevelopment;•

Scenario 3: scenario 2 plus simple-cycle turbine interim operations in Phase II; and•Scenario 4: full facility operation.

Scenario 3 and 4 are the scenarios with the highest potential to emit air pollutants. Due tothe differences between scenarios in terms of equipment that would be operated and the operating
mode of the gas turbines (simple cycle versus combined cycle), the maximum potential to emit for
NOX and CO occurs under Scenario 3, whereas Scenario 4 results in the highest potential to emit
for PM10, PM2.5, and SO2. These scenarios were modeled in the SIL, full NAAQS, and PSD
increment analyses.

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Secondary Formation of PM2.5
Particulate matter PM2.5 can be directly emitted from an emission source and modeled as
is done for gaseous pollutants. PM2.5 may also form from gaseous pollutants emitted from theemission source. EPA guidance calls for PSD permit applications to address the potential forsecondary formation of PM2.5 in the atmosphere due to emissions of NOX (which forms nitrateparticulate matter) and SO2 (which forms sulfate particulate matter). Venture Global performed
an assessment of the potential formation of secondary PM2.5 from the Project in accordance withthe hybrid qualitative/quantitative assessment Case 3 from EPA guidance.
The maximum modeled direct PM2.5 concentrations typically do not occur where maximum
secondary PM2.5 impacts occur because the emissions of NOX and SO2 from the Project would
require time in the atmosphere to form particulate nitrates and sulfates. Typically, secondary PM2.5
maximum occurs further downwind due to transport of NOX and SO2 and time required for thetransformation to PM2.5. Consequently, the maximum secondary PM2.5 impacts would not occur
close to the Project site where the maximum direct PM2.5 impacts are expected to occur.
The Case 3 secondary PM2.5 analysis procedure consists of several steps:•

establishing the role that nitrates and sulfates have in the total formation of PM2.5 in theregion;•comparing the relationship of regional emissions of NOX and SO2 to locally monitored
values of PM2.5 that have data showing the composition of total PM2.5 (e.g., sulfate,nitrate);•comparing the Project’s NOX and SO2 emissions to regional NOX and SO2 emissions;and•developing an estimate of the expected secondary PM2.5 that could form due to Projectemissions.

Monitoring data were used from the closest site with PM2.5 data showing sulfate and nitratecomposition to establish the role each has in total PM2.5. The monitor is located in Baton Rouge,Louisiana (monitor ID 22-033-0009). This monitor is located in an urban area and reflects a higher
degree of development, hence higher sulfate and nitrate values, than the Project site. The
composition data are used to determine whether one of these materials (sulfate and nitrate) is moreprevalent in total PM2.5. The data for 2013 and 2015 indicated that sulfate is approximately
20 percent of the PM2.5 and nitrate is approximately 6 percent. Thus, sulfate is more prevalent in
total PM2.5 than nitrate. Venture Global also used data from 2013 and 2015 to determine the change
in nitrate and sulfate concentration.
The Project’s analysis also compiled NOX and SO2 regional emissions within 50 kilometersof the Project site for the same 2 years used in the monitoring data analysis. The Project’s NOX
emissions would be 6 percent of the total regional NOX emissions, and the Project’s emissions of
SOX would be 3 percent of the total regional SOX emissions. The change in total NOX and SO2
emissions from 2013 to 2015 was also compared to the Project’s estimated emissions and to the4-188change in annual PM2.5 concentration at the closest PM2.5 monitor to the site. This monitor is in
Marrero, Louisiana; note that this monitor does not collect data on which chemical species makeup the total PM2.5 concentration.
Using this analysis procedure, the applicant estimated a combined contribution to nitrateand sulfate concentrations of less than 0.01 micrograms per cubic meter (µg/m3) for interim
emission scenario 3 and for operating emission scenario 4. This is less than the annual PM2.5 SIL
of 0.3 μg/m3. Consequently, the emissions of NOX and SO2 associated with the Project would not
be expected to cause significant formation of secondary PM2.5 in the region.
SIL Analysis – Stationary Sources
The SIL analysis is a preliminary analysis used to determine whether a project would havesignificant impacts that require further analysis using more detailed procedures. Venture Global
conducted the SIL analysis for pollutants emitted above thresholds that subject them to PSD. In
this analysis, the Project’s potential to emit PSD pollutants is evaluated to determine whether it
may have significant impacts on air quality in the area surrounding the facility. The pollutants
evaluated are CO, NO2, PM10, PM2.5, and SO2.
Modeled concentrations are compared to the respective EPA SILs. If the maximum
modeled concentration at all receptor locations is less than the SIL, then the impact is considered
to be less than significant with respect to the NAAQS and PSD increment for that pollutant andaveraging period combination, and further analysis is not required. If the maximum modeled
concentration is greater than the SIL, or if the SIL plus a relevant background concentration
exceeds the corresponding NAAQS, then an NAAQS full impact analysis and a PSD increment
analysis are required.
Pursuant to EPA guidance specific to modeling PM2.5, an analysis was performed todetermine whether the PM2.5 SIL is applicable for use in comparison with preliminary model
results. The test consists of determining the difference between the NAAQS and PM2.5 monitored
background and comparing it to the SIL. If the result is greater than the SIL, there is sufficientevidence to conclude that model results below the SIL would not cause or contribute to a violationof the NAAQS, and no cumulative analysis is needed. Venture Global used data from the Marrero
monitoring station, located in an urban part of New Orleans, to conservatively represent
background PM2.5 at the more rural Project site. The result of the analysis show that the differenceis significantly greater than the SIL, and therefore provides sufficient evidence that model results
below the SIL would not cause or contribute to an NAAQS violation and do not require acumulative modeling analysis.
The modeled impact also is compared to the significant monitoring concentration (SMC).
Impacts greater than the SMC indicate that Project-specific air quality measurements may beneeded to characterize existing background air quality within the Project’s impact area. A projectthat has an impact greater than the SMC may require preconstruction monitoring via theinstallation of on-site air quality monitors.

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A fence-line grid and set of four additional receptor grids were used to locate receptors
throughout the 50-kilometer modeling radius surrounding the Project site. The receptor grids aredefined as follows:•

fence-line grid consisting of receptors spaced at 100-meter intervals along the property
line;

•

a finely spaced grid consisting of receptors spaced 100 meters apart extending
1 kilometer in all directions from the property line;•

a first coarse grid with 500-meter receptor spacing extending from 1 to 5 kilometers inall directions from the property line;•

a second coarse grid with 1,000-meter receptor spacing extending from 5 to
10 kilometers in all directions from the property line; and•a third coarse grid with 5,000-meter receptor spacing extending from 10 to
50 kilometers in all directions from the property line.

Table 4.11-8 lists the SIL and SMC concentration values, the preliminary modeling results,
and radius of influence distance for pollutant/averaging period results that are above the respective
SILs. This comparison determines the additional analyses that were required to demonstrate theProject’s impact on the surrounding air quality and compliance with standards. The preliminarymodeling results demonstrated that the Project would exceed the corresponding SILs for 1-hour
NO2, annual NO2, 24-hour PM2.5, 1-hour SO2, and 3-hour SO2. Therefore, Venture Global
conducted a full impact analysis for these pollutant/averaging period combinations.
Based on prior LDEQ guidance and precedent on other similar projects in Louisiana,
Venture Global determined that on-site preconstruction air quality monitoring would likely not be
required because preliminary assessment modeling demonstrated that maximum modeling results
are below the respective SMCs. For use in cumulative modeling, Venture Global proposed to the
LDEQ use of an appropriate data set of background data collected at existing monitors in theregion. These data were subsequently approved by the LDEQ.

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Table 4.11-8
Preliminary Model Results – Stationary Sources

Pollutant
CO
NO2
PM10
PM2.5

SO2

Preliminary Maximum
Modeled Concentration(µg/m3)Radius of Influence for SIL
Analysis (km)Averaging
PeriodSIL(µg/m3)SMC(µg/m3)

Scenario 3

Scenario 4

Scenario 3

Scenario 4

1-hour2,000

n/a

1,709.2

1,709.2

Below SIL

Below SIL

8-hour

500

575

156.2

156.2

Below SIL

Below SIL

1-hour

7.5

n/a

17.8

21.2

17.92

17.92

Annual

1

14

1.4

1.5

1.21

1.25

24-hour

5

n/a

2.8

3.3

Below SIL

Below SIL

Annual

1.0

10

0.3

0.4

Below SIL

Below SIL

24-hour

1.2

4

2.4

2.7

3.47

6.10

Annual

0.3

n/a

0.2

0.3

Below SIL

Equal to SIL

1-hour

7.8

n/a

8.8

8.9

1.50

1.50

3-hour

25

n/a

75.4

75.4

0.76

0.76

24-hour

5

13

5.0

5.0

Below SIL

Below SIL

Annual

1

n/a

0.1

0.1

Below SIL

Below SIL

Key:
µg/m3 = micrograms per cubic meter
CO = carbon monoxide
km = kilometers
NO2 = nitrogen dioxide
PM10 = particulate matter equal to or less than 10 micrometers in aerodynamic diameter
PM2.5 = particulate matter equal to or less than 2.5 micrometers in aerodynamic diameter
SIL = Significant Impact Level
SMC = Significant Monitoring Concentration
SO2 = sulfur dioxide

Full NAAQS (Cumulative) Modeling Analysis – Stationary Sources
Emission sources included in the full NAAQS modeling included the Project emission
sources plus non-project off-site emission sources. The radius of influence (ROI) shown in table
4.11-8 defines the circular area around the Project known as the area of influence (AOI). Basedon LDEQ guidance, the Project AOI radius, plus a 20-kilometer distance beyond the AOI radius,
was evaluated for the presence of major emission sources (i.e., greater than 250 tpy) for the
cumulative analysis. Venture Global queried a publicly available LDEQ database (the Emissions
Reporting and Inventory Center [ERIC]) to extract the non-project emission source inventory data.
Additional LDEQ data sources such as the Electronic Document Management System (EDMS),
emission source data at similar facilities, and LDEQ guidance on default values were used to fillin missing data in the off-site emission source inventory.
In addition to the contribution of facility emissions and off-site emissions sources,
background monitor data were added to modeled results. The background monitor data represents
all other emission sources in the modeling area such as minor stationary sources, area sources, andmobile sources.

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In the SIL analysis, all NOX emitted from the Project is conservatively assumed to convert
to NO2. In the full NAAQS analysis, guidance allows the use of a refined conversion ratio thatreflects a more realistic conversion process. The Project followed appropriate EPA guidance
regarding selection and use of conversion ratios for determining the amount of total NOX emitted
converted to NO2. The analysis used the Tier 2 Ambient Ratio Method, which prescribes that 80
percent of emitted NOX converts to NO2 for the 1-hour averaging period, and 75 percent of the
NOX emitted converts to NO2 for the annual average period.
Emission scenarios 3 and 4, described above, were modeled in conjunction with off-site
emission sources to evaluate NAAQS compliance. For short-term averaging periods (1-hour, 3hour, 8-hour, and 24-hour), emissions were based on hourly maximum emission rates forcontinuously or near continuously operating emission sources. Long-term (annual) averaging
period emission rates were based on an average annual emission rate that takes into account periodsof the source not operating.
Intermittent sources—that is, equipment that operates only a few hours per year or on an
emergency basis—were included in the modeling, where appropriate, with emission rates derived
based on EPA guidance (EPA, 2011b).
Stack and building locations and dimensions were input to AERMOD to assess potential
downwash effects. This data were used with EPA’s currently approved version of the Building
Profile Input Program – Plume Rise Model Enhancements software (version 04274) to develop
wind direction-specific building profiles.
Table 4.11-9 shows the modeling results for the NAAQS assessment. The table shows thatall predicted concentrations were less than the NAAQS except for 1-hour NO2. To address the 1hour NO2 exceedance, a “culpability analysis” was performed. A culpability analysis looks not
only at the maximum values shown in table 4.11-5, but also at the contribution of the Project toeach individual exceedance over all receptors and modeled hours. EPA guidance provides that a
Project is considered to be in compliance with the NAAQS if its contribution to each individualmodeled exceedance is less than the SIL. None of the Project’s contributions to modeled NAAQS
exceedances are greater than the SIL for 1-hour NO2. Therefore, the Project would not
significantly contribute to any of the modeled NAAQS exceedances and is shown to be incompliance with the NAAQS.

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Table 4.11-9
NAAQS Assessment Results – Project Stationary Sources and Off-Site Cumulative Sources
Model
Predicted
Concentration(µg/m3)aBackground
Concentration(µg/m3)

Total
Concentration(µg/m3)NAAQS(µg/m3)

Scenario

Pollutant

Averaging
PeriodScenario 3

NO2

1-hour

Note bNote b

1,883.9

188

Annual

4.5

35.1

39.6

100

PM2.5

24-hour

184.1

18.6

202.6

35

SO2

1-hour

424.1

49.5

473.7

196

3-hour

216.6

62.3

278.8

1,300

1-hour

Note bNote b

1,883.9

188

Annual

4.6

35.1

39.6

100

PM2.5

24-hour

737.9

18.6

756.5

35

SO2

1-hour

424.1

49.5

473.7

196

3-hour

216.6

62.3

278.9

1,300

Scenario 4NO2aModel predicted concentration shown is the value corresponding to the statistical nature of the NAAQS. This value is different than the
maximum modeled value used in the SIL analysis.
b The analysis for the 1-hour NO2 concentration involved use of seasonal (e.g., winter, spring, summer, fall) background concentration
values added to the model predicted concentration. The total concentration shown for 1-hour NO2 is the maximum value from thisanalysis.
Key:µg/m3 = micrograms per cubic meter
NAAQS = National Ambient Air Quality Standards
NO2 = nitrogen dioxide
PM2.5 = particulate matter equal to or less than 2.5 micrometers in aerodynamic diameter
SO2 = sulfur dioxide

Exceedances of the NAAQS are shown for both scenarios for 1-hour NO2, 1-hour SO2, and24-hour PM2.5. However, based solely on this step of the analysis, it is unknown whether the
Project is contributing above the SIL at receptor locations that show an exceedance of the NAAQS.
Therefore, Venture Global conducted a statistical analysis per EPA modeling guidance and the
Project’s approved modeling protocol that involves a detailed examination of each cumulativeemission source’s contribution, including the Project’s, to predicted NAAQS exceedances at all
receptors. Based on this additional analysis, it was found that the Project did not contribute above
the applicable SIL at any of the receptor locations where a modeled NAAQS exceedance waspredicted. Therefore, the Project demonstrated compliance with the NAAQS based on theemission scenarios modeled. However, the modeling analysis did not consider the concurrent
construction emissions that are projected to occur during Scenario 3.
Modeling Including Mobile (Vessel) Emission Sources
Venture Global prepared an additional modeling analysis that included only Project
stationary sources (no off-site cumulative sources were included) with the Project’s LNG carriers
and support vessels. The analysis consisted of modeling the impact of the emissions, adding in a
background value from monitoring stations used in the PSD modeling analysis, and comparing thetotal concentration to the applicable NAAQS. Vessels were modeled for maneuvering activities
within the moored safety (security) zone and hoteling at the terminal, and also within the moored4-193

safety (security) zone. The mobile sources during maneuvering activities included one LNG
carrier and four tug boats, while the sources during the hoteling activities included one LNG carrier
and one tug boat. Venture Global conducted the modeling analysis for the terminal plus LNG
carrier and supporting vessel mobile emissions, with background concentrations, and comparedthese concentrations to the NAAQS.
The position and emission rates for the vessels included in the modeling varied for shortterm (e.g., 1-hour, 3-hour, 8-hour, and 24-hour) periods compared to the annual period. For the
short-term modeling periods of 1, 3, and 8 hours, one LNG carrier and three attendant tug boats
were assumed in the safety zone performing maneuvering activities, with one LNG carrier and one
tug boat docked at the terminal. For the 24-hour short-term modeling period, two LNG carriers
were modeled as docked at the terminal with two tug boats standing by. For the annual modeling
period, LNG carriers were located at all three loading docks along with their attendant support
vessels. For operation of stationary sources in the modeling, scenarios 3 and 4 described earlier
were included. Thus, the following combinations of stationary and vessel sources were modeled:•

Scenario 3 – Phase I final operating mode (gas turbines in combined-cycle operation),plus Phase II interim operating mode (Phase II gas turbines in simple-cycle operatingmode), plus marine vessels; and•Scenario 4 – Final operating model for the terminal (Phase I and Phase II) plus marine
vessels.

The NAAQS Assessment results in table 4.11-10 show compliance with the NAAQS. The
combined stationary/marine vessel modeling analysis was not carried through to include the offsite cumulative emission source inventory as was done for the PSD modeling.

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Table 4.11-10
NAAQS Assessment Results – Project Stationary and Vessel Sources
Model
Predicted
Concentration(µg/m3)aBackground
Concentration(µg/m3)

Total
Concentration(µg/m3)NAAQS(µg/m3)

Scenario

Pollutant

Averaging
PeriodScenario 3CO1-hour

1,675.2

5,713.6

7,388.7

40,0008-hour147.9

2,290.0

2,437.9

10,000

1-hour

Note bNote b84.0

188

Annual

1.4

35.1

36.5

100

24-hour

1.8

18.6

20.4

35

Annual

0.2

7.9

8.1

12

PM10

24-hour

2.4

75.0

77.4

150

SO2

1-hour

8.0

49.5

57.5

196

3-hour

11.4

62.3

73.7

1,300

24-hour

3.0

21.8

24.8

365

Annual

0.1

14.1

14.2

80

1-hour

1,675.2

5,713.6

7,388.7

40,0008-hour147.9

2,290.0

2,437.9

10,000

1-hour

Note bNote b84.0

188

Annual

1.5

35.1

36.6

100

24-hour

2.0

18.6

20.6

35

Annual

0.3

7.9

8.2

12

PM10

24-hour

2.5

75.0

77.5

150

SO2

1-hour

8.1

49.5

57.6

196

3-hour

11.4

62.3

73.7

1,300

24-hour

3.0

21.8

24.8

365

Annual

0.1

14.1

14.2

80

NO2
PM2.5

Scenario 4

CO
NO2
PM2.5

a

Model predicted concentration shown is the value corresponding to the statistical nature of the NAAQS. This value is different than the
maximum modeled value used in the SIL analysis.
b The analysis for the 1-hour NO2 concentration involved use of seasonal (e.g., winter, spring, summer, fall) background concentration
values added to the model predicted concentration. The total concentration shown for 1-hour NO2 is the highest value from this analysis.
Key:µg/m3 = micrograms per cubic meter
CO = carbon monoxide
NAAQS = National Ambient Air Quality Standards
NO2 = nitrogen dioxide
PM10 = particulate matter equal to or less than 10 micrometers in aerodynamic diameter
PM2.5 = particulate matter equal to or less than 2.5 micrometers in aerodynamic diameter
SO2 = sulfur dioxide

Additional Impact Analyses
The PSD modeling analysis also requires additional assessments of potential impacts fromair emissions on Class I areas; soil, vegetation, and wildlife; and additional or induced growth.

4-195

The additional assessments were based on the results of the NAAQS analysis and are summarized
below.
The nearest Class I area is the Breton National Wildlife Refuge. Venture Global performeda modeling analysis to evaluate potential air quality and visibility impacts on sulfate and nitratedeposition. This is discussed in section 4.11.1.6.
The secondary NAAQS are set at levels designed to protect soil, vegetation, and wildlife.
The NAAQS assessment demonstrates that the Project would comply with the primary NAAQS,
which are more stringent (set at lower levels) than the secondary NAAQS. Therefore, the Project
is not expected to result in significant impacts on soil, vegetation, or wildlife as a result of air
pollutant emissions.
Additional Growth
Venture Global conducted a growth analysis to determine whether the Project could induce
additional development that could lead to air quality impacts on the surrounding area. The Gulf
Coast region historically has been a center for the oil and gas industry, and the Project would beof similar character. Raw materials, other supplies, and services to be used by the Project are
currently available to serve existing oil and gas facilities, and it is believed that existing suppliers
would be able to support the Project. Therefore, growth of the supply industry in the immediatearea is not expected and will not lead to additional growth related air quality impacts.
The area surrounding the Project site contains an established road network and available
workforce. Venture Global anticipates that the majority of the permanent workforce at the Project
would be local hires already residing in the area. There would not be a large demand fordevelopment of new housing in the area. With little induced development, there would not be alarge increase in emissions associated with residential growth.
In addition to the Class I visibility analysis discussed in section 4.11.1.6, Venture Global
reviewed land uses that may be sensitive to reductions in visibility. The area examined was definedas the 3-kilometer area surrounding the Project, where potential PM10 concentrations could beabove the SIL. No airports, state or federal parks, or other land uses sensitive to changes invisibility were identified.
Louisiana Toxic Air Pollutant Modeling – Stationary Sources
As part of the air permit application submitted to the LDEQ, Venture Global was required
to conduct a modeling analysis for toxic air pollutants (TAPs) per LAC 33:III Chapter 51. TAPs
include chemical compounds that are known, probable or suspected human carcinogens, and acuteand chronic non-carcinogenic toxins. TAPs with a potential to emit above minimum emission
rates specified in LDEQ’s regulation may be subject to dispersion modeling. However, according
to LDEQ regulations in LAC 33:III Chapter 51, emissions associated with the combustion ofcertain fossil fuels such as natural gas and gas streams with a heating value above 7,000 British
thermal units (BTU) per pound of fuel are exempt from the modeling requirement. This exemption
eliminates consideration of any TAP emissions from equipment burning natural gas.

4-196

Ammonia would be released from the selective catalytic reduction control technology units
that would be installed on the combined-cycle, heavy-duty frame combustion turbines, andaeroderivative combustion turbines at the power facility. Since this TAP is not produced by
combustion of virgin fossil fuels and is not a gas stream with a BTU per pound content greaterthan 7,000, it is subject to modeling.
The modeling procedures in LDEQ’s Air Quality Modeling Guidance consist of threesteps: an initial screening analysis, an initial refined analysis, and an additional refined analysis.
Modeling followed previously established modeling procedures and receptor grids as used for the
SIL analysis. For TAP modeling, the LDEQ requires that only the latest year of meteorological
data (2015) in the 5-year data set be used. Ammonia emission rates from the combined cycle gas
turbine and aeroderivative gas turbine stacks for emission scenarios 3 and 4 were modeled
separately.
Venture Global conducted modeling in the initial screening analysis step. The maximum
modeled concentration of ammonia is compared to 7.5 percent of the LDEQ ambient air standard
for ammonia shown in LAC 33:III.51, Table 51.2. The results of the modeling are shown in table
4.11-11. Because the results are less than 7.5 percent of the ambient air standard, the modelingdemonstration is complete and no further analysis is required.
Table 4.11-11
Ammonia Model Results – LDEQ Toxic Air Pollutant Analysis
Scenario

Averaging
PeriodModel Result(µg/m3)LDEQ AAS(µg/m3)

3

8 hour

4.1

640

4

8 hour

5.0

640

Key:
µg/m3 = micrograms per cubic meter
AAS = ambient air standard
LDEQ = Louisiana Department of Environmental Quality

4.11.1.7 Impacts on Ambient Ozone Concentrations
Venture Global prepared an ozone impact analysis in accordance with LDEQ Air Quality
Modeling Procedures. An ozone impact analysis is required because a Project’s potential to emit
NOX and VOC is above the 100-ton per year emission threshold prescribed by LDEQ.
The Project would be located in Plaquemines Parish, which is currently designated as an
attainment area for the 2008 ozone NAAQS. In November 2017, the EPA published an initialround of final designations for the 2015 ozone NAAQS that included designating Plaquemines
Parish as unclassifiable or in attainment for the 2015 ozone NAAQS.
Although the Project area is in attainment or unclassifiable for the Ozone NAAQS, there
is one nearby area and two more distant areas of potential air quality concern in the larger region
beyond Plaquemines Parish:

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•

parishes in the Baton Rouge Metropolitan Statistical Area that were only recently
designated as in attainment for the 2008 ozone NAAQS (about 90 miles northwest of
the Project site).
These parishes were also very recently designated asattainment/unclassifiable for the 2015 ozone NAAQS after the LDEQ requested and
EPA agreed with exclusion of certain exception event data from Ascension Parish anda submittal of certified 2017 monitoring data indicating attainment with the standard;•

the Beaumont/Port Arthur 2008 ozone NAAQS attainment area, a former
nonattainment area in which ozone remains a concern and which is about 250 miles
west of the Project site; and•the Houston/Galveston/Brazoria 2008 ozone NAAQS nonattainment area, about
320 miles west of the Project site.

Due to the quantity of ozone precursor emissions (VOC and NOx) from the Project and theproximity of the Project to these three areas, Venture Global performed an ozone modeling
analysis to quantify the potential impact of the Project on ozone concentrations in the surroundingarea. The analysis was performed in accordance with current EPA and LDEQ air quality modelingguidelines. The analysis evaluated interim operating scenario 3 and final operating scenario 4.
Both scenarios were evaluated because scenario 3 has the highest NOx emissions of the two
scenarios, while scenario 4 has higher VOC emissions. However, interim operating scenario 3
only included stationary emissions sources and did not include concurrent construction emissions.
As noted earlier, during construction, NOx and VOC emissions would be significantly higher thanin the final operating model. As a result, ambient ozone concentration may be higher than shownfor the final operating mode.
Photochemical Grid Model
The potential 8-hour ozone impact of Project emissions was quantified using a state-ofthe-science regional photochemical grid model, the Comprehensive Air Quality Model with
Extensions (CAMx) in conjunction with data for an ozone episode that occurred in the Baton
Rouge region from August 17 through October 31, 2010. The LDEQ had prepared the ozone
episode data as part of its submittal to EPA requesting redesignation of the Baton Rouge ozone
nonattainment area to attainment for the 1997 8-hour ozone standard. These data and this study
are fully described in the Photochemical Modeling for the Louisiana 8-Hour Ozone State
Implementation Plan Technical Support Document (LDEQ, 2013). This modeling was conducted
on a nested grid configuration of 22-mile (36-kilometer), 7.5-mile (12-kilometer), and 2.5-mile (4kilometer) grid cells. In a photochemical grid modeling analysis, grid cells correspond to
receptors. Consistent with the analysis by the LDEQ, the modeling for the Project was restricted
to the 2.5-mile (4-kilometer) domain.
The modeling approach used in this analysis follows the EPA (2016) guidance for a“Refined or Second Tier” modeling study. The guidance specifies a step-wise approach for the
analyses, beginning with a significant impact analysis followed by, if necessary, a cumulative
analysis (second tier). Consistent with the guidance, the Project impact was assessed using theepisode maximum daily 8-hour average concentration at receptors (as grid cells) on days where
the ozone is estimated to be over 60 parts per billion (ppb) on more than five episode days (known
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as “high modeled days”). The emission sources and rates, land use and terrain, and other inputs
were consistent with those used in the Class II PSD modeling analysis conducted for the Projectand submitted to the LDEQ.
Venture Global conducted a preliminary modeling analysis for ozone in which the peakincreases in ozone concentrations from the Project, as modeled with CAMx, were evaluated todetermine whether they have the potential to have a significant impact on ozone in the areasurrounding the facility. Modeled concentrations are compared to the EPA SIL for ozone; a draft
SIL value of 1.0 ppb was established by the EPA in August 2016. If the modeled level is less thanthe SIL, then the impact is considered to be less than significant with respect to the NAAQS andno further analysis is required.
The modeled peak ozone impact from the Project is 2.45 ppb for scenario 3 and 2.47 ppb
for scenario 4. Both exceed the draft ozone SIL of 1.0 ppb. Because the Project’s impact fromthe preliminary analysis exceeds the SIL, a cumulative modeling analysis for ozone impacts was
performed.
The cumulative ozone modeling analysis was performed using CAMx as described above,
but with the addition of background concentrations in the region. In accordance with the EPA
guidance, a monitored design concentration value was used for the background values. The
background monitor design value was obtained from the Houma-Thibodaux air quality monitor(AIRS ID: 220570004).
The 2016 Modeling Guidance specifies that the highest daily 8-hour maximum ozone
contribution from the Project source on high modeled days at each receptor should be added to themonitored design value at that receptor. For this analysis, the maximum monitored design value
in the Houma-Thibodaux area for 2013–2015 was used to conservatively represent the monitored
design value at all receptors. The design value used in the analysis was 65 ppb.
The addition of the modeled Project impact of 2.45 ppb for scenario 3 and 2.47 ppb for
scenario 4 to the monitored design concentration value of 65 ppb would not exceed either the 75
ppb 2008 ozone NAAQS or the 70 ppb 2015 ozone NAAQS for each scenario. Therefore, theProject would not cause or contribute to a violation of the ozone NAAQS. However, Project
impacts during the interim operating mode including construction emissions would result in higher
ozone impacts.
4.11.1.8 Summary Conclusion – Overall Air Quality
During the construction period (currently estimated 2019 - 2023), residents in the vicinityof the Project would experience local impacts on air quality. During the period of combined
construction and operation, nearby locations would experience larger air quality impacts due tothe high level of emissions during certain years, and may exceed the NAAQS. These exceedances
would not be persistent at any one time during these years due to the dynamic and fluctuating
nature of construction activities within a day, week, or month. During operation, extensivemodeling has indicted that the Project would have not have significant impacts on the local andregional air quality and Class I areas.

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4.11.2 NoiseThe noise environment can be affected during both construction and operation of the
Project. The magnitude and frequency of environmental noise may vary considerably over thecourse of the day, throughout the week, and across seasons, in part due to changing weather
conditions and the effects of seasonal vegetative cover. This section identifies the potential sourcesof noise, the magnitude of noise, and discusses the change in noise attributable to construction andoperation of the Project.
Noise is defined as any unwanted sound. Sound is defined as any pressure variation thatthe human ear can detect. Humans can detect a wide range of sound pressures, but only thepressure variations occurring within a particular set of frequencies are experienced as sound.
However, the acuity of human hearing is not the same at all frequencies. Humans are less sensitive
to low frequencies than to mid-frequencies; therefore, noise measurements are often adjusted (orweighted) to account for human perception and sensitivities.
The ambient sound level of a region is defined by the total noise generated within thespecific environment and usually comprises natural and man-made sounds.
Two measures used by some federal agencies to relate the time-varying quality ofenvironmental noise with its known effect on people are the equivalent continuous sound level(Leq) and the day-night average sound level (Ldn). The preferred single value figure to describe
sound levels that vary over time is Leq, which is defined as the sound pressure level of a noise
fluctuating over a period of time, expressed as the amount of average energy. Ldn is defined as the
24-hour average of the equivalent average of the sound levels during the daytime (Ld – from 7:00
a.m. to 10:00 p.m.) and the equivalent average of the sound levels during the nighttime (Ln – 10:00
p.m. to 7:00 a.m.). Specifically, in the calculation of the Ldn, late night and early morning (10:00
p.m. to 7:00 a.m.) noise exposures are increased by 10 dB to account for people’s greater sensitivity
to sound during nighttime hours. In general, if the sound energy does not vary over the given time
period, the Ldn level will be equal to the Leq level plus 6.4 dB. The 6.4 dB difference between the
Ldn and the Leq is a result of the 10 dB nighttime addition for the Ldn calculation.
Decibels are the units of measurement used to quantify the intensity of noise. To accountfor the human ear’s sensitivity to low level noises the decibel values are corrected to weighted
values known as decibels on the A-weighted scale (dBA). The A-weighted scale is used because
human hearing is less sensitive to low and high frequencies than mid-range frequencies.
Decibels are relative units that compare two pressures: the sound pressure and a reference
pressure. The reference pressures typically used for air and water are not the same, and a directcomparison of values between in-air and underwater noises is not appropriate. Underwater sounds
use a reference pressure of 1 µPa while in air sounds have a reference pressure of 20 µPa. For inair sound levels, the reference pressure is often not explicitly stated, as is the case in this text. The
reference pressure of underwater sounds is typically stated, and is presented in this text. This isdone to remind readers of the different reference pressures between underwater and in air soundlevels, and avoid direct comparison. Therefore, in this text, in air sound levels are presented indecibels while underwater sound levels are presented as “dB referenced to (re) 1 µPa.” Underwatersound levels may also include a distance to indicate setback from the sound source. For example,
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a setback distance of 1 meter would be expressed as “dB (re 1 µPa) at 1 meter.” Propagation
distances in water are farther than in air because water is denser; however, loudness underwater
diminishes quickly with distance from the sound source.
Table 4.11-12 lists relative dBA noise levels of common sounds measured in theenvironment and industry. A 3 dB change of sound level is considered to be barely perceivableby the human ear, a 5 or 6 dB change of sound level is considered noticeable, and a 10 dB increaseis perceived as if the sound intensity has doubled.
Table 4.11-12
Sound Levels and Relative Loudness
Sound Level(dBA)

Subjective Impression a

Relative Loudness(perception of change)

Jet aircraft takeoff from carrier (50 feet)

140

Threshold of pain

64 times as loudLoud rock concert near stage120

Uncomfortably loud16 times as loudJet takeoff (2,000 feet)

100

Very loud

4 times as loud

Garbage disposal / food blender (2 feet)

80

Loud

Reference loudness

Vacuum cleaner (10 feet)70

Moderate

1/2 as loudLight auto traffic (100 feet)

50

Quiet

1/8 as loudQuiet library, soft whisper (15 feet)

30

Very quiet

1/32 a loudWilderness with no wind or animal activity

25

Extremely quiet

No perceptible change

Noise Source or ActivityaBarnes et al., 1977; EPA, 1971

4.11.2.1 Noise Regulations
Federal Regulations
In 1974, the EPA published Information on Levels of Environmental Noise Requisite toProtect Public Health and Welfare with an Adequate Margin of Safety (EPA, 1974). This
document provides information for state and local governments to use in developing their own
ambient noise standards. The EPA has determined that, to protect the public from activity
interference and annoyance outdoors in residential areas, noise levels should not exceed an Ldn of
55 dBA. We have adopted this criterion and have used it to evaluate the potential noise impacts
from the Project at noise sensitive areas (NSA). NSAs can be residences, hospitals, places ofworship, temporary residences, and other areas that may have a greater sensitivity to noise thanother locations. Due to the 10 dBA nighttime penalty added prior to calculation of the Ldn, for a
facility to meet the Ldn 55 dBA limit, it must be designed such that actual constant noise levels on
a 24-hour basis do not exceed 48.6 dBA Leq at any NSA.
State and Local Regulations
The State of Louisiana has not adopted noise regulations applicable to construction andoperation of the Project. Plaquemines Parish does maintain noise regulations within its Code of

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Ordinances, Part 1 – Chapter for Local Self Government for Plaquemines Parish, Louisiana,
Chapter 17 – Offenses – Miscellaneous, Article IX – Noise (Plaquemines Parish, Louisiana
Municipal Code, 2015). The FERC noise limits are more stringent than Plaquemines Parish limits;
therefore, the FERC noise limits represent the governing limits for the Project.
Section 17-133 of the noise article for Plaquemines Parish states the following:
For any source of sound, the sound level shall not exceed the maximum
permissible sound level limit set forth in table 1 by fifteen dB (A) for all land use
categories. Sound level measurement shall be made with a sound level meterusing the A-weighing scale in accordance with the standards promulgated by theAmerican National Standards Institute.
See table 4.11-13 for the maximum permissible sound level limit, referenced as “table 1”
in the Plaquemines Parish noise article.
Table 4.11-13
Maximum Permissible Sound Levels by Receiving Land Use Category (Table 1)
Time

Sound Level
Limited dB(A)Residential, noise sensitive area, public space

7:00 a.m.–10:00 p.m.
10:01 p.m.–6:59 a.m.

60
55

Multifamily dwelling

7:00 a.m.–10:00 p.m.
10:01 p.m.– 6:59 a.m.

50
45Commercial, convention

7:00 a.m.–10:00 p.m.
10:01 p.m.– 6:59 a.m.

65
60

At all times

75

Land Use Category

Industrial

4.11.2.2 Existing Sound Levels and Noise-sensitive Areas
The terminal site is located in a mixed industrial and rural area, with two small groups ofresidences over 0.5 mile from the center (0.2 mile from the nearest corner) of the terminal site.
The primary noise sources currently in the area include wind, birds, insects, industrial facilities,
marine traffic, and vehicular traffic on local roads. The pipeline system is located in a remote areaof open water and wetlands, where noise levels are influenced by occasional recreational marine
traffic and rural background sources. Additional noise from road traffic may be associated with
the Lake Hermitage Road crossing the pipeline system. There are residences within 0.5 mile ofthe pipeline system, which could contribute to ambient noise levels at these residences during
construction.
Residences, along with schools, recreational areas, and hospitals, are considered NSAs.
Venture Global conducted an ambient noise survey at nine measurement locations. Venture
Global identified several residences that would be considered NSAs. These residences weregrouped into four NSA clusters containing multiple residences. Five other areas, identified as
potential noise receptors (PNRs), were also included in Venture Global’s baseline ambient noise

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survey. Table 4.11-14 provides the distance and direction of each NSA and PNR cluster, andfigure B-9 in appendix B identifies their location.
Table 4.11-14
Ambient Noise Level Survey Locations
NSA/PNR

Direction

Distance to Terminal Site(miles)aDistance to Pipeline
System (miles)b

NSA 1

NW

0.90

0.69

NSA 2

W

0.56

0.29

PNR 3

NNW

0.71

0.92

PNR 4

ENE

0.97

1.29

PNR 5

ENE

1.70

1.96

NSA 6

E

1.80

2.09

PNR 7

SSW

0.81

0.13

PNR 8

SW

0.97

0.95

NSA 9

NE

1.80

2.08

a Measured from the center of the terminal site.
b Measured from the nearest workspace.
Key:
NSA = noise-sensitive area
PNR = potential noise receptor

The ambient noise survey was conducted at each of the nine measurement locations over a
24-hour period using a calibrated sound level meter and analyzer and a field microphone equippedwith a windscreen to minimize wind turbulence. The noise survey results for the four locations
subsequently identified as NSAs are presented in table 4.11-15.
Table 4.11-15
Ambient Noise Level Survey Results
NSA

Daytime Ambient NoiseLevel (dBA)Nighttime Ambient NoiseLevel (dBA)24-Hour Ambient NoiseLevel (dBA)

NSA 1

46.5

44.5

51.3

NSA 2

46.9

45.9

52.5

NSA 6

52.4

47.9

55.3

NSA 9

46.5

43.2

50.3

Key:
dBA = A-weighted decibels
NSA = noise-sensitive area

The most common noise producing activities were noted as vessel traffic along theMississippi River, construction activities, vehicle traffic along SH 23 and Lake Hermitage Road,
and wildlife and birds. At NSA 6, the predominant noise during the day was related to nearby
construction. As shown in the table above, the nighttime levels at NSA 6 are more in line with theother NSAs at night than during the day.
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4.11.2.3 Construction Noise Impacts and Mitigation
LNG Terminal
Construction activities at the Project site would involve clearing and grading, placement offill, installation of foundations for the planned Project facilities, other equipment settings, ancillaryequipment, piping, and structures. Construction of the Project would cause temporary increases
in ambient noise levels in the immediate vicinity of the construction sites. Construction operating
hours would be from 7:00 a.m. to 7:00 p.m., Monday through Saturday. Land-based and marineside pile driving, which is the loudest construction activity, is expected to also occur 6 days per
week starting at 7:00 a.m., as well, but would end at 5:00 p.m. It is anticipated that the Project
would require nighttime construction at the terminal site during the initial 6 to 12 months. The
level of construction-related noise would also vary over the course of the construction period,
depending on the construction phase in progress. In water and marine pile driving and theanticipated sound pressure levels effect on marine wildlife is discussed in section 4.6.3.2.
Noise levels resulting from construction equipment are dependent on several factors
including the number and type of equipment operating, the level of operation, and the distance
between sources and receptors. The loudest equipment during construction would contribute to acomposite average or equivalent site noise level. Pile-driving activities are expected to produce
the highest level of noise during construction of approximately 110 dBA at 50 feet. The composite
noise level of all other heavy equipment that would be used during construction is expected to beapproximately 90 dBA. For this EIS, the impacts on NSAs from land-based and marine-side piledriving are being evaluated, since they are the predominant noise-producing activity.
The evaluation of land-based and marine-side pile driving assumed that 12 pile drivers
would be operating simultaneously for 16-months, which would be the worst-case scenario,
according to Venture Global. Table 4.11-16 reports the predicted noise levels at each of the four
NSAs, based on this worst-case scenario in Phase I of construction. Phase II would have thebenefit of a constructed floodwall, and thus pile-driving noise levels would be greatly reduced (ascompared to Phase I) due to the floodwall’s indirect suppression of pressure waves. Venture
Global based the predictive modeling on noise emanating from the center of the terminal site
because that location would contain the most noise-making construction equipment.
Table 4.11-16
Predicted Noise Levels at NSAs During Pile Driving – Phase I
NSA

Distance from Center of Terminal
Site (miles)

Predicted Noise Level LMAX
(dBA)

NSA 1

0.90

65.3

NSA 2

0.56

69.9

NSA 6

1.80

58.1

NSA 9

1.80

56.5

Key:
dBA = A-weighted decibels
LMAX = Maximum sound level during a measurement period or noise event.
NSA = noise-sensitive area

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Impact pile driving is an intermittent noise source (i.e., non-constant), so a usage factor
was applied to the calculated maximum noise level (Lmax). In accordance with the Federal
Highway Administration Roadway Construction Noise Model (Federal Highway Administration,2006), Venture Global applied a usage factor of 20 percent to the predicted Lmax levels from piledriving as shown in table 4.11-17. Calculating pile-driving noise without a usage factor would not
be an appropriate way of estimating noise impacts from an intermittent noise source forcomparison to ambient background noise levels because ambient noise is also applied a usage
factor.
Table 4.11-17
Predicted Noise Levels at NSAs During Pile Driving and Applying 20 Percent Usage Factor

NSA

Baseline
Ld (dBA)

Predicted Noise Level
LMAX (dBA)

Predicted Noise Level
LMAX (dBA) with Usage
FactorIncrease on Baseline
(dBA)

NSA 1

46.5

65.3

58.3

11.8

NSA 2

46.9

69.9

62.9

16.0

NSA 6

52.4

58.1

51.1

-1.3

NSA 9

46.5

56.5

49.5

3.0

Key:
LMAX = Maximum sound level during a measurement period or noise event.
dBA = A-weighted decibels
Ld = daytime equivalent sound level (dBA)
NSA = noise-sensitive area
Lmax = highest sound measured by the sound level meter over a given period of time
Lmax with Usage Factor = highest sound measured by the sound level meter over a given period of time with consideration to Usage Factor
for intermittent noise sources.

Noise impacts on NSAs during construction would be temporary and moderate,considering the predicted noise levels from land-based and marine-side pile driving range from
11.8 to 16.0 dBA greater than existing ambient noise levels during daytime hours at the two closest
NSAs.
Venture Global has committed to implement mitigation measures to reduce land-based andmarine-side pile-driving noise impact on NSAs. Venture Global would construct 5-meter-highnoise protection walls around piling rigs for mitigation. As modeled, these noise barriers would
reduce the increase of ambient noise levels to 0.4 dBA and 2.2 dBA at the two nearest NSAs.
Without this mitigation, the increase above ambient noise levels would range from 11.8 dBA to
16.0 dBA.
Pipeline System
During construction of the pipeline system, noise would be primarily generated byconstruction equipment, including HDD equipment, and pile installation activities. Noiseassociated with HDD and pile installation activities are further described below.
HDD construction involves various equipment and activities, including power generation,
mobile equipment, and mixing pumps. Different equipment is used on the entry and exit side of
the HDD section. Typical equipment used at the HDD entry side includes:
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•

drilling rig and engine-driven hydraulic power unit;•

engine-driven mud pump(s) and engine-driven generator set(s);•mud mixing/cleaning equipment and associated fluid systems’ shale-shakers;•

mobile equipment, including a crane, forklift, and/or truck(s);•drill mud and make up tanks; and•engine-driven lights.

Predicted noise levels at the closest NSA (NSA 2) associated with the HDD at Lake
Hermitage Road are presented in table 4.11-18.
Table 4.11-18
Predicted Noise Level from Lake Hermitage Road HDD at NSA 2

HDD Site

Distance to
NSA 2

Ambient Noise
Level

Predicted Ldnof HDD (dBA)

Predicted Ldn HDD+ Ambient Ldn(dBA)

Potential
Change in NoiseLevel (dBA)HDD Entry Site

1,610 feet

46.4

59.5

59.7

13.3

HDD Exit Site

1,925 feet

46.4

46.0

49.2

2.8

Key:
dBA = A-weighted decibels
HDD = horizontal directional drill
Ldn = day-night average sound level
NSA = noise-sensitive area

To minimize impacts on NSAs from HDD operations, Venture Global proposes toimplement a sound curtain enclosure or acoustic barrier as necessary. Sound curtain enclosureswould be used around the drilling rig and other stationary equipment during the HDD process.
Sound curtain enclosures have been shown to provide 10 to 14 dBA of mitigation. To obtain aconservative estimate of the noise levels, it is assumed that 10 dBA of mitigation would be
provided due to the sound curtain enclosure. Sound enclosures or acoustic barriers could also be
used during dredging activities if nearby structures are occupied during barge access channel
dredging.
Impacts associated with pipeline HDD and dredging activities would be temporary andminor at NSAs and PNRs. Further implementation of sound curtains, as necessary, would further
minimize this temporary impact.
To insure that potential noise impacts on nearby NSAs are minimized to the extent
practical, we recommend that:•

Prior to beginning the HDD at Lake Hermitage Road, Gator Express Pipeline
should file with the Secretary, for the review and written approval by the Directorof OEP, an HDD noise mitigation plan for the crossing to reduce the projected
noise level attributable to the proposed drilling operations at the nearby
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NSA. During drilling operations, Gator Express Pipeline should implement theapproved plan, monitor noise levels, and make all reasonable efforts to restrict thenoise attributable to the drilling operations to no more than an Ldn of 55 dBA at
the NSA.
The pipe bridge that would be constructed north of Lake Hermitage Road would be used
to traverse an existing non-federal levee. Two NSAs are located within 1 mile of pile installation
activities associated with the pipe bridge at respective distances of approximately 3,900 and 1,600
feet. Construction activities at the pipe bridge would generally occur during the daytime and would
occur over a period of 20 days involving 18 piles. Pile installation would involve an auger typedrill rig instead of an impact rig as discussed in LNG terminal construction. An auger drill rig has
an Lmax of 85 dBA at a distance of 50 feet. Use of an auger drill for pipe bridge pile installation
would be estimated to produce a noise level of 54.3 dBA at NSA 2, located approximately
1,713 feet to the west. This would be a 7.9 dBA increase during daytime ambient noise levels.
Venture Global has committed to keep noise impacts at the NSAs under 10 dBA above the ambient
noise levels for all Project activities.
Additional noise produced during pipeline construction would come from installation ofpiles for the metering stations and dredging along the barge access routes. Although no NSAs arewithin 0.5 mile of a proposed metering station, pile installation would create greater noise levels
for possible boaters nearby. However, Venture Global anticipates that piles would be installed via
a vibratory process for metering stations that produces less noise than impact pile driving.
Venture Global anticipates no dredging within the Mississippi River is needed and,
therefore, NSAs near the terminal site would not be affected by dredging activities. However,during construction of the pipeline system, Venture Global would require water access to theconstruction site for barges and other vessels involved in dredging, pipe laying, equipment andmaterials deliveries, and spoil storage. Barge access to the work area would follow existingwaterways, and the majority of the system is sufficiently deep (at least 8 feet) to allow free passage;
however, some dredging would be required in four areas, totaling 8.9 miles, to facilitate access.
The nearest PNR to the areas to be dredged is a structure within a coastal marshland locatedapproximately 265 feet south of Barge Access Channel No. 2. Approximately 24 additional
structures are located near this structure but farther away along the Wilkinson Canal. These
structures are vacation/seasonal homes accessible only by water and are considered NSAs.
However, as a conservative measure, dredging noise levels at the nearest structure were evaluatedfor this EIS.
Dredging activities are anticipated to occur only during the daytime and are estimated tolast for 1 month (17 days for excavation and 11 days for backfill). Dredging of the channel is
expected to be required to support construction of both pipeline laterals, resulting in two separate
dredging events. It is estimated that the dredging noise level (24-hour Leq) would be 84 dBA at a
distance of 50 feet for this type of activity (FERC, 2002). This corresponds to a daytime soundlevel of 65.7 dBA at the nearest structure. The distance at which the noise related to dredging
activities decreases to 55.0 dBA is approximately 900 feet. There are ten structures within a 900foot radius of dredging activities.

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Pipeline construction and dredge barge operation would be audibly noticeable at the nearest
NSAs (in relation to the specific construction activity). Venture Global has committed tomitigation measures, such as sound curtains around drillings rigs, which would reduce noise fromconstruction equipment to within acceptable thresholds. Furthermore, the recommendation madein this section regarding the HDD ensure noise impacts would not be significant during the pipeline
system construction.
4.11.2.4 Operational Noise Impacts and Mitigation
LNG Terminal
Operation of the LNG terminal would produce noise on a continuous basis, but is expected
to remain within applicable FERC limits. The primary noise-generating sources would be:•

steam power generation;•

fan-driven air-cooled heat exchangers;•

LNG refrigerant compressor electric motor drive units;•

mixed refrigerant and boil-off gas (BOG) compressor units;•

power plant electric generation units;•

inlet and discharge piping;•

expander units;•

packaged items; and•LNG carriers.

Additionally, during the scoping period and draft EIS comment period, comments werereceived to address noise generated from flaring activities during normal LNG terminal operation.
Venture Global does not consider the flares to be significant contributors to the noise generated by
the facility due to their infrequent use and low exit velocity. After initial facility start-up, during
which flaring would occur during the daytime, the LNG terminal is designed to limit flaring events
only to LNG carrier gas up/cool down operations, which may occur up to 40 times a year. Due tothe nature of the operations, the vapor routed to the marine loading flare (a low pressure flare)
would be discharged at a low exit velocity. Consequently, Venture Global does not anticipate suchflaring events would have noise impacts on NSAs during facility operation. Thus, flaring would
create negligible, intermittent impacts at the closest NSAs. We agree.
We require that the noise attributable to the operation of a newly constructed facility must
not exceed an Ldn of 55 dBA at any pre-existing NSA. The predicted noise levels due to LNG
terminal operation at NSAs are listed in table 4.11-19. The predicted contribution from LNG
terminal operation (Ldn 55.0 dBA) meets FERC’s contribution threshold (Ldn 55.0 dBA) with
implementation of mitigation measures, as discussed below.
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Table 4.11-19
Predicted Noise Levels at NSAs from Terminal Operation

NSA

Ambient NoiseLevel Ldn (dBA)

Predicted Ldn ofTerminal
Operation (dBA)

Predicted Ldn
Relative to FERC
Threshold Ldn 55(dBA)

Ambient Ldn +Predicted Ldn ofTerminal (dBA)

NSA 1

51.3

51.6

-3.4

54.6

NSA 2

52.5

55.0

0.0

57.0

NSA 6

55.3

43.1

-0.9

55.5

NSA 9

50.4

50.8

-4.6

53.8

Key:
dBA = A-weighted decibels
FERC = Federal Energy Regulatory Commission
HDD = horizontal directional drill
Ldn = day-night average sound level
NSA = noise-sensitive area

Specifically, blowdowns associated with steam generation in the power island would havethe greatest potential to affect NSAs during normal operation of the LNG terminal. Venture Global
anticipates 5 to 25 blowdown events per year as a result of routine maintenance and/or planned
shutdowns and restarts of the heat recovery steam generators. Other potential blowdown events
associated with forced outages (equipment- or weather-based) are expected to be infrequent, withless potential impact on NSAs.
Each vent outlet associated with the heat recovery steam generators would be equippedwith a silencer in order to limit the sound power level to a maximum of 115 dBA during blowdown
events. The blowdown stack is closest to NSA 2 at approximately 2,300 feet. The sound levelproduced by this vent would be approximately 50 dBA at NSA 2, which is the closest NSA. Noise
impacts on NSAs located farther away from blowdown stack would be less.
Venture Global plans to implement the following mitigation measures to reduce noiselevels emanating from the LNG terminal during normal operations:•liquefaction air coolers reduced to sound power level of 88 dBA per fan;•elastomeric foam Class D mixed refrigerant compressor piping insulation;•

mixed refrigerant compressor blankets;•

steam turbine duct insulation D; and•heat recovery steam generators would be equipped with silencers to limit the soundpower level to a maximum of 115 dBA during blowdown events.

To ensure the above proposed and implemented mitigation measures reduce noise levels
from LNG Terminal operations, including flaring events, to an acceptable level, we recommend
that:

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No later than 60 days after placing Phase I into service, Plaquemines LNG should
file a full power load noise survey with the Secretary for the LNG terminal. If thenoise attributable to operation of the equipment at the LNG terminal exceeds an
Ldn of 55 dBA at the nearest NSA, within 60 days Plaquemines LNG should modify
operation of the liquefaction facilities or install additional noise controls until anoise level below an Ldn of 55 dBA at the NSA is achieved. Plaquemines LNG
should confirm compliance with the above requirement by filing a second noise
survey with the Secretary no later than 60 days after it installs the additional noise
controls.

We also recommend that:•

No later than 60 days after placing the entire LNG terminal into service,
Plaquemines LNG should file a noise survey with the Secretary. If a full loadcondition noise survey is not possible, Plaquemines LNG should provide aninterim survey at the maximum possible horsepower load within 60 days ofplacing the LNG terminal into service and provide the full load survey within 6months. If the noise attributable to operation of the equipment at the LNG
terminal exceeds an Ldn of 55 dBA at the nearest NSA under interim or fullhorsepower load conditions, Plaquemines LNG should file a report on whatchanges are needed and shall install the additional noise controls to meet the levelwithin 1 year of the in-service date. Plaquemines LNG should confirm compliancewith the above requirement by filing an additional noise survey with the Secretaryno later than 60 days after it installs the additional noise controls.

With implementation of these noise reducing mitigation efforts, we have determined that
operation of the LNG terminal would not exceed an Ldn 55.0 dBA at all NSAs. Nearby residents
would hear operational activities, especially flaring/venting events, but the overall impacts would
not be significant.
Pipeline System
The pipeline system would include new meter stations. There are no known NSAs or other
PNRs within 0.5 mile of the proposed meter station locations. Because noise related to themetering station would be limited to construction, it is unlikely that the existence of the newfacilities would markedly alter existing noise levels. Currently, Venture Global has not proposed
mitigation measures to reduce the potential of elevated noise levels resulting from new meterstation operation. Based on all available data, we do not anticipate an impact from elevated noiselevels from pipeline system operation on any NSAs.

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4.12

RELIABILITY AND SAFETY

4.12.1 LNG Terminal Reliability, Safety and Security Regulatory Oversight
LNG facilities handle flammable and sometimes toxic materials that can pose a risk to the
public if not properly managed. These risks are managed by the companies owning the facilities,
through selecting the site location and plant layout, as well as through suitable design, engineering,
construction, and operation of the LNG facilities. Multiple federal agencies share regulatory
authority over LNG facilities and the operator’s approach to risk management. The safety,
security, and reliability of Plaquemines LNG’s Project would be regulated by the DOT, USCG,
and FERC.
In February 2004, the DOT, the USCG, and FERC entered into an Interagency Agreement
to ensure greater coordination among these three agencies in addressing the full range of safety
and security issues at LNG terminals and LNG carrier vessel operations, and maximizing theexchange of information related to the safety and security aspects of LNG facilities and related
marine operations. Under the Interagency Agreement, FERC is the lead federal agency responsible
for the preparation of the analysis required under NEPA for impacts associated with terminal
construction and operation. The DOT and the USCG participate as cooperating agencies but
remain responsible for enforcing their regulations covering LNG facility siting, design,
construction, and operation. All three agencies have some oversight and responsibility for theinspection and compliance during the LNG facility’s operation.
The DOT establishes and has the authority to enforce the federal safety standards for thelocation, design, installation, construction, inspection, testing, operation, and maintenance ofonshore LNG facilities under the Federal Pipeline Safety Laws (49 U.S.C. 60101 et seq.). The
DOT’s LNG safety regulations are codified in 49 CFR 193, which prescribes safety standards for
LNG facilities used in the transportation of gas by pipeline that are subject to federal pipeline
safety laws (49 U.S.C. 60101 et seq.), and 49 CFR 192. On August 31, 2018, DOT and FERC
signed a Memorandum of Understanding (MOU) regarding methods to improve coordination
throughout the LNG permit application process for FERC jurisdictional LNG facilities. In the
MOU, DOT agreed to issue an LOD stating whether a proposed LNG facility would be capable ofcomplying with location criteria and design standards contained in Subpart B of Part 193. The
Commission committed to rely upon the DOT determination in conducting its review of whether
the facilities would be consistent with the public interest. The issuance of the LOD does not
abrogate DOT’s continuing authority and responsibility over a project’s compliance with Part 193
during construction and future operation of the facility. The DOT’s conclusion on the siting andhazard analysis required by Part 193 would be based on preliminary design information, which
may be revised as the engineering design progresses to final design. DOT regulations also containrequirements for the design, construction, installation, inspection, testing, operation, maintenance,
qualifications and training of personnel, fire protection, and security for LNG facilities, as definedby 49 CFR 193, which would be completed during later stages of the Project. If the Project isauthorized, constructed, and operated, the LNG facilities, as defined by 49 CFR 193, would be
subject to the DOT’s inspection and enforcement programs to ensure compliance with therequirements of 49 CFR 193.

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The USCG has authority over the safety of an LNG terminal’s marine transfer area and
LNG marine traffic, as well as over security plans for the waterfront facilities handling LNG and
LNG marine traffic. The USCG regulations for water front facilities handling LNG are codified
in 33 CFR 105 and 33 CFR 127. As a cooperating agency, the USCG assists FERC staff inevaluating whether an applicant’s proposed waterway would be suitable for LNG marine traffic
and whether the waterfront facilities handling LNG would be in accordance with 33 CFR 105 and33 CFR 127. If the facilities are constructed and become operational, the waterfront facilities
handling LNG would be subject to the USCG inspection program to ensure compliance with therequirements of 33 CFR 105 and 33 CFR 127.
FERC authorizes the siting and construction of LNG terminals under the NGA anddelegated authority from the DOE. FERC requires standard information to be submitted toperform safety and reliability engineering reviews. FERC’s filing regulations are codified in 18
CFR 380.12(m) and (o), and requires each applicant to identify how its proposed design would
comply with the DOT’s siting requirements of 49 CFR 193 Subpart B. The level of detailnecessary for this submittal requires the applicant to perform substantial front-end engineering of
the complete project. The design information is required to be site-specific and developed to theextent that further detailed design would not result in significant changes to the siting
considerations, basis of design, operating conditions, major equipment selections, equipment
design conditions, or safety system designs. As part of the review required for a FERC order, we
use this information from the applicant to assess whether the proposed facilities would have apublic safety impact and to suggest additional mitigations for the Commission to consider in theorder. If the facilities are approved and the mitigations are incorporated into the order as
conditions, FERC staff would review material filed to satisfy the conditions of the order andconduct periodic inspections throughout construction and operation.
In addition, the Energy Policy Act of 2005 requires FERC to coordinate and consult with
the DoD on the siting, construction, expansion, and operation of LNG terminals that would affectthe military. On November 21, 2007, FERC and the DoD (http://www.ferc.gov/legal/mou/moudod.pdf) entered into a MOU formalizing this process. In accordance with the MOU, FERC sent
a letter to the DoD on April 1, 2015, requesting their comments on whether the planned Project
could potentially have an impact on the test, training, or operational activities of any active military
installation. On June 4, 2018, FERC received a response letter from the DoD Siting Clearinghousestating that the Plaquemines LNG facility would have a minimal impact on military training andoperations conducted in the area.
4.12.2 DOT Safety Regulatory Requirements and 49 CFR 193 Subpart B Determination
Siting LNG facilities as defined in 49 CFR 193, with regard to ensuring that the proposedsite selection and location would not pose an unacceptable level or risk to public safety is required
by DOT’s regulations in 49 CFR 193, Subpart B. The Commission’s regulations under
18 CFR 380.12(o)(14) require Plaquemines LNG to identify how the proposed design complies
with the siting requirements in DOT’s regulations under 49 CFR 193, Subpart B. The scope of

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DOT’s siting authority under 49 CFR 193 applies to LNG facilities used in the transportation ofgas by pipeline subject to the federal pipeline safety laws and 49 CFR 192. 4
The regulations in 49 CFR 193, Subpart B require the establishment of an exclusion zone
surrounding an LNG facility in which an operator or government agency must exercise legal
control over the activities where specified levels of thermal radiation and flammable vapors may
occur in the event of a release for as long as the facility is in operation. Approved mathematicalmodels must be used to calculate the dimensions of these exclusion zones. The siting requirements
specified in NFPA 59A (2001), an industry consensus standard for LNG facilities, are incorporated
into 49 CFR 193, Subpart B by reference, with regulatory preemption in the event of conflict. The
following sections of 49 CFR193 Subpart B specifically address siting requirements:•

Section 193.2051, Scope, states that each LNG facility designed, replaced,
relocated or significantly altered after March 31, 2000, must be provided with siting
requirements in accordance with Subpart B and NFPA 59A (2001). In the event of
a conflict with NFPA 59A (2001), the regulatory requirements in Part 193 prevail.

•

Section 193.2057, Thermal radiation protection, requires that each LNG containerand LNG transfer system have thermal exclusion zones in accordance with section
2.2.3.2 of NFPA 59A (2001).

•

Section 193.2059, Flammable vapor-gas dispersion protection, requires that each
LNG container and LNG transfer system have a dispersion exclusion zone inaccordance with sections 2.2.3.3 and 2.2.3.4 of NFPA 59A (2001).

•

Section 193.2067, Wind forces, requires that shop fabricated containers of LNG orother hazardous fluids less than 70,000 gallons must be designed to withstand windforces based on the applicable wind load data in American Society of Civil
Engineers (ASCE) 7 (2005). All other LNG facilities must be designed for asustained wind velocity of not less than 150 mph unless the DOT Administrator
finds a lessor wind speed is justified or the most critical combination of windvelocity and duration for a 10,000-year mean return interval.

As stated in 49 CFR 193.2051, under Subpart B, LNG facilities must meet the siting
requirements of NFPA 59A (2001), Chapter 2, and include but may not be limited to:

4•

NFPA 59A (2001) section 2.1.1(c) requires consideration of protection against
forces of nature.

•

NFPA 59A (2001) section 2.1.1(d) requires that other factors applicable to thespecific site that have a bearing on the safety of plant personnel and surrounding
public be considered, including an evaluation of potential incidents and safetymeasures incorporated in the design or operation of the facility.

49 CFR 193.2001(b)(3), Scope of part, excludes any matter other than siting provisions pertaining to marine cargotransfer systems between the LNG carrier and the last manifold or valve immediately before a storage tank.

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NFPA 59A (2001) section 2.2.3.2 requires provisions to minimize the damaging
effects of fire from reaching beyond a property line, and requires provisions toprevent a radiant heat flux level of 1,600 British thermal units per square foot perhour (Btu/ft2-hr) from reaching beyond a property line that can be built upon. The
distance to this flux level is to be calculated with LNGFIRE3 or with models thathave been validated by experimental test data appropriate for the hazard to beevaluated and that have been approved by DOT.

•NFPA 59A (2001) 2.2.3.4 requires provisions to minimize the possibility of any
flammable mixture of vapors from a design spill from reaching a property line thatcan be built upon and that would result in a distinct hazard. Determination of the
distance that the flammable vapors extend is to be determined with DEGADIS orapproved alternative models that take into account physical factors influencing
LNG vapor dispersion. 5

Taken together, 49 CFR 193 Subpart B and NFPA 59A (2001) require that flammable LNG
vapors either from an LNG tank withdrawal impoundment or from a design spill do not extend
beyond areas in which the operator or a government agency legally controls all activities.
Furthermore, consideration of other hazards which may affect the public or plant personnel mustbe evaluated as prescribed in NFPA 59A (2001) section 2.1.1(d).
Title 49 CFR 193 Subpart B and NFPA 59A (2001) also specify three radiant heat flux
levels which must be considered for LNG storage tank spills for as long as the facility is inoperation:•

1,600 Btu/ft2-hr - This level can extend beyond the plant property line that can bebuilt upon but cannot include areas that are used for outdoor assembly by groupsof 50 or more persons; 6•3,000 Btu/ft2-hr - This level can extend beyond the plant property line that can bebuilt upon but cannot include areas that contain assembly, educational, health care,detention or residential buildings or structures; 7 andThe DOT has approved two additional models for the determination of vapor dispersion exclusion zones inaccordance with 49 CFR 193.2059: FLACS 9.1 Release 2 (Oct. 7, 2011) and PHAST-UDM Version 6.6 and 6.7(Oct. 7, 2011).
6
The 1,600 Btu/ft2-hr flux level is associated with producing pain in less than 15 seconds, first degree burns in 20
seconds, second degree burns in approximately 30-40 seconds, 1 percent mortality in approximately 120 seconds,
and 100 percent mortality in approximately 400 seconds, assuming no shielding from the heat, and is typically the
maximum allowable intensity for emergency operations with appropriate clothing based on average 10-minuteexposure.
7
The 3,000 Btu/ft2-hr flux level is associated with producing pain in less than 5 seconds, first degree burns in 5
seconds, second degree burns in approximately 10-15 seconds, 1 percent mortality in approximately 50 seconds,
and 100 percent mortality in approximately 180 seconds, assuming no shielding from the heat, and is typically thecritical heat flux for piloted ignition of common building materials (e.g., wood, PVC, fiberglass, etc.) withprolonged exposures.
5

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10,000 Btu/ft2-hr - This level cannot extend beyond the plant property line that canbe built upon. 8

The requirements for design spills from process or transfer areas are more stringent. For
LNG spills, the 1,600 Btu/ft2-hr flux level cannot extend beyond the plant property line onto a
property that can be built upon.
In addition, NFPA 59A (2001) section 2.1.1 requires that factors applicable to the specificsite with a bearing on the safety of plant personnel and surrounding public must be considered,including an evaluation of potential incidents and safety measures incorporated into the design or
operation of the facility. DOT has indicated that potential incidents, such as vapor cloud
explosions and toxic releases should be considered to comply with part 193 Subpart B. 9
In accordance with the August 31, 2018, MOU, DOT issued a LOD to FERC on the 49
CFR 193 Subpart B regulatory requirements. 10 The LOD provides PHMSA’s analysis andconclusions regarding 49 CFR 193, Subpart B regulatory compliance. Pursuant to the 2018 MOU,
the LOD is a consideration in the Commission’s decision to authorize, with or without
modification or conditions, or deny an application.
4.12.3 USCG Regulatory Requirements and Letter of Recommendation
4.12.3.1 LNG Carrier Historical Record
Since 1959, LNG carriers have transported LNG without a major release of cargo or amajor accident involving an LNG carrier. There are more than 370 LNG carriers in operation
routinely transporting LNG between more than 100 import/export terminals currently in operationworldwide. Since U.S. LNG terminals first began operating under FERC jurisdiction in the 1970s,
there have been thousands of individual LNG carrier arrivals at terminals in the U.S. For morethan 40 years, LNG carrier operations have been safely conducted in U.S. ports and waterways.
A review of the history of LNG maritime transportation indicates that there has not been aserious accident at sea or in a port which resulted in a spill due to rupturing of the cargo tanks.
However, insurance records, industry sources, and public websites identify a number of incidents
involving LNG carriers, including minor collisions with other vessels of all sizes, groundings,
minor LNG releases during cargo unloading operations, and mechanical/equipment failures typicalThe 10,000 Btu/ft2-hr flux level is associated with producing pain in less than 1 seconds, first degree burns in 1
seconds, second degree burns in approximately 3 seconds, 1 percent mortality in approximately 10 seconds, and100 percent mortality in approximately 35 seconds, assuming no shielding from the heat, and is typically thecritical heat flux for unpiloted ignition of common building materials (e.g., wood, PVC, fiberglass) anddegradation of unprotected process equipment after approximate 10 minute exposure and to reinforced concrete
after prolonged exposure.
9
The US DOT PHMSA’s “LNG Plant Requirements: Frequently Asked Questions” item H1,
https://www.phmsa.dot.gov/pipeline/liquified-natural-gas/lng-plant-requirements-frequently-asked-questions,accessed August 2018.
10
April 3, 2019 letter “Re: Plaquemines LNG Project, Docket No. CP17-66-000, 49 CFR Part 193, Subpart B,
Siting – Letter of Determination” from Alan K. Mayberry to Rich McGuire. Filed in Docket Number CP17-66000 on April 4, 2019. FERC eLibrary accession number 20190404-3002.
8

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of large vessels. Some of the more significant occurrences, representing the range of incidents
experienced by the worldwide LNG carrier fleet, are described below:•

El Paso Paul Kayser grounded on a rock in June 1979 in the Straits of Gibraltar during
a loaded voyage from Algeria to the United States. Extensive bottom damage to theballast tanks resulted; however, no cargo was released because no damage was done tothe cargo tanks. The entire cargo of LNG was subsequently transferred to another LNG
carrier and delivered to its U.S. destination.

•

Tellier was blown by severe winds from its docking berth at Skikda, Algeria in
February 1989 causing damage to the loading arms and the vessel and shore piping.
The cargo loading had been secured just before the wind struck, but the loading arms
had not been drained. Consequently, the LNG remaining in the loading arms spilled
onto the deck, causing fracture of some plating.

•

Mostefa Ben Boulaid had an electrical fire in the engine control room during
unloading at Everett, Massachusetts on February 5, 1996. The LNG carrier crew
extinguished the fire and the LNG carrier completed unloading.

•

Khannur had a cargo tank overfill into the vessel’s vapor handling system on
September 10, 2001, during unloading at Everett, Massachusetts. Approximately
100 gallons of LNG were vented and sprayed onto the protective decking over the
cargo tank dome, resulting in several cracks. After inspection by the USCG, theKhannur was allowed to discharge its LNG cargo.

•

Mostefa Ben Boulaid had LNG spill onto its deck during loading operations in Algeria
in 2002. The spill, which is believed to have been caused by overflow rather than amechanical failure, caused significant brittle fracturing of the steelwork. The vessel
was required to discharge its cargo, after which it proceeded to dock for repair.

•

Norman Lady was struck by the USS Oklahoma City nuclear submarine while thesubmarine was rising to periscope depth near the Strait of Gibraltar in November 2002.
The 87,000 m3 LNG carrier, which had just unloaded its cargo at Barcelona, Spain,
sustained only minor damage to the outer layer of its double hull but no damage to its
cargo tanks.

•

Tenaga Lima grounded on rocks while proceeding to open sea east of Mopko, South
Korea due to strong current in November 2004. The shell plating was torn open andfractured over an approximate area of 20 by 80 feet, and internal breaches allowed
water to enter the insulation space between the primary and secondary membranes.
The vessel was refloated, repaired, and returned to service.

•

Golar Freeze moved away from its docking berth during unloading on
March 14, 2006, in Savannah, Georgia. The powered emergency release couplings on
the unloading arms activated as designed, and transfer operations were shut down.

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Catalunya Spirit lost propulsion and became adrift 35 miles east of Chatham,
Massachusetts on February 11, 2008. Four tugs towed the vessel to a safe anchorage
for repairs. The Catalunya Spirit was repaired and taken to port to discharge its cargo.

•

Al Gharrafa collided with a container ship, Hanjin Italy, in the Malacca Strait off
Singapore on December 19, 2013. The bow of the Al Gharrafa and the middle of the
starboard side of the Hanjin were damaged. Both marine vessels were safely anchored
after the incident. No loss of LNG was reported.

•

Al Oraiq collided with a freight carrier, Flinterstar, near Zeebrugge, Belgium on
October 6, 2015. The freight carrier sank, but the Al Oraiq was reported to havesustained only minor damage to its bow and no damage to the LNG cargotanks. According to reports, the Al Oraiq took on a little water but was towed to the
Zeebrugge LNG terminal where its cargo was unloaded using normal procedures. No
loss of LNG was reported.

•

Al Khattiya suffered damage after a collision with an oil tanker off the Port of Fujairahon February 23, 2017. Al Khattiya had discharged its cargo and was anchored at thetime of the incident. A small amount of LNG was retained within the LNG carrier tokeep the cargo tanks cool. The collision damaged the hull and two ballast tanks on the
Al Khattiya, but did not cause any injury or water pollution. No loss of LNG wasreported.

•

Aseem collided with a very large crude carrier (VLCC) Shinyo Ocean off the Port ofFujairah on March 26, 2019. The VLCC suffered severe portside hull height breachand Aseem had damage to its bow. Both marine vessels were unloaded at the time of
the collision and subsequently no LNG or oil was released. Aseem was moved to port
for anchorage and Shinyo Ocean was relocated to another point of anchorage.

4.12.3.2 LNG Carrier Regulatory Oversight
The USCG exercises regulatory authority over LNG carriers under 46 CFR 154, whichcontains the United States safety standards for LNG carriers transporting bulk liquefied gases. The
LNG carriers visiting the facility would also be constructed and operated in accordance with the
IMO Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk and theInternational Convention for the Safety of Life at Sea. All LNG carriers entering U.S. waters are
required to possess a valid IMO Certificate of Fitness and either a USCG Certificate of Inspection(for U.S. flag marine vessels) or a USCG Certificate of Compliance (for foreign flag marine
vessels). These documents certify that the marine vessel is designed and operating in accordancewith both international standards and the U.S. regulations for bulk LNG carriers under Title 46
CFR 154.
The LNG carriers that would deliver or receive LNG to or from the facility would alsoneed to comply with various U.S. and international security requirements. The IMO adopted theInternational Ship and Port Facility Security Code in 2002. This code requires both marine vessels
and ports to conduct vulnerability assessments and to develop security plans. The purpose of thecode is to prevent and suppress terrorism against marine vessels; improve security aboard marine
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vessels and ashore; and reduce the risk to passengers, crew, and port personnel on board marine
vessels and in port areas. All LNG carriers, as well as other cargo marine vessels 500 gross tons
and larger, and ports servicing those regulated marine vessels, must adhere to the IMO standards.
Some of the IMO requirements for marine vessels are as follows:•marine vessels must develop security plans and have a Vessel Security Officer;•

marine vessels must have a ship security alert system. These alarms transmit ship-toshore security alerts identifying the marine vessel, its location, and indication that the
security of the marine vessel is under threat or has been compromised;•marine vessels must have a comprehensive security plan for international port facilities,
focusing on areas having direct contact with marine vessels; and•marine vessels may have equipment onboard to help maintain or enhance the physicalsecurity of the marine vessel.

In 2002, the MTSA was enacted by the U.S. Congress and aligned domestic regulations
with the maritime security standards of the International Ship and Port Facility Security Code andthe Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk and theInternational Convention for the Safety of Life at Sea. The USCG’s regulations in 33 CFR 104,
require marine vessels to conduct a vessel security assessment and develop a vessel security planthat addresses each vulnerability identified in the vessel security assessments. All LNG carriers
servicing the facility would have to comply with the MTSA requirements and associatedregulations while in U.S. waters.
The USCG also exercises regulatory authority over LNG facilities that affect the safety andsecurity of port areas and navigable waterways under Executive Order 10173; the Magnuson Act(50 U.S.C. Section 191); the Ports and Waterways Safety Act of 1972, as amended (33 U.S.C.
Section 1221, et seq.); and the MTSA of 2002 (46 U.S.C. Section 701). The USCG is responsible
for matters related to navigation safety, LNG carrier engineering and safety standards, and all
matters pertaining to the safety of facilities or equipment located in or adjacent to navigable waters
up to the last valve immediately before the receiving tanks. The USCG also has authority for LNG
facility security plan review, approval, and compliance verification as provided in 33 CFR 105.
The USCG regulations in 33 CFR 127 apply to the marine transfer area of waterfront
facilities between the LNG carrier and the last manifold or valve immediately before the receivingtanks. 33 CFR 127 applies to the marine transfer area for LNG of each new waterfront facility
handling LNG and to new construction in the marine transfer areas for LNG of each existingwaterfront facility handling LNG. The scope of the regulations includes the design, construction,equipment, operations, inspections, maintenance, testing, personnel training, firefighting, andsecurity of the marine transfer area of LNG waterfront facilities. The safety systems, including
communications, emergency shutdown, gas detection, and fire protection, must comply with theregulations in 33 CFR 127. Under 33 CFR 127.019, Plaquemines LNG would be required tosubmit two copies of its Operations and Emergency Manuals to the USCG Captain of the Port
(COTP) for examination.

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Both the USCG regulations under 33 CFR 127 and FERC regulations under 18 CFR
157.21, require an applicant who intends to build an LNG terminal facility to submit a Letter ofIntent (LOI) to the USCG no later than the date that the owner/operator initiates pre-filing with
FERC, but, in all cases, at least 1 year prior to the start of construction. In addition, the applicant
must submit a Preliminary WSA to the COTP with the LOI.
The Preliminary WSA provides an initial explanation of the port community and thefacility and transit routes. It provides an overview of the expected impacts LNG operations may
have on the port and the waterway. Generally, the Preliminary WSA does not contain detailed
studies or conclusions. This document is used by the COTP to begin his or her evaluation of thesuitability of the waterway for LNG marine traffic. The Preliminary WSA must provide an initial
explanation of the following•

port characterization;•

characterization of the LNG facility and the LNG carrier route;•risk assessment for maritime safety and security;•

risk management strategies; and•resource needs for maritime safety, security, and response.

A Follow-On WSA must be provided no later than the date the owner/operator files anapplication with FERC, but in all cases at least 180 days prior to transferring LNG. The Followon WSA must provide a detailed and accurate characterization of the waterfront facilities handling
LNG, the LNG carrier route, and the port area. The Follow-on WSA provides a complete analysisof the topics outlined in the Preliminary WSA. It should identify credible security threats andnavigational safety hazards for the LNG marine traffic, along with appropriate risk management
measures and the resources (i.e., federal, state, local, and private sector) needed to carry out thosemeasures. Until a facility begins operation, applicants must also annually review their WSAs andsubmit a report to the COTP as to whether changes are required. This document is reviewed andvalidated by the USCG and forms the basis for the agency’s LOR to FERC.
In order to provide the USCG COTPs/Federal Maritime Security Coordinators, membersof the LNG industry, and port stakeholders with guidance on assessing the suitability of a waterway
for LNG marine traffic, the USCG has published a Navigation and Vessel Inspection Circular –Guidance on Assessing the Suitability of a Waterway for Liquefied Natural Gas (LNG) Marine
Traffic (NVIC 01-11).
NVIC 01-11 directs the use of the three concentric Zones of Concern, based on LNG
carriers with a cargo carrying capacity up to 265,000 m³, used to assess the maritime safety andsecurity risks of LNG marine traffic. The Zones of Concern are:•Zone 1 – impacts on structures and organisms are expected to be significant within
500 meters (1,640 feet). The outer perimeter of Zone 1 is approximately the distanceto thermal hazards of 37.5 kW/m2 (12,000 Btu/ft2-hr) from a pool fire.

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•

Zone 2 – impacts would be significant but reduced, and damage from radiant heat levels
are expected to transition from severe to minimal between 500 and 1,600 meters(1,640 and 5,250 feet). The outer perimeter of Zone 2 is approximately the distance tothermal hazards of 5 kW/m2 (1,600 Btu/ft2-hr) from a pool fire.

•

Zone 3 – impacts on people and property from a pool fire or an un-ignited LNG spill
are expected to be minimal between 1,600 meters (5,250 feet) and a conservative
maximum distance of 3,500 meters (11,500 feet or 2.2 miles). The outer perimeter ofZone 3 should be considered the vapor cloud dispersion distance to the lower
flammability limit from a worst-case un-ignited release. Impacts on people andproperty could be significant if the vapor cloud reaches an ignition source and burns
back to the source.

Once the applicant submits a complete Follow-On WSA, the USCG reviews the document
to determine if it presents a realistic and credible analysis of the public safety and security
implications from LNG marine traffic both in the waterway and when in port.
As required by its regulations (33 CFR 127.009), the USCG is responsible for issuing a
LOR to FERC regarding the suitability of the waterway for LNG marine traffic with respect to thefollowing items:•

physical location and description of the facility;•

the LNG carrier’s characteristics and the frequency of LNG shipments to or from thefacility;•waterway channels and commercial, industrial, environmentally sensitive, andresidential areas in and adjacent to the waterway used by LNG carriers en route to thefacility, within 25 kilometers (15.5 miles) of the facility;•

density and character of marine traffic in the waterway;•

locks, bridges, or other manmade obstructions in the waterway;•

depth of water;•

tidal range;•

protection from high seas;•

natural hazards, including reefs, rocks, and sandbars;•

underwater pipes and cables; and•distance of berthed LNG carriers from the channel and the width of the channel.

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The USCG may also prepare an LOR Analysis, which serves as a record of review of the
LOR and contains detailed information along with the rationale used in assessing the suitability of
the waterway for LNG marine traffic.
4.12.3.3 Plaquemines LNG’s Waterway Suitability Assessment
On June 17, 2015, Plaquemines LNG submitted a Letter of Intent to the COTP, Sector New
Orleans to notify the USCG that it proposed to construct an LNG export terminal. On June 18,
2015, Plaquemines LNG submitted a Preliminary WSA to the COTP, Sector New Orleans. In thedevelopment of the Follow-On WSA, Plaquemines LNG consulted with the USCG and port
stakeholders. Plaquemines LNG submitted the Follow-On WSA to the USCG on May 12, 2016.
4.12.3.4 LNG Carrier Routes and Hazard Analysis
As described in Plaquemines LNG’s WSAs, an LNG carrier’s transit to the terminal would
begin in the Gulf of Mexico. The LNG carrier would travel approximately 90 miles in the Gulf of
Mexico and the Lower Mississippi River to the LNG terminal. LNG carriers would return to sea
by reversing their travel. Pilotage is compulsory for foreign marine vessels and U.S. marine
vessels under registry in foreign trade when in U.S. waters. All deep draft marine vessels currently
entering the waterway would employ a U.S. pilot. The National Vessel Movement Center in the
U.S. would require a 96-hour advance notice of arrival for deep draft marine vessels calling on
U.S. ports. During transit, LNG carriers would be required to maintain voice contact with
controllers and check in on designated frequencies at established way points.
The transit of an LNG carrier from the Gulf of Mexico up the Lower Mississippi River tothe LNG terminal would be approximately 90 miles. Pilots would board the LNG carrier and be
responsible for the passage of the LNG carrier throughout its entire transit. During the transit, theLNG carrier would pass by the towns and incorporated areas of Pilottown, Venice, BoothvilleVenice, Triumph, Buras, Empire, Port Sulphur, Bohemia, Pointe a la Heche, and Davant. The
LNG carrier would also pass by several schools during its transit to the LNG terminal: the South
Plaquemines High School, the South Plaquemines Elementary School, the McBride School, andthe Saint Jude School.
NVIC 01-11 references the “Zones of Concern” for assisting in a risk assessment of thewaterway. As LNG carriers proceed along the intended transit route, Hazard Zone 1 would
encompass coastal areas along the Mississippi Delta, up through Port Sulphur, Bohemia, andDavant. Hazard Zone 2 would encompass a wider swath of coastal areas along the Mississippi
Delta, up through Port Sulphur, Bohemia, and Davant. Hazard Zone 3 would encompass an evenlarger portions coastal areas along the Mississippi Delta, up through Port Sulphur, Bohemia, andDavant.
The areas impacted by the three different hazard zones are illustrated for both accidental
and intentional events in figures 4.12-1 and 4.12-2, respectively.
4.12.3.5 Coast Guard Letter of Recommendation and Analysis
In a letter dated January 23, 2017, the USCG issued an LOR to FERC stating that the Lower
Mississippi River be considered suitable for accommodating the type and frequency of LNG
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marine traffic associated with this Project. The recommendation was based on full implementationof the strategies and risk management measures identified to the USCG by Plaquemines LNG in
its WSA.
Although Plaquemines LNG has suggested mitigation measures for responsibly managing
the maritime safety and security risks associated with LNG marine traffic, the necessary marine
vessel traffic and/or facility control measures may change depending on changes in conditions
along the waterway. The USCG regulations in 33 CFR 127 require that applicants annually review
WSAs until a facility begins operation. Accordingly, Plaquemines LNG is required to submit areport to the USCG identifying any changes in conditions, such as changes to the port environment,
the LNG facility, or the LNG carrier route, that would affect the suitability of the waterway.
Accordingly, Plaquemines LNG submitted its annual WSA update on January 23, 2018 and the
USCG responded on March 5, 2018, stating the annual review met the requirements of 33 CFR
127.007(h)(1).
The USCG’s LOR is a recommendation, regarding the current status of the waterway, toFERC, the lead agency responsible for siting the on-shore LNG facility. Neither the USCG nor
FERC has authority to require waterway resources of anyone other than the applicant under any
statutory authority or under the Emergency Response Plan (ERP) or the Cost Sharing Plan. As
stated in the LOR, the USCG would assess each transit on a case-by-case basis to identify what, if
any, safety and security measures are necessary to safeguard the public health and welfare, criticalinfrastructure and key resources, the port, the marine environment, and the LNG carrier.

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Venture Global
Plaquemines
LNG Terminal

Accidental Sandia "Zone of Concern 1" (0 - 250m)

Accidental Sandia "Zone of Concern 2" (250 - 750m)

Accidental Sandia "Zone of Concern 3" (750 - 1700m)

Figure 4.12-1
Accidental Sandia"Zones of Concern"
Along LNG Transit Route

Plaquemines Parish,
Louisiana

0

2.5

5

10 Miles

Source: DigitalGlobe 2017, USGS 2018

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Venture Global
Plaquemines
LNG Terminal

Intentional Sandia "Zone of Concern 1" (0 - 500m)

Intentional Sandia "Zone of Concern 2" (500 - 1600m)

Intentional Sandia "Zone of Concern 3" (1600 - 3500m)

Figure 4.12-2
Intentional Sandia"Zones of Concern"
Along LNG Transit Route

Plaquemines Parish,
Louisiana

0

2.5

5

10 Miles

Source: DigitalGlobe 2017, USGS 2018

Under the Ports and Waterways Safety Act, the Magnuson Act, the MTSA, and the Security
and Accountability for Every Port Act, the COTP has the authority to prohibit LNG transfer or
LNG carrier movements within his or her area of responsibility if he or she determines that suchaction is necessary to protect the waterway, port, or marine environment. If this Project isapproved and if appropriate resources are not in place prior to LNG carrier movement along thewaterway, then the COTP would consider at that time what, if any, marine vessel traffic and/or
facility control measures would be appropriate to adequately address navigational safety andmaritime security considerations.
4.12.3.6 LNG Terminal Security Regulatory Requirements
The security requirements for the proposed Project are governed by 33 CFR 105, 33 CFR
127, and 49 CFR 193 Subpart J. Title 33 CFR 105, as authorized by the Marine Transportation
Security Act, requires all terminal owners and operators to submit a Facility Security Assessment(FSA) and a Facility Security Plan (FSP) to the USCG for review and approval before
commencement of operations of the proposed Project facilities. Plaquemines LNG would also be
required to control and restrict access, patrol and monitor the plant, detect unauthorized access,and respond to security threats or breaches under 33 CFR 105. Some of the responsibilities of theapplicant include, but are not limited to:•designating a Facility Security Officer with a general knowledge of current security
threats and patterns, security assessment methodology, LNG carrier and facility
operations, conditions, security measures, emergency preparedness, response, andcontingency plans, who would be responsible for implementing the FSA and FSP and
performing an annual audit for the life of the Project;•conducting a FSA to identify site vulnerabilities, possible security threats andconsequences of an attack, and facility protective measures; developing a FSP basedon the FSA, with procedures for: responding to transportation security incidents;
notification and coordination with federal, state, and local authorities; prevention ofunauthorized access; measures to prevent or deter entrance with dangerous substancesor devices; training; and evacuation;•

defining the security organizational structure with facility personnel with knowledge
or training in current security threats and patterns; recognition and detection ofdangerous substances and devices, recognition of characteristics and behavioral
patterns of persons who are likely to threaten security; techniques to circumvent
security measures; emergency procedures and contingency plans; operation, testing,calibration, and maintenance of security equipment; and inspection, control,
monitoring, and screening techniques;•

implementing scalable security measures to provide increasing levels of security at
increasing maritime security levels for facility access control, restricted areas, cargohandling, LNG carrier stores and bunkers, and monitoring; ensuring that the TWIC
program is properly implemented;

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•

ensuring coordination of shore leave for LNG carrier personnel or crew change out aswell as access through the facility for visitors to the LNG carrier;•conducting drills and exercises to test the proficiency of security and facility personnel
on a quarterly and annual basis; and•reporting all breaches of security and transportation security incidents to the National
Response Center.

Title 33 CFR 127 has requirements for access controls, lighting, security systems, security
personnel, protective enclosures, communications, and emergency power. In addition, an LNG
facility regulated under 33 CFR 105 and 33 CFR 127 would be subject to the Transportation
Worker Identification Credential (TWIC) Reader Requirements Rule issued by the USCG on
August 23, 2016. This rule requires owners and operators of certain marine vessels and facilities
regulated by the USCG to conduct electronic inspections of TWICs (e.g., readers with biometricfingerprint authentication) as an access control measure. The final rule would also include
recordkeeping requirements and security plan amendments that would incorporate these TWIC
requirements. The implementation of the rule was first proposed to be in effect August 23,
2018. In a subsequent notice issued on June 22, 2018, USCG indicated delaying the effective date
for certain facilities by 3 years, until August 23, 2021. On August 2, 2018, the President of theUnited States signed into law the Transportation Worker Identification Credential Accountability
Act of 2018 (H.R. 5729). This law prohibits the USCG from implementing the rule requiring
electronic inspections of TWICs until after the Department of Homeland Security has submitted areport to the Congress. Although the implementation of this rule has been postponed, the company
may need to consider the rule when developing access control and security plan provisions for thefacility.
Title 49 CFR 193 Subpart J also specifies security requirements for the onshore componentof LNG facilities, as defined in 49 CFR 193, including requirements for conducting security
inspections and patrols, liaison with local law enforcement officials, design and construction ofprotective enclosures, lighting, monitoring, alternative power sources, and warning signs.
If the Project is authorized, constructed and operated, compliance with the security
requirements of 33 CFR 105, 33 CFR 127, and 49 CFR 193, Subpart J would be subject to therespective USCG and DOT inspection and enforcement programs.
Plaquemines LNG provided preliminary information on these security features andindicated additional details would be completed in the final design. We recommend in section
4.12.5 that Plaquemines LNG provide final details on these security features for review andapproval, including: provide drawings and simulations that demonstrate lighting adequately cover
the perimeter and interior of the site, in accordance with API 540, including in liquefaction blocks,
oily water treatment plant area, exterior of buildings, and along paths/roads of access and egress;
provide drawings that demonstrate cameras adequately cover interior of plant, including a camera
be provided at the top of each LNG storage tank; provide drawings that demonstrate fencing or
equivalent barrier would restrict and deter access at the road crossing and is set back from exterior
power lines and trees and from interior hazardous piping and equipment by at least 10 feet; provide
drawings and specifications of vehicle barrier at controlled access points; and provide additional
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details on these security features and others in final design for review and approval. In accordancewith the February 2004 Interagency Agreement among FERC, DOT, and USCG, FERC staff
would collaborate with USCG and DOT on the Project’s security features.
4.12.4 FERC Engineering and Technical Review of the Preliminary Engineering Designs
4.12.4.1 LNG Facility Historical Record
The operating history of the U.S. LNG industry has been free of safety-related incidents
resulting in adverse effects on the public or the environment with the exception of the October 20,
1944, failure at an LNG plant in Cleveland, Ohio. The 1944 incident in Cleveland led to a fire thatkilled 128 people and injured 200 to 400 more people. 11 The failure of the LNG storage tank was
due to the use of materials not suited for cryogenic temperatures. LNG migrated through streets
and into underground sewers due to inadequate spill impoundments at the site. Current regulatory
requirements ensure that proper materials suited for cryogenic temperatures are used in the design
and that spill impoundments are designed and constructed properly to contain a spill at the site.
To ensure that this potential hazard would be addressed for LNG facilities, we also evaluate thepreliminary and final specifications for suitable materials of construction and for the spillcontainment systems that would properly contain a spill at the site.
Another operational accident occurred in 1979 at the Cove Point LNG plant in Lusby,
Maryland. A pump electrical seal located on a submerged electrical motor LNG pump leak causing
flammable gas vapors to enter an electrical conduit and settle in a confined space. When a worker
switched off a circuit breaker, the flammable gas ignited, causing severe damage to the building
and a worker fatality. With the participation of FERC, lessons learned from the 1979 Cove Point
accident led to changes in the national fire codes to better ensure that the situation would not occur
again. To ensure that this potential hazard would be addressed for facilities that have electricalseal interfaces, we evaluated the preliminary designs and recommend in section 4.12.5 that
Plaquemines LNG provide, for review and approval, the final design details of the electrical seal
design at the interface between flammable fluids and the electrical conduit or wiring system, detailsof the electrical seal leak detection system and the details of a downstream physical break (i.e., airgap) in the electrical conduit to prevent the migration of flammable vapors.
On January 19, 2004, a blast occurred at Sonatrach’s Skikda, Algeria, LNG liquefaction
plant that killed 27 and injured 56 workers. No members of the public were injured. Findings ofthe accident investigation suggested that a cold hydrocarbon leak occurred at Liquefaction Train
40 and was introduced into a high-pressure steam boiler by the combustion air fan. An explosion
developed inside the boiler firebox, which subsequently triggered a larger explosion of thehydrocarbon vapors in the immediate vicinity. The resulting fire damaged the adjacentliquefaction process and liquid petroleum gas separation equipment of Train 40, and spread toTrains 20 and 30. Although Trains 10, 20, and 30 had been modernized in 1998 and 1999, Train
40 had been operating with its original equipment since start-up in 1981. To ensure that thispotential hazard would be addressed for the LNG terminal, we evaluated the preliminary designfor mitigation of flammable vapor dispersion and ignition in buildings and combustion equipment
11

For a description of the incident and the findings of the investigation, see “U.S. Bureau of Mines, Report on theInvestigation of the Fire at the Liquefaction, Storage, and Regasification Plant of the East Ohio Gas Co.,
Cleveland, Ohio, October 20, 1944,” dated February 1946.

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to ensure they would be adequately covered by hazard detection equipment that could isolate anddeactivate any combustion equipment whose continued operation could add to or sustain an
emergency. We also recommend in section 4.12.5 that Plaquemines LNG provide, for review andapproval, the final design details of hazard detection equipment, including the location andelevation of all detection equipment, instrument tag numbers, type and location, alarm indication
locations, and shutdown functions of the hazard detection equipment.
On March 31, 2014, a detonation occurred within a gas heater at Northwest Pipeline
Corporation’s LNG peak-shaving plant in Plymouth, Washington. 12 This internal detonation
subsequently caused the failure of pressurized equipment, resulting in high velocity projectiles.
The plant was immediately shut down, and emergency procedures were activated, which included
notifying local authorities and evacuating all plant personnel. No members of the public were
injured, but one worker was sent to the hospital for injuries. As a result of the incident, theliquefaction trains and a compressor station located onsite were rendered inoperable. Projectiles
from the incident also damaged the control building that was located near pre-treatment facilities
and penetrated the outer shell of one of the single containment LNG storage tanks. All damaged
facilities were ultimately taken out of service for repair. The accident investigation showed thatan inadequate purge after maintenance activities resulted in a fuel-air mixture remaining in thesystem. The fuel-air mixture auto-ignited during startup after it passed through the gas heater atfull operating pressure and temperature. To ensure that this potential hazard would be addressed,
we recommend in section 4.12.5 that Plaquemines LNG provide a plan for purging, for review andapproval, which addresses the requirements of the American Gas Association Purging Principles
and Practice and to provide justification if not using an inert or non-flammable gas for purging.
In evaluating such plans, we would assess whether the purging could be done safely based onreview of other plans and lessons learned from this and other past incidents. If a plan proposes theuse of flammable mediums for cleaning, dry-out or other activities, we would evaluate the plans
against other recommended and generally accepted good engineering practices, such as NFPA 56,
Standard for Fire and Explosion Prevention during Cleaning and Purging of Flammable Gas
Piping Systems. We also recommend in section 4.12.5 that Plaquemines LNG provide, for review
and approval, its operating and maintenance plans, including safety procedures, prior tocommissioning. In evaluating such plans, we would assess whether the plans cover all standard
operations, including purging activities associated with startup and shutdown. Also, in order toprevent other sources of projectiles from affecting occupied buildings and storage tanks, werecommend in section 4.12.5 that Plaquemines LNG incorporate mitigation into their final design
with supportive information, for review and approval, that demonstrates it would mitigate the riskof a pressure vessel burst or boiling liquid expanding vapor explosion (BLEVE) from occurring.
4.12.4.2 FERC Preliminary Engineering Review
FERC requires an applicant to provide safety, reliability, and engineering design
information as part of its application, including hazard identification studies and front-endengineering-design (FEED) information for its Project. FERC staff evaluates this information witha focus on potential hazards from within and nearby the site, including external events, which may
have the potential to cause damage or failure to the Project facilities, and the engineering design
12

For a description of the incident and the findings of the investigation, see Root Cause Failure Analysis, Plymouth
LNG Plant Incident Investigation under CP14-515.

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and safety and reliability concepts of the various protection layers to mitigate the risks of potential
hazards.
The primary concerns are those events that could lead to a hazardous release of sufficientmagnitude to create an offsite hazard or interruption of service. Furthermore, the potential hazards
are dictated by the site location and the engineering details. In general, we consider an acceptable
design to include various layers of protection or safeguards to reduce the risk of a potentiallyhazardous scenario from developing into an event that could impact the offsite public. Theselayers of protection are generally independent of one another so that any one layer would perform
its function regardless of the initiating event or action, or failure of any other protection layer.
Such design features and safeguards typically include:•

A facility design that prevents hazardous events, including the use of inherently safer
designs; suitable materials of construction; adequate design margins from operating
limits for process piping, process vessels, and storage tanks; adequate design for wind,flood, seismic, and other outside hazards;•

Control systems, including monitoring systems and process alarms, remotely-operated
control and isolation valves, and operating procedures to ensure that the facility stays
within the established operating and design limits;•

Safety instrumented prevention systems, such as safety control valves and emergency
shutdown systems, to prevent a release if operating and design limits are exceeded;•

Physical protection systems, such as appropriate electrical area classification, proper
equipment and building spacing, pressure relief valves, spill containment, andcryogenic, overpressure, and fire structural protection, to prevent escalation to a more
severe event;•

Site security measures for controlling access to the plant, including security inspections
and patrols, response procedures to any breach of security, and liaison with local law
enforcement officials; and•Onsite and offsite emergency response, including hazard detection and control
equipment, firewater systems, and coordination with local first responders, to mitigate
the consequences of a release and prevent it from escalating to an event that could
impact the public.

The inclusion of such protection systems or safeguards in a plant design can minimize thepotential for an initiating event to develop into an incident that could impact the safety of the offsite
public. The review of the engineering design for these layers of protection are initiated in theapplication process and carried through to the next phase of the Project in final design if
authorization is granted by the Commission.
The reliability of these layers of protection are informed by occurrence and likelihood ofroot causes of past incidents and the potential severity of consequences based on past incidents
and validated hazard modeling. As a result of a preliminary engineering review, FERC staff

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recommend mitigation measures and continuous oversight to the Commission for consideration to
include as requirements in the order. If a facility is authorized and recommendations are adopted
as conditions to the order, FERC staff will continue its engineering review through final design,
construction, and operation.
4.12.4.3 Process Design
In order to liquefy natural gas, most liquefaction technologies require that the feed gas
stream be pre-treated to remove components that could freeze out and clog the liquefaction
equipment or would otherwise be incompatible with the liquefaction process or equipment,
including H2S, CO2, water, and heavy hydrocarbons. Most other designs would also propose amercury removal system to safeguard their equipment and reduce the likelihood of potential lossesof containment because mercury can react with damaging effects with downstream aluminum heatexchangers. While Plaquemines LNG expects the feed gas to be mercury free and mercury
concentrations have been generally low in the U.S., mercury concentrations can still exceed typical
specified mercury concentration limits for liquefaction facilities and no specific tests for mercury
have been carried out to support that mercury does not currently exist in their proposed feed gas
sources. Plaquemines LNG proposes to provide space and connections for a future mercury
removal unit. To ensure these provisions are provided and feed gas mercury concentrations aremonitored, we recommend in section 4.12.5 that Plaquemines LNG provide a means to limit
mercury concentrations to less than 0.01 micrograms per normal cubic meter or alternatively
provide monitoring for mercury by means of an analyzer, sample connection, or preventative
maintenance inspections of the heat exchangers with provisions for a mercury removal package.
The inlet gas would be conditioned to remove solids and water droplets prior to entering
feed gas pretreatment processes. Once the inlet gas is conditioned, the feed gas would enter aknockout (KO) drum before flowing to a booster compressor. If the inlet gas pressure is sufficient,
the booster compressor would be bypassed and the feed gas would flow through a feed gas heater
to ensure the feed gas is an appropriate temperature prior to entering the non-regenerative H2S
removal beds to remove most of the H2S. The feed gas would then contact an amine-based solvent
solution in the acid gas absorber column to remove acid gas (i.e., CO2 and trace amounts of H2S
carried over from the H2S removal beds). Once the acid gas components accumulate in the amine
solution, it is routed to an amine regenerator column that utilizes a reboiler to create hot amine
vapor. Contact with the hot amine vapor would release the acid gas from the amine solution. The
regenerated amine solution would be recycled back to the acid gas absorber column and theremoved acid gas would be sent to a thermal oxidizer, where CO2, trace amounts of H2S, and trace
amounts of hydrocarbons would be incinerated. The treated feed gas exiting the acid gas absorbercolumn then enters the dehydration unit where a dryer inlet separator would recover bulk waterand recycle it to the acid gas absorber column. After the dryer inlet separator, any remaining waterin the feed gas would be removed in regenerative molecular sieve beds. During the molecularsieve bed regeneration process, heated regeneration gas would remove water from the molecularsieve beds. Water would then be separated from the regeneration gas and would be routed to theacid gas absorber column. The treated gas would then flow to the liquefaction unit.
The Project proposes to install 36 liquefaction trains (2 trains per liquefaction block), eachconsisting of a brazed aluminum heat exchanger (BAHX). Heavy hydrocarbon removal would be
integrated into the liquefaction process. In the initial BAHX pass, the treated feed gas would be
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precooled and would flow into a separator to remove the liquids. The vapor portion from theseparator would reenter the BAHX and would be desuperheated, condensed, and sub-cooled into
LNG. The liquid portion from the separator would flow into the debutanizer to further separate
the condensate product (C4+) from the lighter hydrocarbons. The liquid condensate product within
the debutanizer would be sent to the condensate system and the lighter hydrocarbons would be
returned to the BAHX where it would also be desuperheated, condensed, and sub-cooled into LNG.
The condensate product would be sent to the condensate surge drum where the condensate vapors
would be directed to the hot oil furnace fuel gas system and the condensate liquids would bevaporized and directed into the hot oil furnace fuel gas system. The LNG exiting the BAHX would
flow to the LNG flash vessel before being routed to the LNG storage tanks. In order to achieve
the cryogenic temperatures needed to liquefy the natural gas stream in the above process, the gas
would be cooled by a thermal exchange process driven by a single mixed refrigerant process
comprised of a mixture of nitrogen, methane, ethylene, propane, and i-pentane. Methane would
be provided from the BOG system and the other refrigerants required for the liquefaction process
would be delivered as a liquid by truck and stored onsite for initial filling and use, as needed, formake-up.
After cooling the natural gas into its liquid form, LNG would be routed to and stored infour full-containment LNG storage tanks. During export operations, LNG stored within the LNG
storage tanks would be sent out through multiple in-tank pumps (the pump discharge piping would
penetrate through the roof and is an inherently safer design when compared to penetrating the sideof an LNG storage tank). The LNG would flow through a marine transfer line and multiple liquidmarine transfer arms connected to a LNG carrier. In order to keep the marine transfer line cold
between LNG export cargoes, a recirculation line would be provided so that the marine transfer
line would not have to be cooled down prior to every LNG carrier loading operation. The LNG
transferred to the LNG carriers would displace vapors from the LNG carriers, which would be sent
back through a vapor marine transfer arm and vapor return line to the BOG header. Once loaded,the LNG carrier would be disconnected and leave for export.
Low pressure BOG generated from stored LNG (LNG is continuously boiling) as well asvapors returned during LNG carrier filling operations would be compressed and be routed to thefuel gas system. The closed BOG system would prevent the release of BOG to the atmosphere
and would be in accordance with NFPA 59A. This would be an inherently safer design whencompared to allowing the BOG to vent to the atmosphere.
In addition, the Project would include many utilities and associated auxiliary equipment.
The major auxiliary systems required for the operation of the liquefaction facility include fuel gas,
hot oil, flares, instrument and utility air, water, demineralized water, steam, nitrogen, and power
generation. Hot oil would be used to provide the heat to the inlet feed gas heater, amine regenerator
reboilers, regeneration gas heaters, debutanizer reboilers, condensate vaporizers, and fuel gas
heaters. There would be three flare systems: warm (wet), cold (dry), and low pressure flares.
Each system would be routed to a separate flare stack and would be designed to handle the ventgases from the process areas. Diesel would be stored in a dedicated tank to supply the backup
power generators as well as in double walled daytanks for each diesel firewater pump. Gas turbine
generators would provide electric power to the site. In addition, aqueous ammonia would be usedin the selective catalytic removal process to reduce the NOx emissions created during power

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generation. Liquid nitrogen vaporizers would be used to supply gaseous nitrogen for various usesin the plant including pre-commissioning, start-up, and refrigerant make-up.
The failure of process equipment could pose potential harm if not properly safeguarded
through the use of appropriate engineering controls and operation. Plaquemines LNG would
install process control valves and instrumentation to safely operate and monitor the facilities.
Alarms would have visual and audible notification in the control room to warn operators thatprocess conditions may be approaching design limits. We recommend Plaquemines LNG design
their control systems and human machine interfaces to the International Society for Automation(ISA) Standards 5.3, 5.5, 60.1, 60.3, 60.4, and 60.6, and other standards and recommended
practices. We recommend in section 4.12.5 that Plaquemines LNG develop and implement an
alarm management program, for review and approval to ensure the effectiveness of the alarms.
FERC staff will evaluate the alarm management program against recommended and generally
accepted good engineering practices, such as ISA Standard 18.2.
Operators would have the capability to take action from the control room to mitigate an
upset. Plaquemines LNG would develop facility operation procedures after completion of the final
design; this timing is fully consistent with accepted industry practice. We recommend in section
4.12.5 that Plaquemines LNG provide more information, for review and approval, on the operating
and maintenance procedures, including safety procedures, hot work procedures and permits,
abnormal operating conditions procedures, and personnel training prior to commissioning. We
will evaluate these procedures to ensure that an operator can operate and maintain all systems
safely, based on benchmarking against other operating and maintenance plans and comparing
against recommended and generally accepted good engineering practices, such as American
Institute of Chemical Engineers (AIChE) Center for Chemical Process Safety (CCPS), Guidelines
for Writing Effective Operating and Maintenance Procedures, AIChE CCPS Guidelines forManagement of Change for Process Safety, AIChE CCPS, Guidelines for Effective Pre-Startup
Safety Reviews, AGA, Purging Principles and Practices, and NFPA 51B, Standard for Fire
Prevention During Welding, Cutting, and Other Hot Work.. In addition, we recommend in section
4.12.5 that Plaquemines LNG tag and label instrumentation and valves, piping, and equipment andproviding car-seals/locks to address human factor considerations and improve facility safety andprevent incidents.
In the event of a process deviation, ESD valves and instrumentation would be installed tomonitor, alarm, shutdown, and isolate equipment and piping during process upsets or emergency
conditions. The Project would have a plant-wide ESD system to initiate closure of valves andshutdown of the process during emergency situations. Furthermore, each Liquefaction block
would have the individual shutdown capability to address local emergency conditions. Safetyinstrumented systems would comply with ISA Standard 84.00.01 and other recommended andgenerally accepted good engineering practices. We recommend in section 4.12.5 that Plaquemines
LNG file information, for review and approval, on the final design, installation, andcommissioning of instrumentation and emergency shutdown equipment to ensure appropriatecause-and-effect alarm or shutdown logic and enhanced representation of the emergency shutdown
system in the plant control room and throughout the plant.
In developing the FEED, Plaquemines LNG conducted a hazard identification review to
identify potential hazards (both safety and environmental) associated with the facility location, site
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layout, process design, marine operations, simultaneous operations, and construction. In theapplication, Plaquemines LNG stated that a preliminary process hazard review was underdevelopment and would be submitted at a later date. Therefore, we recommended in the draft EIS
for Plaquemines LNG to provide a preliminary process hazard review for review prior to the endof the draft EIS comment period. As comments to the draft EIS, Plaquemines LNG indicated thatthey previously filed the process hazard review. Plaquemines LNG conducted a HAZID based on
the PFDs, HMBs, and plot plan of the facility using a risk matrix based on severity of consequences
and likelihood. There were some inconsistencies in severity of consequences and frequency oflikelihoods, but, more importantly, resolution or recommendations were not fully demonstrated.
For example, in some high risk scenarios, Plaquemines LNG indicated that safeguards were
provided, but did not indicate what the safeguards were (e.g., 2.20), Plaquemines LNG did notprovide supportive documentation for some of the resolutions (e.g., 1.73), and Plaquemines LNG
indicated some of the resolutions would be completed in final design (e.g., 6.03/6.04). Therefore,
we recommend in section 4.12.5 that Plaquemines LNG demonstrate the recommendations to the
HAZID have all been resolved and reflected in the final design and include any supportive
documentation on the safeguards added.
A more detailed hazard and operability review (HAZOP) analysis would be performed by
Plaquemines LNG during the final design to identify the major process hazards that may occur
during the operation of the facilities. The HAZOP study would be intended to address hazards ofthe process, engineering and administrative controls and would provide a qualitative evaluation ofa range of possible safety, health, and environmental consequences that may result from theprocess hazard, and identify whether there are adequate safeguards (e.g., engineering andadministrative controls) to prevent or mitigate the risk from such events. Where insufficientengineering or administrative controls were identified, recommendations to prevent or minimize
these hazards would be generated from the results of the HAZOP review. We recommend insection 4.12.5 that Plaquemines LNG file the HAZOP study on the completed final design forreview and approval. We will evaluate the HAZOP to ensure all systems and process deviations
are addressed appropriately based on likelihood, severity and risk values with commensurate layers
of protection in accordance with recommended and generally accepted good engineering practices,such as American Institute of Chemical Engineers, Guidelines for Hazard Evaluation Procedures.
We also recommend in section 4.12.5 that Plaquemines LNG file the resolutions of therecommendations generated by the HAZOP review so that FERC staff can monitor theseresolutions. Once the design has been subjected to a HAZOP review, the design development
team would track, manage, and keep records of changes in the facility design, construction,
operations, documentation, and personnel. Plaquemines LNG would evaluate these changes toensure that the safety, health, and environmental risks arising from these changes are addressedand controlled based on its management of change procedures. We also recommend in section
4.12.5 that Plaquemines LNG file all changes to their FEED for our review and approval.
However, major modifications could require an amendment or new proceeding.
If the Project is authorized and constructed, Plaquemines LNG would install equipment inaccordance with its design. We recommend in section 4.12.5 that the Project facilities be subject
to construction inspections and that Plaquemines LNG provide, for review and approval,commissioning plans, procedures and commissioning demonstration tests that would verify theperformance of equipment. In addition, we recommend in section 4.12.5 that Plaquemines LNG
provide semi-annual reports that include abnormal operating conditions and facility modifications.
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Furthermore, we recommend in section 4.12.5 that the Project facilities be subject to regularinspections throughout the life of the facilities to verify that equipment is being properly
maintained and to verify basis of design conditions, such as feed gas and sendout conditions, do
not exceed the original basis of design.
4.12.4.4 Mechanical Design
Plaquemines LNG provided codes and standards for the design, fabrication, construction
and installation of piping and equipment and specifications for the facility. The design specifies
materials of construction and ratings suitable for the pressure and temperature conditions of theprocess design. Piping would be designed, fabricated, assembled, erected, inspected, examined,
and tested in accordance with the ASME Standards B31.1, B31.3, B31.8, B36.10, and B36.19M.
Valves and fittings would be designed to standards and recommended practices such as API
Standards 594, 598, 600, 602, 607, and 609; ASME Standards B16.5, B16.9, B16.10, B16.11,
B16.20, B16.21, B16.25, B16.34, B16.47, B16.48; and ISA Standard 75.08.01. Portions of the
facility regulated under 33 CFR 127 for the marine transfer system, including piping, hoses, andloading arms should also be tested in accordance with 33 CFR 127.407.
Pressure vessels must be designed, fabricated, inspected, examined, and tested inaccordance with ASME Boiler and Pressure Vessel Code (BPVC) Section VIII and must be codestamped per NFPA 59A (2001 edition), as incorporated by 49 CFR 193, Subparts C, D, and E.
LNG storage tanks must be designed, fabricated, tested, and inspected in accordance with 49 CFR
193, Subpart D, NFPA 59A (2001 and 2006), and API 620. In addition, Plaquemines LNG would
design, fabricate, test, and inspect the full containment LNG storage tanks in accordance with API
625 and ACI 376. Other low-pressure storage tanks such as the amine, and condensate storage
tanks, would be designed, inspected, and maintained in accordance with the API Standards 650
and 653. All LNG storage tanks would also include boil-off gas compression to prevent the releaseof boil-off to the atmosphere in accordance with NFPA 59A (2001) for an inherently safer design.
Heat exchangers would be designed to ASME BPVC Section VIII standards; API Standards 530,
660, and 661; and the Tubular Exchanger Manufacturers Association standards. Rotating
equipment would be designed to standards and recommended practices, such as API Standards
610, 611, 612, 613, 614, 616, 617, 618, 619, 670, 671, 672, 675, and 682; and ASME Standards
B73.1 and B73.2. Fired heaters would be specified and designed to standards and recommended
practices, such as API Standards 556 and 560.
Pressure and vacuum safety relief valves and flares would be installed to protect the storage
containers, pressure vessels, process equipment, and piping in the event of an unexpected vapor
release or uncontrolled pressure excursion. The safety relief valves would be designed to handle
process upsets and thermal expansion, per NFPA 59A (2001), ASME Standard B31.3, and ASMEBPVC Section VIII; and would be designed in accordance with API Standards 520, 521, 526, 527,
and 2000; and other recommended and generally accepted good engineering practices. In addition,
the operator should verify the set pressure of the pressure relief valves meet the requirements in
33 CFR 127.407. We recommend in section 4.12.5 Plaquemines LNG provide final design
information on pressure and vacuum relief devices and flares, for review and approval, to ensurethat the final sizing, design, and installation of these components are adequate and in accordancewith the standards reference and other recommended and generally accepted good engineering
practices.
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Although many of the codes and standards were listed as ones the Project would meet,
Plaquemines LNG did not make reference to all codes and standards required by regulations(e.g., NFPA 51B) or are recommended and generally accepted good engineering practices. In
addition, they were not consistently reflected in any specifications or data sheets reviewed.
Therefore, we recommend in section 4.12.5 that Plaquemines LNG provide the final specifications
for all equipment and a cross referenced list of all codes and standards for review and approval. If
the Project is authorized and constructed, Plaquemines LNG would install equipment inaccordance with its design and FERC staff would verify equipment nameplates to ensure
equipment is installed based on approved design and conduct construction inspections including
reviewing quality assurance and quality control plans to ensure construction work is performed
according to Project specifications, procedures, codes and standards. We recommend in section
4.12.5 Plaquemines LNG provide semi-annual reports that include equipment malfunctions andabnormal maintenance activities. In addition, we recommend in section 4.12.5 that the Project
facilities be subject to inspections throughout the life of the facility to verify that the plant
equipment is properly maintained.
4.12.4.5 Hazard Mitigation Design
If operational control of the facilities were lost and operational controls and emergency
shutdown systems failed to maintain the Project within the design limits of the piping, containers,
and safety relief valves, a release could potentially occur. FERC regulations under 18 CFR 380.12(o) (1) through (4) require applicants to provide information on spill containment, spacing andplant layout, hazard detection, hazard control, and firewater systems. In addition, 18 CFR 380.12(o) (7) require applicants to provide engineering studies on the design approach and 18 CFR 380.12(o) (14) requires applicants to demonstrate how they comply with 49 CFR 193 and NFPA 59A(2001). As required by 49 CFR 193 Subpart I and by incorporation section 9.1.2 of NFPA 59A(2001), fire protection must be provided for all DOT regulated LNG plant facilities based on an
evaluation of sound fire protection engineering principles, analysis of local conditions, hazards
within the facility, and exposure to or from other property. NFPA 59A (2001) also requires a fire
protection evaluation to determine the type, quantity, and location of hazard detection and hazard
control, passive fire protection, emergency shutdown and depressurizing systems, and emergency
response equipment, training, and qualifications.
If authorized, constructed, and operated, LNG facilities as defined in 49 CFR 193, mustcomply with the requirements of 49 CFR 193, Subpart I and would be subject to DOT’s inspectionand enforcement programs. However, NFPA 59A (2001) also indicates the wide range in size,
design, and location of LNG facilities precludes the inclusion of detailed fire protection provisions
that apply to all facilities comprehensively and includes subjective performance-based language
on where ESD systems and hazard control are required and does not provide any additional
guidance on placement or selection of hazard detection equipment and provides minimal
requirements on firewater. Also, the marine facilities would be subject to 33 CFR 127, which
incorporates sections of NFPA 59A (1994), which have similar performance-based guidance.
Therefore, we evaluated the proposed spill containment and spacing, hazard detection, emergency
shutdown and depressurization systems, hazard control, firewater coverage, structural protection,and onsite and offsite emergency response to determine whether they would provide adequate
protection of the LNG facilities as described more fully below.

4-235Plaquemines LNG performed a preliminary fire protection evaluation to ensure that
adequate mitigation would be in place, including spill containment and spacing, hazard detection,
emergency shutdown and depressurization systems, hazard control, firewater coverage, structuralprotection, and onsite and offsite emergency response. We evaluated the fire protection evaluation
and recommend in section 4.12.5 that Plaquemines LNG provide a final fire protection evaluation
for review and approval, and to provide more information on the final design, installation, andcommissioning of spill containment, hazard detection, hazard control, firewater systems, structuralfire protection, and onsite and offsite emergency response procedures for review and approval.
Spill Containment
In the event of a release, sloped areas at the base of storage and process facilities would
direct a spill away from equipment and into the impoundment system. This arrangement would
minimize the dispersion of flammable vapors into confined, occupied, or public areas andminimize the potential for heat from a fire to impact adjacent equipment, occupied buildings, or
public areas if ignition were to occur.
Title 49 CFR 193.2181, under Subpart C specifies that each impounding system serving an
LNG storage tank must have a minimum volumetric liquid capacity of 110 percent of the LNG
tank’s maximum design liquid capacity for an impoundment serving a single tank, unless surge isaccounted for in the impoundment design. If authorized, constructed, and operated, LNG facilities
as defined in 49 CFR 193, must comply with the requirements of 49 CFR 193, Subpart C andwould be subject to DOT’s inspection and enforcement programs. For full containment LNG
tanks, we also consider it prudent to provide a barrier to prevent liquid from flowing to an
unintended area (i.e., outside the plant property). The purpose of the barrier is to prevent liquidfrom flowing off the plant property and does not define containment or an impounding area forthermal radiation or flammable vapor exclusion zone calculations or other code requirements
already met by sumps and impoundments throughout the site. Plaquemines LNG proposes four
(two constructed during phase 1, two constructed during phase 2) full-containment LNG storage
tanks for which the outer tank wall would serve as the impoundment system. We verified that the
LNG storage tank’s outer concrete wall would have a liquid capacity of at least 110 percent of theinner LNG tank’s maximum liquid capacity. In addition, Plaquemines LNG would also install aberm (i.e., 26-foot storm surge barrier) around the facility, which would prevent liquid in thestorage tank area from flowing off-site in the event of an outer tank impoundment failure. We
recommend in section 4.12.5 that Plaquemines LNG should provide an evaluation prior toconstruction of final design that demonstrates the storm surge barrier, including any gated areas
and water discharge through the storm surge barrier, would prevent LNG from extending offsite
in the event of a release of the full contents of a LNG storage tank. The evaluation should also
demonstrate whether and how high the sheet piles would need to be protected from embrittlement.
Plaquemines LNG proposes to install an LNG Transfer Area Spill Impoundment Basinlocated between the LNG storage tanks that would collect a spill from the LNG transfer lines inthe storage tank area. Plaquemines LNG proposes to install an LNG Spill Impoundment Basinslocated in each of the marine berth areas that would collect a potential spill from the LNG lines atthe berth. Between these LNG tank and berth areas, Plaquemines LNG proposes to install astainless-steel outer pipe to collect spills from the LNG transfer lines. In response to the draft EIS,
Plaquemines LNG commented on the recommendation requiring spill containment for the entire4-236

length of the pipe-in-pipe system between the LNG storage tanks and the marine berth area. They
said they disagree with this recommendation because the outer pipe in the pipe-in-pipe design
serves as the containment/conveyance system so there would be no need for a spill containment
trough. We do not agree with Plaquemines LNG’s comment that the pipe-in-pipe design issufficient in this particular case given the proximity of the LNG transfer lines to SH 23 andpotential risk to the public. Therefore, we still recommend that containment be provided for thisentire pipe-in-pipe system. We also recommend that where the piping system would cross overSH 23, the containment should be designed to withstand collisions or explosions, as discussed
under the “Road” heading in the External Impact Review section, and also be demonstrated towithstand and capture the range of potential releases up to the full pipe diameter, considering thesudden cryogenic temperatures and the pressures of the releases. We also recommend in section
4.12.5 that the final design details of the pipe-in-pipe system be filed for review and approval.
In addition, Plaquemines LNG proposes to install a Process Area LNG Impoundment Basinnear each of the two liquefaction trains to collect a potential spill from the liquefaction equipment
and piping. Parts of the spill conveyance system are proposed to be constructed of steel, which
would also need to be demonstrated to withstand the sudden cryogenic temperatures and pressuresof the full range of potential spills, as steel typically needs a gradual cooldown to be prepared tohandle cryogenic fluids. Plaquemines LNG would also provide a Refrigerant Impoundment Basindesigned to contain a spill from the refrigerant storage tanks and refrigerant truck transfer area.
Diked or curbed impoundments would be provided for each of the solvent, hot oil, diesel andaqueous ammonia storage tanks, as well as the diesel/hot oil truck transfer area. FERC staff was
not able to verify the provision of containment for all significant amounts of hazardous liquids,
such as for the condensate process area, liquid nitrogen storage area, the aqueous ammonia truck
transfer area, and other hazardous fluid facilities. We recommend in section 4.12.5 that
Plaquemines LNG provide additional information on the final design of the impoundment systems
for review and approval.
Under NFPA 59A (2001) section 2.2.2.2, for all of DOT regulated facilities under 49 CFR
193, Subpart C, the capacity of impounding areas for vaporization, process, or LNG transfer areas
must equal the greatest volume that can be discharged from any single accidental leakage source
during a 10-minute period or during a shorter time period based upon demonstrable surveillanceand shutdown provisions acceptable to the DOT. If authorized, constructed, and operated, LNG
facilities as defined in 49 CFR 193, must comply with the requirements of 49 CFR 193, Subpart
C and would be subject to DOT’s inspection and enforcement programs. The impoundment
system design for the marine facilities would be subject to the USCG’s 33 CFR 127, which does
not specify a spill or duration for impoundment sizing. However, FERC staff evaluated whether
all hazardous liquids are provided with spill containment and whether they would be sized basedon the largest flow capacity from a single pipe for 10 minutes plus de-inventory volumes or thecapacity of the largest vessel served, whichever is greater and whether providing spill containment
reduces consequences from a release. Some of the proposed impoundment system details appear
to need clarification or adjustment during the final design phase, including but not limited to:
calculation of the total sizing spill for the ship transfer header considering all pumps in both LNG
tanks at pump run-out rates unless an adequate mechanism is proposed to prevent this; sizing of
troughs to include the total pump run out flow volumes; clarification of the design of the spill
conveyance from the pipe rack to grade at road crossings; clarification of maximum liquid levels
for vessels and tanks; calculation of usable impoundment volumes considering only the depth
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under any trough intersection and considering the volume used by any foundations and equipment;
and technical justification for any hazardous liquid tank impoundments sized for less than the
maximum liquid inventory of the tank. We would verify adequate sizing of the final containment
design during our final design review, based on our recommendation in section 4.12.5 for review
and approval of the final details. In addition, Plaquemines LNG proposes a shorter spill duration
for sizing the marine impoundments, which it attempts to justify based on demonstrable
surveillance and shutdown provisions. FERC staff reviewed this justification and recommends
that Plaquemines LNG provides spill containment of a 10-minute duration given the potential
consequences of overflowing the spill containment.
FERC staff also generally evaluate the means to remove water and snow from impounding
areas to ensure impoundment volumes would not be reduced through accumulations of rainwateror snow. In addition, FERC staff generally evaluate whether there are provisions to ensure thathazardous fluids are not accidentally discharged through the systems intended to remove rainwateror snow. In addition, if authorized, constructed, and operated, LNG facilities as defined in 49 CFR
193, must comply with the requirements of 49 CFR 193 and would be subject to DOT’s inspectionand enforcement programs. Plaquemines LNG indicated that the stormwater removal pumps for
the LNG and refrigerant impoundments would be automatically regulated to remove rainwater andwould be interlocked using low temperature and gas detectors to automatically shut off or preventthe pumps from operating when exposed to LNG or refrigerant temperatures or flammable gases.
Plaquemines LNG would need to verify that the applicable sump pumps for DOT regulated
impoundments meet the automatic shutdown controls and water removal requirements specified
in 49 CFR 193, Subpart C. In addition, the curbed or diked impoundments are proposed to beequipped with a drain line and external isolation valve. Plaquemines LNG indicates that the drain
valve would remain in the closed position at all times except for supervised drainage. We
recommend that Plaquemines LNG consult with DOT’s Pipeline and Hazardous Materials Safety
Administration (PHMSA) on compliance with 49 CFR 193 for the water removal design using
drains. If authorized, constructed, and operated, , final compliance with the requirements of 49
CFR 193, Subpart C would be subject to DOT’s inspection and enforcement programs.
If the Project is authorized, constructed, and operated, Plaquemines LNG would install spill
impoundments in accordance with its design and FERC staff would verify during construction
inspections that the spill containment system including dimensions, and slopes of curbing andtrenches, and capacity matches final design information. In addition, we recommend in section
4.12.5 that Project facilities be subject to regular inspections throughout the life of the facility toverify that impoundments are being properly maintained.
Spacing and Plant Layout
The spacing of vessels and equipment between each other, from ignition sources, and to
the property line must meet the requirements of 49 CFR 193 Subparts C, D, and E, which
incorporate NFPA 59A (2001). NFPA 59A (2001) includes requirements for spacing and plantlayout further references NFPA Standards 30, NFPA 58, and NFPA 59 for additional spacing andplant layout requirements. If authorized, constructed, and operated, LNG facilities as defined in
49 CFR 193, must comply with the requirements of 49 CFR 193 and would be subject to DOT’s
inspection and enforcement programs.

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In addition, we evaluated the spacing to determine if there could be cascading damage andto inform what fire protection measures may be necessary to reduce the risk of cascading damage.
If it was not practical for spacing to mitigate the potential for cascading damage, FERC staff
evaluated whether other mitigation measures were in place and evaluated those systems in further
detail as discussed in subsequent sections in section 4.12.4.4. We evaluated the spacing ofbuildings in line with AIChE CCPS, Guidelines for Evaluating Process Plant Buildings forExternal Explosions and Fires, API 752 and API 753, which provide guidance on identifying andevaluating explosion and fire impacts to buildings and occupants resulting from events external tothe buildings. In addition, FERC staff evaluated other hazards associated with releases andwhether any damage would likely occur at buildings or would result in cascading damage.
To minimize the risk of cryogenic spills causing structural supports and equipment fromcooling below their minimum design metal temperature, Plaquemines LNG would generally locate
cryogenic equipment away from noncryogenic process areas and would direct cryogenic releases
to remote impoundment basins. In addition, for areas that would have cryogenic equipment andcould be exposed to cryogenic temperatures, Plaquemines LNG would insulate structural steel andpipe racks or use materials of construction suitable for cryogenic temperatures, as discussed under
Passive Cryogenic and Fire Protection.
To minimize risk for flammable or toxic vapor ingress into buildings and combustion air
intakes, Plaquemines LNG would generally locate buildings away from process areas and would
generally locate fired equipment and ignition sources away and generally upwind from processareas. Plaquemines LNG provided hazard analysis using two different software models that show
flammable and toxic vapor dispersion would not reach their administration building, control roombuilding, workshop building, or essential diesel generators, but may reach their warehousebuilding, various substations, and various equipment with air intakes. We note that in the case of
one of the software packages, not all wind directions were considered for all release scenarios that
could cause the flammable vapors to reach the administration building, control room building, orworkshop building, or essential diesel generators. Therefore, we recommend in section 4.12.5 that
Plaquemines LNG conduct a technical review of facility, for review and approval, identifying all
combustion/ventilation air intake equipment and the distances to any possible flammable gas or
toxic release; and verify that these areas would be adequately covered by hazard detection devices
that would isolate or shut down any combustion or heating ventilation and air conditioning
equipment whose continued operation could add to or sustain an emergency.
To minimize flammable vapors reaching areas that could result in cascading damage from
explosions, Plaquemines LNG proposed design of the process facilities minimizes confinement
and congestion with the exception of a few areas described. In particular, we evaluated how
flammable vapors would be prevented from accumulating within confined areas, such as
underneath the LNG storage tanks. The LNG storage tanks would be located away from processequipment. However, Plaquemines LNG provided hazard analyses that showed that flammablevapor releases could disperse underneath the elevated LNG storage particularly for releases near
the base of the tank. We recommend in section 4.12.5 that Plaquemines LNG file an analysis, forreview and approval, to demonstrate that the flammable vapor dispersion from design spills would
be prevented from dispersing underneath the elevated LNG storage tanks or detail how the LNG
storage tanks would be able to withstand an overpressure due to ignition of the flammable vapors
that disperse underneath the elevated LNG storage tanks. We also evaluated overpressures from4-239

vapor cloud explosions at buildings, emergency equipment and the LNG storage tanks andrefrigerant storage vessels. Plaquemines LNG provided hazard analyses that showed that
overpressures would not exceed 1 psi at any of these structures, and they would also mound therefrigerant storage vessels.
To minimize the risk of pool fires from causing cascading damage that could exacerbate
the initial hazard, Plaquemines LNG would generally locate spill impoundments such that theradiant heats would have a minimal impact on most areas of the plant. A pool fire from the LNG
storage tank roof would result in less than 4,000 Btu/ft2-hr in most other areas of the plant withthe exception of the BOG compressor area and northern portions of the liquefaction blocks. inaddition, a pool fire at the proposed LNG Storage Tank Process Area Sump located between thefour LNG storage tanks would result in high radiant heats at elevated pipe racks and troughs; apool fire from the LNG marine impoundments would result in high radiant heats at the marine
platforms; and a pool fire from the refrigerant impoundment would result in high radiant heats at
adjacent process equipment, such as the plant air system, refrigerant storage vessels, process
vessels, and pipe racks. To mitigate these radiant heat impacts from pool fires, the BOG
compressors would be within shelters and the refrigerant storage vessels would be mounded. In
addition, the liquefaction blocks, pipe racks, marine platforms, and other process areas would havepassive structural protection, firewater monitors and deluge systems as described under firewater
systems. There would also be emergency shutdown systems to minimize the volume and durationof releases.
To minimize the risk of pool fires from causing cascading damage that could exacerbate
the initial hazard, Plaquemines LNG would generally locate flammable and combustible fluidcontaining piping and equipment away from buildings and process areas that do not handle
flammable and combustible materials. Jet fires would result in less than 1,600 Btu/ft2-hr at theadministration building, control room building, warehouse building, and workshop. However inareas that handle flammable and combustible fluids, jet fire distances to 4,000 Btu/ft2-hr and
4,900 Btu/ft2-hr levels from piping and equipment could impact other components handling or
supporting hazardous fluids. To mitigate jet fires within the plant, Plaquemines LNG indicatesthat measures would be in place to prevent cascading events, including fire-safe ESD valves withfire resistant instrument and power cabling, depressurization systems, fire and gas detectors, fire
proofing of structural steel columns supporting critical equipment, deluge systems, water curtains,
cellular foam blocks, and fire monitors and hydrants. However, details of these systems would be
developed in the final design. We recommend in section 4.12.5 that Plaquemines LNG provide
the final design of these thermal mitigation measures, for review and approval, to demonstratecascading events would be mitigated. In addition, we recommend in section 4.12.5 that
Plaquemines LNG provide an analysis, for review and approval, demonstrating the adjacent LNG
storage tank can withstand the radiant heat from which it would be exposed from a LNG storagetank roof fire.
We also recommend in section 4.12.5 that Project facilities be subject to periodic
inspections during construction to verify flammable/toxic gas detection equipment is installed inheating, ventilation and air condition intakes of buildings at appropriate locations. In addition, we
recommend in section 4.12.5 that Project facilities be subject to regular inspections throughout thelife of the facilities to continue to verify that flammable/toxic gas detection equipment installed inbuilding air intakes function as designed and are being maintained and calibrated.
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If the Project is authorized, Plaquemines LNG would finalize the plot plan, and werecommend in section 4.12.5 that Plaquemines LNG provide any changes for review and approvalto ensure capacities and setbacks are maintained. If the facilities are constructed, Plaquemines
LNG would install equipment in accordance with the spacing indicated on the plot plans, and werecommend in section 4.12.5 that Project facilities be subject to periodic inspections during
construction to verify equipment is installed in appropriate locations and the spacing is met in thefield. In addition, we recommend in section 4.12.5 that Project facilities be subject to regularinspections throughout the life of the facilities to continue to verify that equipment setbacks fromother equipment and ignition sources are being maintained during operations.
Ignition Controls
Plaquemines LNG’s plant areas would be designated with an appropriate hazardous
electrical classification and process seals commensurate with the risk of the hazardous fluids being
handled in accordance with NFPA 59A (2001), NFPA 70, and API RP 500. If authorized,
constructed, and operated, LNG facilities, as defined in 49 CFR 193, must comply with therequirements of 49 CFR 193 and would be subject to DOT’s inspection and enforcement programs,
which require compliance, by incorporation by reference, with NFPA 59A (2001) and NFPA 70(1999). The marine facilities must comply with similar electrical area classification requirements
of NFPA 59A (1994) and NFPA 70 (1993), which are incorporated by reference into the USCG
regulations in 33 CFR 127. Depending on the risk level, these areas would either be unclassified
or classified as Class 1 Division 1, or Class 1 Division 2. Electrical equipment located in theseareas would be designed such that in the event a flammable vapor is present, the equipment would
have a minimal risk of igniting the vapor. We evaluated the Plaquemines LNG electrical areaclassification drawings to verify whether the Project would generally meet the electrical areaclassification requirements in NFPA 59A, 70, 497, and API RP 500 and found that some revisions
would be needed to properly implement these classification areas, including but not limited to,illustrating Class 1 Division 1 and Division 2, as applicable, at all impoundment trenches, the LNG
ship transfer connection, refrigerant truck transfer connection, diesel truck transfer connection,
diesel and other combustible tank vents, power plant area, gas turbines, feed gas aftercoolers,
mixed refrigerant (MR) coolers, and pig launchers. If the Project is authorized, Plaquemines LNG
would finalize the electrical area classification drawings and would describes changes made fromthe FEED design. We recommend in section 4.12.5 that Plaquemines LNG file the final design ofthe electrical area classification drawings for review and approval. If facilities are constructed,
Plaquemines LNG would install appropriately classed electrical equipment, and we recommend insection 4.12.5 that Project facilities be subject to periodic inspections during construction for
FERC staff to spot check electrical equipment and verify equipment is installed per classification
and are properly bonded or grounded in accordance with NFPA 70. In addition, we recommend
in section 4.12.5 that Project facilities be subject to regular inspections throughout the life of the
facility to ensure electrical equipment is maintained (e.g., bolts on explosion proof equipment
properly installed and maintained, and panels provided with purge), and electrical equipment areappropriately de-energized and locked out and tagged out when being serviced.
In addition, submerged electric motor pumps and instrumentation that have a directinterface with a flammable fluid must be equipped with electrical process seals, and leak detectionin accordance with NFPA 59A (2001) and NFPA 70 at each interface between a flammable fluid
system and an electrical conduit or wiring system. We recommend in section 4.12.5 that
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Plaquemines LNG provide, for review and approval, final design drawings showing process seals
installed at the interface between a flammable fluid system and an electrical conduit or wiring
system that meet the requirements of NFPA 59A (2001) and NFPA 70. In its application,
Plaquemines LNG describes an electrical process seal design that may not “continuously vent toatmosphere” as required by NFPA 59A section 7.6.3.4. The design may also not detect a range ofleak sizes through either side of the seal. Therefore, our recommendation includes language
indicating that Plaquemines LNG should provide the results of consultation with DOT PHMSA
indicating that the proposed electrical process seal design would be considered to meet the design
requirements of NFPA 59A (2001), as incorporated by 49 CFR 193.2101, and that Plaquemines
LNG should provide a means to detect a range of leak sizes in either side of the seal. In addition,
we recommend in section 4.12.5 that Plaquemines LNG file, for review and approval, details of
an air gap or vent equipped with a leak detection device that should continuously monitor for thepresence of a flammable fluid, alarm the hazardous condition, and shut down the appropriate
systems. In addition, we recommend in section 4.12.5 that Project facilities be subject to regularinspections throughout the life of the facility to ensure electrical process seals for submerged
pumps continue to conform to NFPA 59A and NFPA 70 and that air gaps are being properly
maintained.
Hazard Detection, Emergency Shutdown, and Depressurization Systems
Plaquemines LNG would also install hazard detection systems to detect cryogenic spills,
flammable and toxic vapors, and fires. The hazard detection systems would alarm and notify
personnel in the area and control room to initiate an emergency shutdown, depressurization, or
initiate appropriate procedures, and would meet NFPA Standard 72, ISA Standard 12.13.01,
Performance Requirements for Combustible Gas Detectors, and other recommended and generally
accepted good engineering practices. However, we note that Plaquemines LNG does not makereference to other recommended and generally accepted good engineering practices in their codesand standards list or data sheets, such as ISA 60079-29-2 or ISA 12.13.02, Recommended Practicefor the Installation, Operation and Maintenance of Combustible Gas Detection Instruments,
ISA 12.13.04, Performance Requirements for Open Path Combustible Gas Detectors, ISA
12.15.01, Performance Requirements for Hydrogen Sulfide Detection Instruments, ISA 12.15.02,
Installation, Operation and Maintenance of Hydrogen Sulfide Detection Instruments,
ISA 92.00.01, Performance Requirements for Toxic Gas Detectors, ISA 92.00.02, Installation,
Operation, and Maintenance of Toxic Gas-Detection Instruments, ISA 92.04.01, Performance
Requirements for Instruments Used to Detect Oxygen Deficient/Oxygen Enriched Atmospheres,and ISA 92.04.02, Installation, Operation, and Maintenance of Instruments Used to Detect Oxygen
Deficient/Oxygen Enriched Atmospheres. In addition, Plaquemines LNG did not include a
specification for hazard detection. Therefore, we recommend in section 4.12.5 that Plaquemines
LNG provide specifications, for review and approval, of the final design of fire safety
specifications, including hazard detection, hazard control, and firewater systems to verify it would
meet these and other recommended and generally accepted good engineering practices, or
equivalents. We also recommend in section 4.12.5 that Plaquemines LNG file a list of final hazard
detection equipment, including the selected manufacturer and model that would allow FERC staff
to verify whether it would generally meet these and other recommended and generally accepted
good engineering practices, or equivalents.

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We evaluated the adequacy of the general hazard detection type, location and layout toensure adequate coverage to detect cryogenic spills, flammable and toxic vapors, and fires near
potential release sources or in spill containment systems (i.e., pumps, compressors, sumps,
trenches, flanges, and instrument and valve connections). Plaquemines LNG submitted spillcontainment drawings that show all LNG and refrigerant impoundments and trenches would
include low temperature detection. In addition, Plaquemines LNG would have ammonia detectors,
However, it was unclear if a number of other hazard detectors, such as low oxygen, hydrogen, andsmoke detectors would be installed due to conflicting information. For example, Plaquemines
LNG indicated in its hazard analyses that low oxygen detectors would be installed near the liquid
nitrogen vessel, but they were not shown in its hazard detection drawings, hazard detection matrix,
or described in the hazard detection basis of design. In addition, Plaquemines LNG indicated in
its hazard detection basis of design that hydrogen gas detectors would be installed in battery rooms,
but they were not shown in its hazard detection drawings, hazard detection matrix, or described in
the hazard analyses. Other discrepancies existed for flammable gas detection at air intakes ofequipment and HVAC intakes of buildings. As a result of that review, we recommend in section
4.12.5 that additional hazard detection be placed throughout the plant and supported by aperformance based study in accordance with ISA 84.00.07 or equivalent methodologies, includingnear the diesel and hot oil tanks, steam turbine power plant, flare KO drums, ethylene packages,
peaking generator, essential diesel generator, acid gas removal area, hot oil furnaces, thermaloxidizer, combustion air intakes and heating, ventilating, and air conditioning (HVAC) intakes ofbuildings. This evaluation would need to demonstrate that 90 percent or more of releases(unignited and ignited) that could result in an offsite or cascading impact would be detected by
two or more detectors and result in isolation and de-inventory within 10 minutes. The analysis
should take into account the set points, voting logic, wind speeds, and wind directions. We
recommend in section 4.12.5 that Plaquemines LNG provide additional information, for review
and approval, on the final design of all hazard detection systems (e.g., manufacturer and model,
elevations, etc.) and hazard detection layout drawings.
We also reviewed the fire and gas cause and effect matrices to evaluate the detectors thatwould initiate an alarm, shutdown, depressurization, or other action based on the FEED. The fireand gas system cause and effect matrices only indicate shutdowns in the marine area and do notshow any other shutdowns, such as for detection of flammable gas at the HVAC intake orequipment air intakes or shutdown of a sump pump upon detection of low temperature. Therefore,
we recommend in section 4.12.5 that Plaquemines LNG provide final fire and gas cause and effects
for review and approval. In addition, we recommend ESD pushbutton drawings of the final design
be provided that demonstrate there is sufficient pushbuttons in each process area.
If authorized, constructed, and operated,, Plaquemines LNG would install hazard detectors
according to its final specifications and drawings, and we recommend in section 4.12.5 that Project
facilities be subject to periodic inspections during construction to verify hazard detectors and ESD
pushbuttons are appropriately installed per approved design and functional based on cause andeffect matrixes prior to introduction of hazardous fluids. In addition, we recommend in section
4.12.5 that Project facilities be subject to regular inspections throughout the life of the facility toverify hazard detector coverage and functionality is being maintained and are not being bypassed
without appropriate precautions.

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Hazard Control
If ignition of flammable vapors occurred, hazard control devices would be installed toextinguish or control incipient fires and releases. Plaquemines LNG indicates hazard control
layout and design would meet NFPA 59A (2001); NFPA 10, 12, 15, 17, and 2001; API 2510A;
as well as other recommended and generally accepted good engineering practices. We evaluatedthe adequacy of the number and availability of handheld, wheeled, and fixed fire extinguishingdevices throughout the site based on the FEED. We also evaluated whether the spacing of the fire
extinguishers meet NFPA 10 and agent type and capacities meet NFPA 59A (2009 and later
editions). In addition, we evaluated whether clean agent systems would be installed in all electricalswitchgear, and instrumentation buildings systems in accordance with NFPA 2001 and CO2
systems in gas turbine enclosures in accordance with NFPA 12. Based on those reviews, werecommend in section 4.12.5 that CO2 systems be installed in gas turbine enclosures in accordancewith NFPA 12, portable extinguishers be provided near the metering station and pig launchers,
and portable extinguishers be provided at the top of all tanks. We also recommend additional
portable extinguishers be provided in the liquefaction blocks in accordance with travel distancesof NFPA 10. Additionally, we recommend Plaquemines LNG provide portable extinguishers inall buildings in accordance with NFPA 10 and include clean agent systems in buildings housing
instrumentation in accordance with NFPA 2001. In addition, we recommend in section 4.12.5 that
Plaquemines LNG file additional information on the final design of these systems, for review andapproval, where details are yet to be determined (e.g., manufacturer and model, elevations,flowrate, capacities, etc.) and where the final design could change as a result of these details orother changes in the final design of the Project.
If authorized, constructed, and operated, Plaquemines LNG would install hazard control
equipment, and we recommend in section 4.12.5 that Project facilities be subject to periodic
inspections during construction to verify hazard control equipment is installed in the field andfunctional prior to introduction of hazardous fluids. In addition, we recommend in section 4.12.5
that Project facilities be subject to regular inspections throughout the life of the facility to verify
in the field that hazard control coverage and is being properly maintained and inspected.
Passive Cryogenic and Fire Protection
If cryogenic release or fires could not be mitigated from impacting facility components toinsignificant levels, passive protection (e.g. – fireproofing structural steel, cryogenic protection,etc.) would be provided to prevent failure of structural supports of equipment and pipe racks. The
structural fire protection would comply with NFPA 59A (2001) and other recommended andgenerally accepted good engineering practices. NFPA 59A (2001) section 6.4.1 requires pipe
supports, including any insulation systems used to support pipe whose stability is essential to plantsafety, to be resistant to or protected against fire exposure, escaping cold liquid, or both, if they
are subject to such exposure. However, NFPA 59A (2001) does not provide the criteria for
determining if they are subject to such exposure or the level of protection needed to protect thepipe supports against such exposures. In addition, NFPA 59A does not address pressure vessels
or other equipment.
Therefore, FERC staff evaluated whether passive cryogenic and fire protection would beapplied to pressure vessels and structural supports to facilities that could be exposed to cryogenic
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liquids or to radiant heats of 4,000 Btu/ft2-hr or greater from fires with durations that could resultin failures 13 and that they are specified in accordance with recommended and generally accepted
good engineering practices, such as: ISO 20088, API 2001, API 2010A, API 2218, ASCE/SFPE
29, ASTM E 84, ASTME E 2226, IEEE 1202, ISO 22899, NACE 0198, NFPA 58, NFPA 255,
NFPA 290, OTI 95 634, UL 1709, and/or UL 2080, with protection commensurate with thecryogenic temperature and duration and fire radiant heat and duration to the exposure.
To minimize the risk of cryogenic spills causing structural supports and equipment fromcooling below their minimum design metal temperature to a point of failure, Plaquemines LNG
would specify materials of construction that would not fail when exposed to a cryogenic releaseor would insulate structural supports and equipment with materials that would be cryogenic
resistant. In addition, Plaquemines LNG would generally locate cryogenic equipment away from
non-cryogenic process areas and would direct cryogenic releases to remote impoundment basins.
However, additional details were not provided on exact locations or equipment that would andwould not be protected from cryogenic releases or the performance characteristics of the passive
cryogenic protection. Therefore, we recommend in section 4.12.5 that Plaquemines LNG filedrawings and specifications for the cryogenic structural protection and calculations or test results(e.g., ISO 20088) that demonstrate the effectiveness of the cryogenic structural protection.
To minimize the risk of pool and jet fires causing structural supports and equipment fromheating above their maximum design metal temperatures to a point of failure, Plaquemines LNG
would specify materials of construction that would not fail when exposed to a fire or would install
structural fire protection. In addition, Plaquemines LNG would mound the refrigerant storage
tanks to prevent cascading damage (i.e., BLEVEs) by protecting the refrigerant storage tanks fromexcessive radiant heat from nearby jet or pool fires. Plaquemines LNG indicated that cryogenic
spill protection would be provided and that passive fire protection would also be provided, but thatdrawings for cryogenic structural passive protection would be developed in final design.
Fireproofing requirements in the application make reference to API 2218 in absence of otherspecifications, but leave it up to the owner and indicate details for the would be resolved in final
design. In addition, API 2218 requires structural fire protection in certain areas and also
recommends fire envelopes be defined based on potential fire scenarios for defining where passive
fire protection is needed. API 2218 recommends the use of UL 1709 for performance requirementsof passive fire protection in areas that are determined to be subjected to pool fires and provides
more limited guidance on defining what jet fire scenarios to consider or the performancerequirements of passive fire protection. However, API 2218 does not define the pool fire or jet
fire scenarios or the radiant heats to be used to determine the extent of passive fire protection.
Therefore, we recommend in section 4.12.5 that Plaquemines LNG file drawings andspecifications for the passive fire protection and calculations or test results (e.g., ISO 22899, NFPA
290, OTI 95 634, etc.) that demonstrate the effectiveness of the passive fire protection. We also
recommend that passive protection be defined based on scenarios that could lead to offsite impacts
or cascading damage and that structural supports may fail as low as 4,900 Btu/ft2-hr 14 andPool fires from impoundments are generally mitigated through use of emergency shutdowns, depressurization
systems, structural fire protection, and firewater, while jet fires are primarily mitigated through the use of
emergency shutdowns, depressurization systems, and firewater without structural fire protection.
14
FERC staff’s heat impact preliminary analyses indicate most carbon structural steels (e.g., ASTM A36), will
begin to have a noticeable loss of strength at 570°F (300°C), lose approximately 1/3 of strength at 840°F (450°C),
13

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pressurized equipment may fail as low as 4,000 Btu/ft2-hr 15, and recognize pool fire tests under
UL 1709 are for 65,000 Btu/ft2-hr (2,000°F) within 5 minutes and sustained for a 1 hour duration,
which would provide thicker passive protection than may be necessary to prevent failure in someareas and thinner passive protection than may be necessary to prevent failure in other areas. We
also note the application of fireproofing is sometimes prescribed in API 2218 to be 20 to 40 feethigh, which may be less than or more than a pool fire height or jet fire flame length. Therefore,
we also recommend in section 4.12.5 that Plaquemines LNG file a detailed quantitative analysis
to demonstrate that adequate mitigation would be provided for each significant component within
the 4,000 Btu/ft2-hr zone from pool or jet fires that could cause failure of the component. Trucks
at the truck loading/unloading areas should be included in the analysis. A combination of passive
and active protection for pool fires and passive and/or active protection for jet fires should be
provided and demonstrate the effectiveness and reliability. Effectiveness of passive mitigation
should be supported by calculations for the thickness limiting temperature rise and active
mitigation should be justified with calculations demonstrating flow rates and durations of any
cooling water would mitigate the heat absorbed by the vessel. In addition, we recommend insection 4.12.5 that Plaquemines LNG file the final design of these mitigation measures, for review
and approval, to demonstrate cascading events would be mitigated.
In addition, it is unclear as to whether Plaquemines LNG would separate or have fire rated
barriers between transformers to prevent cascading damage. Therefore, we recommend in section
4.12.5 that Plaquemines LNG either separate or provide fire walls for electrical transformers inaccordance with NFPA 850 or equivalent that would prevent cascading damage
If the Project is authorized, constructed, and operated, Plaquemines LNG would install
structural cryogenic and fire protection according to its design, and we recommend in section
4.12.5 that Project facilities be subject to periodic inspections during construction to verify
structural cryogenic and fire protection is properly installed in the field as designed prior to
introduction of hazardous fluids. In addition, we recommend in section 4.12.5 that Project

and lose approximately 1/2 of strength at 1,000°F (540°C). These temperatures would correspond to black bodyradiant heats of approximately 2,000 Btu/ft2-hr (6.1 kW/m2), 4,900 Btu/ft2-hr (15.5 kW/m2), and 7,750 Btu/ft2hr (24.5 kW/m2), respectively, and the latter radiant heats may correspond to when structural steel begins to
exceed yield strengths and suffer possible structural damage based on allowable stress/strength designs in
structural and mechanical design codes(e.g., ASCE 7, AISC 360, ASME B31.3, ASME BPVC, etc.), which mostcommonly limit stresses to 1/2 to 2/3 of yield strength. In addition, these values are in line with NFPA 59A (2016edition and 2019 editions) that recommend similar temperature and corresponding radiant heats for steel, ABS
Consulting, Consequence Assessment Methods for Incidents Involving Release from Liquefied Natural Gas
Carriers, 2004 that reports long term exposures at approximately 8,000 Btu/ft2-hr (25 kW/m2) steel surfaces
experience serious dislocation as well as paint peeling, and structural elements undergo substantial deformationaccording to damage resulting from thermal radiation for various materials, and Sandia National Laboratories,
Guidance on Risk Analysis and Safety Implications of a Large Liquefied Natural Gas (LNG) Spill Over Water,
2004, that reports durations of more than 10 minutes at approximately 12,000 Btu/ft2-hr causes temperatures torise to 980°F (530°C) and result in 25 to 40 percent loss in steel strength and damages structures.
15
FERC staff recognize that pressurized equipment in accordance with ASME BPVC allows for pressure relief
valves to pressures to rise to 1.2 times the design pressure, which would lower the pressure in the vessel to lessthan the bursting pressure of typically 3 to 4 times the design pressure but adds stress to the equipment above
normal design conditions, and causes a reduction in temperature and subsequent reduction in radiant heat from4,900 Btu/ft2-hr to 4,000 Btu/ft2-hr for when pressurized equipment may fail. We also recognize that 4,000
Btu/ft2-hr is a commonly used endpoint in fire analyses.

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facilities be subject to regular inspections throughout the life of the facility to continue to verify
that passive protection is being properly maintained.
Firewater Systems
Plaquemines LNG would also provide firewater systems, including remotely operated
firewater monitors, sprinkler systems, fixed water spray systems, and firewater hydrants and hoses
for use during an emergency to cool the surface of storage vessels, piping, and equipment exposedto heat from a fire. These firewater systems would be designed, tested, and maintained to meet
NFPA 59A (2001), 11, 13, 14, 15, 20, 22, 24, and 25 requirements. Plaquemines LNG would havehigh expansion foam trailers at the facility to be used on an as-needed basis. These high expansion
foam trailers would meet the requirements of NFPA 1901. We evaluate the adequacy of thegeneral firewater coverage. We recommend in section 4.12.5 that Plaquemines LNG provide
firewater coverage by two or more hydrants or monitors (or deluge systems) for all process areasthat contain flammable or combustible fluids, including all three docks, diesel generators andstorage, hot oil storage, and gas dehydration units. We recommend in section 4.12.5 that the LNG
storage tanks be provided with firewater coverage. In addition, where coverage circles intersect
pipe racks, large vessels or process equipment, the firewater coverage could be blocked, and thecoverage circles should be modified to account for obstructions during the final design. In
addition, where areas may be inaccessible or difficult to access in the event of an emergency, we
recommend in section 4.12.5 that Plaquemines LNG install remotely operable monitors. We
recommend in section 4.12.5 that Plaquemines LNG provide final firewater capacities for themonitors and hydrants in order to verify the appropriateness of the associated firewater demandsof those systems and worst-case fire scenarios to size the firewater pumps that demonstrate thefirewater monitors and hydrants provide sufficient firewater to reach and cool exposed equipment
based on the throw distance, design density, and surface areas that are needed to be cooled. As
comments to the draft EIS, we recommended that Plaquemines LNG clarify the water sprayconnection shown for the control building. Plaquemines LNG indicated that the water sprayconnection would connect to a riser for a firewater distribution system within the control building.
However, it is not clear what the firewater system would protect. Generally, firewater is notprovided in control rooms where they could damage electrical equipment, but may be provided inadjacent offices. Therefore, we recommend in section 4.12.5 that Plaquemines LNG provide final
drawings for their firewater systems, which would include any firewater provided in the control
room building.
We also recommend in section 4.12.5 that Plaquemines LNG complete anddocument the firewater monitor and hydrant coverage test to verify that actual coverage area fromeach monitor and hydrant as shown on facility plot plan(s). We also recommend in section 4.12.5
that Plaquemines LNG complete and document the firewater monitor and hydrant coverage test toverify that actual coverage area from each monitor and hydrant as shown on facility plot plan(s).
We assessed whether the reliability of the firewater pumps and firewater source or onsite
storage volume are appropriate. Firewater would be sourced from the Mississippi River from one
main and one back diesel firewater pump. There would also be a tie in to the municipal watersupply from the Plaquemines Parish Waterworks District to a firewater/firewater tank with twojockey pumps that would maintain pressure in the firewater piping. We recommend in section
4.12.5 that Plaquemines LNG specify the reducer on the suction side of the firewater pump to be
eccentric or otherwise justify the use of an alternative reducer that will not cause air pockets toform and cause possible damage the firewater pump. We also recommend in section 4.12.5 that
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Plaquemines LNG install a flow measurement test device that reads into the control room andhistorian. In addition, we recommend in section 4.12.5 that Plaquemines LNG file an updated fire
protection evaluation performed on the final design, for review and approval, where details are yet
to be determined (e.g., manufacturer and model, and nozzle types) and where the final design couldchange as a result of these details or other changes in the final design of the Project.
If authorized, constructed, and operated, Plaquemines LNG would install the firewater andfoam systems based on the final specifications and drawings, and we recommend in section 4.12.5
that Project facilities be subject to periodic inspections during construction and that companies
provide results of commissioning tests to verify the firewater and foam systems are installed andfunctional as designed prior to introduction of hazardous fluids. In addition, we recommend insection 4.12.5 that Project facilities be subject to regular inspections throughout the life of the
facility to ensure firewater and foam systems are being properly maintained and tested.
4.12.4.6 Geotechnical and Structural Design Review
Plaquemines LNG provided geotechnical and structural design information for its facilities
to demonstrate the site preparation and foundation designs would be appropriate for the underlying
soil characteristics and to ensure the structural design of the Project facilities would be inaccordance with federal regulations, standards, and recommended and generally accepted goodengineering practices. The application focuses on the resilience of the Project facilities against
natural hazards, including extreme geological, meteorological, and hydrological events, such as
earthquakes, tsunamis, seiche, hurricanes, tornadoes, floods, rain, ice, snow, regional subsidence,
sea level rise, landslides, wildfires, volcanic activity, and geomagnetism.
Geotechnical Evaluation
FERC regulations under 18 CFR 380.12 (h) (3) require geotechnical investigations to beprovided. In addition, FERC regulations under 18 CFR 380.12 (o) (14) require an applicant todemonstrate compliance with regulations under 49 CFR 193 and NFPA 59A (2001). If authorized,
constructed, and operated, LNG facilities, as defined in 49 CFR 193, must comply with therequirements of 49 CFR 193 and would be subject to DOT’s inspection and enforcement programs.
DOT regulations incorporate by reference NFPA 59A (2001). NFPA 59A (2001) section 2.1.4
requires soil and general investigations of the site to determine the design basis for the facility.
However, no additional requirements are set out in 49 CFR 193 or NFPA 59A on minimum
requirements for evaluating existing soil site conditions or evaluating the adequacy of thefoundations, therefore we evaluated the existing site conditions, geotechnical report, and proposed
foundations to ensure they are adequate for the LNG facilities as described below.
Plaquemines LNG contracted Fugro to conduct geotechnical investigations to evaluate theexisting soil site conditions and proposed foundation design for the Project. The existing site
elevation ranges from -2 feet to -4 feet NAVD88. The site would be cleared, grubbed, and preparedusing standard earthmoving and compaction equipment. Site preparation would result in a final
grade elevation of -2 feet NAVD88 for the process area, and a final elevation of -3 feet in the
laydown area. In addition, the site would be surrounded by a levee topped with a flood wall witha final top of wall elevation of +26 feet NAVD88. Plaquemines LNG would not plan to dredge or4-248

reshape the Mississippi River with fill material in order to construct loading docks or the berthingarea.
Fugro conducted 86 soil borings to depths ranging from 60 feet to 300 feet below existing
grade, 10 cone penetration tests (CPTs) to depths ranging from 142 feet to 148 feet (or to refusal)
below existing grade (b.e.g.), and 2 seismic cone penetration tests (SCPTs) to depths ranging to
143 feet below existing grade. Over 14 different tests were conducted on 486 recovered soil
samples, including soil identification and classification tests (water content, Atterberg liquid andplastic limits, sieve tests), strength and compressibility tests (consolidation tests, shear tests,
triaxial tests), corrosion potential tests (pH, sulfate, chloride, electrical resistivity, and carbonate
content), and organic content tests in general accordance with pertinent American Society for
Testing and Materials standards. We evaluated the geotechnical investigation to ensure theadequacy in the number, coverage, and types of the geotechnical borings, CPTs, SCPTs, and othertests, and found them to more than adequately cover all major facilities, including the marine
facilities, LNG storage tanks, liquefaction areas, pretreatment areas, flare system, buildings, power
generation, and berms. We conclude that an adequate number of test borings were performed andsoil samples were collected for the facility, but will continue our review of the results of thegeotechnical investigation to ensure foundation designs are appropriate prior to construction of
final design and throughout the life of the facilities.
Based on the test borings conducted, the site is composed of cohesive soils consisting ofclay, silt, and silty clay to a depth of approximately 150 feet b.e.g., underlain by a layer of natural
granular soils consisting of silty sand and clayey sand extending to a depth of approximately 175
feet b.e.g., underlain by another layer of cohesive soils consisting of clays and sandy clays to adepth of 300 feet b.e.g., where borings were terminated. The near-surface clays contain highamounts of preserved organic (vegetative) materials with some sand intermixed. Furthermore, thenear-surface clays are plastic in nature could compress if not mitigated before the installation offoundations. Plasticity is a material property that directly influences deformation, which could
risk the integrity of a foundation of corrective designs or replacement materials are not used. Dueto the poor soil conditions at the Project site, Fugro has recommended the use of ground
improvement measures to bring the site’s soil conditions to an acceptable status. Corrosion tests
indicate there is very high potential for corrosion of steel based on electrical resistivity results(chloride ion concentration generally indicated high and pH generally indicated mild to highcorrosion potential), and a mild to moderate deterioration of concrete based on sulfate ion
concentrations depending on location within the site. Based on these results, the Project has
considerable potential for corrosion and concrete degradation in the design. Plaquemines LNG
has indicated that it would provide engineering solutions consistent with standard practices.
Based on the subsurface conditions, shallow foundations would be suitable for only somelightly loaded, settlement insensitive structures; however, the majority of heavier loaded
structures, including the LNG storage tanks, liquefaction trains, and many of the associatedstructures would require deep foundations in order to limit settlement to acceptable levels. The
deep foundations would be supported by embedded pre-stressed precast square concrete piles,
auger cast-in-place piles, displacement cast-in-place piles, and open-ended steel pipe piles. Fugro
recommended that piles are proposed to be embedded to depths between an elevation of -80 feetand -220 feet NAVD88 depending on the equipment being supported, pile spacing, pile type, andpile diameter.
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Regional subsidence is the sudden sinking or gradual downward settling of land with little
or no horizontal motion, caused by movements on surface faults or by subsurface mining or
pumping of oil, natural gas, or ground water. The results of Fugro’s geotechnical investigation at
the Project site indicate the Project site could be impacted by regional subsidence at a rate of
approximately 0.27 to 0.42 inches per year, and that subsurface conditions are generally ill suitedfor the facilities, unless adequate site preparation, foundation design, and construction methods are
implemented. Because subsidence is a recognized concern in the area of the Project, Plaquemines
LNG proposes to install all key liquefaction facilities on deep piles, including but not limited to:loading facilities and trestles, LNG storage tanks, LNG booster pumps, gas turbines, pre-treatment
and liquefaction equipment, and all compressors and blowers. Plaquemines LNG has been
recommended by Fugro to develop a monitoring plan for foundations and other critical facilities
to ensure they are maintained within acceptable limits. Site preparation activities would bemonitored to ensure adherence to the geotechnical design. Surface subsidence would be controlled
by potential use of lime stabilization of the fill materials during placement and compaction with
monitoring settlement and systematic reworking, as needed. Foundations would be constructedwith deep pile supports to protect equipment and interconnecting piping from differential
movement. Earth-supported elements, such as the storm surge barrier and plant roads, would
require periodic maintenance to mitigate the long-term effects of settlements and differential
movements. Because site-specific geotechnical mitigation has been incorporated into the Project(e.g., pile-supported foundations) in accordance with NFPA 59A (2001) and where applicable,
NFPA 59A (2006), subsidence would not be a significant hazard to the facilities.
The results of Plaquemines LNG’s geotechnical investigation at the Project site indicatethat subsurface conditions are generally suitable for the facilities, if proposed site preparation,foundation design, and construction methods are implemented appropriately.
Structural and Natural Hazard Evaluation
FERC regulations under 18 CFR 380.12 (m) requires applicants to address the potential
hazard to the public from failure of facility components resulting from accidents or natural
catastrophes, evaluate how these events would affect reliability, and describe the design featuresand procedures that would be used to reduce potential hazards. In addition, 18 CFR 380.12 (o)(14) require an applicant to demonstrate how they would comply with 49 CFR 193 and NFPA
59A. In addition, if authorized, constructed, and operated, LNG facilities as defined in 49 CFR
193, must comply with the requirements of 49 CFR 193 and would be subject to DOT’s inspectionand enforcement programs. DOT regulations under 49 CFR 193 have some specific requirements
on designs to withstand certain loads from natural hazards and also incorporates by reference
NFPA 59A (2001 and 2006) and ASCE 7-05 and ASCE 7-93 via NFPA 59A (2001). NFPA 59A(2001) Section 2.1.1(c) also requires that Plaquemines LNG consider the effects of natural hazards,
such as flooding, storm surge, and seismic activities, for plant site location. This was covered in
DOT PHMSA’s LOD on 49 CFR 193, Subpart B. However, the LOD would not cover whether
the facility is designated appropriately against these hazards, which would be part of 49 CFR 193,
Subpart C. If authorized, constructed, and operated, LNG facilities as defined in 49 CFR 193,
must comply with the requirements of 49 CFR 193 and would be subject to DOT’s inspection andenforcement programs. The marine facilities would be subject to 33 CFR 127, which requires, if
the waterfront facility handling LNG is in a region subject to earthquakes, that the piers andwharves must be designed to resist earthquake forces. In addition, USCG regulations under 33
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CFR 127 incorporates by reference certain portions of NFPA 59A (1994) and ASCE 7-88 via
NFPA 59A (1994). However, USCG regulations do not provide criteria for a region subject toearthquakes or the earthquake forces the piers and wharves are to withstand and NFPA 59A (1994)
section referenced in 33 CFR 127 is for seismic design only and is applicable to stationary LNG
containers, which would not be under 33 CFR 127. Therefore, we evaluated the basis of design
for all facilities for all natural hazards under FERC jurisdiction, including those under DOT and
USCG jurisdiction.
If authorized, the proposed facilities would be constructed to the requirements in the 2009
International Building Code (IBC), ASCE 7-05 for LNG facilities and the 2012 IBC and ASCE 710 for non-LNG facilities. These standards require various structural loads to be applied to thedesign of the facilities, including live (i.e., dynamic) loads, dead (i.e., static) loads, andenvironmental loads. We also evaluated potential the engineering design to withstand impacts
from natural hazards, such as earthquakes, tsunamis, seiche, hurricanes, tornadoes, floods, rain,
ice, snow, regional subsidence, sea level rise, landslides, wildfires, volcanic activity, andgeomagnetism. We recommend in section 4.12.5 that Plaquemines LNG file final design
information (e.g., drawings, specifications, and calculations) and associated quality assurance andquality control procedures with the documents reviewed, approved, and stamped and sealed by aprofessional engineer of record registered in the state of Louisiana. If the Project is authorized,
constructed, and operated, Venture Global would install equipment in accordance with its final
design. In addition, we recommend in section 4.12.5 that Plaquemines LNG file, for review andapproval, settlement results during hydrostatic tests of the LNG storage containers and periodicallythereafter to verify settlement is as expected and does not exceed the applicable criteria in API
620, API 625, API 653, and ACI 376.
Earthquakes, Tsunamis, and Seiche
Earthquakes and tsunamis have the potential to cause damage from shaking ground motion
and fault ruptures. Earthquakes and tsunamis often result from sudden slips along fractures in theearth’s crust (i.e., faults) and the resultant ground motions caused by those movements, but canalso be a result of volcanic activity or other causes of vibration in the earth’s crust. The damage
that could occur as a result of ground motions is affected by the type/direction and severity of thefault activity and the distance and type of soils the seismic waves must travel from the hypocenter(or point below the epicenter where seismic activity occurs). To assess the potential impact fromearthquakes and tsunamis, Venture Global evaluated historic earthquakes along fault locations andtheir resultant ground motions.
The USGS maintains a database containing information on surface and subsurface faultsand folds in the United States that are believed to be sources of earthquakes of greater than
6.0 magnitude occurring during the past 1.6 million years (Quaternary Period). 16 The location of
the Project is within the Gulf Coast Basin geologic tectonic province. The Gulf Coast Basin ischaracterized as having thick sedimentary rocks above basement rock structures. The province’s
sedimentary strata thickens toward the south, with salt domes and relatively shallow listric growthfaults that run parallel to the Gulf of Mexico Coastline. Movement within the fault system has
16

USGS. Earthquake Hazards Program. Quaternary Fault and Fold Database of the United States. Website:
https://earthquake.usgs.gov/hazards/qfaults/. Accessed: August 2018.

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been classified as a general creep as opposed to the breaking of rocks, which is often associatedwith earthquake events (Stevenson and McCulloh, 2001). Salt domes are prevalent throughout the
Gulf Coast Basin and are characterized by having a system of faults arranged in a circular patternaround them (Gagliano, 1999).
Plaquemines LNG conducted a site-specific growth fault analysis for the Project, involving
field investigations and subsequent data evaluation. The Phase 1 Geologic Fault Study included
the examination of growth faults in the region of the Project area. These growth fault systems
have previously been assessed by the USGS as not capable of generating significant earthquakes,
and these faults have not previously been considered as seismogenic sources. While growth faults
are not a source of seismic hazard for the Project site, there may be a potential source of surface
deformation. The closest mapped suspected surface faults are the South of Bayou Dupont Fault,
Bayou Dupont Fault, Bayou Barataria Fault, and the Round Lake Fault. The Round Table Lakefault is located approximately 1 mile south of the site. The South of Bayou Dupont Fault, Bayou
Dupont Fault, Bayou Barataria Fault each strike generally east-west and are located approximately
7 miles west of the site. Where the suspected faults are currently mapped, they do not extend into
the site. If these faults do extend further east than they are currently mapped, the suspected faults
could pose a risk to the site. An evaluation of topographic maps, aerial imagery, and light detection
and ranging imagery maps indicate linear geomorphic features 5 miles southwest of the site thatcoincides with the Round Lake Fault. In addition, Fugro also evaluated subsurface structure mapsof drilled oil and gas wells that indicate growth faults at depth with projections that are estimatedto be approximately 2,000 feet south of the southern boundary of the site and one of the two
identified coincides with the Rounnd Lake Fault southwest of the site. Visual observations of thesite also did not show evidence of surface faulting. While Fugro found no credible evidence
indicating that a surface fault extends into the site, a review of literature on surface faulting in thearea has identified several known and suspected surface faults west and southwest of the site.
These faults trend in the general direction of the site, although they are not shown to extend into
the site. As such, the site is at a higher-than-normal risk of being impacted by a fault. As a result,
Fugro recommends the logs of oil and gas explorations be interpreted to develop a higher degreeof confidence as to the presence or absence of faults that could impact the site. Fugro has identified
six well logs that would be useful for this purpose. These logs would be interpreted for offsets instratigraphic markers indicative of subsurface faulting. It should be noted though that dependingon the results of the interpretation of oil and gas well logs, further study using geophysically logged
borings may be required to determine the presence or absence of a fault extending across the site.
Therefore, we recommend in section 4.12.5 that Plaquemines LNG conduct further study usinggeophysically logged boring to determine the presence or absence of a fault extending across thesite prior to initial site preparation. If growth faults are determined to be present, we recommend
in section 4.12.5 that Plaquemines LNG file a plan to avoid or mitigate growth fault impacts with
the Secretary that is stamped and sealed by the professional engineer-of-record, registered inLouisiana.
While the presence of growth and seismogenic faults can require special consideration, thepresence or lack of growth or seismogenic faults identified near the site does not define whether
earthquake ground motions can impact the site because ground motions can be felt large distancesaway from an earthquake hypocenter depending on number of factors.

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To address the potential ground motions at the site, DOT regulations in 49 CFR 193.2101,
under Subpart C require that field-fabricated LNG tanks must comply with section 7.2.2. of NFPA
59A (2006) for seismic design. NFPA 59A (2006) requires LNG storage tanks to be designed tocontinue safely operating with earthquake ground motions at the ground surface at the site thathave a 10 percent probability of being exceeded in 50 years (475 year mean return interval), termed
the operating basis earthquake (OBE). In addition, DOT regulations in 49 CFR 193.2101, under
Subpart C require that LNG tanks be designed to have the ability to safely shutdown whensubjected to earthquake ground motions which have a 2 percent probability of being exceeded in
50 years (2,475 year mean return interval) at the ground surface at the site (termed the safe
shutdown earthquake [SSE]). DOT regulations in 49 CFR 193.2101, under Subpart C also
incorporate by reference of NFPA 59A (2001) Chapter 6, which require piping systems conveying
flammable liquids and flammable gasses with service temperatures below -20 degrees Fahrenheit,
be designed as required for seismic ground motions. The facilities, once constructed, would be
subject to the DOT’s inspection and enforcement programs.
In addition, we recognize Plaquemines LNG would also need to address hazardous fluid
piping with service temperatures at -20 degrees Fahrenheit and higher and equipment other thanpiping and LNG storage containers. We also recognize the current FERC regulations under
18 CFR 380.12 (h) (5) continues to incorporate NBSIR 84-2833. NBSIR 84-2833 provides
guidance on classifying stationary storage containers and related safety equipment as Category I
and classifying the remainder of the LNG project structures, systems, and components as either
Category II or Category III, but does not provide specific guidance for the seismic design
requirements for them. Absent any other regulatory requirements, this guidance recommends that
other LNG project structures classified as Seismic Category II or Category III be seismicallydesigned to satisfy the Design Earthquake (DE) and seismic requirements of the ASCE 7-05 inorder to demonstrate there is not a significant impact on the safety of the public. ASCE 7-05 isrecommended as it is a complete American National Standards Institute consensus design standard,
its seismic requirements are based directly on the National Earthquake Hazards Reduction
Program Recommended Provisions, and it is referenced directly by the IBC. Having a link directly
to the IBC and ASCE 7 is important to accommodate seals by the engineer of record because the
IBC is directly linked to state professional licensing laws while the National Earthquake Hazards
Reduction Program Recommended Provisions are not.
The geotechnical investigations of the existing site indicate the site is classified as Site
Class E 17 in accordance with ASCE 7-05 and in accordance with IBC 2006 based on a site average
shear wave velocity that ranged between 300 and 350 feet per second (Fugro, 2016a) in the upper
100 feet of strata. Sites with soil conditions of this type could experience significant amplificationsof surface earthquake ground motions. However, due to the absence of a major fault in proximity
to the site and lower ground motions, the seismic risk to the site is considered low.

17

There are six different site classes in ASCE 7-05, A through F, that are representative of different soil conditions
that impact the ground motions and potential hazard ranging from Hard Rock (Site Class A), Rock (Site Class B),
Very dense soil and soft rock (Site Class C), Stiff Soil (Site Class D), Soft Clay Soil (Site Class E), to soils
vulnerable to potential failure or collapse, such as liquefiable soils, quick and highly sensitive clays, andcollapsible weakly cemented soils (Site Class F).

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Fugro performed a site-specific seismic hazard study for the site. The study concluded that
the LNG facility would have an OBE PGA of 0.036 g, an SSE PGA of 0.092 g, a 0.2-second design
spectral acceleration value of 0.119 g, a DE 1.0-second design spectral acceleration at the site of
0.132 g and a DE PGA of 0.055 g (Fugro, 2016b). We independently evaluated the OBE PGA,
SSE PGA, 0.2-second design spectral acceleration, and 1.0-second design spectral accelerations
for the site using the USGS Earthquake Hazards Program Seismic Design Maps 18 and Unified
Hazard 19 tools for all occupancy categories (I-IV). We conclude that the SSE PGA, OBE PGA,
and 5 percent-damped spectral design accelerations used by Plaquemines LNG are acceptable.
These ground motions are relatively low compared to other locations in the United States. Basedon the design ground motions for the site and the importance of the facilities, the facility seismic
design is assigned Seismic Category I for LNG containers, systems required for isolation of LNG
containers, and systems required for safe shutdown or fire protection. Seismic Category II
structures include facilities and systems not included in Category I required for safe plant
operation, which include LNG liquefaction trains, inlet facilities, pre-treatment area(s), power
generation area(s), fuel gas system, interconnecting piping systems, metering systems, LNG
pumps, and other items. Seismic Category III includes all other facilities that are not included in
Categories I and II, including administration buildings, dock service equipment, waste treatment
plant, and incoming electrical power supply.
ASCE 7-05 also requires determination of the Seismic Design Category based on the
Occupancy Category (or Risk Category in ASCE 7-10 and 7-16) and severity of the earthquake
design motion. The Occupancy Category (or Risk Category) is based on the importance of the
facility and the risk it poses to the public.20 We have identified the Project as a Seismic Design
Category B based on the ground motions for the site and an Occupancy Category (or Risk
Category) of III, this seismic design categorization would appear to be consistent with the 2006
IBC and ASCE 7-05 (and ASCE 7-10).
Seismic events can also result in soil liquefaction in which saturated, non-cohesive soils
temporarily lose their strength/cohesion and liquefy (i.e., behave like viscous liquid) as a result of
increased pore pressure and reduced effective stress when subjected to dynamic forces such as
intense and prolonged ground shaking. Areas susceptible to liquefaction may include saturated
soils that are generally sandy or silty. Typically, these soils are located along rivers, streams, lakes,
and shorelines or in areas with shallow groundwater. The site-specific geotechnical investigations
USGS. Changes to U.S. Seismic Design Maps Web Tools.
https://earthquake.usgs.gov/designmaps/us/application.php. Accessed: April 2019.
19 USGS. Unified Hazards Tool. https://earthquake.usgs.gov/hazards/interactive/. Accessed: April 2019.
20 ASCE 7-05 defines Occupancy Categories I, II, III, and IV. Occupancy Category I represents facilities with a low
hazard to human life in even of failure, such as agricultural facilities; Occupancy Category III represents facilities
with a substantial hazard to human life in the event of failure or with a substantial economic impact or disruptionof day to day civilian life in the event of failure, such as buildings where more than 300 people aggregate, daycare
facilities with facilities greater than 150, schools with capacities greater than 250 for elementary and secondaryand greater than 500 for colleges, health care facilities with 50 or more patients, jails and detention facilities,
power generating stations, water treatment facilities, telecommunication centers, hazardous facilities that could
impact public; Occupancy Category IV represents essential facilities, such as hospitals, fire, rescue, and police
stations, emergency shelters, power generating stations and utilities needed in an emergency, aviation control
towers, water storage and pump structures for fire suppression, national defense facilities, and hazardous facilities
that could substantially impact public; and Occupancy Category II represents all other facilities. ASCE 7-10
changed the term to Risk Categories I, II, III, and IV with some modification.
18

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indicate the presence of layers of silty sands and sandy silts that are dense to very dense. Thesesand layers could be liquefiable under sufficiently strong ground motions. However, due to thelow seismicity of the region, the potential for soil liquefaction to occur is low. In addition,
Plaquemines LNG would address possible issues relating to the potential for soil liquefaction andloss of soil strength by using piles in the foundation design. Should soil improvement be required
to counteract soil liquefaction, Plaquemines LNG would utilize ground improvement techniques(e.g., cementitious strengthening).
Seismic events in waterbodies can also cause tsunamis or seiches by sudden displacementof the sea floors in the ocean or standing water. Tsunamis and seiche may also be generated fromvolcanic eruptions or landslides. Tsunami wave action can cause extensive damage to coastal
regions and facilities. The LNG terminal’s low lying position would make it potentially vulnerable
were a tsunami to occur. There is little evidence that the northern Gulf of Mexico is prone totsunami events, but the occurrence of a tsunami is possible. Two did occur in the Gulf of Mexicoin the early 20th century and had wave heights of 3 feet or less (USGS, 2009), which is not
significantly higher than the average breaking wave height of 1.5 feet (Owen, 2008). Hydraulicmodeling conducted for off the coast of Louisiana in 2009, based off of historic submarine
landslides, indicated that the maximum tsunami run-up could be as high as 13 feet above mean sea
level. No earthquake generating faults have been identified that are likely to produce tsunamis,
despite recorded seismic activity in the area.
The potential for tsunamis associated with submarine landslides is more likely a source in
the Gulf of Mexico and remains a focus of government research (USGS, 2009). Plaquemines
LNG’s Seismic Hazard Assessment report included a Tsunami Hazard Assessment for the Project
area. There are four main submarine landslide hazard zones in the Gulf of Mexico including theNorthwest Gulf of Mexico, Mississippi Canyon and Fan, the Florida Escarpment, and theCampeche Escarpment (USGS, 2009). Based on modeling and limited historical data, it isestimated that tsunamis generated from landslides would be more than 2 feet and less than 13 feet
These tsunami run-up elevations are significantly less than the hurricane design storm surge
elevations discussed below, so any tsunami hazard has already been considered in design.
Hurricanes, Tornadoes, and other Meteorological Events
Hurricanes, tornadoes, and other meteorological events have the potential to cause damage
or failure of facilities due to high winds and floods, including failures from flying or floating
debris. To assess the potential impact from hurricanes, tornadoes, and other meteorological events,
Plaquemines LNG evaluated such events historically. The severity of these events are often
determined on the probability that they occur and are sometimes referred to as the average number
years that the event is expected to re-occur, or in terms of its mean return/recurrence interval.
Because of its location, the Project site would likely be subject to hurricane-force winds
during the life of the Project. Plaquemines LNG states that all LNG facilities, as defined in
49 CFR 193, would be designed to withstand a 183 mph 3-second gust. The designed wind speed
would also have a load factor of 1.6 applied in accordance with Chapter 2 of ASCE 7-05. Other
Project facilities classified as Risk Category III would be designed in accordance with ASCE 7-10
to withstand a 170 mph 3-second gust, including the oily water sump pumps; butane, propane,
ethylene, and pentane storage drums and transfer pumps; power generation and steam turbine
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components; heat recovery steam and gas turbine generators and associated and aqueous ammonia
emission control systems; and instrument air, water, electrical and other utility components.
Project facilities classified as Risk Category II would be designed to withstand a 157 mph 3-second
gust including water treatment and sanitary waste components, sump pumps, admin building,warehouses, and guardhouses. A 183 mph 3-second gust would convert to a sustained wind speedof 150 mph, using the Durst Curve in ASCE 7-05 or using a 1.23 gust factor recommended foroffshore winds at a coastline in World Meteorological Organization, Guidelines for Converting
between Various Wind Averaging Periods in Tropical Cyclone Conditions. These wind speeds areequivalent to approximately 7,000-year mean return interval or 0.25 percent probability ofexceedance in a 50 year period for the site, based on whether ASCE 7-05 wind speed return period
conversions. The 183 mph 3-second gust equates to a strong Category 4 Hurricane using theSaffir-Simpson scale (130-156 mph sustained winds, 166-195 mph 3-second gusts). A 170 mph
3-second gust would equate to approximately a 2,750-year return period and weak Category 4
hurricane, and a 157 mph 3-second gust would equate to approximately a 1,200-year return period
and moderate Category 3 hurricane. Plaquemines LNG must meet 49 CFR 193.2067, under
Subpart B for wind load requirements. In accordance with the MOU, the DOT evaluated in its
LOD whether Plaquemines LNG’s proposed Project meets the DOT siting requirements under
Subpart B. If the Project is authorized, constructed, and operated, the LNG facilities, as definedin 49 CFR 193, would be subject to the DOT’s inspection and enforcement programs. Final
determination of whether the facilities are in compliance with the requirements of 49 CFR 193
would be made by the DOT staff. However, DOT has indicated structures that do not fall under
the definition of LNG facilities in 49 CFR 193 would not be subject to the design wind speed
requirements in 49 CFR 193.2067, under Subpart B. Plaquemines LNG would specify facilities
not covered by DOT’s LOD be designed to withstand basic wind speeds in accordance withASCE 7-16 based on appropriate Risk Category.
However, as noted in the limitation of ASCE 7-05 section 6.5.4.3 and ASCE 7-10 section
26.5.4, tornadoes were not considered in developing basic wind speed distributions. This leaves apotential gap in potential impacts from tornadoes. Therefore, we evaluated the potential for
tornadoes. Appendix C of ASCE 7-05 makes reference to American Nuclear Society 2.3 (1983
edition), Standard for Estimating Tornado and Extreme Wind Characteristics at Nuclear Power
Sites. This document has since been revised in 2011 and reaffirmed in 2016 and is consistent with
Nuclear Regulation NUREG/CR-4461, Tornado Climatology of the Contiguous U.S. Rev. 2 (U.S.
Nuclear Regulatory Commission, 2007). These documents provide maps of a 100,000 mean year
return period for tornadoes using 2° latitude and longitude boxes in the region to estimate a tornado
striking within 4,000 feet of an area. Figures 5-8 and 8-1 from NUREG/CR-4461 indicate a
100,000-year maximum tornado wind speeds would be approximately 140 mph 3-second gusts forthe project site location. Later editions of ASCE 7 (ASCE 7-10 and ASCE 7-16) make reference
to International Code Council 500, Standard for Design and Construction of Storm Shelters, for
10,000-year tornadoes. However, the International Code Council 500 maps were conservatively
developed based on tornadoes striking regions and indicate a 200 mph 3-second gust for a 10,000year event, which is higher than the 140 mph 3-second gust in American Nuclear Society 2.3 and
NUREG/CR-4461.
ASCE 7 also recognizes the facility would be in a wind borne debris region. Wind borne
debris has the potential to perforate equipment and the LNG storage tanks if not properly designed
to withstand such impacts. The potential impact is dependent on the equivalent projectile wind
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speed, characteristics of projectile, and methodology or model used to determine whether
penetration or perforation would occur. Unfortunately, no criteria is provided in 49 CFR 193 or
ASCE 7 for these specific parameters. However, NFPA 59A (2016) recommends CEB 187 beused to determine projectile perforation depths. In order to address the potential impact, werecommend in section 4.12.5 that Plaquemines LNG provide a projectile analysis, for review andapproval, to demonstrate that the outer concrete impoundment wall of a full-containment LNG
tank could withstand wind borne projectiles prior to construction of the final design. The analysis
should detail the projectile speeds and characteristics and method used to determine penetration or
perforation depths. We would compare the analysis and specified projectiles and speeds using
established methods, such as CEB 187, and DOE and Nuclear Regulatory Commission guidance.
In addition, we evaluated historical tropical storm, hurricane, and tornado tracks in thevicinity of the Project facilities using data from NOAA’s Historical Hurricane Tracker. 21 Between
1865 and August 2017, 45 hurricanes and tropical storms made landfall within 60 miles of the
Project site. Of the 45 storm events, 5 were considered major hurricanes, defined as Category 3
or greater; including Unnamed (Category 4) hurricane in 1893, Unnamed (Category 4) hurricane
in 1915, Hurricane Betsy (Category 4) in 1965, Hurricane Camille (Category 5) 1969, andHurricane Katrina (Category 3) 2005. During Hurricane Camille storm surges were observed toreach heights of up to 20 feet, and during Hurricane Katrina storm surges were observe to reachheights of up to 18 feet (USGS, 2004).
Potentials flood levels may also be informed from the FEMA Flood Insurance Rate Maps,
which identifies Special Flood Hazard Areas (base flood) that have a 1 percent probability ofexceedance in 1 year to flood (or a 100-year mean return interval) and moderate flood hazard areasthat have a 0.2 percent probability of exceedance in 1 year to flood (or a 500-year mean returninterval). According to the FEMA National Flood Insurance Rate Maps (FEMA, 1985) for
Plaquemines Parish, Louisiana, the 100-year Base Flood Elevation for the Project site is +15.8 ft.
NAVD88. We also recognize that a 500-year flood event has been recommended as the basis ofdesign for critical infrastructure in publications, including ASCE 24, Flood Resistant Design andConstruction. Therefore, we believe it is good practice to design critical energy infrastructure towithstand 500-year event from a safety and reliability standpoint for both SWEL and wave crests.
The proposed design would be able to withstand a 500-year flood event. Furthermore, we
determined the use of intermediate values from NOAA for sea level rise and subsidence is more
appropriate for design and higher projections are more appropriate for planning in accordance withNOAA 2017, 22 which recommends defining a central estimate or mid-range scenario as baseline
for shorter-term planning, such as setting initial adaptation plans for the next two decades anddefining upper bound scenarios as a guide for long-term adaptation strategies and a generalplanning envelope.
The entire LNG terminal site, with the exception of the marine facilities, would be enclosed
for flood protection by construction of a levee topped with a floodwall. The floodwall top
elevation is proposed to be +26 feet NAVD88 with levee crest elevations ranging from +24.5 feetto +27 feet NAVD88. The channel-side earthen levee height is designed for a 500-year still water
21
22

NOAA. Historical Hurricane Tracker. Available at: https://coast.noaa.gov/hurricanes/. Accessed August 2018.
Global and Regional Sea Level Rise Scenarios for the United States. U.S. Department of Commerce. National
Ocean and Atmospheric Administration. National Ocean Service Center for Operational Oceanographic Products
and Services. January 2017.

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elevation (SWEL) of 19.1 feet NAVD88, a 500-year wave of 5.0 feet, and 1.1 feet of sea level riseand subsidence over the life of the Project, yielding an initial crest height of 25.2 feet with a final
initial elevation of +26 feet NAVD88, which provides an over build allowance of 0.5 feet toaccount for downdraft effects on piles. Given the uncertainty in conditions and settlement, werecommend in section 4.12.5 that Plaquemines LNG file a plan for maintaining the levee andfloodwall total elevation of +26 feet for the life of the Project.
We generally evaluate the design against a 500-year SWEL with a 500-year wave crest andsea level rise and subsidence. Using maximum envelope of water (MEOW) storm surge
inundation maps generated from the Sea, Lake, and Overland Surge from Hurricanes (SLOSH)
model developed by NOAA National Hurricane Center, a 500-year event would equate to a
Category 2 Hurricane and approximately 9-12 feet MEOW. 23 This is lower than indicated in the
500-year FEMA maps. In addition, while NOAA seems to provide higher resolution of
topographic features, it limits its SLOSH maps to storm surge levels at high tide above 9 feet. As
a result, we evaluated the storm surge against other sources using SLOSH maps that indicate asimilar upper range of 6-9 feet MEOW for Category 2 Hurricanes, and also indicated 8-12 feet
MEOW for Category 3 Hurricanes, 12-15 feet MEOW for Category 4 Hurricanes, and 15-20 feet
MEOW for Category 5 Hurricanes. 24 This data suggests that Plaquemines LNG design may
withstand Category 4 Hurricane storm surge SWEL equivalent to 1,000- to 10,000-year mean
return intervals. In addition, wave heights would likely impact the channel side, but would notreach the landward side. We also would expect the sea level rise to be closer to the 1.1 feetintermediate projection provided by NOAA. Sea level rise projections are 1.1 feet over 30 years.
However, given the uncertainty in the 500-year SWEL data, 500-year wave data, SLOSH maps,
sea level rise and subsidence projections, and settlement projections and uncertainties, we agree
that the 26 feet NAVD88 post settlement storm surge floodwall would provide adequate protectionof the Plaquemines LNG site and should be periodically monitored and maintained to assure thecrest elevation would not be lower than 26 feet NAVD88 on the channel side. We also recommend
in section 4.12.5 that Plaquemines LNG provide the monitoring and maintenance plan that has
been reviewed, approved, stamped and sealed by the professional engineer of record registered in
the state of Louisiana.
The Texas and Louisiana Gulf Coast area is experiencing the highest rates of coastal
erosion and wetland loss in the United States (Ruple, 1993). Louisiana experiences 90 percent of
the coastal wetland loss for the continental United States. Of this erosion loss, six percent affects
the basins in which this Project is located. Aerial photography taken from 1998 to 2015 indicateslittle or no shoreline loss on the Mississippi River adjacent to the Project site. Shoreline erosion
could occur at the Project site and along the opposite shoreline as a result of waves, currents, andvessel wakes. To prevent erosion along the river bank, an articulated concrete mattress was
installed by the USACE. Even though shoreline erosion is a concern for this geography,
implemented mitigation measures would minimize erosion and scour impacts.

U.S. Department of Commerce. NOAA. National Hurricane Center. National Storm Surge Hazard Maps.
Available at: https://www.nhc.noaa.gov/nationalsurge/#pop. Accessed August 2018.
24 Masters. J.. Weather Underground. Storm Surge Inundation Maps for the U.S. Coast. Available
at:https://www.wunderground.com/hurricane/surge_images.asp. Accessed August 2018.
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Landslides and other Natural Hazards
Landslides involve the downslope movement of earth materials under force of gravity due
to natural or human causes. Due to the low relief across the LNG terminal there is little likelihoodthat landslides or slope movement at the LNG terminal would be a realistic hazard. In general, theclay soils have a comparatively lower risk of forming a landslide, subject to numerous otherfactors.
Volcanic activity is primarily a concern along plate boundaries on the West Coast andAlaska and also Hawaii. Based on our review of maps from USGS 25 and Department of Homeland
Security 26 of the nearly 1,500 volcanoes with eruptions since the Holocene period (in the past
10,000 years) there are no known active or historic volcanic activity within proximity to the sitewith the closest volcano being 1,785 miles of the Project across the Gulf of Mexico in Los Atlixcos,
Mexico.
Geomagnetic disturbances (GMDs) may occur due to solar flares or other natural eventswith varying frequencies that can cause geomagnetically induced currents, which can disrupt theoperation of transformers and other electrical equipment. USGS provides a map of GMD
intensities with an estimated 100-year mean return interval. 27 The map indicates the Plaquemines
LNG site could experience GMD intensities of 20-70 nano-Tesla with a 100-year mean returninterval. However, Plaquemines LNG would be designed such that if a loss of power were to occur
the valves would move into a fail-safe position. In addition, Plaquemines LNG is an export facility
that does not serve any U.S. customers.
4.12.4.7 External Impact Review
To assess the potential impact from external events that are dependent on the site location,
Plaquemines LNG provided FERC with a series of studies that evaluate transportation routes andland use and activities within and surrounding their site and the safeguards in place to mitigate therisk from events, where warranted. We reviewed these studies in coordination with other federal
agencies to assess these impacts for potential vehicle impacts from nearby external roads and rail;
aircraft impacts from nearby airports, heliports, and military facilities; pipeline incident impacts
from nearby pipelines, and adjacent facilities that handle hazardous materials. Mitigation of
impacts from use of internal roadways, rail, helipads, airstrips, or pipelines would also be
considered as part of the engineering review done in conjunction with the NEPA review. FERC
staff takes a risk-based approach in assessing the potential impact of the external events and on theadequacy of the mitigation. The risk-based approach is informed by data on the frequency of
events that could lead to an impact and the potential severity of consequences to the Project andthe resulting consequences to the public beyond the initiating events. The frequency is based on

U.S. Geological Survey. U.S. Volcanoes and Current Activity Alerts. Available at:https://volcanoes.usgs.gov/index.html. Accessed August 2018.
26 Department of Homeland Security. Homeland Infrastructure. Foundation-Level data (HIFLD). Natural Hazards.
hifld-geoplatform.opendata.arcgis.com. accessed Aug 2018
27 U.S. Geological Survey. Magnetic Anomaly Maps and Data for North America. Available at:https://mrdata.usgs.gov/magnetic/map-us.html#home. Accessed August 2018.
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past incidents and the consequences is based on past incidents as well as hazard modeling ofpotential failures.
Road
FERC staff reviewed whether any truck operations would be associated with the Project
and whether any existing roads would be located near the site. FERC staff uses this information
to evaluate whether the Project and any associated truck operations could increase the risk along
the roadways and subsequently to the public and whether any pre-existing unassociated vehiculartraffic could adversely increase the risk to the Project site and subsequently increase the risk to the
public. If authorized, constructed, and operated, LNG facilities, as defined in 49 CFR 193, mustcomply with the requirements of 49 CFR 193 and would be subject to the DOT’s inspection andenforcement programs. DOT regulations under 49 CFR 193.2155(a)(5)(ii), under Subpart C
require that structural members of an impoundment system must be designed and constructed toprevent impairment of the system’s performance reliability and structural integrity as a result of acollision by or explosion of a tank truck that could reasonably be expected to cause the most severe
loading if the liquefaction facility adjoins the right-of-way of any highway. Similarly, NFPA 59A(2001), section 8.5.4, requires transfer piping, pumps, and compressors to be located or protectedby barriers so that they are safe from damage by rail or vehicle movements. The marine facilities
subject to USCG regulations, including 33 CFR 127.001, incorporate NFPA 59A (1994), which
requires pipelines be located on the dock or pier so that they are not exposed to damage fromvehicular traffic or other possible cause of physical damage. However, the DOT and USCG
regulations and NFPA 59A (2001 and 1994) requirements do not prescribe or indicate what
collision(s) or explosion(s) could reasonably be expected to cause the most severe loading.
Therefore, FERC staff evaluated consequence and frequency data from these events to evaluate
these potential impacts.
FERC staff evaluated the risk of the truck operations based on the consequences from arelease, incident data from the DOT Federal Highway Administration (FHWA) 28, DOT National
Highway Traffic Safety Administration (NHTSA) 29, and DOT PHMSA30, EPA, NOAA 31, andother reports 32, 33, 34, and frequency of trucks and proposed mitigation to prevent or reduce theimpacts of a vehicular incident.
Incident data from DOT’s FHWA, NHTSA, and PHMSA, indicates hazardous material
incidents are very infrequent (4e-3 incidents per lane-mile per year) and nearly 75-80 percent of
U.S. DOT FHWA, Office of Highway Policy Information, Highway Statistics 2016,
https://www.fhwa.dot.gov/policyinformation/statistics/2016/, accessed March 2019.
29
U.S. DOT NHTSA, Traffic Safety Facts Annual Report Tables, https://cdan.nhtsa.gov/tsftables/tsfar.htm,
accessed March 2019.
30
U.S. DOT PHMSA, Office of Hazardous Material Safety, Incdent Reports Database Search,https://hazmatonline.phmsa.dot.gov/IncidentReportsSearch/Welcome.aspx, accessed March 2019.
31
U.S. Environmental Protection Agency, National Oceanic and Atmospheric Administration, ALOHA®, User’s
Manual, The CAMEO® Software System, February 2007.
32
Birk, A.M., BLEVE Response and Prevention Technical Documentation, 1995.
33
American Institute of Chemical Engineers, Center for Chemical Process Safety, Guidelines for Vapor Cloud
Explosion, Pressure Vessel Burst, BLEVE, and Flash Fire Hazards, Second Edition, 2010.
34
Lees, F.P, Lees Loss Prevention in the Process Industries, Hazard Identification, Assessment, and Control,
Volume 2, Second Edition, 1996.
28

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hazardous material vehicular incidents occur during unloading and loading operations while theother 20-25 percent occur while in transit or in transit storage. In addition, approximately 99
percent of releases are 1,000 gallons or less and catastrophic events that would spill 10,000 gallons
or more make up less than 0.1 percent of releases. In addition, less than 1 percent of all reportablehazardous material incidents with spillage result in injuries and less than 0.1 percent of allreportable hazardous material incidents with spillage result in fatalities.
The EPA and NOAA report that 80 percent of fires that lead to container ruptures results
in projectiles and that 80 percent of projectiles from liquefied petroleum gas (LPG) incidents,
which constitute the largest product involved in BLEVEs, travel less than 660 feet. The EPA also
reports that on average container ruptures would result in less than four projectiles for cylindricalcontainers and 8.3 for spherical vessels. FERC staff evaluated other reports that affirmed the EPA
estimates based on data for approximately 150 experimental and accidental pressure vessel bursts(PVB) and BLEVEs with approximately 683 total projectiles (4.6 average fragments per incident)
that showed approximately 80 percent of fragments traveled 490 to 820 feet and within 6.25 times
the estimated or observed fireball radius. The data also showed projectiles have traveled up to
3,900 feet for large LPG vessels and 1,200 feet for LPG rail cars. In all the documented cases, theprojectiles traveled less than 15 times the fireball diameter, but one of the reports indicated up to
30 times the fireball diameter is possible albeit very rare.
Unmitigated consequences under average ambient conditions from releases of 1,000
gallons through a 1-inch hole would result in much more modest distances ranging from 25-200
feet for flammable vapor dispersion, and 75-175 feet for jet fires. Unmitigated consequences underworst-case weather conditions from catastrophic failures of trucks proposed at the site generally
can range from 200-2,000 feet for flammable vapor dispersion, 275-350 feet for radiant heat of
5 kW/m2 from jet fires, 800-1,050 feet to a 1 psi overpressure from a BLEVE, 850-1,500 feet fora heat dose equivalent to a radiant heat of 5 kW/m2 over 40 seconds from 250-325 feet radii
fireballs burning 5-15 seconds from a boiling liquid expanding vapor explosion (BLEVE), andprojectiles from BLEVEs possibly extending farther. Based on distribution function of the
projectile distances, FERC staff estimate approximately 90 percent of all projectiles for a 10,000
gallon tanker truck would be within 0.5 mile and there is approximately a 1 percent probability
they would extend beyond 1 mile and less than 0.1 percent probability they would extend 30 times
the fireball diameter. These values are also close to the distances provided by DOT FHWA 35 fordesignating hazardous material trucking routes (0.5 mi for flammable gases for potential impact
distance) and DOT PHMSA 36 for emergency response (0.5-1 mi for initial evacuation and 1 mifor potential BLEVEs for flammable gases).
During operation of the Project, Plaquemines LNG estimates 15 refrigerant make-up
trucks, one hot oil truck, and two nitrogen trucks would be needed at the site annually.
Plaquemines LNG indicated they do not plan to utilize any trucks for condensate removal or todeliver LNG.
SH 23 would bisect the LNG terminal between the process area, which includes the LNG
storage tanks, and the marine berth area. The speed limit is 65 mph along SH 23 near the LNG
U.S. DOT FHWA. Office of Highway Safety. Guidelines for Applying Criteria to Designate Routes forTransporting Hazardous Materials. September 1994.
36
U.S. DOT PHMSA. Emergency Response Guidebook. 2016.
35

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terminal site. Plaquemines LNG provided a Traffic Management Plan for the LNG terminal during
the construction period and describes the current usage of SH 23.
Plaquemines LNG provided a Road Safety and Reliability Impact Study (RSRIS). TheRSRIS addresses potential safety and reliability impacts of proposed tanker trucks loaded or
unloaded at the LNG terminal, and from commercial and recreational roadway traffic along SH 23.
Plaquemines LNG has held several meetings with the Louisiana DOTD discussing a variety of
mitigation measures to be adopted into the design of the pipe trestle crossing SH 23. One such
mitigation measure would be to incorporate 42-inch-tall F-shaped or safety shaped reinforced
concrete barriers along with tier type transition guardrails, as prescribed in the Louisiana DOTD
“Bridge Design and Evaluation Manual” (July 2018), to provide protection to the pipe trestle
supports that would be located in the median of SH 23. Also the process area would be protectedfrom a vehicular incident from the 26-foot-tall storm surge barrier that surrounds the entire processarea. The marine berth area would be protected by the Mississippi River levee that has an
approximate height of 16 feet. Given the potential consequences of a vehicle impacting the LNG
transfer line and SH 23 serving as the only road for evacuation, we recommend that Plaquemines
LNG provide details of the vehicle collision protection at the road crossing of the LNG transfer
line that demonstrate it can withstand impact from the most severe loading, including potential
explosion loads from any trucks carrying hazardous materials.
With the implementation of our recommendation, we conclude the proposed Project would
not pose a significant increase in risk to the public because of the height of the pipe trestle clearance
from SH 23, the setback distances of the process area and marine berth area, the fact the facilities
would be protected by a storm surge floodwall and the Mississippi River Levee, and therecommended vehicular barrier protection for the pipe trestle supports.
Rail
We reviewed whether any rail operations would be associated with the Project and whether
any existing rail lines would be located near the site. We use this information to evaluate whether
the Project and any associated rail operations could increase the risk along the rail line andsubsequently to the public and whether any pre-existing unassociated rail operations could
adversely increase the risk to the Plaquemines LNG site and subsequently increase the risk to the
public. If authorized, constructed, and operated, LNG facilities, as defined in 49 CFR 193, mustcomply with the requirements of 49 CFR 193 and would be subject to the DOT’s inspection andenforcement programs. DOT regulations under 49 CFR §193.2155(a)(5)(ii), under Subpart C
states if the LNG facility adjoins the right-of-way of any railroad that applicants should evaluate
the potential impact and loading on the dike due to collision by or explosion of a train or tank carthat could reasonably be expected to cause the most severe loading. Section 8.5.4 of NFPA 59A(2001), incorporated by reference in 49 CFR 193, requires transfer piping, pumps, and compressors
to be located or protected by barriers so that they are safe from damage by rail or vehicle
movements.
Section 8.5.4 of NFPA 59A (2001), incorporated by reference in 49 CFR 193, requires
transfer piping, pumps, and compressors to be located or protected by barriers so that they are safe
from damage by rail or vehicle movements. The marine facilities subject to USCG regulations,
including 33 CFR 127.001, incorporate NFPA 59A (1994), which requires pipelines be located on
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the dock or pier so that they are not exposed to damage from vehicular traffic or other possible
cause of physical damage. However, the DOT and USCG regulations and NFPA 59A (2001 and1994) requirements do not prescribe or indicate what collision(s) or explosion(s) could reasonably
be expected to cause the most severe loading. Therefore, FERC staff evaluated consequence andfrequency data from these events to evaluate these potential impacts.
FERC staff evaluated the risk of the rail operations based on incident data from the DOT
Federal Rail Administration (FRA), DOT PHMSA, and frequency of rail operations nearby thePlaquemines LNG project. Incident data from DOT FRA and DOT PHMSA indicates hazardous
material incidents are very infrequent (6e-3 incidents per rail-mile per year). In addition,
approximately 95 percent of releases are 1,000 gal or less, and catastrophic events that would spill
30,000 gal or more make up less than 1 percent of releases. In addition, less than 1 percent of
hazardous material incidents result in injuries and less than 0.1 percent result in fatalities.
As previously discussed, the EPA and NOAA report that 80 percent of fires that lead tocontainer ruptures results in projectiles and that 80 percent of projectiles from LPG incidents,
which constitute the largest product involved in BLEVEs, travel less than 660 feet. The EPA andNOAA also report that container ruptures average less than four projectiles for cylindricalcontainers and 8.3 for spherical vessels. FERC staff evaluated other reports that affirmed the EPA
and NOAA estimates based on data for approximately 150 experimental and accidental PVBs and
BLEVEs with approximately 683 total projectiles (4.6 average fragments per incident) that showedapproximately 80 percent of fragments traveled 490 to 820 feet and within 6.25 times the estimatedor observed fireball radius. The data also showed projectiles have traveled up to 3,900 feet forlarge LPG vessels and 1,200 feet for LPG rail cars. In all the documented cases, the projectiles
traveled less than 15 times the fireball diameter, but one of the reports indicated up to 30 times thefireball diameter is possible albeit very rare.
Unmitigated consequences under average ambient conditions from releases of 1,000
gallons through a 1-inch hole would result in distances ranging from 25-200 feet for flammablevapor dispersion, and 75-175 feet for jet fires. Unmitigated consequences under worst-caseweather conditions from catastrophic failures of rail cars containing various flammable products
generally can range from 300-3,000 feet for flammable vapor dispersion, 450-575 feet for radiantheat of 5 kW/m2 from jet fires, 1,225 to 1,500 feet to a 1 psi overpressure from a BLEVE,
1,250-2,100 feet for a heat dose equivalent to a radiant heat of 5 kW/m2 over 40 seconds from 350
to 450 feet radii fireballs burning for 7 to 20 seconds from a BLEVE, and projectiles from
BLEVEs possibly extending farther. Based on distribution function of the projectile distances,
FERC staff estimate approximately 80 percent of all projectiles for a 30,000 gallon rail car would
be within 0.5 mile and there is approximately a 5 percent probability they would extend beyond 1
mile and less than 0.1 percent probability they would extend 30 times the fireball diameter. These
values are also close to the distances provided by DOT PHMSA for emergency response (0.5-1 mifor initial evacuation and 1 mi for potential BLEVEs for flammable gases).
There would be no rail associated with the Project. The closest rail line is locatedapproximately 5.5 miles away from the Project. This would be farther than the consequence
distances under unmitigated worst-case weather conditions and events. Given the distance fromthe rail line and lack of rail associated with the project, we conclude the proposed Project would

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not pose a significant risk or significant increase in risk to the public from proximity of the Projectto the rail lines.
Air
We reviewed whether any aircraft operations would be associated with the Project (e.g.,
helipads) and whether any existing aircraft operations would be located near the site. We use thisinformation to evaluate whether the Project and any associated aircraft operations could increase
the risk to the public and whether any pre-existing unassociated aircraft operations could adversely
increase the risk to the Project site and subsequently increase the risk to the public. In addition, if
authorized, constructed, and operated, LNG facilities as defined in 49 CFR 193, must comply withthe requirements of 49 CFR 193 and would be subject to the DOT’s inspection and enforcement
programs. DOT regulations under 49 CFR 193.2155(b), Subpart C, require an LNG storage tankmust not be located within a horizontal distance of 1 mile from the ends, or 1/4 mile from thenearest point of a runway, whichever is longer and that the height of LNG structures in the vicinityof an airport must comply with DOT FAA requirements. In addition, FERC staff evaluated therisk of an aircraft impact from nearby airports.
There would be no aircraft associated with the proposed Project (e.g., helipads) that would
warrant a review that would increase the risk to the public from aircraft operations. The closest
airport to the LNG terminal site is the Birdwin Airport, which is approximately 16 miles away tothe southeast. There are nine heliports, two general aviation airports, and one naval air station
within the 22-mile radius. The other airport within a 20-mile radius is the Braithwaite Park Airport,
which is approximately 20 miles to the north. These are all farther than the 0.25-mile distancereferenced in DOT regulations.
The DOT FAA regulations in 14 CFR 77 require Plaquemines LNG to provide a notice tothe FAA of its proposed construction. This notification should identify all equipment that are morethan 200 feet above ground level or lesser heights if the facilities are within 20,000 feet of an
airport (at 100:1 ratio or 50:1 ratio depending on length of runway) or within 5,000 feet of a helipad(at 100:1 ratio). In addition, mobile objects, including the LNG marine vessel that would be above
the height of the highest mobile object that would normally traverse it would require notification
to DOT FAA. The FAA aeronautical study would identify which structures and mobile objects(e.g., LNG marine vessels) exceed obstruction standards and would indicate if the identified
structures would be a hazard to air navigation. Based on this study, FAA would issue adetermination for each structure and mobile object that exceeds the obstruction standards.
The facilities include equipment taller than 200 feet and would utilize construction cranes
that could reach up to 350 feet. Therefore, the regulations in 14 CFR 77 apply to that equipment
and require Plaquemines LNG to provide notice to the FAA of its proposed construction. On
January 16, 2017, Plaquemines LNG submitted notice to the FAA for an aeronautical obstruction
study required under 14 CFR Part 77 for the tallest structure at its property boundaries. On January
25, 2017, DOT FAA issued a determination of no hazard to air navigation provided the structure
is marked/lighted in accordance with FAA circular 70/7460-1 L change 1, Obstruction Marking
and Lighting, a med-dual system - Chapters 4,8 (MDual), and 12. These determinations were set
to expire on July 25, 2018, but Plaquemines LNG filed for extensions of all the determinations andthey were granted on July 19, 2018.
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In addition, FERC staff analyzed existing aircraft operation frequency data based on the
airports identified above and their proximity to the LNG storage tank and process areas, the typeand frequency of aircraft operations, take-off and landing directions, and the non-airport flightpaths using the DOE Standard, DOE-STD-3014-2006, Accident Analysis for Aircraft Crash into
Hazardous Facilities. DOE Standard 3014 uses a 22-mile radius from the hazardous facility as
the threshold for consideration of hazards posed by airport and heliport operations. Per the DOE
Standard 3014, heliports need only be considered if there are local overflights associated withfacility operations and/or area operations; because Plaquemines LNG does not have facility or
area-associated helicopter flights, and does not have an on-site heliport, the impact risk due toheliport operations is considered insignificant. The two general aviation airports, Birdwin Airportand Southern Seaplane Airport, are located 16.2 miles SE and 20.0 miles NNW of the site,
respectively. The runway orientations and associated offsets of the runways of the two airports
relative to Plaquemines LNG deems the threat from general aviation operations insignificant.
Lastly, the New Orleans Naval Air Station is located 17.7 miles NNW of the site, with theorientation and associated offsets of its runways deeming threats from military aircraft operations
also insignificant.
Based upon the DOT requirements, FAA determinations, and our review, we conclude theProject would not pose a significant risk or significant increase in risk to the public due to nearby
aircraft operations as a result of the potential consequences, incident data, and distance and positionof the closest aircraft operations relative to the populated areas north of the LNG terminal.
Pipelines
FERC staff reviewed whether any pipeline operations would be associated with theproposed Project and whether any existing pipelines would be located near the site. FERC staff
uses this information to evaluate whether the Project and any associated pipeline operations could
increase the risk to the pipeline facilities and subsequently to the public and whether any preexisting unassociated pipeline operations could adversely increase the risk to the Project site andsubsequently increase the risk to the public. In addition, pipelines associated with this Project
must meet DOT regulations under 49 CFR 192 and are discussed in section 4.12.7. If authorized,
constructed, and operated, LNG facilities as defined in 49 CFR 193, must comply with therequirements of 49 CFR 192 and 49 CFR 193 and would be subject to the DOT’s inspection andenforcement programs. FERC staff evaluated the risk of a pipeline incident impacting the Project
and the potential of cascading damage increasing the risk to the public based on the consequencesfrom a release, incident data from the DOT PHMSA, and proposed mitigation to prevent or reducethe impacts of a pipeline incident from the Project.
We identified one pipeline that is approximately 0.5 miles to the west of the terminal. We
evaluated the potential risk from an incident from the pipeline and its’ potential impacts byconsidering the design and operating conditions and location of the pipeline. Given the proximityof the pipeline to the Project and populations, we conclude the Project would not pose a significant
risk or increase in risk to the public.

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Hazardous Material Facilities and Power Plants
FERC staff reviewed whether any EPA RMP regulated facilities handling hazardous
materials and power plants were located near the site to evaluate whether the facilities could
adversely increase the risk to the LNG terminal and whether the LNG terminal could increase therisk to the EPA RMP facilities and subsequently increase the risk to the public. There were no
adjacent facilities handling hazardous materials identified by the site. The closest facilities
handling hazardous materials are the Elmwood Marine Services and International Marine
Terminals, which are both greater than one mile from the LNG terminal. The closest power plant
identified was at a refinery approximately 7 miles from the terminal. Given the distance andposition of the facilities relative to the populated areas near the LNG terminal, we conclude theProject would not pose a significant increase in risk to the public.
4.12.4.8 Onsite and Offsite Emergency Response Plans
As part of its application, Plaquemines LNG submitted a draft ERP and indicated that it
would be further developed with local, state, and federal agencies as well as other stakeholders.
The emergency procedures would provide for the protection of personnel and the public as well as
the prevention of property damage that may occur as a result of incidents at the Project facilities.
The facility would also provide appropriate personnel protective equipment to enable operations
personnel and first responder access to the area.
As required by 49 CFR 193.2509, under Subpart F, Plaquemines LNG would need toprepare emergency procedures manuals that provide for: a) responding to controllable
emergencies and recognizing an uncontrollable emergency; b) taking action to minimize harm to
the public including the possible need to evacuate the public; and c) coordination and cooperation
with appropriate local officials. Specifically, 49 CFR 193.2509(b)(3) requires “Coordinating withappropriate local officials in preparation of an emergency evacuation plan…,” which sets forth thesteps required to protect the public in the event of an emergency, including catastrophic failure of
an LNG storage tank. DOT regulations under 49 CFR 193.2905, under Subpart J also require atleast two access points in each protective enclosure to be located to minimize the escape distancein the event of emergency. In addition, FERC staff verified roads were at least 20 ft wide toaccommodate emergency apparatus.
Title 33 CFR 127.307 also requires the development of emergency manual thatincorporates additional material, including LNG release response and emergency shutdown
procedures, a description of fire equipment, emergency lighting, and power systems, telephone
contacts, shelters, and first aid procedures. In addition, 33 CFR 127.207 establishes requirements
for warning alarm systems. Specifically, 33 CFR 127.207(a) requires that the LNG marine transfer
area to be equipped with a rotating or flashing amber light with a minimum effective flash
intensity, in the horizontal plane, of 5,000 candelas with at least 50 percent of the required effective
flash intensity in all directions from 1.0 degree above to 1.0 degree below the horizontal plane.
Furthermore, 33 CFR 127.207(b) requires the marine transfer area for LNG to have a siren with aminimum 1⁄3- octave band sound pressure level at l meter of 125 dB referenced to 0.0002
microbars. The siren must be located so that the sound signal produced is audible over 360 degrees
in a horizontal plane. Lastly, 33 CFR 127.207(c) requires that each light and siren must be locatedso that the warning alarm is not obstructed for a distance of 1.6 km (1 mile) in all directions. The
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warning alarms would be required to be tested in order to meet 33 CFR 127. Plaquemines LNG
would be required to meet the warning alarms requirements specified in 33 CFR 127.207.
In accordance with the EPAct 2005, FERC must also approve an emergency response plan
covering the LNG terminal and LNG carrier transit prior to construction. Section 3A(e) of the
NGA, added by Section 311 of the EPAct 2005, stipulates that in any order authorizing an LNG
terminal, the Commission must require the LNG terminal operator to develop an ERP in
consultation with the USCG and state and local agencies. The final ERP would need to beevaluated by appropriate emergency response personnel and officials. Section 3A(e) of the NGA(as amended by EPAct 2005) specifies that the ERP must include a Cost-Sharing Plan that contains
a description of any direct cost reimbursements the applicant agrees to provide to any state andlocal agencies with responsibility for security and safety at the LNG terminal and in proximity to
LNG carriers that serve the facility. The Cost-Sharing Plan must specify what the LNG terminal
operator would provide to cover the cost of the state and local resources required to manage thesecurity of the LNG terminal and LNG carrier, and the state and local resources required for safety
and emergency management, including:•

direct reimbursement for any per-transit security and/or emergency management costs(for example, overtime for police or fire department personnel);•

capital costs associated with security/emergency management equipment andpersonnel base (for example, patrol boats, firefighting equipment); and•annual costs for providing specialized training for local fire departments, mutual aid
departments, and emergency response personnel; and for conducting exercises.

The cost-sharing plan must include the LNG terminal operator’s letter of commitment withagency acknowledgement for each state and local agency designated to receive resources.
Plaquemines LNG provided a draft of an ERP with its application. As part of FEED, weevaluated the initial draft of the ERP to ensure that it would cover the hazards associated with the
Project. In addition, we recommend in section 4.12.5 that Plaquemines LNG provide additional
information, for review and approval, on development of the ERP prior to initial site preparation.
We also recommend in section 4.12.5 that Plaquemines LNG file, for review and approval, threedimensional drawings, or other documentation, which demonstrate there is a sufficient number ofaccess and egress locations. If this Project is authorized, constructed, and operated, Plaquemines
LNG would coordinate with local, state, and federal agencies on the development of an ERP andcost-sharing plan. We recommend in section 4.12.5 that Plaquemines LNG provide periodic
updates on the development of these plans and ensure they are in place prior to introduction of
hazardous fluids. In addition, we recommend in section 4.12.5 that Project facilities be subject toregular inspections throughout the life of the facility and would continue to require companies tofile updates to the ERP.
4.12.5 Recommendations from FERC Preliminary Engineering and Technical Review
Based on our preliminary engineering and technical review of the reliability and safety of
the Project, we recommend the following mitigation as conditions to any order authorizing the

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Project. These recommendations would be implemented prior to initial site preparation, prior toconstruction of final design, prior to commissioning, prior to introduction of hazardous fluids, prior
to commencement of service, and throughout the life of the facility to enhance the reliability andsafety of the facility and to mitigate the risk of impact on the public.
•

Prior to initial site preparation, Plaquemines LNG should file with the Secretarya study that determines the presence or absence of growth faults extending acrossthe site using geophysically logged borings that is stamped and sealed by theprofessional engineer-of-record, registered in Louisiana. If growth faults are
determined to be present, Plaquemines LNG should file a plan to avoid or mitigate
growth fault impacts with the Secretary that is stamped and sealed by theprofessional engineer-of-record, registered in Louisiana.

•

Prior to construction of final design, Plaquemines LNG should file with theSecretary the following information, stamped and sealed by the professional
engineer-of-record, registered in Louisiana:
a. site preparation drawings and specifications;b. LNG terminal structures and foundation design drawings and calculations(including prefabricated and field constructed structures);c. seismic specifications for procured equipment; andd. quality control procedures to be used for civil/structural design andconstruction.
In addition, Plaquemines LNG should file, in its Implementation Plan, theschedule for producing this information.

•

Prior to commencement of service, Plaquemines LNG should file with theSecretary a monitoring and maintenance plan, stamped and sealed by theprofessional engineer-of-record registered in Louisiana, for the perimeter leveethat ensures the crest elevation relative to mean sea level will be maintained forthe life of the facility considering berm settlement, subsidence, and sea level rise.

Information pertaining to these specific recommendations should be filed with theSecretary, for review and written approval by the Director of OEP, or the Director’s
designee, within the timeframe indicated by each recommendation. Plaquemines LNG
should submit specific engineering, vulnerability, or detailed design information meeting thecriteria specified in Order No. 833 (Docket No. RM16-15-000), including security
information, as critical energy infrastructure information pursuant to Title 18 of the Codeof Federal Regulations, Part 388.113 (18 CFR 388.113). See Critical Electric Infrastructure
Security and Amending Critical Energy Infrastructure Information, Order No. 833, 81 Fed.
Reg. 93,732 (December 21, 2016), FERC Stats. & Regs. 31,389 (2016). Information
pertaining to items such as offsite emergency response, procedures for public notificationand evacuation, and construction and operating reporting requirements will be subject topublic disclosure. All information should be filed a minimum of 30 days before approval toproceed is requested.
•

Prior to initial site preparation, Plaquemines LNG should file an overall Projectschedule, which includes the proposed stages of the commissioning plan.
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•

Prior to initial site preparation, Plaquemines LNG should file quality assurance
and quality control procedures for construction activities.

•

Prior to initial site preparation, Plaquemines LNG should file procedures forcontrolling access during construction.

•

Prior to initial site preparation, Plaquemines LNG should file its design windspeed criteria for all other facilities not covered by DOT PHMSA’s LOD to be
designed to withstand wind speeds commensurate with the risk and reliability
associated with the facilities in accordance with ASCE 7-16 or equivalent.

•

Prior to initial site preparation, Plaquemines LNG should develop an ERP(including evacuation) and coordinate procedures with the USCG; state, county,
and local emergency planning groups; fire departments; state and local law
enforcement; and appropriate federal agencies. This plan should include at aminimum:a. designated contacts with state and local emergency response agencies;b. scalable procedures for the prompt notification of appropriate local officials
and emergency response agencies based on the level and severity of potential
incidents;c. procedures for notifying residents and recreational users within areas ofpotential hazard;
d. evacuation routes/methods for residents and public use areas that are within
any transient hazard areas along the route of the LNG marine transit;
e. locations of permanent sirens and other warning devices; andf. an “emergency coordinator” on each LNG marine vessel to activate sirens andother warning devices.
Plaquemines LNG should notify FERC staff of all planning meetings in advanceand should report progress on the development of its ERP at 3‑month intervals.

•

Prior to initial site preparation, Plaquemines LNG should file a Cost-Sharing Plan
identifying the mechanisms for funding all Project-specific security/emergency
management costs that would be imposed on state and local agencies. This
comprehensive plan should include funding mechanisms for the capital costs
associated with any necessary security/emergency management equipment andpersonnel base. Plaquemines LNG should notify FERC staff of all planningmeetings in advance and should report progress on the development of its CostSharing Plan at 3-month intervals.

•

Prior to construction of final design, Plaquemines LNG should include spillcontainment (e.g., a trough collection system) for the entire length of the pipe-inpipe system between the LNG storage tanks and the marine berth area sized fora full guillotine rupture of the pipe-in-pipe line based on a 10-minute duration.

•

Prior to construction of final design, Plaquemines LNG should file details of thepipe-in-pipe system design, including wall thicknesses, spacers, expansion bellows
or loops, and transitions.

•

Prior to construction of final design, Plaquemines LNG should file change logs
that list and explain any changes made from the front-end engineering design4-269

provided in Plaquemines LNG’s application and filings. A list of all changes withan explanation for the design alteration should be provided and all changes should
be clearly indicated on all diagrams and drawings.
•

Prior to construction of final design, Plaquemines LNG should fileinformation/revisions pertaining to the response numbers 14 of its October 11,
2018, filing, response numbers 8, 15, 24, 25, 27, 39, 40, and 43 of its October 16,
2018, filing, and response numbers 11, 31, and 38 of its October 30, 2018, filing,which indicated features to be included or considered in the final design.

•

Prior to construction of final design, Plaquemines LNG should file a plot plan of
the final design showing all major equipment, structures, buildings, andimpoundment systems.

•

Prior to construction of final design, Plaquemines LNG should file drawings ofthe storage tank piping support structure and support of horizontal piping at
grade including pump columns, relief valves, pipe penetrations, instrumentation,
and appurtenances.

•

Prior to construction of final design, Plaquemines LNG should file an up-to-dateequipment list, process and mechanical data sheets, and specifications. The
specifications should be in consistent units and include:
a. building specifications (e.g., control buildings, electrical buildings, compressor
buildings, storage buildings, pressurized buildings, ventilated buildings, blast
resistant buildings);
b. mechanical specifications (e.g., piping, valve, insulation, rotating equipment,
heat exchanger, storage tank, pressure vessel, other specialized equipment);c. electrical and instrumentation specifications (e.g., power system, control
system, safety instrument system [SIS], cable, other electrical andinstrumentation);d. security and fire safety specifications (e.g., lighting, cameras, vehicle barriers,
passive protection, hazard detection, hazard control, firewater).

•Prior to construction of final design, Plaquemines LNG should specify and design
their control systems and human machine interfaces in accordance with the ISA
Standards 5.3, 5.5, 60.1, 60.3, 60.4, and 60.6, or other equivalent standards andrecommended practices for designing control buildings, displaying graphic
symbols for human machine interfaces, and consideration of other human factors.

•

Prior to construction of final design, Plaquemines LNG should file a list of allcodes and standards and the final specification document number where they arereferenced.

•

Prior to construction of final design, Plaquemines LNG should file threedimensional plant drawings, or other documentation, to confirm plant layout for
maintenance, access, egress, and congestion.

•

Prior to construction of final design, Plaquemines LNG should file up-to-dateprocess flow diagrams (PFDs) and piping and instrument diagrams (P&IDs). The
PFDs should include heat and material balances. The P&IDs should include thefollowing information:

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a. equipment tag number, name, size, duty, capacity, and design conditions;b. equipment insulation type and thickness;c. storage tank pipe penetration size and nozzle schedule;
d. valve high-pressure side and internal and external vent locations;e. piping with line number, piping class specification, size, and insulation type
and thickness;
f. piping specification breaks and insulation limits;
g. all control and manual valves numbered;h. relief valves with size and set points; andi. drawing revision number and date.
•

Prior to construction of final design, Plaquemines LNG should include a means toremove mercury as part of the design to limit concentrations to less than 0.01
micrograms per normal cubic meter or alternatively provide monitoring for
mercury by means of an analyzer or preventive maintenance inspections of theheat exchangers and connections for a mercury removal package.

•

Prior to construction of final design, Plaquemines LNG should file layout anddesign specifications of the pig trap, inlet separation and liquid disposal,
inlet/send-out meter station, filters, and pressure control.

•

Prior to construction of final design, Plaquemines LNG should file a car seal
philosophy and a list of all car-sealed and locked valves consistent with the P&IDs.

•

Prior to construction of final design, Plaquemines LNG should file documentation
demonstrating that the recommendations from the Front End Engineering Design
Hazard Identification are complete and consistent with the requirements of the
final design as determined by the engineering, procurement, and construction
contractor.

•

Prior to construction of final design, Plaquemines LNG should file a hazard andoperability review prior to issuing the P&IDs for construction. A copy of thereview, a list of the recommendations, and actions taken on the recommendations
should be filed.

•Prior to construction of final design, Plaquemines LNG should file the safe
operating limits (upper and lower), alarm and shutdown set points for all
instrumentation (i.e., temperature, pressures, flows, and compositions).

•

Prior to construction of final design, Plaquemines LNG should include LNG tankfill flow measurement with high-flow alarm.

•

Prior to construction of final design, Plaquemines LNG should include BOG flow,tank density profile and temperature profile measurement for each tank.

•Prior to construction of final design, Plaquemines LNG should file cause-andeffect matrices for the process instrumentation, fire and gas detection system, andemergency shutdown system for review and approval. The cause-and-effectmatrices should include alarms and shutdown functions, details of the voting andshutdown logic, and set points.

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•

Prior to construction of final design, Plaquemines LNG should specify that all
ESD valves are to be equipped with open and closed position switches connectedto the Distributed Control System (DCS)/SIS.

•

Prior to construction of final design, Plaquemines LNG should specify theminimum distance required for valve maintenance, between the LNG loadingheader and the first valve in the discharge piping to the loading arm.

•

Prior to construction of final design, Plaquemines LNG should specify that piping
and equipment that may be cooled with liquid nitrogen is to be designed for liquid
nitrogen temperatures, with regard to allowable movement and stresses.

•

Prior to construction of final design, Plaquemines LNG should include any
isolation valves necessary for startup, operation, shutdown, restart, andmaintenance procedures.

•

Prior to construction of final design, Plaquemines LNG should demonstrate that,for hazardous fluids, piping and piping nipples 2 inches or less in diameter aredesigned to withstand external loads, including vibrational loads in the vicinity ofrotating equipment and operator live loads in areas accessible by operators.

•

Prior to construction of final design, Plaquemines LNG should specify that all
drains from high-pressure hazardous fluid systems are to be equipped with double
isolation and bleed valves or equivalent positive isolation.

•

Prior to construction of final design, Plaquemines LNG should file the sizing basis
and capacity for the final design of the flares and/or vent stacks as well as thepressure and vacuum relief valves for major process equipment, vessels, andstorage tanks.

•

Prior to construction of final design, Plaquemines LNG should file pressurerelieving protection for flammable liquid piping segments (i.e., refrigerants, liquidhydrocarbons, condensate products) that can be isolated by valves.

•

Prior to construction of final design, Plaquemines LNG should file an updated fire
protection evaluation of the proposed facilities. A copy of the evaluation, a list ofrecommendations and supporting justifications, and actions taken on therecommendations should be filed. The evaluation should justify the type,
quantity, and location of hazard detection and hazard control, passive fire
protection, emergency shutdown and depressurizing systems, firewater, andemergency response equipment, training, and qualifications in accordance with
NFPA 59A (2001). The justification for the flammable and combustible gas
detection and flame and heat detection should be in accordance with ISA 84.00.07
or equivalent methodologies that would demonstrate 90 percent or more of
releases (unignited and ignited) that could result in an offsite or cascading impact
would be detected by two or more detectors and result in isolation and deinventory
within 10 minutes. The analysis should take into account the set points, voting
logic, wind speeds, and wind directions. The justification for firewater should
provide calculations for all firewater demands (including firewater coverage on
the LNG storage tanks) based on design densities, surface area, and throw
distance and specifications for the corresponding hydrant and monitors needed toreach and cool equipment.

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•

Prior to construction of final design, Plaquemines LNG should file spillcontainment system drawings with dimensions and slopes of curbing, trenches,
impoundments, and capacity calculations considering any foundations andequipment within impoundments, as well as the sizing and design of the downcomer that would transfer spills from the tank top to the ground-level
impoundment system. The spill containment drawings should show containment
for all hazardous fluids, including all liquids handled above their flashpoint, fromthe largest flow from a single line for 10 minutes, including de-inventory, or the
maximum liquid from the largest vessel (or total of impounded vessels) orotherwise demonstrate that providing spill containment would not significantly
reduce the flammable vapor dispersion or radiant heat consequences of a spill. In
addition, Plaquemines LNG should demonstrate that the stainless steel piping spilltrays at each LNG storage tank would withstand the force and shock of a sudden
cryogenic release.

•

Prior to construction of final design, Plaquemines LNG should consult with the
DOT PHMSA on compliance with 49 CFR 193 for the water removal design using
drains.

•Prior to construction of final design, Plaquemines LNG should file electrical areaclassification drawings. The drawings should be updated with the latest design,
including liquefaction blocks and full containment tanks, and demonstratecompliance with NFPA 59A, NFPA 70, NFPA 497, API 500, or equivalent,
including but not limited to, illustrating Class 1 Division 1 and Division 2, asapplicable, at all impoundment trenches, the LNG ship transfer connection,
refrigerant truck transfer connection, diesel truck transfer connection, diesel andother combustible tank vents, power plant area, gas turbines, feed gas
aftercoolers, mixed refrigerant (MR) coolers, and pig launchers.

•

Prior to construction of final design, Plaquemines LNG should file detailed
calculations to confirm that the final firewater volumes would be accounted forwhen evaluating the capacity of the impoundment system during a spill and fire
scenario.

•

Prior to construction of final design, Plaquemines LNG should file an analysis
demonstrating the flammable vapor dispersion from design spills would be
prevented from dispersing underneath the elevated LNG storage tanks, ordemonstrating the LNG storage tanks would be able to withstand theoverpressure due to ignition of the flammable vapors that disperses underneaththe elevated LNG storage tanks.

•

Prior to construction of final design, Plaquemines LNG should file drawings anddetails of how process seals or isolations installed at the interface between aflammable fluid system and an electrical conduit or wiring system meet therequirements of NFPA 59A (2001 edition). Plaquemines LNG should also provide
the results of consultation with the DOT PHMSA indicating that the proposed
electrical process seal design would be considered to meet the design requirements
of NFPA 59A (2001), as incorporated by 49 CFR 193.2101.

•

Prior to construction of final design, Plaquemines LNG should file details of an
air gap or vent installed downstream of process seals or isolations installed at theinterface between a flammable fluid system and an electrical conduit or wiring
system. Each air gap should vent to a safe location and be equipped with a leak4-273

detection device that should continuously monitor for the presence of a flammablefluid, alarm the hazardous condition, and shut down the appropriate systems.
•

Prior to construction of final design, Plaquemines LNG should file an analysis of
the localized hazards to operators from a potential liquid nitrogen release andshould also provide spill containment and low oxygen detectors to mitigate liquid
nitrogen releases.

•

Prior to construction of final design, Plaquemines LNG should file a drawing
showing the location of the emergency shutdown buttons. Emergency shutdown
buttons should be easily accessible, conspicuously labeled, and located in an areathat would be accessible during an emergency.

•

Prior to construction of the final design, Plaquemines LNG should install a plantwide shutdown button or provide a human reliability analysis that demonstrates
the multiple pushbutton approach does not significantly increase the risk
compared to a plant-wide shutdown button.

•

Prior to construction of final design, Plaquemines LNG should file complete
drawings and a list of the hazard detection equipment. The drawings should
clearly show the location and elevation of all detection equipment, including near
the diesel and hot oil tanks, steam turbine power plant, flare KO drums, ethylene
packages, peaking generator, essential diesel generator, acid gas removal area, hot
oil furnaces, thermal oxidizer, combustion air intakes and HVAC intakes ofbuildings. The list should include the instrument tag number, type and location,
alarm indication locations, and shutdown functions of the hazard detection
equipment.

•

Prior to construction of final design, Plaquemines LNG should account for thecalibration gas of the hazard detectors when determining the lower flammable
limit set points for methane, propane, butane, ethylene, and condensate.

•

Prior to construction of final design, Plaquemines LNG should account for thecalibration gas of hazard detectors when determining the set points for toxic
components such as aqueous ammonia, natural gas liquids and hydrogen sulfide.
Include a list of alarm and shutdown set points for each hazard detector.

•

Prior to construction of final design, Plaquemines LNG should file a technicalreview of facility design that:a. identifies all combustion/ventilation air intake equipment and the distances toany possible flammable gas or toxic release; andb. demonstrates that these areas are adequately covered by hazard detection
devices and indicates how these devices would isolate or shut down any
combustion or heating ventilation and air conditioning equipment whose
continued operation could add to or sustain an emergency.

•

Prior to construction of final design, Plaquemines LNG should file an analysis of
the off gassing of hydrogen in battery rooms and ventilation calculations that limit
concentrations below the lower flammability limits (e.g., 25 percent LFL) andshould also provide hydrogen detectors that alarm (e.g., 20 to 25 percent LFL)
and initiate mitigative actions (e.g., 40 to 50 percent LFL).

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•

Prior to construction of final design, Plaquemines LNG should specify smoke
detection in occupied buildings.

•

Prior to construction of final design, Plaquemines LNG should specify hazard
detection suitable to detect high temperatures and smoldering combustion
products in electrical buildings and control room buildings.

•

Prior to construction of final design, Plaquemines LNG should file an evaluationof the voting logic and voting degradation for hazard detectors.

•

Prior to construction of final design, Plaquemines LNG should file facility plandrawings and a list of the fixed and wheeled dry-chemical, hand-held fire
extinguishers, and other hazard control equipment. Plan drawings should clearlyshow the location by tag number of all fixed dry chemical stations in accordancewith NFPA 17, and wheeled and hand-held extinguishers along normal paths ofaccess and egress in accordance with NFPA 10 travel distances including, but notlimited to, at the liquefaction blocks, near the metering station and pig launchers,
on top of all tanks, and in all buildings. The list should include the equipment tag
number, manufacturer and model, agent type, agent capacity, discharge rate,
automatic and manual remote signals initiating discharge of the units, andequipment covered.

•

Prior to construction of final design, Plaquemines LNG should specify carbon
dioxide systems installed in accordance with NFPA 12 or equivalent in gas turbine
enclosures.

•

Prior to construction of final design, Plaquemines LNG should specify clean agent
systems installed in accordance with NFPA 2001 or equivalent in instrumentationbuildings.

•

Prior to construction of final design, Plaquemines LNG should file drawings andcalculations for the structural passive protection systems to protect equipment
and supports from cryogenic releases.

•

Prior to construction of final design, Plaquemines LNG should file calculations or
test results for the structural passive protection systems to demonstrate that
equipment and supports are protected from cryogenic releases.

•

Prior to construction of final design, Plaquemines LNG should file drawings andspecifications for the structural passive protection systems to demonstrate theequipment and supports are protected from pool and jet fires.

•

Prior to construction of final design, Plaquemines LNG should file a detailed
quantitative analysis to demonstrate that adequate mitigation would be provided
for each significant component within the 4,000 BTU/ft2-hr zone from pool and jet
fires that could cause failure of the component. Trucks at the truck
loading/unloading areas should be included in the analysis. A combination ofpassive and active protection for pool fires and passive and/or active protection
for jet fires should be provided and demonstrate the effectiveness and reliability.
Effectiveness of passive mitigation should be supported by calculations or test
results for the thickness limiting temperature rise and active mitigation should bejustified with calculations or test results demonstrating flow rates and durationsof any cooling water will mitigate the heat absorbed by the vessel.

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•

Prior to construction of final design, Plaquemines LNG should file a projectile
analysis to demonstrate that the outer concrete impoundment wall of a fullcontainment LNG storage tank could withstand projectiles from explosions andhigh winds. The analysis should detail the projectile speeds and characteristics
and method used to determine penetration or perforation depths.

•

Prior to construction of final design, Plaquemines LNG should file specifications
and drawings demonstrating how cascading damage of transformers would be
prevented (e.g., firewalls or spacing) in accordance with NFPA 850 or equivalent.

•

Prior to construction of final design, Plaquemines LNG should file facility plandrawings showing the proposed location of the firewater and any foam systems.
Plan drawings should clearly show the location of firewater and foam piping, post
indicator valves, and the location and area covered by, each monitor, hydrant,
hose, water curtain, deluge system, foam system, water-mist system, andsprinkler. The drawings should also include piping and instrumentation
diagrams of the firewater and foam systems. The firewater coverage drawings
should illustrate firewater coverage by two or more hydrants or monitors
accounting for obstructions (or deluge systems) for all process areas that contain
flammable or combustible fluids, including all three docks, diesel generators andstorage, hot oil storage, gas dehydration units, and LNG storage tanks.

•

Prior to construction of final design, Plaquemines LNG should specify remotely
operated or automatic firewater monitors in areas inaccessible or difficult toaccess in the event of an emergency.

•

Prior to construction of final design, Plaquemines LNG should specify firewatercapacities for the monitors and hydrants.

•

Prior to construction of final design, Plaquemines LNG should design thefirewater pump shelter for maintenance access to the firewater pumps.

•

Prior to construction of final design, Plaquemines LNG should specify that afirewater flow test meter is installed and equipped with a transmitter and that apressure transmitter is installed upstream of the flow transmitter. The flowtransmitter and pressure transmitter should be connected to the DCS andrecorded.

•Prior to construction of final design, Plaquemines LNG should specify the reducer
on the suction side of the firewater pump to be eccentric or otherwise justify theuse of an alternative reducer that will not cause air pockets to form and cause
possible damage to the firewater pump.

•

Prior to construction of final design, Plaquemines LNG should file an analysis of
the structural integrity of the outer containment of the full containment storage
tanks when exposed to a roof tank top fire or adjacent tank top fire.

•

Prior to construction of final design, Plaquemines LNG should file drawings andspecifications for protecting transfer piping, pumps, and compressors, etc. toensure that they are located away from roadway or protected from inadvertent
damage from vehicles.

•

Prior to construction of final design, Plaquemines LNG should file specifications,drawings, and details of vehicle barriers at each facility entrance for access
control.
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•Prior to construction of final design, Plaquemines LNG should file specifications,drawings, and details of the vehicle collision protection at the SH 23 road crossingof the LNG transfer line that demonstrate it can withstand impact from the most
severe loading, including potential explosion loads from any trucks carrying
hazardous materials.

•

Prior to construction of final design, Plaquemines LNG should file security
camera drawings showing the location, areas covered, and features of the camera(e.g., fixed, tilt/pan/zoom, motion detection alerts, low light, and mounting height)
to verify camera coverage of the entire perimeter with redundancies and camerasinterior to the facility, including atop the LNG storage tanks, that would enable
rapid monitoring of the LNG plant.

•

Prior to construction of final design, Plaquemines LNG should file a photometriclighting simulation or other calculations that demonstrate lighting coverageadequately covers, in accordance with API 540, the interior and perimeter of the
facility, including in liquefaction blocks, oily water treatment plant area, exteriorof buildings, and along paths/roads of access and egress.

•

Prior to construction of final design, Plaquemines LNG should file details offencing with barbed or razor wire, or equivalent, at road crossing that would
restrict and deter access.

•Prior to construction of final design, Plaquemines LNG should file drawings ofthe security fence. The fencing drawings should provide details of fencing that
demonstrates it would restrict and deter access around the entire facility and has
a setback from exterior features (e.g., power lines, trees, etc.) and from interiorfeatures (e.g., piping, equipment, buildings, etc.) that does not allow the fence tobe overcome.

•Prior to construction of final design, Plaquemines LNG should provide anevaluation that demonstrates the storm surge barrier, including any gated areas
and water discharge through the storm surge barrier, would prevent LNG fromextending offsite in the event of a release of the full contents of a LNG storagetank. The evaluation should also demonstrate whether and how high the sheet
piles would need to be protected from embrittlement..

•

Prior to commissioning, Plaquemines LNG should file a detailed schedule forcommissioning through equipment startup. The schedule should include
milestones for all procedures and tests to be completed: prior to introduction of
hazardous fluids and during commissioning and startup. Plaquemines LNG
should file documentation certifying that each of these milestones has been
completed before authorization to commence the next phase of commissioning andstartup will be issued.

•

Prior to commissioning, Plaquemines LNG should file the operation andmaintenance procedures and manuals, as well as safety procedures, hot work
procedures and permits, abnormal operating conditions reporting procedures,
simultaneous operations procedures, and management of change procedures andforms.

•

Prior to commissioning, Plaquemines LNG should provide procedures forremoving the spent H2S catalyst.

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•

Prior to commissioning, Plaquemines LNG should tag all equipment,
instrumentation, and valves in the field, including drain valves, vent valves, main
valves, and car-sealed or locked valves.

•

Prior to commissioning, Plaquemines LNG should file and maintain a detailed
training log to demonstrate that operating, maintenance, and emergency response
staff has completed the required training.

•

Prior to commissioning, Plaquemines LNG should file detailed plans andprocedures for: testing the integrity of onsite mechanical installation; functional
tests; introduction of hazardous fluids; operational tests; and placing theequipment into service.

•

Prior to commissioning, Plaquemines LNG should file the procedures forpressure/leak tests that address the requirements of ASME VIII and ASME
B31.3.

•

Prior to commissioning, Plaquemines LNG should file a plan for clean-out, dryout, purging, and tightness testing. This plan should address the requirements of
the American Gas Association’s Purging Principles and Practice, and should
provide justification if not using an inert or non-flammable gas for clean-out, dryout, purging, and tightness testing.

•Prior to commissioning, Plaquemines LNG should equip the LNG storage tanks
and adjacent piping and supports with permanent settlement monitors to allow
personnel to observe and record the total and relative settlement between the LNG
storage tank and adjacent piping. The settlement record should be reported in
the semi-annual operational reports.

•

Prior to introduction of hazardous fluids, Plaquemines LNG should file settlement
results from the hydrostatic tests of the LNG storage containers and shall file aplan to periodically verify settlement is as expected and does not exceed theapplicable criteria set forth in API 620, API 625, API 653, and ACI 376.

•

Prior to introduction of hazardous fluids, Plaquemines LNG should complete all
pertinent tests (Factory Acceptance Tests, Site Acceptance Tests, Site Integration
Tests) associated with the DCS and SIS that demonstrates full functionality andoperability of the system.

•

Prior to introduction of hazardous fluids, Plaquemines LNG should develop andimplement an alarm management program to ensure effectiveness of process
alarms.

•Prior to introduction of hazardous fluids, Plaquemines LNG should complete afirewater pump acceptance test and firewater monitor and hydrant coverage test.
The actual coverage area from each monitor and hydrant should be shown on
facility plot plan(s).

•Prior to introduction of hazardous fluids, Plaquemines LNG should complete anddocument foam system and sprinkler system acceptance tests.

•

Prior to introduction of hazardous fluids, Plaquemines LNG should complete anddocument a clean agent acceptance tests.

•

Prior to introduction of hazardous fluids, Plaquemines LNG should complete anddocument a pre-startup safety review to ensure that installed equipment meets the
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design and operating intent of the facility. The pre-startup safety review should
include any changes since the last hazard review, operating procedures, andoperator training. A copy of the review with a list of recommendations, andactions taken on each recommendation, should be filed.
•

Plaquemines LNG should file a request for written authorization from the
Director of OEP prior to unloading or loading the first LNG commissioning cargo.
After production of first LNG, Plaquemines LNG should file weekly reports on
the commissioning of the proposed systems that detail the progress towarddemonstrating the facilities can safely and reliably operate at or near the design
production rate. The reports should include a summary of activities, problems
encountered, and remedial actions taken. The weekly reports should also include
the latest commissioning schedule, including projected and actual LNG
production by each liquefaction train, LNG storage inventories in each storagetank, and the number of anticipated and actual LNG commissioning cargoes,along with the associated volumes loaded or unloaded. Further, the weekly
reports should include a status and list of all planned and completed safety andreliability tests, work authorizations, and punch list items. Problems of significant
magnitude should be reported to FERC within 24 hours.

•

Prior to commencement of service, Plaquemines LNG should label piping withfluid service and direction of flow in the field, in addition to the pipe labelingrequirements of NFPA 59A (2001 edition).

•

Prior to commencement of service, Plaquemines LNG should file any preventive
and predictive maintenance program that performs periodic or continuous
equipment condition monitoring to ensure mechanical integrity of equipment.

•

Prior to commencement of service, Plaquemines LNG should file procedures foroffsite contractors’ responsibilities, restrictions, and limitations and forsupervision of these contractors by Plaquemines LNG staff.

•

Prior to commencement of service, Plaquemines LNG should notify FERC staff
of any proposed revisions to the security plan and physical security of the plant.

•

Prior to commencement of service, Plaquemines LNG should file a request for
written authorization from the Director of OEP. Such authorization would only
be granted following a determination by the USCG, under its authorities under
the Ports and Waterways Safety Act, the Magnuson Act, the Maritime
Transportation Security Act of 2002, and the Security and Accountability For
Every Port Act, that appropriate measures to ensure the safety and security of the
facility and the waterway have been put into place by Plaquemines LNG or otherappropriate parties.

In addition, we recommend that the following measures should apply throughout the life of
the facility.
•

The facility should be subject to regular FERC staff technical reviews and site
inspections on at least an annual basis or more frequently as circumstancesindicate. Prior to each FERC staff technical review and site inspection,
Plaquemines LNG should respond to a specific data request including information
relating to possible design and operating conditions that may have been imposedby other agencies or organizations. Up-to-date detailed P&IDs reflecting facility
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modifications and provision of other pertinent information not included in thesemi-annual reports described below, including facility events that have takenplace since the previously submitted semi-annual report, should be submitted.
•

Semi-annual operational reports should be filed to identify changes in facility
design and operating conditions; abnormal operating experiences; activities (e.g.,
LNG marine vessel arrivals, quantity and composition of imported and exported
LNG, liquefied and vaporized quantities, boil off/flash gas); and plantmodifications, including future plans and progress thereof. Abnormalities should
include, but not be limited to, unloading/loading/shipping problems, potential
hazardous conditions from offsite vessels, storage tank stratification or rollover,geysering, storage tank pressure excursions, cold spots on the storage tanks,storage tank vibrations and/or vibrations in associated cryogenic piping, storagetank settlement, significant equipment or instrumentation malfunctions or
failures, non-scheduled maintenance or repair (and reasons therefore), relative
movement of storage tank inner vessels, hazardous fluids releases, fires involving
hazardous fluids and/or from other sources, negative pressure (vacuum) within astorage tank, and higher than predicted boil-off rates. Adverse weather
conditions and the effect on the facility also should be reported. Reports should
be submitted within 45 days after each period ending June 30 and December 31.
In addition to the above items, a section entitled “Significant Plant Modifications
Proposed for the Next 12 Months (dates)” should be included in the semi-annual
operational reports. Such information would provide FERC staff with early
notice of anticipated future construction/maintenance at the LNG facilities.

•

In the event the temperature of any region of any secondary containment,
including imbedded pipe supports, becomes less than the minimum specified
operating temperature for the material, the Commission should be notified within
24 hours and procedures for corrective action should be specified.

•Significant non-scheduled events, including safety-related incidents (e.g., LNG,
condensate, refrigerant, or natural gas releases; fires; explosions; mechanicalfailures; unusual over pressurization; and major injuries) and security-related
incidents (e.g., attempts to enter site, suspicious activities) should be reported to
FERC staff. In the event that an abnormality is of significant magnitude tothreaten public or employee safety, cause significant property damage, orinterrupt service, notification should be made immediately, without unduly
interfering with any necessary or appropriate emergency repair, alarm, or otheremergency procedure. In all instances, notification should be made to FERC staff
within 24 hours. This notification practice should be incorporated into the LNG
facility’s emergency plan. Examples of reportable hazardous fluids-related
incidents include:a. fire;b. explosion;c. estimated property damage of $50,000 or more;d. death or personal injury necessitating in-patient hospitalization;e. release of hazardous fluids for 5 minutes or more;

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f. unintended movement or abnormal loading by environmental causes, such as
an earthquake, landslide, or flood, that impairs the serviceability, structural
integrity, or reliability of a facility that contains, controls, or processes
hazardous fluids;
g. any crack or other material defect that impairs the structural integrity or
reliability of a facility that contains, controls, or processes hazardous fluids;
h. any malfunction or operating error that causes the pressure of a pipeline or
LNG facility that contains or processes hazardous fluids to rise above its
maximum allowable operating pressure (MAOP; or working pressure forfacilities) plus the build-up allowed for operation of pressure-limiting orcontrol devices;
i. a leak in a facility that contains or processes hazardous fluids that constitutes
an emergency;
j. inner tank leakage, ineffective insulation, or frost heave that impairs the
structural integrity of an LNG storage tank;k. any safety-related condition that could lead to an imminent hazard and cause(either directly or indirectly by remedial action of the operator), for purposes
other than abandonment, a 20 percent reduction in operating pressure or
shutdown of operation of a pipeline or a facility that contains or processes
hazardous fluids;
l. safety-related incidents from hazardous fluids transportation occurring at or
en route to and from the LNG facility; orm. an event that is significant in the judgment of the operator and/or management
even though it did not meet the above criteria or the guidelines set forth in an
LNG terminal’s incident management plan.
In the event of an incident, the Director of OEP has delegated authority to takewhatever steps are necessary to ensure operational reliability and to protect
human life, health, property, or the environment, including authority to direct the
LNG facility to cease operations. Following the initial company notification,
FERC staff would determine the need for a separate follow-up report or follow up
in the upcoming semi-annual operational report. All company follow-up reports
should include investigation results and recommendations to minimize areoccurrence of the incident.
4.12.6 Conclusions on LNG Reliability and LNG Carrier Reliability and Safety
As part of the NEPA review, Commission staff assesses the potential impact on the humanenvironment in terms of safety and whether the proposed facilities would operate safely, reliably,and securely.
As a cooperating agency, the DOT assisted FERC staff by determining whether
Plaquemines LNG’s proposed design would meet the DOT’s 49 CFR 193 Subpart B siting
requirements. On April 3, 2019, the DOT issued an LOD to FERC regarding the proposed
Project’s compliance with the 49 CFR 193, Subpart B regulatory requirements. The LOD provides
PHMSA’s analysis and conclusions regarding 49 CFR 193, Subpart B regulatory requirements,
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including the determination of legal control of exclusion zones, for the Commission’s
consideration in its decision on the Project application. If the Project is authorized, constructed,
and operated, the facility would be subject to the DOT’s inspection and enforcement program andfinal determination of whether a facility is in compliance with the requirements of 49 CFR Part
193 would be made by the DOT staff.
As a cooperating agency, the USCG also assisted FERC staff by reviewing the proposed
LNG terminal and the associated LNG carrier traffic. The USCG reviewed a Waterway Suitability
Assessment submitted by Plaquemines LNG that focused on the navigation safety and maritime
security aspects of LNG carrier transits along the affected waterway. On January 23, 2017, the
USCG issued a Letter of Recommendation to FERC staff indicating the Lower Mississippi River
could be made suitable for accommodating the type and frequency of LNG marine traffic
associated with this Project, based on the WSA and in accordance with the guidance in the USCG’s
NVIC 01-11. If the Project is authorized, constructed, and operated, the facility would be subject
to the USCG’s inspection and enforcement program to ensure compliance with the requirementsof 33 CFR Part 105 and 33 CFR Part 127.
FERC staff conducted a preliminary engineering and technical review of the Plaquemines
LNG design, including potential external impacts based on the site location. Based on this review,
we recommend the Commission consider incorporating into the order a number of proposed
mitigation measures to be implemented prior to initial site preparation, prior to construction of
final design, prior to commissioning, prior to introduction of hazardous fluids, prior tocommencement of service, and throughout life of the facility to enhance the reliability and safetyof the facility to mitigate the risk of impact on the public. Based on our external impact analysis
and preliminary evaluations of the engineering design and with the incorporation of thesemitigation measures and oversight, we conclude that the Plaquemines LNG terminal design would
include acceptable layers of protection or safeguards that would reduce the risk of a potentiallyhazardous scenario from developing into an event that could impact the offsite public.
4.12.7 Pipeline System Safety
The transportation of natural gas by pipeline involves some incremental risk to the public
due to the potential for accidental release of natural gas. The greatest hazard is a fire or explosion
following a major pipeline rupture.
Methane, the primary component of natural gas, is colorless, odorless, and tasteless. It is
not toxic, but is classified as a simple asphyxiate, possessing a slight inhalation hazard. If breathedin high concentration, oxygen deficiency can result in serious injury or death
Methane has an auto-ignition temperature of 1,000 degrees Fahrenheit and is flammable atconcentrations between 5.0 percent and 15.0 percent in air. An unconfined mixture of methane
and air is not explosive; however, it may ignite and burn if there is an ignition source. A flammableconcentration within an enclosed space in the presence of an ignition source can explode. It isbuoyant at atmospheric temperatures and disperses rapidly in air.

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4.12.7.1 Safety Standards
The DOT is mandated to prescribe minimum safety standards to protect against risks posedby pipeline facilities under Title 49, U.S.C. Chapter 601. The DOT’s PHMSA administers thenational regulatory program to ensure the safe transportation of natural gas and other hazardous
materials by pipeline. It develops safety regulations and other approaches to risk management that
ensure safety in the design, construction, testing, operation, maintenance, and emergency responseof pipeline facilities. Many of the regulations are written as performance standards that set thelevel of safety to be attained and allow the pipeline operator to use various technologies to achievesafety. The PHMSA’s safety mission is to ensure that people and the environment are protectedfrom the risk of pipeline incidents. This work is shared with state agency partners and others at
the federal, state, and local level.
Title 49, U.S.C. Chapter 601 provides for a state agency to assume all aspects of the safety
program for intrastate facilities by adopting and enforcing the federal standards. A state may also
act as DOT’s agent to inspect interstate facilities within its boundaries; however, the DOT is
responsible for enforcement actions. Louisiana has delegated authority to inspect interstate
pipeline facilities.
The DOT pipeline standards are published in Parts 190-199 of Title 49 of the CFR. Part
192 specifically addresses natural gas pipeline safety issues.
Under a MOU on Natural Gas Transportation Facilities (Memorandum) dated January 15,
1993, between the DOT and FERC, the DOT has the exclusive authority to promulgate federal
safety standards used in the transportation of natural gas. Section 157.14(a)(9)(vi) of FERC’sregulations require that an applicant certify that it will design, install, inspect, test, construct,
operate, replace, and maintain the facility for which a Certificate is requested in accordance withfederal safety standards and plans for maintenance and inspection. Alternatively, an applicant
must certify that it has been granted a waiver of the requirements of the safety standards by the
DOT in accordance with section 3(e) of the Natural Gas Pipeline Safety Act. FERC accepts thiscertification and does not impose additional safety standards. If the Commission becomes awareof an existing or potential safety problem, there is a provision in the Memorandum to promptly
alert DOT. The Memorandum also provides for referring complaints and inquiries made by stateand local governments and the general public involving safety matters related to pipelines under
the Commission’s jurisdiction.
FERC also participates as a member of the DOT’s Technical Pipeline Safety Standards
Committee, which determines if proposed safety regulations are reasonable, feasible, andpracticable.
The pipeline and aboveground facilities associated with the Project must be designed,
constructed, operated, and maintained in accordance with the DOT’s Minimum Federal Safety
Standards for the Transportation of Natural and Other Gas by Pipeline in 49 CFR 192. The
regulations are intended to ensure adequate protection for the public and to prevent natural gas
facility accidents and failures. The DOT specifies material selection and qualification; minimum
design requirements; and protection from internal, external, and atmospheric corrosion.

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The DOT also defines area classifications, based on population density in the vicinity ofthe pipeline, and specifies more rigorous safety requirements for populated areas. The classlocation unit is an area that extends 220 yards on either side of the centerline of any continuous 1mile length of pipeline. The four area classifications are defined below:
Class 1

Location with 10 or fewer buildings intended for human occupancy.

Class 2

Location with more than 10 but less than 46 buildings intended for humanoccupancy.

Class 3

Location with 46 or more buildings intended for human occupancy or where
the pipeline lies within 100 yards of any building, or small well-defined outside
area occupied by 20 or more people on at least 5 days a week for 10 weeks inany 12-month period.

Class 4

Location where buildings with four or more stories aboveground are prevalent.

Class locations representing more populated areas require higher safety factors in pipeline
design, testing, and operation. For instance, pipelines constructed on land in Class 1 locations
must be installed with a minimum depth of cover of 30 inches in normal soil and 18 inches in
consolidated rock. Class 2, 3, and 4 locations, as well as drainage ditches of public roads andrailroad crossings, require a minimum cover of 36 inches in normal soil and 24 inches in
consolidated rock.
Class locations also specify the maximum distance to a sectionalizing block valve (e.g.,
10.0 miles in Class 1, 7.5 miles in Class 2, 4.0 miles in Class 3, and 2.5 miles in Class 4). Pipewall thickness and pipeline design pressures; hydrostatic test pressures; MAOP; inspection andtesting of welds; and frequency of pipeline patrols and leak surveys must also conform to higher
standards in more populated areas.
Currently, the entire pipeline system is in a Class 1 location. If a subsequent increase inpopulation density adjacent to the right-of-way results in a change in class location for the pipeline,
the operator would reduce the MAOP or replace the segment with pipe of sufficient grade and wall
thickness, if required to comply with DOT requirements for the new class location.
The US DOT’s Pipeline Safety Regulations require operators to develop and follow a
written integrity management program that contain all the elements described in 49 CFR 192.911
and address the risks on each transmission pipeline segment. The rule establishes an integrity
management program that applies to all high consequence areas (HCAs).
The DOT has published rules that define HCAs where a gas pipeline accident could do
considerable harm to people and their property and requires an integrity management program tominimize the potential for an accident. This definition satisfies, in part, the Congressional mandate
for DOT to prescribe standards that establish criteria for identifying each gas pipeline facility in ahigh-density population area.
The HCAs may be defined in one of two ways. In the first method an HCA includes:

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•

current class 3 and 4 locations;•any area in Class 1 or 2 where the potential impact radius 37 is greater than 660 feet andthere are 20 or more buildings intended for human occupancy within the potential
impact circle 38; or•any area in Class 1 or 2 where the potential impact circle includes an identified site.

An identified site is an outside area or open structure that is occupied by 20 or more persons
on at least 50 days in any 12-month period; a building that is occupied by 20 or more persons on
at least 5 days a week for any 10 weeks in any 12-month period; or a facility that is occupied bypersons who are confined, are of impaired mobility, or would be difficult to evacuate.
In the second method, an HCA includes any area within a potential impact circle, whichcontains:•

20 or more buildings intended for human occupancy; or•an identified site.

Once a pipeline operator has determined the HCAs along its pipeline, it must apply theelements of its integrity management program to those segments of the pipeline within HCAs. The
DOT regulations specify the requirements for the integrity management plan at section 192.911.
The pipeline integrity management rule for HCAs requires inspection of the pipeline HCAs every
7 years.
Currently, there are no HCAs along the pipeline system.
The DOT prescribes the minimum standards for operating and maintaining pipeline
facilities, including the requirement to establish a written plan governing these activities. Eachpipeline operator is required to establish an emergency plan that includes procedures to minimize
the hazards of a natural gas pipeline emergency. Key elements of the plan include procedures for:•receiving, identifying, and classifying emergency events, gas leakage, fires, explosions,and natural disasters;•

establishing and maintaining communications with local fire, police, and public
officials, and coordinating emergency response;•

emergency system shutdown and safe restoration of service;•

making personnel, equipment, tools, and materials available at the scene of an
emergency; andThe potential impact radius is calculated as the product of 0.69 and the square root of the MAOP of the pipeline inpsig multiplied by the square of the pipeline diameter in inches.
38
The potential impact circle is a circle of radius equal to the potential impact radius.
37

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•

protecting people first and then property, and making them safe from actual or potential
hazards.

The DOT requires that each operator establish and maintain liaison with appropriate fire,police, and public officials to learn the resources and responsibilities of each organization that may
respond to a natural gas pipeline emergency, and to coordinate mutual assistance. The operator
must also establish a continuing education program to enable customers, the public, government
officials, and those engaged in excavation activities to recognize a gas pipeline emergency andreport it to appropriate public officials. Plaquemines LNG would provide the appropriate training
to local emergency service personnel before the pipeline is placed in service.
4.12.7.2 Pipeline Accident Data
The DOT requires all operators of natural gas transmission pipelines to notify DOT of any
significant incident and to submit a report within 30 days. Significant incidents are defined as any
leaks that:•caused a death or personal injury requiring hospitalization; or•involved property damage of more than $50,000 (1984 dollars). 39

During the 20-year period from 1995 through 2014, a total of 1,265 significant incidents
were reported on the more than 300,000 total miles of natural gas transmission pipelines
nationwide.
Additional insight into the nature of service incidents may be found by examining the
primary factors that caused the failures. Table 4.12-1 provides a distribution of the causal factors
as well as the number of each incident by cause.
The dominant causes of pipeline incidents are corrosion and pipeline material, weld or
equipment failure constituting 49.6 percent of all significant incidents. The pipelines included in
the data set in table 4.12-1 vary widely in terms of age, diameter, and level of corrosion control.
Each variable influences the incident frequency that may be expected for a specific segment ofpipeline.
The frequency of significant incidents is strongly dependent on pipeline age. Olderpipelines have a higher frequency of corrosion incidents and material failure, because corrosion
and pipeline stress/strain is a time-dependent process.

39$50,000 in 1984 dollars is approximately $112,955.73 as of May 2015 (CPI, Bureau of Labor Statistics, 2015).

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Table 4.12-1
Natural Gas Transmission Pipeline Significant Incidents by Cause (1996-2015) a
Cause

Number of Incidents

Percentage

Pipeline material, weld, or equipment failure

354

27.0

Corrosion

311

23.7

Excavation

210

16.0

All other causes b

165

12.6

Natural forces c

146

11.1

Outside force d

84

6.4

Incorrect operation

40

3.1

Total

1,310

100

a All data gathered from PHMSA’s Oracle BI Interactive Dashboard website for Significant Transmission Pipeline Incidents,
https://hip.phmsa.dot.gov/analyticsSOAP/saw.dll?Portalpages&NQUser=PDM_WEB_USER&NQPassword=Public_Web_
User1&PortalPath=%2Fshared%2FPDM%20Public%20Website%2F_portal%2FSC%20Incident%20Trend&Page=Signific
ant&Action=Navigate&col1=%22PHP%20-%20Geo%20Location%22.%22State%20Name%22&val1=%22%22
b All other causes include miscellaneous, unspecified, or unknown causes.
c Natural force damage includes earth movement, heavy rain, floods, landslides, mudslides, lightning, temperature, highwinds, and other natural force damage.
d Outside force damage includes previous mechanical damage, electrical arcing, static electricity, fire/explosion,
fishing/maritime activity, intentional damage, and vehicle damage (not associated with excavation).

The use of both an external protective coating and a cathodic protection system, 40 requiredon all pipelines installed after July 1971, significantly reduces the corrosion rate compared tounprotected or partially protected pipe.
Outside force, excavation, and natural forces are the cause in 34.2 percent of significant
pipeline incidents. These result from the encroachment of mechanical equipment such as
bulldozers and backhoes; earth movements due to soil settlement, washouts, or geologic hazards;
weather effects such as winds, storms, and thermal strains; and willful damage. Table 4.12-2
provides a breakdown of external force incidents by cause.
Older pipelines have a higher frequency of outside forces incidents partly because theirlocation may be less well known and less well marked than newer lines. In addition, the older
pipelines contain a disproportionate number of smaller-diameter pipelines, which have a greaterrate of outside forces incidents. Small diameter pipelines are more easily crushed or broken bymechanical equipment or earth movement.
Since 1982, operators have been required to participate in “One Call” public utility
programs in populated areas to minimize unauthorized excavation activities in the vicinity ofpipelines. The “One Call” program is a service used by public utilities and some private sector
companies (e.g., oil pipelines and cable television) to provide preconstruction information to40

Cathodic protection is a technique to reduce corrosion (rust) of the natural gas pipeline through the use of an
induced current or a sacrificial anode (like zinc) that corrodes at faster rate to reduce corrosion.

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contractors or other maintenance workers on the underground location of pipes, cables, andculverts.
Table 4.12-2
Excavation, Natural Forces, and Outside Force Incidents by Cause (1996-2015) a

Cause

Number of Excavation,
Natural Forces, andOutside Force Incidents

Percentage ofAll Incidents b,cThird party excavation damage

172

13.1

Heavy rain, floods, mudslides, landslides

74

5.7

Vehicle (not engaged with excavation)

49

3.7

Earth movement, earthquakes, subsidence

32

2.4

Lightning, temperature, high winds

27

2.1

Operator/contractor excavation damage

25

1.9

Unspecified excavation damage/previous damage

13

1.0

Other or unspecified natural forces

13

1.0

Fire/explosion

9

0.7

Fishing or maritime activity

9

0.7

Other outside force

9

0.7

Previous mechanical damage

6

0.5

Electrical arcing from other equipment/facility1

0.1

Intentional damage

1

0.1

Total

440

33.5

a All data gathered from PHMSA’s Oracle BI Interactive Dashboard website for Significant Transmission Pipeline Incidents, .
b Percentage of all incidents was calculated as a percentage of the total number of incidents natural gas transmission pipeline
significant incidents (i.e., all causes) presented in table 4.12-1.
c Due to rounding, column does not equal 33.6 percent.

4.12.7.3 Impact on Public Safety
The service incidents data summarized in table 4.12-1 include natural gas transmission
system failures of all magnitudes with widely varying consequences.
Table 4.12-3 presents the annual injuries and fatalities that occurred on natural gas
transmission lines from incidents for the 5-year period between 2010 and 2014. The majority offatalities from pipelines are due to local distribution pipelines not regulated by FERC. These arenatural gas pipelines that distribute natural gas to homes and businesses after transportation
through interstate natural gas transmission pipelines. In general, these distribution lines are smaller
diameter pipes and/or plastic pipes, which are more susceptible to damage. Local distribution
systems do not have large rights-of-way and pipeline markers common to FERC regulated natural
gas transmission pipelines. Therefore, incident statistics inclusive of distribution pipelines areinappropriate to use when considering natural gas transmission projects.

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Table 4.12-3
Injuries and Fatalities – Natural Gas Transmission Pipelines a
Injuries

Fatalities

Year

Employees

PublicEmployees

Public

2011

1

0

0

0

2012

3

4

0

0

2013

0

2

0

0

2014

1

0

1

0

2015

12

2

6

0

a All data gathered from PHMSA Pipeline Incident Flagged Files (USDOT, 2015).

The nationwide totals of accidental fatalities from various anthropogenic and natural
hazards are listed in table 4.12-4 in order to provide a relative measure of the industry-wide safetyof natural gas transmission pipelines. Direct comparisons between accident categories should bemade cautiously, however, because individual exposures to hazards are not uniform among all
categories. The data nonetheless indicate a low risk of death due to incidents involving natural
gas transmission pipelines compared to the other categories. Furthermore, the fatality rate is much
lower than the fatalities from natural hazards such as lightning, tornados, or floods.
The available data show that natural gas transmission pipelines continue to be a safe,
reliable means of energy transportation. From 1996 to 2015, there were an average of 65
significant incidents, nine injuries and two fatalities per year. The number of significant incidents
over the more than 303,000 miles of natural gas transmission lines indicates the risk is low for an
incident at any given location. The operation of the pipeline system would represent a slightincrease in risk to the nearby public.

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Table 4.12-4
Nationwide Accidental Fatalities by Cause
Type of Accident

Annual Number of Deaths

All unintentional deaths

146,571

Motor vehicle a

35,369Poisoning a38,851

Falls a30,208Pedestrians from vehicle crashb

5,977

Drowning a3,391

Fire, smoke inhalation, burns a

2,760

Floods c

81

Tornado c

72

Lightning c49

Hurricane c

47

Natural gas distribution lines d

13

Natural gas transmission pipelines d

2

a Accident data presented for motor vehicle, poisoning, falls, drowning, fire, smoke inhalation, and burns represent the annual
accidental deaths recorded in 2013 (Centers for Disease Control and Prevention, 2013)b National Highway Traffic Safety Administration 2017 data, October 2018c Accident data presented for floods, tornados, lightning, and hurricanes represent the 30-year average of accidental deaths
between 1985 and 2014 (NOAA, 2016)d Accident data presented for natural gas distribution lines and transmission pipelines represent the 20-year average between 1996
and 2015 (USDOT, 2016b)

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4.13

CUMULATIVE IMPACTS

In accordance with NEPA, we considered the cumulative impacts of the Project with otherprojects or actions within the geographic and temporal scope of the Project. As defined by CEQ,
a cumulative effect is the impact on the environment that results from the incremental effects ofthe proposed action when added to other past, present, and reasonably foreseeable actions,regardless of what agency or person undertakes such actions (CEQ, 1997). Although theindividual impact of each separate project may be minor, the additive effects of multiple projects
can be significant. The potential direct and indirect impacts of the Project on environmental
resources are described in previous sections of this EIS.
The purpose of this analysis is to identify and describe cumulative impacts that would
potentially result from construction and operation of the Project. Inclusion of actions is based on
identifying commonalities of impacts from other actions to the Venture Global’s potential impacts
on various environmental resources. To ensure that the analysis focuses on relevant projects andpotentially significant impacts, this cumulative impacts analysis includes other actions meeting thefollowing criteria:•

the action impacts a resource that would be affected by the Project;•

the action causes impacts within all or part of the geographic scope of the Project; and•the action causes impacts within all or part of the temporal scope of the Project.

The regional landscape in the Project area has been significantly altered since the latter partof the nineteenth century, initially by agriculture and later by the development of industrial
complexes, oil and gas support facilities, port facilities, residential and commercial centers, andattendant public infrastructure (schools, hospitals, roads, etc.). These developments, along withassociated upgrades to flood protection and drainage systems (levees, ditches, pumping stations,etc.), have had a permanent impact on the regional landscape. Consistent with CEQ guidelines(2005), we have aggregated past actions that helped shape the current environment into our
discussion of the affected environment in section 4.0. Thus, we discuss present and reasonably
foreseeable actions in this section.
Based on our evaluations in section 4.0, the Project would have negligible or no impacts
on groundwater, recreation, and cultural resources. As a result, the Project would not contributeto potentially significant cumulative effects on these three resources. However, the Project could
contribute incrementally to cumulative impacts on other resources in the Project area.
Most present and reasonably foreseeable actions with impacts during the Project’s temporalextent would commence construction or operation during the Project’s construction period. One
exception is a recently announced container terminal that is so early in the planning phase we
assumed it would only overlap the Project’s operation period. The Project anticipates construction
would begin in 2019 and continue until late 2023. Operation of Phase I facilities would commencein 2022, and Phase II facilities would be operational by 2023. The Project would continue
operations for at least 30 years. Thus, actions identified in this assessment were those for which
publicly available sources indicated that (i) some portion of construction would occur during years

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2019-2023, or (ii) some phase of operation would commence in 2019 or later. We also considered
actions that commenced operation in 2017 or 2018 because their effects may not have been realizedprior to the analyses in section 4.0.
Actions with resource impacts within the same geographic scope as the Project would occur
within a prescribed distance from the Project, uniquely defined based on the characteristics of theresource and how far the Project’s effects might extend. Geographic scope, then, defines how far
out from the Project a cumulative impact could occur. Table 4.13-1 provides the geographic scopefor each resource and the reasoning behind its establishment.
As in section 4.1 through 4.12, we use specific terms to describe the intensity and durationof cumulative impacts. The intensity of a cumulative impact could be negligible, minor, moderate,or significant. The duration of a cumulative impact could be temporary, short term, or long term
if the resource would return to its preconstruction condition; otherwise, the impact would bepermanent. Temporary impacts may continue for a few months after construction. For ecologicaland physical resources, short-term impacts could extend up to 3 years, and long-term impacts
would last longer than 3 years. For socioeconomic resources, a short-term impact could extend up
to 5 years, and a long-term impact would continue after 5 years.
Table 4.13-1
Resource-Specific Geographic Scope and Temporal Extent of Project Impacts
Resource

Geographic Scope

Reasoning

Geology and Soils

Project workspace

Effects would not extend beyond the area of the
Project’s direct disturbance.

Groundwater

Aquifers within the HUC-12 subwatersheds
directly affected by the ProjectBecause an HUC-12 subwatershed is a localized
drainage basin, runoff, spills, etc., from the Project
could travel across affected HUC-12 subwatersheds
and affect aquifers beneath them.

Surface Waters andAquatic Wildlife andHabitatWaterbodies crossed by and downstream of
the Project that are within the HUC-12
subwatersheds directly affected by the
Project

Runoff, spills, discharges, etc., from the Project could
travel across affected HUC-12 subwatersheds anddrain into downstream waterbodies.

Wetlands

Wetlands within the HUC-12
subwatersheds directly affected by the
Project

Runoff, spills, discharges, etc., from the Project could
travel across affected HUC-12 subwatersheds andintercept wetlands.

Vegetation and Wildlife

Vegetation and wildlife communities within
the HUC-12 subwatersheds directly
affected by the Project

Runoff, spills, etc., from the Project could travel
across affected HUC-12 subwatersheds and intercept
the vegetative cover.

Land Use andRecreation

Land use within the broader west bankcommunity and land cover within the HUC12 subwatersheds directly affected by the
Project; recreation within 1.0 mile of the
Project

Land uses are planned at the community level; land
cover that is not yet paved is partially affected bywater flow patterns within the watershed or
subwatershed.

Visual Resources

Common viewpoints from which Project or
Project activities would be visible

Accounts for visual impacts at the viewshed level.

Socioeconomics

Plaquemines Parish and, to a lesser extent,
Jefferson and Orleans parishes

Economic, housing, and public service impacts
distribute through local jurisdictions and are notconfined to the neighborhood or community around adevelopment.

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Table 4.13-1
Resource-Specific Geographic Scope and Temporal Extent of Project Impacts
Resource

Geographic Scope

Reasoning

Roadway TrafficWest bank in Plaquemines Parish

Traffic flow effects from the Project would primarily
impact SH 23, which runs the length of the west bank.

Vessel Traffic

Mississippi River in Plaquemines Parish
and waterways in the Barataria Basin

The LNG terminal would generate traffic along theriver, which would be concentrated in the reach
within the parish; the pipeline system would generate
traffic on west bank inland waterways.

Cultural Resources

Area of Potential Effect (as defined in
section 4.10)

See section 4.10

Construction

Concurrently constructed projects within
0.25 mile of the Project

Vehicle, vessel, and equipment emissions and dust
generated during construction would not travel farther
than 0.25 mile.

Operation

31-mile radius around LNG terminal

Matches EPA’s distance for cumulative modeling oflarge PSD sources during permitting.

Construction

Concurrently constructed projects within
0.25 mile of the Project and within 0.5 mileof HDD entry and exit points and piledriving activities

Distances represent the furthest construction noise
could potentially adversely affect NSAs, given thetemporary duration.

Operation

1.0-mile radius around LNG terminal

Distance represents the furthest that operation noise
could potentially adversely affect NSAs, given thepermanent duration.

Air Quality

Noise

Key:
EPA = U.S. Environmental Protection Agency
HDD = horizontal directional drilling
HUC = hydrologic unit code
NSA= noise-sensitive area
PSD = prevention of significant deterioration
SH = State Highway

4.13.1 Projects and Activities ConsideredThis analysis identified several different types of present, proposed, and permitted actions
that could cause a cumulative impact when considered along with the Project. The actions were
provided by Venture Global and by a general literature review of several online website sources
including, but not limited to:• FERC eLibrary;
•

LDEQ;

•

Louisiana Economic Development;•

USACE Regulatory Public Notices;•

Greater New Orleans, Inc., Regional Economic Development;

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•

Plaquemines Association of Business and Industry; and

•

CPRA.

Table 4.13-2 summarizes the actions that have the potential for cumulative impacts becauseof their location and timing. The actions are mapped on figure 4.13-1. Of the 16 total actions,
including the Project, there are:•two non-jurisdictional facilities associated with the Project;•seven major industrial developments;•

one major transportation project;•

two drainage and shoreline protection projects;•

four wetland mitigation and restoration projects; and•one dredging project.

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Table 4.13-2
Present and Future Actions Considered in the Cumulative Impact Analysisa

Action/
Proponent

ClosestDistance to
Project(Location)

Project Type

Estimated
Construction
Period or Start
Date (years)b

Description

Estimated
Operation
Period orStart Date(years)Action Site(acres, feet,or miles)cResources thatMay BeCumulatively
Affectedd

Plaquemines LNG
and Gator Express
Pipeline Project0 miles

Major
Industrial

Project nameplate capacity of 20.0 MTPA LNG
export capacity

2019–2023

2022 (Phase I)

637 acres –LNG terminal
27 milespipeline
systemAll except
groundwater,
recreation, andcultural resourcesEntergy Electric
Utility Connection/
Entergy Louisiana,
LLC

0 miles,tie-in at LNG
terminal

Nonjurisdictional
Utility Line

Temporary tie-in using a 1,500-foot-long electricalline from an existing power line on SH 23 to atemporary construction electrical distribution center
within the LNG terminal site. Ground disturbancewould involve an electrical junction box, meters, andassociated equipment. Following start-up of the
LNG terminal power plant, the temporary line would
be removed.

2019

2019–2021

1,500 feetwithin projectworkspace

None - the disturbed
resources areaccounted for in theevaluation of the
LNG terminal insections 4.1 through
4.12.

Plaquemines Parish
Water Line
Connection/
Plaquemines Parish
Water Works

0 miles,tie-in at LNG
terminal

Nonjurisdictional
Utility Line

Temporary or permanent tie-in using a 1,500-footlong aboveground pipeline from an existing waterline along SH 23 to a distribution point at the LNG
terminal site. Installation would require temporary
ground disturbance.
StatusVenture Global’s evaluation of water supply sources
is ongoing, as are discussions with the parish; the1,500-foot-long tie-in is one option of threealternatives and may not be selected.

2019

2019–2024

1,500 feetwithin projectworkspace

None - the disturbed
resources areaccounted for in theevaluation of the
LNG terminal insections 4.1 through
4.12.

NOLA Oil
Terminal/
NOLA Oil
Terminal, LLC

4 milesnorthwest of
LNG
terminal(west bank )Major
Industrial

New bulk liquid petroleum product blending,storage, and transfer terminal with up to 54 storage
tanks having up to 8.2 million barrels capacity. Thismarine loading operation would receive various oil
products (e.g., fuel oil, crude oil, heavy oil carbon
black feedstock, and other materials) from barge orship. Site still lacks feedstock pipeline connection.
Permit status
2013: LDEQ Title V air and USACE permits issued
2013: Plaquemines Parish building permit issued
2016: LPDES permit issued

Unavailable

Unavailable

128 acresSurface Water &Aquatic Wildlife;
Wetlands;
Veg & Wildlife;
Land Use;
Visual;Socioec - net benefit;
Road Traffic;
Vessel Traffic;
Air Quality;
Safety4-295

Information
about future
pipelineconnection
unavailable

Table 4.13-2
Present and Future Actions Considered in the Cumulative Impact Analysisa

Action/
Proponent
Braithwaite
Methanol Plant/
Castleton
Commodities
International
Port Nickel, LLC

18 milesnorth of
LNG
terminal(Braithwite,
east bank )Major
Industrial

New methanol manufacturing facility with 5,000metric ton daily production capacity (1.8 million tons
per annum). Feedstock natural gas to be supplied via
pipeline, although this connection has not been
identified. The final product to be stored on-site
prior to being shipped off-site via marine vessels.
Market conditions became unfavorable in period
after permits first issued. The site is the former
Amax Nickel site.
Permit status
2014: LDEQ Title V air and USACE permits issued
2017: LDEQ issued extension of construction startdate (or binding agreement to construct) to June 29,
20192017: Extension requested for USACE permit

2019(extension
granted to delay
construction
start-datedeadline to June
2019)

2021
(construction
reported torequire 2 years)

36 acres

Gulf Coast
Methanol Complex/
IGP Methanol LLC

2 milesnorthwest of
LNG
terminal(MyrtleGrove, west
bank)

Major
Industrial

New methanol manufacturing facility with 200,000metric ton daily production capacity. Feedstock
natural gas to be supplied via ~13-mile-long lateral
to Tennessee Gas Pipeline near Happy Jack,Louisiana. The final product, pure methanol, to be
stored on-site prior to being shipped off-site via
marine vessels. At full build-out, four operating
units, each producing 1.8 million tons per annum.
Estimated construction period is 5–7 years, with eachphase staggered 12 months.
Permit status2018 LDEQ Title V air permit issued

2018–2025

2020 or 2021
(first phase)

140 acres –terminal

Project Type

Estimated
Construction
Period or Start
Date (years)b

Estimated
Operation
Period orStart Date(years)ClosestDistance to
Project(Location)

Description

4-296

Action Site(acres, feet,or miles)c

Information on
future pipeline
connection
unavailable~13 miles –pipeline

Resources thatMay BeCumulatively
Affectedd
Surface Water &Aquatic Wildlife
Wetlands;
Veg & Wildlife;
Socioec- net benefit;
Vessel Traffic;
Air Quality;

Surface Water &Aquatic Wildlife ;Wetlands;
Veg & Wildlife;
Land Use;
Visual;Socioec - net benefit;
Road Traffic;
Vessel Traffic;
Air Quality;
SafetyTable 4.13-2
Present and Future Actions Considered in the Cumulative Impact Analysisa

Action/
Proponent

ClosestDistance to
Project(Location)

Pointe Celeste
Container Terminal/
Plaquemines Port
Harbor andTerminal District
and American
Patriot Holdings
LLC

3 milessoutheast of
LNG
terminal

Pointe LNG/ Pointe
LNG LLC andPointe Pipeline
Company, LLC

8 milessoutheast of
LNG
terminal

Project Type

Action Site(acres, feet,or miles)cResources thatMay BeCumulatively
Affectedd

Container terminal equipped to receive 20,000
Twenty-Foot Equivalent Unit vessels or any postPanamax vessel with three berths exceeding 60 feet.
It would provide inland self-propelled vessel service
to deliver containers to and from other ports on
Mississippi and Illinois Rivers. Container terminal ispart of Port District’s plan to develop a modernized
port facility on 4,200 acres of Port property. The
Venture Global Project is considered one element of
the new port. The container terminal, along with anenvisioned breakbulk terminal, would comprise
1,000 acres.
StatusPre-feasibility studies conducted to demonstrateproject value. Current effort focused on attracting
investors and a terminal operator.

Unavailable:
overlap notassumed

Unavailable

Up to 1,000
acres

Surface Water &Aquatic Wildlife;
Wetlands;
Veg & Wildlife;
Land Use;
Visual;Socioec;
Road Traffic;
Vessel Traffic;
Air Quality;
SafetyMajor
Industrial

LNG export facility consisting of three liquefaction
trains with combined production capacity of 6.0
MTPA. Project will include two gas supply pipeline
laterals extending north and south, 3.2 miles and 3.4
miles respectively. Two LNG storage tanks of
160,000m3 will be onsite, which will be surrounded
by a floodwall. Power will be generated on-site bygas turbines.
The leased property is the site of the proposed
Louisiana LNG Project, which submitted a pre-filingprocess request in 2014 but was later abandoned.
The founders of Pointe LNG are the same foundersof the defunct Louisiana LNG.

2022–2025

2025

600 acresSocioec;
Vessel Traffic;
Air Quality;
SafetyMajor
Industrial

The Project will liquefy domestic natural gas
received from the new Delta Express Pipeline andstore and deliver LNG as needed to LNG carriers forexport overseas. The Delta Express Pipeline will
supply feed gas to the LNG terminal. It stretches
287 miles from Perryville, LA to the terminal site.

2021-2024

2024

524

Surface Water,
Habitat, Wetlands,
Aquatic Resources,
Socioec;
Vessel Traffic;
Air Quality;
Safety(PointeCeleste, westbank)Adjacent
Land

Description

Estimated
Operation
Period orStart Date(years)

Major
Industrial(east bank)

Delta LNG

Estimated
Construction
Period or Start
Date (years)b

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Table 4.13-2
Present and Future Actions Considered in the Cumulative Impact Analysisa

Action/
Proponent

ClosestDistance to
Project(Location)

Project Type

Description

Estimated
Construction
Period or Start
Date (years)b

Estimated
Operation
Period orStart Date(years)Mid-Barataria
Sediment Diversion
Project/
Louisiana Coastal
Protection and
Restoration
Authority

Diversion
structure:
5 milesnorthwest of
LNG
terminal;
Targeted
area: portionof theBarataria
Basin thatencompasses
the project(LowerMississippi
River andBarataria
Basin)

Wetland
Mitigation and
Restoration

Project would restore marshes in the Barataria Basinby reintroducing sediment and nutrients that
historically built up the area. Expected to reduce
land loss in portion of the Barataria Basin by 20,000
to 32,000 acres over 50 years. The project would
create an opening in the West Bank levee just northof Ironton, LA.
Permit status
October 2022: Target date for design completionand permit acquisition. Construction would startfollowing permits and take 2 to 4 years.

2022–2026

NOV/NFL
Hurricane Risk
Reduction ProjectLevee Upgrade/USACE

0 miles(adjacent topipelinesystem) and
0.3 mile
south of
LNG
terminal(total project
covers west
and east
banks)

Drainage andShoreline
Protection

In lower Plaquemines Parish, these complimentary
projects involve upgrading or restoring existing
levees and completing unconstructed authorized ones
to achieve storm risk reduction. Seven levee
reaches, comprising 58 miles, are being upgraded,either to a 20- to 25-year or 50-year storm level ofrisk reduction.

2012–2024

Ongoing(Levee segment
adjacent to theproject:
construction date
unavailable)(Leveesegment
adjacent to theproject: by2024)

Subset of NOV/NFL adjacent to the project(Plaquemines Parish non-federal levee project): 34
miles of levees from Oakville to St. Jude originallyconstructed by the parish to be replaced or modified,some of which will be incorporated into the NOV
federal system. Upgraded levee will be crossed by
the Southwest laterals. Construction began in 2012
and is scheduled to finish in 2024.
Status of levee segment adjacent to the project
In design as of December 2016.

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2026

Action Site(acres, feet,or miles)c
4.5 acres
20,000 to
32,000 acres –area benefited

58 milesaffected (notall within
geographic
scope)

Resources thatMay BeCumulatively
Affectedd
Surface Water &Aquatic Wildlife net benefit;
Wetlands - benefit;
Socioec - net benefit;
Air Quality

Surface Water &Aquatic Wildlife -net
benefit;
Wetlands;
Veg & Wildlife;
Land Use - benefit;
Road Traffic;
Air Quality;
Noise;
Safety - benefit

Table 4.13-2
Present and Future Actions Considered in the Cumulative Impact Analysisa

Action/
Proponent
NOV/NFL
Hurricane Risk
Reduction Project Wetland Mitigation/
USACE

ClosestDistance to
Project(Location)
1 mile westof pipeline
system(total projectcrosses fourparishes)

Estimated
Construction
Period or Start
Date (years)b

Project Type

Description

Wetland
Mitigation and
Restoration

Wetland mitigation projects for some, but not all, of
the NOV/NFL Hurricane Risk Reduction Project.
The Environmental Assessment #543 discusses theimpacts of creating and nourishing nine distinct
marshes, three of which are within the HUC-12
subwatersheds intersected by the project: Delfelice(345 acres brackish marsh); Coleman (230 acres
brackish marsh); Jesuit Bend (225 bottom land
hardwood-wet and 95 acres swamp). Dredge
material from 606 acres within Mississippi Riverwould provide sediment.

2019

Estimated
Operation
Period orStart Date(years)2021

Action Site(acres, feet,or miles)c
Acres within
geographic
scope forwetlands:
670 acres nonforested
wetlands

Resources thatMay BeCumulatively
Affectedd
Surface Water &Aquatic Wildlife benefit;
Wetlands - benefit;
Vessel Traffic

225 acres
forested
wetlands

NOV/NFL
Hurricane Risk
Reduction ProjectDrainage Canal
Relocation/
USACE and
Plaquemines Parish
Government

0 miles(adjacent topipelinesystem) and
0.3 mile
south of
LNG
terminal(west bank)

Drainage andShoreline
Protection

Because of the expansion of portions of the nonfederal levee base, the existing drainage canallocated on the levee’s protected side would be filled;
as part of the overall project, Plaquemines Parish
government would redirect the water flow to thecanal that fringes the southern edge of the terminal
and improve it to accommodate the additional flow.

Prior to August
2024

By August2024~1.8 acres(80,000 squarefeet)aSurface Water &Aquatic Wildlifebenefit;
Wetlands;
Road Traffic;
Noise;Air Quality;
Safety - benefit

Mississippi River
Ship Channel
Deepening, Venice
to Gulf/ USACE
andLouisiana
Department ofTransportation andDevelopment

35 milessoutheast of
the terminal(LowerMississippi
River)

Dredging

Increase depth from 45 feet to 50 feet in thesouthernmost segment of the Mississippi River shipchannel ~35 miles from river mile 13.4 above Headof Passes to river mile 22.0 below Head of Passes inSouthwest Pass. This is the next phase of
construction in an overarching plan to deepen the
majority of the ship channel from Baton Rouge to
Venice.
StatusDraft Integrated General Reevaluation Report andSupplemental Environmental Impact Statement wasissued November 2016.

Unavailable:
overlap notassumed

Unavailable~400-footlength of canalalong the 400foot pipeline
systemworkspace atthe pipe bridge

Vessel Traffic;
Socioec - benefit;
Air Quality;
Safety4-299

Table 4.13-2
Present and Future Actions Considered in the Cumulative Impact Analysisa

Action/
Proponent

ClosestDistance to
Project(Location)

Project Type

Description

Estimated
Construction
Period or Start
Date (years)b

Estimated
Operation
Period orStart Date(years)Action Site(acres, feet,or miles)cResources thatMay BeCumulatively
Affectedd

SH 23
Improvement
Project/ Louisiana
Department ofTransportation andDevelopment

10 milessoutheast of
terminal(Happy Jack
to PortSulphur,west bank)

Major
Transportation

Resurfacing 2-lane section of SH 23 between Happy
Jack and Port Sulphur, Louisiana (almost 4 miles),and adding turning lanes in Port Sulphur at Civic
Drive, Freeport Drive, and the entrance toPlaquemines Medical Center. Minor drainage work
included replacing deficient cross drains. SH 23 is
the main artery in the west bank and is theevacuation route.

Completed
March 20172017

4-mile-longroad section

Road Traffic benefit

Bayou Grande
Chenier Marsh andRidge Restoration/
Coastal Protection
and Restoration
Authority

2 miles eastof pipeline
system(west bank)

Wetland
Mitigation and
Restoration

Creating and nourishing marsh and forested ridge
habitat with dredged material from Mississippi
River. Material would be hydraulically dredged andpiped.

Unavailable

Unavailable

Total wetlands:
486 acresSurface Water &Aquatic Wildlife net benefit;
Wetlands - benefit;
Vessel Traffic;
Air Quality

342 acres –created

StatusConstruction services agreement signed in January
2015.

Approximately
132 acres –nourished
12 acres –forested ridge
creation

Barataria Bay Rim
MarshCreation andNourishment/
Coastal Protection
and Restoration
Authority

2 miles westof pipeline
system;adjacent tobarge routefor pipeline
systemconstruction(west bank)

Wetland
Mitigation and
Restoration

Creating marsh with dredged material from theBarataria Bay. The site is at the northwest end of theBarataria Bay, adjacent to Mud Lake.
StatusThe project was approved for Phase I engineeringand design in January 2016, and construction wasscheduled for November 2020 through November
2021, pending funding approval. However, an
update from Costal Protection shows status as“awaiting additional funding for implementation”
through end of 2021.

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2020-21, pending
funding

2021, pending
funding

Total wetlands:
517 acres
251 acres –created266 acres –nourished

Surface Water &Aquatic Wildlife net benefit;
Wetlands - benefit;
Vessel Traffic;
Air Quality

Table 4.13-2
Present and Future Actions Considered in the Cumulative Impact Analysisa

Action/
Proponent

ClosestDistance to
Project(Location)

Project Type

Estimated
Construction
Period or Start
Date (years)b

Description

Estimated
Operation
Period orStart Date(years)Action Site(acres, feet,or miles)cResources thatMay BeCumulatively
Affectedda This table lists those activities that are most likely to contribute to cumulative impacts within the vicinity of the Project; it is not intended to provide an all-inclusive listing of activities in the region.
b Actions with “unavailable” construction dates are assumed to undergo construction concurrent with Project construction, unless otherwise noted.
c Some of the area within a project site may not be disturbed or affected by an activity.
d Actions’ effects on listed resources are adverse unless otherwise noted as “benefit” or “net benefit,” implying some effect would be adverse.
e Abbreviated resource categories are as follows:
SurWater & Aquatic Wildlife = Surface Water and Aquatic Wildlife and Habitat
Veg & Wildlife = Vegetation and Wildlife
Socioec = Socioeconomics [jobs, revenues and stimulus, taxes, housing, and public services]
Safety = Safety and Reliability
Key:
HUC = hydrologic unit code
LDEQ = Louisiana Department of Environmental Quality
LNG = liquefied natural gas
LPDES = Louisiana Pollutant Discharge Elimination System
MTPA = million metric tons per annum
NFL = Non-Federal Levees
NOV = New Orleans to Venice
SH = State Highway
USACE = U.S. Army Corps of Engineers

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M:\Houston\Plaquemines_LNG\Maps\Mxds\Report_Figures\Cumulative_Overview.mxd

4/30/2019

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Non-jurisdictional, New Utility Lines to Serve Project1 Entergy Electric Utility Connection
2 Plaquemines Parish Water Line Connection
Other Projects, Non-Linear
3 New Orleans to Venice, Hurricane Protection, Drainage Canal Relocation
New Orleans to Venice, Louisiana Hurricane Protection, Wetland Mitigation:
4a Delfelice wetland
4b Coleman wetland
4c Jesuit Bend wetland
5 Gulf Coast Methanol
6 NOLA Oil Terminal
7 Pointe Celeste Container Terminal
8a Mid-Barataria Sediment Diversion Structure
8b Mid-Barataria Sediment Diversion Affected Area
9 Bayou Grande Chenier Marsh and Ridge Restoration
10 Barataria Bay Rim Marsh Creation and Nourishment
11 Braithwaite Methanol Plant
Other Projects, Linear
12 New Orleans to Venice, Louisiana Hurricane Protection Levee Upgrade
13 SH 23 Repavement and Turning Lane Addition
14 Mississippi River Ship Channel Deepening, Venice to Gulf
Other LNG
15 Pointe LNG
16 Delta LNG
Projects With Potential Cumulative Impacts Project Components and Buffers!
(

Non-linear Projects*

"
)
"
)

Linear Projects
Boundary of Project 8b*Boundaries delineated for selected projects

0

2.5

/
5

Interconnects

Parking Area for Pipeline Construction Employees
Laterals (TETCO & TGP)
Barge Access Channel - Dredge/Excavation Proposed
Barge Access Channel - No Dredge Required

10 MilesTerminal Site Boundary

14

0.25-mi buffer of Terminal and Pipeline
0.5-mi buffer of HDD entry/exit
0.5-mi buffer of Pipeline
1-mi buffer of Terminal
31-mi buffer of Terminal (air-operations)
HUC-12 Subwatersheds Intersected by Project

Figure 4.13-1

Projects with Potential
Cumulative Impacts
Plaquemines Parish,
Louisiana

Source: DigitalGlobe 2017, USGS 2018

As a simplifying assumption, we assumed permitted actions with unavailable construction
start dates would be constructed concurrently with the Project. However, we did not assume
concurrent construction with announced actions that are in an early planning stage and have not
filed a permit application. Rather, we assumed these actions would eventually operateconcurrently with the Project.
In the case of the Project and its vicinity, several planned actions identified within thegeographic and temporal scope would not likely compound adverse impacts of the Project suchthat they would cause long-term or permanent degradation of a local environmental resource. Of
the 14 identified actions, six are designed specifically to improve environmental quality or safety(i.e., the wetland nourishment and wetland creation actions and the levee and drainage canal
improvements). Construction associated with these improvements would generate vessel traffic
and associated air emissions and could adversely affect water quality and aquatic species during
construction. However, the chief effects of these actions would be the restoration of different
marsh types, improved surface water flow, and enhanced sedimentation patterns to mitigate
wetland and other land loss. Whether constructed concurrently with each other and the Project, orin sequence during Project construction, these actions have low potential for tipping the scale andresulting in significant adverse cumulative impacts.
4.13.1.1 Non-jurisdictional Activities
Non-jurisdictional facilities are those components of an interstate natural gas transmission
project or liquefied natural gas project that are not under the jurisdiction of FERC. The two nonjurisdictional actions—construction of an electrical utility tie-in and a water utility tie-in to serve
the LNG terminal—are negligible in scale compared with the LNG terminal and the other majorindustrial developments identified in the geographic and temporal extent. Each utility tie-in would
extend approximately 1,500 feet from existing utilities along SH 23, originating from the segmentof SH 23 that passes through the LNG terminal site. Thus, almost all ground disturbance would
occur within the LNG terminal site. The non-jurisdictional actions would not have any minor or
greater impacts beyond those already accounted for in the evaluation of the LNG terminal.
4.13.1.2 Major Transportation Projects
One major transportation project had temporal and geographic overlap with the Project.
The major transportation project—the recent resurfacing of SH 23 between Happy Jack and Port
Sulphur, Louisiana, and the addition of turn lanes at three intersections—could potentially enhanceor improve traffic flow in this part of lower Plaquemines Parish, a benefit to all potential
developments in the region. The SH 23 improvement was completed after Venture Global
conducted its LNG terminal and pipeline system transportation studies, so it was carried forwardin this cumulative effects analysis.
The dredging project, which involves deepening 35 miles of the Mississippi River shipchannel from the Gulf entrance to Venice, is intended to reduce transportation costs by decreasing
the need for bulk carriers, tankers, and container ships to “light load” in order to reach inland ports(USACE New Orleans District, 2016). It would also permit easier maneuvering and reduceshoaling between each maintenance dredging cycle. The dredging location, at least 35 miles fromthe LNG terminal, would not contribute cumulative effects during the excavation. When

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completed, however, the channel deepening would improve vessel maneuvering and reduce theincidence of shoaling. The overall effect on vessel counts is unknown, though we assume thecount of large vessels would increase. In balance, the dredging project would improve vesseltransportation along the ship channel, negating its potential to cause a significant adverse effectcumulatively with other actions.
4.13.1.3 Major Industrial Developments
The remaining actions are major industrial developments planned or proposed along thelower Mississippi River. Three have acquired permits from LDEQ or USACE, or both, one wasonly recently announced in 2017 and one in 2018. Although we acknowledge and discuss theother actions on our list, we focus much of our analysis and scrutiny on these five projects. Two
permitted actions are within 4 miles of the LNG terminal—the Gulf Coast Methanol Complex andNOLA Oil Terminal. NOLA Oil Terminal acquired its first federal permit in 2013 but has not yet
commenced construction. A feedstock pipeline is a critical limiting factor for the proposed bulk
liquid petroleum blending, storage, and transfer facility; and, to date, plans to construct or connect
one have not been made public. The Gulf Coast Methanol Complex, classified as a major air
emissions source, was issued an LDEQ air permit in January 2018. The methanol manufacturing
plant would receive natural gas from Tennessee Gas pipeline and extract and refine methanol for
use as a fuel, and as a fuel for plastics and other material manufacturing. The Braithwaite Methanol
Manufacturing Plant on the east bank in Braithwaite, 18 miles from the LNG terminal, acquired
its first major permit in 2014. However, the project is on hold as proponents seek financing. The
Point Celeste Terminal was only recently announced in 2017 as a joint partnership between
Plaquemines Port Harbor and Terminal District and American Patriot Holdings LLC to develop a
container ship terminal on port-owned property 3 miles from the LNG terminal. They plan tonegotiate agreements with upriver ports on the Mississippi, particularly in Memphis and St. Louis,
to create a more efficient system of inland cargo delivery and transportation that could attract
customers to the new container port. The parties are in the preliminary phase and seeking investor
interest. Pointe LNG was announced in 2018 and is located approximately 8 miles southeast of
the Project while Delta LNG was announced in 2019 and is located adjacent to Plaquemines LNG.
Both are expected to carry similar environmental impacts as the Project.
4.13.1.4 Drainage and Shoreline Protection Activities
Three drainage and shoreline protection activities are proposed or underway in the vicinityof the Project facilities.
The Mid-Barataria Sediment Diversion Project is proposed by the CPRA to restore theriverine and estuarine habitat between the Mississippi River and the Mid-Barataria basin. The
reintroduction of freshwater and sediment to reestablish the deltaic process is expected to build,sustain, and maintain land and mimic historic deltaic sediment deposition (CPRA, 2012). The
proposed diversion structure is approximately 5 miles northwest of the terminal site on the westbank of the Mississippi River, near river mile 61. Planning is underway, and completion of design
and permitting is expected in October 2022. Construction is expected to commence shortly
thereafter and last 2 to 4 years.

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The New Orleans to Venice (NOV/NFL) Hurricane Risk Reduction Project is proposed by
the USACE to provide storm risk reduction for Plaquemines Parish. The project involves
upgrading approximately 90 miles of existing federal and non-federal levees on the east and westbanks of the Mississippi River (USACE, 2016c). The geographic range of this activity will spanfrom Phoenix to Bohemia on the east bank, and from St. Jude to Venice on the west bank. This isan ongoing activity and the USACE began awarding contracts in 2012, with the most recent
contracts awarded in June 2016. Construction is anticipated to continue into 2024. Sections of
this activity are adjacent to the terminal site and will be crossed by the Southwest laterals.
This levee upgrade requires an expansion of the non-federal levee base during the
NOV/NFL Hurricane Risk Reduction Project that will fill the existing drainage canal on theprotected side, necessitating its relocation. Thus, the Plaquemines Parish government, with funds
from USACE, intends to redirect the water flow to the canal that fringes the southern edge of theterminal and, to accommodate the additional flow. To date, the construction schedule for thisactivity has not been announced, although funds for this work were released by the USACE in2016.
4.13.1.5 Marsh and Wetland Mitigation Activities
The NOV/NFL Hurricane Risk Reduction Project includes two wetland mitigation
projects. These two projects are sponsored by the USACE and involve regional wetland mitigation
initiatives totaling approximately 876 acres, including marsh creation, to offset the impacts of the
New Orleans to Venice, Louisiana, Hurricane Protection Project (BA-0067). Construction startup is scheduled for the 1st quarter of 2019, with completion scheduled for the 2nd quarter of 2021.
The Barataria Bay Rim Marsh Creation and Nourishment Project is sponsored by the
CPRA and NRCS. The project would use dredged material from Barataria Bay to create
approximately 251 acres of marsh and nourish approximately 266 acres of marsh to mitigate
wetland loss in the area (USACE, 2015; Louisiana Coastal Wetlands Conservation and Restoration
Task Force, 2016). The proposed site is located at the northwest end of Barataria Bay, adjacent to
Mud Lake, and is approximately 9.6 miles southwest of the terminal site. Construction isscheduled for the 4th quarter of 2020 through the 4th quarter of 2021, pending funding approval.
The Bayou Grande Chenier Marsh and Ridge Restoration Project (BA-173) is sponsoredby the CPRA and U.S. Fish and Wildlife Service. The project will create approximately 342 acresof marsh and 12 acres of forested ridge habitat at a site about 3.3 miles southeast of the pipeline
system proposed route. The project also involves marsh nourishment. Material will behydraulically dredged and piped from the Mississippi River for this purpose. Phase I engineering
design has been completed, but no additional schedule details are publicly available at this time.
During the draft EIS comment period, a commenter questioned if terminal construction
would lock in sand resources that could be used for renousishment projects as described above.
According to the Louisiana Sand Resources Database (LASARD) Deposit Borrow Areas layer on
the Coastal Information Management System (CIMS) provided by the CPRA, the LNG terminalsite and marine facilities are not located over mapped sand resources. The nearest potential borrow
area within the Mississippi River is located on the river bottom about 1,000 feet off the west bank.
Further, the marine facilities would be in an area that has been previously been modified by

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placement of riprap and concrete revetment blankets, likely precluding its consideration as apotential borrow area. In short, the Project would not affect the potential use of the river as a sandborrow area for future use in wetland restoration projects.
4.13.2 Potential Cumulative Impacts by Resource
Based on our evaluations in section 4.1 through 4.12, the Project would have only
negligible impacts on groundwater, recreation, and cultural resources. As a result, the Project
would not contribute to potentially significant cumulative effects on these three resources.
For each remaining resource, the following sections address the potential cumulative
impacts from Venture Globals’s Project and other projects identified within the cumulative impact
area on specific environmental resources. We briefly summarize the anticipated Project-specificconstruction and operational impacts in order to associate the other projects’ actions to potential
impacts on the resources. In some cases, the resource area was too broad a category to evaluate
collectively, and we identified impacts on a subset instead. For example, under land use we
consider the change in the amount of agricultural land, not the change in land use categories
generally. We advise the reader that when we summarize the effects of the Project, we assume
that mitigation measures in section 4.1 through 4.12 would be implemented.
4.13.2.1 Geology and Soils
Aside from the non-jurisdictional utility lines, only one of the actions in table 4.13-2 would
occur within the workspaces of the Project, which comprise the geographic scope for cumulative
effects on geologic resources and soils. Delta LNG would likely have an overlap of workspaces
from feed gas pipelines. However, geologic resources and soils affected by the Project would notsustain significant impacts from the present or foreseeable actions; therefore, no cumulative effects
would occur. As stated in section 4.13.1, effects from the non-jurisdictional utility lines are alreadyaccounted for in sections 4.1 through 4.12 and, therefore, would not have additive or cumulative
effects. The utility lines would be located on the LNG terminal site.
Although prime farmland is a subset of soils, it is also associated with land use and, assuch, is discussed in the cumulative evaluation of land use on the west bank in section 4.13.2.6.
4.13.2.2 Groundwater
As described in the introduction to this section, our evaluation determined that constructionof the LNG terminal and pipeline would have only negligible effects on groundwater. As a result,
there would be no contribution to cumulative effects on this resource. Moreover, Venture Global
would not withdraw groundwater for hydrostatic testing of the pipeline system facilities, nor would
it use groundwater for hydrostatic testing of the LNG storage tanks, terminal piping, and non LNG
tanks, which constitute the largest user of hydrostatic test water among the LNG terminal
facilities.
Based on these factors, we found that construction and operation of the Project would not
likely affect groundwater resources. Given this low likelihood of occurrence, we conclude that
the Project would not contribute to an adverse cumulative effect on groundwater resources within
the geographic scope.
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4.13.2.3 Surface Waters and Aquatic Wildlife and Habitat
Surface waters and aquatic wildlife and habitat are combined in this analysis because
activities that affect surface waters also affect fish and other aquatic species such as marine
mammals and sea turtles, as well as their habitats. The surface waters affected by the Project are
the Lower Mississippi River and several waterbodies in the Barataria Basin (see tables 4.3-2 forspecific waterbodies in the Barataria Basin). Our evaluation determined that the Project would
have minor deleterious effects on these waterbodies and associated aquatic resources.
Excavation and pile driving to construct the LNG loading docking in the Mississippi Riverwould increase suspended sediment and turbidity. Other in-water and shore-based construction
activities—including use of in-water construction equipment, shore-based equipment, and vesseltransits to and from the work site—could cause erosion and sediment resuspension. Pile drivingin the river could injure or induce behavioral changes in fish or marine mammals and, should theyoccur, leaks or spills from the marine offloading facilities or construction support vessels could
contaminate the river. During operation, stormwater that washes over the marine facilities would
drain to the Mississippi River, while stormwater over the landward portion of the LNG terminal
would be collected into sump pumps and eventually discharged into the Mississippi River via
pipeline. LNG carriers calling at the terminal would discharge ballast water, increasing thepotential to introduce invasive species, and their transits could cause sediment resuspension anderosion.
In the Barataria Basin, trenching and installation of the pipeline system and dredging ofspecific segments of the barge routes would increase suspended sediment and turbidity.
Hydrostatic test water would be discharged into the basin, as would stormwater from the LNG
terminal during construction, when stormwater would be directed to the canals bordering the site
and then eventually pumped to Lake Judge Perez in the Barataria Basin. The majority ofhydrostatic test water for the LNG terminal and pipeline system would be withdrawn fromindustrial canals in the Barataria Basin. Pile driving for two pipeline system metering stations in
the Barataria Basin could injure or induce behavioral changes in fish, sea turtles, and marine
mammals; and oyster reefs within the pipeline right-of-way would be removed. During operation,
the only minor effect in the basin would be risk of a spill or leak from the pipeline system.
Eleven other actions could occur within the geographic and temporal extent for cumulative
impacts on surface waters, fish, and aquatic resources and also affect those same resources (seetable 4.13-3). Four of the actions would benefit those resources in the Barataria Basin, and two of
the actions would, at a minimum, improve drainage in and around the region. Although the siteof Bayou Grande Chenier Marsh and Ridge Restoration is outside the HUC 12 subwatersheds
intersected by the Project, we included the site because it would occur in the Barataria Basin only
2 miles from the pipeline system.
Cumulative Impacts on the Mississippi River
Given our assumptions about Project schedules, Gulf Coast Methanol Park, NOLA Oil
Terminal, Braithwaite Methanol Manufacturing Plant, Delta LNG and the Mid-Barataria Sediment
Diversion structure would be constructed concurrently with the LNG terminal between 2019 and2023 and would also affect the Mississippi River. The major industrial facilities, including the

4-307Pointe Celeste Container Terminal when it comes online and Delta LNG, would affect the riverduring operation,
Table 4.13-3
Other Actions with the Potential to Cumulatively Impact Surface Waters and Aquatic Wildlife and Habitat

Site Area(acres/miles)

ClosestDistance to
Project

Project

637 acres-

Gulf Coast
Methanol

140 acres

NOLA Oil Terminal

Affected
Waterbodies withPotential
Cumulative Impacts

Construction
Overlap

Operation
Overlap

Lower Mississippi
River, Barataria
Basin

-

-

2 miles

Lower Mississippi
River

X

X

128 acres

4 miles

Lower Mississippi
River, Barataria Basin(primarily Wilkinson
Canal)X

X

Pointe Celeste
Container Terminal

up to
1,000 acres

3 miles

Lower Mississippi
River

Braithwaite
Methanol
Manufacturing Plant

36 acres18 milesLower Mississippi
River

X

X

Delta LNG

524 acres

0 miles

Lower Mississippi
River

X

X

ActionX

Actions with Net Benefits
NOV/NFL Levee
Upgrade58 miles –not all within
geographic scope

0 miles

Barataria BasinXX

NOV/NFL Drainage
Canal Relocation

1.8 acres

0 miles

Barataria Basin

X

X

Mid-Barataria
Sediment Diversion

4.5 acres –diversion structure
on west bank

5 miles

Lower Mississippi
River

X

X

20,000 to 32,000
acres –
marsh and open
water to benefit fromsedimentation

0 miles

Barataria Basin-XNOV/NFL Wetland
Mitigation

895 acres

1 mileBarataria Basin

X

X

Bayou Grande
Chenier Marsh andRidge Restoration

486 acres

2 miles

Barataria Basin

X

X

Barataria Bay Rim
Marsh Creation andNourishment

517 acres

2 miles

Barataria Basin

X

X

Key:
- = not applicable
NFL = Non-Federal Levees
NOV = New Orleans to Venice

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If the aforementioned actions were constructed concurrently, the chief concern about
effects on river water quality would be increases in suspended sediments, turbidity, stormwater
effluent and shoreline erosion from in-water construction, site-based modifications near the shore,and vessel traffic. In-water and shore-based construction activities associated with the methanol
manufacturing plants, NOLA Oil Terminal, and Delta LNG would be similar to those at the LNG
terminal. The scale of shore-based construction associated with the NOLA Oil Terminal, Gulf
Coast Methanol Complex, and Delta LNG would be commensurate with the LNG terminal—theirsites each have approximately 5,000 feet of river frontage compared with the LNG terminal’s 7,000
feet. Braithwaite Methanol Manufacturing Plant would require less shore-based construction
because its frontage is about 3,000 feet, and proponents propose to modify existing docking
facilities rather than construct new ones. Construction of the 4.5-acre Mid-Barataria Sediment
Diversion structure would also increase suspended sediment loads and turbidity if the majority of
construction activities occur in the river.
Similar to the LNG terminal, turbidity and suspended sediment increases from eachaction’s construction would be localized and would be flushed through the system rapidly. The
river discharges 400 billion gallons daily, indicating the volume of water that moves through it
regularly. Turbidity and suspended sediment is high in the Mississippi River, even with the highflushing rates, such that turbidity and sediment contributions from the six actions occurring
simultaneously, including the LNG terminal, would have a minor, temporary effect on water
quality. For the reasons stated, sediment and turbidity effects would be similarly minor when theactions are operating and the Pointe Celeste Container Terminal and Delta LNG are underconstruction.
In addition to the physical environment that would minimize impacts on water quality, theregulatory environment would help ensure erosion, sediment loads, and effluents in stormwater
discharges do not impair water quality during construction and operation. The LPDES program(Construction General Permit for stormwater discharges and a Project-specific SWPPP, asrequired under the CWA and Louisiana law) would require erosion control devices and sedimentbarriers at all of the industrial sites during construction until restoration or surface stabilization iscomplete. In compliance with the LPDES, the other actions would collect and process stormwater
through oil/water separators or comparable filters to remove effluents. They would also test for
hazardous materials prior to discharge.
Pile driving in the river from each of the actions could injure or induce behavioral changes
in fish and marine mammals, though several mitigation measures exist that can minimize theseadverse effects. Venture Global has submitted its Underwater Noise Mitigation Plan to the FWS,
NMFS, and LDWF as described in section 4.6.2.3 to minimize and avoid impacts from marine piledriving. As discussed in sections 4.6 and 4.7, bottlenose dolphins potentially occur in the river,while listed whales only occur offshore, and manatees are extremely rare in the Project area. Pile
driving to support the other actions could injure fish near each site, but their pile-driving soundpropagation would not accumulate with the effects of the Project to harm fish because they are too
far away. Moreover, neither the actions alone nor combined would have population-level effects
on fish because their area of effect would be minor compared with the adjacent river and the habitat
therein.
The MMPA prohibits, with limited exceptions, harassment or take of any marine mammal.
Thus, actions that would conduct pile driving are required to submit and implement mitigation
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plans. Venture Global has submitted its Underwater Noise Mitigation Plan to the FWS, NMFS,
and LDWF as described in section 4.6.2.3 to minimize and avoid impacts from marine pile driving.
The other actions’ proponents would likely be required to implement noise mitigation
before commencing any pile driving. However, even if we assumed that the actions would involve
pile driving without mitigation, they would not have a significant cumulative population-level
effect on manatees because their occurrence in the river is so rare. The cumulative pile-driving
activities could potentially have an adverse effect on the dolphin population. Individual dolphins
could experience an adverse synergistic effect if they were harmed multiple times during the courseof construction. However, at the population level, the cumulative effect on dolphins would not
likely be significant.
The risk of spills or leaks of hazardous materials in the Mississippi River would increase
if each action were constructed and commenced operation. All actions would require Section 10
Rivers and Harbors Act and/or Section 404 CWA authorizations from the USACE andcorresponding Section 401 CWA Water Quality Certifications, which Venture Global acquired
from LDEQ on October 1, 2018. These authorizations require that Project recipients implement a
Spill Prevention Plan during construction and an SPCC Plan during operation. Because Venture
Global is regulated under FERC, EI’s would be present on-site during construction to ensure
implementation of all measures intended to protect the environment. Though a spill or leak fromany of the actions could be significant, it is unlikely that multiple actions would result in spills or
leaks in the same relative timeframe to produce a significant cumulative effect given the regulatoryenvironment regarding spill prevention. Thus, we considered the cumulatively increased risk to
be minor.
All actions except the Mid-Barataria Sediment Diversion structure would generateincreases in large, ocean-going vessel traffic with terminal destinations in the affected HUC 12
subwatershed segment of the river. These vessels would discharge ballast water while in berth,which would increase risk of introducing an invasive species into the Mississippi River. As
required by the USCG’s regulations (33 CFR 151.2026), vessels equipped with ballast tanks must
implement one of five specified options to control nonindigenous species in waters of the UnitedStates. All ships calling at U.S. ports and intending to discharge ballast water must either carryout open-sea exchange of ballast water or ballast water treatment, in addition to fouling andsediment management. The USCG considers vessel traffic levels nationwide when establishingand updating ballast water management regulations. Hence, we found it reasonable to assume that
USCG regulations would adequately manage the cumulative increase in susceptibility to invasive
species from the vessel calls generated by the five cumulative actions, including the LNG terminal.
Cumulative Impacts on the Barataria Basin Waterbodies
Venture Global would trench and conduct other types of excavation to install the pipeline
system. They would also dredge specific segments of the barge routes in the Barataria Basin. The
supply barges transiting to and from the pipeline route would, themselves, increase turbidity bystirring up sediment, as would the vessels that ferry workers back and forth.
At this time, the other industrial actions have not publicized plans to trench or excavate in
the Barataria Basin or transport supplies to their respective locations through associated waterways

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although Delta LNG could likely implement similar types of construction for its pipeline.
Construction of the levee upgrade and the drainage canal relocation associated with the NOV/NFL
Hurricane Risk Reduction Project could increase sediment in the runoff and cumulatively effectturbidity and suspended sediment in Barataria Basin waterbodies. These effects are typically
adverse, but the Mid-Barataria Sediment Diversion action would actually increase sediment levelsin the Barataria Basin by design to nourish and restore marsh vegetation. We conclude, then, thatrunoff, sediment, and turbidity effects from the other actions would not be significantly adverse,
and, in balance, would likely be neutral.
At this time, the NOLA Oil Terminal is the only action known to include a plan to discharge
treated water into waterbodies in the Barataria Basin in accordance with limits established by the
LPDES. In 2016, the NOLA Oil Terminal was issued an LPDES permit to discharge industrial
stormwater, fire test water, hydrostatic test water, and miscellaneous wastewater (e.g., from safety
shower and eyewash stations) to a local drainage that drains to Wilkinson Canal. The limits andconditions of the permit were designed to avoid any negative impacts on the designated or existinguses of the receiving waterbody, though it does allow for changes in water quality as long as thechange does not adversely affect designated or existing uses. In Wilkinson Canal, those uses areprimary contact recreation, secondary contact recreation, and propagation of fish and wildlife.
During at least some portion of the LNG terminal’s construction, stormwater would drain
to adjacent industrial canals that flow to a pumping station, which discharges the water into Lake
Judge Perez in the Barataria Basin. Eventually, stormwater on the LNG terminal site would becollected in sump tanks, treated, and pumped into the Mississippi River. Venture Global would
discharge hydrostatic test water into the drainage canals along the pipeline system, and Venture
Global may discharge some percentage of its hydrostatic test water into the industrial canaladjacent to the LNG terminal. Like NOLA Oil Terminal, Venture Global is required todemonstrate that its discharges would maintain the designated uses of the receiving waterbodies
before an LPDES permit would be issued. All receiving waterbodies identified in Venture
Global’s Project plans have the same designated uses as those in Wilkinson Canal, plus oyster
propagation, so effluent thresholds would be similar or more stringent. We acknowledge that both
NOLA Oil Terminal and the Project would discharge into the Barataria Basin waterbodies, but
their discharge points would be about 4 miles apart, limiting the potential for discharged water
having an adverse cumulative effect on water quality, while discharges from the adjacent Delta
LNG project are unknown at this time. This, coupled with the requirements in the LPDES
program, indicate that the cumulative adverse effects from the actions’ discharges would be minor.
None of the other actions have publicized plans to conduct pile driving in the Barataria
Basin. Thus, pile driving conducted for the pipeline meter stations would not accumulate withother underwater noise effects to harm wildlife. Venture Global would withdraw water from
canals in the Barataria Basin for hydrostatic testing of the pipeline system. Because Venture
Global would have large, pressurized storage tanks, its test water budget would be up to an orderof magnitude greater than NOLA Oil Terminal or Gulf Coast Methanol, activities that also could
withdraw water from the Barataria Basin canals for hydrostatic testing. At this time, any plans for
Delta LNG’s test water budget are unknown. Venture Global would screen water intake hoses tominimize entrainment of larvae and pre-juvenile fish and would place them at the lowest possible
elevation to reduce impingement of biological organisms. Although the Project’s test water budget
is large, mitigation would minimize effects to minor and temporary. Hydrostatic test water
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withdrawal by the other actions would be subject to the general LPDES program, which would
manage withdrawal limits and practices to maintain use of the waterbodies for propagation of fish
and wildlife. Thus, we conclude the cumulative adverse effect on fish and wildlife would likely
be minor and temporary.
We considered that the NOV/NFL Project-related wetland mitigation, Bayou Grande
Chenier Marsh and Ridge Restoration, and Barataria Bay Rim Marsh Creation and Nourishment
actions would have net benefits on water quality, aquatic wildlife, and habitat in the Barataria
Basin. Any negative effects on water quality from vessel traffic or in-water construction activities
to support those actions would likely be negligible compared with vessel traffic and excavationand trenching activities to construct the pipeline system, and we have already determine that thoseeffects would be minor.
4.13.2.4 Wetlands
Wetlands are protected by the CWA, and the USACE and LDEQ administer regulations
and issues permits in scenarios in which coastal wetlands in Louisiana would be affected.
Construction of the LNG terminal would permanently fill 368.1 acres of non-forested wetlands
and convert 2.8 acres of forested wetlands to non-forested ones. Per the CWA, no development ispermitted to have a significant adverse impact on wetlands, so Venture Global would be required
to mitigate. Venture Global proposes to utilize an in-lieu of fee program, a method currently underreview by the USACE as it reviews Venture Global’s permit application submitted in 2017. The
final mitigation plan must result in no net loss of function, though a net loss of wetland acreage
would be permitted.
Construction of the pipeline system would permanently displace about 0.4 acre of nonforested wetlands to permit construction of the mainline valves, permanent access road to themainline valves, and portions of the pipe trestle over the levee near Lake Hermitage Road. No
additional wetlands would be permanently filled. Pipeline system construction activities would
result in temporary clearing or other disturbance of 70.4 acres of non-forested wetlands. Venture
Global would restore these wetlands in accordance with its Project-specific Procedures
immediately following construction. In addition, pipeline installation would involve clearing andexcavation in 877.7 acres of adjacent open water, which could adversely affect wetland hydrology
and revegetation potential if contours and elevation are not properly restored. Post-construction
reports, surveys, and inspections would all be required as part of Venture Global’s wetland
restoration plan and in-water construction permit, which is currently under review by the USACE.
Eleven other actions could occur within the geographic and temporal extent for cumulative
impacts on wetlands and could also affect those resources (see table 4.13-4). Although the site ofBayou Grande Chenier Marsh and Ridge Restoration is outside the HUC 12 subwatersheds
intersected by the Project, we included the site because it would occur in the Barataria Basin only
2 miles from the pipeline system.

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Table 4.13-4
Other Actions with the Potential to Cumulatively Impact Wetlands
Closest Distanceto Project

Wetland Impacts in
Affected HUC-12 Subwatersheds-

370 acres – LNG terminal
70 acres – pipeline system

Gulf Coast Methanol

2 miles

up to 103 acresa

NOLA Oil Terminal

4 miles

up to 128 acresa

Pointe Celeste Container Terminal

3 miles

Unavailable

Braithwaite Methanol Manufacturing Plant

18 miles0 acres

Mid-Barataria Sediment Diversion

0 miles

52 acres

NOV/NFL Levee Upgrade

0 miles

Unavailable

NOV/NFL Drainage Canal Relocation

0 miles

Unavailable

Delta LNG

0 miles

Unavailable

ActionProject

Subtotal

723 acres

Action with Wetland Benefits
NOV/NFL Wetland Mitigation

1 mile895 acres – beneficial

Bayou Grande Chenier Marsh and Ridge Restoration

2 miles

486 acres – beneficial

Barataria Bay Rim Marsh Creation and Nourishment

2 miles

517 acres – beneficial

Subtotal

1,412 acres

a Estimated from USGS land cover data (2011); assumes all wetlands on-site impacted.
Key:- = not applicable
HUC = hydrologic unit code
NFL = Non-Federal Levees
NOV = New Orleans to Venice

Wetland impacts were recorded from permit applications or publicly available Projectplans unless otherwise noted. In these other cases, we calculated wetlands from USGS land cover
data and, to be conservative, assumed all would be impacted. For the case of Delta LNG, notenough detail was publicly available to determine wetland along the pipeline route.
The combination of the construction activities of the Project and the other actions would
adversely impact more than twice as much wetland as the Project would alone within thegeographic scope. However, per federal regulations, no action that disturbs more than 5 acres cancause a permanent loss of wetland function. In order to acquire necessary construction permits
from the USACE, each proponent would have to demonstrate no net loss of wetland function
through a wetland restoration plan or participation in a mitigation program. Because of thisfederally mandated protection measure, we conclude that cumulative adverse impacts fromconstruction and permanent fill would be adequately mitigated.

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4.13.2.5 Vegetation and Wildlife
Vegetation and upland wildlife are combined in this analysis because actions that affectvegetation also affect wildlife—vegetation is critical to wildlife food webs, and it also serves as
habitat. Development of the LNG terminal and pipeline system would have temporary andpermanent effects on upland and wetland vegetation, and because cumulative wetland impacts are
discussed exclusively in the previous section, we restrict our focus in this section to uplands. A
basic distinction among vegetation types is the presence or absence of trees or other woody species.
While they have some overlap, the two groups each support basic wildlife types that would not befound in the other. They also perform non-habitat-related ecological functions that are indicatedby the presence or absence of forest or woody vegetation. According to field surveys noted in
section 4.5.1, the Project would permanently impact 84.3 acres of upland forest and scrub/shrub
vegetation, and 151.2 acres of herbaceous upland vegetation.
Seven other actions could occur within the geographic and temporal extent for cumulative
impacts on non-wetland vegetation and upland wildlife that could also affect these resources (seetable 4.13-5). The upland portion of the Braithwaite Methanol Manufacturing Plant is outside of
the geographic scope, i.e., the affected HUC 12 subwatersheds. The Braithwaite project property
is on the east bank of the river, and only the shoreline of the property and planned in-water docks
are in an affected HUC 12 subwatershed—the one consisting of a segment of the Mississippi Riverthat also runs along the LNG terminal.
Table 4.13-5
Other Actions with the Potential to Cumulatively Impact Vegetation and Wildlife
Selected Vegetation Impacts
in Geographic Scope

Distance

Area/Length

Forested andScrub-Shrub
Upland-637 acres

84.3 acres

151.2 acres

Gulf Coast Methanol

2 miles

140 acres

0 acres0 acres

NOLA Oil Terminal

4 miles

128 acres

0 acres0 acres

Pointe Celeste
Container Terminal

3 miles

940 acres

25 acres

2 acres

NOV/NFL Levee
Upgrade0 miles

58 milesUnavailable

Unavailable

NOV/NFL Drainage
Canal Relocation

0 miles

Unavailable

Unavailable

Unavailable

Delta LNG

0 miles

524 acres

Unavailable

Unavailable

Mid-Barataria Sediment
Diversion Structure

5 miles

4.5 acres

Unavailable

Unavailable--

105.9 acres

153.2 acres

2,484 acres

2,021 acres

ActionProject

Total

Total in affected HUC-12 subwatersheds
Key:- = not applicable
HUC = hydrologic unit code
NFL = Non-Federal Levees

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Herbaceous UplandTable 4.13-5
Other Actions with the Potential to Cumulatively Impact Vegetation and Wildlife
Selected Vegetation Impacts
in Geographic Scope

ActionDistance

Area/Length

Forested andScrub-Shrub
UplandHerbaceous Upland

NOV = New Orleans to Venice

Based on their limited acreage of undeveloped woody and non-woody land cover, theactions with estimated vegetation impacts would constitute a negligible contribution to a
cumulative adverse impact with the Project. In other words, these actions would not create moreof an adverse effect on vegetation and wildlife beyond what is already accounted for in theevaluation of the Project in sections 4.5 through 4.7. Lacking detailed engineering drawings ofthe levee upgrade and drainage canal relocation projects, we did not estimate the vegetation
disturbance and displacement within the affected HUC 12 subwatersheds associated with theirconstruction. However, because much of the construction would be upgrading existing levee
structures and rerouting drainage to an existing canal, we assume impacts on undisturbed swathsof vegetation would be minimal. We conclude that there would be no more than a minor,
permanent cumulative impact on vegetation and associated wildlife.
4.13.2.6 Land Use
As noted in previous sections, the portion of the LNG terminal site south of SH 23 was
historically used for sugar cane production and has been extensively ditched and drained. Most of
the LNG terminal site is currently fallow agricultural land and used for cattle pasture. The
proposed land use of the Project is major industrial; however, because it would receive large vessel
calls for loading with LNG for export, this Project could also be considered a port/terminal
complex. No agricultural uses would be preserved.
The geographic scope for land use is the west bank, and the temporal extent is any instanceof overlap with the Project’s construction or operation periods. Many actions fall within this scope,
but we determined that the four other major industrial actions in the west bank had real potential
to create adverse effects on the land use inventory in the west bank, whereas the others did not.
We reasoned that the remaining actions—levee and drainage canal upgrades, wetland restoration,
and a transportation improvement—could have indirect effects on land use but were not the typesof actions that would contribute to significant adverse land use effects in a community. That said,
we acknowledge that industrial developments are not necessarily adverse from a land use
perspective; in fact, they are necessary and frequently economically beneficial uses in a society.
To evaluate the proposed land uses’ effect, then, we considered the existing context as well as
future land uses envisioned by the parish as part of their master planning process.
Table 4.13-6 lists the planned or permitted developments we considered. We used the term
“major industrial” to broadly identify any high-intensity use such as industrial manufacturing or
an industrial port facility.

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Plaquemines Parish published a draft, final Comprehensive Master Plan in 2012
(Plaquemines Parish, 2012) (Parish Plan). The Parish Plan assigned anticipated future land use
designations to all developable properties and included the anticipated future land uses on maps inthe “Land Use” technical addendum to the “Community Assessment.” Future land use
designations in a comprehensive master plan typically represent the collective input of community
stakeholders, landowners, and planning professionals.

Table 4.13-6
Other Actions With Potential for Cumulatively Impact Land Use
Future Land Use(s)per Parish Master
Plan

ActiveFarming on
Property?

Major Industrial

Port/Terminal
Complex/Major
Industries/ Business
ComplexNo

Agricultural/
Undeveloped

Major Industrial

Major
Industries/Agricultural

Yes, negligible

130 acres

Undeveloped

Major Industrial

Agricultural

No

PointeCelesteContainer
Terminal

Up to 1,000
acres

Agricultural/
Undeveloped

Major Industrial

Port/Terminal Complex

Yes

Delta LNG

524 acres

Agricultural(Inactive
farmland; active
grazing land)

Major Industrial

Major Industries/
Business Complex

Unknown

Site Area(acres)Existing Land
Use(s)

Planned/ Proposed
Land Use

Project

637 acres

Agricultural(Inactive
farmland; active
grazing land)

Gulf Coast
Methanol

140 acres

NOLA Oil
Terminal

ActionAfter considering the overlapping actions, our chief concerns were conversion of parcels
to higher intensity uses compared with their anticipated future land use designations in the Parish
Plan, and the permanent conversion of agricultural land, including prime farmland. We believethese have the highest potential for becoming significant adverse cumulative land use effects inthe west bank.
Of the overlapping actions, the Pointe Celeste Container Terminal is the only action thatwill permanently displace more than a negligible amount of actively cultivated farmland. Basedon USCG land cover data (2011), almost 700 acres of the site is farmed. However, this property
and Delta LNG are Port-owned and targeted for development due to their location on a relatively
wide portion of the river and other factors. The Parish Plan reinforces this future plan fordevelopment on the future site of the proposed container terminal and LNG port.
The effect of implementing all the reasonably foreseeable developments would convert
five sites within 4 miles of each other on the west bank to major industrial and port terminal
complex land uses. Compared with the existing uses, this change would be readily apparent;
however the majority of the acreage affected would be consistent with the Parish Plan. For
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instance, the majority of the 637-acre site of the LNG terminal consists of land designated as“major industries” and “port/terminal complex” in the Parish Plan. The 524 acre Delta LNG site
is mostly designated as “major industries” and “business complex.” All of the nearly 1,000-acresite of the Pointe Celeste Container Terminal is designated as “port terminal complex” in the Parish
Plan. Part of the 140-acre Gulf Coast Methanol site is designated with the future land use of “majorindustries.” Only the smallest site, the 130-acre proposed site of the NOLA Oil Terminal, lacks a“major industries” or “port/terminal complex” future land use designation on all or part of the site.
Thus, we conclude that the cumulative land use change in this portion of the west bank would be
mostly consistent with the Parish Plan.
4.13.2.7 Visual Resources
The operation of the LNG terminal could have an adverse impact on the residents, drivers,
and recreational/commercial users of the area. Its presence on the landscape could adversely affectviews from residences on Lake Hermitage Road, travelers on SH 23 and the Mississippi River,where recreational boating occurs. The LNG terminal would consist of numerous tall and bulky
components, LNG loading docks, and ship berthing facilities developed on and adjacent to a sitewhere only agricultural activities have occurred to date. In comparison, the pipeline system would
minimally affect visual integrity or scenic quality in the Barataria Basin, because construction
periods would not exceed 9 months and the overall visual quality would be restored in the months
after installation. Moreover, we did not identify any other major industrial facilities proposed for
installation or operation in the Barataria Basin with pubic ally available information. Thus, welimited our cumulative effects evaluation to the LNG terminal.
Three other major industrial facilities planned or permitted in the west bank are within thegeographic scope and could adversely affect visual resources cumulatively with the LNG terminal(see table 4.13-7).
Table 4.13-7
Other Actions with the Potential to Cumulatively Impact Visual Resources
Distance
from
Project

Site area-

637 acres~7,000 feet

280 feet

Four LNG storage tanks,liquefaction trains, flare stacks,
power generators, dockfacilities

Gulf Coast Methanol

2 miles

140 acres~5,000 feet

200 feet

Storage tanks (shorter than LNG
storage tanks), stacks, power
generators, dock facilities

NOLA Oil Terminal

4 miles

130 acres~5,000 feet

Unavailable

54 storage tanks, dock facilities

Delta LNG

0 miles

524 acres~3,100 feet

Unavailable

Four LNG storage tanks

Activity
ProjectRiver
frontage

Tallest Stack
HeightReadily Visible Features

Key: - = not applicable

Two of the activities would not likely be visible from the residential communities on Lake
Hermitage Road given their distance from the residences, topography, and intervening vegetation.
However, if one or more actions would be visible from an individual residence that would also
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have a view of the LNG terminal, the cumulative effect would only be negligible compared with
the LNG terminal’s visual effect alone.
Delta LNG would have four storage tanks located on adjacent property to the Plaquemines
LNG terminal. No information is known about the heights of any of Delta LNG’s terminal
facilities and therefore no evaluation on the cumulative impacts to the viewshed from nearby
residences can be properly addressed.
The cumulative actions would all be visible from SH 23, a scenic byway that is not heavily
traveled by nature-oriented tourists. Within the 4-mile span that includes all of the foreseeable
activity sites, the existing views are characterized by industrial operations, agricultural land, andundeveloped properties largely covered by scrub-shrub vegetation. International Marine
Terminals, a coal distribution terminal a little more than one mile north of the LNG terminal site,
is occupied by bulk piles of coal and a variety of heavy industrial equipment. Neither the river nor
river vessel traffic can be seen from SH 23. In the opposite direction of the river, the view ischaracterized by large agricultural fields and residential development in Myrtle Grove. If thestorage tanks, stacks, power generators, etc., required for each facility are constructed, theirgeometric forms and artificial texture would be high-contrast by comparison. The exposure to theviewers on SH 23 would be intermittent. As a result, the cumulative adverse effect on the visual
integrity and scenic quality from the view provided by SH 23 would be moderate given themagnitude of the proposed changes and the duration of exposure experienced by those travelingon SH 23.
The cumulative actions would all be visible from the Mississippi River, which is transitedby recreational vessels as well as commercial and industrial ones. We assume the viewer
sensitivity of the recreational mariners and recreational boat passengers is moderate. Within the
4-mile stretch of the river between the LNG terminal and the proposed NOLA Oil Terminal are
three existing industrial terminals serving the two coal export facilities and a cargo storage anddistribution facility. If dock facilities and marine berths are constructed at the NOLA Oil Terminal,
Gulf Coast Methanol Complex, Delta LNG, and LNG terminal, as planned, the change would benoticeable but would not significantly deteriorate the visual integrity or scenic quality given theexisting concentration of industrial marine terminal operations. Thus, we conclude the cumulativevisual impact from the perspective of the Mississippi River would be minor.
4.13.2.8 Socioeconomics
In this case, we only evaluated the other major industrial projects in the geographic scopethat could potentially have overlapping construction schedules. We were concerned withdetermining any significant or otherwise substantial adverse cumulative effects on socioeconomic
resources that might result from concurrent construction. We acknowledge that the jobs creationand capital investments from the major industrial projects would benefit the region, but we did notdelve deeper to evaluate the level of this positive cumulative effect. Nor did we consider theindirect economic benefits, i.e., ecosystem services, which might stem from the wetland restorationand drainage and levee system projects.
Five other actions could occur within the geographic scope and temporal extent for
cumulative impacts on socioeconomic resources and could adversely affect those resources (see4-318

table 4.13-8). We identified the construction period of the Project as the period during which
concurrent actions could have adverse socioeconomic effects, namely on housing and public
services. We did not assume that the Pointe Celeste Terminal would be constructed concurrently.
Table 4.13-8
Other Actions with the Potential to Contribute to a Cumulative Adverse Effect on
Socioeconomic Resources
Site Area

Capital Investment

Construction
Workforce

Operation
Workforce a

Project

637 acres$8.5 billion

1,400 to 3,700 b

250

Gulf Coast Methanol Complex

140 acres$3.6 billion; $900
million per production
unit (4)900325

NOLA Oil Terminal

130 acres

Unavailable

Unavailable

Unavailable

Braithwaite Methanol Plant

36 acres$1.2 billion

1,000

50

Pointe LNG

600 acres$3.2 billion

Unavailable

Unavailable

Delta LNG

524 acres

Unavailable

Unavailable

Unavailable

Activitya Included to demonstrate the scale of the action.
b The peak workforce estimate of 3,700 would only occur if all peak construction efforts on the LNG terminal and two pipeline laterals
coincided for 1 month.

In section 4.9, we concluded that the Project’s construction could have minor, temporary
adverse impacts on others in the area seeking rental housing. We assumed that half of theworkforce would be locally hired, leaving half to seek housing in the three parishes nearest the
Project—Plaquemines, Jefferson, and Orleans. The Greater New Orleans area has an abundanceof rental and short-term housing options. The concentration of this housing would require workers
to commute up to an hour to their work site, but this drive time is not unusual in the industry.
We assumed that the at least half of the workforce hired by the other projects would also
be local residents, for the same reasons we examined in section 4.9. Although the combined
workforce of the developments would be high, exceeding 4,000 workers, with half assumed to be
non-local hires, the greater New Orleans area could absorb 2,000 or more individuals seeking
rental or short-term housing without significantly adversely affecting the housing market.
Likewise, we conclude that existing public and safety services would be adequate, even with theaddition of these non-local workers and their households.
4.13.2.9 Roadway and Vessel Traffic
Roadway Traffic
The construction workforce traffic that would be generated by the Project is high enoughthat several mitigation measures would be required to maintain uninterrupted flow on SH 23 in thevicinity of the LNG terminal. Venture Global will construct auxiliary turn lanes for southboundSH 23 at the LNG terminal’s main entrance. In addition, Venture Global will construct a medianlane for U-turns from southbound SH 23 to northbound SH 23 to accommodate construction
traffic. These auxiliary lanes would prevent the temporary traffic impact during construction from4-319

becoming significantly adverse. The majority of construction materials would be delivered bybarge directly to the site, minimizing traffic impacts from heavy traffic to negligible levels. We
assume traffic impacts during operation would be minor given the comparatively small workforce.
Five other actions that may occur within the geographic and temporal extent of the Project
could contribute to cumulative impacts, including more-than-negligible effects on cumulative
roadway traffic, especially traffic on SH 23 (see table 4.13-9).
One action in table 4.13-9 had a beneficial impact on traffic in the region. The SH 23
Improvement Project consisted of resurfacing a 4-mile-long section of the road between Happy
Jack and Port Sulphur and adding turning lanes to three intersections in Port Sulphur. The project
was completed in March 2017, subsequent to the traffic impact assessments for the project. Thisis the only two-lane section of SH 23 in Plaquemines Parish, so this upgrade significantly improved
the flow of traffic through Port Sulphur for locals as well as the freight and maritime industry(Louisiana Department of Transportation and Development, 2017). The remainder of SH 23
through the parish is four lanes.

Table 4.13-9
Other Actions with the Potential to Cumulatively Impact Roadway Traffic
Distance and Direction
from the Project

Construction Workforce

Operation Workforce-

1,400 to 3,700 a

250

Gulf Coast Methanol
Complex

2 miles northwest

900

325

NOLA Oil Terminal

4 miles northwest

Unavailable

Unavailable

3 miles southeast-aUnavailable

SH 23 Improvement
Project

10 miles southeast-b-

Delta LNG

Adjacent Property

Unavailable

Unavailable

Activity
Project

Pointe Celeste Terminala We assumed Pointe Celeste Terminal construction would overlap with the Project’s operation period but not its construction period.
b SH 23 improvement was completed in 2017.
Key:- = not applicable
SH = State Highway

The other actions with construction overlap would have adverse effects on traffic. Boththe Gulf Coast Methanol Complex and NOLA Oil Terminal would require large construction
workforces that would commute back and forth along SH 23 to their worksites. IGP Methanol
LLC estimates a construction workforce of 900 at the Gulf Coast Methanol Complex, thoughavailable documents do not clarify whether this estimate is an average or peak number. As
demonstrated by the LNG terminal and pipeline system’s workforce estimates, the size of aconstruction workforce in any given month fluctuates widely. The Delta LNG scope is similar the
Project’s thus we assume the workforce would be of similar size. The NOLA Oil Terminal site isapproximately as large as the Gulf Coast Methanol Complex, and the development would include
construction of 54 storage tanks. Thus, we assume the NOLA Oil Terminal construction
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workforce would be as large as the one estimated for the Gulf Coast Methanol Complex. All threedevelopments would require substantial amounts of construction materials, equipment, andspecialty parts, and we assume these would be delivered both by heavy trucks and by barges.
Based on our assumptions, the cumulative amount of material deliveries and the numberof construction workers commuting to worksites within 4 miles of each other on SH 23 could
double the number of LNG terminal and pipeline system construction workers alone at some point
during the 2019-2023 construction period. This cumulative adverse effect could be significant,and we would expect traffic delays on SH 23 during commute periods for construction workers.
We based this finding on the conservative assumption that the NOLA Oil Terminal would beconstructed concurrently with the Project, Gulf Coast Methanol Complex, and Delta LNG. In fact,
the NOLA Oil Terminal is stalled; the website launched by its proponents has not been updated
since 2016, and it has not broken ground despite acquiring its initial air and LPDES permits in
2013. As a result of the NOLA Terminal not going forward, the cumulative effect on SH 23 traffic
would be less-than-significant.
Vessel Traffic on the Mississippi River
Vessel traffic during construction of the LNG terminal could peak at around 16 vesseltransits per day for several months when Phase I and II overlap. Given the width of the river andthe brief period, the vessel traffic increase would be too low to cause greater than negligible effects.
During operation, LNG carrier vessel calls on the LNG terminal would average about one per day,or slightly less. The USCG issued a Letter of Recommendation advising that, upon review ofVenture Global’s Required Waterway Suitability Assessment, the Mississippi River in the vicinityof the LNG terminal was appropriate for LNG carrier traffic. Projected LNG carrier calls are six
per week, thought the maximum number of transits would be established by the USCG before
operation commences.
Six other actions could cumulatively affect vessel traffic levels in the Mississippi River(see table 4.13-10).
Table 4.13-10
Other Actions with the Potential to Cumulatively Impact Vessel Traffic on the Mississippi River
Distance
andDirectionfrom theProject

River
Frontage(linear feetroundedto nearest
1,000)

Project-

7,000 feet

Gulf Coast
Methanol2 milesnorthwest

NOLA Oil
Terminal

4 milesnorthwest

Activity

Vessel Traffic
Types during
Operationa

Estimated
Construction
Period or Start
Date (years)b

Estimated
Operation
Period orStart Date(years)3 LNG
Loading
Berths

LNG carriers

2019–2023

2022(Phase I)

5,000 feet

N/A

Methanol carriers

2018–2025

2020 or 2021
(first phase)

5,000 feet

2 for postpanamax
tankers

Tankers

Unavailable

Unavailable

Berths(number)

4-321

Table 4.13-10
Other Actions with the Potential to Cumulatively Impact Vessel Traffic on the Mississippi River

Activity

Distance
andDirectionfrom theProject

River
Frontage(linear feetroundedto nearest
1,000)

Berths(number)

Vessel Traffic
Types during
Operationa

Estimated
Construction
Period or Start
Date (years)b

Estimated
Operation
Period orStart Date(years)PointeCelesteContainer
Terminal

3 milessoutheast

10,000 feet

3 deep draft
and additional
for inland
vesselContainer ships,
breakbulk cargoships;

Unavailable:
overlap notassumed

Unavailable

Braithwaite
MethanolPlant

13 milesnorth

3,000 feet

3 deep draft

Methanol carriers

2019

2021

Pointe LNG

8 milessoutheast

6,500 feet

1 LNG
loading berth

LNG carriers

2022–2025

2025

Delta LNG

0 miles

Unavailable

3 LNG
Loading
BerthsLNG Carriers

2021 - 2024

2024

a Not including support vessels.
Key:
N/A = Not available.

If peak construction periods of all identified actions overlap, the vessel traffic increase
could delay voyages of other vessels in the Lower Mississippi River for a period of several months.
At its peak, LNG terminal construction traffic could increase daily vessel transits by 2.6 percent
or more for several months, constituting a temporary, but an unnoticeable increase in vessel traffic.
Additional vessel traffic destined for the six other major industrial construction sites could begin
to cause a noticeable increase in the waterway. A mitigating factor is that material deliveries to amajor industrial site are typically concentrated at the front end of a construction period, and thenrapidly decline. Thus, the likelihood is low that the projects’ peak vessel delivery periods to therespective sites would all overlap. The more likely outcome is that peak periods would stagger
over the ensuing years, and some of the projects may never be constructed. We conclude that theoverall cumulative adverse effect would be minor but acknowledge that vessel traffic increases
could be noticeable for a few months if some of the projects’ peak vessel traffic periods overlap.
During operation, the LNG terminal would generate about one vessel call per day by an
LNG carrier, which are very large vessels and assume Delta LNG would be similar. We assume
the two methanol manufacturing plants and the NOLA Oil Terminal would generate about one callper day each by a very large vessel, either a methanol carrier or a petroleum product tanker. Pointe
LNG will have the capacity to load 100 LNG carriers per year (two per week). We assume that
Pointe Celeste Container Terminal could generate up to two or three very large vessel calls bycontainer and cargo ships in a day, and we conservatively assume it would average two very large
ships per day. Based on these assumptions, the cumulative effect would be an addition of sevento eight very large vessels to the Lower Mississippi River in the vicinity of the LNG terminal,
averaging around 15 transits per day. The Crescent River Pilots Association estimate they pilot
about 44 transits each day between Pilottown, near the southern tip of Plaquemines Parish, and4-322

New Orleans. Increasing piloted vessel transits in this stretch of the river from 44 to 59 per day, a
25 percent increase, would constitute a substantial increase. If the projects are all built as planned,
the increase in piloted vessel traffic would require USCG Vessel Traffic Services - Lower
Mississippi River to expend additional effort coordinating and managing the transits for safety andefficiency. The river pilots, who schedule voyages along the segment of the river in theirjurisdiction, would have to increase coordination and management, but they would benefit fromthe increase in clients. The presence of USCG Vessel Traffic Services–Lower Mississippi Riverand the capacity of the Mississippi River to accommodate vessel traffic would mitigate theadditional transits’ effect on traffic flow, so we do not expect any increase in wait-times to besignificantly adverse.
Vessel Traffic in Waterbodies of the Barataria Basin
The designated barge routes to the pipeline system are depicted on figures 4.13-1 and4.13-2. Crew boats and barges would transport workers and materials, respectively, to theworksite, and their effect on local vessel traffic would be minor. The only other actions that would
generate construction vessel transits through or near the barge routes are the Barataria Bay Rim
Marsh Creation and Nourishment project and the “Delfelice” wetland, a mitigation wetland project
associated with the NOV/NFL level upgrade. Venture Global has already met with the Coastal
Protection Restoration Authority about the Barataria Bay Rim Marsh Creation and Nourishment
project and established that their joint use of a canal would not interfere with the other’s vesseltransits (see section 4.9.8). We assume the vessel transits required in the course of construction
the Delfelice wetland would be negligible. Thus, no cumulative effect on vessel traffic in or near
the barge routes in the Barataria Basin would occur.
4.13.2.10

Cultural Resources

Based on fieldwork and desktop surveys, no known historic or archaeological properties,
traditional cultural properties, or properties of religious or cultural importance to federally
recognized tribes are present in the area of potential effect of the LNG terminal and pipeline system(see section 4.10). The SHPO has concurred that no historic properties are present.
Based on surveys to date and correspondence with tribes, we do not expect the Project tocontribute to a cumulative impact on cultural resources. Venture Global has prepared an
Unanticipated Discovery Plan and would implement the plan in the unlikely event that an
unreported cultural resource or human remains are encountered during construction.
4.13.2.11

Air Quality

Project construction would produce significant quantities of criteria pollutant emissions
over a multi-year period. During operation, the Project’s impacts on ambient air quality would be
required to comply with the NAAQS, designed to protect human health, flora, and fauna.
Demonstration of compliance is required by LDEQ before any construction permits may be issued.
Moreover, the potential ambient impacts from toxic air pollutants emitted during Project operation
are subject to review by the Louisiana Toxic Air Pollutant Program. Venture Global has submitted
an air permit application for operating emissions, currently under review by LDEQ. The samedispersion modeling used in the application is summarized in section 4.11, and based on the

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modeling results, we determined that the ambient air quality impact during operation would be
below ambient air quality standards based on that submittal.
The only other actions within the 0.25-mile radius geographic scope for construction air
emissions are the NOV/NFL levee upgrade and drainage canal relocation projects. These are linear
projects that extend many miles. Within the geographic scope, earth-moving vehicles andequipment and other construction support vehicles would produce emissions temporarily while thelevee segment adjacent to the pipe bridge is upgraded. The same would be true for the drainage
canal relocation near the southern boundary of the LNG terminal. These comparatively minor
emissions would not increase emissions appreciably beyond levels already accounted for in the
Project’s construction air impact evaluation in section 4.11. Therefore, we find no cumulative
impact on air quality during the Project’s construction.
All actions except the Mississippi River ship channel deepening south of Venice would
occur within the geographic scope and temporal extent for cumulative impacts on air quality during
operation of the LNG terminal. Aside from the major industrial developments, the other actions
within scope would have no long-term or permanent air emissions, and any construction emissions
they produce during the LNG terminal’s operation would be negligible in comparison. Thus, we
focused on these five developments upriver and downriver from the LNG terminal, centering ouranalysis on a future point in time when all developments would be operating concurrently.
Delta LNG requested to initiate the NEPA pre-filing process with the Commission on April
17, 2019. Delta LNG would be a 20 MTPA LNG export facility constructed in two phases, andof similar design to Plaquemines LNG. Delta LNG would be located adjacent to Plaquemines
LNG. The pre-filing request indicates construction of phase 1 would occur in years 2022 and2023, with full LNG production for phase 1 commencing in November 2024. At this time, we do
not have emission or modeling estimates of the Delta LNG facility, and. Should both facilities beconstructed, there would be overlapping operational emissions that would cause a cumulative
impact on local and regional air quality. In addition, due to the proximity of the facilities, ifconstruction occurs at the same time, there would be cumulative impacts on local air quality. As
Delta LNG progresses through the NEPA process, it would be required to address air quality
cumulative impacts during construction and operation with all projects in its region of influence,
including Plaquemines LNG.
Table 4.13-11 provides the estimated potential air pollutant emissions during operation of
three of the six major industrial facilities that could add to the emissions produced by the LNG
terminal. Emission estimates are not available for the recently announced Pointe Celeste Container
Terminal or Pointe LNG. Should they move forward, they would both require LDEQ permits.

4-324

M:\Houston\Plaquemines_LNG\Maps\Mxds\Report_Figures\Cumulative_Central.mxd

12

4/30/2019

11

4c !(

!
(

8a

"
)

6

5

4a !(

8b

1

!
( !
(

2

!
(

!
(

3 16

7
15
4b

!
(

9

!
(

Non-jurisdictional, New Utility Lines to Serve Project1 Entergy Electric Utility Connection
2 Plaquemines Parish Water Line Connection
Other Projects, Non-Linear
3 New Orleans to Venice, Hurricane Protection, Drainage Canal Relocation
New Orleans to Venice, Louisiana Hurricane Protection, Wetland Mitigation:
4a Delfelice wetland
4b Coleman wetland
4c Jesuit Bend wetland
5 Gulf Coast Methanol
6 NOLA Oil Terminal
7 Pointe Celeste Container Terminal
8a Mid-Barataria Sediment Diversion Structure
8b Mid-Barataria Sediment Diversion Affected Area
9 Bayou Grande Chenier Marsh and Ridge Restoration
10 Barataria Bay Rim Marsh Creation and Nourishment
11 Braithwaite Methanol Plant
Other Projects, Linear
12 New Orleans to Venice, Louisiana Hurricane Protection Levee Upgrade
13 SH 23 Repavement and Turning Lane Addition
14 Mississippi River Ship Channel Deepening, Venice to Gulf
Other LNG
15 Pointe LNG
16 Delta LNG!
(

Non-linear projects*")

Interconnects

Linear Projects")

Parking Area for Pipeline Construction Employees

Boundary of Project 8b*Boundaries delineated for selected projects

0

1.25

/
2.5

Laterals (TETCO & TGP)
Barge Access Channel - Dredge/Excavation Proposed
Barge Access Channel - No Dredge Required

5 Miles14

10 !(Projects With Potential Cumulative Impacts Project Components and Buffers

130.25-mi buffer of Terminal and Pipeline
0.5-mi buffer of HDD entry/exit
0.5-mi buffer of Pipeline
1-mi buffer of Terminal
HUC-12 Subwatersheds Intersected by Project

Figure 4.13-2

Projects with Potential
Cumulative Impacts
Plaquemines Parish,
Louisiana

Terminal Site Boundary
Source: DigitalGlobe 2017, USGS 2018

Table 4.13-11
Other Activities within the Geographic and Temporal Scope for Cumulative Air Impacts during Operation

Distance

LDEQ
Air
PermitStatusTitle V
Category(minor/major)

Triggers
PSD?
(yes/no)Emissionsfrom Five
Criteria
Pollutantsa(metric tons
per year)

Project-

In Process

Major

Yes

2,906

7,749,799

354

Gulf Coast
MethanolComplex

2 milesIssued
2018

Major

Yes

726

2,533,377

146

NOLA Oil
Terminal

4 milesIssued
2013

Minor

No

83

N/Ab

115

Braithwaite
Methanol
ManufacturingPlant

18 milesIssued
2014

Major

No

431

746,626

77

Pointe Celeste
Container
Terminal

3 milesNo
application
submitted

Minorc

Noc

Unknown

Unknown

Unknown

Pointe LNG

8 milesNo
application
submitted

Majorc

Yesc

Unknown

Unknown

Unknown

Delta LNG

0 milesUnknown

Unknown

Unknown

Unknown

Unknown

Unknown

-

-

-

-

4,146

10,979,319-

Activity

Total

Greenhouse
Gas
Emissions(metric tonsof CO2e per
year)

LAC
Regulated
Toxic Air
Pollutants(metric tons
per year)

Sources: See table 4.13-2.
a carbon monoxide, sulfur dioxide, inhalable particulate matter, volatile organic compounds, and nitrogen oxideb Not calculated. As a minor source, NOLA Oil Terminal proponent was not required to calculate greenhouse gas emissions.
c This classification is unconfirmed and based on professional judgment.
Key:- = not applicableCO2e = carbon dioxide equivalent
LAC = Louisiana Administrative CodeLDEQ = Louisiana Department of Environmental Quality
N/A = Not available because estimate not required for minor sources per Title V
PSD = Prevention of Significant Deterioration
TBD = to be determined

Section 4.11 describes the air quality permitting regime, including the two most salient
programs—Title V and the PSD program—implemented after adoption of the CAA. Under Title
V, the LNG terminal, Gulf Coast Methanol Complex, and Braithwaite Methanol Manufacturing
Plant are considered major air emissions sources. Based on PSD program thresholds, the LNG
terminal and Gulf Coast Methanol Complex are considered major sources and the NOLA Oil
Terminal is considered a minor source of emissions.
Three actions in table 4.13-11 have been issued their required air permits from LDEQ,
covering both state and federal preconstruction requirements. In order to be eligible for their air
emissions permit, each facility had to show that it “[would] not significantly contribute to any

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NAAQS exceedances” (LDEQ, 2018b). Moreover, the facilities’ emissions, in combination withbackground emissions, could not exceed thresholds for Louisiana state-regulated toxic air
pollutants. For unconstructed facilities with LDEQ permits, construction must begin within 18
months, and extensions may be applied for 12 to 18 months prior to expiration. Braithwaite
Methanol Plant was granted an extension in 2017.
LDEQ is currently reviewing an air permit application from Venture Global for operationof the LNG terminal. The substance of that application is reported in section 4.11. Federal
standards require modeling of a proposed facility’s emissions along with other ongoing andbackground emissions to demonstrate compliance with the NAAQS. These “baseline” emissions
include emissions of other permitted facilities that are not yet built, therefore Venture Global’s air
permit application included the emissions from the Braithwaite Methanol Plant and NOLA Oil
Terminal. Based on the results of that analysis, the cumulative impact on air quality fromoperations emissions at these three facilities would not exceed the limits of the NAAQS. On theother hand, emissions from the Gulf Coast Methanol Complex were not included in Venture
Global’s analysis submitted to LDEQ, nor were the LNG terminal’s emissions incorporated into
IGP Methanol LLC’s air permit application to LDEQ. LDEQ recently issued Gulf Coast Methanol
Complex’s air permit in January 2018. We requested Venture Global include Gulf Coast
Methanol’s emissions in a cumulative modeling analysis. Based on results from the updated
cumulative analysis that included Gulf Coast Methanol, Venture Global demonstrated that it would
not contribute significantly (i.e., would be below the significant impact level) at all locations thatmodeling indicated a potential exceedance of the NAAQS. Because the emissions from Venture
Global that would accumulate with those from other sources would not contribute significantly,
we estimate that Venture Global’s cumulative effect on air quality would not be significant.
The two unpermitted actions in table 4.13-11 are still in early phases of planning or
permitting. Pointe LNG, a proposed LNG manufacturing facility and export terminal, would
trigger major source regulations, requiring it to model its regulated emissions in combination withemissions from the LNG terminal and the permitted projects in table 4.13-11. Pointe LNG would
be required to demonstrate that the combined emissions do not exceed NAAQS thresholds before
it became eligible to receive an LDEQ air permit, thus limiting its contribution to an adverse
cumulative effect and ensuring the combined air pollution from regulated pollutants does notexceed health standards.
Pointe Celeste Container Terminal would require an LDEQ air permit for onsite, stationary
sources like a backup emergency generator or a maintenance shop where solvents are used.
However, most of its related emissions would not be regulated by LDEQ. Its greatest emission
sources would likely be vessels that call at the container terminal combined with other mobile
sources.
While emissions from facilities are well regulated and require ongoing inspection andcompliance, cumulative emissions from large vessels that would call at major facilities once
operation commences are not evaluated in CAA air permits. Given the quantities of marine diesel
fuel burned by large ocean-going vessels, their emissions of SO2 and NOX from fuel combustion
are a concern. The major industrial actions planned along the Lower Mississippi River would
generate daily vessel calls by tankers, methanol carriers, and in the case of the Pointe Celeste
Container Terminal, bulk carriers and container ships, all calling on terminals within
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approximately 21 miles of each other. NEPA evaluations include disclosure of these associatedvessel emissions, and those associated with the LNG terminal operation are reported in section
4.11.
Although emissions from vessels calling on the six new industrial developments could
contribute to an adverse cumulative effect on air quality, we do not expect the effect to besignificant. Localized cumulative effects from vessel emissions would be short-lived, because
vessel emissions near any of the facilities would dissipate shortly after the vessel passes by. While
docked, vessels’ main engines would typically operate at a very low load, known as hoteling, or
go into stand-by mode, minimizing the vessels’ emissions at berth.
Moreover, vessel emissions are regulated through international treaties and domestic
regulatory standards, even though they are not addressed in LDEQ air permit applications at the
project level. The United States is party to the International Maritime Organization, which has
implemented fuel, engine, and vessel standards as a result of the International Convention ofPrevention of Pollution from Ships, a treaty called “MARPOL” (EPA, 2017b). The resulting
standards limiting SOX and NOX entered into force as early as 2005, and the most recent updates
became effective in 2016. The international standards apply to U.S. vessels and foreign vessels.
In addition, the EPA has adopted fuel standards and engine emission standards for engines installedon U.S. vessels under the authority of the CAA (EPA, 2017b).
Given these factors, we do not expect vessel emissions from the Project to significantly
impair air quality.
If Delta LNG, as described in its pre-filing request to the Commission, moves forward,
additional LNG carrier traffic would be added in the Lower Mississippi River. Delta LNG would
be required to evaluate emissions and air quality impacts from the additional vessel traffic in its
NEPA documentation.
4.13.2.12

NoiseConstruction activities associated with the LNG terminal would have a moderate,
temporary adverse effect on land-based NSAs. Land-based and marine-side pile-driving to installover 500 pile supports for the LNG loading docks would generate the loudest noise, while thecomposite noise level of all other heavy equipment would be somewhat less. Construction
activities associated with the pipeline system would have minor, temporary effects on NSAs.
Activities include pile driving at the pipe bridge and metering station locations, dredging along thebarge access routes, HDD-related activities, and equipment operation. Operational noise emitted
from the LNG terminal would have minor adverse effect on NSAs, while the metering stations
associated with pipeline system would not affect NSAs with noise during operation.
Three other actions, in addition to the LNG terminal, could occur within the geographic
and temporal extent for cumulative impacts on noise, summarized in table 4.13-12. Two of theseactions, the levee upgrade and associated drainage canal relocation, would have no associatedoperational noise. Thus, we limited our evaluation to cumulative noise impacts during
construction of the Project and the additional actions.

4-328

The Delta LNG project would likely have operational noise but no information is available
to properly assess a cumulative operational impact. We can assume that if operational noise issimilar to the Project then similar mitigation would be implemented to minimize any elevatedoperational noise levels.
The main source of noise during the levee upgrade and drainage canal relocation actions
would be heavy earth-moving vehicles and other construction equipment. We do not expect thatpile driving or HDD equipment would be used, which generate louder noise than other standard
construction equipment. The Commission allows a maximum of a 10.0 dBA increase above
ambient noise levels at NSAs, and Venture Global has demonstrated that by constructing 5-meterhigh noise protection walls around piling rigs, Venture Global would limit the increase of ambient
noise levels to 0.4 dBA and 2.2 dBA at the two nearest NSAs. The NSAs are residences in theDeer Range neighborhood and are located 0.60 mile and 0.9 mile from the center of the LNG
terminal site. These same NSAs are 1,600 and 3,900 feet from the pipe bridge, where Venture
Global would conduct pile-driving of 18 piles over 20 days. The closest NSA would experience
about an 8 dBA increase during those 20 days of pile driving. Finally, HDD activities to thread
the two 0.4-mile-segments of pipe under live oak sensitive habitat between the non-federal leveeand the terminal boundary would be a similar distance from the NSAs. Venture Global would
implement a sound curtain enclosure or acoustic barrier around the drilling rig and stationary
equipment that would limit the noise level increase at the closest NSA to around 3 or 4 dBA. Pile
driving to support the pipe bridge would not occur concurrently with HDD pipeline construction,
but pile driving associated with the LNG loading docks could occur concurrently with one or bothof these pipeline activities. We should note, however, that noise emissions are not additive, butrather accumulate, and blend such that the combined noise level is less than the sum.
Table 4.13-12
Other Activities within the Geographic Scope and Temporal Scope for Cumulative Noise Impacts during
Construction
Distance from theProject Boundary

Construction Period

Noise during
Operation?

-

2019–2023

Yes

NOV/NFL Levee Upgrade

0 miles

By 2024No

NOV/NFL Drainage Canal Relocation

0 miles

By 2024

No

Delta LNG

0 miles

2021 - 2024

Yes

Activity
ProjectKey:- = not applicable
NFL = Non-Federal Levees
NOV = New Orleans to Venice

The NSAs referred to above are just a few hundred feet from the levee, where construction
equipment and vehicles would eventually be used to perform the levee upgrade. Heavy trucks orequipment could be used concurrently to help implement the drainage canal relocation that isnecessitated by the levee upgrade, but we assume only minor earthworks activities because thecanal already exists. Thus, we considered noise from the canal relocation to be negligible.

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In the unlikely event that Venture Global’s pile-driving and/or HDD construction activities
overlap with USACE upgrades of the levee portion within 0.5 mile of the LNG terminal, thecumulative noise effects on the closest NSAs would be temporary and adverse, lasting for a few
days or weeks. However, the likelihood of timing overlap is low. The USACE has not announced
projected construction dates for this section of the levee, indicating that the construction start date
could still be several years in the future. Venture Global, on the other hand, would commence andcomplete pile driving for the LNG loading docks within the first years of constructioncommencement in 2019. Regardless, Venture Global will coordinate its construction activities
with the USACE in accordance with the Section 408 Permit issued by the USACE for the pipe
bridge over the levee.
4.13.2.13

Safety and Reliability

Potential impacts on public safety would be mitigated through implementation of
applicable federal, state, and local rules and regulations for the proposed Project. These rules andregulations, described in section 4.12.1 and 4.12.2, would ensure appropriate standards would beapplied to design and engineering, construction, operation, and maintenance to protect the public
and avoid or minimize the potential for accidental or intentional incidents. The other LNG projects
listed in table 4.13-2 would be required to follow the same rules and regulations, and other large
industrial projects listed in table 4.13-2 would be subject to similar rules and regulations. These
rules and regulations are intended to protect the public from the potential impacts of industrial
projects singularly and cumulatively, and no significant cumulative impact on public safety is
anticipated. Public services, including emergency services, would need to be appropriately sizedto accommodate the population at the time the Project was constructed and operated. In addition,
the Project and the other LNG projects would be required to prepare a comprehensive ERP (per49 CFR 192.615) and identify the cost sharing mechanisms for funding these emergency response
activities. These plans would minimize the potential for impacts on public safety from individual
projects or when considered cumulatively with the other concurrent projects. In the unlikely eventthat major incidents occur at multiple facilities concurrently, the acute cumulative demand on
emergency services would likely be significant; however, assistance from emergency service
providers from neighboring parishes and communities would serve to mitigate the demand. We
conclude that the impact of the Project, when considered cumulatively with the other concurrent
projects, would not have a significant impact on demand for public services.
4.13.2.14

Climate Change

Climate change is the variation in climate (including temperature, precipitation, humidity,
wind, and other meteorological variables) over time, whether due to natural variability, humanactivities, or a combination of both, and cannot be characterized by an individual event or
anomalous weather pattern. For example, a severe drought or abnormally hot summer in aparticular region is not a certain indication of climate change. However, a series of severe droughts
or hot summers that statistically alter the trend in average precipitation or temperature over decades
may indicate climate change. Recent research has begun to attribute certain extreme weather
events to climate change (USGCRP, 2018).

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The leading U.S. scientific body on climate change is the U.S. Global Change Research
Program (USGCRP), composed of representatives from 13 federal departments and agencies.41
The Global Change Research Act of 1990 requires the USGCRP to submit a report to the President
and Congress no less than every four years that “1) integrates, evaluates, and interprets the findingsof the USGCRP; 2) analyzes the effects of global change on the natural environment, agriculture,energy production and use, land and water resources, transportation, human health and welfare,human social systems, and biological diversity; and 3) analyzes current trends in global change,
both human-induced and natural, and projects major trends for the subsequent 25 to 100 years.”
These reports describe the state of the science relating to climate change and the effects of climatechange on different regions of the U.S. and on various societal and environmental sectors, such as
water resources, agriculture, energy use, and human health.
In 2017 and 2018, the USGCRP issued its Climate Science Special Report: Fourth
National Climate Assessment, Volumes I and II (Fourth Assessment Report) (USGCRP, 2017; andUSGCRP, 2018, respectively). The Fourth Assessment Report states that climate change has
resulted in a wide range of impacts across every region of the country. Those impacts extend
beyond atmospheric climate change alone and include changes to water resources, transportation,
agriculture, ecosystems, and human health. The U.S. and the world are warming; global sea levelis rising and acidifying; and certain weather events are becoming more frequent and more severe.
These changes are driven by accumulation of GHG in the atmosphere through combustion of fossil
fuels (coal, petroleum, and natural gas), combined with agriculture, clearing of forests, and othernatural sources. These impacts have accelerated throughout the end 20th and into the 21st century(USGCRP 2018).
Climate change is a global phenomenon; however, for this analysis, we will focus on theexisting and potential cumulative climate change impacts in the Project area. The USGCRP’s
Fourth Assessment Report notes the following observations of environmental impacts are
attributed to climate change in the Southeast region (USGCRP, 2017; USGCRP, 2018):

41•

temperatures cycled between warm and cool periods extending from 1920 to 1970.
After 1970, annual average temperatures have warmed to levels above the 1930s; thedecade of 2010 through 2017 has been warmer than any previous decade for average
daily maximum and average daily minimum temperature;•since 1960, there have been lower numbers of days above 95°F compared to the pre1960 period but during the 2010’s the number of nights above 75°F has been nearly
double the average over 1901 – 1960. The length of the freeze free season was 1.5
weeks longer on average in the 2010s compared to any other historical period onrecord;The USGCRP member agencies are: Department of Agriculture, Department of Commerce, Department of
Defense, Department of Energy, Department of Health and Human Services, Department of the Interior,
Department of State, Department of Transportation, Environmental Protection Agency, National Aeronautics
and Space Administration, National Science Foundation, Smithsonian Institution, and U.S. Agency forInternational Development.

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•

number of days with 3 or more inches of rain has been historically high over the past
25 years. The 1990s, 2000s and 2010s rank first, third and second, respectively innumber of events;•

summers have been either increasingly dry or extremely wet, depending on location;•

due to a combination of sea level rise and soil subsidence, approximately 2,006 square
miles of land has been lost in Louisiana between 1932 and 2016, or about 23 square
miles per year; and•in southeast Louisiana, relative sea level is rising at a rate of 1 to 3 feet per 100 years.

The USGCRP’s Fourth Assessment Report notes the following projections of climatechange impacts in the Project region (Southeast U.S.) with a high or very high level of confidence 42(USGCRP, 2018):•

climate models project nighttime temperatures above 75°F and daytime maximum
temperatures above 95°F become the summer norm. Nights above 80°F and days
above 100°F, which are now relatively rare, would become common;•

lowland coastal areas are expected to receive less rainfall on average but experience
more frequent intense rainfall events followed by longer drought periods;•

coastal areas along the Gulf of Mexico are flat; therefore, expected sea level rises may
cause inundation in certain low lying areas;•

drought and sea level rise will create stressful conditions for coastal trees that are notadapted to higher salinity levels;•

other coastal species may also be stressed by sea level rise and warmer temperatures,prompting migration out of the area; and•tropical storms and hurricanes may become more intense.

It should be noted that while the impacts described above taken individually may be
manageable for certain communities, the impacts of compound extreme events (such as
simultaneous heat and drought, wildfires associated with hot and dry conditions, or flooding
associated with high precipitation on top of saturated soils) can be greater than the sum of the parts(USGCRP, 2018).

42

The report authors assessed current scientific understanding of climate change based on available scientific
literature. Each “Key Finding” listed in the report is accompanied by a confidence statement indicating theconsistency of evidence or the consistency of model projections. A high level of confidence results from “moderate
evidence (several sources, some consistency, methods vary and/or documentation limited, etc.), medium
consensus.” A very high level of confidence results from “strong evidence (established theory, multiple sources,consistent
results,well
documented
and
acceptedmethods,etc.),
highconsensus.”
https://science2017.globalchange.gov/chapter/front-matter-guide/

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The GHG emissions associated with construction and operation of the Project wereidentified and quantified in section 4.11. Construction and operation of the Project would increase
the atmospheric concentration of GHGs in combination with past, current, and future emissions
from all other sources globally and contribute incrementally to future climate change impacts.
Currently, there is no universally accepted methodology to attribute discrete, quantifiable,
physical effects on the environment to the Project’s incremental contribution to GHGs. We havelooked at atmospheric modeling used by the EPA, National Aeronautics and Space Administration,
the Intergovernmental Panel on Climate Change, and others, and we found that these models are
not reasonable for project-level analysis for a number of reasons. For example, these global
models are not suited to determine the incremental impact of individual projects, due to both scaleand overwhelming complexity. We also reviewed simpler models and mathematical techniques
to determine global physical effects caused by GHG emissions, such as increases in global
atmospheric CO2 concentrations, atmospheric forcing, or ocean CO2 absorption. We could not
identify a reliable, less complex model for this task and we are not aware of a tool to meaningfully
attribute specific increases in global CO2 concentrations, heat forcing, or similar global impacts toproject-specific GHG emissions. Similarly, it is not currently possible to determine localized or
regional impacts from GHG emissions from the Project.
Absent such a method for relating GHG emissions to specific resource impacts, we are notable to assess potential GHG-related impacts attributable to this project. Additionally, we havenot been able to find any GHG emission reduction goals established either at the federal level 43 orby the State of Louisiana 44. Without either the ability to determine discrete resource impacts oran established target to compare GHG emissions against, we are unable to determine thesignificance of the Project’s contribution to climate change.
4.13.3 Conclusion
Based on our evaluations of resources affected by the Project, geology; soils; surface
waters and aquatic wildlife and habitat; wetlands; vegetation and wildlife; land use; visual
resources; socioeconomics; vessel traffic; noise; and cultural resources would not sustain
significant adverse cumulative impacts. In the case of geology and soils, no other present orforeseeable actions would occur within the geographic scope. Several actions would occur within
the scope for surface waters and aquatic wildlife and habitat, and we assessed potential cumulative
effects to the Mississippi River and the Barataria Basin. However, we found no significant adverse
cumulative impact on water quality or aquatic wildlife populations or habitat from increases inturbidity, sediment, effluent discharge, ballast water discharge, increased erosion, risk of leaks andspills, or pile driving. Because federal regulations stipulate that an action disturbing more than 5acres cannot cause a permanent loss of wetland function, we found that cumulative adverse impacts
on wetlands would not be significant. The other identified actions within the area of disturbanceof the Project would affect only a minimal amount of forested and herbaceous vegetated area
43
44

The national emissions reduction targets expressed in the EPA’s Clean Power Plan and the Paris climate
accord are pending repeal and withdrawal, respectively.
We reviewed the U.S. State Greenhouse Emission Targets site for individual state requirements locatedat:https://www.c2es.org/document/greenhouse-gas-emissions-targets/

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compared with the Project, so the cumulative effect on vegetation and associated wildlife would
be no more than minor.
Given the presence of New Orleans and the greater metropolitan region near the Project,
existing temporary housing accommodations and public services could absorb the needs of theworkforces on concurrent construction projects in Plaquemines Parish without creating significant
socioeconomic adverse effects. Because field and desktop surveys and correspondence with tribes
did not uncover any archaeological or historic properties in the area of potential effect of the LNG
terminal or pipeline system, we do not expect any cumulative effect on cultural resources.
Potential exists for noticeable impacts on land use and visual resources. The Project andthree other foreseeable industrial actions on the west bank would convert agricultural andundeveloped land to major industrial uses. This change would be clearly noticeable, but the
majority of the acreage affected by foreseeable activities would be consistent with the Parish Plan.
We found that the cumulative visual effect from development of the major industrial actions on
SH 23 would be moderate given the magnitude of change and intermittent exposure level oftravelers on the highway.
The cumulative noise effects near certain residences in the Deer Range neighborhood could
be adverse for a few days or weeks if Venture Global’s pile-driving and/or HDD construction
activities overlap with USACE upgrades and/or Delta LNG. However, overlap of these specificactivities is unlikely. Venture Global has committed to coordinating with the USACE on these
activities to ensure no overlapping effects.
The only resource that could sustain significant adverse cumulative impact is air quality.
Effects on ambient air quality during operation of the Project when combined with the Gulf Coast
Methanol Complex operations could be significant, i.e., exceed the NAAQS. The Project’s air
quality application incorporated emissions from other permitted industrial actions in the vicinity,
but not those from the Gulf Coast Methanol Complex.
We assessed the Project’s annual GHG emissions, 7,749,799 tpy, and noted the GHG
emissions of two other foreseeable actions for which GHG emissions have been calculated. The
total estimated GHG emissions from the three projects is 10,979,319 tpy, while three otherforeseeable industrial actions would generate additional GHG emissions which have not been
quantified. Venture Global would implement multiple EPA-approved BACT to minimize GHG
emissions and demonstrated through modeling in its air permit application to LDEQ and EPA theemission limits each BACT would achieve. Because of a lack of standard methodologies, we
could not determine whether the Project’s incremental contribution of GHGs would result in aphysical effect on the environment, or whether the cumulative contribution of GHGs from multiple
industrial facilities would be significant.
In this cumulative impact analysis, we established conservative assumptions about theother actions in the region. To the extent possible, we considered the most intense cumulativeenvironmental outcomes that could reasonably be expected. In fact, the likelihood is low that all
projects would go forward according to schedule or according to our assumptions that unscheduled
projects would coincide with this Project.

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5.0

CONCLUSIONS AND RECOMMENDATIONS

5.1

SUMMARY OF THE ENVIRONMENTAL ANALYSISThe conclusions and recommendations presented in this section are those of the FERC
environmental staff. Our conclusions and recommendations were developed with input from the
USACE, USCG, DOE, DOT, and EPA as cooperating agencies. The federal cooperating agencies
may adopt the EIS per 40 CFR 1506.13 if, after an independent review of the document, they
conclude that their permitting requirements and/or regulatory responsibilities have been satisfied.
However, these agencies would present their own conclusions and recommendations in theirrespective and applicable records of decision or determinations. Otherwise, they may elect toconduct their own supplemental environmental analysis, if necessary.
We determined that construction and operation of the Project would result in limited
adverse environmental impacts. Most adverse environmental impacts would be temporary or shortterm during construction and operation, but long-term and permanent environmental impacts on
wetlands, open water habitats, vegetation, view shed, and land use would also occur as part of the
Project. This determination is based on a review of the information provided by Venture Global
and further developed from data requests; field investigations; scoping; literature research;alternatives analysis; and contacts with federal, state, and local agencies, as well as tribes andindividual members of the public. As part of our review, we developed specific mitigation
measures that we determined would appropriately and reasonably reduce the environmental
impacts resulting from construction and operation of the Project. Therefore, we are recommendingthat our mitigation measures be attached as conditions to any authorization issued by theCommission. If the Project is constructed and operated in accordance with applicable laws andregulations, the mitigating measures discussed in this EIS, and our recommendations, adverse
environmental impacts would be reduced to less than significant levels. A summary of the
anticipated impacts from the Project and our conclusions regarding impacts are provided below by
resource area.
5.1.1

Geologic Resources

Construction and operation of the Project would not affect active mining or non-fuelmineral resources during construction or operation. The nearest non-fuel mineral resource isapproximately 3 miles to the south and east of the pipeline system. Three plugged and abandoned
former oil and gas wells are located within the proposed pipeline construction workspace. In
addition to the aforementioned wells, 18 additional plugged and abandoned wells, one permitted
well, and two producing wells (currently shut-in for future utility) are located within 0.25 mile ofthe proposed pipeline system workspace. To avoid impacts on the two producing wells, and toafford the owner(s) or their representative the opportunity to be on-site during construction
activities, we have made a recommendation in section 4.1.2 that Gator Express Pipeline notify wellowner(s) 72 hours prior to construction activities near the producing oil and gas wells locatedwithin 0.25 mile of the Project workspace and allow a representative to be present during
construction.

5-1

The proposed pipeline system crosses two state mineral lease areas. Venture Global has
indicated they will negotiate permanent easement rights and any necessary access restrictions withthe lease owners.
In general, the potential for geologic hazards such as earthquakes, soil liquefaction,
shoreline erosion and landslides, or a seismically generated tsunami to significantly affectconstruction or operation of the pipeline system is low. However, some hazards such as flooding
and hurricanes could affect pipeline construction. Venture Global would construct the meterstations at an elevation to minimize potential impacts from flooding and hurricanes.
Impacts on geologic resources due to installation of the pipelines and meter stations would
be primarily limited to construction activities and include disturbance by “prop-washing” forconstruction in open water locations. Such impacts resulting from trenching would be temporary
because Venture Global would restore these areas to preconstruction contours to the maximum
extent practicable.
The full design of the pipeline system is currently being developed. Venture Global has
proposed a feasible design and committed to conducting additional detailed design work for if the
Project is authorized by the Commission. Information regarding the development of the final
design would need to be reviewed by FERC staff in order to ensure that the final design addresses
the requirements identified in the FEED. Therefore, we are recommending (see section 4.3.2.1)
that Venture Global file its final site preparation drawings and specifications, meter station
foundation design drawings and calculations, and quality control procedures to be used for
civil/structural design and construction on a schedule to be identified in its Implementation Plan.
We do not anticipate that any blasting would be required for construction of the proposed
pipeline system. Based on the above discussion, in consideration of Venture Global’s proposed
mitigation and design criteria, and based on our recommendations, we conclude that the pipeline
system would not markedly affect or be affected by geological conditions in the area.
5.1.2

Soils

Construction of the Project could affect soil resources by increasing the potential for
erosion, compaction, and rutting. Based on the soil properties reviewed, none of the soils
potentially affected by the Project is considered highly susceptible to erosion by wind or water.
Due to fine textured soils and nearly level topography, no revegetation concerns were identified.
However, most of the soils found at the terminal site are prone to compaction and are consideredhydric. Approximately 150 acres of prime farmland are found along the pipeline route and LNG
terminal site.
Construction activities such as clearing, grading, excavation, backfilling, and the
movement of construction equipment may affect soil resources at the LNG terminal site. In order
to increase the load-bearing capacity of soils within the terminal site, soil modifications would bemade through the addition of materials to the soil at the LNG terminal site such as lime or cement
and a surface layer of aggregate.
Following construction, approximately 622 acres of soils at the LNG terminal site would
be permanently impacted by paved or gravel plant roads or occupied by aboveground facilities.
5-2

Venture Global would seed the remaining acreage within the terminal site with native vegetation
recommended by the NRCS. The remaining acres of soils would be restored to preconstruction
conditions and are anticipated to retain their former productivity.
To reduce the impacts of construction on soils, Venture Global would implement measures
outlined in its Project-specific Plan and Procedures, which provide measures to control erosion
and sedimentation during construction and to ensure proper restoration of disturbed areas
following construction. The Project-specific Plan and Procedures include some modifications to
our Plan and Procedures where Venture Global consider individual measures unnecessary,
technically infeasible, or unsuitable due to local conditions (see appendix C, tables 1 and 2,
respectively). We agree that most of Venture Global’s proposed modifications are reasonable andthat its proposed alternative measures would achieve a comparable level of mitigation as the FERC
measures.
In addition, disturbed areas would be monitored by Venture Global following construction
for the first and second (as necessary) growing seasons in upland areas and at least 3 years inwetlands to ensure successful restoration. With implementation of the proposed mitigation
measures and Project-specific Plan and Procedures, we conclude that impacts on soil resources
would be adequately minimized.
5.1.3

Water Resources

5.1.3.1 Groundwater
The LNG terminal site and pipeline system route are underlain by multiple, stratified
aquifer systems, including the Gramercy aquifer, Norco aquifer, Gonzales-New Orleans aquifer,
and the “1,200 foot” aquifer. These aquifers are primarily saline in the vicinity of the Project andare not designated EPA sole-source aquifers. Drinking water in Plaquemines Parish is primarily
from the Mississippi River. Venture Global may utilize groundwater sourced from a newly
installed well or wells at the terminal site for operation. Venture Global plans to utilize surface
water for hydrostatic testing of the LNG tanks, piping, and non-LNG tanks from a drainage canallocated along the terminal property. No groundwater would be utilized during the construction of
the proposed pipeline system.
Most of the construction activities associated with the LNG terminal and pipeline systemfacilities would involve shallow, temporary, and localized excavation, with the exception of theinstallation of groundwater wells and concrete and steel piles at the LNG terminal. Limited
transmissivity data suggest that the Gramercy aquifer, Norco aquifer, Gonzales-New Orleansaquifer, and the unnamed 1,200-foot-thick sand aquifer will each have a transmissivity values
greater than 10,000 square feet per day at the LNG terminal site. Aquifers with similartransmissivity values can typically yield greater than 300 gallons per minute for a properly
constructed supply well. If new supply wells were to be installed at the LNG terminal site, one ormore wells would be installed in the targeted aquifer to produce 600 gallons per minute fortreatment and use. Concrete and steel piles required for the LNG storage tanks and LNG shiploading and berthing areas would be driven to a depth no lower than approximately 250 feet andare not expected to have direct impacts on the underlying aquifer, which is overlain by about 300
feet of surficial sediments.

5-3

Neither the LNG terminal site nor the pipeline system are within drinking water protection
areas for public supply wells. The portion of the terminal within the batture habitat is within thesource water protection area for the Pointe a la Hache water system and the Port Sulfur Water
District and is discussed in detail below in the Surface Water section. Only one well is locatedwithin 1 mile of the LNG terminal site and pipeline system. This well is an artesian well locatedwithin the 80-acre construction yard (eastern workspace) adjacent to the LNG terminal. The well
was intended for agricultural purposes; however, the water salinity is too high for agriculture use
according to local farmers. Plaquemines LNG plans to plug and abandon the artesian well during
construction. Since no other wells are located within a mile of the Project, it is unlikely that the
Project will affect public or private supply wells.
Venture Global anticipates that surface water from an onsite drainage canal would be
utilized for hydrostatic testing of the LNG storage tanks. If the drainage canal does not containenough water at the time of testing, water would then be appropriated from the Mississippi River.
Therefore, the localized effects of the LNG terminal groundwater use would not have a significant
effect on the aquifers.
5.1.3.2 Surface Water
The Mississippi River at the LNG terminal site is a Navigable Waterway under section 10of the Rivers and Harbors Act. According to Venture Global, the Mississippi River depth at the
LNG terminal site is sufficient to support the terminal marine facilities. Therefore, no dredging
within the Mississippi River would be required to construct and operate the Project. Constructionof the terminal facilities would temporarily impact 72.7 acres of the Mississippi River, andoperation of the LNG terminal would permanently impact 14.6 acres of the Mississippi River.
In addition to impacts on the Mississippi River, construction of the LNG terminal facility
would impact man-made ditches within the LNG terminal Project area and within the easternworkspace adjacent to the LNG terminal site. These man-made ditches are part of the fastlands
system. These impacts would primarily consist of filling the ditches to construct the LNG terminal.
In-water construction associated with the LNG loading and ship berthing facilities, ground
disturbance, filling of waterbodies within the fastlands, and general construction activities within
the LNG terminal site would result in localized, temporary increases in turbidity and suspended
sediment levels. To minimize impacts on water quality, land disturbing activities would be
conducted in compliance with the LPDES General Permit. In addition, Venture Global would
implement its Project-specific construction SWPPP, Plan, and Procedures. Our Procedures requirethat instream work within cool-water and warm-water fisheries must occur from June 1 toNovember 30, unless expressly permitted or further restricted by the appropriate federal or stateagency. Venture Global has stated the seasonal restriction would not be practical and has obtained
written consent from the LDWF to construct outside of the warm-water construction window. As
a result, impacts on water quality from terminal construction are expected to be temporary andlimited to the area within and immediately adjacent to the ship berthing facilities and within the
fastland ditch system.
Operation of the LNG terminal would increase the amount of impervious surface, which
would result in an increased volume of stormwater. Stormwater inside the terminal facilities would

5-4

be collected through series of ditches into sumps. Sumps that service LNG spill impoundment
basins and other facilities where hazardous materials may be present would be equipped with
automatic shutoffs that activate when LNG or other solvents are present. This would prevent
contaminated stormwater from being pumped from the facility. Sumps pumps within the floodwall
would pump the stormwater to a stormwater header and then to the Mississippi River. Stormwatercollected from the terminal marine facilities would be processed through oil/water separators prior
to being discharged to the Mississippi River.
The majority of the pipeline system would be constructed in open water, including bays,
canals, bayous, and unnamed channels. Additionally, portions of the barge access channels would
require dredging to accommodate equipment and pipe delivery. None of the surface waters
impacted by the pipeline system are listed as National Wild and Scenic Rivers or designatedOutstanding Natural Resource Waters. The majority of the surface waters traversed by the pipeline
system are considered EFH and support some federal and state listed species. Potential impacts
on EFH and federally and state-listed species are summarized in section 5.1.7. Venture Global
would minimize potential impacts on surface waters by implementing the Project-specificProcedures.
During construction of the LNG terminal, barges and support vessels would deliver large
equipment and materials to the MOF, and during operation, LNG vessels would call on the LNG
terminal. The construction and operational vessel traffic may increase shoreline erosion andtemporarily increase turbidity levels within the Mississippi River and along vessel transit routes.
The shoreline at the terminal site is already armored, and any impacts on the existing armoringfrom terminal construction would be repaired. The existing armoring would prevent erosion of
the adjacent shoreline by wave activity from vessels maneuvering within the berthing area. The
Mississippi River currently functions as a navigation channel that provides deep-water access formaritime commerce. As such, use of the waterways by LNG carriers, barges, and support vessels
during construction and operation of the LNG terminal would be consistent with the current useof active shipping channels, and associated impacts on water quality within the shipping channel
would be minor.
Ballast water discharges at the LNG terminal could impact water quality by changing thesalinity, temperature, pH, and dissolved oxygen level of water within the Mississippi River in thevicinity of the LNG terminal. Differences between the physiochemical composition of ballast
water and the water present within the Mississippi River would vary depending on hydrologic
conditions at the time of discharge. The primary potential impact on water quality due to ballast
water discharge would be a temporary increase in salinity level. The Mississippi River is usuallyfreshwater at the LNG terminal site. However, during periods of low flow, saltwater can push up
the Mississippi River to the LNG terminal site and beyond. Ballast water, which would generally
consist of open ocean water, would have a salinity of approximately 35 ppt (NOAA, 2018). In
general, ballast water would have a higher salinity than the surrounding water at the LNG loading
docks. The amount of ballast water discharged into the Mississippi River during each LNG carrier
visit to the LNG terminal would make up a small percent of the water within the Mississippi River,as the Mississippi River discharges, on average, nearly 400 billion gallons per day into the Gulf of
Mexico (NPS, 2018).

5-5During construction and operation, spills or leaks of hazardous materials flushed into
waterbodies could have an adverse impact on water quality. To prevent spills and leaks, Venture
Global would implement its Project-specific SPCC Plans during construction and operation of the
LNG terminal and pipeline system, which identify potential sources of releases at the site,measures to prevent a release, and initial responses in the event of a spill.
Venture Global would utilize 50,000 gallons of water, recycled over five uses, to test plant
piping and tanks other than the LNG storage tanks. Venture Global would utilize 26,200,000
gallons of water for hydrostatic testing of the LNG storage tanks. The water for LNG storage tankhydrostatic testing would be transferred between tanks to conserve water. The water for testing
plant piping and tanks other than LNG storage tanks would also be sourced from the nearby
drainage canal. Water would be withdrawn from the canal at a rate of 1,500 gallons per minute tominimize impingement of aquatic organisms and debris. The intake structure would be fitted with
0.25-inch to 1.0-inch screens to minimize entrainment of aquatic organisms and debris. Smallquantities of water used for hydrostatic testing may be discharged directly to the ground. Largedischarges of hydrostatic test water would be treated, as necessary, and discharged to theMississippi River, into adjacent drainage canals, or on-site in accordance with permit conditions.
Pumps and energy dissipation devices would be used to control the discharge rate and limit
scouring and erosion.
Venture Global estimates that 5,626,316 gallons would be required for hydrostatic testingof the Southwest Lateral TGP pipeline and 3,997,658 gallons of water would be required forhydrostatic testing of the Southwest Lateral TETCO pipeline. The water for testing the pipeline
system would be sourced from a drainage canal near the terminal. The pumping rate would varyfrom 250 to 500 gallons per minute, and the water would be passed through a 0.25-inch to 0.5inch mesh screen to block the uptake of various debris and aquatic biota. After testing, the water
would be discharged back into the canal through an energy dissipating structure.
Where water from the nearby drainage canal is used to hydrostatically test the LNG storage
tanks and pipeline system, chemical additives may be required during the testing process toneutralize bacteria and other components that can be corrosive. Before returning hydrostatic water
to its surface water source, Venture Global would pass the water through 25- to 50-micron filters
and an active carbon medium to remove suspended solids and neutralize or biodegrade thechemical additives. Following completion of the hydrostatic testing and prior to being discharged,
the test water would be analyzed for total suspended solids, oil and grease, and pH in accordancewith LPDES general permit LAG670000.
To reduce the impacts of construction on surface waters (wetlands and waterbodies),
Venture Global would implement measures outlined in its Project-specific Plan and Procedures,
which provide measures to control erosion and sedimentation during construction and to ensure
proper restoration of disturbed areas following construction. The Project-specific Plan andProcedures include some modifications to our Plan and Procedures where Venture Global consider
individual measures unnecessary, technically infeasible, or unsuitable due to local conditions (seeappendix C, tables 1 and 2, respectively). We agree that most of Venture Global’s proposed
modifications are reasonable and that its proposed alternative measures would achieve acomparable level of mitigation as the FERC measures. However, concerning the modification to
Section V.B.1 of our Procedures that limits the time window for construction in waterbodies,
5-6

Venture Global has obtained consent from LDWF to construct instream construction outside ofthese windows.
With the implementation of Venture Global’s Project-specific Plans and Procedures, theproposed mitigation measures discussed in this EIS, and our recommendation, we conclude that
impacts on surface waters would be minimized.
5.1.4

Wetlands

Construction of the LNG terminal would result in the permanent filling of PEM wetlands,
including impacts on wetlands within the eastern workspace. In addition, PFO wetlands would bepermanently converted to PEM/PSS wetlands. In addition, temporary impacts, affecting PEM andPFO wetlands would result during construction of the terminal facilities. Once construction iscomplete, these areas of temporary impacts would be restored. Construction at the LNG terminalsite has the potential to have secondary and indirect impacts on adjacent wetlands. Implementationof protective measures in the Project-specific Plan and Procedures, the SPCC Plan, and the
SWPPP, including erosion and sediment controls, would minimize the impacts on adjacent
wetlands.
Construction and operation of the pipeline system would result in the permanent filling of
ESS wetlands and PSS wetlands. Additionally, permanent impacts on open water would result
from construction of platforms for the aboveground facilities. Construction of the pipeline system
would result in temporary impacts on wetlands and open water. Wetland impact acreages areshown in tables 4.4-1 and 4.4-2.
Section II.A.2 of our Procedures requires site-specific justifications for the use of aconstruction right-of-way greater than 75-feet-wide in wetlands. Venture Global states that the
Project requires a 130-foot-wide construction right-of-way for pipeline installation where the pushmethod is used, due to the need for a relatively wide and deep trench to ensure the required depthof cover in the wet, poorly cohesive, and easily sloughed substrate, and the consequent need forincreased space to sidecast relatively high spoil volumes to be used for later restoration. Venture
Global further states that the Project requires a 300-foot-wide construction right-of-way forpipeline installation in open waters, where the barge lay method is used, to accommodate an
approximately 100-foot-wide flotation channel for lay barge and supply barge access and up to
approximately 100 feet on either side of the flotation channel for construction workspace to deposit
sidecast trench material to be used for later restoration. The 300-foot-wide construction right-ofway would allow for safe and wholly waterborne construction.
We accept that this proposed modification is necessary because the combination of pipe
size, the inundated or saturated soil conditions, and the pervasiveness and extent of wetlands andopen water in the Project area make the 75-foot-wide right-of-way infeasible.
Our Procedures state that aboveground facilities should be located outside of wetlands,
except where such siting would prohibit compliance with DOT regulations. Venture Global has
proposed locating portions of aboveground facilities within wetlands, as there are no uplandalternatives because the pipeline system is largely located in wetlands and open water.
Additionally, based on comments received from the LDWF, the use of bank line stabilization

5-7

material at the interface of marsh and open water for all pipelines installed via the open trench
would mitigate loss of marsh from open water intrusion. We agree that locating some abovegroundfacilities is unavoidable in the Project area and concur with the LDWF that the pipeline
construction methods and wetland compensation plan would result in no net loss of wetlands.
The USACE would require Venture Global to propose compensatory mitigation that iscommensurate with the amount and type of wetland impacts resulting from construction andoperation of the Project. There are three mechanisms for providing compensatory mitigation.
These wetland mitigation mechanisms, in order of USACE preference, are: mitigation banks, inlieu fee mitigation, and permittee-responsible compensatory mitigation. As part of the section
10/404 process, Venture Global would be required to develop a Compensatory Mitigation Plan tomitigate unavoidable wetland impacts. The Compensatory Mitigation Plan would be subject toreview and approval by the USACE as part of the section 10/404 process.
5.1.5

Vegetation

Much of the area affected by the terminal facility is former agricultural lands that are
surrounded by levees and are dewatered through pumping specifically for agriculture use anddevelopment. These lands have been utilized as pasture lands in the past and exhibit limited
diversity. Therefore, the impact on vegetation communities as a result of the LNG terminal
construction would be minor.
The collocation of the pipelines would minimize impacts on vegetation communities
during construction and operation of the pipeline system. Venture Global would also implement
the Project-specific Plan and Procedures, which require the use of temporary and permanenterosion control measures, topsoil segregation in select areas, testing and mitigation for soil
compaction, post-construction monitoring, and limited routine vegetation maintenance. All
disturbed areas would be routinely monitored in accordance with the Project-specific Plan andProcedures until restoration and revegetation are successful. Venture Global would also
implement its Noxious Weed Plan to control the spread and introduction of noxious and invasive
species.
With the implementation of the minimization efforts described above, we conclude that
construction and operation of the pipeline system would have a minor impact on vegetation
communities.
5.1.6

Wildlife and Aquatic Resources

5.1.6.1 Wildlife
Wildlife species occurring in the vicinity of the proposed LNG terminal and pipeline
system are characteristic of the habitats provided by the vegetative communities that occur in theseareas. Construction of the LNG terminal would impact vegetated wildlife habitat, of which, someacreage would be permanently converted to industrial use. Based on field surveys, over 92 percentof the permanent impacts at the LNG terminal site are to current pasture and hay production land
(cultivated cropland in USGS classification). In addition to the cultivated cropland impacts,
operation of the terminal would result in permanent impacts on forested/scrub-shrub uplands and

5-8

PFO wetlands (batture). Due to the site’s history as pastureland, species diversity is low, which
lessens its value as habitat for wildlife.
Operation of the LNG terminal would result in increased noise, lighting, and humanactivity that could disturb wildlife in the area. However, due to current industrial activities at otherfacilities on the Mississippi River, wildlife species in the area are expected to be acclimated to thenoise and artificial lighting associated with these activities. Therefore, we expect impacts due tonoise, light, and human activity during operation of the LNG terminal to be negligible. Birds could
also be affected by flaring at the terminal. The terminal is designed to limit flaring events only to
LNG carrier gas up/cool down operations, which may occur up to forty times a year. During
operation of the LNG terminal, use of the marine and emergency flares would only occur during
process upset conditions. To the extent practical, use of the flares during initial facility start-up
will be limited to daylight hours, limiting potential impacts on birds, and, to the extent practical,
will be planned to avoid inclement weather when the risk of bird mortalities from attraction to theflares would be the highest. Therefore, we find that occasional flaring during operation would not
substantially impact migratory birds passing through the area.
The majority of the pipeline system would temporarily impact herbaceous and shrub/scrub
habitats including EEM wetlands, ESS wetlands, PSS wetlands, forested/scrub-shrub upland, PEM
wetlands, and coastal live oak hackberry forest, based on field surveys. These habitats would berestored post-construction to the extent allowed within temporary and permanent easements.
Construction of the pipeline system would permanently convert 1.7 acres of coastal live oakhackberry forest to maintained herbaceous right-of-way. In addition, 0.4 acres of ESS wetlands
would be permanently converted into aboveground facilities for the pipeline system.
Individuals of some wildlife species would be affected by construction and operation of
the facilities, but most impacts on wildlife would be short term and limited predominantly to theconstruction period. The forested and shrub scrub portions of the pipeline system would require
some maintenance and mowing. However, the majority of the pipeline system consists of open
water and herbaceous wetlands and would not likely require vegetation maintenance. With theimplementation of the Project-specific Plan and Procedures, and due to the fact that abundantsimilar habitat is available for wildlife adjacent to the affected areas, we conclude that construction
and operation of the pipeline system would have permanent but minor impacts on local wildlife
populations and habitat.
The vegetation communities within the LNG terminal and pipeline system facilities
provide potential habitat for migratory bird species, including songbirds, waterbirds, and raptors.
However, much of the vegetated land associated with the LNG terminal and pipeline systemfacilities is previously disturbed, within or adjacent to existing facilities, and/or composed ofagricultural land, all of which reduce bird nesting habitat value. Impacts on migratory birds andtheir habitat due to construction and operation of the Project would typically be similar to impacts
on general wildlife resources. In addition, potential impacts specific to migratory birds include
loss of habitat and injury or disorientation due to flaring and other artificial illumination.
Colonial nesting waterbirds that occur in the Project area include various herons, egrets,
ibises, terns, gulls, pelicans, and other species. A possible colonial-nesting waterbird area on an
island in Barataria Bay occurs within a 2-mile radius of the pipeline system. The island is located5-9between 600 and 1,800 feet from the proposed pipeline system. Based on the FWS guidance,
Venture Global would educate on-site personnel to be cognizant of colonial nesting waterbirds,
conduct pre-construction surveys, and restrict construction activities within 1,000 feet of any
identified rookeries. Based on adherence to the FWS restrictions and completion of
preconstruction surveys, impacts on colonial nesting waterbirds due to construction and operationof the Project would be minimal.
The LNG terminal and pipeline facilities would require adequate lighting for operations
and safety. During construction, Venture Global would direct all nighttime lighting towards
construction activity and use the minimum light level necessary to ensure site safety and security.
While the facility lighting plan for operation of the LNG terminal has not been fully developed,
Venture Global expects the plan to include downward-facing lights with shielding needed to meet
regulatory standards and minimize illumination specifications. Measures that may be included in
the final facility lighting plan include: (i) light minimization through limited outdoor lighting at
the terminal and pipeline meter stations; (ii) shielded and downward-facing lights to facilitate safe
operations at night or during inclement weather; (iii) the use of only white or red strobe lights atnight, using the fewest number of lights as practicable, and using the minimum intensity andnumber of flashes per minute allowable; (iv) avoidance of solid red or pulsating red warning lights
when possible; and (v) turning off perimeter lighting at aboveground facilities at night and using
them only when necessary for work conducted at night.
In accordance with the facility lighting plan, lighting would be chosen to minimize thehorizontal emission of light away from intended areas, and shielding would help minimize impacts
on birds and other wildlife while providing the illumination needed to ensure safe operation of the
facility.
5.1.6.2 Aquatic Resources
All waterbodies potentially affected by the Project support warm-water fisheries. Habitat
for aquatic resources present within the LNG terminal includes the Mississippi River and manmade drainages ditches/canals within the LNG terminal site. The aquatic resources potentiallyaffected by the pipeline system consist of drainage ditches, wetlands (PSS, PEM, ESS, and EEM)
and open water.
Activities associated with construction and operation of the LNG terminal with the greatest
potential to impact aquatic resources include pile driving and vessel traffic. No dredging is
proposed at the LNG terminal site. The proposed waterbody modifications, water withdrawals forhydrostatic testing, stormwater runoff, lighting, and inadvertent spills could also affect aquatic
resources; although the implementation of the proposed mitigation measures, would reduce these
impacts to minimal levels.
Construction of the LNG terminal marine facilities would result in localized, temporary
increases in turbidity and suspended sediment levels. However, these impacts are expected to be
temporary (i.e., confined primarily to the period of in-water activity and shortly thereafter) andlimited to the area within and immediately adjacent to the LNG loading and marine facilities. No
permanent or long-term water quality impacts are anticipated. Impacts on fisheries resources and5-10

supporting habitat as a result of construction and operation would occur in the Mississippi River
from construction of the marine facilities.
Construction of the LNG terminal would require the installation of approximately 600 piles
to support the proposed marine facility structures, MOF, and meter stations. It is anticipated thataquatic species would largely avoid the pile-driving area when the piles are being installed,
although some aquatic resources could experience stress or injury due to the underwater soundpressure levels. Venture Global submitted an underwater noise mitigation plan based on NMFS
2018 technical guidance identifying mitigation measures that would be taken to reduce noisepressure levels. This plan was submitted to and approved by the FWS and NMFS.
During construction and operation of the LNG terminal, barges, support vessels, and LNG
vessels would call on the LNG terminal, increasing ship traffic within the Mississippi River andGulf of Mexico. Potential impacts on aquatic resources resulting from increased vessel traffic
include shoreline erosion and resuspension of sediments, ballast water discharges, cooling water
discharges, and increased noise levels. The Mississippi River shoreline at the LNG terminal site
is currently armored to protect the shoreline from erosion, and the Mississippi River is currently aheavily utilized shipping channel. Therefore, associated impacts on aquatic resources due toincreased shoreline erosion and resuspension of sediments would be negligible.
Ballast water discharges at the terminal would modify the temperature, pH, dissolved
oxygen, and salinity of the water in the vicinity of the discharge. However, the impacts on water
quality, and thus aquatic resources, due to changes in temperature and pH would be temporary andnegligible. During and immediately following ballast water discharges, benthic aquatic species
may be affected by higher salinity levels, although ships moving into and out of the LNG terminal
marine facilities would displace water, circulating it into, around, and out of the berthing area.
Therefore, any increased salinity levels resulting from ballast water discharges would be temporary
and unlikely to adversely affect aquatic resources.
Dissolved oxygen levels below 4 mg/L are generally considered unhealthy for aquatic life,and levels below 2 mg/L are considered hypoxic and inadequate to support most aquatic life. As
discussed in section 4.3.2.2, ballast water would contain low dissolved oxygen levels and could
decrease existing dissolved oxygen levels within the immediate vicinity of the discharge point.
Depending on the oxygen levels present in both the ballast and ambient water at the time ofdischarge, aquatic resources present in the vicinity of the discharge point could be exposed todissolved oxygen levels considered unhealthy for aquatic life. The adaptability of resident species
in the Mississippi River to natural spatio-temporal variation in oxygen levels, and the ability tomove over a short distance to more suitable conditions, would minimizes the adverse impacts
associated with ballast water discharges. Given that the amount of ballast water discharged into
the river during each LNG vessel visit to the LNG terminal would make up only a very small
percentage of the water flowing downstream, we have determined that impacts on aquatic
resources from reduced dissolved oxygen would be temporary and minor.
During construction and operation, hazardous materials resulting from spills or leaks
entering the Mississippi River could have adverse impacts on aquatic resources. The impacts arecaused by either the physical nature of the material (e.g., physical contamination and smothering)or by its chemical components (e.g., toxic effects and bioaccumulation). These impacts would
5-11

depend on the depth and volume of the spill, as well as the properties of the material spilled. To
prevent spills and leaks, Venture Global would implement its Project-specific Spill Prevention
Plan during construction and its SPCC Plan during operation of the LNG terminal. These plansoutline potential sources of releases at the site, measures to prevent a release, and initial responses
in the event of a spill (see detailed discussion in section 4.2.3). Given the impact minimizationand mitigation measures described above, we conclude that the probability of a spill of hazardous
materials is small and any resulting impacts on aquatic resources would be temporary and minor.
Pipeline system construction impacts on fisheries resources and habitat would occur
primarily in estuarine wetlands and open water. Impacts would primarily be localized andtemporary, with disturbed areas returning to preconstruction conditions following pipeline
installation. The pipeline trench would be backfilled following construction, and the barge
channels would be allowed to backfill naturally through sedimentation. The push method or barge
lay method would be used for trenched pipeline installation across most waterbodies and wetlands.
Although these methods are designed to minimize equipment use and disturbance during pipeline
construction, the crossing methods could result in temporary loss or modification of aquatic
habitat, increases in sedimentation and turbidity levels, and alteration of vegetative cover. The
majority of fish present within the waterbody at the time of construction activities would likely bedisplaced to similar nearby habitats. However, stress, injury, or death of individual fish may occur.
Increased suspended sediment and turbidity levels may cause degradation of benthic and spawning
habitat and decreased dissolved oxygen levels within and downstream of the crossing location.
Temporary increases in suspended solids would decrease rapidly following the completion of inwater activities.
During construction of the two pipeline meter stations in Barataria Bay, 615 12-inchdiameter steel piles would be installed during construction. Installation could result in noise
impacts on fish similar to those discussed for the marine facilities in the Mississippi River. Venture
Global plans to install the piles associated with the meter stations either by the impact hammer orvibratory pile-driving method. Generally, vibratory pile driving takes much less time than impactdriven pile installation. For the LNG terminal, Venture Global has agreed to general pile-driving
mitigation measures such as buffers and soft starts to reduce noise impacts on aquatic species.
Dredging within barge access areas would cross private oyster leases. According to the
LDWF, lessees must be notified as part of the Coastal Use permitting process about projects
occurring in their oyster lease. In addition, a water bottom assessment must be conducted on thoseportions of leases located within 1,500 feet of the pipeline system. Further, in the event that
Venture Global cannot reach an agreement within an affected oyster lease holder, Venture Global
will seek a preliminary determination of damages through an arbitration process with the LDNR
– Oyster Lease Damage Evaluation Board. The final damage payment to be made to each leaseholder will be made following the construction activities and completion of a final biologicalsurvey subject to review by the board.
Both the LNG terminal marine facilities and significant portions of the pipeline system are
mapped as EFH. Correspondence between Venture Global and NMFS (NMFS, 2017) indicatethat the portion of the Mississippi River located in the Project area does not provide EFH sincemanaged fish species would not be common this far upriver (river mile 55). Therefore, the marine
facilities located in the Mississippi River at the terminal site would likely have no effect on EFH.
5-12

Construction of the pipeline system would impact EFH for post-larval and juvenile life
stages of white shrimp, brown shrimp, and lane snapper, all life stages of red drum, and adult graysnapper. Affected EFH includes benthic substrates and/or water column habitats in estuarine open
water (collectively referred to in this assessment as estuarine open water) and estuarine emergent
wetlands. Potential adverse impacts on EFH would primarily be temporary, while some permanent
impacts may be beneficial. Temporary adverse impacts during construction would be minimized
through adherence to the BMPs set forth in Venture Global’s Project-specific Procedures, SWPPP,
and SPCC Plan.
5.1.7

Threatened, Endangered, and Other Special Status Species

Based on our review of publicly available information, agency correspondence, and fieldsurveys, a total of 16 federally listed threatened or endangered species may occur in Plaquemines
Parish (see table 4.7.1). Also within Plaquemines Parish, there is designated critical habitat for
piping plover and loggerhead sea turtles. Review of the FWS Information for Planning andConservation System database and the FWS Louisiana Ecological Services list of endangered,threatened, candidate, and proposed for listing species by county identified 10 species aspotentially present in Plaquemines Parish, including the West Indian manatee, piping plover, redknot, Gulf and pallid sturgeon, and five species of sea turtles (FWS, 2018a). The NMFS Southeast
Region lists 12 federally listed species as potentially occurring in the Project area or along the
LNG vessel transit route in the Gulf of Mexico, including Gulf sturgeon, oceanic white-tip shark,
giant manta ray, four species of whales, and five species of sea turtles (NMFS, 2018). The FWS
and NMFS split jurisdiction for six species, including the Gulf sturgeon and the five sea turtles(see section 4.7.1). The FWS proposed the eastern black rail for listing as threatened under the
ESA in October 2018, and there is appropriate habitat for the eastern black rail within the projectarea.
For the 16 species listed under the ESA, we have determined that the Project may affectbut is not likely to adversely affect these species. For the eastern black rail, which the FWS
proposed for listing as threatened, we have determined that the Project may affect but is not likely
to jeopardize the continued existence of the eastern black rail. These determination of effects are
based upon our review of the species habitat requirements, the low likelihood of the species tooccur within the Project area, and Venture Global’s commitment to implement mitigation
measures in section 4.7. To ensure construction does not begin before FERC confirms compliancewith section 7 of the ESA, we recommend in section 4.7.1.4 that Venture Global not begin
construction of the Project until the staff completes formal consultation with the FWS/NMFS, if
required.
Based on information obtained from the LDWF, 15 state-listed threatened or endangered
species are known to occur within Plaquemines Parish (LDWF, 2018a). Twelve of the 15 state
listed species are also federally listed and are discussed above. The three species that are notfederally listed are the bald eagle, peregrine falcon, and the brown pelican (see table 4.7.1).
Suitable bald eagle habitat exists in the vicinity of the terminal site, but no known nests have been
identified. Because of the potential for bald eagles to be nesting in the Project area, Venture Global
has committed to conduct preconstruction surveys to identify active bald eagle nests within 660
feet of the Project area. If active bald eagle nests are found, Venture Global will follow appropriate
mitigation measures according to the National Bald Eagle Management Guidelines to minimize or
5-13

avoid impacts on individual bald eagles. Impacts on the peregrine falcon would be temporary andminor and primarily associated with seasonal disruption of foraging due to pipeline construction.
Colonial waterbirds, such as the brown pelican, could potentially nest in the vicinity of the Project.
Venture Global will implement measures to identify any nesting colonies prior to construction andwould implement measures to prevent impacts on nesting brown pelicans. Based on the above,
we have determined that the Project would not likely adversely impact state-listed species.
5.1.8

Land Use, Recreation, and Visual Resources

Construction of the LNG terminal and pipeline facilities would affect a total of 1,682.6
acres of land. Of this, 773.8 acres would be permanently affected by operation of the LNG terminaland pipeline facilities and 908.8 acres would be allowed to revert to the existing land use type after
the completion of construction.
Construction of the LNG terminal would affect a total of 728.7 acres of land and water
within the LNG terminal site, including the marine facility construction footprint and otherworkspaces adjacent to the terminal site. The USGS Land Use Land Cover data land use types
affected during construction of the LNG terminal, including the marine facility construction
footprint and other workspaces adjacent to the terminal site, would include cultivated crops,
forested, open water, wetland, developed industrial/commercial, herbaceous, and scrub-shrub.
Because the majority areas affected by construction and operation of the LNG terminal are masterplanned for “port/terminal complex” (Plaquemines Parish Master Plan, 2011), we have determinedthat impacts on land use would be negligible.
Venture Global currently leases the LNG terminal site. The property is owned by the Portof Plaquemines. A lease option agreement grants Venture Global the exclusive right to lease theterminal site for up to 70 years. Aside from the Port of Plaquemines property, no federally, state,
or local agency owned or managed lands would be affected by the liquefaction facility. Likewise,
the additional workspaces located adjacent to the LNG terminal site are also owned by the Port ofPlaquemines, and Venture Global currently has the option to lease those lands involving additional
workspaces. A USACE-maintained levee along the Mississippi River is controlled by the federal
government but is located within port-owned property. Aside from the Port of Plaquemines and
USACE, no federally, state, or local agency owned or managed lands would be directly affectedby the LNG terminal.
Construction of the pipeline facilities would affect about 953.9 acres of land and open
water. Because the activities involve new rights-of-way and easements, much of the land and open
water affected by the pipeline facilities would be greenfield. The pipeline facilities would beconstructed almost entirely within open water and wetlands, although small areas of herbaceousarea and developed land would also be affected. Impacts on land use associated with construction
and operation of the pipeline facilities would be temporary and minor, and all disturbed areas
would be allowed to revert to preconstruction conditions after construction is complete. Venture
Global would retain permanent easements over the header pipelines, which would be subject tovegetation maintenance and monitoring. The lands necessary for construction and operation of
the pipeline and its associated facilities would consist of land currently owned or leased by Venture
Global and other private land for which Venture Global would seek easement agreements with theowners.
5-14

No residential land is located within the footprint of the areas that would be affected byconstruction or operation of the LNG terminal and pipeline. The nearest occupied residences are
0.2 mile southwest of the terminal site. The nearest residence to any pipeline workspace is locatedapproximately 0.3 mile northwest along Lake Hermitage Road. No residential areas or
subdivisions are currently proposed within a 0.25-mile radius of the terminal site or pipeline
workspaces, according to the Plaquemines Parish Department of Permits, Zoning and Planning.
In addition, no commercial/industrial projects are planned or announced within a 1-mile radius of
the terminal site or pipeline workspaces.
One designated management area, Barataria-Terrebonne National Estuary Program, Gulf
Ecological Management Site, is located within 1 mile of the pipeline route and LNG terminal site.
Recreational boating and fishing activities occurring within the proposed open water areas of thepipeline route and within the Mississippi River could be affected by construction of the pipeline
and construction and operation of the LNG terminal due to increased noise, restrictions on vessel
traffic in the immediate vicinity of the LNG terminal, and pipeline construction. Increased noise
associated with construction of the pipeline would likely deter recreational users from fishing in
the immediate vicinity of pipeline construction. Fishing and recreational boating within theMississippi River near the terminal site is not popular; therefore, impacts would be minimal.
During operation of the LNG terminal, delays to recreational users could result due to the moving
security zone around LNG vessels during transit to and from the LNG terminal, which we expect
would be intermittent and minor.
Other public areas, conservation lands, or special interest areas near the terminal site and/or
pipeline routes include four local marinas between 0.1 and 1.8 miles from a Project workspace;
Delta NWR; Breton NWR; Pass A Loutre State Wildlife Refuge; Woodland Trail and Park, aprivately owned conservation land; and Jean Lafitte National Historic Park. Users of these areas
may experience an increase in vehicular traffic and minor interruptions in traffic flow, particularly
along SH 23 near the terminal site during construction. Vessel traffic to and from these areas may
also be prevented from using established channels during pipeline construction. Because impacts
on vessel traffic and vehicular traffic would be temporary, impacts are expected to be minor.
The LDWF regulates statewide fishing in addition to the harvest of crabs, crawfish, oysters,
shrimp, and certain reptiles and amphibians. The Project does not encroach any public oyster
areas. The closest public oyster area and active clutch planting is 5.3 miles southwest of theterminal site in Petit Bay Chene Fleur. Commercial fishing traffic is expected to experience minor,
temporary impacts during pipeline constriction. Venture Global was granted permission by the
LDWF to conduct instream work within the warmwater fisheries associated with the Project yearround. Only areas immediately near construction barges would be restricted for safety reasons,otherwise all waters would be accessible to recreational and commercial fishing.
As stated in section 4.8, “visual resources” refer to any object or feature that is visible ona landscape and that influences the visual appeal of an area for residents, local workers, or visitors.
Potential impacts on visual resources were considered for both the LNG terminal site and thepipeline system. The study area included a 2-mile buffer area from the Project (used primarily for
the LNG terminal site) and the footprint of the pipeline system and its immediate surroundings.
Present within the 2-mile buffer area are residences, commercial facilities, public recreational
facilities, the Mississippi River, and SH 23 (a National Scenic Byway). The study area generally
5-15

is characterized by industrial views, with other land uses as described herein. Beyond an
approximately 2.0-mile radius, the infrastructure associated with the Project would likely blend
into its surroundings, therefore, visual resources beyond the 2 miles are not considered.
The area surrounding the LNG terminal site currently includes industrial operations andassociated facilities; the LNG terminal site would be in the viewshed of local residents (particularly
from elevated points-of-view), drivers, and visitors travelling along SH 23 and other nearby
roadways. It also would be visible to recreational and commercial users of the Mississippi River.
Visual impacts associated with the LNG terminal site would be experienced temporarily
during construction due to the presence of heavy equipment/personnel, lighting, materials storage,
and infrastructure (e.g., the pipe bridge and temporary aerial conveyor system). Existing scrubshrub and tree cover may provide some cover for those nearby observers with potential views of
the LNG terminal site; a perimeter wall also may block some of the nearby views of the terminalsite. Construction would be anticipated to generate minor impacts due to the industrial nature of
the LNG terminal site and its surroundings, as well as the temporary nature of the construction
activities.
During operation, views of the LNG terminal may include exterior plant lighting, airnavigation lighting, LNG storage tanks, electric power generation facilities, liquefaction heatexchangers, air coolers, and the flare stack. Similar to the construction phase, the LNG terminal
would be visible to residents (particularly from elevated points of view), drivers, andrecreational/commercial users. While new facilities would be present, the impacts associated with
operation is expected to be minor, as the LNG terminal would be consistent with the masterplanned industrial nature of the site and its surroundings. To minimize potential lighting impacts,
the exterior plant lighting would primarily consist of full cutoff types, directed toward the ground,
and where possible, floodlight mast locations would be directed to avoid light emissions on land
and water.
The pipeline system generally would be in rural areas and areas previously disturbed byother utilities. During construction of the pipeline system, visual impacts would result from thepresence of personnel and their workday activities, large construction equipment, and vehicles.
Visual impacts associated with construction of the pipeline system would to include the removal
or alteration of existing vegetation and the exposure of bare soils, as well as earthwork and grading
scars associated with heavy equipment tracks, trenching, and machinery and tool storage. A pipe
bridge also would be built that would be visible to outside viewers. Existing vegetation may
provide some buffer to the construction, but noticeable changes would result from the changes
within the footprint and workspaces of the pipeline system.
During construction of the pipeline system, barges would be utilized in open water areas
associated with the barge access channels. A short-term change in visual resources would benoticeable to recreational and commercial boaters in proximity to the workspaces due to theactivity. Occupants of other vessels traveling on the barge access channels would be able to seelarge equipment, pipe joints, and materials being transported to the active construction sites.
Operational impacts associated with the pipeline system would be anticipated to occur inlocations surrounding the permanent aboveground facilities. Similar aboveground pipeline

5-16infrastructure is common in this area of Louisiana; therefore, the presence of these stations would
not detract from the overall industrial nature of the area.
As much of the pipeline system would be located in rural or industrial areas, the pipeline
system would be anticipated to cause minor impacts with regard to visual resources. Existing
vegetation would help to provide some visual buffers from the operation of the pipeline system.
In areas where vegetation would be removed or altered, pre-Project conditions would be restoredaccording to the Project-specific Plan and Procedures as practicable.
The proposed LNG terminal would be located within the Louisiana Coastal Zone, and a
CUP from the OCM would is required. Venture Global submitted its Joint Permit Application for
activities within the Louisiana Coastal Zone to the USACE and the OCM in March 2018. Venture
Global has not received its CUP and subsequent consistency determination from the OCM. We
recommend that Venture Global file its consistency determination with the Secretary prior to any
construction activities, if approved.
5.1.9

Socioeconomics

Venture Global expects that construction of the terminal site would occur in two 35-monthphases, with start dates spaced 12 months apart. Thus, construction on the LNG terminal would
be continuous for about 4 years. The pipeline system would also be constructed in two phases,
each less than a year in duration, overlapping with the LNG terminal construction. Each phase of
the LNG terminal’s construction would average 1,400 workers and rise to 2,200 workers for a 6month peak. However, the number of workers on-site would typically be higher during the 23
months of terminal construction phase overlap. During this 23-month period, the total number ofworkers at the terminal site could range from 1,500 to 3,600, and would average approximately
3,000 workers during the overlapping period. Half of the workforce is expected to be hired locally.
If the remaining workforce is hired from locations farther away, we estimate those workers andtheir households would number a maximum of 4,100 individuals that could relocate to the affected
area. This total is based on a 1-month hypothetical peak workforce, and only a portion of workers
was assumed to bring householders.
Project construction would generate local jobs, local spending on supplies and services,and other local economic benefits that accrue indirectly. Venture Global estimates 10 percent of
Project costs would be spent locally or regionally over the 4 years of construction, and the total
estimated Project cost is $8.5 billion. The Project’s local expenditures and stimulus effects during
construction would be at least a moderate benefit to local communities in Plaquemines, Jefferson,
and Orleans Parishes, lasting through the 4 years of construction and for a year or two after
construction ends. During operation, the economic and employment benefits would be permanent
as Venture Global would hire 250 workers and spend approximately $20 million annually onmaterials, land leases, and utilities (water, sewer, waste disposal) for the foreseeable future.
During construction, the Project’s tax contributions to the local and state economies would
be minor, short-term benefits, consisting of approximately $7 million annually in local taxes and$26 million annually in state taxes over the 4 years of construction. During operation, tax
contributions in the form of sales, payroll, and property taxes would provide minor benefits at thestate and local level, though the level of tax benefit in Plaquemines Parish could increase. The

5-17

LNG terminal may be granted a Louisiana Industrial Tax Exemption Program waiver on ad
valorem taxes for up to 10 years, after which ad valorem taxes to Plaquemines Parish would be atleast a moderate benefit to the local economy. The pipeline system would generate ad valorem
taxes starting in year one of operation.
The LNG terminal would have a negligible impact on commercial and recreational fishing.
The pipeline system, which crosses private oyster lease areas in Barataria Basin, would impact
leaseholders of the traversed and adjacent oyster grounds. In addition, pipeline systemconstruction vessel traffic could be noticeable to some recreational anglers, and the right-of-way
would be off-limits to fishing during construction. The LDWF and LDNR require water bottom
assessments of oyster lease areas within prescribed distances of installation activities. Venture
Global would conduct the assessments, as mandated, and prepare financial impact evaluations on
individual oyster leases and work with leaseholders and the state to determine compensation forleaseholders. To ensure successful and timely completion of these consultations, in section 4.9.3
we recommend that Gator Express Pipeline file the results of its consultations with any affected
oyster leaseholders and the LDNR Oyster Lease Damage Evaluation Board, prior to construction.
The vessel traffic impacts would be limited to the brief period of construction (12 months), andthe right-of-way fishing restrictions during construction would affect a proportionately small areaof Barataria Basin. Thus, we conclude that the pipeline system’s effect on fishing would be
temporary and minor.
Given the available housing and accommodations in the Greater New Orleans metropolitan
area near the Project, the Project workforce’s impact on housing in the affected area would beminor, though impacts on individual proprietors or tenants could be substantial. The terminal andpipe bridge could have a long-term, minor effect at the community level on property values, while
the pipeline system’s effect on property values would be negligible. Individual properties in theDeer Range neighborhood could experience property value change, but these changes would be
similar to a change accompanying any “port terminal complex” and “major industries” that could
be constructed according to the Parish’s Master Plan.
Workers and their householders who relocate to the affected area during construction andoperation would have minor impacts on schools, hospitals, and public safety departments. Venture
Global would provide firefighting equipment on-site in case of an accident and would train
firefighters at the nearby Myrtle Grove and/or Lake Hermitage Volunteer Fire Stations to serve as
backup responders. Venture Global would also employ 24-hour security services. Thus, theProject’s impact on public safety services is expected to be minor, barring a catastrophic incident.
The Project’s effect on roadway transportation would be mitigated to less than significant
during construction. Venture Global intends to implement several mitigation measures that would
reduce heavy traffic congestion and traffic queues on SH 23 north and south of the LNG terminal
during the workforce’s commute hours. Example measures include constructing auxiliary turning
lanes along SH 23 and limiting the number of parking permits in designated parking areas tomaintain carpooling of at least two people per vehicle. During construction of the pipeline system,
signs and flagmen would be appropriately positioned to alert drivers of any construction activities
that would affect local roads. After construction is complete, Venture Global would restore orreconstruct any damaged roadways. During operation, roadway impacts would be negligible. In

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addition, as required by the DOT regulations for LNG operators, Venture Global would develop
emergency response plans in coordination with appropriate local officials.
Supply delivery barges associated with LNG terminal construction would have a negligible
impact on vessel traffic in the Mississippi River and connected bayous. Pipe delivery barges, onsite construction support barges, and crew boats could have a minor effect on vessel traffic in
Barataria Basin during the brief periods of pipeline construction. During operation, LNG carrier
calls on the terminal could reach six to seven calls per week. Given the width of the Mississippi
River and the consistency of the LNG carrier traffic with other large vessel traffic, the Project’s
LNG carrier calls during operation would be a minor impact.
During normal operations, the Project would not have high and adverse human health orenvironmental effects and would not disproportionately impact potential environmental justicepopulations in proximity. If a rare, catastrophic event at the LNG terminal temporarily closed SH
23, communities in the southern west would be affected, some of which have high minority or
low-income population percentages. Venture Global held open houses in Plaquemines andJefferson Parishes to circulate information about the proposed Project and has been has beenworking with local, state, and federal agencies to develop its emergency response plan. Venture
Global anticipates the levee system would be available to residents in the southern west bank if
SH 23 ever became temporarily closed.
5.1.10 Cultural Resources
As construction of the Project could directly affect cultural resources through ground
disturbance associated with the construction, operation, and maintenance of the facility andpipelines, as well as indirectly by the presence of the personnel and associated activities (visual,auditory, or other secondary impacts), cultural resources surveys have been conducted, andconsultation with the SHPO and tribes has occurred. The surveys and consultations wereconducted to meet FERC’s obligations for Section 106 of the NHPA.
The conclusions and recommendations resulting from SHPO review have been
incorporated into this EIS. Consultation with the SHPO for the LNG terminal and pipeline system
is complete.
5.1.11 Air Quality and Noise
5.1.11.1 Air Quality
Construction activities at the LNG terminal and pipeline system would generate criteria air
pollutants, hazardous air pollutants, and greenhouse gas emissions during Phase I and Phase II of
construction. Active construction would occur over a 70-month period. Construction activity
would produce emissions from use of off-road equipment and vehicles; on-road vehicles, including
delivery trucks and worker commuting; marine vessels delivering construction materials; supplies
and equipment; and fugitive dust produced from vehicles and equipment operating at the site andfrom the handling of soils, fill material, soil stabilization components and concrete production.
The duration of construction (4-plus years) and the quantity of pollutants emitted during each yearof construction may have an impact on air quality.

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As construction proceeds and components of the LNG terminal become ready for
operation, Venture Global plans to enter into an Interim Operating mode. This mode would
continue from year 2 of construction until the completion of Phase II construction. In this mode,the power-generating facility would operate in simple-cycle mode, with LNG liquefaction
beginning as the LNG trains become operational. At the same time, construction on the remainderof the LNG terminal and pipeline would continue. During the Interim Operating mode, total
emissions (construction plus interim operation) would be higher than during construction oroperation alone. We have summarized emissions in the air quality discussion for the overlapping
Interim Operating mode and continued construction.
At the completion of the Interim Operating mode, construction activities would cease andthe facility would enter the final operating mode. Emissions would be produced from equipment
at the power-generating facility and at the LNG terminal, and from marine vessels associated withtransport of LNG from the LNG terminal. Emission controls at the LNG terminal would be fully
operational during the final operating mode. Pipeline operation would generate only a minor
amount of fugitive emissions; there is no compression associated with pipeline operation thatwould generate combustion emissions. An operational emission inventory was developed toprovide an estimate of annual emissions during full LNG terminal operation.
The operational emission inventory for the final operating mode included the effects ofcertain mitigation measures used to reduce emissions. Mitigation is based on the applicantprepared BACT analysis that was prepared as part of its air permit application to the LDEQ.
Emissions of NOX from the combined-cycle gas turbines, supplemental duct burners, andaeroderivative turbines at the power-generating facility would be reduced by using low NOX
combustion and SCR. Other mitigation measures proposed by Venture Global include (i) the useof catalytic oxidation on the exhaust of the combined gas turbine/duct burners to reduce CO and
VOCs, (ii) use of natural gas as fuel, (iii) use of ultra-low sulfur diesel fuel in backup diesel engine
electric generators and firewater pump engines, (iv) good combustion practices, (v) proper
equipment design, and (vi) adherence to manufacturers’ operating and maintenance procedures.
Modeling analyses were performed for emissions from two operating scenarios of the
Project. Modeling analyses conducted for the Project and reviewed include the following:•

criteria pollutant dispersion modeling for emissions from the LNG terminal alone andin combination with marine vessels;•

cumulative dispersion modeling analysis for the LNG terminal (without marine
vessels) as part of the air permit application to the LDEQ;•

a dispersion modeling analysis for Louisiana Toxic Air Pollutants, specificallyammonia (The use of SCR to control NOX emissions results in the emission ofammonia, a Louisiana toxic air pollutant.);•

a Class I modeling analysis (without marine vessels) to evaluate Project stationary
source effects at the Breton NWR Class I area; and

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•

an ambient ozone analysis using regional-scale photochemical grid modeling (without
marine vessels).

The modeling studies were conducted according to modeling protocols reviewed by the
LDEQ and other agencies. The modeling protocols were based on EPA and Louisiana modelingguidelines and requirements. The modeling demonstrated that the Project would comply withNAAQS, PSD increments, Louisiana toxic air pollutant limits for ammonia, and applicable ClassI Area thresholds for the Project’s stationary sources. The additional modeling conducted for the
LNG terminal in combination with marine vessels also demonstrated compliance with the
NAAQS.
Based on the analyses conducted for the final operating mode of the Project and mitigation
measures proposed in the BACT analysis, operation of the Project would result in quantifiable
impacts but would be in compliance with applicable standards.
During the construction period, residents in the vicinity of the Project would experience
local impacts to air quality. Concurrent emissions from staged construction, commissioning andstart-up, and operation of the LNG terminal would temporarily impact local air quality, and could
result in exceedances of the NAAQS in the immediate vicinity of the LNG terminal during these
construction years. These exceedances would not be persistent at any one time during these years
due to the dynamic and fluctuating nature of construction activities within a day, week, ormonth. During operation, extensive modeling has indicted that the Project would not havesignificant impacts on the local and regional air quality and Class I areas.
5.1.11.2 Noise
Construction activities at the LNG terminal would generate temporary increases in soundlevels over the duration of both phases of construction. Construction activities would occur
predominantly during the day, Monday through Saturday. Certain activities that produce higher
levels of noise would have more condensed working timeframes. In particular, dredging would
occur for only 1 month and be limited to daytime hours, and land-based pile driving would occur
no later than 5 p.m. HDD may occur 24 hours per day but would be shrouded by sound curtains
or an acoustic barrier to mitigate stray noise.
The most prevalent sound-generating equipment and activity during construction of the
LNG terminal is anticipated to be pile driving. Venture Global anticipates that impact-type piledrivers would be used during construction of the terminal facilities and auger type pile installation
would be used to construct pipe bridges over levees. Onshore piles would be driven by up to 12
hydraulic piling rigs at a time. The use of one auger rig is anticipated during pipe bridge
construction. Based on the construction schedule provided by Venture Global, land-based piledriving to create the foundations for the LNG storage tanks and other process equipment
foundations and structures would occur over a period of 12 months, and pile driving associatedwith construction of the LNG loading and ship berthing area would occur over a period of 6months.
Land-based pile driving is scheduled to occur in 10-hour shifts, 6 days per week, over a
total of about 12 months. During land-based pile-driving operations, the estimated sound level at

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the nearest NSA when the maximum number of land-based pile-driving platforms are in use wouldbe 65.4 dBA Lmax. These levels would correspond to a moderate sound level and would be clearly
audible. Based on the estimates provided by Venture Global, and because of the 12-month
duration of the pile-driving activities, these sound levels may have a moderate adverse impact at
the nearest NSAs. Venture Global proposes to implement mitigation measures to reduce landbased and marine-side pile-driving noise impacts on NSAs. Venture Global would construct 5meter-high noise protection walls around piling rigs for noise reduction mitigation. As modeled,these noise barriers would reduce the increase in ambient noise levels at the two nearest NSAsfrom 11.8 dBA and 16.0 dBA (without mitigation) to 0.4 dBA and 2.2 dBA, respectively.
The most prevalent sound-generating equipment and activity during construction of thepipeline system is anticipated to be the HDD near Lake Hermitage Road. Venture Global estimatesthat an increase of 13.3 dBA Lmax would be experienced at NSA 2; no other NSAs are expected tobe affected. To minimize impacts on NSAs from HDD operations, Venture Global assures toimplement a sound curtain enclosure to mitigate impacts. Sound curtain enclosures would be usedaround the drilling rig and other stationary equipment during the HDD process. Sound curtain
enclosures have been shown to provide 10 to 14 dBA of mitigation. Sound enclosures or acoustic
barriers could also be used during dredging activities if nearby structures are occupied during
dredging of barge access channels.
Dredging activities associated with barge access channels would increase noise levels
above 10 dBA Lmax at a structure approximately 265 feet away from a dredging area. Venture
Global has committed to take measures to reduce noise levels to no greater than 10 dBA over Leq
ambient levels at this structure and other structures nearby.
LNG terminal operation is not expected to produce noise levels greater than 10 dBA over
Leq ambient levels at any NSA. Periodic operational blowdown events would be the greatest causeof stray noise emanating from the LNG terminal. The sound level produced by this vent will beapproximately 50 dBA at NSA 2. Venture Global also plans to implement various mitigation
measures to further reduce general operation noise not associated with blowdown events. With
the implementation of the noise reducing mitigation efforts presented in section 4.11.2.4, we havedetermined that the terminal would be in compliance with our new facility noise level threshold of
Ldn 55.0 dBA at all defined NSAs.
The only noise-producing facilities that would be associated with the pipeline system are
the new metering stations. These facilities are not anticipated to affect ambient noise levels in theimmediate vicinity or at an NSA.
Based on the analyses conducted, mitigation measures and noise barriers proposed, andwith our additional recommendations, we conclude that construction of the Project would result in
temporary and minor noise impacts on residents and the surrounding communities and that
operation of the Project would result in permanent and minor impacts on the surrounding residents.

5-225.1.12 Reliability and Safety
As part of the NEPA review, Commission staff assesses the potential impact to the humanenvironment in terms of safety and assess whether the proposed facilities would be able to operatesafely, reliably, and securely.
As a cooperating agency, DOT assists FERC staff in evaluating whether Venture Global’s
proposed design would meet DOT’s 49 CFR 193, Subpart B siting requirements. On April 3,
2019, the DOT issued an LOD to FERC regarding the proposed Project’s compliance with the 49
CFR 193, Subpart B regulatory requirements. The LOD provides PHMSA’s analysis andconclusions regarding 49 CFR 193, Subpart B regulatory requirements, including the resolution oflegal control of exclusion zones, for the Commission’s consideration in its decision on the Projectapplication. If the Project is authorized, constructed, and operated, the facility would be subject
to the DOT’s inspection and enforcement program and final determination of whether a facility isin compliance with the requirements of 49 CFR 193 would be made by the DOT staff.
As a cooperating agency, the Coast Guard also assisted the FERC staff by reviewing the
proposed LNG terminal and the associated LNG carrier traffic. The USCG reviewed a WSA
submitted by Plaquemines LNG that focused on the navigation safety and maritime security
aspects of LNG carrier transits along the affected waterway. On January 23, 2017, the Coast Guard
issued a LOR to FERC staff indicating the Lower Mississippi River would be considered suitable
for accommodating the type and frequency of LNG marine traffic associated with this Project,based on the WSA and in accordance with the guidance in the USCG’s NVIC 01-11. If the Projectis authorized and constructed, the facility would be subject to the Coast Guard’s inspection andenforcement program to ensure compliance with the requirements of 33 CFR 105 and 33 CFR 127.
We conducted a preliminary engineering and technical review of the Venture Global
design, including potential external impacts based on the site location. Based on this review, we
recommend the Commission Order include a number of mitigation measures prior to initial site
preparation, prior to construction of final design, prior to commissioning, prior to introduction of
hazardous fluids, prior to commencement of service, and throughout life of the facility to enhance
the reliability and safety of the facility. With the incorporation of these mitigation measures, we
believe that the Venture Global Project design would include acceptable layers of protection or
safeguards that would reduce the risk of a potentially hazardous scenario from developing into an
event that could impact the offsite public.
5.1.13 Cumulative Impacts
During the cumulative impact analysis, we identified 16 actions, including the Project, thatwarranted careful consideration based on geographic and temporal criteria we established for eachenvironmental resource. Consistent with CEQ (2005) guidelines, the effects of past actions were
aggregated into our assessments of affected environments in section 4.0. Thus, we focused thecumulative analysis on effects of the Project in combination with current and future actions. Seven
major industrial developments, including the Project, planned on the banks of the Mississippi Riverin Plaquemines Parish presented the highest potential for creating cumulative adverse effects alongwith the LNG terminal and pipeline system. These industrial developments, all within 21 miles ofeach other, include two methanol manufacturing facilities; three LNG manufacturing facilities and5-23

export terminals, including the Project; an oil blending, storage, and distribution facility; and acontainer shipping terminal. The remaining actions consist of two minor non-jurisdictional utilitylines associated with the LNG terminal, two drainage and shoreline protection projects, four
wetland mitigation and restoration projects, a dredging project to deepen part of the Mississippi
River ship channel, and a very recently completed transportation improvement on a portion of SH
23.
Because the Project would not affect or have negligible impacts on groundwater, recreationand cultural resources, it would not contribute to adverse cumulative effects on those resources.
Geology and soil resources affected by the Project would not experience cumulative effects
because no other identified actions are within the cumulative geographic scope for those resources.
Based on our evaluations, surface waters and aquatic wildlife and habitat; wetlands; uplandvegetation and wildlife; housing and public services (socioeconomic resources); vessel traffic;
noise; and safety and reliability would experience negligible or minor adverse cumulative impacts.
The cumulative land use effects would be noticeable, but the majority of the affected acreage
would be consistent with the parish’s Comprehensive Master Plan. The cumulative visual effects
from development along the designated scenic byway SH 23 would be moderate given themagnitude of change and intermittent exposure level of residents. If all proposed actions weredeveloped, the associated increase in piloted vessel traffic would be noticeable, but the presenceof USCG Vessel Traffic Services–Lower Mississippi River and the capacity of the Mississippi
River to accommodate vessel traffic would mitigate the additional transits’ effect on traffic flow.
The cumulative noise effects near certain residences in the Deer Range neighborhood could be
adverse for a few days or weeks if Venture Global’s pile-driving and/or HDD construction
activities overlap with USACE upgrades of the adjacent levee. However, Venture Global has
stated that it would coordinate with the USACE to ensure overlapping activities would not occur.
We identified only air quality as having the potential to sustain significant adverse
cumulative impacts. More information could illuminate whether cumulative effects on thisresource would likely be significant or less than significant.
GHGs were identified by the EPA as pollutants in the context of climate change. GHG
emissions do not directly cause local ambient air quality impacts. GHG emissions result in
fundamentally global impacts that feed back to localized climate change impacts. Thus, thegeographic scope for cumulative analysis of GHG emissions is global rather than local or regional.
For example, a project 1 mile away emitting 1 ton of GHGs would contribute to climate change ina similar manner as a project 2,000 miles distant also emitting 1 ton of GHGs. Currently, there isno universally accepted methodology to attribute discrete, quantifiable, physical effects on theenvironment to the Project’s incremental contribution to GHGs. Absent such a method for relating
GHG emissions to specific resource impacts, we are not able to assess potential GHG-related
cumulative impacts attributable to this project. Additionally, we have not been able to find any
GHG emission reduction goals established either at the federal level 1 or by the State of Louisiana. 2
1
2

The national emissions reduction targets expressed in the EPA’s Clean Power Plan and the Paris climate
accord are pending repeal and withdrawal, respectively.
We reviewed the U.S. State Greenhouse Emission Targets site for individual state requirements located at:https://www.c2es.org/document/greenhouse-gas-emissions-targets/

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Without either the ability to determine discrete resource impacts or an established target tocompare GHG emissions against, we are unable to determine the significance of the Project’s
contribution to climate change.
Air Quality: The Clean Air Act and implementing regulations establish limits on pollutant
emissions from major industrial developments, among others. Venture Global has prepared amodeling study of the LNG terminal’s future effects on air quality that includes baseline emissions
from existing and permitted activities within the vicinity. Venture Global included the future
effects of the permitted Braithwaite Methanol Manufacturing Plant and NOLA Oil Terminal anddemonstrated that their combined emissions would not exceed the NAAQS. Gulf Coast Methanol
Park was recently issued an air permit in January 2018, and Venture Global updated its cumulativemodeling to include Gulf Coast Methanol Park. Although cumulative modeling showed thepotential for NAAQS exceedances, the modeling indicates that the Project would not contributeabove significant levels and therefore would not contribute to a significant adverse combined effectof the Project with other existing and foreseeable actions.
The recently announced Pointe LNG project would trigger major source regulations and sowould be required to conduct a cumulative air modeling study that captures estimated emissions
from existing and permitted projects and projects in the advanced stages of permitting, including
the LNG terminal. Pointe LNG must demonstrate that the combined emissions fall below NAAQS
thresholds to obtain an air permit, ensuring the cumulative air quality effect from the LNG
terminal, Pointe LNG, and the other actions would not exceed health and safety standards forregulated pollutants.
Emissions from vessels, vehicles, and other mobile sources associated with operation of
the foreseeable industrial facilities along the Mississippi River could contribute to an adverse effecton air quality. Vessel emissions are not addressed in LDEQ regulations and air permit application
requirements, but the International Maritime Organization, of which the U.S. is a member,promulgates emissions standards limiting SOX and NOX. Also, the EPA adopted emission
standards on engines installed on U.S. vessels. Thus, the resulting cumulative effect of vessel
emissions on air quality in the geographic scope of the Project is not likely to be significant.
5.1.14 Alternatives
As alternatives to the proposed action, we evaluated the No-Action Alternative, system
alternatives for the proposed LNG terminal and pipeline system, alternative LNG terminal
configurations, alternatives sites for the proposed LNG terminal, alternative routes for the
pipelines, and alternative locations for the aboveground facilities associated with the pipeline
system. While the No-Action Alternative would eliminate the short and long-term environmental
impacts identified in the EIS, the stated objectives of the proposed action would not be met.
We evaluated system alternatives for the LNG terminal, including operating LNG
import/export terminals with approved, proposed, or planned expansions to provide liquefactionand export capabilities, and stand-alone (greenfield) liquefaction terminals with approved,
proposed, or planned liquefaction projects along the Gulf Coast in the southern United States. Allof these were eliminated from further consideration as viable alternatives for reasons that include
incompatible timeframes with in-service dates, capacity demands that would not meet Venture

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Global’s customer commitments, and environmental impacts that were considered comparable toor greater than those of the proposed LNG terminal.
We evaluated three system alternatives to the proposed pipeline system and two majorroute alternatives along the preferred route. To serve as a viable system alternative to the preferredpipeline system, the pipeline would have to transport all or a part of the volume of natural gas
required for liquefaction at the proposed terminal and cause less impact on the environment thanthe preferred pipeline system route. All three systems accomplished the goal of supply. However,
two were eliminated because they did not provide an environmental advantage over the preferredroute. The two route alternatives were evaluated but also eliminated because they did not provide
an environmental advantage over the preferred alignment of the Southwest laterals.
We evaluated five sites for the LNG terminal, including the proposed site and four
alternatives. In order to meet the stated objectives of the Project, we applied screening criteria to
identify sites that would be reasonable and most likely to provide some environmental advantage
over the proposed LNG terminal site. The screening criteria included deep berth waterfront access,property size, land use compatibility with an LNG terminal, site availability, proximity to natural
gas pipelines and transmission lines, distance from population centers and residences, distance tothe interstate highway system, local and state government support, and presence of wetlands within
the site. The alternatives analysis concluded that the proposed site represents an acceptable site
for the proposed LNG terminal because it is currently zoned for heavy industrial use, is sufficiently
sized to allow optimal facility layout design, and would not require dredging to create berths. The
proposed site also contains the lowest acreage of wetlands of the alternatives considered.
Therefore, the loss of habitat diversity and function resulting from facility development would be
generally less than that anticipated at the other sites. Additionally, from a visual impact
perspective, the new LNG terminal would be consistent with the existing industrial development
along the Lower Mississippi River at this location.
The proposed aboveground facilities would occur within or adjacent to the Southwest
lateral pipeline route right-of-way, which would minimize the footprint and associatedenvironmental impacts. The new aboveground facilities are not located near residences, and theirfootprint would overlap with pipeline workspaces that would be disturbed by construction. We
did not identify any environmental concerns that require the need to identify and evaluate
alternative aboveground facility sites.
We evaluated the arrangement of plant infrastructure to ensure compliance with federal
siting and safety requirements. Aligning the major infrastructure components in sequenceaccording to process flow minimizes the amount of cryogenic piping required and optimizes thesite layout for process efficiency. The proposed site layout provides the adequate minimum
practical distance between the LNG loading docks and the LNG storage tanks, and theadministrative offices, maintenance facilities, and the central control room are well separated fromthe main plant. The proposed location of each of the components of the LNG terminal is inaccordance with the applicable federal safety requirements. We did not identify any alternative
configurations that would meet the regulations, codes, and guidelines while avoiding or reducing
impacts when compared to those of the proposed LNG terminal configuration.

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Therefore, we conclude that the proposed action, as modified by our recommended
mitigation measures, is the preferred alternative to meet the Project objectives.
5.2

FERC STAFF’S RECOMMENDED MITIGATION

If the Commission authorizes the Project, we are recommending that the following
measures be included as specific conditions in the Commission’s Order. We believe that thesemeasures would further mitigate the environmental impacts associated with the construction andoperation of the Project. Unless otherwise noted within the condition, a recommendation madefor Venture Global applies to both the LNG terminal and pipeline system.
1.

Venture Global shall follow the construction procedures and mitigation measuresdescribed in its applications and supplements (including responses to staff data
requests) and as identified in the EIS, unless modified by the Order. Venture Global
must:
a. request any modification to these procedures, measures, or conditions in a filingwith the Secretary;b. justify each modification relative to site-specific conditions;c. explain how that modification provides an equal or greater level of environmental
protection than the original measure; andd. receive approval in writing from the Director of OEP before using thatmodification.

2.

For the LNG terminal, the Director of OEP, or the Director’s designee, has delegatedauthority to address any requests for approvals or authorizations necessary to carryout the conditions of the Order, and take whatever steps are necessary to ensure theprotection of life, health, property, and the environment during construction andoperation of the Project. This authority shall allow:
a. the modification of conditions of the Order;
b. stop-work authority and authority to cease operation; andc. the imposition of any additional measures deemed necessary to ensure continued
compliance with the intent of the conditions of the Order as well as the avoidanceor mitigation of unforeseen adverse environmental impact resulting from Project
construction and operation.

3.

For the pipeline facilities, the Director of OEP, or the Director’s designee, hasdelegated authority to address any requests for approvals or authorizations necessary
to carry out the conditions of the Order, and take whatever steps are necessary toensure the protection of environmental resources during construction and operationof the Project. This authority shall allow:

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a. the modification of conditions of the Order;
b. stop-work authority; andc. the imposition of any additional measures deemed necessary to ensure continued
compliance with the intent of the conditions of the Order as well as the avoidanceor mitigation of unforeseen adverse environmental impact resulting from Project
construction and operation.
4.

Prior to any construction, Venture Global shall file an affirmative statement with
the Secretary, certified by a senior company official, that all company personnel, EIs,
and contractor personnel will be informed of the EI’s authority and have been or willbe trained on the implementation of the environmental mitigation measuresappropriate to their jobs before becoming involved with construction and restoration
activities.

5.

The authorized facility locations shall be as shown in the EIS, as supplemented by
filed alignment sheets. As soon as they are available, and before the start ofconstruction, Venture Global shall file with the Secretary any revised detailed surveyalignment maps/sheets at a scale not smaller than 1:6,000 with station positions for
all facilities approved by the Order. All requests for modifications of environmental
conditions of the Order or site-specific clearances must be written and must reference
locations designated on these alignment maps/sheets.
For the pipeline, Gator Express Pipeline’s exercise of eminent domain authority
granted under NGA section 7(h) in any condemnation proceedings related to theOrder must be consistent with these authorized facilities and locations. Gator Express
Pipeline’s right of eminent domain granted under NGA section 7(h) does not
authorize it to increase the size of its natural gas pipeline to accommodate futureneeds or to acquire a right-of-way for a pipeline to transport a commodity other thannatural gas.

6.

Venture Global shall file with the Secretary detailed alignment maps/sheets and aerial
photographs at a scale not smaller than 1:6,000 identifying all route realignments or
facility relocations, and staging areas, pipe storage yards, new access roads, and otherareas that would be used or disturbed and have not been previously identified infilings with the Secretary. Approval for each of these areas must be explicitly
requested in writing. For each area, the request must include a description of theexisting land use/cover type, documentation of landowner approval, whether any
cultural resources or federally listed threatened or endangered species would be
affected, and whether any other environmentally sensitive areas are within or abutting
the area. All areas shall be clearly identified on the maps/sheets/aerial photographs.
Each area must be approved in writing by the Director of OEP before constructionin or near that area.

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This requirement does not apply to extra workspace allowed by the Commission’sPlan and/or minor field realignments per landowner needs and requirements which
do not affect other landowners or sensitive environmental areas such as wetlands.
Examples of alterations requiring approval include all route realignments and facility
location changes resulting from:a. implementation of cultural resources mitigation measures;
b. implementation of endangered, threatened, or special concern species mitigation
measures;c. recommendations by state regulatory authorities; andd. agreements with individual landowners that affect other landowners or could
affect sensitive environmental areas.
7.

Within 60 days of the Order and before construction begins, Venture Global shallfile an Implementation Plan with the Secretary for review and written approval by
the Director of OEP. Venture Global must file revisions to the plan as schedules
change. The plan(s) shall identify:
a. how Venture Global will implement the construction procedures and mitigation
measures described in its application and supplements (including responses tostaff data requests), identified in the EIS, and required by the Order;
b. how Venture Global will incorporate these requirements into the contract bid
documents, construction contracts (especially penalty clauses and specifications),
and construction drawings so that the mitigation required at each site is clear toon-site construction and inspection personnel;c. the number of EIs assigned per spread, and how Venture Global will ensure thatsufficient personnel are available to implement the environmental mitigation;
d. company personnel, including EIs and contractors, who will receive copies of theappropriate material;e. the location and dates of the environmental compliance training and instructions
Venture Global will give to all personnel involved with construction andrestoration initial and refresher training as the Project progresses and personnel
change, with the opportunity for OEP staff to participate in the training session(s);f. the company personnel and specific portion of Venture Global’s organization
having responsibility for compliance;
g. the procedures (including use of contract penalties) Venture Global will follow ifnoncompliance occurs; and5-29

h. for each discrete facility, a Gantt or PERT chart (or similar Project schedulingdiagram), and dates for:1) the completion of all required surveys and reports;
2) the environmental compliance training of on-site personnel;
3) the start of construction; and4) the start and completion of restoration.
8.

Venture Global shall employ at least one EI for the terminal and one EI per pipeline
construction spread, or as may be required by the Director of OEP. The EIs shall be:a. responsible for monitoring and ensuring compliance with all mitigation measuresrequired by the Order and other grants, permits, certificates, or other authorizing
documents;
b. responsible for evaluating the construction contractor's implementation of theenvironmental mitigation measures required in the contract (see condition 6
above) and any other authorizing document;c. empowered to order correction of acts that violate the environmental conditionsof the Order, and any other authorizing document;
d. a full-time position, separate from all other activity inspectors;
e. responsible for documenting compliance with the environmental conditions of
the Order, as well as any environmental conditions/permit requirements imposedby other federal, state, or local agencies; andf. responsible for maintaining status reports.

9.

Beginning with the filing of its Implementation Plan, Venture Global shall file
updated status reports with the Secretary, on a monthly basis for the terminal and on
a biweekly basis for the pipeline system, until all construction and restoration
activities are complete. On request, these status reports will also be provided to otherfederal and state agencies with permitting responsibilities. Status reports shall
include:a. an update on Venture Global’s efforts to obtain the necessary federal
authorizations;b. the construction status of the LNG terminal and each pipeline spread, work
planned for the following reporting period, and any schedule changes for stream
crossings or work in other environmentally-sensitive areas;

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c. a listing of all problems encountered, contractor nonconformance/deficiency
logs, and each instance of noncompliance observed by the EIs during thereporting period (both for the conditions imposed by the Commission and any
environmental conditions/permit requirements imposed by other federal, state, or
local agencies);
d. a description of the corrective actions implemented in response to all instances ofnoncompliance;e. the effectiveness of all corrective actions implemented;
f. a description of any landowner/resident complaints which may relate tocompliance with the requirements of the Order, and the measures taken to satisfy
their concerns; andg. copies of any correspondence received by Venture Global from other federal,state, or local permitting agencies concerning instances of noncompliance, andVenture Global’s response.
10.

Venture Global must receive written authorization from the Director of OEP before
commencing construction of any Project facilities. To obtain such authorization,
Venture Global must file with the Secretary documentation that it has received allapplicable authorizations required under federal law (or evidence of waiver thereof).

11.

Plaquemines LNG must receive written authorization from the Director of OEP prior
to introducing hazardous fluids into the terminal facilities. Instrumentation andcontrols, hazard detection, hazard control, and security components/systems
necessary for the safe introduction of such fluids shall be installed and functional.

12.

Plaquemines LNG must receive written authorization from the Director of OEP
before placing each phase of the LNG terminal into service. Such authorization
will only be granted following a determination that the facilities have been
constructed in accordance with FERC approval, can be expected to operate safely as
designed, and the rehabilitation and restoration of the right-of-way and other areas
affected by the Project are proceeding satisfactorily.

13.

Gator Express Pipeline must receive written authorization from the Director of OEP,
before placing each phase of the pipeline system into service (i.e., the Southwest
Lateral TGP in Phase 1 and the Southwest Lateral TETCO in Phase II). Suchauthorization will only be granted following a determination that rehabilitation andrestoration of the right-of-way and other areas affected by the Project are proceedingsatisfactorily.

14.

Within 30 days of placing each of the authorized facilities in service, Venture
Global shall file an affirmative statement with the Secretary, certified by a seniorcompany official:

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a. that the facilities have been constructed in compliance with all applicableconditions, and that continuing activities will be consistent with all applicableconditions; orb. that identifies which of the conditions in the Order Venture Global has compliedwith or will comply with. This statement shall also identify any areas affected by
the Project where compliance measures were not properly implemented, if notpreviously identified in filed status reports, and the reason for noncompliance.
15.

Gator Express Pipeline shall provide 72 hours’ notice to the owner(s) of producing
oil and gas wells located within 0.25 mile from the pipeline workspace in order toallow the owner’s representative to be on-site during construction activities. (Seesection 4.1.2)

16.

Venture Global shall not begin construction of the Project until:
a. FERC staff receives comments from the FWS and NMFS regarding the proposed
action;b. FERC staff completes formal consultation or conference with the FWS and
NMFS, if required; andc. Venture Global has received written notification from the Director of OEP that
construction or use of mitigation may begin. (See section 4.7.1.4)

17.

Venture Global shall not begin construction of the Project until it files with theSecretary a copy of the determination of consistency with the Coastal Zone
Management Plan issued by the LDNR. (See section 4.8.7)

18.

Prior to construction of the pipelines, Gator Express Pipeline shall file with theSecretary documentation that consultation with the LDNR Oyster Lease Damage
Evaluation Board and/or the affected lease holder(s) has been completed. (See section
4.9.3.1)

19.

Prior to beginning the HDD at Lake Hermitage, Gator Express Pipeline shall filewith the Secretary, for the review and written approval by the Director of OEP, an
HDD noise mitigation plan for the crossing to reduce the projected noise level
attributable to the proposed drilling operations at the nearby NSA. During drilling
operations, Gator Express Pipeline shall implement the approved plan, monitor noiselevels, and make all reasonable efforts to restrict the noise attributable to the drilling
operations to no more than an Ldn of 55 dBA at the NSA. (See section 4.11.2.3)

20.

No later than 60 days after placing Phase I into service, Plaquemines LNG shallfile a full power load noise survey with the Secretary for the LNG terminal. If thenoise attributable to operation of the equipment at the LNG terminal exceeds an Ldnof 55 dBA at the nearest NSA, within 60 days Plaquemines LNG shall modify
operation of the liquefaction facilities or install additional noise controls until a noiselevel below an Ldn of 55 dBA at the NSA is achieved. Plaquemines LNG shall
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confirm compliance with the above requirement by filing a second noise survey with
the Secretary no later than 60 days after it installs the additional noise controls. (Seesection 4.11.2.4)
21.

No later than 60 days after placing the entire LNG terminal into service,
Plaquemines LNG shall file a noise survey with the Secretary. If a full load condition
noise survey is not possible, Plaquemines LNG shall provide an interim survey at the
maximum possible horsepower load within 60 days of placing the LNG terminal into
service and provide the full load survey within 6 months. If the noise attributable tooperation of the equipment at the LNG terminal exceeds an Ldn of 55 dBA at thenearest NSA under interim or full horsepower load conditions, Plaquemines LNG
shall file a report on what changes are needed and shall install the additional noise
controls to meet the level within 1 year of the in-service date. Plaquemines LNG
shall confirm compliance with the above requirement by filing an additional noise
survey with the Secretary no later than 60 days after it installs the additional noise
controls. (See section 4.11.2.4)

22.

Prior to initial site preparation, Plaquemines LNG shall file with the Secretary a
study that determines the presence or absence of growth faults extending across thesite using geophysically logged borings that is stamped and sealed by the professional
engineer-of-record, registered in Louisiana. If growth faults are determined to bepresent, Plaquemines LNG shall file a plan to avoid or mitigate growth fault impacts
with the Secretary that is stamped and sealed by the professional engineer-of record,
registered in Louisiana.

23.

Prior to construction of final design, Plaquemines LNG shall file with the Secretary
the following information, stamped and sealed by the professional engineer-ofrecord, registered in Louisiana:
a. site preparation drawings and specifications;b. LNG terminal structures and foundation design drawings and calculations(including prefabricated and field constructed structures);c. seismic specifications for procured equipment; andd. quality control procedures to be used for civil/structural design and construction.
In addition, Plaquemines LNG shall file, in its Implementation Plan, the schedule
for producing this information.

24.

Prior to commencement of service, Plaquemines LNG shall file with the Secretarya monitoring and maintenance plan, stamped and sealed by the professional engineerof-record registered in Louisiana, for the perimeter levee which ensures the crest
elevation relative to mean sea level will be maintained for the life of the facility
considering berm settlement, subsidence, and sea level rise.

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Conditions 25 through 121 shall apply to the Plaquemines LNG terminal. Information
pertaining to these specific conditions shall be filed with the Secretary for review and written
approval by the Director of OEP, or the Director’s designee, within the timeframe indicated byeach condition. Specific engineering, vulnerability, or detailed design information meeting thecriteria specified in Order No. 833 (Docket No. RM16-15-000), including security information,
shall be filed as critical energy infrastructure information pursuant to 18 CFR §388.113. See
Critical Electric Infrastructure Security and Amending Critical Energy Infrastructure Information,
Order No. 833, 81 Fed. Reg. 93,732 (December 21, 2016), FERC Stats. & Regs. 31,389 (2016).
Information pertaining to items such as offsite emergency response, procedures for public
notification and evacuation, and construction and operating reporting requirements would be
subject to public disclosure. All information shall be filed a minimum of 30 days before approval
to proceed is requested.
25.

Prior to initial site preparation, Plaquemines LNG shall file an overall projectschedule, which includes the proposed stages of the commissioning plan.

26.

Prior to initial site preparation, Plaquemines LNG shall file quality assurance andquality control procedures for construction activities.

27.

Prior to initial site preparation, Plaquemines LNG shall file procedures forcontrolling access during construction.

28.

Prior to initial site preparation, Plaquemines LNG shall file its design wind speed
criteria for all other facilities not covered by DOT PHMSA’s LOD to be designed towithstand wind speeds commensurate with the risk and reliability associated with thefacilities in accordance with ASCE 7-16 or equivalent.

29.

Prior to initial site preparation, Plaquemines LNG shall develop an ERP (including
evacuation) and coordinate procedures with the Coast Guard; state, county, and local
emergency planning groups; fire departments; state and local law enforcement; andappropriate federal agencies. This plan shall include at a minimum:
a. designated contacts with state and local emergency response agencies;b. scalable procedures for the prompt notification of appropriate local officials andemergency response agencies based on the level and severity of potential
incidents;c. procedures for notifying residents and recreational users within areas of potential
hazard;d. evacuation routes/methods for residents and public use areas that are within anytransient hazard areas along the route of the LNG marine transit;
e. locations of permanent sirens and other warning devices; andf. an “emergency coordinator” on each LNG marine vessel to activate sirens andother warning devices.

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Plaquemines LNG shall notify the FERC staff of all planning meetings in advanceand shall report progress on the development of its ERP at 3‑month intervals.
30.

Prior to initial site preparation, Plaquemines LNG shall file a Cost-Sharing Plan
identifying the mechanisms for funding all Project-specific security/emergency
management costs that would be imposed on state and local agencies. This
comprehensive plan shall include funding mechanisms for the capital costs associatedwith any necessary security/emergency management equipment and personnel base.
Plaquemines LNG shall notify FERC staff of all planning meetings in advance andshall report progress on the development of its Cost-Sharing Plan at 3-monthintervals.

31.

Prior to construction of final design, Plaquemines LNG shall include spillcontainment (e.g., a trough collection system) for the entire length of the pipe-in-pipe
system between the LNG storage tanks and the marine berth area sized for a full
guillotine rupture of the pipe-in-pipe line based on a 10-minute duration.

32.

Prior to construction of final design, Plaquemines LNG shall file details of the pipein-pipe system design, including wall thicknesses, spacers, expansion bellows orloops, and transitions.

33.

Prior to construction of final design, Plaquemines LNG shall file change logs thatlist and explain any changes made from the front end engineering design provided in
Plaquemines LNG’s application and filings. A list of all changes with an explanation
for the design alteration shall be provided and all changes shall be clearly indicatedon all diagrams and drawings.

34.

Prior to construction of final design, Plaquemines LNG shall fileinformation/revisions pertaining to the response numbers 14 of its October 11, 2018
filing, response numbers 8, 15, 24, 25, 27, 39, 40, and 43 of its October 16, 2018
filing, and response numbers 11, 31, and 38 of its October 30, 2018 filing, whichindicated features to be included or considered in the final design.

35.

Prior to construction of final design, Plaquemines LNG shall file a plot plan of the
final design showing all major equipment, structures, buildings, and impoundment
systems.

36.

Prior to construction of final design, Plaquemines LNG shall file drawings of thestorage tank piping support structure and support of horizontal piping at grade
including pump columns, relief valves, pipe penetrations, instrumentation, andappurtenances.

37.

Prior to construction of final design, Plaquemines LNG shall file an up-to-dateequipment list, process and mechanical data sheets, and specifications. The
specifications shall be in consistent units and include:

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a. Building Specifications (e.g., control buildings, electrical buildings, compressor
buildings, storage buildings, pressurized buildings, ventilated buildings, blast
resistant buildings);
b. Mechanical Specifications (e.g., piping, valve, insulation, rotating equipment,
heat exchanger, storage tank, pressure vessel, other specialized equipment);c. Electrical and Instrumentation Specifications (e.g., power system specifications,control system specifications, SIS specifications, cable specifications, otherelectrical and instrumentation specifications);
d. Security and Fire Safety Specifications (e.g., security, passive protection, hazard
detection, hazard control, firewater).
38.

Prior to construction of final design, Plaquemines LNG specify and design theircontrol systems and human machine interfaces in accordance with the ISA Standards
5.3, 5.5, 60.1, 60.3, 60.4, and 60.6, or other equivalent standards and recommended
practices for designing control buildings, displaying graphic symbols for humanmachine interfaces, and consideration of other human factors.

39.

Prior to construction of final design, Plaquemines LNG shall file a list of all codesand standards and the final specification document number where they are referenced.

40.

Prior to construction of final design, Plaquemines LNG shall file three-dimensional
plant drawings, or other documentation, to confirm plant layout for maintenance,
access, egress, and congestion.

41.

Prior to construction of final design, Plaquemines LNG shall file up-to-date PFDs
and P&IDs. The PFDs shall include heat and material balances. The P&IDs shall
include the following information:a. equipment tag number, name, size, duty, capacity, and design conditions;b. equipment insulation type and thickness;c. storage tank pipe penetration size and nozzle schedule;
d. valve high pressure side and internal and external vent locations;e. piping with line number, piping class specification, size, and insulation type andthickness;
f. piping specification breaks and insulation limits;
g. all control and manual valves numbered;h. relief valves with size and set points; andi. drawing revision number and date.
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42.

Prior to construction of final design, Plaquemines LNG shall include a means toremove mercury as part of the design to limit concentrations to less than 0.01
micrograms per normal cubic meter or alternatively provide monitoring for mercury
by means of an analyzer or preventative maintenance inspections of the heatexchangers and connections for a mercury removal package.

43.

Prior to construction of final design, Plaquemines LNG shall file layout and design
specifications of the pig trap, inlet separation and liquid disposal, inlet/send-out meterstation, filters, and pressure control.

44.

Prior to construction of final design, Plaquemines LNG shall file a car seal
philosophy and a list of all car-sealed and locked valves consistent with the P&IDs.

45.

Prior to construction of final design, Plaquemines LNG shall file documentation
demonstrating that the recommendations from the Front End Engineering Design
Hazard Identification are complete and consistent with the requirements of the final
design as determined by the engineering, procurement, and construction contractor.

46.

Prior to construction of final design, Plaquemines LNG shall file a hazard andoperability review prior to issuing the P&IDs for construction. A copy of the review,a list of the recommendations, and actions taken on the recommendations shall be
filed.

47.

Prior to construction of final design, Plaquemines LNG shall file the safe operating
limits (upper and lower), alarm and shutdown set points for all instrumentation (i.e.,
temperature, pressures, flows, and compositions).

48.

Prior to construction of final design, Plaquemines LNG shall include LNG tank fillflow measurement with high flow alarm.

49.

Prior to construction of final design, Plaquemines LNG shall include BOG flow,tank density profile and temperature profile measurement for each tank.

50.

Prior to construction of final design, Plaquemines LNG shall file cause-and-effectmatrices for the process instrumentation, fire and gas detection system, andemergency shutdown system for review and approval. The cause-and-effect matrices
shall include alarms and shutdown functions, details of the voting and shutdown
logic, and set points.

51.

Prior to construction of final design, Plaquemines LNG shall specify that all ESD
valves are to be equipped with open and closed position switches connected to the
DCS/SIS.

52.

Prior to construction of final design, Plaquemines LNG shall specify the minimum
distance required for valve maintenance, between the LNG loading header and thefirst valve in the discharge piping to the loading arm.

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53.

Prior to construction of final design, Plaquemines LNG shall specify that piping
and equipment that may be cooled with liquid nitrogen is to be designed for liquid
nitrogen temperatures, with regard to allowable movement and stresses.

54.

Prior to construction of final design, Plaquemines LNG shall include any isolation
valves necessary for startup, operation, shutdown, restart, and maintenanceprocedures.

55.

Prior to construction of final design, Plaquemines LNG shall demonstrate that, forhazardous fluids, piping and piping nipples 2 inches or less in diameter are designed
to withstand external loads, including vibrational loads in the vicinity of rotating
equipment and operator live loads in areas accessible by operators.

56.

Prior to construction of final design, Plaquemines LNG shall specify that all drainsfrom high pressure hazardous fluid systems are to be equipped with double isolation
and bleed valves or equivalent positive isolation.

57.

Prior to construction of final design, Plaquemines LNG shall file the sizing basis
and capacity for the final design of the flares and/or vent stacks as well as the pressureand vacuum relief valves for major process equipment, vessels, and storage tanks.

58.

Prior to construction of final design, Plaquemines LNG shall file pressure relieving
protection for flammable liquid piping segments (i.e., refrigerants, liquidhydrocarbons, condensate products) that can be isolated by valves.

59.

Prior to construction of final design, Plaquemines LNG shall file an updated fire
protection evaluation of the proposed facilities. A copy of the evaluation, a list ofrecommendations and supporting justifications, and actions taken on therecommendations shall be filed. The evaluation shall justify the type, quantity, andlocation of hazard detection and hazard control, passive fire protection, emergency
shutdown and depressurizing systems, firewater, and emergency response equipment,
training, and qualifications in accordance with NFPA 59A (2001). The justification
for the flammable and combustible gas detection and flame and heat detection shallbe in accordance with ISA 84.00.07 or equivalent methodologies that would
demonstrate 90 percent or more of releases (unignited and ignited) that could resultin an offsite or cascading impact would be detected by two or more detectors andresult in isolation and deinventory within 10 minutes. The analysis shall take into
account the set points, voting logic, wind speeds, and wind directions. The
justification for firewater shall provide calculations for all firewater demands(including firewater coverage on the LNG storage tanks) based on design densities,
surface area, and throw distance and specifications for the corresponding hydrant andmonitors needed to reach and cool equipment.

60.

Prior to construction of final design, Plaquemines LNG shall file spill containment
system drawings with dimensions and slopes of curbing, trenches, impoundments,
and capacity calculations considering any foundations and equipment within

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impoundments, as well as the sizing and design of the down-comer that would
transfer spills from the tank top to the ground-level impoundment system. The spillcontainment drawings shall show containment for all hazardous fluids, including all
liquids handled above their flashpoint, from the largest flow from a single line for 10
minutes, including de-inventory, or the maximum liquid from the largest vessel (ortotal of impounded vessels) or otherwise demonstrate that providing spillcontainment would not significantly reduce the flammable vapor dispersion orradiant heat consequences of a spill. In addition, Plaquemines LNG shall demonstratethat the stainless steel piping spill trays at each LNG storage tank would withstandthe force and shock of a sudden cryogenic release.
61.

Prior to construction of final design, Plaquemines LNG shall consult with DOT
PHMSA on compliance with 49 CFR 193 for the water removal design using drains.

62.

Prior to construction of final design, Plaquemines LNG shall file electrical areaclassification drawings. The drawings shall be updated with the latest design,
including liquefaction blocks and full containment tanks, and demonstratecompliance with NFPA 59A, NFPA 70, NFPA 497, API 500, or equivalent, including
but not limited to, illustrating Class 1 Division 1 and Division 2, as applicable, at all
impoundment trenches, the LNG ship transfer connection, refrigerant truck transfer
connection, diesel truck transfer connection, diesel and other combustible tank vents,
power plant area, gas turbines, feed gas aftercoolers, MR coolers, and pig launchers.

63.

Prior to construction of final design, Plaquemines LNG shall file detailed
calculations to confirm that the final fire water volumes would be accounted for whenevaluating the capacity of the impoundment system during a spill and fire scenario.

64.

Prior to construction of final design, Plaquemines LNG shall file an analysis
demonstrating the flammable vapor dispersion from design spills would be prevented
from dispersing underneath the elevated LNG storage tanks, or demonstrating the
LNG storage tanks would be able to withstand the overpressure due to ignition of the
flammable vapors that disperses underneath the elevated LNG storage tanks.

65.

Prior to construction of final design, Plaquemines LNG shall file drawings anddetails of how process seals or isolations installed at the interface between aflammable fluid system and an electrical conduit or wiring system meet therequirements of NFPA 59A (2001 edition). Plaquemines LNG shall also provide theresults of consultation with DOT PHMSA indicating that the proposed electrical
process seal design would be considered to meet the design requirements of NFPA
59A (2001), as incorporated by 49 CFR 193.2101.

66.

Prior to construction of final design, Plaquemines LNG shall file details of an air
gap or vent installed downstream of process seals or isolations installed at theinterface between a flammable fluid system and an electrical conduit or wiring
system. Each air gap shall vent to a safe location and be equipped with a leakdetection device that shall continuously monitor for the presence of a flammablefluid, alarm the hazardous condition, and shut down the appropriate systems.

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67.

Prior to construction of final design, Plaquemines LNG shall file an analysis of thelocalized hazards to operators from a potential liquid nitrogen release and shall also
provide spill containment and low oxygen detectors to mitigate liquid nitrogen
releases.

68.

Prior to construction of final design, Plaquemines LNG shall file a drawing
showing the location of the emergency shutdown buttons. Emergency shutdown
buttons shall be easily accessible, conspicuously labeled, and located in an area which
would be accessible during an emergency.

69.

Prior to construction of the final design, Plaquemines LNG shall install a plantwide shutdown button or provide a human reliability analysis that demonstrates themultiple pushbutton approach does not significantly increase the risk compared to aplant-wide shutdown button.

70.

Prior to construction of final design, Plaquemines LNG shall file complete
drawings and a list of the hazard detection equipment. The drawings shall clearlyshow the location and elevation of all detection equipment, including near the diesel
and hot oil tanks, steam turbine power plant, flare KO drums, ethylene packages,
peaking generator, essential diesel generator, acid gas removal area, hot oil furnaces,
thermal oxidizer, combustion air intakes and HVAC intakes of buildings. The list
shall include the instrument tag number, type and location, alarm indication locations,and shutdown functions of the hazard detection equipment.

71.

Prior to construction of final design, Plaquemines LNG shall account for thecalibration gas of the hazard detectors when determining the lower flammable limit
set points for methane, propane, butane, ethylene, and condensate.

72.

Prior to construction of final design, Plaquemines LNG shall account for thecalibration gas of hazard detectors when determining the set points for toxic
components such as aqueous ammonia, natural gas liquids and hydrogen sulfide.
Include a list of alarm and shutdown set points for each hazard detector.

73.

Prior to construction of final design, Plaquemines LNG shall file a technical review
of facility design that:a. identifies all combustion/ventilation air intake equipment and the distances to any
possible flammable gas or toxic release; andb. demonstrates that these areas are adequately covered by hazard detection devices
and indicates how these devices would isolate or shut down any combustion or
heating ventilation and air conditioning equipment whose continued operation
could add to or sustain an emergency.

74.

Prior to construction of final design, Plaquemines LNG shall file an analysis of theoff gassing of hydrogen in battery rooms and ventilation calculations that limit
concentrations below the lower flammability limits (e.g., 25 percent LFL) and shall5-40

also provide hydrogen detectors that alarm (e.g., 20 to 25 percent LFL) and initiate
mitigative actions (e.g., 40 to 50 percent LFL).
75.

Prior to construction of final design, Plaquemines LNG shall specify smoke
detection in occupied buildings.

76.

Prior to construction of final design, Plaquemines LNG shall specify hazard
detection suitable to detect high temperatures and smoldering combustion products
in electrical buildings and control room buildings.

77.

Prior to construction of final design, Plaquemines LNG shall file an evaluation of
the voting logic and voting degradation for hazard detectors.

78.

Prior to construction of final design, Plaquemines LNG shall file facility plandrawings and a list of the fixed and wheeled dry-chemical, hand-held fire
extinguishers, and other hazard control equipment. Plan drawings shall clearly show
the location and elevation by tag number of all fixed dry chemical systems inaccordance with NFPA 17, and wheeled and hand-held extinguishers along normal
paths of access and egress in accordance with NFPA 10 travel distances, including
but not limited to, at the liquefaction blocks, near the metering station and pig
launchers, on top of all tanks, and in all buildings. The list shall include theequipment tag number, manufacturer and model, agent type, agent capacity,
discharge rate, automatic and manual remote signals initiating discharge of the units,
and equipment covered.

79.

Prior to construction of final design, Plaquemines LNG shall specify carbon
dioxide systems installed in accordance with NFPA 12 or equivalent in gas turbine
enclosures.

80.

Prior to construction of final design, Plaquemines LNG shall specify clean agent
systems installed in accordance with NFPA 2001 or equivalent in instrumentationbuildings.

81.

Prior to construction of final design, Plaquemines LNG shall file drawings andcalculations for the structural passive protection systems to protect equipment andsupports from cryogenic releases.

82.

Prior to construction of final design, Plaquemines LNG shall file calculations or
test results for the structural passive protection systems to demonstrate that
equipment and supports are protected from cryogenic releases.

83.

Prior to construction of final design, Plaquemines LNG shall file drawings andspecifications for the structural passive protection systems to demonstrate theequipment and supports are protected from pool and jet fires.

84.

Prior to construction of final design, Plaquemines LNG shall file a detailed
quantitative analysis to demonstrate that adequate mitigation would be provided foreach significant component within the 4,000 BTU/ft2-hr zone from pool and jet fires
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that could cause failure of the component. Trucks at the truck loading/unloading
areas shall be included in the analysis. A combination of passive and active
protection for pool fires and passive and/or active protection for jet fires shall be
provided and demonstrate the effectiveness and reliability. Effectiveness of passive
mitigation shall be supported by calculations or test results for the thickness limiting
temperature rise and active mitigation shall be justified with calculations or test
results demonstrating flow rates and durations of any cooling water will mitigate theheat absorbed by the vessel.
85.

Prior to construction of final design, Plaquemines LNG shall file a projectile
analysis to demonstrate that the outer concrete impoundment wall of a fullcontainment LNG storage tank could withstand projectiles from explosions and highwinds. The analysis shall detail the projectile speeds and characteristics and method
used to determine penetration or perforation depths.

86.

Prior to construction of final design, Plaquemines LNG shall file specifications anddrawings demonstrating how cascading damage of transformers would be prevented(e.g., firewalls or spacing) in accordance with NFPA 850 or equivalent.

87.

Prior to construction of final design, Plaquemines LNG shall file facility plandrawings showing the proposed location of the firewater and any foam systems. Plan
drawings shall clearly show the location of firewater and foam piping, post indicatorvalves, and the location and area covered by, each monitor, hydrant, hose, water
curtain, deluge system, foam system, water-mist system, and sprinkler. The drawings
shall also include piping and instrumentation diagrams of the firewater and foamsystems. The firewater coverage drawings shall illustrate firewater coverage by two
or more hydrants or monitors accounting for obstructions (or deluge systems) for allprocess areas that contain flammable or combustible fluids, including all three docks,
diesel generators and storage, hot oil storage, gas dehydration units, and LNG storage
tanks.

88.

Prior to construction of final design, Plaquemines LNG shall specify remotely
operated or automatic firewater monitors in areas inaccessible or difficult to accessin the event of an emergency.

89.

Prior to construction of final design, Plaquemines LNG shall specify firewatercapacities for the monitors and hydrants.

90.

Prior to construction of final design, Plaquemines LNG shall design the firewater
pump shelter for maintenance access to the firewater pumps.

91.

Prior to construction of final design, Plaquemines LNG shall specify that afirewater flow test meter is installed and equipped with a transmitter and that apressure transmitter is installed upstream of the flow transmitter. The flowtransmitter and pressure transmitter shall be connected to the DCS and recorded.

92.

Prior to construction of final design, Plaquemines LNG shall specify the reducer
on the suction side of the firewater pump to be eccentric or otherwise justify the use
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of an alternative reducer that will not cause air pockets to form and cause possible
damage to the firewater pump.
93.

Prior to construction of final design, Plaquemines LNG shall file an analysis of thestructural integrity of the outer containment of the full containment storage tanks
when exposed to a roof tank top fire or adjacent tank top fire.

94.

Prior to construction of final design, Plaquemines LNG shall file drawings andspecifications for protecting transfer piping, pumps, and compressors, etc. to ensurethat they are located away from roadway or protected from inadvertent damage fromvehicles.

95.

Prior to construction of final design, Plaquemines LNG shall file specifications,drawings, and details of vehicle barriers at each facility entrance for access control.

96.

Prior to construction of final design, Plaquemines LNG shall file specifications,drawings, and details of the vehicle collision protection at the SH 23 road crossing of
the LNG transfer line that demonstrate it can withstand impact from the most severe
loading, including potential explosion loads from any trucks carrying hazardous
materials.

97.

Prior to construction of final design, Plaquemines LNG shall file security camera
drawings showing the location, areas covered, and features of the camera (fixed,
tilt/pan/zoom, motion detection alerts, low light, mounting height, etc.) to verify
camera coverage of the entire perimeter with redundancies and cameras interior to
the facility, including atop the LNG storage tanks, that would enable rapid monitoringof the LNG plant.

98.

Prior to construction of final design, Plaquemines LNG shall file a photometriclighting simulation or other calculations that demonstrate lighting coverageadequately covers, in accordance with API 540, the interior and perimeter of the
facility, including in liquefaction blocks, oily water treatment plant area, exterior ofbuildings, and along paths/roads of access and egress.

99.

Prior to construction of final design, Plaquemines LNG shall file details of fencing
with barbed or razor wire, or equivalent, at road crossing that would restrict and deter
access.

100. Prior to construction of final design, Plaquemines LNG shall file drawings of the
security fence. The fencing drawings shall provide details of fencing that
demonstrates it would restrict and deter access around the entire facility and has asetback from exterior features (e.g., power lines, trees, etc.) and from interior features(e.g., piping, equipment, buildings, etc.) that does not allow the fence to be overcome.
Prior to the construction of the final design, Plaquemines LNG shall provide anevaluation that demonstrates the storm surge barrier, including any gated areas andwater discharge through the storm surge barrier, would prevent LNG from extending
offsite in the event of a release of the full contents of a LNG storage tank. The

5-43

evaluation shall also demonstrate whether and how high the sheet piles would need
to be protected from embrittlement.
101. Prior to commissioning, Plaquemines LNG shall file a detailed schedule forcommissioning through equipment startup. The schedule shall include milestones for
all procedures and tests to be completed: prior to introduction of hazardous fluids
and during commissioning and startup. Plaquemines LNG shall file with theSecretary documentation certifying that each of these milestones has been completed
before authorization to commence the next phase of commissioning and startup will
be issued.
102. Prior to commissioning, Plaquemines LNG shall file the operation and maintenanceprocedures and manuals, as well as safety procedures, hot work procedures andpermits, abnormal operating conditions reporting procedures, simultaneous
operations procedures, and management of change procedures and forms.
103. Prior to commissioning, Plaquemines LNG shall provide procedures for removing
the spent H2S catalyst.
104. Prior to commissioning, Plaquemines LNG shall tag all equipment, instrumentation,and valves in the field, including drain valves, vent valves, main valves, and carsealed or locked valves.
105. Prior to commissioning, Plaquemines LNG shall file and maintain a detailed
training log to demonstrate that operating, maintenance and emergency response staff
has completed the required training.
106. Prior to commissioning, Plaquemines LNG shall file detailed plans and procedures
for: testing the integrity of onsite mechanical installation; functional tests;
introduction of hazardous fluids; operational tests; and placing the equipment into
service.
107. Prior to commissioning, Plaquemines LNG shall file the procedures forpressure/leak tests which address the requirements of ASME VIII and ASME B31.3.
108. Prior to commissioning, Plaquemines LNG shall file a plan for clean-out, dry-out,
purging, and tightness testing. This plan shall address the requirements of theAmerican Gas Association’s Purging Principles and Practice, and shall provide
justification if not using an inert or non-flammable gas for clean-out, dry-out,
purging, and tightness testing.
109. Prior to commissioning, Plaquemines LNG shall equip the LNG storage tanks andadjacent piping and supports with permanent settlement monitors to allow personnel
to observe and record the total and relative settlement between the LNG storage tank
and adjacent piping. The settlement record shall be reported in the semi-annual
operational reports.

5-44

110. Prior to introduction of hazardous fluids, Plaquemines LNG shall file settlement
results from the hydrostatic tests of the LNG storage containers and shall file a planto periodically verify settlement is as expected and does not exceed the applicable
criteria set forth in API 620, API 625, API 653, and ACI 376.
111. Prior to introduction of hazardous fluids, Plaquemines LNG shall complete all
pertinent tests (Factory Acceptance Tests, Site Acceptance Tests, Site Integration
Tests) associated with the DCS and SIS that demonstrates full functionality andoperability of the system.
112. Prior to introduction of hazardous fluids, Plaquemines LNG shall develop andimplement an alarm management program to ensure effectiveness of process alarms.
113. Prior to introduction of hazardous fluids, Plaquemines LNG shall complete afirewater pump acceptance test and firewater monitor and hydrant coverage test. The
actual coverage area from each monitor and hydrant shall be shown on facility plot
plan(s).
114. Prior to introduction of hazardous fluids, Plaquemines LNG shall complete anddocument foam system and sprinkler system acceptance tests.
115. Prior to introduction of hazardous fluids, Plaquemines LNG shall complete anddocument a clean agent acceptance tests.
116. Prior to introduction of hazardous fluids, Plaquemines LNG shall complete anddocument a pre-startup safety review to ensure that installed equipment meets thedesign and operating intent of the facility. The pre-startup safety review shall include
any changes since the last hazard review, operating procedures, and operator training.
A copy of the review with a list of recommendations, and actions taken on each
recommendation, shall be filed.
117. Plaquemines LNG shall file a request for written authorization from the Director of
OEP prior to unloading or loading the first LNG commissioning cargo. After
production of first LNG, Plaquemines LNG shall file weekly reports on thecommissioning of the proposed systems that detail the progress toward demonstrating
the facilities can safely and reliably operate at or near the design production rate. The
reports shall include a summary of activities, problems encountered, and remedialactions taken. The weekly reports shall also include the latest commissioning
schedule, including projected and actual LNG production by each liquefaction train,
LNG storage inventories in each storage tank, and the number of anticipated andactual LNG commissioning cargoes, along with the associated volumes loaded or
unloaded. Further, the weekly reports shall include a status and list of all plannedand completed safety and reliability tests, work authorizations, and punch list items.
Problems of significant magnitude shall be reported to the FERC within 24 hours.
118. Prior to commencement of service, Plaquemines LNG shall label piping with fluid
service and direction of flow in the field, in addition to the pipe labeling requirements
of NFPA 59A (2001 edition).
5-45

119. Prior to commencement of service, Plaquemines LNG shall file any preventativeand predictive maintenance program that performs periodic or continuous equipment
condition monitoring to ensure mechanical integrity of equipment.
120. Prior to commencement of service, Plaquemines LNG shall file procedures foroffsite contractors’ responsibilities, restrictions, and limitations and for supervisionof these contractors by Plaquemines LNG staff.
121. Prior to commencement of service, Plaquemines LNG shall notify the FERC staff
of any proposed revisions to the security plan and physical security of the plant.
Prior to commencement of service, Plaquemines LNG shall file a request for
written authorization from the Director of OEP. Such authorization would only be
granted following a determination by the Coast Guard, under its authorities under thePorts and Waterways Safety Act, the Magnuson Act, the Maritime Transportation
Security Act of 2002, and the Security and Accountability For Every Port Act, thatappropriate measures to ensure the safety and security of the facility and thewaterway have been put into place by Plaquemines LNG or other appropriate parties.
In addition, conditions 122 through 125 shall apply throughout the life of the Plaquemines
LNG terminal.
122. The facility shall be subject to regular FERC staff technical reviews and site
inspections on at least an annual basis or more frequently as circumstances indicate.
Prior to each FERC staff technical review and site inspection, Plaquemines LNG shall
respond to a specific data request including information relating to possible designand operating conditions that may have been imposed by other agencies ororganizations. Up-to-date detailed P&IDs reflecting facility modifications andprovision of other pertinent information not included in the semi-annual reports
described below, including facility events that have taken place since the previously
submitted semi-annual report, shall be submitted.
123. Semi-annual operational reports shall be filed to identify changes in facility designand operating conditions; abnormal operating experiences; activities (e.g., LNG
marine vessel arrivals, quantity and composition of imported and exported LNG,
liquefied and vaporized quantities, boil off/flash gas); and plant modifications,
including future plans and progress thereof. Abnormalities shall include, but not belimited to, unloading/loading/shipping problems, potential hazardous conditions
from offsite vessels, storage tank stratification or rollover, geysering, storage tankpressure excursions, cold spots on the storage tanks, storage tank vibrations and/or
vibrations in associated cryogenic piping, storage tank settlement, significant
equipment or instrumentation malfunctions or failures, non-scheduled maintenanceor repair (and reasons therefore), relative movement of storage tank inner vessels,
hazardous fluids releases, fires involving hazardous fluids and/or from other sources,
negative pressure (vacuum) within a storage tank, and higher than predicted boil off
rates. Adverse weather conditions and the effect on the facility also shall be reported.
Reports shall be submitted within 45 days after each period ending June 30 and
December 31. In addition to the above items, a section entitled “Significant Plant
5-46

Modifications Proposed for the Next 12 Months (dates)” shall be included in thesemi-annual operational reports. Such information would provide the FERC staff
with early notice of anticipated future construction/maintenance at the LNG facilities.
124. In the event the temperature of any region of any secondary containment, including
imbedded pipe supports, becomes less than the minimum specified operating
temperature for the material, the Commission shall be notified within 24 hours andprocedures for corrective action shall be specified.
125. Significant non-scheduled events, including safety-related incidents (e.g., LNG,
condensate, refrigerant, or natural gas releases; fires; explosions; mechanical failures;
unusual over pressurization; and major injuries) and security-related incidents (e.g.,
attempts to enter site, suspicious activities) shall be reported to the FERC staff. In
the event that an abnormality is of significant magnitude to threaten public or
employee safety, cause significant property damage, or interrupt service, notification
shall be made immediately, without unduly interfering with any necessary or
appropriate emergency repair, alarm, or other emergency procedure. In all instances,notification shall be made to the FERC staff within 24 hours. This notification
practice shall be incorporated into the LNG facility’s emergency plan. Examples ofreportable hazardous fluids-related incidents include:a. fire;b. explosion;c. estimated property damage of $50,000 or more;d. death or personal injury necessitating in-patient hospitalization;e. release of hazardous fluids for 5 minutes or more;
f. unintended movement or abnormal loading by environmental causes, such as anearthquake, landslide, or flood, that impairs the serviceability, structural integrity,
or reliability of a facility that contains, controls, or processes hazardous fluids;
g. any crack or other material defect that impairs the structural integrity or reliabilityof a facility that contains, controls, or processes hazardous fluids;
h. any malfunction or operating error that causes the pressure of a pipeline or LNG
facility that contains or processes hazardous fluids to rise above its maximum
allowable operating pressure (or working pressure for facilities) plus the build-up
allowed for operation of pressure-limiting or control devices;
i. a leak in a facility that contains or processes hazardous fluids that constitutes an
emergency;
j. inner tank leakage, ineffective insulation, or frost heave that impairs the structural
integrity of an LNG storage tank;5-47

k. any safety-related condition that could lead to an imminent hazard and cause(either directly or indirectly by remedial action of the operator), for purposes
other than abandonment, a 20 percent reduction in operating pressure or shutdownof operation of a pipeline or a facility that contains or processes hazardous fluids;
l. safety-related incidents from hazardous fluids transportation occurring at or enroute to and from the LNG facility; orm. an event that is significant in the judgment of the operator and/or management
even though it did not meet the above criteria or the guidelines set forth in an
LNG terminal’s incident management plan.
In the event of an incident, the Director of OEP has delegated authority to takewhatever steps are necessary to ensure operational reliability and to protect human
life, health, property, or the environment, including authority to direct the LNG
facility to cease operations. Following the initial company notification, the FERC
staff would determine the need for a separate follow-up report or follow up in theupcoming semi-annual operational report. All company follow-up reports shall
include investigation results and recommendations to minimize a reoccurrence of theincident.

5-48

APPENDIX A
DISTRIBUTION LIST FOR NOTICE OF AVAILABILITYAPPENDIX A
DISTRIBUTION LIST
U.S. Coast Guard, Commandant (CG-OES4) Chief (Acting), Deepwater Ports
Standards Division, Attorney/Advisor,
Curtis E. Borland, DC

FEDERAL GOVERNMENT AGENCIES
Council on Environmental Quality, Associate
Director for NEPA Oversight, Edward
Boling, DC

U.S. Coast Guard, Commanding Officer,
Captain Randall Ogrydziak, TX

Office of Federal Programs, Advisory
Council on Historic Preservation,
Assistant Director for Federal Program
Development, Charlene D. Vaughn, DC

U.S. Coast Guard, Commanding Officer,
Commander Monica Rochester, LA

Senate Energy and Natural Resources
Committee, Chairman, Lisa Murkowski,
DC

U.S. Coast Guard, Executive Officer,
Lieutenant Commander Jennifer Andrew,
LA

U.S. Air Force, Office of the Deputy
Assistant Secretary of the Air Force(Installations), SAF/IEI, Liaison, DoD
Siting Clearinghouse, DC

U.S.
Department
ofAgriculture,
Conservation
andEnvironmental
Program Division, FSA, National
Environmental Compliance Manager,
Nell Fuller, DC

U.S. Army Corps of Engineers, New Orleans
District,
CEMVN-OD-S,
Western
Evaluation Section Regulatory Branch,
Chief, Mr. Darrell Barbara, LA

U.S. Department of Agriculture, Forest
Service,
Ecosystem
Management
Coordination, Assistant Director, NEPA,
Joe Carbone, DC

U.S. Army Corps of Engineers, New Orleans
District, Chief Regulatory Branch, Mr.
Martin Mayer, LA

U.S. Department of Agriculture, Natural
Resources Conservation Service, State
Conservationist, Mr. Kevin D. Norton,
LA

U.S. Army Corps of Engineers, Planning andPolicy Division, Senior Policy Advisor,
John Furry, DC

U.S. Department of Agriculture, Natural
Resources
Conservation
Service,National Environmental Coordinator,
Andree DuVarney, DC

U.S. Army Corps of Engineers, Stephanie
Castaing, LA
U.S. Army, Office of the Deputy Assistant
Secretary of the Army (Energy &Sustainability), Liaison, DoD Siting
Clearinghouse, DC

U.S. Department of Commerce, National
Oceanic
andAtmospheric
Administration
National
MarineFisheries Service, Southwest Region,
Regional Administrator, Dr. Roy
Crabtree, FL

U.S. Coast Guard, Facility ComplianceBranch, MSTC Jason Spence, LA

A-1

U.S. Department of Energy, Office ofEnvironmental Management, Principal
Deputy Assistant Secretary, Mark
Whitney, DC

FEDERAL GOVERNMENT AGENCIES(CONT’D)
U.S. Department of Commerce, National
Oceanic
andAtmospheric
Administration,
National
MarineFisheries Service, Habitat Conservation
Division,
Assistant
Regional
Administrator, Mr. Miles Croom, FL

U.S. Department of Energy, Office of Fossil
Energy, Natural Gas Analyst, Kyle
Moorman, DC
U.S. Department of Energy, Office of NEPA
Policy and Compliance, Acting Director,
OGC, Brian Costner, DC

U.S. Department of Commerce, National
Oceanic
andAtmospheric
Administration
National
MarineFisheries Service, Protected Resources
Division,
Assistant
Regional
Administrator for Fishery Resources, Mr.
Dave Bernhart, FL

U.S. Department of Health and Human
Services, Centers for Disease Control andPrevention,
National
CenterforEnvironmental Health, Division of
Emergency and Environmental HealthServices, Director, Sharunda Buchanan,
GA

U.S. Department of Commerce, National
Oceanic
andAtmospheric
Administration,
National
MarineFisheries Service, Habitat Conservation
Division,Fishery
Biologist/Team
Leader, Mr. Richard Hartman, LA

U.S. Department of Health and Human
Services, Chief Environmental Officer,
Mr. Everett Bole, CHMM, DC

U.S. Department of Commerce, National
Oceanic
andAtmospheric
Administration, NEPA Coordinator, MD

U.S. Department of Homeland Security, U.S.
Customs and Border Protection, Branch
Chief, Christopher Oh, DC

U.S. Department of Commerce, National
Oceanic
andAtmospheric
Administration,
National
MarineFisheries Service, Habitat Conservation
Division, Fishery Biologist, Twyla
Cheatwood, LA

U.S. Department of Housing and Urban
Development, Office of Environment andEnergy, Community Planner, Danielle
Schopp, DC
U.S. Department of Justice, Environment andNatural Resources Division, NEPA
Coordinator, DC

U.S. Department of Defense, DOD Siting
Clearinghouse, Steve Sample, DC

U.S. Department of State, Bureau of Oceans
and International Environmental andScientific Affairs, Foreign Affairs
Officer, Alexander Yuan, DC

U.S. Department of Defense, Office of the
Deputy Under Secretary of Defense(Installations & Environment), Chief,
Mission Evaluation Branch, DOD Siting
Clearinghouse, DC

U.S. Department of the Army, Office of theAssistant Secretary of the Army for Civil
Works, Assistant for Environment, Tribal
and Regulatory Affairs, DC

U.S. Department of Energy, Division of
Natural Gas Regulatory Activities,
Director, John Anderson, DC
A-2

U.S. Department of Transportation, Pipelineand Hazardous Materials Safety
Administration, SW Region, Community
Assistant and Technical Services, Mr.
Bill Lowry, TX

FEDERAL GOVERNMENT AGENCIES(CONT’D)
U.S. Department of the Interior, Bureau ofIndian Affairs, B.J. Howerton, VA
U.S. Department of the Interior, Bureau ofIndian Affairs, NEPA Coordinator, Terry
L McClung, DC

U.S. Department of Transportation, Pipelineand Hazardous Materials Safety
Administration, Office of Pipeline
Safety, Attorney Advisor, Ahuva
Battams, DC

U.S. Department of the Interior, Bureau ofLand Management, NEPA Specialist, DC

U.S. Department of Transportation, Pipelineand Hazardous Materials Safety
Administration, Office of Pipeline
Safety, Community Liaison Services
Program Manager, Karen Lynch, DC

U.S. Department of the Interior, Bureau of
Ocean Energy Management, Chief,
Division of Environmental Assessment,
Dr. Jill Lewandowski, VA
U.S. Department of the Interior, Bureau of
Safety and Environmental Enforcement,
Chief,
Environmental
Compliance
Division, David Fish, VA

U.S. Department of Transportation, Pipelineand Hazardous Materials Safety
Administration,
EngineeringandResearch Division, Office of Pipeline
Safety, Director, Kenneth Y Lee, DC

U.S. Department of the Interior, National
Park Service, Chief, Environmental
Planning and Compliance, Branch,
Patrick Walsh, CO

U.S. Department of Transportation, Pipelineand Hazardous Materials Safety
Administration, Associate Administrator
for Hazardous Materials Safety, William
Schoonover, DC

U.S. Department of the Interior, National
Park Service, Oil and Gas Program
Manager, Haigler “Dusty” Pate, TX
U.S. Department of the Navy, Office of theAssistant Secretary of the Navy (Energy,
Installations and Environment), DC

U.S. Department of Transportation, Pipelineand Hazardous Materials Safety
Administration, Office of Pipeline
Safety, Attorney Advisor, Melanie
Stevens, DC

U.S. Department of Transportation, Office ofAssistant Secretary for Transportation
Policy, Environmental Policy Team
Coordinator, Camille Mittelholtz, DC

U.S. Department of Transportation, Surface
Transportation Board, Chief, Section ofEnvironmental
Analysis,
Victoria
Rutson, DC

U.S. Department of Transportation, Office ofAssistant Secretary for Transportation
Policy, Senior Environmental Attorney
Advisor, Helen Serassio, DC

U.S. Environmental Protection AgencyRegion 6, Environmental Scientist, Keith
Hayden, TX
U.S. Environmental Protection Agency, Air
Permits Section Chief, Mr. Jeffrey
Robinson, TX
A-3

FEDERAL GOVERNMENT AGENCIES(CONT’D)

U.S. Fish and Wildlife Service, Regional
Energy Coordinator, Barret Fortier, LA

U.S. Environmental Protection Agency,
Office of Enforcement and Compliance
Assurance, Assistant Administrator,
Lawrence Starfield, DC

U.S. Geological Survey, Environmental
Management Branch, Chief, Mark
Leeper, VA
FEDERALSENATORSREPRESENTATIVES

U.S. Environmental Protection Agency,
Office of Federal Activities, Director,
Susan E Bromm, DC

AND

U.S. House of Representatives, U.S.
Representative, Representative CedricRichmond, DC

U.S. Environmental Protection Agency,
Region 6, Barbara Keeler, TX

U.S. House of Representatives, U.S.
Representative, Representative CedricRichmond, LA

U.S. Environmental Protection Agency,
Region 6, Interstate Oil & Gas
Commission Liaison, Rob Lawrence, TX
U.S. Environmental Protection Agency,
Region 6, Jeff Riley, TX
U.S. Environmental Protection Agency,
Region 6, Office of Planning and
Coordination, Chief, Michael Jansky(6EN-XP), TX

U.S. House of Representatives,
Representative, Representative
Higgins, DC

U.S.
Clay

U.S. House of Representatives,
Representative, Representative
Higgins, LA

U.S.
Clay

U.S. House of Representatives, U.S.
Representative, Representative Steve
Scalise, DC

U.S. Environmental Protection Agency,
Regional Administrator, Mr. Ron Curry,
TX

U.S. House of Representatives, U.S.
Representative, Representative Steve
Scalise, LA

U.S. Environmental Protection Agency,
Wetlands Section, Dr. Raul Gutierrez,
TX

U.S. Senate, U.S. Senator, Senator Bill
Cassidy, DC

U.S. Fish and Wildlife Service, Fish andWildlife Biologist, Mr. Joshua Marceaux,LA

U.S. Senate, U.S. Senator, Senator Bill
Cassidy, LA

U.S. Fish and Wildlife Service, Region 4,
Southeast
Louisiana
Refuges
Headquarters, Refuge Manager, Shelley
Stiaes, LA

U.S. Senate, U.S. Senator, Senator John
Kennedy, DC
U.S. Senate, U.S. Senator, Senator John
Kennedy, LA

U.S. Fish and Wildlife Service, Regional
Director, Ms. Cindy Dohner, GA

A-4

Louisiana Department of Culture, Recreation
and Tourism, Division of Archaeology,
State Archaeologist and Director, Dr.
Charles (Chip) McGimsey, LA

STATE SENATORS AND
REPRESENTATIVESLouisiana House of Representatives, State
Representative,
District103,
Representative Raymond E. Garofalo, Jr.,LALouisiana
Department
ofCulture,Recreation, and Tourism, Division ofArchaeology, Section 106 Review andCompliance, Rachel Watson, LALouisiana House of Representatives, State
Representative,
Representative
Christopher J. Leopold, District 105, LALouisiana Department of Environmental
Quality- Water Permits Division,
Environmental Scientist, Elizabeth Hill,
LA

Louisiana House of Representatives, State
Representative, Representative Joseph
Marino, District 85, LALouisiana Department of Environmental
Quality, Office of Environmental
Services, Environmental Scientist, Bryan
Johnston, LALouisiana House of Representatives, State
Representative, Representative Patrick
Connick, District 84, LALouisiana State Senate, State Senator,
District 1, Senator Sharon Hewitt, LALouisiana Department of Environmental
Quality, Office of Environmental
Sciences, Assistant Secretary, Ms. Tegan
Treadaway, LALouisiana State Senate, State Senator,
District 7, Senator Troy Carter, LALouisiana Department of Environmental
Quality, Secretary, Ms. Peggy Hatch, LALouisiana State Senate, State Senator,
District 8, Senator John Alario Jr., LA

Louisiana Department of Environmental
Quality, Water Permits Division, Water
Permits Administrator, Mr. Scott
Guilliams, LA

STATE GOVERNMENT OFFICIALS
AND AGENCIES
Coastal Protection and Restoration Authorityof Louisiana, Chairman, Mr. Chip Kline,
LALouisiana Department of Natural Resources
OCM, Coastal Resources Scientist –Permits, Andi Zachary, LA

CoastalProtection
andRestoration
Authority, Attorney, Duncan S. Kemp,
IV, LALouisiana Department of Natural Resources,
Assistant Secretary, Mr. Keith Lovell,LA

CoastalProtection
andRestoration
Authority, General Counsel, David A.
Peterson, LALouisiana Department of Natural Resources,
Coastal Resources Scientist Manager,
Ms. Christine Charrier, LALouisiana Department of Agriculture andForestry, Commissioner, Commissioner
Mike Strain, LALouisiana Department of Natural Resources,
Permits and Mitigation Division,
Administrator, Mr. Karl Morgan, LA
A-5

Louisiana State Police, Troop B,
Commander, Captain Donovan Archote,LA

STATE GOVERNMENT OFFICIALS
AND AGENCIES (CONT’D)Louisiana Department of Natural Resources,
Secretary, Secretary Stephen Chustz, LALouisiana State University Center for Energy
Studies, Executive Director, Dr. David
Dismukes, LALouisiana Department of Transportation andDevelopment, Dr. Secretary, Shawn
Wilson, LALouisiana Workforce Commission, Manager
LMI & BLS Programs at Louisiana
Workforce Commission, Mr. Sachin
Chinatwar, LALouisiana Department of Transportation andDevelopment, Environmental Engineer
Administrator, Noel Ardoin, LALouisiana Workforce Commission, Ms.
Stephanie Moris, LALouisiana Department of Wildlife andFisheries, Biologist Program Manager,
Mr. Kyle Balkum, LALouisiana Workforce Commission/WIOA,
Linda Galloway, LALouisiana Department of Wildlife andFisheries, Secretary, Mr. Robert Barham,
LA

Regional Planning Commission, Executive
Director, Mr. Walter R. Brooks, LALouisiana Department of Wildlife andFisheries, T&E Species, Biologist, Zach
Chain, LALouisiana Department of Environmental
Quality, ec. 401 Water Quality
Certification, Ms. Elizabeth Johnson, LALouisiana Economic Development, Secretaryof Economic Development, Mr. Steven
Grissom, LA

State of Louisiana, Attorney General,
Attorney General Jeff Landry, LA
State of Louisiana, Governor, Governor John
Bel Edwards, LALouisiana
Economic
Development,
Secretary, Mr. Stephen Moret, LA

State of Louisiana, Lieutenant Governor,
Lieutenant Billy Nungesser, LALouisiana Economic Development, SeniorDirector of Business Development, Mr.
Donald Pierson Jr., LA

State of Louisiana, Secretary of State,
Secretary Tom Schedler, LALouisiana Economic Development, Small
Business Development and Community
Services, Director, Mr. Patrick Witty, LA

NATIVE AMERICAN GROUPS
Alabama Coushatta Tribe of Texas, Council
Chairwoman, Chairwoman Nita Battise,
TX

Louisiana Office of State, Fire Marshall’s
Office, State Fire Marshall, Chief, Mr.
Butch Browning, LA

Alabama Coushatta Tribe of Texas, HistoricPreservation Officer, Mr. Bryant
Celestine, TXLouisiana State Police, Command Inspector,
Region II, Major Bryson Williams, LA

A-6

LOCAL GOVERNMENT AGENCIESNATIVE AMERICAN GROUPS(CONT’D)

Belle Chasse Volunteer Fire Department,
District 2, Fire Chief, Chief Roy
Robichaux Jr., LA

Chitimacha Tribe of Louisiana, Chairman,
Chairman John Paul Darden, LA

City of Gretna Police Department, Chief of
Police, Chief Arthur Lawson, LA

Chitimacha Tribe of Louisiana, Tribal
Historic Preservation Officer, Kimberly
S. Walden, LA

City of Gretna Police Department, Deputy
Chief of Police, Deputy Chief Christiana
Anthony, LA

Choctaw Nation of Oklahoma, Chief, Chief
Gary Batton, OK

City of Gretna Volunteer Fire Department,
Fire Chief, Chief Michael Labruzza, LA

Choctaw Nation of Oklahoma, Tribal
Historic Preservation Officer, Dr. Ian
Thompson, OK

City of Gretna, City Clerk, Ms. Norma Cruz,
LA

Coushatta Tribe of Louisiana, Chairman,
Chairman Lovelin Poncho, LA

City of Gretna, District 1, Councilman,
Councilman Milton Crosby, LA

Coushatta Tribe of Louisiana, Tribal HistoricPreservation Officer, Dr. Linda Langley,
LA

City of Gretna, District 2, Councilman,
Councilman Joseph Marino, LA

Jena Band of Choctaw Indians, Chief, Chief
B. Cheryl Smith, LA

City of Gretna, District 3, Councilman,
Councilman Mark Miller, LA

Jena Band of Choctaw Indians, Deputy
THPO, Alina Shively, LA

City of Gretna, District 4, Councilman,
Councilman Jackie Berthelot, LA

Mississippi Band of Choctaw Indians, Chief,
Chief Phyllis J. Anderson, MS

City of Gretna, Mayor Pro-Tem, Councilman
at Large, Councilman Wayne Rau, LA

Mississippi Band of Choctaw Indians, Tribal
Archaeologist, Mr. Ken Carleton, MS

City of Gretna, Mayor, Mayor Belinda
Constant, LA

Tunica-Biloxi Political Action Committee,
Tribal Chairman, Tribal Chairman Joey
P. Barbry, LA

City of Gretna, Planning and Zoning Official,
Ms. Azalea Roussell, LA
City of Gretna, Public Works, Director, Mr.
Danny Lasyone, LA

Tunica-Biloxi Tribe of Louisiana, Tribal
Historic Preservation Officer, Earl J.
Barbry, Jr., LA

Consolidated Recreation & Community
Center and Playground District No. 2, LA
Gretna Economic Development Association,
President, Mr. Anthony Buckley, LA

A-7

Jefferson Parish School Board, LA

LOCAL GOVERNMENT AGENCIES(CONT’D)

Jefferson Parish Streets Department,
Director, Randy Nicholson, LA

Jefferson Parish Drainage Department,
Director, Mitchell T. Theriot, P.E., LA

Jefferson Parish, Council Clerk, Ms. Eula
Lopez, LA

Jefferson Parish Economic Development
Commission, Executive Director, Mr.
Jerry Bologna, LA

Jefferson Parish, District 1, Councilman,
Councilman Ricky Templet, LA

Jefferson Parish Environmental Department,
Kathy Russo, LA

Jefferson Parish, District 2, Councilman Paul
W. Johnston, Councilman, LA

Jefferson Parish Public School Board,
District I, Board Member, Mr. Mark D.
Morgan, LA

Jefferson Parish, District 3, Councilman,
Councilman Mark D. Spears, LA
Jefferson Parish, District 4, Councilman,
Councilman E. “Ben” Zahn, LA

Jefferson Parish Public School Board,
District II, Board Member, Mr. Ricky
Johnson, LA

Jefferson Parish, District 5, Councilwoman,Councilwoman Cynthia Lee-Sheng, LA

Jefferson Parish Public School Board,
District III, Vice President, Mr. Ray St.
Pierre, LA

Jefferson Parish, Division A, Councilman-atLarge, Council Chairman, Councilman
Christopher L. Roberts, LA

Jefferson Parish Public School Board,
District IV, Board Member, Ms. Melinda
Bourgeois, LA

Jefferson Parish, Division B, Councilman-atLarge, Councilman Elton M. Lagasse,LA

Jefferson Parish Public School Board,
District V, President, Mr. Cedric Floyd,LA

Jefferson Parish, Eastbank Consolidated Fire
Department, Fire Department, Director,
Mr. Joseph Greco Sr., LA

Jefferson Parish Public School Board,
District VI, Board Member, Mr. Larry
Dale, LA

Jefferson Parish, Emergency Management,
Director, Mr. Charles Hudson, LA

Jefferson Parish Public School Board,
District VII, Board Member, Ms.
Melinda Doucet, LA

Jefferson Parish, Environmental Affairs,
Director, Ms. Marnie Winter, LA

Jefferson Parish Public School Board,
District VIII, Board Member, Mr. Marion
Bonura, LA

Jefferson Parish, Floodplain Managementand Hazard Mitigation, Director, Ms.
Michelle Gonzales, LA

Jefferson Parish Public School Board,
District XI, Board Member, Ms. Sandy
Denapolis-Bosarge, LA

Jefferson Parish, Parish Attorney, Ms.
Deborah Cunningham Foshee, LA

A-8

Plaquemines Parish School Board, District 6,
Board Member, Ms. Fran BayhiMartinez, LA

LOCAL GOVERNMENT AGENCIES(CONT’D)
Jefferson Parish, Parish President, Parish
President John Young, LA

Plaquemines Parish School Board, District 7,
Board Member, Mr. Carlton LaFrance,LA

Jefferson Parish, Sheriff, Sheriff Newell
Normand, LA

Plaquemines Parish School Board, District 8,
Board Member, Mr. Paul W. Lemaire,LA

Lafitte, Barataria, Crown Point Volunteer
Fire Department, Fire Chief, Chief Linton
Duet, LA

Plaquemines Parish School Board, District 9,
Board Member, Mr. Chuck Soileau, LA

Lake Hermitage Volunteer Fire Department,
District 6, Fire Chief, Chief Donald Durr,
LA

Plaquemines Parish School Board, LA
Plaquemines Parish School Board, Sharon
Zilucca, LA

Marrero-Estelle Volunteer Fire Department,
Fire Chief, Deputy Chief Blake Hunter,LA
New Orleans District
Transportation, LA

Department

Plaquemines Parish, Clerk of Court, Ms.
Dorothy Lundin, LA

ofPlaquemines Parish, Director of Coastal
Restoration, Mr. Vincent W. Frelich, LA

Plaquemines Department of Transportation,
Land Superintendent, Blair Rittiner, LA
Plaquemines Parish
Rittiner, LA

Government,

Plaquemines Parish, Director of Economic
Development and Tourism, Mr. Stan
Mathes, LA

Blair

Plaquemines Parish, Director of Operations,Mr. Stanley Wallace, LA

Plaquemines Parish Government, LA
Plaquemines Parish School Board, District 1,
Board Member, Ms. Jan Morgan, LA

Plaquemines Parish, District 1, Council
Member, Councilman John Barthelemy,
LA

Plaquemines Parish School Board, District 2,
Board Member, Mr. Daniel Morrill, LA

Plaquemines Parish, District 2, Council
Member, Councilman Beau Black, LA

Plaquemines Parish School Board, District 3,
Board Member, Mr. Corey Arbourgh, LA

Plaquemines Parish, District 3, Council
Member, Councilman Kirk Lepine, LA

Plaquemines Parish School Board, District 4,
Board Member, Ms. Joyce Lamkin, LA

Plaquemines Parish, District 4, Council
Member, Councilman Irvin Juneau, LA

Plaquemines Parish School Board, District 5,
Board Member, Ms. Shayne Meyers, LA

A-9

LOCAL GOVERNMENT AGENCIES(CONT’D)

Town of Jean Lafitte, Councilman, Mr. Barry
Bartholomew, LA

Plaquemines Parish, District 5, Council
Chairman, Chairman Benny Rousselle,LA

Town of Jean Lafitte, Councilwoman,Councilman Verna Smith, LA
Town of Jean Lafitte, Councilwoman,Councilwoman Christy Creppel, LA

Plaquemines Parish, District 6, Council
Member, Councilman Charlie Burt, LA

Town of Jean Lafitte, Councilwoman,Councilwoman Shirley Guillie, LA

Plaquemines Parish, District 7, Council
Member,Councilwoman
AudreyTrufant-Salvant, LA

Town of Lafitte, Mayor, Mayor Timothy
Kerner, LA

Plaquemines Parish, District 8, Council
Member, Councilman Jeff Edgecombe,
LA

LIBRARIES
Jefferson Parish Library, Library Director,
Ms. Marilyn Haddican, LA

Plaquemines Parish, District 9, Council
Member, Councilwoman Nicole Smith
Williams, LA

Lafitte Library, LA
Library Director, Gretna Public Library, LA

Plaquemines Parish, Homeland Security andEmergency Preparedness, Director, Mr.
Guy Laigast, LA

Plaquemines Parish Library, Assistant
Director, Ms. Patricia Walker, LA

Plaquemines Parish, Mr. District Attorney,
Charles Ballay, LA

NON-PROFIT ORGANIZATIONSPlaquemines Parish, Parish President, Parish
President Amos Cormier Jr., LA

Center for Human-Environmental Research,
Rusty Graves, LA

Plaquemines Parish, Sheriff, Sheriff Lonnie
Greco Sr., LA

MEDIA
The Plaquemines Gazette, Public Notices,
Shanice Mack, LA

Plaquemines Port Harbor & Terminal
District, LA

COMPANIES AND ORGANIZATIONS

St. Charles Parish, District IV Councilman,
Paul Hogan, LA

A/C Heating & Plumbing Inc Domino’s, LA
America’s Natural Gas Alliance, Mr. Charlie
Riedl, DC

Town of Jean Lafitte, Chief of Police, Chief
Marcell Rodriguez, LA

American Petroleum Institute,Counsel, Mr. Ben Norris, DC

Town of Jean Lafitte, Councilman,
Councilman, Calvin LeBeau, LA

SeniorApache Louisiana Minerals LLC, Timothy
Allen, LA
A-10

COMPANIES AND ORGANIZATIONS(CONT’D)

Jefferson Homeowners Association, Mr.
Lawrence Caillouet, LA

Apache Louisiana Minerals LLC, TX

Jefferson Parish Farm Bureau, Parish
President, Mr. Bruce Kennair, LA

Associated Branch Pilots, President, Captain
Mike Lorino, LALouisiana Land & Exploration Co, Ashley
Golmon, LA

Bear Associates Inc., LA
Louisiana Land & Exploration Co, c/o
Conoco Phillips, TX

Belle Chasse Marine Transportation, LA
BNB Partners LLC, LALouisiana Oil and Gas Association, Assistantto the President, Ms. CeCe Richter, LA

Bradish-Johnson Co Ltd, c/o Camilla Jones
Strachan, Gen Manager, LALouisiana Oil and Gas Association, Vice
President, Mr. Gifford Briggs, LA

Buras Levee District, LA

MCMK LLC, LA

Colmac Corp, LA

New City Co, LA

Crescent River Port Pilots Association,
Captain, Captain Allen “A.J.” Gibbs, LA

New Orleans Baton Rouge Steamship Pilots
Association, Captain, Captain Steve
Hawthorne, LA

Defelice Land Co., LLC, c/o Ronald H.
Kilgen, Ph.D., LA

Phillips 66 Co, PTRRC, OK

Entergy Louisiana Properties LLC, Mail Unit
L-ENT-12B, LA

Plaquemines Association of Business &Industry, Chair, Ms. Denise Buford, LA

ESC Properties LLC, LA

Plaquemines Association of Business &Industry, Executive Director, Mr. Bobby
Thomas, LA

Gene H. Koss LLC, LA
Go Do Your Business LLC, LA
Hero Lands Co, LA

Plaquemines Parish Canal Co, c/o Camilla
Jones Strachan, Gen Manager, LA

Hero Wall Co, LA

Plaquemines Parish Farm Bureau, LA

Industrial Pipe Inc, LA

Plaquemines Port, Deputy Port Director, Mr.
Paul Matthews, LAInternational Marine Terminals, LA
Jefferson Business Council,
Director, Mr. Tony Ligi, LA

Plaquemines Port, Executive Director, Mr.
Maynard Jackson (Sandy) Sanders, LA

Executive

Plaquemines Port, Port Security and Vessels,
Director, Mr. Donald Durr, LA

Jefferson Chamber of Commerce, Mr. Todd
Murphy, President, LA

A-11

Barbara E. Comeaux, LA

COMPANIES AND ORGANIZATIONS(CONT’D)

Benedict Rousselle, LA
Ridgeland Properties LLC, LA
Bernard J. Graf, LARiver Rest LLC, LA
Betty A. Kuehne, LA
Rotary Club of West Bank/Gretna, President,
Mr. Tony Sciacca, LA

Beverly Palmisano, LA
Beverly S. Jarvis, LA

Southwest Louisiana Association of Realtors,
CEO, Ms. Lisa Verrette, LA

Bonnie T. Hinyup, LA

Springwood
Estates
Homeowners
Association, President, Mr. Shawn Coco,LA

Bonnie Tonglet, LA
Brian H. Anderson, LA

Stone Energy Corp, LA

Brian K. Falgout, LA

Stonebridge Property Owners Association,
President, Ms. Suzanne Farrar, LA

Bruce M. Comeaux, LA
Bryan A. Ragas, LA

Tennessee Gas Pipeline Co, Property Tax
Dept, TX

Bryan S. Fisher, LA

The Parks of Plaquemines Homeowners
Association, LA

Carey A. Borgeois, LA
Carol Gaudet, LA

United Bulk Terminals Davant LLC, c/o
Tracy Ohmart, TX

Carol P. Riley, LA

Warves & Docks Co LLC, LA

Carolyn Willhoft, LA

William (Billy) Nungesser, Duckland LLC,LA

Celeste D. Ancar, LACharles Iv Andres, LA

Woodland Borrow Pits LLC, LA

Charles Jones, TX

Woodland Borrow Pits, LLC, Phyllis Adams,
LACharles R. Falcone, Jr., LA

INDIVIDUALS

Cheryl D. Entwisle, LA

Adah J. Watt, c/o William G Christian Jr., TX

Christie Nielsen, LA

Alfred J. Rousselle, Jr., LA

Clayton P. Hinyup, Jr., LA

Ann M. Jeanfreau, LA

Clint E & Reine, c/o Craig A Reine, LA

A-12

INDIVIDUALS (CONT’D)

Ellied P. Riley Jr., LA

Connely J. Wright, LA

Eric J. Paolini & Melissa A. M. Paolini, LA

Constance Meyer, LA

Errance Plaisance, LA

Cynthia C. Caster, LA

Etole C. Furrow Estate, LA

Cynthia L. Lawson, LA

Evelyn Edwards, LA

Daniel E. Levasseur, LA

Foster Creppel, LA

Daniel T Carroll, c/o Lisa Voisin Carroll, VAFrank A. Trapani, LA

Danny Trusclair, LA

Frank R. Penton, LA

Darrell J. Behre, LA

Frederick G. Willhoft Jr., LA

Darrella A. Jordan & Katherine Jordan
Revocable Living Trust, LA

Frederick H Jr Gondrella, LA
Gail D. Penton, LA

David A. Atkinson et al, LA
Genice R. Rivit, c/o Mary Ann Matherne, LADavid F Hardesty, KY
Gerard J. Tonglet Jr., LA
David Cole Bostrom-Wilson, c/o Cindy Ann
Loup, LA

Gills Parria, Sr, LA

David E. Banks III & Sandra G. Banks, LA

Gladys B. Allen, LA

David M. Wooton, LA

Gordon V. Rojas, LA

Dian B. Campbell, LA

Grant M. Gaudet, LA

Dill Family Trust Dated December 4, 2009,
LA

Greg Beuerman, LA
Greg Fell, LA

Don C. Adams, LA
Donna H. Comeaux, LA

Gretchen L Lopez,
Lachmann, LA

c/oDouglas M. Lanasa, Jr., LA

Guy J. Allen, LA

Edward Flanagan, Jr., c/o Clayton P. Hinyup,
Jr. & Julie A. Hinyup, LA

H. H. Harvey, Et Al, Attn: Clarke J Gernon
Sr, Harvey Heirs Family Representative,LA

Elaine P. Trapani, LA
Helena Bieber Mollo, LA
Eleanor Coman, LA

A-13

JanethGaile

INDIVIDUALS (CONT’D)

Jonathan M. Hymel, LA

Henry J. McAnespy, LA

Judith B. Exsterstein, LA

Henry McAnespy, LA

Julie H. Hinyup, LA

Iris Mae E. Rojas, LA

Junius Plaisance, MS

Jack W Sr & Lisa L & Comeaux, c/o Patricia
C Jefferson, LA

Justin Casey, FL
Karen Bonvillian, LA

Jacob Brand, LA
Karen S. Des Roches, LA
James C. Holbrook Jr., LA
Katherine B. May, LA
James D. Jarvis, LA
Katie S. Daigle Et Al, GA
James L. Drachenberg, c/o Robert A. Pitre
Jr., LA

Kay L. Joyner, LA
Keith E. May, LA

James L. Toca, III Estate, Attn: Timothy M.
Duncan, LA

Kelli S. Morris, LA

James P. Rojas, LA

Kenneth J. Morrison, LA

James W. Crawford, LA

Kenneth P Morrison, LA

James Wason, LA

Kevin M. Horner, LA

Janeth Gaile Lachmann, LA

Laddis M. Hinyup, LA

Jeffrey G. Kiefer, LA

Larry A. Pizani, c/o Annette Pizani, LA

Joel Frederick, LA

Larry T. Ancar, LAJohn E & Kimberly RauchJohn E. Hourcade, Jr., LA

Lena L. B. R. Curol, Et Al, c/o Mrs John A.
Rojas, Sr, LAJohn N & Carolyn T Guidry, LA

Lenora Levasseur, LAJohn R. Coman, Jr., LA

Leon Rojas Est, Et Al, c/o Wayne J. Nolan,
LAJohn Rojas, Et Al, c/o Andrew Nolan, LA
Linda Johnson, LA
John Thornton, LA
Linda Rousselle, LAJohn Wisniewski, VALouis E. Mcanespy, LA

A-14

INDIVIDUALS (CONT’D)

Nancy K. Juge, LA

Loycel A. Morvant, LA

Ned Randolph, LA

Lucien A. Jeanfreau, LA

Numa C. Hero & Son, LA

Lynn P. Perez, c/o United Bulk Terminal
Devant LLC, TX

Pamela A. Adams, LA
Pamela Plaisance, MS

Madelyn M. O’Donohue, MS
Patricia S. Wright, LAMark E. Comeaux, LAPaul J. Von Bodungen, LA
Mary Nell B Poole, LA
Paul Matthews, LA
Matthew Wall, LA
Peter R. Monrose et al, c/o Marcy Monrose,LA

Maude L. Mann, c/o David M Hunter, Jones
Walker, LA

Philip, Salvadore & Carolyn T St, LA
Maunsel Hickey, Maunsel White Sr. Heirs etal, FL

Rachel M. Jones, TX

May Nguyen, LA

Ray T. Johnson, LA

Melanie C. Horner, LA

Richard A. Juge, LA

Michael A. Entwisle, LA

Richard C & Boni P Palazzo, LA

Michael Boyle, VA

Richard E. Waldner, LA

Michael C. Kuehne, LA

Robert D. Wilson Jr., LA

Michael W & Helms, c/o Stephen Helms, TX

Robert J. O’Donohue III, MS

Mike Gartman, FL

Richard Leonhard, LA

Mike Kuehne, LA

Richie Blink, LA

Mildred R. Collins Est, c/o Carl Navarre, Jr.,LA

Robert L. Seals, LA

Miriam Blanchard
Schindler, LAPowers,c/oRobert S. Campbell, LA

Kaia

Roberta L. Beaver, LA

Morgan M. Perrin Jr., LA

Rodney J. Barthelemy, LA

Murray Stabol, TX

Rodney J. Bonvillian, LA
Roland J. Melancon, III, LA
A-15

INDIVIDUALS (CONT’D)

Tuan Q. Nguyen, LA

Ross M. Easley, LA

Verda A. Anderson, LA

Russell A. Easley, LA

Wade T. Des Roches, LA

Sandra B. Chauvin, LA

Wayne P. Perrin, LA

Sarah V. Levron, LA

W. Beau Black, LA

Scott Eustis, LA

Wilbert J. Levron, LA

Shawn E Townsend, LA

William A & Kathy N Lutz, LA

Sidney D Bieber Jr, LA

William Caster Sr., LA

Stanley Hebert, LA

William E. Adam, c/o Adelaide Fabre, LA

Stanley J Jr & Kimberly M Holliday, LA

William K. Bergeron, LA

Stephen C. Hourcade, LA

Zane G. Elliott, LA

Sterling P. Chauvin, III, LA

George Howard, NC

Sterling P. Chauvin, Jr., LA

Rick Clute, IL

Steve C. Small, LA

Rev. Tyronne Edwards, LA

Steven Armstrong, LA

Jason Placke, LA

Susan L. Murrell, LA
Tammy C. Graf, LA
The Estate of Isidore Antoine, c/o Mary Roth,LA
The Living Trust of Hugh R & Evelyn
Revocable Babylon, LA
Timothy P. Gaudet, Jr., LA
Tracy C. Orvis, LA
Trang T. Pham, TN
Troy D. Borgeois, LA
Trudy Newberry, LA

A-16

APPENDIX B
FIGURES
Figure B-1 - Proposed Workspace Layout at Terminal Site (Aerial Map)
Figure B-2a - Terminal Site Alternatives Mississippi River Mile 56 Site
Figure B-2b - Terminal Site Alternatives Mississippi River Mile 55 Site - East Bank
Figure B-2d -Terminal Site Alternatives Cutrone Property Site
Figure B-2e - Terminal Site Alternatives Carlyss I Site
Figure B-2f - Terminal Site Alternatives Carlyss II Site
Figure B-3 -Alternative Pipeline Routes
Figure B-4 - Oil and Gas Fields in the Project Vicinity
Figure B-5 - Oil and Gas Wells Within 0.25 mile of the Project
Figure B-6a - Field Delineated Wetlands and Waterbodies at the Terminal Site
Figure B-6b - Overview of Field Delineated Wetlands and Waterbodies Crossed by the
Proposed Pipeline System
Figure B-6c through B-6w - Field Delineated Wetlands and Waterbodies Crossed by the
Proposed Pipeline System
Figure B-7 - Socioeconomic Study Area and Overview
Figure B-8 - Plaquemines Parish Census Tracts
Figure B-9 - Noise-Sensitive Areas within 0.5 mile of Terminal Site
Figure B-10 - Noise-Sensitive Areas within 0.5 mile of Proposed Pipline System(Topographic Map)

This information is for environmental review purposes only.

Louisiana!

!

Terminal Site Boundary

MarineEastern Workspace

Facilities ...........

Floodwall
Terminal Site - Terminal
Facilities

No Impact Area
Area Not Being Used
Phase 1/2 Workspace

Eastern Workspace
Temporary Workspace

No Impact Area- SH 23
Federal Levee

Marine Workspace
Easement Area in SH23

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR01\_Plaquemines_RR01_1_3_13.mxd | REVISED: 02/14/2017 | SCALE: 1:12,000 when printed at 11x17

1:12,000
0

500

q

1,000
Feet

Gulf of Mexico

Figure B-1
Proposed Workspace Layout at Terminal Site (Aerial Map)
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
DRAWN BY: JSnyder

Carlyss II// Carlyss I

MS 56

Proposed Terminal Site

//

MS 55

_
^

/

CutroneProperty/

Louisiana

Alternative Sites

MS 55 = Mississippi River Mile 55 Site
MS 56 = Mississippi River Mile 56 Site0

1:1,468,419
20

p

40
Miles

Figure B-2a
Terminal Site Alternatives
Overview
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR10\_Plaquemines_RR10_5_1_1_Overview.mxd | REVISED: 02/17/2017 | SCALE: 1:1,468,419 when printed at 11x17

DRAWN BY: GISMississippi
River Mile
56 Site

1:24,000Louisiana
0

1,000

p

2,000
Feet

Figure B-2b
Terminal Site Alternatives
Mississippi River Mile 56 Site
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR10\_Plaquemines_RR10_5_1_1.mxd | REVISED: 02/17/2017 | SCALE: 1:24,000 when printed at 11x17

DRAWN BY: GISMississippi River
Mile 55 Site
- East Bank

1:24,000Louisiana
0

1,000

p

2,000
Feet

Figure B-3c
Terminal Site Alternatives
Mississippi River Mile 55 Site - East Bank
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR10\_Plaquemines_RR10_5_1_1.mxd | REVISED: 02/17/2017 | SCALE: 1:24,000 when printed at 11x17

DRAWN BY: GIS

Cutrone
Property
Site

1:24,000Louisiana
0

1,000

p

2,000
Feet

Figure B-2d
Terminal Site Alternatives
Cutrone Property Site
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR10\_Plaquemines_RR10_5_1_1.mxd | REVISED: 02/17/2017 | SCALE: 1:24,000 when printed at 11x17

DRAWN BY: GIS

Carlyss
I Site1:24,000Louisiana
0

1,000

p

2,000
Feet

Figure B-2e
Terminal Site Alternatives
Carlyss I Site
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR10\_Plaquemines_RR10_5_1_1.mxd | REVISED: 02/17/2017 | SCALE: 1:24,000 when printed at 11x17

DRAWN BY: GIS

Carlyss
II Site

1:24,000Louisiana
0

1,000

p

2,000
Feet

Figure B-2f
Terminal Site Alternatives
Carlyss II Site
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR10\_Plaquemines_RR10_5_1_1.mxd | REVISED: 02/17/2017 | SCALE: 1:24,000 when printed at 11x17

DRAWN BY: GIS

Bridgeline
Holdings
Interconnect

Louisiana.
!

No rthw est Lateral
Pi
p el
i
n eRo ute

High Point
Interconnect.
!

So utheast Lateral
Pi
p el
i
n eRo ute

SW Lateral
TETCO
-Al
tern ati
ve1

Tennessee Gas
Pipeline Company. Interconnect!

SW Lateral
TETCO-Pro p o sedRo ute

SW Lateral
TGP-Pro p o sedRo ute

Texas Eastern
Transmission
Interconnect !
.

p0

SW Lateral
TETCO
-Al
tern ati
ve2

2

!
.

Texas Eastern !
.
Transmission
Proposed
Interconnect
TETCO
Interconnect!
. Proposed TGP
Interconnect

4

Mi
l
es

T
ermi
n alSiteBo un dary
SW LateralTETCO –Pro p o sedRo ute
SW LateralTGP–
Pro p o sedRo ute

No rthw estLateral
Pi
p el
i
n eRo ute

This information is for environmental review purposes only.

SW LateralTETCO
Al
tern ati
ve1
SW LateralTETCO
Al
tern ati
ve2
So utheastLateral
Pi
p el
i
n eRo ute!
.
.
!

Pro p o sedIn terco n n ect
an dMeter StationAltern ativeI
n terco n n ect
an dMeter Station

Figure B-3
Alternative Pipeline Routes

Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

M:
\
Cl
i
en ts\VX\
VGL\
Pl
aq uemin es\_ArcGIS\_Reso urc
eRep o rts\
RR10\
_Pl
aq uemin es_RR10_5_3_1.
mx
d |REVI
SED:02/17/2017 |SCALE:1:
253,
440

DRAWNBY :GI
S

St.
BernardBAYOU
GENTILLY

St. Bernard

St. Bernard

St. Charles

LAKE
SALVADOR,NORTHEAST

St. Bernard

SPANISH LAKE

BARATARIA
BARATARIA,
WEST

St. Bernard

LAKE PETITBAYOU DEFLEUR

BARATARIA,
SOUTH
BAYOU PEROTBAYOU DE
FLEUR,
SOUTH

CROOKED BAYOUSPANISH
LAKE,
SOUTH

ALLIANCE

LAKE
CALEBASSE

DELACROIXISLANDLAKE
FORTUNA

LAKE CAMPOPHOENIXDELTA FARMSDELTAFARMS, WEST

Plaquemines LNG and
Gator Express Pipeline
Project Location

Plaquemines

MAIN PASSBLOCK 12

BLACK
BAY,
NORTH

POINTE A
LA HACHE

Jefferson

BLACK
BAY,
WEST

LAFITTELITTLE TEMPLEDIAMONDBLACK BAY

BOHEMIA

Jefferson

LITTLE LAKEMC CALLSISLAND

Jefferson

THREE
BAYOU BAY

LAKE HERMITAGE
SL 707MAGNOLIA
CLAM BAY
LONG BAY

HAPPY JACKPELICAN POINT

Jefferson

POTASH
LITTLE LAKE,
SOUTH
PLUM POINT

CLOVELLY

MANILAVILLAGE

COX BAY
MANILAVILLAGE,SOUTHEAST

Jefferson
Lafourche

BAY BATISTE

Lafourche Lafourche
TETCO
Interconnect !
.

Jefferson

KINGS RIDGESATURDAY SATURDAY
ISLAND,ISLANDWEST

COFFEE BAY

SL 21423

NAIRN
TGPInterconnect!
.

Jefferson

BAYOU RAPHAELEMPIREBAY DE CHENE
GOLDENMEADOW,
EAST
Terminal Site Boundary
Eastern Workspace
Louisiana

LAKE
WASHINGTON
Plaquemines!
.

Interconnect
Active Mineral Lease
1:190,080

SW Lateral TETCOSW Lateral TGP

0

1.5

3

p

Gulf of Mexico

ADAMS BAY

QUARANTINE
BAY, SOUTH

This information is for environmental review purposes only.

Figure B-4
Oil and Gas Fields in the Project Vicinity

Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

Miles

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR06\_Plaquemines_RR06_3_1.mxd | REVISED: 01/20/2017 | SCALE: 1:190,080 when printed at 11x17

DRAWN BY: JMS

Plaquemines LNG and
Gator Express Pipeline
Project Location

/ /
/
//

/

TETCO
Interconnect !
.
/TGPInterconnect!
.

This information is for environmental review purposes only.

Terminal Site Boundary!
.

Interconnect

SW Lateral TETCO/

Oil and Gas Well with Well Pit

Eastern Workspace

Louisiana

SW Lateral TGP

Oil and Gas Well

1:126,720
0

1

2

Miles

p

Louisiana Department of Natural Resources. 2014. Strategic Online Natural Resources Information System Oil/Gas Wells Data Layer.
Available online at: http://sonris-www.dnr.state.la.us/gis/agsweb/IE/JSViewer/index.html?TemplateID=181. Accessed December 2014.

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR06\_Plaquemines_RR06_3_2.mxd | REVISED: 01/23/2017 | SCALE: 1:126,720 when printed at 11x17

Gulf of
MexicoFigure B-5
Oil and Gas Wells Within 0.25 mile of the Project
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

DRAWN BY: JSnyder

Mi

ss

is

si

pp

i R
iv
e

r

Delineated PEM Wetland
Delineated PFO Wetland
Delineated Waterbody
This information is for environmental review purposes only.

Terminal Site Boundary
Deer Range Davant_^

Eastern Workspace_^

1:18,000
0

750

p

1,500
Feet

Figure B-6a
Field Delineated Wetlands and Waterbodies
at the Terminal Site
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_3_Terminal.mxd | REVISED: 02/13/2017 | SCALE: 1:18,000

DRAWN BY: TG

SW TGP 14

SW TGP 13

Barge 5Barge
6SW TGP 12

Barge 7

SW TGP 11

SW TGP 10
Barge 4
SW TGP 9

Sheet
SW TGP 1
SW TGP 2
SW TGP 3
SW TGP 4
SW TGP 5
SW TGP 6
SW TGP 7
SW TGP 8
SW TGP 9
SW TGP 10
SW TGP 11
SW TGP 12
SW TGP 13
SW TGP 14

SW TGP 8

SW TGP 7

SW TGP 6
Barge
3

Barge
2
Barge 1SW TGP 4

!
.

MP In
0.0
0.3
1.1
2.0
2.8
4.0
5.4
6.7
8.1
9.3
10.5
11.8
13.1
13.8

MP Out
0.7
1.6
2.5
4.0
4.3
5.6
6.9
8.1
9.5
10.8
12.1
13.4
14.7
15.1

TETCO

SW TGP 5
TGP!
.

SW TGP 3
SW TGP 2

SW TGP 1

Louisiana

This information is for environmental review purposes only.

Terminal Site Boundary

Sheet

Eastern Workspace

Barge Access Channels

SW Lateral TETCO

1:75,000

SW Lateral TGP!
. Interconnect and Meter Station

0

0.5

p
1
Miles

Figure B-6b

Overview of Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System Plaquemines
LNG and Gator Express Pipeline Project Plaquemines
Parish, Louisiana
Sheet Index

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW_Overview.mxd | REVISED: 02/17/2017 | SCALE: 1:75,000 when printed at 11x17

DRAWN BY: GIS

WBB000

MP 0.5/

MP 0.4/

MP 0.3

Barg
e Ac
ce ss

/

Cha

MP 0.2nnel/3
MP 0.1
/

TGP
/
!
.
MP 0

WBB000This information is for environmental review purposes only.

/!
.

TGP Lateral Milepost

Meter Station

SW Lateral TGP

Delineated Waterbody

Barge Access Channel
Interconnect and Meter Station
1:6,000

Temporary Workspace
Permanent Easement

0

250

p

500
Feet

Figure B-6c

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 1 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

MP 1.4/

MP 1.3/

MP 1.2/

MP 1.1

WBB000/

MP 1/

MP 0.9
/

Barg
e Ac
ce ss

MP 0.8

Cha

/

nne
l

3

MP 0.7/

MP 0.6/

MP 0.5/

WBB000This information is for environmental review purposes only.

/

TGP Lateral Milepost
SW Lateral TGP
Barge Access Channel
Temporary Workspace
1:6,000

Permanent Easement
Delineated Waterbody

0

250

p

500
Feet

Figure B-6d

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 2 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

MP 2.2/

MP 2.1/

MP 2/

MP 1.9/MP 1.8WBB000

/

Barg
e Ac
ce ss

MP 1.7
/

Cha

nne
l

MP 1.63/

MP 1.5/

MP 1.4/

WBB000This information is for environmental review purposes only.

/

TGP Lateral Milepost
SW Lateral TGP
Barge Access Channel
Temporary Workspace
1:6,000

Permanent Easement
Delineated Waterbody

0

250

p

500
Feet

Figure B-6e

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 3 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

MP 3
/

MP 2.9/MP 2.8/WBB000MP 2.7/

MP 2.6/

MP 2.5

Barg
e Ac
ce ss

/

Cha

MP 2.4nnel/

3
MP 2.3/MP 2.2/MP 2.1/

WBB000This information is for environmental review purposes only.

/

TGP Lateral Milepost
SW Lateral TGP
Barge Access Channel
Temporary Workspace
1:6,000

Permanent Easement
Delineated Waterbody

0

250

p

500
Feet

Figure B-6f

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 4 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

//

MP 4.2
MP 0.8//MP 4.1

MP 0.7 //MP 4

MP 0.6 //MP 3.9MP 0.5 //MP 3.8MP 0.4 //WBB000MP 3.7

MP 0.3 //MP 0.2MP 3.6/

WBB000

Bar

ge A
cce
ss

/

/

MP 0.1

Cha

nne
l

1

MP 0 /!
.

MP 3.5

MP 3.4/TETCO
MP 3.3/

WBB000

WBB000MP 3.2/MP 3.1
/

MP 3

/

Barg
e Ac
ce ss

Cha

nne
l

3

This information is for environmental review purposes only.

/

TETCO Lateral Milepost

Temporary Workspace/

TGP Lateral Milepost

Permanent Easement

SW Lateral TETCOSW Lateral TGP

Meter Station
Delineated Waterbody
1:6,000

Barge Access Channel!
.

Interconnect and Meter Station

0

250

p

500
Feet

Figure B-6g

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 5 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

MP 2.2 // MP 5.5

MP 2.1// MP 5.4

MP 2 // MP 5.3

MP 1.9 // MP 5.2

MP 1.8 // MP 5.1

MP 1.7 // MP 5

WBB000MP 1.6 // MP 4.9

MP 1.5 // MP 4.8

MP 1.4 // MP 4.7

MP 1.3 // MP 4.6

MP 1.2 // MP 4.5

MP 1.1 /

/

MP 1

/

MP 4.4/MP 4.3

MP 0.9 //MP 4.2

MP 0.8 /This information is for environmental review purposes only.

/

TETCO Lateral Milepost/

TGP Lateral Milepost

Delineated Waterbody

SW Lateral TETCOSW Lateral TGP
1:6,000

Temporary Workspace
Permanent Easement

0

250

p

500
Feet

Figure B-6h

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 6 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

MP 3.5// MP 6.8

MP 3.4 // MP 6.7

MP 3.3 // MP 6.6

MP 3.2 // MP 6.5

MP 3.1 //MP 3

MP 6.4// MP 6.3

MP 2.9 /WBB000/ MP 6.2

MP 2.8// MP 6.1

MP 2.7 // MP 6

MP 2.6 //MP 5.9MP 2.5 // MP 5.8

MP 2.4 //MP 2.3MP 5.7// MP 5.6

MP 2.2 // MP 5.5

This information is for environmental review purposes only.

/

TETCO Lateral Milepost

Permanent Easement/

TGP Lateral Milepost

Delineated Waterbody

SW Lateral TETCOSW Lateral TGP
1:6,000

ATWS
Temporary Workspace

0

250

p

500
Feet

/

Figure B-6i

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 7 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

/ MP 8.1

MP 4.7 // MP 8MP 4.6 // MP 7.9

MP 4.5 // MP 7.8

MP 4.4 // MP 7.7

MP 4.3 // MP 7.6

MP 4.2 // MP 7.5

MP 4.1 // MP 7.4

WBB000MP 4 // MP 7.3

MP 3.9 // MP 7.2

MP 3.8// MP 7.1

MP 3.7 // MP 7

MP 3.6 // MP 6.9

MP 3.5 // MP 6.8

MP 3.4/TETCO Lateral Milepost

Permanent Easement/

TGP Lateral Milepost

Delineated Waterbody

SW Lateral TETCOSW Lateral TGP
1:6,000

ATWS
Temporary Workspace

0

250

p

500
Feet

/
This information is for environmental review purposes only.

Figure B-6j

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 8 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

MP 6.1// MP 9.4

MP 6 // MP 9.3

WBB000MP 5.9 // MP 9.2

MP 5.8 /wlb007e/ MP 9.1

wlb007eMP 5.7 // MP 9MP 5.6 // MP 8.9

wlb007eMP 5.5 // MP 8.8

MP 5.4 // MP 8.7

MP 5.3 // MP 8.6

MP 5.2 // MP 8.5

MP 5.1 // MP 8.4

WBB000MP 5 // MP 8.3

MP 4.9 // MP 8.2

MP 4.8 // MP 8.1
This information is for environmental review purposes only.

/

TETCO Lateral Milepost

Permanent Easement/

TGP Lateral Milepost

Delineated E2EM Wetland

SW Lateral TETCOSW Lateral TGP

Delineated Waterbody
1:6,000

ATWS
Temporary Workspace

0

250

p

500
Feet

Figure B-6k

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 9 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

/ MP 10.7

wlb010e
MP 7.3 //MP 10.6

MP 7.2 // MP 10.5

MP 7.1 /wlb010e/ MP 10.4

MP 7 //MP 10.3

MP 6.9 // MP 10.2

MP 6.8 // MP 10.1

MP 6.7 // MP 10

WBB000MP 6.6 // MP 9.9

MP 6.5 // MP 9.8

MP 6.4 // MP 9.7

MP 6.3 // MP 9.6

MP 6.2 // MP 9.5

MP 6.1 // MP 9.4

MP 6 /

This information is for environmental review purposes only.

//

TETCO Lateral Milepost

Delineated E2EM Wetland/

TGP Lateral Milepost

Delineated Waterbody

SW Lateral TETCOSW Lateral TGP
1:6,000

Temporary Workspace
Permanent Easement

0

250

p

500
Feet

Figure B-6l

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 10 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

wlb004e/

MP 12

MP 8.6 /WBB000wlb004s
wlb004e/ MP 11.9

MP 8.5 // MP 11.8

MP 8.4 // MP 11.7

MP 8.3 /wlb004e

WBB000/MP 11.6

MP 8.2 // MP 11.5

eA
rg
Ba

MP 8.1 /sC
escc

WBB0002elnnha/ MP 11.4

MP 8 /

wlb004e/ MP 11.3

MP 7.9 //WBB000MP 11.2

MP 7.8 // MP 11.1

MP 7.7 // MP 11

MP 7.6 // MP 10.9

MP 7.5 // MP 10.8

wlb010e
MP 7.4 // MP 10.7

MP 7.3 /This information is for environmental review purposes only.

/

TETCO Lateral Milepost

Temporary Workspace/

TGP Lateral Milepost

Permanent Easement

SW Lateral TETCOSW Lateral TGP

Delineated E2SS Wetland
Delineated E2EM Wetland

Barge Access Channel

Delineated Waterbody

ATWS

1:6,000
0

250

p

500
Feet

Figure B-6m

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline
Project Plaquemines Parish, Louisiana
Sheet 11 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

/ MP 13.3

MP 9.9 /WBB000wlb004e

WBB000/ MP 13.2

WBB000wlb004eMP 9.8 /wlb004e/ MP 13.1

MP 9.7 /wlb004e/ MP 13

MP 9.6 // MP 12.9

MP 9.5 /wlb004e

WBB000/ MP 12.8

MP 9.4 /wlb004e

wlb004e/ MP 12.7

WBB000MP 9.3 // MP 12.6

MP 9.2 /WBB000wlb004e/ MP 12.5

MP 9.1 /WBB000/ MP 12.4

MP 9 /
wlb004e/ MP 12.3

WBB000MP 8.9 // MP 12.2

MP 8.8 /wlb004e/ MP 12.1

WBB000MP 8.7 // MP 12wlb004s
wlb004eMP 8.6 /wlb004e/ MP 11.9/

TETCO Lateral Milepost

Delineated E2SS Wetland/

TGP Lateral Milepost

Delineated E2EM Wetland

SW Lateral TETCOSW Lateral TGP

Delineated Waterbody

This information is for environmental review purposes only.

1:6,000

Temporary Workspace
Permanent Easement

0

250

p

500
Feet

Figure B-6n

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 12 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

MP 11.3 /wbb016/ MP 14.6

MP 11.2

wla017s/

wlb003e/MP 14.5
MP 11.1/

wlb009s

wlb003s/

MP 14.4

wlb002s

MP 11

wlb003s//

MP 14.3
wlb002e
MP 10.9 /WBB000/ MP 14.2

wlb002s
MP 10.8 /wlb003e
wlb003s

wlb002e
wlb003s/ MP 14.1

wlb002e
MP 10.7 /WBB000wlb002s

wlb001e
MP 10.6 /wlb002s

ag e R d

wlb004e/ MP 13.9

La ke H er m it

/ MP 14

MP 10.5 // MP 13.8

MP 10.4 /wlb001e
wlb004e/ MP 13.7

MP 10.3 // MP 13.6

wlb008e
MP 10.2 /WBB000/ MP 13.5

wlb008e

MP 10.1 /wlb004e/ MP 13.4

wlb004e
MP 10 /

/ MP 13.3

MP 9.9 /wlb004e
WBB000/ MP 13.2

wlb004eMP 9.8 /This information is for environmental review purposes only.

/

TETCO Lateral Milepost

Permanent Easement

Delineated E2EM Wetland/

TGP Lateral Milepost

Main Line Block Valve Site

Delineated Waterbody

SW Lateral TETCOPermanent Access RoadSW Lateral TGP

Temporary Access Road

ATWS

Delineated E2SS Wetland

Temporary Workspace

Delineated PSS Wetland

1:6,000
0

250

p

500
Feet

Figure B-6o

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 13 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

Rd

MP 14.9

wba056

MP 11.5 /

Do

ui
Sq

/

wla017e

ve

rr

el

Rd

/

MP 11.6

wla017s

MP 15
/

er
De
Rd

Rd

/ MP 14.8/

MP 11.7

He

Ga

to

rR
d
L
rm ak
ita e
ge

MP 11.4 // MP 14.7

MP 11.3 /wbb016/ MP 14.6

MP 11.2 //MP 14.5
MP 11.1/

wlb009s

wlb003s

wlb003s/

MP 14.4

wlb002s

MP 11
/

La
ke
H
er

/ MP 14.3

m
ita
ge

wlb002eR

MP 10.9 /dwlb003e

WBB000/ MP 14.2

wlb002s
MP 10.8 /wlb003s

wlb002e
wlb003s/ MP 14.1

wlb002e
MP 10.7 /WBB000wlb002s/ MP 14wlb002s

wlb001e
MP 10.6 /wlb004e/ MP 13.9

wlb001eThis information is for environmental review purposes only.

/

Terminal Site

Temporary Workspace

Delineated PEM Wetland/

TETCO Lateral Milepost

Permanent Easement

Delineated PSS Wetland/

TGP Lateral Milepost

Main Line Block Valve Site

Delineated E2EM Wetland

SW Lateral TETCOPermanent Access Road

Delineated Waterbody

SW Lateral TGP

Temporary Access Road

ATWS

Delineated E2SS Wetland

1:6,000
0

250

p

500
Feet

Figure B-6p

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline
Project Plaquemines Parish, Louisiana
Sheet 14 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

WBB000

Bar

ge A
cce
ss

Cha

nne
l

1

This information is for environmental review purposes only.

Barge Access Channel
Delineated Waterbody

1:6,000
0

250

p

500
Feet

Figure B-6q

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 15 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

nnel 2
cce ss C
ha
Barge A

WBB000

Bar

ge A
cce
ss

Cha

nne
l

1

This information is for environmental review purposes only.

Barge Access Channel
Delineated Waterbody

1:6,000
0

250

p

500
Feet

Figure B-6r

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 16 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

WBB000

Bar

ge A
cce
ss

Cha

nne
l

1

This information is for environmental review purposes only.

Barge Access Channel
Delineated Waterbody

1:6,000
0

250

p

500
Feet

Figure B-6s

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 17 of 21

FILE: M:\Clients\V-X\VGL\Plaquemines\_ArcGIS\_ResourceReports\RR02\_Plaquemines_RR02_2_3_2_4_SW.mxd | REVISED: 02/17/2017 | SCALE: 1:6,000 when printed at 11x17

DRAWN BY: GIS

Barge Access Channel 2

WBB000This information is for environmental review purposes only.

Barge Access Channel
Delineated Waterbody

1:6,000
0

250

p

500
Feet

Figure B-6t

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 18 of 21

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This information is for environmental review purposes only.

Barge Access Channel
Delineated Waterbody

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500
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Figure B-6u

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 19 of 21

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DRAWN BY: GIS

WBB000

s Cha nnel 2
Barge Acces

This information is for environmental review purposes only.

Barge Access Channel
Delineated Waterbody

1:6,000
0

250

p

500
Feet

Figure B-6v

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 20 of 21

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Barge Access Channel
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1:6,000
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500
Feet

Figure B-6w

Field Delineated Wetlands and Waterbodies
Crossed by the Proposed Pipeline System
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
Sheet 21 of 21

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This information is for environmental review purposes only.

Economic Impact Area
Terminal Site BoundaryLouisiana

Interconnect_^

Parish Seat
1:715,000

SW Lateral TETCOSW Lateral TGP

010

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p

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Figure B-7
Socioeconomic Study Area and Overview
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
DRAWN BY: JSnyder

St. John the
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St.
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ParishHahnville

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ParishCensusTract 501

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la HacheLafourche
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CensusTract 505

CensusTract 501

CensusTract 504
TETCO Interconnect
TGP
Interconnect

Terrebonne
ParishCensusTract 506
CensusTract 507
CensusTract 508

This information is for environmental review purposes only.

Terminal Site Boundary
SW Lateral TETCOLouisiana

SW Lateral TGP

Interconnect_ Parish Seat^

1:570,240

2010 USA Census Tract
0

4.5

9
Miles

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Plaquemines Parish Census Tracts
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
DRAWN BY: JSnyder

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Terminal Site BoundaryLouisiana!
.

Approximate Center ofTerminal Site
Noise Sensitive Areas
(NSA)

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Noise Measurement
Location (ML)/

Potential Noise
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0.5 mile Radius from
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Figure B-9
Noise-Sensitive Areas within 0.5 mile of Terminal Site
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana
DRAWN BY: GIS

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This information is for environmental review purposes only.

Barge Access Channel - No
Dredge Required

Terminal Site Boundary
SW Lateral TETCOSW Lateral TGP
Barge Access Channel Dredge/Excavation Proposed!
. Interconnect and Meter Station!

Noise-Sensitive Area
0.5-mile Radius Study Area

Figure B-10
Noise-Sensitive Areas within 0.5 mile of
Proposed Pipline System (Topographic Map)
Plaquemines LNG and Gator Express Pipeline Project
Plaquemines Parish, Louisiana

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DRAWN BY: GISAPPENDIX CUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN;
WETLAND AND WATERBODY CONSTRUCTION AND MITIGATIONPROCEDURES; AND
MODIFICATIONS TO THE PLAN AND PROCEDURES

Proposed Modifications to the Federal Energy Regulatory Commission’s Plan
Venture Global’s project-specific Plan includes proposed modifications to FERC’s Plan(appendix C). FERC allows project sponsors to request modifications to its Plan. The FERC Plan
directs applicants to specify in their application any individual measures that they consider
unnecessary, technically infeasible, or unsuitable due to local conditions, and to describe thealternative measures they propose to use. They must also explain how their proposed alternative
measures would achieve a comparable level of mitigation as the FERC measures.
The project-specific Plan includes numerous minor wording changes to specify the projectsponsor and provide clarifications that do not require our specific approval. Those proposed
modifications that are substantive and for which we have determined that Venture Global provided
adequate justification are listed in table 1. The table includes the original text from FERC’s Plan,
the modified text in the project-specific Plan, and our determination regarding the proposed
modification.
Appendix C, TABLE 1
Requested Modifications to the Federal Energy Regulatory Commission’s Plan
SectionNumberFERC Plan

Venture Global Plan

FERC Determination

II.A.1

The number and experience ofEnvironmental Inspectors assigned
to each construction spread shall beappropriate for the length of theconstruction spread and thenumber/significance of resources
affected.

The number and experience ofEnvironmental Inspectors (EIs) assigned
the project shall be appropriate for the sizeof the construction area, the level ofactivity, and the number/significance ofresources affected.

FERC accepts that the
proposed alternative
measure will achieve acomparable level of
mitigation.

III.G

The project sponsor shall develop
project-specific Spill Prevention andResponse Procedures, as specified
in section IV of the staff's
Procedures.

The project sponsors will develop projectspecific Spill Prevention and Response
Procedures, as contained in a Spill
Prevention, Control, and Countermeasure
Plan or comparable document, as specified
in section IV of the staff's Procedures.

FERC accepts that the
proposed alternative
measure will achieve acomparable level of
mitigation.

IV.A.2The construction right-of-way width
for a project shall not exceed 75 feetor that described in the FERC
application unless otherwise
modified by a FERC Order.
However, in limited, non-wetland
areas, this construction right-ofway width may be expanded by up
to 25 feet without Director approvalto accommodate full construction
right-of-way topsoil segregation andto ensure safe construction where
topographic conditions (e.g., sideslopes) or soil limitations require it.
Twenty-five feet of extra
construction right-of-way width
may also be used in limited, nonwetland or non-forested areas fortruck turn-arounds where no
reasonable alternative access exists.

The project will require a nominal 130foot-wide right-of-way due to the parallel
installation of two 42-inch-diameter
pipelines.

This is not a necessary
modification because thewording in the FERC Plan
allows for and anticipatesevaluating project-specificrights-of-way in the EIS.

IV.F.3.c

Where wetlands or waterbodies are
adjacent to and downslope of
construction work areas, install
sediment barriers along the edge ofthese areas, as necessary to prevent
sediment flow into the wetland or
waterbody.

The project terrain has limited elevation
changes yielding few downslopes.
However, the soils in upland areas, as wellas wetland areas, are of types that will tend
to slough when stacked as spoil. The
workspace width (130 feet) will limit
sediment migration laterally off theconstruction right-of-way. At upland andwetland/waterbody interfaces within theconstruction right-of-way, sedimentbarriers will be installed as practicable.

FERC accepts that thismeasure will achieve acomparable level of
mitigation in areas
sufficiently inundated toallow installation by thepush method.

Proposed Modifications to the Federal Energy Regulatory Commission’s Procedures
Venture Global’s project-specific Procedures regarding wetland and waterbody crossings
include certain proposed modifications to FERC’s Procedures (appendix C). Just as with our Plan,
FERC’s Procedures directs applicants to specify in their application any individual measures thatthey consider unnecessary, technically infeasible, or unsuitable due to local conditions, and todescribe the alternative measures they propose to use. They must also explain how their proposed
alternative measures would achieve a level of mitigation comparable to the FERC measures.
The project-specific Procedures include numerous minor wording changes to specify the
project sponsor and provide clarifications that do not require our specific approval. Those
proposed modifications that are substantive and for which we have determined Venture Global
provided adequate justification are listed in table 2. This table includes the original text from
FERC’s Procedures, the modified text in the project-specific Procedures, and our determination
regarding the proposed modification. One modification that was proposed by Venture Global
regarding the time-of-year for crossing waterbodies is already allowed by the FERC Procedures
and is not included in the following table.
Appendix C, TABLE 2
Requested Modifications to the Federal Energy Regulatory Commission’s Procedures
SectionNumberII.A.2FERC ProcedureSite-specific justifications for theuse of a construction right-of-way
greater than 75-feet-wide in
wetlands.

Venture Global Procedure(Modified wording in bold)
Site-specific justifications for the use of aconstruction right-of-way greater than75-feet-wide in wetlands. The projectrequires a 130-foot-wide construction
right-of-way for pipeline installation
where the push method is used, due tothe need for a relatively wide and deep
trench to ensure the required depth ofcover in the wet, poorly cohesive, andeasily sloughed substrate, and theconsequent need for increased space tosidecast relatively high spoil volumes.
The project requires a 300-foot-wide
construction right-of-way for pipeline
installation in open waters, where thebarge lay method is used, toaccommodate an approximately 100-

FERC Determination
FERC accepts that this
proposed modification isnecessary because the
combination of pipe size, theinundated or saturated soil
conditions, and thepervasiveness and extent of
wetlands and open water inthe project area make the 75foot-wide right-of-way
infeasible.
The requirement to identify
specific wetlands that
require more than a 75-footwide right-of-way remains.
See section 4.3.2.3 forfurther discussion

Appendix C, TABLE 2
Requested Modifications to the Federal Energy Regulatory Commission’s Procedures
SectionNumberFERC Procedure

Venture Global Procedure(Modified wording in bold)

FERC Determination

foot-wide floatation channel for lay
barge and supply barge access, and up to
approximately 100 feet on either side of
the floatation channel for construction
workspace to deposit sidecast trenchmaterial. The 300-foot-wide
construction right-of-way allows safe andwholly waterborne construction.
IV.A.1.d…all equipment is parked overnight
and/or fueled at least 100 feet froma waterbody or in an upland area atleast 100 feet from a wetland
boundary. These activities canoccur closer only if theEnvironmental Inspector determinesthat there is no reasonable
alternative, and the project sponsor
and its contractors have taken
appropriate steps (including
secondary containment structures)to prevent spills and provide forprompt cleanup in the event of aspill;

In construction locations where there is
no reasonable alternative other than tolocate upland refueling sites less than
100 feet from wetlands or waterbodies,
the project will maintain at least a
10-foot setback. All refueling andequipment storage procedures,
irrespective of proximity to wetlands orwaterbodies, will be undertaken inaccordance with the Spill Prevention,
Control, and Countermeasure Plans to
reduce the potential for spills during
construction and to mitigate theenvironmental impacts if a spill should
occur.

FERC accepts that this
proposed modification isnecessary because thepervasiveness and extent of
wetlands and open water inthe project area make thismeasure infeasible and thealternative measure would
achieve a comparable levelof mitigation.

IV.A.1.e…hazardous materials, including
chemicals, fuels, and lubricating
oils, are not stored within 100 feetof a wetland, waterbody, or
designated municipal watershed
area, unless the location isdesignated for such use by anappropriate governmental authority.
This applies to storage of thesematerials and does not apply tonormal operation or use of
equipment in these areas;

Equipment used in wetlands and open
water would often operate at long
distances (up to several miles) from thenearest upland refueling station. To
track the equipment out of the wetland or
open water for refueling, possibly on
multiple occasions, is logisticallyimpractical and potentially moreenvironmentally damaging than refuelingin situ. To minimize the environmental
damage caused by excessive tracking,towed fuel barges will accompany
amphibious equipment as construction
progresses. Equipment operators will befully trained in refueling procedures andthe Spill Prevention, Control, andCountermeasure Plans.

FERC accepts that this
proposed modification isnecessary because thepervasiveness and extent of
wetlands and open water inthe project area make thismeasure infeasible and thealternative measure would
achieve a comparable levelof mitigation.

VB.2.A

Locate all extra work areas (such as
staging areas and additional spoil
storage areas) at least 50 feet awayfrom water’s edge, except where theadjacent upland consists ofcultivated or rotated cropland orother disturbed land.

Locate all extra work areas (such as
staging areas and additional spoil storage
areas) at least 50 feet away from water’sedge, except where indicated onalignment sheets as located in and withina waterbody. Selected additional
temporary workspace (ATWS) in andwithin 50 feet of the waterbody arenecessary due to the lack of cohesivenessin the saturated soil within the pipeline
construction right-of-way, and theconsequent need for adjacent areas inwhich the additional volumes of loosely
aggregated spoil generated at foreign

FERC accepts that this
proposed modification isnecessary because thepervasiveness and extent of
wetlands and open water inthe project area make thismeasure infeasible. The
project sponsors will provide
FERC with copies of thewetland delineation report,
wetland mitigation plans,
and additional agency
permits and approvals prior
to project construction.

Appendix C, TABLE 2
Requested Modifications to the Federal Energy Regulatory Commission’s Procedures
SectionNumberFERC Procedure

Venture Global Procedure(Modified wording in bold)

FERC Determination

pipeline crossings can be temporarily
stored. These ATWS will only be used
for placement of spoil; any equipmentused for this purpose will work frombarges or other similar platforms and will
be within a secondary containment
structure to reduce the risk of spills offuels or other pollutants from entering
the waterbody. The same secondary
containment provisions will apply forequipment operating within the ATWS
located at the meter station platforms andthe barge staging area.
V.B.4.b

Use sediment barriers to prevent theflow of spoil or silt-laden water into
any waterbody.

Use sediment barriers to prevent the flowof spoil or silt-laden water into any
waterbody. For pipeline construction,
the poor compaction of the native soil in
marshland and open water is notconducive to the installation of sedimentbarriers. Due to the poor cohesiveness ofthe native spoil, as well as its low angleof repose after sidecasting, the use of
sediment barriers, such as silt fences, toprevent the flow of spoil or to contain the
spoil would require the barrier towithstand the pressure of the weight ofthe spoil against the barrier. It is
anticipated that the native soil would notoffer enough lateral support to withstandthe pressure of unconsolidated spoil
against the barrier. Therefore, atwaterbody crossings during pipeline
construction, spoil will be placed in theconstruction right-of-way and ATWS
without lateral silt fencing, with theanticipation that the width of these areas
will be sufficient to preclude spoil
migration beyond their boundaries.

FERC accepts that this
proposed modification isnecessary due to thepervasiveness and extent of
wetlands and open water inthe project area and thealternative measureachieving a comparable levelof mitigation.

During pipeline installation using thebarge lay method, the dredge barge will
cast the flotation canal and pipe trench
spoil to either side of the right-of-way
centerline, keeping the spoil below thewater surface, where feasible, tominimize wave-generated turbidity. The
spoil will be placed parallel to the trenchin 500-foot-long piles, with 50-foot-wide
openings to allow the passage of local
watercraft.
V.B.10Install sediment barriers (as definedin section IV.F.3.a of the Plan)
immediately after initial disturbanceof the waterbody or adjacent upland.

Install sediment barriers (as defined in
section IV.F.3.a of the Plan) immediately
prior to initial disturbance of thewaterbody or adjacent upland. The

FERC accepts that this
proposed modification isnecessary due to thepervasiveness and extent of

Appendix C, TABLE 2
Requested Modifications to the Federal Energy Regulatory Commission’s Procedures
SectionNumberFERC Procedure

Venture Global Procedure(Modified wording in bold)

FERC Determination

project sponsors will install sedimentbarriers, as practicable.

wetlands and open water inthe project area and thealternative measureachieving a comparable levelof mitigation.

V.B.10.a,b, and c{Specific measures related to
installation of sediment barriers andtrench plugs}

Venture Global will implement thesemeasures “Except where the project’s
push and barge lay method is used on theconstruction right-of-way.”

FERC accepts that this
proposed modification isnecessary due to thepervasiveness and extent of
wetlands and open water inthe project area.

VI.A.3

Limit the width of the construction
right-of-way to 75 feet or less. Prior
written approval of the Director isrequired where topographic
conditions or soil limitations requirethat the construction right-of-way
width within the boundaries of afederally delineated wetland be
expanded beyond 75 feet. Early inthe planning process the projectsponsor is encouraged to identify
site-specific areas where excessively
wide trenches could occur and/or
where spoil piles could be difficult
to maintain because existing soils
lack adequate unconfinedcompressive strength.

The project will require a nominal 130foot-wide right-of-way using the pushmethod for the lateral pipelines inwetlands due to soil conditions along the
proposed routes. The soils in the project
area are characteristically poorly
cohesive and prone to sloughing. This isexacerbated in the inundated or saturated
soil conditions found in the marshlandand open water areas that characterize
the routes. It is anticipated that, tomaintain side slopes with a sufficiently
shallow angle to prevent collapse, thepipeline trenches will require relatively
wide tops and bases. Consequently, a
relatively high volume of trench spoil
will be generated, necessitating storage
piles on both sides of the trench line.
Because of the excavated material’s lackof cohesion, the storage piles will be
relatively wide and low. The 130-footwide right-of- way is needed toaccommodate the wide trench, the twowide-based storage piles, and equipmentthat must operate at some distance fromthe trench line to avoid edge cave-in.
The use of the push method for pipeline
installation, while reducing equipmentrelated disturbance, does not preclude thespoil storage issues associated withtrench excavation.

FERC accepts that this
proposed modification isnecessary because of theinundated or saturated soil
conditions found in themarshland and open water
areas, which makeconstructing within a 75foot-wide right-of-way
infeasible. The alternative
measures would achieve acomparable level of
mitigation.

Installation of silt fences or othercontainment structures along the outeredges of the construction right-of-way inmarshland and open water is technicallyinfeasible, given the poorly compacted
benthic substrate and average water
depth of several feet. Compared to anarrower workspace, the 130-footworkspace width means that laterally
migrating spoil is more likely to remain
in an authorized area (the workspace),

Appendix C, TABLE 2
Requested Modifications to the Federal Energy Regulatory Commission’s Procedures
SectionNumberFERC Procedure

Venture Global Procedure(Modified wording in bold)

FERC Determination

where any remedial measures can bereadily and effectively deployed.
The project will require a 300-foot-wideright-of-way using the barge lay method,used to install the pipelines in open wateralong the proposed routes. In water
depths of less than 8 feet, it is anticipatedthat the dredge barge will first excavate
the flotation canal. Afterwards the pipe
trench will be excavated along thebottom of the flotation canal. The dredge
barge will cast the flotation canal andpipe trench spoil to either side of theright-of-way centerline, keeping the spoil
below the water surface, where feasible,
to minimize wave-generated turbidity.
The spoil will be placed parallel to thetrench in 500-foot-long piles, with 50foot-wide openings to allow the passageof local watercraft.
VI.A.6

Do not locate aboveground facilities
in any wetland, except where thelocation of such facilities outside ofwetlands would prohibit compliancewith U.S. Department ofTransportation regulations.

While avoidance and minimization of
wetland impacts was integral to site
selection, construction of the project’s
aboveground facilities will permanently
impact some wetlands, as well as
uplands. All wetlands impacted will beappropriately mitigated, and constructionof the aboveground structures will resultin no net loss of wetlands. The projectsponsors will provide FERC with copiesof the wetland delineation report,
wetland mitigation plans, and additional
agency permits and approvals prior to
project construction.

FERC accepts that this
proposed modification isnecessary because the siteand size of the LNG terminal
make avoiding wetlands
infeasible. The projectsponsors will provide FERC
with copies of the wetlanddelineation report, wetland
mitigation plans, andadditional agency permits
and approvals prior to
project construction.

VI.B.1.a

Locate all extra work areas (such as
staging areas and additional spoil
storage areas) at least 50 feet awayfrom wetland boundaries, except
where the adjacent upland consistsof cultivated or rotated cropland orother disturbed land.

Several ATWSs are necessarily locatedin wetlands and waterbodies due to theirintended use and the limited availabilityof suitable upland sites. These include
ATWSs required at the mainline valve
sites and HDD exit and/or entry
locations, set-up sites for push method
operations, bore exit and/or entry
locations, and crossing sites of multiple
foreign pipelines. The project sponsors
believe there are no feasible location
alternatives for these ATWSs that would
cause less significant environmental
impacts. Moreover, most of the ATWSs
are required for HDD, push method
pipeline installation, and bore crossings,
methods that have been selected tominimize or avoid greater environmental
impacts elsewhere.

FERC accepts that this
proposed modification isnecessary because thepervasiveness and extent of
wetlands and open water inthe project area make thismeasure infeasible. The
project sponsors will provide
FERC with copies of thewetland delineation report,
wetland mitigation plans,
and additional agency
permits and approvals prior
to project construction.

Appendix C, TABLE 2
Requested Modifications to the Federal Energy Regulatory Commission’s Procedures
SectionNumberFERC Procedure

Venture Global Procedure(Modified wording in bold)

FERC Determination

VI.B.1.c

In wetlands that cannot beappropriately stabilized, allconstruction equipment other thanthat needed to install the wetland
crossing shall use access roads
located in upland areas. Where
access roads in upland areas do notprovide reasonable access, limit allother construction equipment to one
pass through the wetland using theconstruction right-of-way

In wetlands that cannot be appropriately
stabilized, all construction equipment
other than that needed to install thewetland crossing shall use access roads
located in upland areas. Project
construction is primarily located within
wetlands and waterbodies, and certain
work areas may require access via theconstruction right-of-way across wetland
areas or waterbodies. The push method
will be used to install portions of thelateral pipelines with limited equipment
traffic crossing the wetlands. At certain
locations, such as tie-ins or foreign line
crossings, additional equipment will be
required to complete the pipeline
installation. To access these locations,multiple passes of construction
equipment through the wetlands will be
required using the construction right-ofway. Access channels through open
water will be used to mobilize
construction equipment to install the
majority length of the lateral pipelines
using the barge lay method. Where
access roads in upland areas do notprovide reasonable access, limit all otherconstruction equipment to one passthrough the wetland using theconstruction right-of-way

FERC accepts that this
proposed modification isnecessary because thepervasiveness and extent of
wetlands and open water inthe project area make thismeasure infeasible. The
project sponsors will provide
FERC with copies of thewetland delineation report,
wetland mitigation plans,
and additional agency
permits and approvals prior
to project construction.

VI.B.1.d

The only access roads, other thanthe construction right-of-way, thatcan be used in wetlands are thoseexisting roads that can be used withno modifications or improvements,
other than routine repair, and no
impact on the wetland.

The only access roads, other than theconstruction right-of-way, that can beused in wetlands are those existing roads
that can be used with no modifications or
improvements, other than routine repair,and no impact on the wetland. The
project will require one new permanent
access road to access two mainline valve
sites during project operation; this roadwill also be used during construction.
The project will require one new
temporary access road to access pipe
bridge and HDD sites during
construction. Both roads cross somewetlands, but they represent the shortest
travel distance to the sites and, given theextensive wetlands in their area, there are
no practicable alternative routes with lesswetland impacts. All impacts will beappropriately mitigated in accordancewith applicable regulatory requirements.

FERC accepts that this
proposed modification isnecessary because thepervasiveness and extent of
wetlands in the project area
make avoiding them with allaccess roads infeasible. The
project sponsors will provide
FERC with copies of thewetland delineation report,
wetland mitigation plans,
and additional agency
permits and approvals prior
to project construction.

VI.B.2.d

Minimize the length of time that
topsoil is segregated and the trenchis open. Do not trench the wetland

Minimize the length of time that topsoil
is segregated and the trench is open. The
project will use the push method for

FERC accepts that the
proposed alternative
measure will achieve a

Appendix C, TABLE 2
Requested Modifications to the Federal Energy Regulatory Commission’s Procedures
SectionNumberFERC Procedure

Venture Global Procedure(Modified wording in bold)

FERC Determination

until the pipeline is assembled andready for lowering in.

portions of the SW TETCO and TCP
laterals, requiring the excavation of thepipe trench prior to pipeline assembly inorder for the assembled pipeline segment
to be floated and lowered into in the open
trench. Do not trench the wetland until
the pipeline is assembled and ready forlowering in.

comparable level of
mitigation.

VI.B.3

Install sediment barriers (as definedin section IV.F.3.a of the Plan)
immediately after initial disturbanceof the wetland or adjacent upland.

Install sediment barriers (as defined in
section IV.F.3.a of the Plan) immediately
prior to initial disturbance of the wetland
or adjacent upland.

FERC accepts that the
proposed alternative
measure will achieve acomparable level of
mitigation.

VI.B.3.aInstall sediment barriers across theentire construction right-of-way
immediately upslope of the wetland
boundary at all wetland crossings
where necessary to prevent
sediment flow into the wetland.

Except for the project’s push method useon the construction right-of-way, install
sediment barriers across the entire
construction right-of-way immediately
upslope of the wetland boundary at all
wetland crossings where necessary to
prevent sediment flow into the wetland

FERC accepts that thismeasure is unnecessary inareas sufficiently inundated
to allow installation by thepush method.

VI.B.3.b

Where wetlands are adjacent to theconstruction right-of-way and theright-of-way slopes toward thewetland, install sediment barriers
along the edge of the construction
right-of-way as necessary to containspoil within the construction rightof-way and prevent sediment flow
into the wetland.

Except for the project’s push method useon the construction right-of-way, where
wetlands are adjacent to the construction
right-of-way and the right-of- way slopes
toward the wetland, install sedimentbarriers along the edge of theconstruction right-of-way as necessary tocontain spoil within the construction
right-of-way and prevent sediment flow
into the wetland

FERC accepts that thismeasure is unnecessary inareas sufficiently inundated
to allow installation by thepush method.

VI.B.3.c

Install sediment barriers along theedge of the construction right-ofway as necessary to contain spoil
and sediment within theconstruction right-of-way throughwetlands. Remove these sedimentbarriers during right-of-way
cleanup.

Except for the project’s push method useon the construction right-of-way, install
sediment barriers along the edge of theconstruction right-of- way as necessary
to contain spoil and sediment within theconstruction right-of-way throughwetlands. Remove these sedimentbarriers during right-of-way cleanup.

FERC accepts that thismeasure is unnecessary inareas sufficiently inundated
to allow installation by thepush method.

VI.C.6

Until a project-specific wetland
restoration plan is developed and/or
implemented, temporarily
revegetate the construction right-ofway with annual ryegrass at a rate of
40 pounds/acre (unless standing
water is present).

Until a project-specific wetland
restoration plan is developed and/or
implemented, temporarily revegetate theconstruction right-of-way with annual
ryegrass at a rate of 40 pounds/acre orother species at a rate acceptable to the
USACE and LDNR (unless standing
water is present).

FERC accepts that the
proposed alternative
measure will achieve acomparable level of
mitigation.

VENTURE GLOBAL PLAQUEMINES LNG, LLC
VENTURE GLOBAL GATOR EXPRESS, LLC

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE
PLAN

Docket No.

February 2017

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

VENTURE GLOBAL PLAQUEMINES LNG, LLC
VENTURE GLOBAL GATOR EXPRESS, LLC
PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND
MAINTENANCE PLAN
Table 1.0 below identifies all changes proposed to the Upland Erosion Control, Revegetation,and Maintenance Plan (Plan) for the Plaquemines LNG and Gator Express Pipeline Project(Project). Within the text of the Plan, the changes are bolded and italicized.
TABLE 1.0

SectionPlaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

II.A.1

The number and experience of Environmental
Inspectors assigned to each construction spread shallbe appropriate for the length of the construction spreadand the number/significance of resources affected.

The number and experience of Environmental
Inspectors assigned the Project shall be appropriate
for the size of the construction area, the level ofactivity, and the number/significance of resources
affected.

III.A.1

The project sponsor must ensure that appropriate
cultural resources and biological surveys are
conducted, as determined necessary by theappropriate federal and state agencies.

The Project sponsors will ensure that appropriate
cultural resources and biological surveys are
conducted, as determined necessary by theappropriate federal and state agencies.

III.A.2

Project sponsors are encouraged to consider
expanding any required cultural resources andendangered species surveys in anticipation of the needfor activities outside of authorized work areas.

The Project sponsors will expand any required
cultural resources and endangered species surveys inanticipation of the need for activities outside ofauthorized work areas.

III.B

Drain Tile and Irrigation Systems

There are no known drain tile irrigation systems in
use within the Project area; however, if the Projectsponsors become aware of a drain tile system, they
will:

III.G

The project sponsor shall develop project-specific Spill
Prevention and Response Procedures, as specified in
section IV of the staff's Procedures.

The Project sponsors will develop project-specific
Spill Prevention and Response Procedures, as
contained in a Spill Prevention, Control, andCountermeasure Plan or comparable document, as
specified in section IV of the staff's Procedures.

III.H

For all properties with residences located within 50 feetof construction work areas, project sponsors shall:

For all properties with residences located within 50 feetof construction work areas, the Project sponsors will:

III.I

Winter Construction Plans

The Project location is in a geographic region not
likely to be affected by winter weather conditions.
Winter construction plans are not anticipated for
the Project.

IV.A.2The construction right-of-way width for a project shallnot exceed 75 feet or that described in the FERC
application unless otherwise modified by a FERC
Order. However, in limited, non-wetland areas, thisconstruction right-of- way width may be expanded by
up to 25 feet without Director approval toaccommodate full construction right-of-way topsoil
segregation and to ensure safe construction where
topographic conditions (e.g., side-slopes) or soil
limitations require it. Twenty-five feet of extra
construction right-of-way width may also be used inlimited, non-wetland or non-forested areas for truck
turn-arounds where no reasonable alternative accessexists.

The Project will require a nominal 130-foot-wideright-of-way due to the parallel installation of two
42-inch-diameter pipelines.

IV.F.3.c

Where wetlands or waterbodies are adjacent to and

The Project terrain has limited elevation changes

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

downslope of construction work areas, install sedimentbarriers along the edge of these areas, as necessary to
prevent sediment flow into the wetland or waterbody.

.

yielding few downslopes. However, the soils in
upland areas, as well as wetland areas, are of types
that will tend to slough when stacked as spoil. The
workspace width (130 feet) will limit sedimentmigration laterally off the construction right-of-way.
At upland and wetland/waterbody interfaces within
the construction right-of-way, sediment barriers
will be installed as practicable.

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

VENTURE GLOBAL PLAQUEMINES LNG, LLC
VENTURE GLOBAL GATOR EXPRESS, LLC
PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND
MAINTENANCE PLAN
TABLE OF CONTENTSI.

APPLICABILITY..................................................................................................................... 1

II.

SUPERVISION AND INSPECTION ....................................................................................... 1A.

ENVIRONMENTAL INSPECTION...................................................................................... 1

B.

RESPONSIBILITIES OF ENVIRONMENTAL INSPECTORS ............................................. 1

III.

PRECONSTRUCTION PLANNING .................................................................................... 3

A.

CONSTRUCTION WORK AREAS ..................................................................................... 3

B.

DRAIN TILE AND IRRIGATION SYSTEMS........................................................................ 3

C.

GRAZING DEFERMENT ................................................................................................ 4

D.

ROAD CROSSINGS AND ACCESS POINTS ................................................................ 4E.

DISPOSAL PLANNING ...................................................................................................... 4F.

AGENCY COORDINATION ............................................................................................... 4G.

SPILL PREVENTION, CONTAINMENT, AND COUNTERMEASURES .......................... 4

H.

RESIDENTIAL CONSTRUCTION................................................................................... 5I.

WINTER CONSTRUCTION PLANS................................................................................... 5IV.

INSTALLATION.................................................................................................................. 5A.

APPROVED AREAS OF DISTURBANCE .......................................................................... 5B.

TOPSOIL SEGREGATION ................................................................................................ 6C.

DRAIN TILES ................................................................................................................. 7

D.

IRRIGATION .................................................................................................................. 7

E.

ROAD CROSSINGS AND ACCESS POINTS .................................................................... 7F.

TEMPORARY EROSION CONTROL ................................................................................ 7

V.

1.

Temporary Slope Breakers ............................................................................................. 82.

Temporary Trench Plugs ................................................................................................ 8

3.

Sediment Barriers ........................................................................................................... 8

4.

Mulch ............................................................................................................................. 9

RESTORATION .................................................................................................................. 10A.

CLEANUP ........................................................................................................................ 10

B.

PERMANENT EROSION CONTROL DEVICES .............................................................. 111.

Trench Breakers ........................................................................................................... 112.

Permanent Slope Breakers........................................................................................... 11iFebruary 2017

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

C.

SOIL COMPACTION MITIGATION ............................................................................... 12D.

REVEGETATION ......................................................................................................... 12

1.

General ........................................................................................................................ 12

2.

Soil Additives................................................................................................................ 13

3.

Seeding Requirements ................................................................................................. 13

VI.

OFF-ROAD VEHICLE CONTROL .................................................................................... 14

VII.

POST-CONSTRUCTION ACTIVITIES AND REPORTING ............................................... 14A.

MONITORING AND MAINTENANCE............................................................................... 14

B.

REPORTING ................................................................................................................... 15

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

Plaquemines LNG and Gator Express Pipeline Project
Upland Erosion Control, Revegetation,and Maintenance Plan
I. APPLICABILITY
Venture Global Plaquemines LNG, LLC (Plaquemines LNG) and Venture Global Gator
Express, LLC (Gator Express Pipeline)1 are adopting the FERC Plan (May 2013 version) for
the Plaquemines LNG and Gator Express Pipeline Project (or Project), with modifications. All
modifications to the original wording are shown in bold italic font. This Plan will apply to all
non-wetland areas of the Project. Wetland and waterbody features are addressed in
Plaquemines LNG’s and Gator Express Pipeline’s Project-specific Wetland and Waterbody
Construction and Mitigation Procedures (Procedures).
Deviations that involve measures different from those contained in this Plan will only bepermitted as certificated by the Commission or by written approval of the Director of the Officeof Energy Projects (OEP), or his/her designee, unless specifically required in writing byanother federal, state, or land managing agency for the portion of the Project on its land. The
Project sponsors will file other agency requirements with the Secretary of the Commission(Secretary) prior to construction.
II. SUPERVISION AND INSPECTION
A. ENVIRONMENTAL INSPECTION
1. At least one Environmental Inspector is required for each construction spread
during construction and restoration (as defined by section V). The number andexperience of Environmental Inspectors assigned to the Project shall beappropriate for the size of the construction area, the level of activity, andthe number/significance of resources affected.
2. Environmental Inspectors shall have peer status with all other activity inspectors.
3. Environmental Inspectors shall have the authority to stop activities that violate theenvironmental conditions of the FERC’s Orders, stipulations of otherenvironmental permits or approvals, or landowner easement agreements; and toorder appropriate corrective action.
B. RESPONSIBILITIES OF ENVIRONMENTAL INSPECTORSAt a minimum, the Environmental Inspector(s) shall be responsible for:1. Inspecting construction activities for compliance with the requirements of thisPlan, the Procedures, the environmental conditions of the FERC’s Orders, themitigation measures proposed by the project sponsor (as approved and/or
modified by the Order), other environmental permits and approvals, andenvironmental requirements in landowner easement agreements.

1

Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC are wholly owned subsidiaries of Venture
Global LNG, Inc.

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

2. Identifying, documenting, and overseeing corrective actions, as necessary tobring an activity back into compliance;
3. Verifying that the limits of authorized construction work areas and locations ofaccess roads are visibly marked before clearing, and maintained throughout
construction;
4. Verifying the location of signs and highly visible flagging marking the boundaries
of sensitive resource areas, waterbodies, wetlands, or areas with special
requirements along the construction work area;
5. Identifying erosion/sediment control and soil stabilization needs in all areas;
6. Ensuring that the design of slope breakers will not cause erosion or direct water
into sensitive environmental resource areas, including cultural resource sites,
wetlands, waterbodies, and sensitive species habitats;
7. Verifying that dewatering activities are properly monitored and do not result in thedeposition of sand, silt, and/or sediment into sensitive environmental resourceareas, including wetlands, waterbodies, cultural resource sites, and sensitive
species habitats; stopping dewatering activities if such deposition is occurringand ensuring the design of the discharge is changed to prevent reoccurrence;and verifying that dewatering structures are removed after completion of
dewatering activities;
8. Ensuring that subsoil and topsoil are tested in agricultural fields, defined as
actively managed cropland, and residential areas to measure compaction anddetermine the need for corrective action;
9. Advising the Chief Construction Inspector when environmental conditions (suchas wet weather or frozen soils) make it advisable to restrict or delay construction
activities to avoid topsoil mixing or excessive compaction;
10. Ensuring restoration of contours and topsoil;
11. Verifying that the soils imported for agricultural or residential use are certified as
free of noxious weeds and soil pests, unless otherwise approved by thelandowner;
12. Ensuring that erosion control devices are properly installed to prevent sedimentflow into sensitive environmental resource areas (e.g., wetlands, waterbodies,cultural resource sites, and sensitive species habitats) and onto roads, anddetermining the need for additional erosion control devices;
13. Inspecting and ensuring the maintenance of temporary erosion control measuresat least:a. on a daily basis in areas of active construction or equipment
operation;b. on a weekly basis in areas with no construction or equipment
operation; and2

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

c. within 24 hours of each 0.5 inch of rainfall;
14. Ensuring the repair of all ineffective temporary erosion control measures within 24
hours of identification, or as soon as conditions allow if compliance with this timeframe would result in greater environmental impacts;
15. Keeping records of compliance with the environmental conditions of the FERC’sOrders, and the mitigation measures proposed by the project sponsor in theapplication submitted to the FERC, and other federal or state environmental
permits during active construction and restoration;
16. Identifying areas that should be given special attention to ensure stabilization andrestoration after the construction phase; and17. Verifying that locations for any disposal of excess construction materials forbeneficial reuse comply with section III.E.
III. PRECONSTRUCTION PLANNING
The project sponsor shall do the following before construction:
A. CONSTRUCTION WORK AREAS
1. Identify all construction work areas (e.g., construction right-of-way, extra work
space areas, pipe storage and contractor yards, borrow and disposal areas,
access roads) that would be needed for safe construction. The Projectsponsors will ensure that appropriate cultural resources and biological surveys
are conducted, as determined necessary by the appropriate federal and stateagencies.
2. The Project sponsors will expand any required cultural resources andendangered species surveys in anticipation of the need for activities outside ofauthorized work areas.
3. Plan construction sequencing to limit the amount and duration of open trench
sections, as necessary, to prevent excessive erosion or sediment flow into
sensitive environmental resource areas.
B. DRAIN TILE AND IRRIGATION SYSTEMS
There are no known drain tile irrigation systems in use within the Project area;
however, if the Project sponsors become aware of a drain tile system, they will:
1. Attempt to locate existing drain tiles and irrigation systems.
2. Contact landowners and local soil conservation authorities to determine thelocations of future drain tiles that are likely to be installed within 3 years of theauthorized construction.
3. Develop procedures for constructing through drain-tiled areas, maintaining
irrigation systems during construction, and repairing drain tiles and irrigation
systems after construction.
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4. Engage qualified drain tile specialists, as needed to conduct or monitor repairs todrain tile systems affected by construction. Use drain tile specialists from the
project area, if available.
C. GRAZING DEFERMENTDevelop grazing deferment plans with willing landowners, grazing permittees, andland management agencies to minimize grazing disturbance of revegetation efforts.
D. ROAD CROSSINGS AND ACCESS POINTS
Plan for safe and accessible conditions at all roadway crossings and access points
during construction and restoration.
E. DISPOSAL PLANNING
Determine methods and locations for the regular collection, containment, anddisposal of excess construction materials and debris (e.g., timber, slash, mats,garbage, drill cuttings and fluids, excess rock) throughout the construction process.
Disposal of materials for beneficial reuse must not result in adverse environmental
impact and is subject to compliance with all applicable survey, landowner or land
management agency approval, and permit requirements.
F. AGENCY COORDINATION
The project sponsor must coordinate with the appropriate local, state, and federal
agencies as outlined in this Plan and/or required by the FERC’s Orders.
1. Obtain written recommendations from the local soil conservation authorities orland management agencies regarding permanent erosion control andrevegetation specifications.
2. Develop specific procedures in coordination with the appropriate agencies toprevent the introduction or spread of invasive species, noxious weeds, and soil
pests resulting from construction and restoration activities.
3. Develop specific procedures in coordination with the appropriate agencies andlandowners, as necessary, to allow for livestock and wildlife movement andprotection during construction.
4. Develop specific blasting procedures in coordination with the appropriate
agencies that address pre- and post-blast inspections; advanced public
notification; and mitigation measures for building foundations, groundwater wells,
and springs. Use appropriate methods (e.g., blasting mats) to prevent damage
to nearby structures and to prevent debris from entering sensitive environmental
resource areas.
G. SPILL PREVENTION, CONTAINMENT, AND COUNTERMEASURESThe Project sponsors will develop project-specific Spill Prevention and Response
Procedures, as contained in a Spill Prevention, Control, and Countermeasure
Plan or comparable document, as specified in section IV of the staff's Procedures.
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A copy must be filed with the Secretary of the FERC (Secretary) prior to construction
and made available in the field on each construction spread. The filing requirement
does not apply to projects constructed under the automatic authorization provisions in
the FERC’s regulations.
H. RESIDENTIAL CONSTRUCTION
For all properties with residences located within 50 feet of construction work areas,
the Project sponsors will: avoid removal of mature trees and landscaping within theconstruction work area unless necessary for safe operation of construction
equipment, or as specified in landowner agreements; fence the edge of theconstruction work area for a distance of 100 feet on either side of the residence; andrestore all lawn areas and landscaping immediately following cleanup operations, oras specified in landowner agreements. If seasonal or other weather conditions
prevent compliance with these time frames, maintain and monitor temporary erosion
controls (sediment barriers and mulch) until conditions allow completion ofrestoration.
I.

WINTER CONSTRUCTION PLANS
The Project location is in a geographic region not likely to be affected by winterweather conditions. Winter construction plans are not anticipated for the
Project.
If construction is planned to occur during winter weather conditions, project sponsors
shall develop and file a project-specific winter construction plan with the FERC
application. This filing requirement does not apply to projects constructed under the
automatic authorization provisions of the FERC’s regulations.
The plan shall address:
1. Winter construction procedures (e.g., snow handling and removal, access road
construction and maintenance, soil handling under saturated or frozen conditions,
topsoil stripping);
2. Stabilization and monitoring procedures if ground conditions will delay restoration
until the following spring (e.g., mulching and erosion controls, inspection andreporting, stormwater control during spring thaw conditions); and3. Final restoration procedures (e.g., subsidence and compaction repair, topsoil
replacement, seeding).

IV. INSTALLATION
A. APPROVED AREAS OF DISTURBANCE
1. Project-related ground disturbance shall be limited to the construction right-ofway, extra work space areas, pipe storage yards, borrow and disposal areas,
access roads, and other areas approved in the FERC’s Orders. Any projectrelated ground disturbing activities outside these areas will require prior Director
approval. This requirement does not apply to activities needed to comply with
the Plan and Procedures (i.e., slope breakers, energy-dissipating devices,5

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

dewatering structures, drain tile system repairs) or minor field realignments andworkspace shifts per landowner needs and requirements that do not affect otherlandowners or sensitive environmental resource areas. All construction or
restoration activities outside of authorized areas are subject to all applicablesurvey and permit requirements, and landowner easement agreements.
The Project will require a nominal 130-foot-wide right-of-way due to theparallel installation of two 42-inch-diameter pipelines.
Project use of these additional limited areas is subject to landowner or land
management agency approval and compliance with all applicable survey andpermit requirements. When additional areas are used, each one shall beidentified and the need explained in the weekly or biweekly construction reports
to the FERC, if required. The following material shall be included in the reports:a.

The location of each additional area by station number and reference topreviously filed alignment sheets, or updated alignment sheets showing theadditional areas;b.

Identification of the filing at FERC containing evidence that the additional
areas were previously surveyed; andc.

A statement that landowner approval has been obtained and is available inproject files.

Prior written approval of the Director is required when the authorized construction
right-of-way width would be expanded by more than 25 feet.
B. TOPSOIL SEGREGATION
1. Unless the landowner or land management agency specifically approves
otherwise, prevent the mixing of topsoil with subsoil by stripping topsoil fromeither the full work area or from the trench and subsoil storage area (ditch plus
spoil side method) in:a. Cultivated or rotated croplands, and managed pastures;
b. Residential areas;c. Hayfields; andd. Other areas at the landowner’s or land managing agency’s request.
2. In residential areas, importation of topsoil is an acceptable alternative to topsoil
segregation.
3. Where topsoil segregation is required, the project sponsor must:a. Segregate at least 12 inches of topsoil in deep soils (more than 12
inches of topsoil); andb. Make every effort to segregate the entire topsoil layer in soils with
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

less than 12 inches of topsoil.
4. Maintain separation of salvaged topsoil and subsoil throughout all construction
activities.
5. Segregated topsoil may not be used for padding the pipe, constructing temporary
slope breakers or trench plugs, improving or maintaining roads, or as a fillmaterial.
6. Stabilize topsoil piles and minimize loss due to wind and water erosion with useof sediment barriers, mulch, temporary seeding, tackifiers, or functional
equivalents, where necessary.
C. DRAIN TILES
1. Mark locations of drain tiles damaged during construction.
2. Probe all drainage tile systems within the area of disturbance to check fordamage.
3. Repair damaged drain tiles to their original or better condition. Do not use filtercovered drain tiles unless the local soil conservation authorities and thelandowner agree. Use qualified specialists for testing and repairs.
4. For new pipelines in areas where drain tiles exist or are planned, ensure that thedepth of cover over the pipeline is sufficient to avoid interference with drain tile
systems. For adjacent pipeline loops in agricultural areas, install the new pipeline
with at least the same depth of cover as the existing pipeline(s).
D. IRRIGATION
Maintain water flow in crop irrigation systems, unless shutoff is coordinated withaffected parties.
E. ROAD CROSSINGS AND ACCESS POINTS
1. Maintain safe and accessible conditions at all road crossings and access points
during construction.
2. If crushed stone access pads are used in residential or agricultural areas, place
the stone on synthetic fabric to facilitate removal.
3. Minimize the use of tracked equipment on public roadways. Remove any soil orgravel spilled or tracked onto roadways daily or more frequent as necessary tomaintain safe road conditions. Repair any damages to roadway surfaces,
shoulders, and bar ditches.
F. TEMPORARY EROSION CONTROL
Install temporary erosion controls immediately after initial disturbance of the soil.
Temporary erosion controls must be properly maintained throughout construction (ona daily basis) and reinstalled as necessary (such as after backfilling of the trench)
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

until replaced by permanent erosion controls or restoration is complete.
1. Temporary Slope Breakers
a. Temporary slope breakers are intended to reduce runoff velocity anddivert water off the construction right-of-way. Temporary slope
breakers may be constructed of materials such as soil, silt fence,staked hay or straw bales, or sand bags.
b. Install temporary slope breakers on all disturbed areas, as necessary
to avoid excessive erosion. Temporary slope breakers must be
installed on slopes greater than 5 percent where the base of theslope is less than 50 feet from waterbody, wetland, and roadcrossings at the following spacing (closer spacing shall be used if
necessary):
Slope (%)
5 - 15>15 - 30
>30Spacing (feet)
300
200
100

c. Direct the outfall of each temporary slope breaker to a stable, wellvegetated area or construct an energy-dissipating device at the endof the slope breaker and off the construction right-of-way.
d. Position the outfall of each temporary slope breaker to prevent
sediment discharge into wetlands, waterbodies, or other sensitiveenvironmental resource areas.
2. Temporary Trench Plugs
Temporary trench plugs are intended to segment a continuous open trench
prior to backfill.
a. Temporary trench plugs may consist of unexcavated portions of thetrench, compacted subsoil, sandbags, or some functional equivalent.
b. Position temporary trench plugs, as necessary, to reduce trenchline
erosion and minimize the volume and velocity of trench water flow atthe base of slopes.
3. Sediment Barriers
Sediment barriers are intended to stop the flow of sediments and to preventthe deposition of sediments beyond approved workspaces or into sensitive
resources.
a. Sediment barriers may be constructed of materials such as silt fence,staked hay or straw bales, compacted earth (e.g., driveable berms
across travelways), sand bags, or other appropriate materials.
b. At a minimum, install and maintain temporary sediment barriers
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

across the entire construction right-of-way at the base of slopes
greater than 5 percent where the base of the slope is less than 50
feet from a waterbody, wetland, or road crossing until revegetation is
successful as defined in this Plan. Leave adequate room between
the base of the slope and the sediment barrier to accommodate
ponding of water and sediment deposition.
c. The Project terrain has limited elevation changes yielding few
downslopes. However, the soils in upland areas, as well as
wetland areas, are of types that will tend to slough whenstacked as spoil. The workspace width (130 feet) will limit
sediment migration laterally off the construction right-of-way.
At upland and wetland/waterbody interfaces within theconstruction right-of-way, sediment barriers will be installed aspracticable.
4. Mulcha. Apply mulch on all slopes (except in cultivated cropland) concurrent
with or immediately after seeding, where necessary to stabilize thesoil surface and to reduce wind and water erosion. Spread mulch
uniformly over the area to cover at least 75 percent of the groundsurface at a rate of 2 tons/acre of straw or its equivalent, unless the
local soil conservation authority, landowner, or land managing
agency approves otherwise in writing.
b. Mulch can consist of weed-free straw or hay, wood fiber hydromulch,erosion control fabric, or some functional equivalent.
c. Mulch all disturbed upland areas (except cultivated cropland) before
seeding if:(1)

Final grading and installation of permanent erosion control
measures will not be completed in an area within 20 days
after the trench in that area is backfilled (10 days in residential
areas), as required in section V.A.1; or(2)Construction or restoration activity is interrupted for extended
periods, such as when seeding cannot be completed due toseeding period restrictions.

d. If mulching before seeding, increase mulch application on all slopes
within 100 feet of waterbodies and wetlands to a rate of 3 tons/acreof straw or equivalent.
e. If wood chips are used as mulch, do not use more than 1 ton/acre
and add the equivalent of 11 lbs/acre available nitrogen (at least 50
percent of which is slow release).
f.

Ensure that mulch is adequately anchored to minimize loss due towind and water.

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

g. When anchoring with liquid mulch binders, use rates recommended
by the manufacturer. Do not use liquid mulch binders within 100 feetof wetlands or waterbodies, except where the product is certified
environmentally non-toxic by the appropriate state or federal agency
or independent standards-setting organization.
h. Do not use synthetic monofilament mesh/netted erosion control
materials in areas designated as sensitive wildlife habitat, unless the
product is specifically designed to minimize harm to wildlife. Anchor
erosion control fabric with staples or other appropriate devices.
V. RESTORATION
A. CLEANUP
1. Commence cleanup operations immediately following backfill operations.
Complete final grading, topsoil replacement, and installation of
permanent erosion control structures within 20 days after backfilling thetrench (10 days in residential areas). If seasonal or other weather
conditions prevent compliance with these time frames, maintaintemporary erosion controls (i.e., temporary slope breakers, sedimentbarriers, and mulch) until conditions allow completion of cleanup.
If construction or restoration unexpectedly continues into the winterseason when conditions could delay successful decompaction, topsoil
replacement, or seeding until the following spring, file with the Secretary
for the review and written approval of the Director, a winter construction
plan (as specified in section III.I). This filing requirement does not apply
to projects constructed under the automatic authorization provisions of
the FERC’s regulations.
2. A travel lane may be left open temporarily to allow access by construction traffic if
the temporary erosion control structures are installed as specified in section IV.F.
and inspected and maintained as specified in sections II.B.12 through 14. When
access is no longer required the travel lane must be removed and the right-ofway restored.
3. Rock excavated from the trench may be used to backfill the trench only to the topof the existing bedrock profile. Rock that is not returned to the trench shall beconsidered construction debris, unless approved for use as mulch or for someother use on the construction work areas by the landowner or land managing
agency.
4. Remove excess rock from at least the top 12 inches of soil in all cultivated or
rotated cropland, managed pastures, hayfields, and residential areas, as well asother areas at the landowner’s request. The size, density, and distribution of rockon the construction work area shall be similar to adjacent areas not disturbed byconstruction. The landowner or land management agency may approve otherprovisions in writing.
5. Grade the construction right-of-way to restore pre-construction contours and
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTUPLAND EROSION CONTROL, REVEGETATION, AND MAINTENANCE PLAN

leave the soil in the proper condition for planting.
6. Remove construction debris from all construction work areas unless thelandowner or land managing agency approves leaving materials onsite forbeneficial reuse, stabilization, or habitat restoration.
7. Remove temporary sediment barriers when replaced by permanent erosion
control measures or when revegetation is successful.
B. PERMANENT EROSION CONTROL DEVICES
1. Trench Breakers
a. Trench breakers are intended to slow the flow of subsurface wateralong the trench. Trench breakers may be constructed of materials
such as sand bags or polyurethane foam. Do not use topsoil in
trench breakers.
b. An engineer or similarly qualified professional shall determine theneed for and spacing of trench breakers. Otherwise, trench breakers
shall be installed at the same spacing as and upslope of permanent
slope breakers.
c. In agricultural fields and residential areas where slope breakers are
not typically required, install trench breakers at the same spacing as
if permanent slope breakers were required.
d. At a minimum, install a trench breaker at the base of slopes greaterthan 5 percent where the base of the slope is less than 50 feet froma waterbody or wetland and where needed to avoid draining awaterbody or wetland. Install trench breakers at wetland boundaries,
as specified in the Procedures. Do not install trench breakers withina wetland.
2. Permanent Slope Breakers
a. Permanent slope breakers are intended to reduce runoff velocity,
divert water off the construction right-of-way, and prevent sedimentdeposition into sensitive resources. Permanent slope breakers may
be constructed of materials such as soil, stone, or some functional
equivalent.
b. Construct and maintain permanent slope breakers in all areas,
except cultivated areas and lawns, unless requested by thelandowner, using spacing recommendations obtained from the local
soil conservation authority or land managing agency.

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In the absence of written recommendations, use the following
spacing unless closer spacing is necessary to avoid excessive
erosion on the construction right-of-way:
Slope (%)
5 - 15>15 - 30
>30Spacing (feet)
300
200
100

c. Construct slope breakers to divert surface flow to a stable area
without causing water to pool or erode behind the breaker. In theabsence of a stable area, construct appropriate energy-dissipating
devices at the end of the breaker.
d. Slope breakers may extend slightly (about 4 feet) beyond the edge ofthe construction right-of-way to effectively drain water off the
disturbed area. Where slope breakers extend beyond the edge ofthe construction right-of-way, they are subject to compliance with allapplicable survey requirements.
C. SOIL COMPACTION MITIGATION
1. Test topsoil and subsoil for compaction at regular intervals in agricultural andresidential areas disturbed by construction activities. Conduct tests on the same
soil type under similar moisture conditions in undisturbed areas to approximate
preconstruction conditions. Use penetrometers or other appropriate devices to
conduct tests.
2. Plow severely compacted agricultural areas with a paraplow or other deep tillage
implement. In areas where topsoil has been segregated, plow the subsoil before
replacing the segregated topsoil.
If subsequent construction and cleanup activities result in further
compaction, conduct additional tilling.
3. Perform appropriate soil compaction mitigation in severely compacted residential
areas.
D. REVEGETATION
1. Generala. The project sponsor is responsible for ensuring successful
revegetation of soils disturbed by project-related activities, except as
noted in section V.D.1.b.
b. Restore all turf, ornamental shrubs, and specialized landscaping inaccordance with the landowner’s request, or compensate thelandowner. Restoration work must be performed by personnel
familiar with local horticultural and turf establishment practices.

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2. Soil Additives
Fertilize and add soil pH modifiers in accordance with written
recommendations obtained from the local soil conservation authority, land
management agencies, or landowner. Incorporate recommended soil pH
modifier and fertilizer into the top 2 inches of soil as soon as practicable
after application.
3. Seeding Requirements
a. Prepare a seedbed in disturbed areas to a depth of 3 to 4 inches
using appropriate equipment to provide a firm seedbed. Whenhydroseeding, scarify the seedbed to facilitate lodging andgermination of seed.
b. Seed disturbed areas in accordance with written recommendations
for seed mixes, rates, and dates obtained from the local soil
conservation authority or the request of the landowner or land
management agency.
Seeding is not required in cultivatedcroplands unless requested by the landowner.
c. Perform seeding of permanent vegetation within the recommended
seeding dates. If seeding cannot be done within those dates, useappropriate temporary erosion control measures discussed in section
IV.F and perform seeding of permanent vegetation at the beginningof the next recommended seeding season. Dormant seeding or
temporary seeding of annual species may also be used, if
necessary, to establish cover, as approved by the Environmental
Inspector. Lawns may be seeded on a schedule established with thelandowner.
d. In the absence of written recommendations from the local soil
conservation authorities, seed all disturbed soils within 6 working
days of final grading, weather and soil conditions permitting, subject
to the specifications in section V.D.3.a through V.D.3.c.
e. Base seeding rates on Pure Live Seed. Use seed within 12 monthsof seed testing.
f.

Treat legume seed with an inoculant specific to the species using the
manufacturer’s recommended rate of inoculant appropriate for theseeding method (broadcast, drill, or hydro).

g. In the absence of written recommendations from the local soil
conservation authorities, landowner, or land managing agency to thecontrary, a seed drill equipped with a cultipacker is preferred for seedapplication.
Broadcast or hydroseeding can be used in lieu of drilling at double
the recommended seeding rates. Where seed is broadcast, firm theseedbed with a cultipacker or roller after seeding. In rocky soils or
where site conditions may limit the effectiveness of this equipment,
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other alternatives may be appropriate (e.g., use of a chain drag) tolightly cover seed after application, as approved by theEnvironmental Inspector.
VI. OFF-ROAD VEHICLE CONTROL
To each owner or manager of forested lands, offer to install and maintain measures to control
unauthorized vehicle access to the right-of-way. These measures may include:
1. Signs;
2. Fences with locking gates;
3. Slash and timber barriers, pipe barriers, or a line of boulders across the right-ofway; and4. Conifers or other appropriate trees or shrubs across the right-of-way.
VII.

POST-CONSTRUCTION ACTIVITIES AND REPORTING
A. MONITORING AND MAINTENANCE
1. Conduct follow-up inspections of all disturbed areas, as necessary, to determine
the success of revegetation and address landowner concerns. At a minimum,
conduct inspections after the first and second growing seasons.
2. Revegetation in non-agricultural areas shall be considered successful if upon
visual survey the density and cover of non-nuisance vegetation are similar indensity and cover to adjacent undisturbed lands.
In agricultural areas,
revegetation shall be considered successful when upon visual survey, crop
growth and vigor are similar to adjacent undisturbed portions of the same field,
unless the easement agreement specifies otherwise.
a. Continue revegetation efforts until revegetation is successful.
3. Monitor and correct problems with drainage and irrigation systems resulting frompipeline construction in agricultural areas until restoration is successful.
4. Restoration shall be considered successful if the right-of-way surface condition issimilar to adjacent undisturbed lands, construction debris is removed (unlessotherwise approved by the landowner or land managing agency per section
V.A.6), revegetation is successful, and proper drainage has been restored.
5. Routine vegetation mowing or clearing over the full width of the permanent rightof-way in uplands shall not be done more frequently than every 3 years. However,to facilitate periodic corrosion/leak surveys, a corridor not exceeding 10 feet inwidth centered on the pipeline may be cleared at a frequency necessary tomaintain the 10-foot corridor in an herbaceous state. In no case shall routine
vegetation mowing or clearing occur during the migratory bird nesting season
between April 15 and August 1 of any year unless specifically approved in writingby the responsible land management agency or the U.S. Fish and Wildlife
Service.
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6. Efforts to control unauthorized off-road vehicle use, in cooperation with thelandowner, shall continue throughout the life of the project. Maintain signs,
gates, and permanent access roads as necessary.
B. REPORTING
1. The project sponsor shall maintain records that identify by milepost:
a. Method of application, application rate, and type of fertilizer, pH
modifying agent, seed, and mulch used;b. Acreage treated;c. Dates of backfilling and seeding;d. Names of landowners requesting special seeding treatment and a
description of the follow-up actions;e. The location of any subsurface drainage repairs or improvements
made during restoration; andf.

Any problem areas and how they were addressed.

2. The project sponsor shall file with the Secretary quarterly activity reports
documenting the results of follow-up inspections required by section VII.A.1; any
problem areas, including those identified by the landowner; and corrective actions
taken for at least 2 years following construction.
The requirement to file quarterly activity reports with the Secretary does
not apply to projects constructed under the automatic authorization,prior notice, or advanced notice provisions in the FERC’s regulations.

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECT
Resource Report 1
APPENDIX 1D
Project-specific Wetland and Waterbody Construction and Mitigation
Procedures

VENTURE GLOBAL PLAQUEMINES LNG, LLC
VENTURE GLOBAL GATOR EXPRESS, LLC
PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION
AND MITIGATION PROCEDURES

Docket No.

February 2017

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

VENTURE GLOBAL PLAQUEMINES LNG, LLC
VENTURE GLOBAL GATOR EXPRESS, LLC
PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION
AND MITIGATION PROCEDURES
Table 1.0 below identifies all changes proposed to the Wetland and Waterbody Construction and
Mitigation Procedures for the Plaquemines LNG and Gator Express Pipeline Project (Project).
Within the text of the Procedures, the changes are bolded and italicized.
TABLE 1.0

SectionPlaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

II.A.2Site-specific justifications for the use of a construction
right-of-way greater than 75-feet-wide in wetlands.

Site-specific justifications for the use of a construction
right-of-way greater than 75-feet-wide in wetlands. The
Project requires a 130-foot-wide construction rightof-way for pipeline installation where the Pushmethod is used, due to the need for a relatively
wide and deep trench to ensure the required depthof cover in the wet, poorly cohesive, and easily
sloughed substrate, and the consequent need forincreased space to sidecast relatively high spoilvolumes. The Project requires a 300-foot-wide
construction right-of-way for pipeline installation inopen waters, where the Barge Lay method is used,
to accommodate an approximately 100-foot-wide
floatation channel for lay barge and supply barge
access, and up to approximately 100 feet on eitherside of the floatation channel for construction
workspace to deposit sidecast trench material. The
300-foot-wide construction right-of-way allows safe
and wholly waterborne construction.

II.B.2

Project sponsor will revise the schedule as necessary
to provide FERC staff at least 14 days advance notice.

The Project sponsors will revise the schedule asnecessary to provide FERC staff at least 14 days
advance notice.

III.B.

The Environmental Inspector’s responsibilities are
outlined in the Upland Erosion Control, Revegetation,and Maintenance Plan (Plan).

The Environmental Inspector’s responsibilities are
outlined in Plaquemines LNG’s and Gator Express
Pipeline’s Project-specific Upland Erosion Control,
Revegetation, and Maintenance Plan (Plan).

IV.A

The project sponsor shall develop project-specific Spill
Prevention and Response Procedures that meet
applicable requirements of state and federal agencies.

The Project sponsors will develop project-specific
Spill Prevention and Response Procedures that meet
applicable requirements of state and federal agencies.

IV.A.1It shall be the responsibility of the project sponsor andits contractors to structure their operations in a mannerthat reduces the risk of spills or the accidental
exposure of fuels or hazardous materials towaterbodies or wetlands. The project sponsor and its
contractors must, at a minimum, ensure that:

It will be the responsibility of Project sponsors andtheir contractors to structure their operations in amanner that reduces the risk of spills or the accidental
exposure of fuels or hazardous materials towaterbodies or wetlands. The Project sponsors andtheir contractors must, at a minimum, ensure that:

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURESTABLE 1.0

SectionPlaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

IV.A.1.d… all equipment is parked overnight and/or fueled atleast 100 feet from a waterbody or in an upland area atleast 100 feet from a wetland boundary. These
activities can occur closer only if the Environmental
Inspector determines that there is no reasonable
alternative, and the project sponsor and its contractors
have taken appropriate steps (including secondary
containment structures) to prevent spills and provide
for prompt cleanup in the event of a spill;

In construction locations where is no reasonable
alternative other than to locate upland refuelingsites less than 100 feet from wetlands orwaterbodies, the Project will maintain at least a 10foot setback. All refueling and equipment storage
procedures, irrespective of proximity to wetlands
or waterbodies, will be undertaken in accordancewith Plaquemines LNG’s and Gator Express
Pipeline’s Spill Prevention, Control, andCountermeasure Plans to reduce the potential forspills during construction and to mitigate theenvironmental impacts if a spill should occur.

IV.A.1.e… hazardous materials, including chemicals, fuels, andlubricating oils, are not stored within 100 feet of awetland, waterbody, or designated municipal
watershed area, unless the location is designated forsuch use by an appropriate governmental authority.
This applies to storage of these materials and does not
apply to normal operation or use of equipment in theseareas;

IV.A.2The project sponsor and its contractors must structure
their operations in a manner that provides for the
prompt and effective cleanup of spills of fuel and otherhazardous materials. At a minimum, the projectsponsor and its contractors must:

Equipment used in wetlands and open water would
often operate at long distances (up to several
miles) from the nearest upland refueling station.
To track the equipment out of the wetland or open
water for refueling, possibly on multiple occasions,is logistically impractical and potentially moreenvironmentally damaging than refueling in situ.
To minimize the environmental damage caused byexcessive tracking, towed fuel barges willaccompany amphibious equipment as construction
progresses. Equipment operators will be fully
trained in refueling procedures and Plaquemines
LNG’s and Gator Express Pipeline’s Spill
Prevention, Control, and Countermeasure Plans;
The Project sponsors and their contractors will
structure their operations in a manner that provides forthe prompt and effective cleanup of spills of fuel andother hazardous materials. At a minimum, the Projectsponsors and their contractors will:

IV.B

The project sponsor must coordinate with theappropriate local, state, and federal agencies as
outlined in these Procedures and in the FERC’sOrders.

The Project sponsors will coordinate with theappropriate local, state, and federal agencies as
outlined in these Procedures and in the FERC’s Orders.

V.B.1.b

Coolwater and warmwater fisheries - June 1 throughNovember 30.

Coolwater and warmwater fisheries - June 1 throughNovember 30. The schedule for pipeline
construction in open waters will necessarily be
integrated with the overall Project schedule, suchthat certain Terminal facilities can receive gas
supply at the appropriate time. As such, pipeline
construction cannot be restricted to a specificseasonal timeframe. Use of the Push and Barge
Lay installation methods will minimize impacts
over reasonable alternative methods. Similarly,
marine facility construction on the Mississippi
River cannot be restricted to a specific seasonal
timeframe, based on the anticipated length of theconstruction period and the need for an integrated
schedule across the multiple Project facilities.

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURESTABLE 1.0

SectionPlaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

V.B.4.b.

Use sediment barriers to prevent the flow of spoil orsilt-laden water into any waterbody.

Use sediment barriers to prevent the flow of spoil orsilt-laden water into any waterbody. For pipeline
construction, the poor compaction of the native
soil in marshland and open water is not conduciveto the installation of sediment barriers. Due to thepoor cohesiveness of the native spoil, as well as its
low angle of repose after sidecasting, the use of
sediment barriers, such as silt fences, to preventthe flow of spoil or to contain the spoil would
require the barrier to withstand the pressure of theweight of the spoil against the barrier. It is
anticipated that the native soil would not offer
enough lateral support to withstand the pressure ofunconsolidated spoil against the barrier.
Therefore, at waterbody crossings during pipeline
construction, spoil will be placed in theconstruction right-of-way and ATWS without lateralsilt fencing, with the anticipation that the width ofthese areas will be sufficient to preclude spoil
migration beyond their boundaries. During
pipeline installation using the Barge Lay method,
the dredge barge will cast the flotation canal andpipe trench spoil to either side of the right-of-way
centerline, keeping the spoil below the water
surface, where feasible, to minimize wavegenerated turbidity. The spoil will be placedparallel to the trench in 500-foot-long piles, with 50foot-wide openings to allow the passage of local
watercraft.

V.B.9

Crossings of Major Waterbodies

The Project involves the crossing of major waterbodies.
The Project sponsors will comply with the following
requirements:

V.B.10Install sediment barriers (as defined in section IV.F.3.aof the Plan) immediately after initial disturbance of thewaterbody or adjacent upland.

Install sediment barriers (as defined in section IV.F.3.aof the Plan) immediately prior to initial disturbance of
the waterbody or adjacent upland. The Projectsponsors will install sediment barriers aspracticable.

V.B.10.a.

Install sediment barriers across the entire construction
right-of-way at all waterbody crossings, where
necessary to prevent the flow of sediments into thewaterbody. Removable sediment barriers (or drivableberms) must be installed across the travel lane. These
removable sediment barriers can be removed during
the construction day, but must be re-installed after
construction has stopped for the day and/or whenheavy precipitation is imminent;

Except for the Project’s Push and Barge Lay
Method use on the construction right-of-way, install
sediment barriers across the entire construction rightof-way at all waterbody crossings, where necessary to
prevent the flow of sediments into the waterbody.
Removable sediment barriers (or drivable berms) must
be installed across the travel lane. These removablesediment barriers can be removed during theconstruction day, but must be re-installed after
construction has stopped for the day and/or whenheavy precipitation is imminent;

V.B.10.b.

Where waterbodies are adjacent to the construction
right-of-way and the right-of-way slopes toward thewaterbody, install sediment barriers along the edge ofthe construction right-of-way as necessary to containspoil within the construction right-of-way and prevent
sediment flow into the waterbody; andExcept for the Project’s Push and Barge Lay
Method use on the construction right-of-way, wherewaterbodies are adjacent to the construction right-ofway and the right-of-way slopes toward the waterbody,install sediment barriers along the edge of theconstruction right-of-way as necessary to contain spoil
within the construction right-of-way and prevent
sediment flow into the waterbody; andV.B.10.c.

…use temporary trench plugs at all waterbody
crossings, as necessary, to prevent diversion of water
into upland portions of the pipeline trench and to keep
any accumulated trench water out of the waterbody.

Except for the Project’s Push and Barge Lay
Method use on the construction right-of-way, use
temporary trench plugs at all waterbody crossings, asnecessary, to prevent diversion of water into uplandportions of the pipeline trench and to keep any
accumulated trench water out of the waterbody.

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURESTABLE 1.0

SectionPlaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

V.C.8.

In addition, install sediment barriers as outlined in Plan.

In addition, install sediment barriers as outlined in
Plaquemines LNG’s and Gator Express Pipeline’s
Project-specific Upland Erosion Control,
Revegetation, and Maintenance Plan.

VI.A.1The project sponsor shall conduct a wetlanddelineation using the current federal methodology andfile a wetland delineation report with the Secretary
before construction.

VI.A.3

Limit the width of the construction right-of-way to 75
feet or less. Prior written approval of the Director isrequired where topographic conditions or soil
limitations require that the construction right-of-way
width within the boundaries of a federally delineatedwetland be expanded beyond 75 feet. Early in theplanning process the project sponsor is encouraged to
identify site-specific areas where excessively wide
trenches could occur and/or where spoil piles could be
difficult to maintain because existing soils lackadequate unconfined compressive strength.

The Project sponsors will conduct a wetlanddelineation using the current federal methodology andfile a wetland delineation report with the Secretary
before construction.
The Project will require a nominal 130-foot-wideright-of-way using the Push method for the lateralpipelines in wetlands due to soil conditions along
the proposed routes. The soils in the project area
are characteristically poorly cohesive and prone tosloughing. This is exacerbated in the inundated or
saturated soil conditions found in the marshlandand open water areas that characterize the routes.
Project anticipates that, to maintain side slopes
with a sufficiently shallow angle to prevent
collapse, the pipeline trenches will require
relatively wide tops and bases. Consequently, a
relatively high volume of trench spoil will be
generated, necessitating storage piles on bothsides of the trench line. Because of the excavatedmaterial’s lack of cohesion, the storage piles will
be relatively wide and low. The 130-foot wide rightof-way is needed to accommodate the wide trench,
the two wide-based storage piles, and equipmentthat must operate at some distance from the trenchline to avoid edge cave-in. The use of the Push
Method for pipeline installation, while reducing
equipment-related disturbance, does not preclude
the spoil storage issues associated with trench
excavation.
Installation of silt fences or other containment
structures along the outer edges of theconstruction right-of-way in marshland and open
water is technically infeasible, given the poorly
compacted benthic substrate and average water
depth of several feet. Compared to a narrower
workspace, the 130-foot workspace width meansthat laterally migrating spoil is more likely toremain in an authorized area (the workspace),
where any remedial measures can be readily andeffectively deployed.
The Project will require a 300-foot-wide right-of-way
using the Barge Lay Method, used to install the
pipelines in open water along the proposed routes.
In water depths of less than 8 feet, it is anticipatedthat the dredge barge will first excavate theflotation canal. Afterwards the pipe trench will be
excavated along the bottom of the flotation canal.
The dredge barge will cast the flotation canal andpipe trench spoil to either side of the right-of-way
centerline, keeping the spoil below the water
surface, where feasible, to minimize wavegenerated turbidity. The spoil will be placedparallel to the trench in 500-foot-long piles, with 50foot-wide openings to allow the passage of local
watercraft.

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURESTABLE 1.0
Plaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

Section
VI.A.6

Do not locate aboveground facilities in any wetland,
except where the location of such facilities outside ofwetlands would prohibit compliance with U.S.
Department of Transportation regulations.

While avoidance and minimization of wetland
impacts was integral to site selection, constructionof the Project’s aboveground facilities will
permanently impact some wetlands, as well as
uplands. All wetlands impacted will beappropriately mitigated, and construction of theaboveground structures will result in no net loss of
wetlands. The Project sponsors will provide the
FERC with copies of the wetland delineation report,
wetland mitigation plans, and additional agency
permits and approvals prior to Project
construction.

VI.B

Installation

Project access roads may be constructed indelineated wetland areas. Project will provide
appropriate mitigation for the unavoidable loss of
wetlands due to Project construction. The Projectsponsors will provide the FERC with copies of thewetland delineation report, wetland mitigationplans, and additional agency permits andapprovals prior to Project construction.

VI.B.1.a

Locate all extra work areas (such as staging areas andadditional spoil storage areas) at least 50 feet awayfrom wetland boundaries, except where the adjacentupland consists of cultivated or rotated cropland orother disturbed land.

Several ATWSs are necessarily located in wetlands
and waterbodies due to their intended use and thelimited availability of suitable upland sites. These
include ATWSs required at the mainline valve sites
and HDD exit and/or entry locations, set-up sites
for Push Method operations, bore exit and/or entry
locations, and crossing sites of multiple foreign
pipelines. The Project sponsors believe there areno feasible location alternatives for these ATWSs
that would cause less significant environmental
impacts. Moreover, most of the ATWSs are
required for HDD, Push Method pipeline
installation, and bore crossings, methods that havebeen selected to minimize or avoid greater
environmental impacts elsewhere.

VI.B.1.b

The project sponsor file with the Secretary for review
and written approval by the Director, site-specificjustification for each extra work area with a less than
50-foot setback from wetland boundaries, except
where adjacent upland consists of cultivated or rotatedcropland or other disturbed land. The justification mustspecify the site-specific conditions that will not permit a
50-foot setback and measures to ensure the wetland isadequately protected.

The Project sponsors will file with the Secretary forreview and written approval by the Director, sitespecific justification for each extra work area with a lessthan 50-foot setback from wetland boundaries, except
where adjacent upland consists of cultivated or rotatedcropland or other disturbed land. The justification mustspecify the site-specific conditions that will not permit a
50-foot setback and measures to ensure the wetland isadequately protected.

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SectionPlaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

VI.B.1.c

In wetlands that cannot be appropriately stabilized, allconstruction equipment other than that needed to
install the wetland crossing shall use access roads
located in upland areas.
Where access roads in upland areas do not provide
reasonable access, limit all other construction
equipment to one pass through the wetland using theconstruction right-of-way

In wetlands that cannot be appropriately stabilized, allconstruction equipment other than that needed to install
the wetland crossing shall use access roads located inupland areas. Project construction is primarily
located within wetlands and waterbodies andcertain work areas may require access via theconstruction right-of-way across wetland areas orwaterbodies. The Push Method will be used to
install portions of the lateral pipelines with limited
equipment traffic crossing the wetlands. At certain
locations, such as tie-ins or foreign line crossings,
additional equipment will be required to complete
the pipeline installation. To access these locations
multiple passes of construction equipment throughthe wetlands will be required , using theconstruction right-of-way. Access channels
through open water will be used to mobilize
construction equipment to install the majority
length of the lateral pipelines using the Barge Lay
Method. Where access roads in upland areas do notprovide reasonable access, limit all other construction
equipment to one pass through the wetland using theconstruction right-of-way

VI.B.1.d

The only access roads, other than the construction
right-of-way, that can be used in wetlands are thoseexisting roads that can be used with no modifications
or improvements, other than routine repair, and no
impact on the wetland.

The only access roads, other than the construction
right-of-way, that can be used in wetlands are thoseexisting roads that can be used with no modifications or
improvements, other than routine repair, and no impact
on the wetland. The Project will require one new
permanent access road, to access two mainline
valve sites during Project operation; this road will
also be used during construction. Project will
require one new temporary access road to accesspipe bridge and HDD sites during construction.
Both roads cross some wetlands but they
represent the shortest travel distance to the sites
and given the extensive wetlands in their area,
there are no practicable alternative routes with lesswetland impacts. All impacts will be appropriately
mitigated in accordance with applicable regulatory
requirements.

VI.B.2.d

Minimize the length of time that topsoil is segregated
and the trench is open. Do not trench the wetland until
the pipeline is assembled and ready for lowering in.

Minimize the length of time that topsoil is segregated
and the trench is open. The Project will use the Push
Method for portions of the SW Laterals, requiring
the excavation of the pipe trench prior to pipeline
assembly in order for the assembled pipeline
segment to be floated and lowered into in the open
trench. Do not trench the wetland until the pipeline isassembled and ready for lowering in.

VI.B.3

Install sediment barriers (as defined in section IV.F.3.aof the Plan) immediately after initial disturbance of thewetland or adjacent upland.

Install sediment barriers (as defined in section IV.F.3.aof the Plan) immediately prior to initial disturbance of
the wetland or adjacent upland.

VI.B.3.aInstall sediment barriers across the entire construction
right-of-way immediately upslope of the wetland
boundary at all wetland crossings where necessary to
prevent sediment flow into the wetland

Except for the Project’s Push Method use on theconstruction right-of-way, install sediment barriers
across the entire construction right-of-way immediately
upslope of the wetland boundary at all wetland
crossings where necessary to prevent sediment flow
into the wetland

VI.B.3.b

Where wetlands are adjacent to the construction rightof-way and the right-of-way slopes toward the wetland,
install sediment barriers along the edge of theconstruction right-of-way as necessary to contain spoil
within the construction right-of-way and prevent
sediment flow into the wetland

Except for the Project’s Push Method use on theconstruction right-of-way, where wetlands are
adjacent to the construction right-of-way and the rightof-way slopes toward the wetland, install sedimentbarriers along the edge of the construction right-of-way
as necessary to contain spoil within the construction
right-of-way and prevent sediment flow into the wetland

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURESTABLE 1.0

SectionPlaquemines LNG and Gator Express Pipeline Project
Table of Changes
Original Text
Proposed Text (Changes bolded and italicized)

VI.B.3.c

Install sediment barriers along the edge of theconstruction right-of- way as necessary to contain spoil
and sediment within the construction right-of-way
through wetlands. Remove these sediment barriers
during right-of-way cleanup

Except for the Project’s Push Method use on theconstruction right-of-way, install sediment barriers
along the edge of the construction right-of- way asnecessary to contain spoil and sediment within theconstruction right-of-way through wetlands. Remove
these sediment barriers during right-of-way cleanup

VI.C6.

Until a project-specific wetland restoration plan isdeveloped and/or implemented, temporarily revegetate
the construction right-of-way with annual ryegrass at a
rate of 40 pounds/acre (unless standing water ispresent).

Until a project-specific wetland restoration plan isdeveloped and/or implemented, temporarily revegetate
the construction right-of-way with annual ryegrass at a
rate of 40 pounds/acre or other species at a rate
acceptable to the USACE and LDNR (unless standing
water is present).

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

VENTURE GLOBAL PLAQUEMINES LNG, LLC
VENTURE GLOBAL GATOR EXPRESS, LLC
PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION
AND MITIGATION PROCEDURESTABLE OF CONTENTSI.

APPLICABILITY..................................................................................................................... 1

II.

PRECONSTRUCTION FILING .............................................................................................. 2III.

ENVIRONMENTAL INSPECTORS .................................................................................... 3

IV.

PRECONSTRUCTION PLANNING .................................................................................... 3

V.

WATERBODY CROSSINGS ................................................................................................. 5A.

NOTIFICATION PROCEDURES AND PERMITS ............................................................... 5

B.

INSTALLATION.................................................................................................................. 5
1.

Time Window for Construction........................................................................................ 52.

Extra Work Areas ........................................................................................................... 5

3.

General Crossing Procedures ........................................................................................ 6

4.

Spoil Pile Placement and Control ................................................................................... 6

5.

Equipment Bridges ......................................................................................................... 7

6.

Dry-Ditch Crossing Methods ........................................................................................... 8

7.

Crossings of Minor Waterbodies ..................................................................................... 9

8.

Crossings of Intermediate Waterbodies ........................................................................ 10

9.

Crossings of Major Waterbodies ................................................................................... 10

10.

Temporary Erosion and Sediment Control ................................................................ 10

11.

Trench Dewatering.................................................................................................... 11C.

RESTORATION ........................................................................................................... 11

D.

POST-CONSTRUCTION MAINTENANCE ................................................................... 12

VI.

WETLAND CROSSINGS ................................................................................................. 12A.

GENERAL ....................................................................................................................... 12

B.

INSTALLATION................................................................................................................ 15
1.

Extra Work Areas and Access Roads ........................................................................... 15

2.

Crossing Procedures .................................................................................................... 16

3.

Temporary Sediment Control........................................................................................ 17

4.

Trench Dewatering ....................................................................................................... 18

C.

RESTORATION ........................................................................................................... 18iFebruary 2017

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURESVII.

HYDROSTATIC TESTING ........................................................................................... 19

A.

NOTIFICATION PROCEDURES AND PERMITS ............................................................. 19

B.

GENERAL ....................................................................................................................... 19C.

INTAKE SOURCE AND RATE ..................................................................................... 19

D.

DISCHARGE LOCATION, METHOD, AND RATE ........................................................ 19

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Plaquemines LNG and Gator Express Pipeline Project
Wetland and Waterbody Construction
and Mitigation Procedures
I. APPLICABILITY
A.

Venture Global Plaquemines LNG, LLC (Plaquemines LNG) and Venture Global Gator
Express, LLC (Gator Express Pipeline)1 (hereinafter referred to as the Projectsponsors) are adopting the FERC Procedures (May 2013 Version) for the
Plaquemines LNG and Gator Express Pipeline Project, or Project, with requested
modifications necessary to differentiate the Terminal Site, as a discrete facility, fromthe pipeline construction requirements. All modifications to the original wording areshowing in bold italic font. These Procedures will apply to Project construction in all
wetlands and waterbodies.
Deviations that involve measures different from those contained in this Procedures
document will only be permitted as certificated by the Commission or by written
approval of the Director of the Office of Energy Projects (OEP), or his/her designee,
unless specifically required in writing by another federal, state, or land managing
agency for the portion of the Project on its land. The Project sponsors will file otheragency requirements with the Secretary of the Commission (Secretary) prior toconstruction.
The Project sponsors have identified individual measures in these Procedures that areconsidered unnecessary, technically infeasible, or unsuitable due to local conditions
and fully describes any alternative measures they would use. The Project sponsors
also explain how these alternative measures would achieve a comparable level of
mitigation.

B.

DEFINITIONS
1.

“Waterbody” includes any natural or artificial stream, river, or drainage
with perceptible flow at the time of crossing, and other permanent
waterbodies such as ponds and lakes:
a. “minor waterbody” includes all waterbodies less than or equal to 10feet wide at the water’s edge at the time of crossing;b. “intermediate waterbody” includes all waterbodies greater than 10feet wide but less than or equal to 100 feet wide at the water’s edge
at the time of crossing; andc. “major waterbody” includes all waterbodies greater than 100 feetwide at the water’s edge at the time of crossing.

2.
1“Wetland” includes any area that is not in actively cultivated or rotated

Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC are wholly owned subsidiaries of Venture
Global LNG, Inc.

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

cropland and that satisfies the requirements of the current federal
methodology for identifying and delineating wetlands.
II. PRECONSTRUCTION FILINGA.

B.

The following information must be filed with the Secretary of the FERC (Secretary) prior
to the beginning of construction, for the review and written approval by the Director:
1.

Site-specific justifications for extra work areas that would be closer
than 50 feet from a waterbody or wetland; and2.

Site-specific justifications for the use of a construction right-of-way
greater than 75-feet-wide in wetlands. The Project requires a 130foot-wide construction right-of-way for pipeline installation where
the Push method is used, due to the need for a relatively wide anddeep trench to ensure the required depth of cover in the wet,poorly cohesive, and easily sloughed substrate, and theconsequent need for increased space to sidecast relatively highspoil volumes. The Project requires a 300-foot-wide construction
right-of-way for pipeline installation in open waters, where theBarge Lay method is used, to accommodate an approximately
100-foot-wide floatation channel for lay barge and supply barge
access, and up to approximately 100 feet on either side of thefloatation channel for construction workspace to deposit sidecast
trench material. The 300-foot-wide construction right-of-way
allows safe and wholly waterborne construction.

The following information must be filed with the Secretary prior to the beginning of
construction. These filing requirements do not apply to projects constructed under the
automatic authorization provisions in the FERC’s regulations:
1.

Spill Prevention and Response Procedures specified in section IV.A;

2.

A schedule identifying when trenching or blasting will occur within eachwaterbody greater than 10 feet wide, within any designated coldwater
fishery, and within any waterbody identified as habitat for federallylisted threatened or endangered species. The Project sponsors willrevise the schedule as necessary to provide FERC staff at least 14
days advance notice. Changes within this last 14-day period must
provide for at least 48 hours advance notice;3.

Plans for horizontal directional drills (HDD) under wetlands orwaterbodies, specified in section V.B.6.d;

4.

Site-specific plans for major waterbody crossings, described in section
V.B.9;

5.

A wetland delineation report as described in section VI.A.1, if
applicable; and6.

The hydrostatic testing information specified in section VII.B.3.

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III. ENVIRONMENTAL INSPECTORSA.

At least one Environmental Inspector having knowledge of the wetland and waterbody
conditions in the Project area is required for each construction spread. The number
and experience of Environmental Inspectors assigned to each construction spreadshall be appropriate for the length of the construction spread and thenumber/significance of resources affected.

B.

The Environmental Inspector’s responsibilities are outlined in Plaquemines LNG’sand Gator Express Pipeline’s Project-specific Upland Erosion Control,
Revegetation, and Maintenance Plan (Plan).

IV. PRECONSTRUCTION PLANNINGA.

The Project sponsors will develop project-specific Spill Prevention and Response
Procedures that meet applicable requirements of state and federal agencies. A copy
must be filed with the Secretary prior to construction and made available in the field oneach construction spread. This filing requirement does not apply to projects
constructed under the automatic authorization provisions in the FERC’s regulations.
1.

It will be the responsibility of the Project sponsors and theircontractors to structure their operations in a manner that reduces therisk of spills or the accidental exposure of fuels or hazardous materials
to waterbodies or wetlands. The Project sponsors and theircontractors must, at a minimum, ensure that:a. All employees handling fuels and other hazardous materials areproperly trained;b. All equipment is in good operating order and inspected on a regularbasis;
c. Fuel trucks transporting fuel to on-site equipment travel only on
approved access roads;
d. In construction locations where is no reasonable alternative
other than to locate upland refueling sites less than 100 feetfrom wetlands or waterbodies, the Project will maintain at leasta 10-foot setback.
All refueling and equipment storage
procedures, irrespective of proximity to wetlands orwaterbodies, will be undertaken in accordance with
Plaquemine LNG’s and Gator Express Pipeline’s Spill
Prevention, Control, and Countermeasure Plans to reduce thepotential for spills during construction and to mitigate theenvironmental impacts if a spill should occur;e. Equipment used in wetlands and open water would often
operate at long distances (up to several miles) from the nearest
upland refueling station. To track the equipment out of thewetland or open water for refueling, possibly on multiple
occasions, is logistically impractical and potentially moreenvironmentally damaging than refueling in situ. To minimize
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

the environmental damage caused by excessive tracking, towed
fuel barges will accompany amphibious equipment asconstruction progresses. Equipment operators will be fully
trained in refueling procedures and Plaquemines LNG’s andGator Express Pipeline’s Spill Prevention, Control, andCountermeasure Plans;f.

Concrete coating activities are not performed within 100 feet of awetland or waterbody boundary, unless the location is an existing
industrial site designated for such use. These activities can occur
closer only if the Environmental Inspector determines that there is no
reasonable alternative, and the project sponsor and its contractors
have taken appropriate steps (including secondary containment
structures) to prevent spills and provide for prompt cleanup in theevent of a spill;g. Pumps operating within 100 feet of a waterbody or wetland boundary
utilize appropriate secondary containment systems to prevent spills;
andh. Bulk storage of hazardous materials, including chemicals, fuels, andlubricating oils have appropriate secondary containment systems toprevent spills.
2.

The Project sponsors and their contractors will structure theiroperations in a manner that provides for the prompt and effective
cleanup of spills of fuel and other hazardous materials. At a minimum,
the Project sponsors and their contractors will:a. Ensure that each construction crew (including cleanup crews) has on
hand sufficient supplies of absorbent and barrier materials to allow
the rapid containment and recovery of spilled materials and knows
the procedure for reporting spills and unanticipated discoveries ofcontamination;b. Ensure that each construction crew has on hand sufficient tools andmaterial to stop leaks;c. Know the contact names and telephone numbers for all local, state,
and federal agencies (including, if necessary, the U. S. Coast Guardand the National Response Center) that must be notified of a spill;andd. Follow the requirements of those agencies in cleaning up the spill, in
excavating and disposing of soils or other material contaminated bya spill, and in collecting and disposing of waste generated during spillcleanup.

B.

AGENCY COORDINATIONThe Project sponsors will coordinate with the appropriate local, state, and federal
agencies as outlined in these Procedures and in the FERC’s Orders.
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

V. WATERBODY CROSSINGS
A. NOTIFICATION PROCEDURES AND PERMITS
1.

Apply to the U.S. Army Corps of Engineers (USACE), or its delegatedagency, for the appropriate wetland and waterbody crossing permits.

2.

Provide written notification to authorities responsible for potablesurface water supply intakes located within 3 miles downstream of thecrossing at least 1 week before beginning work in the waterbody, or asotherwise specified by that authority.

3.

Apply for state-issued waterbody crossing permits and obtain individual
or generic section 401 water quality certification or waiver.

4.

Notify appropriate federal and state authorities at least 48 hours before
beginning trenching or blasting within the waterbody, or as specified inapplicable permits.

B. INSTALLATION
1. Time Window for Construction
Unless expressly permitted or further restricted by the appropriate
federal or state agency in writing on a site-specific basis, instream
work, except that required to install or remove equipment bridges,
must occur during the following time windows:
a. Coldwater fisheries - June 1 through September 30; andb. Coolwater and warmwater fisheries - June 1 through November 30.
The schedule for pipeline construction in open waters will
necessarily be integrated with the overall Project schedule,
such that certain Terminal facilities can receive gas supply at
the appropriate time. As such, pipeline construction cannot be
restricted to a specific seasonal timeframe. Use of the Pushand Barge Lay installation methods will minimize impacts overreasonable alternative methods.
Similarly, marine facility
construction on the Mississippi River cannot be restricted to a
specific seasonal timeframe, based on the anticipated length ofthe construction period and the need for an integrated schedule
across the multiple Project facilities.
2. Extra Work Areasa. Locate all extra work areas (such as staging areas and additional
spoil storage areas) at least 50 feet away from water’s edge, except
where the adjacent upland consists of cultivated or rotated croplandor other disturbed land.
b. The Project sponsors will file with the Secretary for review andwritten approval by the Director, site-specific justification for each5

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

extra work area with a less than 50-foot setback from the water’sedge, except where the adjacent upland consists of cultivated or
rotated cropland or other disturbed land. The justification mustspecify the conditions that will not permit a 50-foot setback andmeasures to ensure the waterbody is adequately protected.
c. Limit the size of extra work areas to the minimum needed toconstruct the waterbody crossing.
3. General Crossing Procedures
a. Comply with the USACE, or its delegated agency, permit terms andconditions.
b. Construct crossings as close to perpendicular to the axis of thewaterbody channel as engineering and routing conditions permit.
c. Where pipelines parallel a waterbody, maintain at least 15 feet ofundisturbed vegetation between the waterbody (and any adjacent
wetland) and the construction right-of-way, except where maintaining
this offset will result in greater environmental impact.
d. Where waterbodies meander or have multiple channels, route thepipeline to minimize the number of waterbody crossings.
e. Maintain adequate waterbody flow rates to protect aquatic life, andprevent the interruption of existing downstream uses.
f.

Waterbody buffers (e.g., extra work area setbacks, refueling
restrictions) must be clearly marked in the field with signs and/or
highly visible flagging until construction-related ground disturbing
activities are complete.

g. Crossing of waterbodies when they are dry or frozen and not flowing
may proceed using standard upland construction techniques inaccordance with the Plan, provided that the Environmental Inspector
verifies that water is unlikely to flow between initial disturbance andfinal stabilization of the feature. In the event of perceptible flow, theproject sponsor must comply with all applicable Procedurerequirements for “waterbodies” as defined in section I.B.1.
4. Spoil Pile Placement and Control
a. All spoil from minor and intermediate waterbody crossings, andupland spoil from major waterbody crossings, must be placed in theconstruction right-of-way at least 10 feet from the water’s edge or in
additional extra work areas as described in section V.B.2.
b. Use sediment barriers to prevent the flow of spoil or silt-laden water
into any waterbody.
For pipeline construction, the poor
compaction of the native soil in marshland and open water is
not conducive to the installation of sediment barriers. Due to
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

the poor cohesiveness of the native spoil, as well as its low
angle of repose after sidecasting, the use of sediment barriers,
such as silt fences, to prevent the flow of spoil or to contain the
spoil would require the barrier to withstand the pressure of theweight of the spoil against the barrier. It is anticipated that thenative soil would not offer enough lateral support to withstandthe pressure of unconsolidated spoil against the barrier.
Therefore, at waterbody crossings during pipeline construction,
spoil will be placed in the construction right-of-way and ATWS
without lateral silt fencing, with the anticipation that the width ofthese areas will be sufficient to preclude spoil migration beyond
their boundaries. During pipeline installation using the Barge
Lay method, the dredge barge will cast the flotation canal andpipe trench spoil to either side of the right-of-way centerline,
keeping the spoil below the water surface, where feasible, tominimize wave-generated turbidity. The spoil will be placedparallel to the trench in 500-foot-long piles, with 50-foot-wide
openings to allow the passage of local watercraft.
5. Equipment Bridges
a. Only clearing equipment and equipment necessary for installation ofequipment bridges may cross waterbodies prior to bridge installation.
Limit the number of such crossings of each waterbody to one per
piece of clearing equipment.
b. Construct and maintain equipment bridges to allow unrestricted flow
and to prevent soil from entering the waterbody. Examples of such(1) equipment pads and culvert(s);(2) equipment pads or railroad car bridges without culverts;(3) clean rock fill and culvert(s); and(4) flexi-float or portable bridges.
Additional options for equipment bridges may be utilized that
achieve the performance objectives noted above. Do not use soil toconstruct or stabilize equipment bridges.
c. Design and maintain each equipment bridge to withstand and pass
the highest flow expected to occur while the bridge is in place. Align
culverts to prevent bank erosion or streambed scour. If necessary,
install energy dissipating devices downstream of the culverts.
d. Design and maintain equipment bridges to prevent soil from entering
the waterbody.
e. Remove temporary equipment bridges as soon as practicable after
permanent seeding.
f.

If there will be more than 1 month between final cleanup and the
beginning of permanent seeding and reasonable alternative accessto the right-of-way is available, remove temporary equipment bridges
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

as soon as practicable after final cleanup.
g. Obtain any necessary approval from the USACE, or the appropriate
state agency for permanent bridges.
6. Dry-Ditch Crossing Methods
a. Unless approved otherwise by the appropriate federal or stateagency, install the pipeline using one of the dry-ditch methods
outlined below for crossings of waterbodies up to 30 feet wide (at thewater’s edge at the time of construction) that are state-designated aseither coldwater or significant coolwater or warmwater fisheries, orfederally- designated as critical habitat.
b. Dam and Pump
(1) The dam-and-pump method may be used without prior approval
for crossings of waterbodies where pumps can adequatelytransfer streamflow volumes around the work area, and there
are no concerns about sensitive species passage.
(2) Implementation of the dam-and-pump crossing method mustmeet the following performance criteria:
(i)
(ii)

(iii)
(iv)
(v)

use sufficient pumps, including on-site backup pumps,
to maintain downstream flows;
construct dams with materials that prevent sedimentand other pollutants from entering the waterbody (e.g.,sandbags or clean gravel with plastic liner);screen pump intakes to minimize entrainment of fish;
prevent streambed scour at pump discharge; andcontinuously monitor the dam and pumps to ensure
proper operation throughout the waterbody crossing.

c. Flume Crossing
The flume crossing method requires implementation of the following
steps:(1) Install flume pipe after blasting (if necessary), but before any
trenching;(2) Use sand bag or sand bag and plastic sheeting diversion
structure or equivalent to develop an effective seal and to divert
stream flow through the flume pipe (some modifications to thestream bottom may be required to achieve an effective seal);(3) Properly align flume pipe(s) to prevent bank erosion andstreambed scour;(4) Do not remove flume pipe during trenching, pipelaying, orbackfilling activities, or initial streambed restoration efforts; and8February 2017

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES(5) Remove all flume pipes and dams that are not also part of theequipment bridge as soon as final cleanup of the stream bed
and bank is complete.
d. Horizontal Directional Drill
For each waterbody or wetland that would be crossed using the
HDD method, file with the Secretary for the review and written
approval by the Director, a plan that includes:(1) Site-specific construction diagrams that show the location of
mud pits, pipe assembly areas, and all areas to be disturbed or
cleared for construction;(2) Justification that disturbed areas are limited to the minimum
needed to construct the crossing;(3) Identification of any aboveground disturbance or clearing
between the HDD entry and exit workspaces during
construction;(4) A description of how an inadvertent release of drilling mud
would be contained and cleaned up; and(5) A contingency plan for crossing the waterbody or wetland in theevent the HDD is unsuccessful and how the abandoned drill
hole would be sealed, if necessary.
The requirement to file HDD plans does not apply to projects
constructed under the automatic authorization provisions in the
FERC’s regulations.
7. Crossings of Minor Waterbodies
Where a dry-ditch crossing is not required, minor waterbodies may be crossed
using the open-cut crossing method, with the following restrictions:a. Except for blasting and other rock breaking measures, complete
instream construction activities (including trenching, pipe installation,
backfill, and restoration of the streambed contours) within 24 hours.
Streambanks and unconsolidated
additional restoration after this period;

streambeds

mayrequireb. Limit use of equipment operating in the waterbody to that needed toconstruct the crossing; andc. Equipment bridges are not required at minor waterbodies that do nothave a state-designated fishery classification or protected status(e.g., agricultural or intermittent drainage ditches). However, if anequipment bridge is used it must be constructed as described in
section V.B.5.
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8. Crossings of Intermediate Waterbodies
Where a dry-ditch crossing is not required, intermediate waterbodies may becrossed using the open-cut crossing method, with the following restrictions:a. Complete instream construction activities (not including blasting andother rock breaking measures) within 48 hours, unless site-specificconditions make completion within 48 hours infeasible;
b. Limit use of equipment operating in the waterbody to that needed toconstruct the crossing; andc. All other construction equipment must cross on an equipment bridgeas specified in section V.B.5.
9. Crossings of Major Waterbodies
The Project involves the crossing of major waterbodies. The Project sponsors
will comply with the following requirements:
Before construction, the project sponsor shall file with the Secretary for thereview and written approval by the Director a detailed, site-specific construction
plan and scaled drawings identifying all areas to be disturbed by construction foreach major waterbody crossing (the scaled drawings are not required for any
offshore portions of pipeline projects). This plan must be developed inconsultation with the appropriate state and federal agencies and shall include
extra work areas, spoil storage areas, sediment control structures, etc., as well
as mitigation for navigational issues. The requirement to file major waterbody
crossing plans does not apply to projects constructed under the automatic
authorization provisions of the FERC’s regulations.
The Environmental Inspector may adjust the final placement of the erosion andsediment control structures in the field to maximize effectiveness.
10. Temporary Erosion and Sediment Control
Install sediment barriers (as defined in section IV.F.3.a of the Plan) immediately
prior to initial disturbance of the waterbody or adjacent upland. The Projectsponsors will install sediment barriers as practicable.
Sediment barriers must be properly maintained throughout construction andreinstalled as necessary (such as after backfilling of the trench) until replacedby permanent erosion controls or restoration of adjacent upland areas iscomplete. Temporary erosion and sediment control measures are addressed in
more detail in the Plan; however, the following specific measures must be
implemented at stream crossings:
a. Except for the Project’s Push and Barge Lay Method use on theconstruction right-of-way, install sediment barriers across theentire construction right-of-way at all waterbody crossings, where
necessary to prevent the flow of sediments into the waterbody.
Removable sediment barriers (or drivable berms) must be installed
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across the travel lane. These removable sediment barriers can beremoved during the construction day, but must be re-installed after
construction has stopped for the day and/or when heavy precipitation
is imminent;b. Except for the Project’s Push and Barge Lay Method use on theconstruction right-of-way, where waterbodies are adjacent to theconstruction right-of-way and the right-of-way slopes toward thewaterbody, install sediment barriers along the edge of theconstruction right-of-way as necessary to contain spoil within theconstruction right-of-way and prevent sediment flow into thewaterbody; andc. Except for the Project’s Push and Barge Lay Method use on theconstruction right-of-way, use temporary trench plugs at allwaterbody crossings, as necessary, to prevent diversion of water into
upland portions of the pipeline trench and to keep any accumulated
trench water out of the waterbody.
11. Trench Dewatering
Dewater the trench (either on or off the construction right-of-way) in a mannerthat does not cause erosion and does not result in silt-laden water flowing into
any waterbody. Remove the dewatering structures as soon as practicable after
the completion of dewatering activities.
C. RESTORATION1.

Use clean gravel or native cobbles for the upper 1 foot of trench backfill
in all waterbodies that contain coldwater fisheries.

2.

For open-cut crossings, stabilize waterbody banks and install
temporary sediment barriers within 24 hours of completing instream
construction activities. For dry-ditch crossings, complete streambed
and bank stabilization before returning flow to the waterbody channel.

3.

Return all waterbody banks to preconstruction contours or to a stable
angle of repose as approved by the Environmental Inspector.

4.

Install erosion control fabric or a functional equivalent on waterbody
banks at the time of final bank recontouring. Do not use synthetic
monofilament mesh/netted erosion control materials in areas
designated as sensitive wildlife habitat unless the product is
specifically designed to minimize harm to wildlife. Anchor erosion
control fabric with staples or other appropriate devices.

5.

Application of riprap for bank stabilization must comply with USACE, or
its delegated agency, permit terms and conditions.

6.

Unless otherwise specified by state permit, limit the use of riprap toareas where flow conditions preclude effective vegetative stabilization
techniques such as seeding and erosion control fabric.
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

7.

Revegetate disturbed riparian areas with native species ofconservation grasses, legumes, and woody species, similar in density
to adjacent undisturbed lands.

8.

Install a permanent slope breaker across the construction right-of-way
at the base of slopes greater than 5 percent that are less than 50 feetfrom the waterbody, or as needed to prevent sediment transport into
the waterbody. In addition, install sediment barriers as outlined in
Plaquemines LNG’s and Gator Express Pipeline’s Project-specificUpland Erosion Control, Revegetation, and Maintenance Plan.
In some areas, with the approval of the Environmental Inspector, anearthen berm may be suitable as a sediment barrier adjacent to thewaterbody.

9.

Sections V.C.3 through V.C.7 above also apply to those perennial orintermittent streams not flowing at the time of construction.

D. POST-CONSTRUCTION MAINTENANCE
1.

Limit routine vegetation mowing or clearing adjacent to waterbodies toallow a riparian strip at least 25 feet wide, as measured from thewaterbody’s mean high water mark, to permanently revegetate withnative plant species across the entire construction right-of-way.
However, to facilitate periodic corrosion/leak surveys, a corridor
centered on the pipeline and up to 10 feet wide may be cleared at afrequency necessary to maintain the 10-foot-wide corridor in an
herbaceous state. In addition, trees that are located within 15 feet ofthe pipeline that have roots that could compromise the integrity of thepipeline coating may be cut and removed from the permanent right-ofway. Do not conduct any routine vegetation mowing or clearing inriparian areas that are between HDD entry and exit points.

2.

Do not use herbicides or pesticides in or within 100 feet of a waterbody
except as allowed by the appropriate land management or stateagency.

3.

Time of year restrictions specified in section VII.A.5 of the Plan (April
15 – August 1 of any year) apply to routine mowing and clearing ofriparian areas.

VI.WETLAND CROSSINGS
A. GENERAL
1.

The Project sponsors will conduct a wetland delineation using thecurrent federal methodology and file a wetland delineation report with
the Secretary before construction. The requirement to file a wetlanddelineation report does not apply to projects constructed under the
automatic authorization provisions in the FERC’s regulations.
This report shall identify:
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURESa.

by milepost all wetlands that would be affected;b.

the National Wetlands Inventory (NWI) classification foreach wetland;c.

the crossing length of each wetland in feet; andd.

the area of permanent and temporary disturbance that would
occur in each wetland by NWI classification type.

The requirements outlined in this section do not apply to wetlands inactively cultivated or rotated cropland. Standard upland protective
measures, including workspace and topsoiling requirements, apply tothese agricultural wetlands.
2.

Route the pipeline to avoid wetland areas to the maximum extent
possible. If a wetland cannot be avoided or crossed by following an
existing right-of-way, route the new pipeline in a manner that minimizes
disturbance to wetlands. Where looping an existing pipeline, overlap
the existing pipeline right-of-way with the new construction right-ofway. In addition, locate the loop line no more than 25 feet away fromthe existing pipeline unless site-specific constraints would adversely
affect the stability of the existing pipeline.

3.

The Project will require a nominal 130-foot-wide right-of-way
using the Push method for the lateral pipelines in wetlands due tosoil conditions along the proposed routes. The soils in the
project area are characteristically poorly cohesive and prone tosloughing. This is exacerbated in the inundated or saturated soil
conditions found in the marshland and open water areas thatcharacterize the routes. Project anticipates that, to maintain sideslopes with a sufficiently shallow angle to prevent collapse, thepipeline trenches will require relatively wide tops and bases.
Consequently, a relatively high volume of trench spoil will be
generated, necessitating storage piles on both sides of the trenchline. Because of the excavated material’s lack of cohesion, thestorage piles will be relatively wide and low. The 130-foot wideright-of-way is needed to accommodate the wide trench, the twowide-based storage piles, and equipment that must operate atsome distance from the trench line to avoid edge cave-in. The
use of the Push Method for pipeline installation, while reducing
equipment-related disturbance, does not preclude the spoil
storage issues associated with trench excavation.
Installation of silt fences or other containment structures along
the outer edges of the construction right-of-way in marshland andopen water is technically infeasible, given the poorly compacted
benthic substrate and average water depth of several feet.
Compared to a narrower workspace, the 130-foot workspace
width means that laterally migrating spoil is more likely to remain
in an authorized area (the workspace), where any remedial
measures can be readily and effectively deployed.
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

The Project will require a 300-foot-wide right-of-way for the Barge
Lay Method, used to install the pipelines in open water along the
proposed routes. In water depths of less than 8 feet, it isanticipated that the dredge barge will first excavate the flotation
canal. Afterwards the pipe trench will be excavated along thebottom of the flotation canal. The dredge barge will cast the
flotation canal and pipe trench spoil to either side of the right-ofway centerline, keeping the spoil below the water surface, where
feasible, to minimize wave-generated turbidity. The spoil will beplaced parallel to the trench in 500-foot-long piles, with 50-footwide openings to allow the passage of local watercraft.
4.

Wetland boundaries and buffers must be clearly marked in the fieldwith signs and/or highly visible flagging until construction-related
ground disturbing activities are complete.

5.

Implement the measures of sections V and VI in the event a waterbody
crossing is located within or adjacent to a wetland crossing. If all
measures of sections V and VI cannot be met, the project sponsor
must file with the Secretary a site-specific crossing plan for review andwritten approval by the Director before construction. This crossing plan
shall address at a minimum:

6.

a.

spoil control;b.

equipment bridges;c.

restoration of waterbody banks and wetland hydrology;d.

timing of the waterbody crossing;e.

method of crossing; andf.

size and location of all extra work areas.

While avoidance and minimization of wetland impacts was
integral to site selection, construction of the Project’s
aboveground facilities will permanently impact some wetlands, aswell as uplands. All wetlands impacted will be appropriately
mitigated, and construction of the aboveground structures will
result in no net loss of wetlands. The Project sponsors will
provide the FERC with copies of the wetland delineation report,
wetland mitigation plans, and additional agency permits andapprovals prior to Project construction.

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

B. INSTALLATION
Project access roads may be constructed in delineated wetland areas. Projectwill provide appropriate mitigation for the unavoidable loss of wetlands due toProject construction. The Project sponsors will provide the FERC with copies of
the wetland delineation report, wetland mitigation plans, and additional agency
permits and approvals prior to Project construction.
1. Extra Work Areas and Access Roads
a. Several ATWSs are necessarily located in wetlands andwaterbodies due to their intended use and the limited
availability of suitable upland sites. These include ATWSs
required at the mainline valve sites and HDD exit and/or entry
locations, set-up sites for Push Method operations, bore exit
and/or entry locations, and crossing sites of multiple foreign
pipelines. Project believes there are no feasible location
alternatives for these ATWSs that would cause less significant
environmental impacts. Moreover, most of the ATWSs are
required for HDD, Push Method pipeline installation, and bore
crossings, methods that have been selected to minimize or
avoid greater environmental impacts elsewhere.
b. The Project sponsors will file with the Secretary for review andwritten approval by the Director, site-specific justification for eachextra work area with a less than 50-foot setback from wetland
boundaries, except where adjacent upland consists of cultivated or
rotated cropland or other disturbed land. The justification mustspecify the site-specific conditions that will not permit a 50-footsetback and measures to ensure the wetland is adequately
protected.
c. The construction right-of-way may be used for access when thewetland soil is firm enough to avoid rutting or the construction rightof-way has been appropriately stabilized to avoid rutting (e.g., withtimber riprap, prefabricated equipment mats, or terra mats).
In wetlands that cannot be appropriately stabilized, all construction
equipment other than that needed to install the wetland crossing
shall use access roads located in upland areas.
Project
construction is primarily located within wetlands andwaterbodies and certain work areas may require access via theconstruction right-of-way across wetland areas or waterbodies.
The Push Method will be used to install portions of the lateralpipelines with limited equipment traffic crossing the wetlands.
At certain locations, such as tie-ins or foreign line crossings,
additional equipment will be required to complete the pipeline
installation. To access these locations multiple passes of
construction equipment through the wetlands will be required,using the construction right-of-way. Access channels throughopen water will be used to mobilize construction equipment toinstall the majority length of the lateral pipelines using the15

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

Barge Lay Method. Where access roads in upland areas do notprovide reasonable access, limit all other construction equipment to
one pass through the wetland using the construction right-of-way.
d. The only access roads, other than the construction right-of-way, thatcan be used in wetlands are those existing roads that can be usedwith no modifications or improvements, other than routine repair, andno impact on the wetland. The Project will require one new
permanent access road, to access two mainline valve sites
during Project operation; this road will also be used during
construction. Project will require one new temporary accessroad to access pipe bridge and HDD sites during construction.
Both roads cross some wetlands but they represent the
shortest travel distance to the sites and given the extensive
wetlands in their area, there are no practicable alternativeroutes with less wetland impacts. All impacts will beappropriately mitigated in accordance with applicableregulatory requirements.
2. Crossing Proceduresa.

Comply with USACE, or its delegated agency, permit terms
and conditions.

b.

Assemble the pipeline in an upland area unless the wetland isdry enough to adequately support skids and pipe.

c.

Use “Push Method” techniques to place the pipe in the trench
where water and other site conditions allow.

d.

Minimize the length of time that topsoil is segregated and the trench is
open. The Project will use the Push Method for portions of the
SW Laterals, requiring the excavation of the pipe trench prior topipeline assembly in order for the assembled pipeline segment
to be floated and lowered into in the open trench. Do not trench
the wetland until the pipeline is assembled and ready for lowering in.

e.

Limit construction equipment operating in wetland areas to thatneeded to clear the construction right-of-way, dig the trench, fabricate
and install the pipeline, backfill the trench, and restore theconstruction right-of-way.

f.

Cut vegetation just above ground level, leaving existing root systems
in place, and remove it from the wetland for disposal.
The project sponsor can burn woody debris in wetlands, if approvedby the USACE and in accordance with state and local regulations,ensuring that all remaining woody debris is removed for disposal.

g.

Limit pulling of tree stumps and grading activities to directly over the
trenchline. Do not grade or remove stumps or root systems from therest of the construction right-of-way in wetlands unless the Chief
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

Inspector and Environmental Inspector determine that safety-related
construction constraints require grading or the removal of tree
stumps from under the working side of the construction right-of-way.
h.

Segregate the top 1 foot of topsoil from the area disturbed bytrenching, except in areas where standing water is present or soils
are saturated. Immediately after backfilling is complete, restore thesegregated topsoil to its original location.

i.

Do not use rock, soil imported from outside the wetland, tree stumps,
or brush riprap to support equipment on the construction right-of-way.

j.

If standing water or saturated soils are present, or if construction
equipment causes ruts or mixing of the topsoil and subsoil inwetlands, use low-ground-weight construction equipment, or operate
normal equipment on timber riprap, prefabricated equipment mats, or
terra mats.

k.

Remove all project-related material used to support equipment on
the construction right-of-way upon completion of construction.

3. Temporary Sediment Control
Install sediment barriers (as defined in section IV.F.3.a of the Plan) immediately
prior to initial disturbance of the wetland or adjacent upland. Sediment barriersmust be properly maintained throughout construction and reinstalled asnecessary (such as after backfilling of the trench). Except as noted below insection VI.B.3.c, maintain sediment barriers until replaced by permanent erosion
controls or restoration of adjacent upland areas is complete. Temporary erosion
and sediment control measures are addressed in more detail in the Plan.
a.

Except for the Project’s Push Method use on the construction
right-of-way, install sediment barriers across the entire construction
right-of-way immediately upslope of the wetland boundary at all
wetland crossings where necessary to prevent sediment flow into thewetland.

b.

Except for the Project’s Push Method use on the construction
right-of-way, where wetlands are adjacent to the construction rightof-way and the right-of-way slopes toward the wetland, install
sediment barriers along the edge of the construction right-of-way asnecessary to contain spoil within the construction right-of-way andprevent sediment flow into the wetland.

c.

Except for the Project’s Push Method use on the construction
right-of-way, install sediment barriers along the edge of theconstruction right-of- way as necessary to contain spoil andsediment within the construction right-of-way through wetlands.
Remove these sediment barriers during right-of-way cleanup.

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

4. Trench Dewatering
Dewater the trench (either on or off the construction right-of-way) in a mannerthat does not cause erosion and does not result in silt-laden water flowing into
any wetland. Remove the dewatering structures as soon as practicable after
the completion of dewatering activities.
C. RESTORATION
1.

Where the pipeline trench may drain a wetland, construct trench breakers at
the wetland boundaries and/or seal the trench bottom as necessary tomaintain the original wetland hydrology.

2.

Restore pre-construction wetland contours to maintain the original wetlandhydrology.

3.

For each wetland crossed, install a trench breaker at the base of slopes near
the boundary between the wetland and adjacent upland areas. Install apermanent slope breaker across the construction right-of-way at the base ofslopes greater than 5 percent where the base of the slope is less than 50 feetfrom the wetland, or as needed to prevent sediment transport into thewetland. In addition, install sediment barriers as outlined in the Plan. In someareas, with the approval of the Environmental Inspector, an earthen berm
may be suitable as a sediment barrier adjacent to the wetland.

4.

Do not use fertilizer, lime, or mulch unless required in writing by theappropriate federal or state agency.

5.

Consult with the appropriate federal or state agencies to develop a projectspecific wetland restoration plan.
The restoration plan shall include
measures for re-establishing herbaceous and/or woody species, controllingthe invasion and spread of invasive species and noxious weeds (e.g., purple
loosestrife and phragmites), and monitoring the success of the revegetation
and weed control efforts. Provide this plan to the FERC staff upon request.

6.

Until a project-specific wetland restoration plan is developed and/or
implemented, temporarily revegetate the construction right-of-way withannual ryegrass at a rate of 40 pounds/acre or other species at a rate
acceptable to the USACE and LDNR (unless standing water is present).

7.

Ensure that all disturbed areas successfully revegetate withwetland herbaceous and/or woody plant species.

8.

Remove temporary sediment barriers located at the boundary between
wetland and adjacent upland areas after revegetation and stabilizationof adjacent upland areas are judged to be successful as specified in
section VII.A.4 of the Plan.

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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

VII. HYDROSTATIC TESTING
A. NOTIFICATION PROCEDURES AND PERMITS
1.

Apply for state-issued water withdrawal permits, as required.

2.

Apply for National Pollutant Discharge Elimination System(NPDES) or state-issued discharge permits, as required.

3.

Notify appropriate state agencies of intent to use specific sources atleast 48 hours before testing activities unless they waive thisrequirement in writing.

B. GENERAL
1.

Perform 100 percent radiographic inspection of all pipeline section
welds or hydrotest the pipeline sections, before installation underwaterbodies or wetlands.

2.

If pumps used for hydrostatic testing are within 100 feet of any
waterbody or wetland, will require secondary containment andrefueling of these pumps in the project’s Spill Prevention, Control,and Countermeasure plan.

3.

The project sponsor shall file with the Secretary before construction alist identifying the location of all waterbodies proposed for use as ahydrostatic test water source or discharge location. This filing
requirement does not apply to projects constructed under the
automatic authorization provisions of the FERC’s regulations.

C. INTAKE SOURCE AND RATE
1.

Screen the intake hose to minimize the potential for entrainment of fish.

2.

Do not use state-designated exceptional value waters, waterbodies
which provide habitat for federally listed threatened or endangered
species, or waterbodies designated as public water supplies, unlessappropriate federal, state, and/or local permitting agencies grant
written permission.

3.

Maintain adequate flow rates to protect aquatic life, provide for all
waterbody uses, and provide for downstream withdrawals of water byexisting users.

4.

Locate hydrostatic test manifolds outside wetlands and riparian
areas to the maximum extent practicable.

D. DISCHARGE LOCATION, METHOD, AND RATE
1.

Regulate discharge rate, use energy dissipation device(s), and install
sediment barriers, as necessary, to prevent erosion, streambed scour,suspension of sediments, or excessive streamflow.
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PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECTWETLAND AND WATERBODY CONSTRUCTION AND MITIGATION PROCEDURES

2.

Do not discharge into state-designated exceptional value waters, waterbodies
which provide habitat for federally listed threatened or endangered species,
or waterbodies designated as public water supplies, unless appropriate
federal, state, and local permitting agencies grant written permission.

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APPENDIX DHORIZONTAL DIRECTIONAL DRILLING CONTINGENCY PLAN

Horizontal Directional Drilling Contingency Plan

Gator Express Pipeline Project

Submitted By:
EN Engineering
Warrenville, Illinois

Gator Exoress Pipeline Project
HDD Contingency Plan

TABLE OF CONTENTS

1.0
2.0

3.0

4.0
5.0

6.0

7.0
8.0
9.0

PURPOSE AND NEED ................................................................................................... 1
HDD PROCESS .............................................................................................................. 1
Drilling Basics ...................................................................................................... 1
Drilling Mud and Drilling Mud System ....................................................................... 2
DRILLING MUD RELEASE ............................................................................................. 3
Prevention............................................................................................................ 3
3.1.1 Suitable Material and Adequate Criteria ...................................................3
3.1.2 Pipeline Geometry .................................................................................... 3
3.1.3 General Observations Regarding Inadvertent Returns ..............................3
3.1.4 Responsibility of Drilling Contractor ..........................................................4
3.1.5 Training .................................................................................................... 4
Detection and Monitoring Procedures .................................................................... 4
3.2.1 Monitoring Procedures Will Include ..........................................................4
3.2.2 If a Release Occurs in a Wetland or Waterbody .......................................5
NOTIFICATION PROCEDURES ..................................................................................... 5
CORRECTIVE ACTION .................................................................................................. 5
HDD Entry and Exit Locations ............................................................................... 6
Waterbody or Wetland Release............................................................................. 6
5.2.1 Wetland Locations .................................................................................... 6
5.2.2 Waterbody Locations ................................................................................8
Uncontrollable Release ............................................................................................. 8
HDD FAILURE AND ABANDONMENT CRITERIA .........................................................9
Pilot Hole Step Failure ......................................................................................... 9Hole Opening Step Failure ................................................................................... 9
Pullback Step Failure ......................................................................................... 10
Mechanical Breakdown Failure .......................................................................... 10
HDD ABANDONMENT APPROVALS .......................................................................... 10
HDD CONTINGENCY ................................................................................................... 10
REGULATORY CONTACTS ......................................................................................... 11

Prepared By:

EN Engineering Project Number: 157407
RevisionNo.

PreparedBy

Date

CheckedBy

DateApproved

Date

By

A

PT

11/11/16

ML

11/11/16

NP

11/11/16

BML

02/22/17

ML

02/22/17

NP

02/22/17

ii

ClientApproval By

Date

Revision
Description
Pipeline Lateralnames update

BF

02/22/17

Revised Per Client
Comments

Gator Express Pipeline Project
HDD Contingency PlanGATOR EXPRESS PIPELINE, LLC
GATOR EXPRESS PIPELINE PROJECTHDD CONTINGENCY PLAN
1.0

PURPOSE AND NEED

As part of its Gator Express Pipeline Project (Project) Gator Express Pipeline, LLC(GDWRU([SUHVV3LSHOLQH) proposes to use the Horizontal Directional Drilling (HDD) method to
install pipe across various large spans of wetlands, waterbodies, roads, utilities and otherobstacles obstructing the proposed pipeline alignment. The HDD method of installation
reduces disturbances during pipeline construction by passing underneath sensitive features atthe surface. The HDD method avoids disturbance to the bed and bank of a waterbody
being crossed, keeps sensitive environmental resources and vegetation intact, and/or allows
for a highway or other fixed feature to be crossed while avoiding open cut excavation
between the drill entry and exit points. However, if a natural fracture or an unconsolidated
area in the ground is encountered during drilling, an unexpected release of drilling mud
could occur. For consistency within this HDD Contingency Plan, an unexpected release ofdrilling fluid will be referred to as an inadvertent return. Due to the potential of inadvertent
returns, it is important to have a plan in place to establish the proper procedures andresponsibilities of onsite personnel.
The objective of this HDD Contingency Plan is to:Provide procedures that will minimize the potential for release of drilling mud into
sensitive resource areas such as wetlands and waterbodies, or onto adjacent uplandsurfaces;• Provide for timely detection of inadvertent returns;• Ensure the implementation of an organized, timely, and “minimum impact” response in
the event an inadvertent return of drilling fluid occurs;• Ensure that all appropriate notifications are made in a timely manner;• Provide for an alternative plan in case of drill failure; and,• Establish the criteria by which GDWRU([SUHVV3LSHOLQH will determine when a proposed
HDD crossing isunsuccessful and must be abandoned.
2.0 HDD PROCESS•DRILLING BASICS
The HDD Method is a technically advanced process involving specialized equipment and skilled
operators. The primary environmental risk associated with this construction method comes fromthe potential for inadvertent release of drilling mud. The supervision of inadvertent
release monitoring is the responsibility of both the drilling Contractor and GDWRU ([SUHVV3LSHOLQH.
Minimal, consistent loss of drilling mud typically occurs during the HDD operation when layers ofloose sand, gravel, or fractured rock are encountered and drilling mud fills voids in those subsurface materials. However, a significant loss of returning drill mud and a reduction in
drilling pressure indicates that excessive seepage is occurring outside of the drill hole.

Rev 2

1

)HEUXDU\ 201

Gator Express Pipeline Project
HDD Contingency Plan

DRILLING MUD AND DRILLING MUD SYSTEM
The HDD Method uses drilling mud consisting primarily of water and bentonite, a naturally
occurring clay. Drilling mud removes the cuttings from the drill hole, stabilizes the walls of
the drill hole, and acts as a coolant and lubricant to the drill bit during the drilling process.
The drilling mud mixture consists of 1 to 5 percent bentonite clay and from 0 to 40 percent
inert solids from the drill hole cuttings, with the remainder being water.
The drilling mud is prepared in a mixing tank using both new and clean recycled drilling mud. The
mud is pumped at rates of 200 gallons per minute (gpm) to 1,000 gpm through the center of thedrill pipe to the drilling tools. Return flow is through the annulus created between the wall of thedrill hole and the drill pipe. During the pilot hole drilling operation, the cuttings are returned toa small excavation at the entry point called the entry pit. From the entry pit, the returned
mud is pumped to the mud processing equipment. Typically, shaker screens, desanders,desilters, and centrifuges process and remove increasingly finer cuttings from the drilling mud.
The clean mud is recycled to the mixing tank for reuse in the borehole. The cuttings removed by
the cleaning process are disposed of at a site approved to accept this type of material.
Certain additives may be LQWURGXFHGLQWRWKH drilling mud mix based on changing conditions
during the drilling activities. Typical drilling fluid additives are listed below.

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Gator Express Pipeline Project
HDD Contingency Plan

Various brands of drilling fluid products may be used based on: functionality,
economics, geographic-location to suppliers, and type of JHRORJLFDOformation anticipated DWWKH
GULOOVLWH. Equivalent brands of products may be supplied as an alternative.
3.0

DRILLING MUD RELEASEPREVENTION

The HDD method is typically used to avoid congested areas and/or to avoid disturbance ofsensitive surface features, including wetlands and waterbodies. HDD does, however, present
potential for surface disturbance through inadvertent drilling mud releases. Drilling mud releases
are typically caused by blockage of the return flow path around the drill pipe where pressurizationof the drilling mud rises above the containment capability of the overburden soil material.
Pressurized drilling mud follows the path of least resistance, which may result in the drilling mud
flowing to the ground surface should the annulus around the drill pipe become plugged. Releases
may follow fractures in bedrock or other voids in the strata that allow the mud to penetrate thesurface.
3.1.1

Suitable Material and Adequate 2YHUEXUGHQCriteria

Prevention of drilling mud seepage is a major consideration in determining the profile of the
HDD crossing. The primary factors in selecting the pipeline crossing profile include the typeof soil and rock WKH SK\VLFDO FRQGLWLRQ RI WKH JHRORJLFDO PDWHULDOV and the depth of DGHTXDWHRYHUEXUGHQcover material. Cohesive soils, such as clays, dense sands and competent rockare considered ideal materials for horizontal drilling.
The areas that present the highest potential for drilling mud seepage are the drill entry and exit
points where the overburden depth is minimal. At both the entry and exit points, above
ground containment containers will provide temporary storage for the inadvertently released
drilling mud or seepage until it can be pumped back into the drilling system.
3.1.2

Pipeline Geometry

The geometry of the pipeline GULOOLQJ profile can also affect the potential for drilling fluid
seepage. In a profile which forces the pipe to make compound or excessively tight radiiturns, downhole pressures can build up, thereby, increasing the potential for drilling fluid
seepage. The profiles for the proposed crossings minimize this potential, with very smoothand gradual vertical curves. HDD design and planning minimizes the potential for pressurebuildup caused by pipeline GULOOLQJgeometry.
3.1.3

General Observations Regarding Inadvertent Returns

The risk of HDD inadvertent returns can also be reduced by evaluating thRse
subsurface conditions prior to construction that could be conducive to inadvertent returns or drill
failureLQFOXGLQJ
• Highly permeable soil such as gravel;• Soil test bore holes in close proximity to the drill path;• Presence of rock joints or other subsurface fractures;• Considerable differences in the elevations of HDD entry and exit points;
and,• Disturbed soil, such as fill.

Rev 2

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Gator Express Pipeline Project
HDD Contingency Plan

3.1.4

Responsibility of Drilling Contractor

Project specifications will require that the drilling Contractor be fully qualified and experienced
with HDD construction. The HDD Contractor will be responsible for monitoring down-hole drilling
fluid pressures and drilling fluid flows and keeping these parameters within safe limits. The
Contractor will also be responsible for complying with all permit requirements, technicalspecifications, and this HDD Contingency Plan. The HDD Contractor will be required to submit adetailed pre-construction contingency plan that supplements this plan. The plan should include
measured design considerations that the Contractor made in LWV HDD design to mitigate
inadvertent returns. General HDD activities will be conducted consistent with *DWRU ([SUHVV3LSHOLQH s Storm Water Pollution Prevention Plan (SWPPP).
3.1.5

Training

Prior to the start of construction, the Construction Manager and (QYLURQPHQWDO,QVSHFWRU EI willverify that the construction field crew members receive the following site specific training:
•
•

•

•
•

Review provisions of this HDD Contingency Plan, equipment maintenance and site
specific permit and monitoring requirements;
Review location of sensitive environmental resources at the site and relevant permit
conditions; review inspection procedures for inadvertent return prevention and be
familiar with containment equipment and materials;
Review Contractor/crew obligation to temporarily suspend forward progress of thedrilling upon first evidence of the occurrence of an inadvertent return and to report any
inadvertent returns to the EI;
Review operation of the control equipment and the location of control materials, asnecessary and appropriate; and,
Review protocols for reporting observed inadvertent returns and communication withappropriate regulatory agencies.
DETECTION AND MONITORING PROCEDURES

The Contractor, Construction Inspector and EI will perform continuous monitoring of the
HDD operation to ensure adequate protection/controls have been installed. As noted, field
personnel will be trained regarding their responsibility to promptly report inadvertent
releases to the EI onsite.
The Contractor will provide a trained operator with experience in HDD techniques to monitor drilling
fluid returns at the drilling mud return pits. If the EI or operator identifies seepage of drilling fluid, theEI has the authority to halt construction until the seepage is controlled and corrective action taken.
The EI will be responsible for reporting any drilling fluid seepage or spill in monitoring reports andnotifying the appropriate agencies as discussed below.
3.2.1

Monitoring Procedures Will Include:

1. Inspection along the drill path;
2. Continuous examination of drilling mud pressure gauges and return flows to the surface
pits; and

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3. Monitoring of drilling status information regarding drilling conditions and drill profilealignments.
3.2.2

If a Release Occurs in a Wetland or Waterbody: The drilling mud will be contained where practicable;
 Continue inspection to determine any potential for movement of released drilling mud
within the wetland or waterbody; Collect drilling mud returns at the location for future analysis, if required; and EI to provide photographic documentation and other documentation of the release(GDWRU([SUHVV3LSHOLQHwill keep photographs of release events on record).
Throughout the drilling and inspection effort, the Contractor, Construction Inspector and EI
will work together to avoid any drilling operation shut-downs. Avoiding shut-downs increases
the likelihood of a successful drill and can limit the timeframe of potential inadvertent returns.
4.0

NOTIFICATION PROCEDURES

If monitoring indicates a release is occurring or has occurred, the Contractor will
begin containment immediately while the Construction Inspector or EI will notify GDWRU
([SUHVV3LSHOLQH construction management personnel immediately.
GDWRU ([SUHVV 3LSHOLQH will notify the appropriate agencies (see appendix for contact
information) immediately upon discovery of an inadvertent wetland or waterbody release,detailing the location and nature of the release, corrective actions being taken, and whether the
release poses any threat to public health and safety.
5.0

CORRECTIVE ACTION

In the event that an inadvertent return is observed or suspected during an HDD crossing, it will
be assessed to determine the amount of dr illing mud ( or slurry) being returned and t hepotential for the inadvertent return to reach the ground, wetland, or waterbody. Response
measures will vary based on the location of inadvertent return as described below. At a minimum,
the following containment, response, and clean-up equipment will be available at each boredcrossing location at the time such crossing occurs:

7

sand bags

7

silt fence;

7

plastic sheeting;7

turbidity barriers;

7

shovels, pails;

7

push brooms;

7

squeegees;

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7

pumps and sufficient hose;

7

mud storage tanks; and7

Yacuum truck on 24-hour call (a vacuum truck may be on site to haul return mud backto the recirculating tank.)

GDWRU([SUHVV3LSHOLQH will address an inadvertent release immediately upon discovery. The
following measures will be implemented to minimize or prevent further release, contain therelease, and clean up the affected area.
HDD ENTRY AND EXIT LOCATIONSThere is a greater potential for drilling fluid seepage at the entry and exit locations than otherareas along the HDD. In the contingency planning for the pipeline crossing, drilling fluid seepage
at the entry and exit locations has been considered, and preventative actions have beendeveloped. To contain and control drilling fluid seepage on the land area, there will be earth
moving equipment such as backhoes or small bulldozers, portable pumps, sandbags, and straw
bales available at each of the drilling sites. Any drilling fluid seepage will first be contained andisolated using sandbag berms, straw bales, silt screens or other suitable structures. For larger
returns, a sump may need to be excavated for containment purposes. Once the return iseffectively contained, pumps or vacuum trucks will be used to remove accumulated drilling fluid
and, if practical, return it to the active drilling fluid system.
If public health and safety are threatened by an inadvertent release, drilling operations will
be shut down until the threat is eliminated.
WATERBODY OR WETLAND RELEASE
Straw bales and silt fences will also be on site readily available for upland and wetland
containment situations. Sufficient spill-absorbent material will be on-site in the event of an
inadvertent return. All inadvertent returns will be immediately contained and reported as
required.
Should an inadvertent return occur within D waterway, WKH Contractor will notify
appropriateparties and evaluate the potential impact of the return on a site-specific basis
in order to determine an appropriate course of action. In general, *DWRU ([SUHVV 3LSHOLQH
FRQVLGHUV thatWU\LQJ to contain and collect drilling fluid returns in a waterway LV QRWHQYLURQPHQWDOO\ EHQHILFLDO. HDD drilling fluids are nontoxic and discharge of the amounts
normally associatedwith inadvertent returns do not pose a threat to public health andsafety. Placement of containment structures and attempting to collect drilling fluid within awaterway often result in greater environmental impact than allowing the drilling fluid returns todissipate naturally.
The Contractor will be responsible for using a drilling fluid with the appropriate viscosity,
maintaining the appropriate amount of pressure, and for establishing and maintaining
containment measures at each drill endpoint. If an inadvertent return is observed or suspected
within a wetland or waterbody, the following measures will be implemented:
5.2.1

7

WHWODQG/RFDWLRQV
7HPSRUDULO\VXVSHQGIRUward drilling and promptly notify the Construction Manager and
(,

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Notification of an inadvertent return to the appropriate Regulatory Agencies listed intheappendix of this HDD Contingency Plan. As long as such notification is possible(e.g., there is phone service) and it does not interfere with response activities, theRegulatory Agencies mentioned above shall be notified within two (2) hours of the
inadvertent returnevent.

7

The Construction Manager and EI will evaluate wetland inadvertent returns and,in
consultation with GDWRU ([SUHVV 3LSHOLQH and Uegulatory Dgencies, implement
appropriate response andcleanup measures. Inadvertent return slurries in or adjacent
to wetlands will be removed to the extent practical and the area restored to its
previous condition. Efforts to contain and recover slurry in wetlands may result infurther disturbance by equipment and personnel, and possibly offset the benefit
gained in removing the slurry. Because it is difficult to predict the effect of an
inadvertent return and attempts to recover the slurry,any inadvertent returns within awetland will be evaluated on a case by case basis, and an appropriate level of
response will be implemented with the intent to minimize any further impact to the
area.

•

If the amount of the inadvertent return slurry is too small to allow the practical physicalcollection from the affected area, it will be diluted with fresh water and/or the fluid will beallowed to dry and dissipate naturally.

•

If the amount of the slurry exceeds that which can be contained with hand placed
barriers, small collection sumps (less than 5 cubic yards) may be used to remove theslurry.

•If the amount of the slurry exceeds that which can be contained and collected using small
sumps, drilling operations will be suspended until the inadvertent return can be brought
under control. Suspending drilling operations immediately is not ideal because the lossof pressure in the borehole could result in a collapse of the borehole.

•

The slurry will be stored in a temporary holding tank or other suitable structure, for reuseor disposal.

Secondary containment will be used for portable equipment brought onto the project site (suchas portable pumps). Secondary containment will consist of spill basins large enough to containthe equipment or earthen berms designed to encompass the equipment, lined with polyethylene
sheeting. After the inadvertent release is stabilized and any required removal is completed,document post-cleanup conditions with photographs and prepare incident report describing time,
place, actions taken to remediate inadvertent release, and measures implemented toprevent recurrence, in accordance with SWPPP. Incident reports will be provided to GDWRU
([SUHVV3LSHOLQH and distributed to appropriate Uegulatory Dgencies.
If public health and safety are threatened, drilling mud circulation pumps will be turned off. Thismeasure will be taken as a last resort because of the potential for WKH drill hole to collapse
resulting from loss of down-hole pressure. If monitoring indicates that the intake water quality at
adjacent or downstream user locations is impacted to the extent that it is no longer suitable fortreatment, alternative water sources (i.e., trucked or bottled water) will be provided to impacted
users. GDWRU([SUHVV3LSHOLQH will assist agencies with any sampling they may require.

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HDD Contingency Plan

5.2.2

Waterbody Locations••

Temporarily suspend forward progress and notify the Construction Manager and EI.
The EI will monitor the extent of the slurry plume.
Notification of an inadvertent return to the appropriate Uegulatory Dgencies listed in the
appendix of this HDD Contingency Plan. As long as such notification is possible (e.g.,there is phone service) and it does not interfere with response activities, the Regulatory
Agencies mentioned above shall be notified within two (2) hours of the inadvertent
return event.

•Initiate containment measures and recovery of the slurry as appropriate. Containment
is not always feasible for waterway inadvertent returns. However, conditions will beassessed as to whether hand placed containment, recovery or other measures, suchas silt curtains and turbidity barriers, would be effective and beneficial at the specificinadvertent return location. Returns will be contained using sandbags and contained
mud recovered by pumping or other means effectively removing the mud to the best
extent practical.

•

Evaluate the current drill profile (e.g., drill pressures, pump volume rates, drilling mud
consistency) to identify means to prevent further inadvertent return events. Drilling
operations will be suspended if the return poses a threat to human health and safety or
the environment.

•

Once the return is mitigated and controlled, forward progress of the drilling may resume.

UNCONTROLLABLE RELEASE
If an inadvertent release of drilling mud exceeds that which can be contained and controlled either
because of volume or rate, HDD activities will cease. An evaluation will provide the probablecause of the release and the stage of the drill installation. Based on the evaluation, the measuresdescribed in the following paragraphs will be implemented.
Depending on the current stage of the installation, the HDD Contractor may choose to plug thehole near the fracture with heavyweight material (i.e., sawdust, nut shells, bentonite pellets, orother commercially available non-toxic product). If the inadvertent release of drilling mud occurs
while drilling the pilot hole, the HDD Contractor may choose to back out of the hole by apredetermined distance and then create a new hole by drilling out of the original hole. Therefore,
Procedures 1 or 2 listed below could occur in either order.
1. Plug the fissures/fracture, then:

Rev 2

a)

Pump sealers such as sawdust, nutshells, bentonite pellets, or othercommercially available non-toxic products into the drill hole;b)

Let set for an appropriate period of time (dependent upon sealant used); andc)Resume HDD activities.

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HDD Contingency Plan

2. If a fissure/fracture cannot be plugged, then, if practical:a)Remove drill pipe from the existing drill hole to a point where a new drill pathcan be attempted by drilling out of the existing hole and creating a new hole. The
original hole will be abandoned and filled with bentonite and cuttings. The cuttings
that are returned to the hole should only be equal to those removed from the hole.
The return should not be under high pressure, therefore additional releases would
not be anticipated.

b)

Resume HDD activities.

3. If the original drill path cannot be utilized:a)Abandon the original drill hole by pumping bentonite and cuttings downhole, thenseal the top 5 vertical feet with grout. Grouting abandoned drill holes is anindustry standard practice and serves to prevent the abandoned hole from
disrupting groundwater flow.

b)Move the drill rig to a new, adjacent location.

c)Verify that the new, adjacent location meets the requirements of all applicableproject permits and approvals. If the new, adjacent location does not meet therequirements of all applicable project permits and approvals, operations willcease until new permits and approvals are received.

d)Design an alternative alignment for the re-drill.

e)

Begin HDD re-drill activities.

If all HDD attempts fail, then the crossing will be constructed using an alternative method after
all necessary permits and approvals have been received. Failure is defined in Section 6.0.
6.0

HDD FAILURE AND ABANDONMENT CRITERIA*DWRU([SUHVV3LSHOLQH considers the failure criteria described below as sufficient reason toabandon the HDD process and install the crossing using an approved alternative method.
PILOT HOLE STEP FAILURE
The HDD installation method will be considered a failure if there are two unsuccessful attempts
at completing the pilot hole. If this happens, the HDD Contractor will demobilize its equipmentfrom the site after approval from *DWRU([SUHVV3LSHOLQH.
HOLE OPENING STEP FAILURE
The HDD installation method will be considered a failure if there is one unsuccessful attempt at
opening the hole to the required diameter, as long as the failure does not include losing parts of
the hole opening tool or loss of the entire hole opening tool downhole. The HDD Contractor willthen be allowed 7 working days to attempt to retrieve the missing tool or parts from the holeand continue the hole opening process. If failure occurs, the HDD Contractor will demobilize its
equipment from the site after approval from GDWRU([SUHVV3LSHOLQH.

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PULLBACK STEP FAILURE
The HDD installation method will be considered a failure if there is o ne unsuccessful attempt atcompleting the pullback, unless the pipe can be removed from the hole. In the latter case, asecond attempt will be made after the hole has been reopened and reconditioned withany necessary hole opening passes as determined jointly by the HDD Contractor and GDWRU
([SUHVV3LSHOLQH. If failure occurs, the HDD Contractor will demobilize its equipment from thesite after approval from GDWRU([SUHVV3LSHOLQH.


MECHANICAL BREAKDOWN FAILURE

The HDD installation method will be considered a failure if, at any point during the HDD,
the HDD Contractor has a major mechanical breakdown and after either repairing or
replacing the broken drilling rig or vital ancillary equipment, the drill pipe, hole opening tool, or
pipeline cannot be rotated or pulled. If failure occurs, the HDD Contractor will demobilize its
equipment from the site after approval from *DWRU([SUHVV3LSHOLQH.
7.0

HDD ABANDONMENT APPROVALS*DWRU([SUHVV3LSHOLQH will provide on-site inspection during the HDD process to keep adequate
documentation, daily progress reports, as-built information, etc., and will describe the events
leading up to the HDD failure. GDWRU ([SUHVV 3LSHOLQH will submit this documentation to theappropriate agencies notifying them of the HDD failure and WKH schedule for implementing theapproved alternate crossing method as described in Section 8.0. The HDD Contractor will
not demobilize until *DWRU ([SUHVV 3LSHOLQH V approval has been received. The alternative
crossing method will not be implemented until *DWRU([SUHVV3LSHOLQH has received confirmation
that the )HGHUDO (QHUJ\ 5HJXODWRU\ &RPPLVVLRQ FERC and U.S. Army Corps ofEngineers (USACE) have received the documentation of HDD failure.
8.0

HDD CONTINGENCY

If HDD failure occurs, GDWRU ([SUHVV 3LSHOLQH will construct the proposed pipeline facilities
across both wetland/ waterbody complexes using the open cut trenching method that is
described in GDWRU ([SUHVV 3LSHOLQH V 3roject-specific Wetland and Waterbody Construction
and Mitigation Procedures and is the approved method for crossings outside of thedesignated HDD areas. Push-pull/float installation will be used where hydrological conditions
and sufficient pipeline length make this approach feasible.
*DWRU ([SUHVV 3LSHOLQH will ensure that the necessary authorizations have been obtained
from the appropriate federal (FERC/USACE) and state agencies prior to the implementation of
any alternative crossing methods.

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9.0

REGULATORY CONTACTS
Agency Notification Requirements$! 8!'!
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APPENDIX E
TRAFFIC SIMULATION STUDYTRAFFIC SIMULATION STUDY(CONSTRUCTION PEAK PERSONNEL PERIOD)

G314
LNG LIQUEFACTION AND EXPORT PROJECT

A

01-NOV-16

Issued For Information

GP

ML

AS

REV

DATE

DESCRIPTIONORIG.

CHECKEDAPPR.

DOCUMENT NUMBER:

G314-0000-CM-GEN-RPT-0001

THIS INFORMATION IS TO BE HELD IN CONFIDENCE IN ACCORDANCE WITH THE CONFIDENTIALITYAGREEMENT BETWEEN VENTURE GLOBAL LNG, INC. AND KBR.

LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016

Change Log
REVA

SECTION

CHANGE DESCRIPTION
Initial Issue

Company Confidential

Page 2 of 9

LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016

Table of Contents
1.0

EXECUTIVE SUMMARY ................................................................................................ 5

2.0

INTRODUCTION ............................................................................................................. 6

3.0

STUDY BASIS ................................................................................................................ 6

4.0

TRAFFIC MODEL RESULTS ......................................................................................... 7

5.0

4.1

Base Case Scenario ............................................................................................................................. 7

4.2

Traffic Management Plan (TMP) Scenario ......................................................................................... 8

TRAFFIC MANAGEMENT PLAN (STUDY RECOMMENDATIONS) ............................. 8

Company Confidential

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LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016

List of Figures
FIGURE 1 - ACCESS POINTS (TRAFFIC MODEL SNAPSHOT)......................................................................6
FIGURE 2 - BASE CASE MODEL SNAPSHOT ..................................................................................................7
FIGURE 3– TRAFFIC MANAGEMENT PLAN MODEL SNAPSHOT ..................................................................8

Company Confidential

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LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

1.0

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016

EXECUTIVE SUMMARYKBR performed a traffic simulation study for the VG Plaquemines LNG facility to assess andmitigate the impact of personnel traffic for the estimated construction peak period with a total of
3,300 craft and management personnel. This document summarizes the basis, methodology, andresults of the study.
After the Base Case Scenario was defined and simulated, a Traffic Management Plan (TMP) was
derived to address major issues observed. In fact, the Base Case Scenario results indicatedpotential heavy congestion as a result of undue queues from both construction entrances spillingback into SH-23. A number of alternative scenarios were run until the successful TMP could beformulated. The following is the list of specific TMP actions required during the personnel
construction peak periods in order to minimize congestion problems:

Eliminate traffic checkpoints along the proposed access roads between the designatedpersonnel parking lots and SH-23 to allow free flow conditionsControl construction personnel traffic demand by limiting the number of available
passenger car parking permits on the designated parking lots.

Designate the secondary site access (northern site access) to be used exclusively by theconstruction management personnel.

Construct auxiliary turn lanes (southbound right and northbound left turn lanes) on SH-23
at the proposed intersection with the main site access point (southern site access).

A police officer will be required to control the proposed intersection of SH-23 and mainsite access during the commuting rush hours (e.g. 6-7 AM and 5-6 PM).



Provide a constant onsite bus shuttle service within the rush hours from designatedparking lots to actual work locations to encourage uniform passenger car arrivals or
departures within those rush hours.



Restrict any project-generated truck traffic during the personnel commuting time windows
at the labor peak period.

Company Confidential

Page 5 of 9

LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

2.0

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016

INTRODUCTION

KBR developed a Traffic Management Plan for the construction phase of the Venture Global (VG)
Plaquemines LNG (PLNG) Project. The plan used a detailed microscopic road traffic simulation
model built with Aimsun software by Transport Simulation systems (TSS) to mitigate the impact of
the traffic generated during the peak construction personnel period. A base case model was
created to represent likely projected conditions and assess traffic impacts for this period.
Alternative scenario models were also developed in order to obtain effective congestion mitigation
measures addressing specific traffic congestion issues from the base case model. The Traffic
Management Plan is comprised of those successful measures.
3.0

STUDY BASIS

Based on initial estimates, this project would generate up to 3,300 craft and management personnel
for peak period estimated to occur during the peak mechanical phase of construction.
One major construction shift is assumed with personnel arriving or departing within a one hour time
window. The Base Case considered unrestricted traffic where everybody drives to the site
construction.
Origin (housing) points of the personnel are assumed as follows:

Craft personnel: 70% come from North SH-23 and 30% come from South SH-23
Management personnel: 100% come from North SH-23

The following Figure 1 shows the proposed access points along SH-23 to the site. A transportation
model was then created using the existing SH-23 configuration after overlaying the proposedintersections. Even though the actual site layout has changed (e.g. combi-walls as opposed tolevee), access points shown from this model snapshot are still accurate for this study’s purposes.

Figure 1 - Access Points (Traffic Model Snapshot)

Company Confidential

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LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016

Base Case Scenario also includes checkpoints at both entrances with average processing times of
10 seconds per vehicle.
Traffic volumes used were obtained from the following sources:

Background traffic – obtained from the most recent traffic count data by the Louisiana
Department of Transportation and Development (LADOTD) Database.
Project traffic – Adds the construction peak project generated 3,300 personnel.

The model focuses in the morning peak operations (e.g. from 6:00 to 7:00AM) considered to be
critical from the PLNG project construction productivity stand point and also from network impact
perspective, once peak morning background traffic is added.
4.0
4.1

TRAFFIC MODEL RESULTS
Base Case Scenario

As stated before, the Base Case considered unrestricted traffic where everybody could drive to theconstruction site. Figure 2 shows a screen capture of the simulation model. Base Case Scenario
results indicated potential heavy congestion as a result of undue queues from both construction
entrances spilling back into SH-23. Such spillback would also create a major impact to backgroundtraffic along SH-23. The model also shows that about 44% of the PLNG construction personnel
would report to work late (after 7:00AM) creating a direct hit in construction productivity andpossibly compromising overall schedule. In summary, Base Case Scenario represented an
unacceptable traffic operations impact and performance for both background and project generated
traffic.

Figure 2 - Base Case Model Snapshot
Company Confidential

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LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

4.2

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016

Traffic Management Plan (TMP) Scenario

After running several alternatives, the following is a number of congestion mitigation measures
found to effectively address issues of traffic congestion observed in the Base Case Scenario. The
combined group of measures confirmed this scenario model referenced as the Traffic Management
Plan. Results from this model confirm that these specific measures would effectively minimize traffic
impacts during the labor construction peak period. Figure 3 shows a screen capture of the TMP
model, where it can be seen that the red traffic is flowing stable with no queues along the entrancesor SH-23. Furthermore, all PLNG construction personnel would report on time.
Note that a video clip of this simulation scenario is available for viewing.

Figure 3– Traffic Management Plan Model Snapshot
5.0

TRAFFIC MANAGEMENT PLAN (STUDY RECOMMENDATIONS)

The following is a list of complete congestion mitigation measures that comprise the proposed traffic
management plan. It is strongly recommended to implement all of them prior to the construction
peak period.
a) Eliminate the need of having any personnel traffic checkpoints along the proposed access roads
between the designated personnel parking lots and SH-23. Models clearly demonstrate thatsuch checkpoints would cause traffic queuing to extend beyond the access roads into SH-23.
Access control would be maintained at the entrances to the construction site from the parkinglot.
b) Control construction personnel traffic demand by limiting the number of available passenger car
parking permits on the designated parking lots. This measure is linked to achieve average
passenger car occupancy targets of no less than 2.0 persons per car for craft personnel and1.25 persons per car for management personnel during the manpower peak period.

Company Confidential

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LNG Liquefaction and Export Project
KBR Project No: G314
Document Title: TRAFFIC SIMULATION STUDY (CONSTRUCTION
PEAK PERSONNEL PERIOD)

Document No: G314-0000-CM-GEN-RPT-0001
Revision: A
Date 01 NOV 2016c) Designate the secondary site access (northern site access) to be used exclusively by theconstruction management personnel.
d) Construct auxiliary turn lanes (southbound right and northbound left turn lanes) along SH-23 atthe proposed intersection with the main site access point (southern site access).
e) A police officer will be required to control the proposed intersection of SH-23 and main site
access during the commuting rush hours (e.g. 6-7 AM and 5-6 PM). They will also block theeast leg of this intersection leading to the marine offsite facility (no truck traffic is allowed atthose times). This will allow control for the temporary T-intersection with just two phases during
the morning and afternoon rush hours: 1) northbound/southbound through (with permissive rightturns); and, 2) concurrent southbound right turn and northbound left turn movements (forinbound traffic in the morning) or concurrent eastbound right and left turn movements (foroutbound traffic in the evening). Operating this intersection with just two phases will significantly
improve capacity and simplify the intersection control task. In addition, the construction projectis calling for widening the main access road to 50 feet which directly supports multi-lane
configuration as required by the concurrent maneuvers for each phase.
f)Provide a continuous onsite bus shuttle service from designated parking lots to actual work
locations. Such onsite bus service should run in a constant schedule for no less than one hour
before and after the workday in an effort to spread out arrivals/departures of passenger cars to
the external network and to operate a reasonable onsite bus fleet size.

g) An integral part of the overall Traffic Management Plan is to minimize the use of external trucks
by transporting most construction freight (material, equipment, and modules) via water. To that
extend, the project will build two separate site preparation berths to be in operation for Early
Works. In addition a dedicated Marine Off-site Facility (MOF) will also be available for themechanical scope of the project and throughout the labor peak construction period. As a result,truck traffic will be largely stay within the site boundaries of the site and off the public roads.
h) Finally, the plan calls for restricting any project-generated truck traffic during the personnel
commuting time windows at the labor peak period.
Note that a video clip illustrating the impact of implementing these suggestions is available forviewing.

Company Confidential

Page 9 of 9

PLAQUEMINES LNG AND GATOR EXPRESS PIPELINE PROJECT
Resource Report 5
APPENDIX 5C
Traffic Management Plan for Pipeline System Construction

Traffic Management Plan for Pipeline Construction

Gator Express Pipeline Project

Submitted by:
EN Engineering
Warrenville, Illinois

Gator Express Pipeline Project
Traffic Management Plan for Pipeline Construction

TABLE OF CONTENTSINTRODUCTION................................................................................................................ 1
TRAFFIC MANAGEMENT ................................................................................................. 2
Public Roads and Construction Access .................................................................... 2
2.1.1 Public Roads ............................................................................................ 2
2.1.2 Right-of-Way Access ................................................................................3
2.1.3 Road Crossings ........................................................................................ 3
Pipe and Equipment Delivery .................................................................................... 4
2.2.1 Pipe Delivery ............................................................................................ 4
2.2.2 Construction Equipment Delivery..............................................................5Worker Commute and Parking .................................................................................. 5
CONSTRUCTION METHODS ............................................................................................ 5
HDD Sites ............................................................................................................ 6
Push Site Locations ............................................................................................. 6
Conventional/Upland Locations............................................................................ 6

Prepared By:

EN Engineering Project Number: 157407
Revision
No.

A
B
C
D

Prepared
By

Date

ML

Approved

Checked
By

Date

Date

03/22/16

PT

03/24/16

NP

03/24/16

Issue for Client Review.

ML

06/02/16

PT

06/03/16

NP

12/05/16

Issue for Client Review.

ML

06/02/16

PT

1/11/17NP

1/13/17

Revision to Table 1.1

ML

02/22/17

ML

02/22/17

NP

02/22/17

Byi

ClientApproval
By

BF

Date

02/22/17

Revision Description

Revised Per Client Comments

Gator Express Pipeline Project
Traffic Management Plan for Pipeline Construction

List of Tables
Page #

Table Name
Table 1.1 – Pipeline Lateral Summary

1

Table B-1 – TGP / TETCO Lateral Access Road Table

8

Table B-2 – TGP / TETCO Lateral Road Crossing Tables

8

List of Figures
Page #

Figure Name

7

Figure A-1 Transportation Plan Exhibit

List of Abbreviations and Acronyms
Gator Express Pipeline ProjectLouisiana State Highway 23
Main Line Valve
Meter and Regulator
Permanent Access Road
Right-of-Way
Temporary Access Road
Transportation Plan Exhibit
Traffic Management Plan for Pipeline Construction
Venture Global Gator Express, LLC

ii

Project
LA-23
MLV
M&R
PAR
ROW
TAR
Exhibit
TMP
Gator Express Pipeline

February 2017

Gator Express Pipeline Project Traffic
Management Plan for Pipeline Construction

GATOR EXPRESS PIPELINE PROJECT
TRAFFIC MANAGEMENT PLAN FOR PIPELINE CONSTRUCTIONINTRODUCTION
The Gator Express Pipeline Project (Project) will include two natural gas pipeline laterals totaling
approximately 26.8 miles in length. Proposed pipeline laterals comprise of two 42-inch-diameterlines (TGP Lateral – 15.1 miles and TETCO Lateral – 11.7 miles). The Project also includes
the construction of meter and regulator (M&R) facilities associated with each proposed
pipeline lateral. M&R facilities are to be located at proposed custody transfer locations,where natural gas will be received from existing pipelines. It is noteworthy that the TETCO
Lateral will be constructed in parallel with the TGP Lateral and installed within a common
ditch. See Table 1.1 for a summary of the details mentioned above.
The Project is located on the west side of the Mississippi River within the southern part ofPlaquemines Parish, Louisiana. The proposed pipeline rights-of-way (ROW) will traverse
varying terrain types including areas of upland, wetland, and open water. The differing typesof terrain will dictate the construction methods used to install the proposed pipelines, resulting
in various means of gaining access to the Project ROW for labor, equipment, and materials.
This document serves as a Traffic Management Plan (TMP) for Pipeline Construction for the
proposed Project. The purpose of this TMP is to:•••

Describe how Venture Global Gator Express, LLC (Gator Express Pipeline) will use,
improve, and maintain roads for construction of the Project;
Evaluate potential impacts of construction traffic on public roads and waterways nearpipe delivery docks, contractor yards and storage/staging yards; andDescribe how Gator Express Pipeline will execute equipment/employee access toand from the Project ROW.

Gator Express Pipeline will engage a competent contractor to carry out the construction stage of
the Project. Gator Express Pipeline or the Contractor will obtain any permits necessary to use
roads/cross roads described herein. The Contractor will adhere to the commitments outlined inthis TMP.
Table 1.1
Gator Express Pipeline Project
Pipeline Lateral Summary
Outer Diameter Total Length
Approximate Custody Transfer Location
Pipeline Lateral(inches)(miles)(Lat./long.)
TGP Lateral

42

15.05

N29.242958° / W89.534649°

TETCO Lateral

42

11.71

N29.255748° / W89.553040°

1

February 2017

Gator Express Pipeline Project Traffic
Management Plan for Pipeline Construction

TRAFFIC MANAGEMENT
Construction activities will create short term impacts on the Louisiana transportation network.
These impacts will be a result of construction activities crossing roads and waterways with the
movement of construction personnel, equipment, and materials to Project locations such as thecontractor yard, staging areas, designated parking locations, and the Project ROW.
The Contractor will institute road signage alerting drivers to pipeline construction activities, aswell as utilize flagman, where necessary, when equipment is crossing a road or traveling on a
public road. The Contractor will be required to use appropriate signage in the vicinity of work
areas and access road entrances, to clearly depict to the public where any potential traffic
delays could occur.
Measures will be implemented to reduce impacts that the Project will have on the
public transportation network. These measures will include, but are not limited to, utilizing
minimally invasive pipeline installation techniques, as well as varying methods of equipment
delivery for optimum efficiency. This TMP describes standards for which the Contractor shallfollow in an effort to ensure that all federal, state, and local regulations are adhered to.
2.1
2.1.1

PUBLIC ROADS AND CONSTRUCTION ACCESS
Public Roads

As mentioned, the Project will have minimal impacts on the transportation network within aclose proximity of where construction occurs. Walker Road and Louisiana State Highway 23(LA-23) will experience increased traffic volume. Increased road traffic will be caused
mainly by the construction of a pipe bridge over an existing levee and HDD operations forthe 42” TGP and TETCO Laterals. A 16-mile stretch of LA-23, south of Walker road and northof the proposed LNG terminal, will be most impacted by construction activity. As may be
expected, this activity will consist primarily of semi-trucks traversing to and from the pipe docklocation to deliver pipe joints to their designated location. Walker Road will serve as a publicroad that would provide direct access to the proposed dock location. Limited use of Lake
Hermitage Road will be required for the construction of the proposed pipeline laterals. See
Figure A-1, in attachment A, for a Transportation Plan Exhibit (Exhibit) which illustrates the
Project area and the public roads in the Project vicinity. Additional signage may be consideredon Lake Hermitage Road where a variety of construction activities will occur including: a slick
bore road crossing operation, construction related to the installation of a Main Line Valve(MLV), and above ground pipe bridge used to cross an existing non-federal levee.
To maintain safe conditions on roads that may be affected by pipeline construction, theContractor will adhere to all state and county vehicle weight limit regulations and will remove
excess soil that is left on the road surface from crossings of construction equipment. In
addition, when it is necessary for equipment to cross paved roads, mats or other appropriate
measures may be used to minimize damage to the road surface. In dry weather, necessary dust
control measures will be taken by the Contractor, specifically on roads with unpaved surfaces
such as Walker and Lake Hermitage Roads. If roadways are damaged during construction of
the proposed Project, Gator Express Pipeline or its Contractor will repair or reconstruct
the damaged roadway to the pre-construction condition.

2

February 2017

Gator Express Pipeline Project Traffic
Management Plan for Pipeline Construction

2.1.2

Right-of-Way Access2.1.2.1 Temporary AccessIn order for construction crews to gain access to the Project ROW, Gator Express Pipeline will
require the use of one temporary access road (TAR). More specifically, the TAR will provide
access for the Contractor to deliver pipe and equipment to the proposed HDD entry and exit
sites. This access road will experience both light-duty and heavy-duty traffic due to thedelivery of pipe and other major equipment used for construction. Due to existing soil
conditions, the TAR may require construction matting or clearing. Upon completion of the
Project, Gator Express Pipeline or its Contractor will return the land impacted by the TAR to its
pre-construction condition. For additional information on the proposed TAR see Table B-1(Attachment B).
To ensure the public’s awareness, the Contractor will install and maintain appropriate
construction fencing in applicable areas where construction access roads are directly adjacentto public access.
2.1.2.2 Permanent Access
Gator Express Pipeline has proposed the construction of one road to be used as a permanent
access road (PAR) for the Project. This PAR will be used throughout the lifetime of the pipeline
for inspections and maintenance of the MLV facility located within the Project’s proposed ROW.
The traffic impact associated with these periodical site visits will be negligible and will typicallyconsist of one worker in a pickup truck. VG will obtain the required permit(s) necessary toconstruct the PAR. Further details on this road are listed in Tables B-1 and B-2 (in Attachment
B).
2.1.2.3 Barge AccessConsidering that the majority, approximately 25.25 miles, of the proposed pipeline length will be
installed within open water, it will be necessary for barges to have access to theconstruction ROW. It is anticipated that the Contractor will primarily utilize the pipeline
construction ROW for barge access. However, the Contractor will have the option to utilize
existing canals and open water areas as practicable and will abide by federal, state andlocal regulations set forth for marine vessels. Figure A-1 in Attachment A illustrates the locationof the proposed barge access routes.
2.1.3

Road Crossings

Lake Hermitage Road will be the only public road crossed by the lateral pipelines. Thisroad crossing will be accomplished by a slick bore installation method, which will avoid the needto open cut a pipe trench through the existing road. The pipeline will be buried to a depth
required byapplicableroadcrossing
permits
andwillbedesignedtowithstand anticipated external loadings. To identify approaching construction, additionalsignage and traffic control personnel will be required during the installation of thecrossing. Should a temporary road closure be required, the Contractor will avoid closing
Lake Hermitage Road during peak traffic hours and will coordinate construction activities
with appropriate local and state officials to avoid or minimize potential traffic delays/impacts.
3

February 2017

Gator Express Pipeline Project Traffic
Management Plan for Pipeline Construction

PIPE AND EQUIPMENT DELIVERY
2.2.1

Pipe Delivery

Semi-truck and barge traffic associated with transporting pipe to the project area could causedelays in traffic flow, but such impacts will be temporary and short term. Pipe will be stored andthen barged in from a pipe coating plant, such as the Bayou Coating plant located in New Iberia,Louisiana. It is anticipated that pipe will be delivered by barge, as needed, directly from the pipe
coating plant. Depending on the location where the proposed pipe is to be installed, pipe will
either be left on the barge and taken directly to lay barges or offloaded at a dock location. The
Bayou Coating plant is approximately 150 miles away from the Project area. To reduce impacts
associated with semi-truck traffic, Gator Express Pipeline will use barges to transport the pipeon an as needed basis. The location of Bayou Coating, relative to the project vicinity, isillustrated in Figure A-1.
The following quantities are based on specifications allowing pipe to be stacked 3x high andpyramid loaded;
2.2.1.1 Pipe Delivered Directly to TGP/TETCO Lateral ROW
The majority of the pipe used for pipeline construction will arrive by barge and remain on thebarge until it is installed through either a barge lay or push-pull type installation method. A rakehaul type barge will be used in conjunction with lay barges for immediate installation in open
water areas. The rake-haul type barge is capable of handling an estimate of 45 concrete coatedpipe segments which equates to approximately 1,800 linear feet of pipe. In order to maintain aconsistent pipe supply, a single barge shipment containing 45 pipe segments will need to bedelivered every other day, on average. The impact on marine traffic associated with thisbarge delivery rate will be minimal, with little effect on existing waterway capacities.
2.2.1.2 Pipe Delivered to Barge Dock Location
Approximately 8,000 feet of pipe for the TGP and TETCO Laterals, will arrive by barge and be
unloaded onto semi-trucks at a designated barge dock location. Semi-trucks will deliver the pipe
segments to their proper staging location along the pipeline route. Public roads, as well as the
TAR and PAR, will be utilized for pipe delivery. Walker Road and LA-23 will serve as theprimary routes to and from the barge dock location and the pipe staging area. A box-haul typebarge will be used when delivering pipe segments to the barge unloading dock. A box-haul typebarge is estimated to carry 80 concrete coated pipe segments or 200 non-concrete coated pipe
segments which equates to approximately 3,200 feet and 8,000 feet in length, respectively. It is
expected that a full barge shipment will require two 12-hour working days for unloading. The
estimated time for pipe unloading applies regardless of concrete coated (1 pipe segment per
truck) or non-concrete coated (3 pipe segments per truck) pipe. This will equate toapproximately 40 semi-truck trips from the unloading dock to the staging area and back per day.
Most pipe delivered to the barge unloading site will be non-concrete coated as the majority ofpipe needing to be delivered by trucks will be used for HDD. This type of truck traffic would be
expected to last for approximately 2 working days. The Contractor will most likely elect to getahead of the pipe schedule and store extra pipe within the construction ROW to avoid potential
delays. Semi-trucks used for pipe delivery will not utilize the shoulder of public roads at any timethroughout construction. Semi-trucks will leave the barge docking location and drive directly tothe appropriate pipe staging location.
4

February 2017

Gator Express Pipeline Project Traffic
Management Plan for Pipeline Construction

2.2.2

Construction Equipment Delivery

Similar to the delivery of pipe segments via semi-trucks, LA-23 will serve as the main public roadused to deliver major construction equipment for the land based portion of the Project. Most
equipment, such as excavators, will be delivered by a low-boy type semi-truck trailer directly toeither the contractor yard location or to the pipeline construction ROW. Specialty equipment likethe Horizontal Directional Drilling (HDD) rig and the crane used to place the proposed pipe
bridge will require additional attention and a written plan from the Contractor. As previously
stated, Gator Express Pipeline will adhere to all state and county vehicle weight and width limit
regulations.
2.3

WORKER COMMUTE AND PARKINGThe Project will temporarily increase traffic on local road networks due to construction
employees commuting to and from work and trucks transporting equipment. Construction
workers will likely be located within a 50-mile radius of the Project and will commute to and fromthe contractor yard or designated employee parking location. It is expected that during peak
construction, approximately 100 employee transporting vehicles per day will be mobilized tothese locations. These vehicles will be used to transport operators, welders, foremen,inspectors and miscellaneous laborers. Some of these vehicles will travel to the contractor
staging yard before proceeding to the ROW. However, many of them, will go directly to a
designated parking area near Myrtle Grove Marina. Crew members would be transported, via
crew boats, from Myrtle Grove Marina to the Contractor’s lay barge(s). Boats transporting
workers from land to the lay barges can hold approximately 25 people. Multiple boats, which
remain with the crew throughout the work day, will be needed to transport the employees. An
estimate of 175 vehicles total (including equipment delivery) will be expected to travel LA-23 ona daily basis during construction.
Vehicle movements will generally occur during the daylight hours, with primary
movements occurring between 5:00 AM and 6:00 AM and at 6:00 PM. Typically, the work week
is six days, sometimes extending to seven days as required by the workload andconstruction schedule. During boring, directional drilling, and hydrostatic testing, work will be
conducted on a 24-hour basis until the drilling and testing is complete. Vehicles will also beentering and leaving the contractor yard throughout the day. This will include construction
management personnel, supply trucks, and vendors. Further, due to the linear andprogressive nature of pipeline construction, workers will be dispersed along the ROW, anddisruptions to traffic on local roads will be limited to short durations at any given location.

CONSTRUCTION METHODSThe Contractor will utilize three construction methods to install the proposed TGP and
TETCO Laterals. The following table illustrates the average construction site duration, truck
traffic and the anticipated increase in barge traffic (for delivery of pipe) associate with each
installation method. The daily truck and barge traffic values, shown in the table below, represent
a per day average required to maintain the corresponding installation method with noexcessive pipe storage or deficit. For instance, an HDD site will require an average of 7.5 pipe
segments per day. Since a barge is estimated to ship 200 non-concrete coated pipe segment
per load, the estimated barge delivery per day is 0.04.

5

February 2017

Gator Express Pipeline Project
Traffic Management Plan for Pipeline Construction

Gator Express Pipeline Project
Construction Related Traffic
Pipeline Construction
Operation

Average Site Duration(days)

Average Daily
Semi-Truck Traffic(Trucks - Ea.)

Average Daily
Barge Traffic(Barges - Ea.)

HDD

14

2.5

0.038

Push-Pull

27

0

0.67

Barge Lay

31.25

0

0.5

HDD SITESHDD equipment will be delivered on a low boy style semi-truck trailer and upon drill completion
will be demobilized. Approximately 15-20 workers will be present onsite during HDD construction
activities. It is anticipated that the Contractor will organize buses or car pool to the worksite andthe increased traffic impact should not pose an issue as the workers will be arriving early in themorning and departing the work site during evening hours.
PUSH SITE LOCATIONS
The push site required to install the pipelines through approximately 3 miles of wetland terrain will
operate from mechanically linked stationary barges. Necessary equipment will be delivered bybarge and will remain on the barge until the push operation is completed. Approximately 40-50
workers will be present onsite during construction activities. It is anticipated that the Contractor
will organize boats to get workers to the worksite, the increased traffic impact should not pose anissue as the workers will be arriving early in the morning and departing the work site during
evening hours.
CONVENTIONAL/UPLAND LOCATIONS
Site clearing, trench excavating and site restoration is considered the bulk of the uplandconstruction operation. Equipment will access the pipeline construction ROW from proposed a
TAR and temporary work areas. Contractor will most likely utilize traditional open cut trenching
methods to install the proposed pipeline in upland areas. Approximately 10-15 workers will bepresent onsite during upland construction activities, this includes all support personnel.

6

February 2017

PREPARED BY:

28100 TORCH PARKWAYWARRENVILLE, IL. 60555
TEL. 630-353-4000
FAX 630-353-7777
WWW.ENENGINEERING.COM

A
REV.
LEVEL

12/5/16RJLISSUED FOR REVIEW

TB

DATE

BY

DESCRIPTION

CK.

APP.

REVISIONSPLAQUEMINES LNG/GATOR EXPRESS PIPELINE PROJECTTRANSPORTATION PLAN EXHIBITPLAQUEMINES PARISH, LA
COUNTY
DATE:

02/18/16

STATE
SCALE:

1"= 3 MILESDRAWN BY: LOC. NO:

RJL

LOC

DRAWING NUMBER:

PLAPL-M-500

SHEET NO:

0

REV:

A

ATTACHMENT – B
ACCESS ROAD DATA

PAR 1
TAR 1

Approximate Location
Road Name
Station # / TGP MP
Access #760+00 / 14.4
Permanent Access Road 1
767+19 / 14.53
Temporary Access Road 1

Table B-1 TGP / TETCO Lateral Access Road Table
Access Road Length
Width Access Road Class
Access Road Areaftft
Permanent / Temp.
Acre
50
20
Permanent
0.02
8,565
24
Temporary
4.72

TOTALS =4.74

Area Disturbed
Acre
0.02
0.73

Perm. Fill
Cubic ft
511.000.00

Temp. Fill
Cubic ft
0.00
26,333.33

0.75

511.0026,333.33

Existing Conditions / Required Improvement
PAR 1
TAR 1

Currently undisturbed, construct 20' wide permanent access road.
Currently undisturbed. Existing conditions are suitable to support timber access road.
Majority of impacts associated with TAR 1 occur within LNG terminal property.

Approximate Location
Station # / TGP MP

Crossing Method
HDD or Open Cut

761+00 / 14.4

Slick Bore

Table B-2: TGP / TETCO Lateral Road Crossing Data
Temporary Fill (see Typ. 1.3-15e)
Road Name
Road TypeAccess From Perm. Fill
Road, Street, Access
Paved/Unpaved/Access Off Main Road Aggregate Fill (cft) Board Bridge (cft) Aggregate (cft)
Lake Hermitage Road

Public - Unpaved

Note that two slick bore crossing operations will occur at Lake Hermitage Road (TGP & TETCO Laterals)

8

HWY 23

0

0

0

Total

0.0

0.0

0.0

APPENDIX F
AIR PERMIT BACT SUMMARY

Appendix F Table 1
BACT Summary from Air Permit Application
July 2017
Emissions SourceGas-fired Combined Cycle
Turbines and AssociatedDuct Burners (CCCT1,
CCCT2, CCCT3, CCCT4,
CCCT5, CCCT6, CCCT7,
CCCT8, CCCT9,
CCCT10)Pollutant
NOX

CO

10.5
51.5
48.7
48.7
5

Proposed Emission Limits for Each Individual Source
ppmv
Limit Based on 30 Day Rolling Average During Normal
Operations
at 15% O2
lb/hr
Limit Based on 30 Day Rolling Average Duct Burnerand CC Turbine Operation
lb/hr
Limit Based on 2-Hour Average During Cold Start
lb/hr
Limit Based on 1-Hour Average During Warm Start
lb/hr
Limit Based on 1-Hour Average During Shutdown
ppmv
at 15% O2
lb/hr◦ Good Combustion Practices

18.9
13.6
13.6

lb/hr
lb/hr
lb/hr

PM / PM10 /PM2.5◦ Exclusive Combustion of Gaseous Fuel

8.0

lb/hr

◦ Good Combustion Practices Including Proper Burner Design

6.3
6.3
6.3

lb/hr
lb/hr
lb/hr

SO2

◦ Exclusive Combustion of Low Sulfur Fuels◦ Proper Equipment Design and Operation

4
0.7

ppmv H2S
lb/hr

0.3
0.3
0.3

lb/hr
lb/hr
lb/hr

◦ Catalytic Oxidation

1.1◦ Combustion of Gaseous Fuel2.2

ppmv @ 15%
O2
lb/hr

◦ Good Combustion Practices◦ Combustor Process Design with Proper Operation

0.7
0.6
0.6

lb/hr
lb/hr
lb/hr

Limit Based on 3-Hour Average During Normal
Operations
Limit Based on 3-Hour Average Duct Burner and CC
Turbine Operation
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown

520,455

tpy

Based on Annual Total per Turbine

9
31.21

ppmv
at 15% O2
lb/hr

54.6
54.6
54.6

lb/hr
lb/hr
lb/hr

25
52.78

ppmv
at 15% O2
lb/hr

24.3
24.3
24.3

lb/hr
lb/hr
lb/hr

◦ Exclusive Combustion of Natural Gas

4.9

lb/hr

◦ Good Combustion Practices Including Proper Burner Design

3.9
3.9
3.9

lb/hr
lb/hr
lb/hr

Limit Based on 3-Hour Average During Normal
Operations
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown◦ Exclusive Combustion of Low Sulfur Interstate Pipeline Quality Natural
Gas◦ Proper Equipment Design and Operation4

ppmv H2S

Based on Annual Average of H2S Content in Fuel

0.60

lb/hr

0.3
0.3
0.3

lb/hr
lb/hr
lb/hr

Limit Based on Annual Average During Normal
Operations
Limit Based on Annual Average During Cold Start
Limit Based on Annual Average During Warm Start
Limit Based on Annual Average During Shutdown◦ Combustor Process Design

1.4◦ Proper Operation

1.7

ppmv @ 15%
O2
lb/hr

◦ Good Combustion Practices◦ Combustion of Natural Gas

0.7
0.7
0.7

lb/hr
lb/hr
lb/hr

Limit Based on 3-Hour Average During Normal
Operations
Limit Based on 3-Hour Average During Normal
Operations
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown

475,382

tpy

Based on Annual Total per Turbine

CO2e◦ Exclusively Combust Low Carbon Fuel Gas◦ Good Combustion Practices◦ Proper O&M Practices◦ Insulation will be Properly Implemented for Surfaces Above 120 °F

NOX◦ Dry Low-NOX Combustor Design will be Used on Each Turbine◦ Good Combustion Practices◦ Combustion of Natural Gas

CO

PM / PM10 /
PM2.5

SO2

VOC

CO2e

BACT Report V8.0

◦ Catalytic Oxidation◦ Proper Equipment Design◦ Proper Operation

2.5

12.8

VOC

Gas-fired Simple Cycle
Turbines (SCCT1, SCCT2,
SCCT3, SCCT4)

Proposed Emissions Controls◦ Dry Low-NOX Combustor Design will be Used on Each Turbine◦ Low NOX Burners will be Installed on the Turbine Duct Burners◦ Selective Catalytic Reduction (SCR) will be Installed on the Turbine
System◦ Good Combustion Practices◦ Combustor Process Design◦ Proper Operation◦ Good Combustion Practices◦ Exclusively Combust Low Carbon Fuel Gas◦ Good Combustion Practices◦ Proper O&M Practices◦ Insulation will be Properly Implemented for Surfaces Above 120 °F

19Limit Based on 30 Day Rolling Average During Normal
Operations
Limit Based on 30 Day Rolling Average Duct Burnerand CC Turbine Operation
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown
Limit Based on 3-Hour Average Duct Burner and CC
Turbine Operation
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown
Based on Annual Average of H2S Content in Fuel
Limit Based on Annual Average Duct Burner and CC
Turbine Operation
Limit Based on Annual Average During Cold Start
Limit Based on Annual Average During Warm Start
Limit Based on Annual Average During Shutdown

Limit Based on 30 Day Rolling Average During Normal
Operations
Limit Based on 30 Day Rolling Average During Normal
Operations
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown
Limit Based on 30 Day Rolling Average During Normal
Operations
Limit Based on 30 Day Rolling Average During Normal
Operations
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown

June 2017

Appendix F Table 1
BACT Summary from Air Permit Application
July 2017
Emissions Source
Smaller Aeroderivative
Simple Cycle Combustion
Turbines (ASCCT1 andASCCT2)

Pollutant
NOX

Proposed Emissions Controls◦ Selective Catalytic Reduction (SCR) will be Installed on the Turbine
System◦ Good Combustion Practices

2.5

2.5
15.4
13.9
13.9
CO

9.0
9.0
9.0

lb/hr
lb/hr
lb/hr

Limit Based on 30 Day Rolling Average During Normal
Operations
Limit Based on 30 Day Rolling Average During Normal
Operation
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown

4.5

lb/hr

◦ Good Combustion Practices Including Proper Burner Design

1.8
1.8
1.8

lb/hr
lb/hr
lb/hr

SO2

◦ Exclusive Combustion of Low Sulfur Fuels◦ Proper Equipment Design and Operation

4
0.17

ppmv H2S
lb/hr

0.09
0.09
0.09

lb/hr
lb/hr
lb/hr

◦ Combustion of Gaseous Fuel

1.5

◦ Good Combustion Practices

0.51

ppmv @ 15%
O2
lb/hr

0.22
0.22
0.22

lb/hr
lb/hr
lb/hr

Limit Based on 3-Hour Average During Normal
Operations
Limit Based on 3-Hour Average During Normal
Operation
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown

Limit Based on 3-Hour Average During Normal
Operations
Limit Based on 2-Hour Average During Cold Start
Limit Based on 1-Hour Average During Warm Start
Limit Based on 1-Hour Average During Shutdown

Based on Annual Total per Turbine

Based on Annual Average of H2S Content in Fuel
Limit Based on Annual Average During Normal
Operation
Limit Based on Annual Average During Cold Start
Limit Based on Annual Average During Warm Start
Limit Based on Annual Average During Shutdown

CO2e◦ Exclusively Combust Low Carbon Fuel Gas◦ Good Combustion Practices◦ Proper O&M Practices◦ Insulation will be Properly Implemented for Surfaces Above 120 °F

134,901

tpy

NOX◦ Ultra Low NOX Burners◦ Good Combustion Practices

0.038

lb/MMBtu

Based on 3-Hour AverageCO◦ Exclusive Combustion of Fuel Gas◦ Good Combustion Practices

0.08

lb/MMBtu

Based on 3-Hour Average◦ Exclusive Combustion of Fuel Gas◦ Good Combustion Practices Including Proper Burner Design

0.0075lb/MMBtu

Based on 3-Hour Average

SO2◦ Exclusive Combustion of Low Sulfur Fuel Gas◦ Proper Engineering Practices

0.0006lb/MMBtu

Based on 3-Hour Average

VOC◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices◦ Exclusive Combustion of Fuel Gas

0.0054lb/MMBtu

Based on 3-Hour Average

CO2e◦ Exclusive Combustion of Low-Carbon Fuel Gas◦ Good Combustion Practices◦ Good O&M Practices◦ Insulation Will be Implemented for Surfaces above 120 °F.
◦ Low NOx Burners◦ Good Combustion Practices

104,114

tpy

0.138

lb/MMBtu

Based on 3-Hour Average◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.082

lb/MMBtu

Based on 3-Hour Average◦ Exclusive Combustion of Fuel Gas◦ Good Combustion Practices

0.0075lb/MMBtu

Based on 3-Hour Average

SO2◦ Proper Equipment Design◦ Proper Operation◦ Monitoring the Sulfur Content at the Facility Inlet

27.17

ppm at 68°F

Based on 3-Hour Average

VOC◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices◦ Exclusive Combustion of Fuel Gas

0.009

lb/MMBtu

Based on 3-Hour Average

CO2e◦ Exclusive Combustion of Low-Carbon Fuel Gas◦ Good Combustion Practices◦ Good O&M Practices◦ Insulation Will be Implemented for Surfaces above 120 °F.

384,350

tpy

NOX

CO

PM / PM10 /PM2.5

BACT Report V8.0

21.6

ppmv
at 15% O2
lb/hr◦ Exclusive Combustion of Gaseous FuelPM / PM10 /PM2.5

Acid Gas Thermal
Oxidizers (AGTO1,
AGTO2, AGTO3, AGTO4)

36

PM / PM10 /
PM2.5

VOC

Hot Oil Heaters (HOH1,
HOH2, HOH3, HOH4,
HOH5, HOH6)◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

Proposed Emission Limits for Each Individual Source
ppmv
Limit Based on 30 Day Rolling Average During Normal
Operations
at 15% O2
lb/hr
Limit Based on 30 Day Rolling Average During Normal
Operationlb/hrLimit Based on 2-Hour Average During Cold Start
lb/hr
Limit Based on 1-Hour Average During Warm Start
lb/hr
Limit Based on 1-Hour Average During Shutdown

20

Based on Annual Total

Based on Annual Total

June 2017

Appendix F Table 1
BACT Summary from Air Permit Application
July 2017
Emissions Source
Large (>560kW) Essential
Emergency Generators(EGEN1-EGEN12)500 kW Essential
Emergency Generators(
EGEN13/MJ001G Admin
and EGEN14/MJ002H
Jetty)

Firewater Pumps(FRPMP1 and FRPMP2)

BACT Report V8.0

Pollutant
NOx

Proposed Emissions Controls◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year
◦ An Ignition Timing Retard will be Installed on Each Engine

5.61

Proposed Emission Limits for Each Individual Sourceg/kW-hrCO◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

3.5

g/kW-hr

PM / PM10 /PM2.5◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

0.20

g/kW-hr

1.2E-05lb/hp-hr

SO2◦ Ultra-low Sulfur Diesel Fuel with Sulfur Content of 15 ppmv not to be
Exceeded (40 CFR 60 Subpart IIII)◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

VOC

◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

0.79

g/kW-hr

CO2e◦ Good Combustion Practices◦ Good O&M Practices◦ Insulation Will be Implemented for Surfaces above 120 °F.
◦ Limiting Normal Operations to 100 Hours per Year
◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year
◦ An Ignition Timing Retard will be Installed on Each Engine

2,411

tpy

3.50

g/kW-hrCO◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

3.5

g/kW-hr

PM / PM10 /PM2.5◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

0.20

g/kW-hr

1.2E-05lb/hp-hr

NOx

SO2◦ Ultra-low Sulfur Diesel Fuel with Sulfur Content of 15 ppmv not to be
Exceeded (40 CFR 60 Subpart IIII)◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

VOC

◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 100 Hours per Year

0.50

g/kW-hr

CO2e◦ Good Combustion Practices◦ Good O&M Practices◦ Insulation Will be Implemented for Surfaces above 120 °F.
◦ Limiting Normal Operations to 100 Hours per Year
◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 52 Hours per Year
◦ An Ignition Timing Retard will be Installed on Each Pump

81

tpy

2.62

g/hp-hrNOx

CO◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 52 Hours per Year

3.50

g/hp-hr

PM / PM10 /PM2.5◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 52 Hours per Year

0.15

g/hp-hr

SO2◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 52 Hours per Year

0.04

lb/galVOC◦ Good Combustion and Operating Practices◦ Compliance with 40 CFR Part 60 Subpart IIII
◦ Limiting Normal Operations to 52 Hours per Year

0.38

g/hp-hr

CO2e◦ Good Combustion Practices◦ Good O&M Practices◦ Insulation Will be Implemented for Surfaces above 120 °F.
◦ Limiting Normal Operations to 52 Hours per Year

28.18

tpy

21

Based on Annual Total

Based on Annual Total

Based on Annual Total

June 2017

Appendix F Table 1
BACT Summary from Air Permit Application
July 2017
Emissions Source
Equipment Leaks (FUG)

Cold Flare Pilot (CLDFLR
Pilot)

Warm Flare Pilot(WRMFLR Pilot)

LP Vent Pilot (LPFLR
Pilot)

Marine Flare Pilot (MFLR
Pilot)BACT Report V8.0

Pollutant
VOC

Proposed Emissions Controls◦ Proper Piping Design◦ The Provisions of LAC 33:III.2111 will be Followed

2.3

Proposed Emission Limits for Each Individual Source
tpy
Based on Annual Total

CO2e
NOX

◦ Proper Piping Design◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

6,500
0.068

tpy
lb/MMBtu

Based on Annual Total
When Flare is OperatingCO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.310

lb/MMBtu

When Flare is Operating

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.0070lb/MMBtu

When Flare is Operating4

ppmv H2S

When Flare is Operating

SO2◦ Proper Equipment Design and Operation◦ Combustion of Low Sulfur Gas in Pilot◦ Good Combustion Practices

VOC◦ Good Combustion Practices

0.218

lb/hr

When Flare is Operating

CO2e
NOX

◦ Good Management Practices and Proper Flare Design◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

979
0.068

tpy
lb/MMBtu

Based on Annual Total
When Flare is OperatingCO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.310

lb/MMBtu

When Flare is Operating

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.0070lb/MMBtu

When Flare is Operating4

ppmv H2S

When Flare is Operating

SO2◦ Proper Equipment Design and Operation◦ Combustion of Low Sulfur Gas in Pilot◦ Good Combustion Practices

VOC◦ Good Combustion Practices

0.218

lb/hr

When Flare is Operating

CO2e
NOX

◦ Good Management Practices and Proper Flare Design◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

979
0.068

tpy
lb/MMBtu

Based on Annual Total
When Flare is OperatingCO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.310

lb/MMBtu

When Flare is Operating

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.0070lb/MMBtu

When Flare is Operating4

ppmv H2S

When Flare is Operating

SO2◦ Proper Equipment Design and Operation◦ Combustion of Low Sulfur Gas in Pilot◦ Good Combustion Practices

VOC◦ Good Combustion Practices

0.218

lb/hr

When Flare is Operating

CO2e
NOX

◦ Good Management Practices and Proper Flare Design◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

979
0.068

tpy
lb/MMBtu

Based on Annual Total
When Flare is OperatingCO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.310

lb/MMBtu

When Flare is Operating

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.0070lb/MMBtu

When Flare is Operating4

ppmv H2S

When Flare is Operating

SO2◦ Proper Equipment Design and Operation◦ Combustion of Low Sulfur Gas in Pilot◦ Good Combustion Practices

VOC◦ Good Combustion Practices

0.218

lb/hr

When Flare is Operating

CO2e◦ Good Management Practices and Proper Flare Design

979

tpy

Based on Annual Total

22

June 2017

Appendix F Table 1
BACT Summary from Air Permit Application
July 2017
Emissions Source
Cold Flare MSS(includes Purge)(CLDFLR MSS)

Warm Flare MSS(includes Purge)(WRMFLR MSS)LP Flare MSS(includes Purge)(LPFLR MSS)

Marine Loading Flare
Gassing Up Operations(MFGU)BACT Report V8.0

Pollutant
NOX

Proposed Emissions Controls◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

139.6

Proposed Emission Limits for Each Individual Source
lb/hr
Maintenance/Start up/Shutdown Operations

CO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

636.3

lb/hr

Maintenance/Start up/Shutdown Operations

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

15.2

lb/hr

Maintenance/Start up/Shutdown Operations

SO2◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

1.4

lb/hr

Maintenance/Start up/Shutdown Operations

VOC◦ Good Combustion Practices

42.2

lb/hr

Maintenance/Start up/Shutdown Operations

CO2e
NOX

◦ Good Management Practices and Proper Flare Design◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

14,441
232.5

tpy
lb/hr

Based on Annual Total
Maintenance/Start up/Shutdown Operations

CO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

1,060.0

lb/hr

Maintenance/Start up/Shutdown Operations

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

25.3

lb/hr

Maintenance/Start up/Shutdown Operations

SO2◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

2.3

lb/hr

Maintenance/Start up/Shutdown Operations

VOC◦ Good Combustion Practices

70.2

lb/hr

Maintenance/Start up/Shutdown Operations

CO2e
NOX

◦ Good Management Practices and Proper Flare Design◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

14,836
24.9

tpy
lb/hr

Based on Annual Total
Maintenance/Start up/Shutdown Operations

CO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

113.6

lb/hr

Maintenance/Start up/Shutdown Operations

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

2.7

lb/hr

Maintenance/Start up/Shutdown Operations

SO2◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices

0.3

lb/hr

Maintenance/Start up/Shutdown Operations

VOC◦ Good Combustion Practices

7.7

lb/hr

Maintenance/Start up/Shutdown Operations

CO2e
NOX

◦ Good Management Practices and Proper Flare Design◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices◦ Marine Gas Recovery for Loading Return Gas with Methane Content of
80% or Greater

13,980
19.6

tpy
lb/hr

Based on Annual Total
Gassing Up Operations

CO◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices◦ Marine Gas Recovery for Loading Return Gas with Methane Content of
80% or Greater

89.1

lb/hr

Gassing Up Operations

PM / PM10 /PM2.5◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices◦ Marine Gas Recovery for Loading Return Gas with Methane Content of
80% or Greater

2.2

lb/hr

Gassing Up Operations

SO2◦ Proper Equipment Design◦ Proper Operation◦ Good Combustion Practices◦ Marine Gas Recovery for Loading Return Gas with Methane Content of
80% or Greater

0.2

lb/hr

Gassing Up Operations

VOC◦ Good Combustion Practices◦ Marine Gas Recovery for Loading Return Gas with Methane Content of
80% or Greater

0.4

lb/hr

Gassing Up Operations

CO2e◦ Good Management Practices and Proper Flare Design◦ Marine Gas Recovery for Loading Return Gas with Methane Content of
80% or Greater

4,045

tpy

Based on Annual Total

23

June 2017

Appendix F Table 1
BACT Summary from Air Permit Application
July 2017
Emissions Source
Pipeline Pigging

Concete Bin Vents (CBV1,
CBV2, CBV3)
Batch Concrete
Operations

Batch Concrete
Non-Emergency Engines(CBGEN1, CBGEN2,
CBGEN3)

Proposed Emissions Controls◦ Limit number of pipeline pigging activities to six per year
◦ FlareCO2e
PM / PM10◦ Limit number of pipeline pigging activities to six per year
◦ Any present storage silos or/and weigh hoppers will use cartridge
filters◦ Aggregate supplier to provide on-site delivery of aggregate that is prewashed◦ Water sprays on all aggregate and sand storage and handling
operations◦ Good Combustion and Operating Practices◦ Selective Catalytic Reduction in Compliance with Tier 4 Standards

0.39
0.01

tpy
gr/dscf

4

tpy PM

Based on Annual Total
Applicable to Point Source (Storage Silos and Weigh
Hoppers with Cartridge Filters)
Based on Annual Total

3

tpy PM10

Based on Annual Total

0.40g/kW-hr◦ Proper Engine Design and Operation with Good Combustion Practices◦ Exclusively Combust Diesel for Improved Combustion Efficiency◦ Oxidation Catalyst in Compliance with Tier 4 Standards

3.5

g/kW-hr◦ Exclusively Combust Diesel for Improved Combustion Efficiency◦ Proper Engine Design and Operation◦ Each Generator will be Equipped with a Diesel Particulate Filter

0.20

g/kW-hr

PM / PM10

NOx

CO

PM / PM10 /PM2.5

0.00142

SO2◦ Ultra-low Sulfur Diesel Fuel with Sulfur Content of 15 ppmv not to be
Exceeded◦ Proper Engine Design and Operation with Good Combustion Practices

3.7E-04lb/hp-hr

VOC◦ Oxidation Catalyst in Compliance with Tier 4 Standards◦ Proper Engine Design and Operation with Good Combustion Practices

0.19

g/kW-hr

CO2e◦ Good Combustion Practices◦ Good O&M Practices◦ Insulation Will be Implemented for Surfaces above 120 °F.
◦ Follow the best practical house keeping and maintenance practices as
specified in LAC 33:III.2113

1,226

tpy

Based on Annual Total

1.83E-01

tpy per tank

Based on Annual Total

1.81E-03

tpy per tank

Based on Annual Total

Diesel Fuel Storage Tank
1 and 2 (DFST1, DFST2)

VOC

Amine (DEA) Solvent
Surge Storage Tank 1 and
2 (SSST1, SSST2)

VOC◦ Follow the best practical house keeping and maintenance practices as
specified in LAC 33:III.2113

Amine Flash Drums(AFD1, AFD2, AFD3,
AFD4, AFD5, AFD6)

VOC◦ Route emissions to the Acid Gas Thermal Oxidizer System

See Acid
Gas Thermal
Oxidizer
LimitsIso-pentane Tanks(PESD1 (previously 128V0004), PESD2)

VOC◦ Route emissions to the Warm FlareSee Warm
Flare Limits

BACT Report V8.0

Proposed Emission Limits for Each Individual Source
tpy
Based on Annual Total

Pollutant
VOC

24

June 2017

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G-14

U.S. Army Corps of Engineers (USACE). 2018. Tonnage for Selected U.S. Ports in 2015.
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G-15

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G-16

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G-17

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Bose (Secretary, Federal Energy Regulatory Commission).

G-18

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Accessed: March 2017.

G-19

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G-21

APPENDIX HRESPONSES TO COMMENTS
ON THE DRAFT ENVIRONMENTAL IMPACT STATEMENT

Venture Global Plaquemines LNG, LLC and Venture Global Gator Express
Pipeline, LLC
Plaquemines LNG and Gator Express Pipeline Project
INDEX
Document Number - Commentor
Individuals
0001 – Paul Hogan
0002 – Guy Gillespie
0003 – Chris Robertson
0006 – Steven Hourcade
0008 – Leslie Gaudet
Public Meeting Transcript
0004 – Professional Shorthand Reports, Inc.
Companies and Organizations
0005 – Plaquemines Port and Terminal District
State and Federal Agencies
0008 – Louisiana Department of Wildlife and Fisheries

0001
0001-1After research the commenter's claim, we conclude that nonatural gas pipeline or servitude exists on the alignment
presented by the comment. Neither the Port of Plaquemines
nor the USACE is aware of any planned pipeline similar to
the alignment identified.

0001-1

During the application prefiling process, Venture Global did
consider a lateral route referred to as the Southeast Lateral
Pipeline Route that was similar to the route identified by thecommenter. This is discussed in Section 3.5.1.2 of the FEIS.
Ultimately Venture Global decided not to use the Southeast
Lateral Pipeline Route after it was determined that the
proposed SW lateral pipelines and interconnection with TGP
and TETCO systems would provide the necessary feed gas forthe facility and allow colocation along most of their routes
avoiding environmental impacts associated with a 3rd lateralpipeline as would be the case for the Southeast Laterals.

0002
0002-1
Section 4.0, Environmental Consequences, describes for thereader how this EIS presents its determinations of the potential
impacts of this project on environmental resources, including
the use of the term "temporary." Presenting the different levelsof impact according to the expected duration is consistent withfederal agency guidance on the preparation of EISs. The
determinations of impact are based on the Project effects on
the existing environmental condition. See section 4.13 for a
discussion on cumulative impact.

Docket Nos. CP17-66-000 and CP17-67-000
Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC Plaquemines LNG and
Gator Express Pipeline Project
OEP/DG2E/Gas Branch 1
Comments on EIS:I own property approximately three miles from the proposed project, and have objections to the DEIS in
the above-referenced docket numbers, as follows:
1. My primary objections relate to the manner in which environmental impacts are described as“minor” or “temporary.” The analysis appears to be based on impact to a stable, secureenvironment. That is not the present reality of the wetlands in the lower Mississippi Delta ,which are in a precarious state of decline. Assessing the impact of this project as if the current
environment is healthy and stable is an entirely inadequate approach. A proper analogy would
be the assessment of depriving drinking water from a person for a day; if the person were
thriving and healthy, the impact might well be assessed as “temporary” or “minor.” However, if
the person were already in declining health, the effect could be fatal.

0002-10002-2
Commercial and recreational fisheries are discussed in Section
4.6.3 of the FEIS. However, we have prepared an additional
analysis of the commercial and recreational fisheries present in
the vicinity of the Project and the expected socioeconomic
impacts associated with the Project. See the revised text in
Section 4.9.3.2 of the FEIS.

The EIS under consideration follows the latter approach, and is patently unreasonable in light of
the actual environment at present.
For example, regarding the pipeline portion of the project and the related canals, the EIS statesthat some of the dredging will be left to fill in “naturally” after construction. This, at a time thatthe entire area is LOSING landfill at an alarming rate, not “filling in.”
The fact of coastal erosion is well established. It is equally well-established that pipelines, canals,
and oil-industry intrusions have accelerated the loss of land mass in this area. A representative
sample of studies documenting these facts are linked below, and are incorporated herein byreference.
My objection is to any EIS that does not adequately address the effects on wetlands that are
already DECLINING. This one certainly does not do so.

2. Secondly, the EIS does not address in any way the impact on sport and charter fishing in the areasurrounding the proposed project. These activities are a major source of commerce and income
in Plaquemines Parish. A search of the DEIS does not reflect any reference to this factor.

0002-2

0002
Representative sample of studies documenting the state of coastal erosion in the area:
A. Louisiana Coastal Wetlands: A Resource At Risk, found at https://pubs.usgs.gov/fs/la-wetlands/
B. Relationship between canal and levee density and coastal land loss in Louisiana, found athttps://www.osti.gov/biblio/5564013
C. Coast 2050: Toward a Sustainable Coastal Louisiana, found athttps://www.doi.gov/sites/doi.gov/files/migrated/deepwaterhorizon/adminrecord/upload/Louisiana-Coastal-Wetlands-Conservation-and-Restoration-Task-Force-and-the-WetlandsConservation-and-Restoration-Authority-Coast-2050.pdf

0002-2
Continued

0002-2 cont'd

0003
0003-1Thank you for your comment.

0003-1

0004

Transcript of the Testimony ofDraft Environmental Impact Statement

Date taken: December 11, 2018

In the Matter of: Venture Global Plaquemines LNG,
LLC and Venture Global Gator Express, LLC

All electronic deposition & exhibit files
are available at <<<www.psrdocs.com>>>.
Please call or e-mail reporters@psrdocs.com if you need a
Username and Password.

Professional Shorthand Reporters, Inc.
Phone:504-529-5255
Fax:504-529-5257
Email:reporters@psrdocs.com
Internet: http://www.psrdocs.com

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 1

UNITED STATES OF AMERICAFEDERAL ENERGY REGULATORY COMMISSION

IN THE MATTER OF:*****************************VENTURE GLOBAL PLAQUEMINES *LNG, LLC and VENTURE GLOBAL*GATOR EXPRESS, LLC******************************

DOCKET NOS.
CP17-66-000
CP17-67-000

DRAFT ENVIRONMENTAL IMPACT STATEMENTFOR THE PROPOSEDPLAQUEMINES LNG AND GATOR EXPRESSPIPELINE PROJECTPUBLIC COMMENTS
BELLE CHASSE LIBRARY
8442 Highway 23
Belle Chasse, Louisiana 70037
Tuesday, December 11, 2018
4:00 p.m.

ALSO PRESENT:JAMES WISNIEWSKIREPORTED BY:
LINDA G. GRIFFIN, RPR
Certified Court Reporter
State of Louisiana
Professional Shorthand Reporters, Inc.
Offices in New Orleans and Baton Rouge

1-800-536-5255
www.psrdocs.com

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 2

1
2
3

PUBLIC COMMENT
INDEX
1.

4
5
6

2.

7

SCOTT EUSTIS.....................
Community Science Director
Gulf Restoration Network
1010 Common Street, Suite 902
New Orleans, Louisiana 70112
MAYNARD JACKSON "SANDY" SANDERS..
Executive Director
Plaquemines Port Harbor& Terminal District

PAGE
3

15

8
3.

Gary Silbert ....................
Business Development Manager
Greater New Orleans, Inc.

17

4.

Michelle Herbert, Chairwoman ....
Plaquemines Association ofBusiness & Industry

18

5.

Paul Matthews ...................
Deputy Port Director
Plaquemines Port Harbor& Terminal District
Foster A. Creppel ...............
Sole Proprietor; Woodland
Plantation
Plaquemines Parish Tourism
Commission
Colette Pichon Battle, Esq. .....
Executive Director
Gulf Coast Center for Law & Policy
Reverend Tyronne Edwards ........
PO Box 1383
Braithwaite, Louisiana 70040
Benny Rousselle .................
Council Member, District 5
Plaquemines Parish Government
Plaquemines Port Harbor& Terminal District

21

9
10
11
12
13
14
15

6.

16
17
18

7.

19
20

8.

21
22

9.

23
24
25

Professional Shorthand Reporters, Inc.
Offices in New Orleans and Baton Rouge

22

32

34

35

1-800-536-5255
www.psrdocs.com

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-1
Because the Commission does not have a program for or
direct the development of the natural gas industry's
infrastructure, either on a broad regional basis or in the designof specific projects, and does not engage in regional planning
exercises that would result in the selection of one project overanother, we have determined that it would not be appropriate
to prepare a programmatic EIS. This EIS analyzes the
project-specific impacts of Plaquemines LNG, and includes a
discussion of cumulative impacts associated with other nearby
actions affecting the environment in the same geographic
scope.

Page 3

1

*

2
3

*

*

SCOTT EUSTIS
MR. EUSTIS:

4

Scott Eustis, E-U-S-T-I-S,

51010 Common, New Orleans, Louisiana.

6

I'm here representing the Gulf

7

Restoration Network.

8

And, yeah, we've had some9

objections that were on a different

10

Federal record, but we'd like to have11

them for this one as well.

12

You know, this proposal is one

13of tens of similar projects with the14same economic objective without a15

purpose.

16

proceed without a Regional Programmatic

17

Environmental Impact Statement for all

18

such economically connected actions for19

all across New Orleans and Galveston

20

Districts.

21

We don't think the project canWell, you all aren't -- that's

22

for the Corps, but, you know, from

23

Corpus Christi all the way over this24

way, and even Mississippi and Alabama,

25

there are so many of these things

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0004-1

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 4

1

proposed that have a tremendous wetland

2

and water and air impact, power impact,3

tremendous emergency management

4

implications, but there's no real

5

statement of need.
0004-2

6

In fact, you know, we heard

7

that the -- we hear about the future8

without action is that the gas will

9

still be exported whether or not this10

terminal is built, so we feel that11

there's no need to put such an explosive

12

facility with lots of dangers to other13

Federal projects, as well as us who live

14

here.

15

zone, you know.

You know, why put this in a flood

160004-3
Venture Global has proposed in its application the installationof a floodwall that would protect the site from the impacts ofstorm surges as well as sea level rise.

We think there really needs to17

be a reckoning if the United States is18

going to move forward with this gas

19export.

20

and it probably should be in a place

21

that's not so vulnerable to catastrophic

22

flooding.

They need to pick a good place,
0004-323

But we just get -- it's like a24pox, and it seems like -- you know, we25

saw this with the coal export terminals

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0004-2
As discussed in more detail in section 4.12.5, DOT PHMSA,
USCG, and FERC share responsibility in the safety, security,
and reliability oversight of the LNG facilities. DOT PHMSA's
issued a LOD on April 3, 2019 evaluated the Project against its
safety requirements for siting a facility and maintaining
applicable exclusion zones based on impacts of various
hazards, including flammable and toxic vapor dispersion,
overpressure or blast wave effects due to an explosion of
flammable vapor, pool and jet fires, and consideration of somecascading effects. USCG issued a LOR on January 23, 2017indicating the Lower Mississippi River would be considered
suitable for accommodating the type and frequency of LNG
marine traffic associated with this Project. The LOR also
considers Zones of Concern as discussed in section 4.12.5. In
addition, FERC staff evaluated the preliminary engineering as
to whether sufficient layers of protection would be in place toreduce the risk of offsite impacts to the public from hazards,
including from various releases that can result in flammableand toxic dispersion, explosions from ignited flammable vapor
clouds, pool and jet fires, and potential cascading damage.
Based on the proposed layers of protection, FERC staff
recommendations, USCG LOR, and DOT PHMSA's LOD, weconcluded that there would not be a significant risk or there
would not be a significant increase in risk to the public.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-4
Venture Global has proposed in its application the installationof a floodwall that would protect the site from the impacts ofstorm surges as well as sea level rise. Socially vulnerable
populations are discussed in Section 4.9.9 of the EIS.

Page 51

in Plaquemines, in particular.

2

this race to the bottom.

3

proposals go out.

4

that do the crappiest job try to get the5market first, and that's who wins.

6

not appropriate, because that's -- if7

you're going to cut costs to try to be

8

first, it's going to ruin the project.

9

There's

All theIt's like the ones

It's

You know, we think the10

investors should be able to reclaim

11

their money from a project like this,12

because it's not in the public's

13

interest; it's probably not in the

14

private interest either.

15

to stay on -- hopefully that's relevant,16

that, like, someone who put their money

17

into a project like this would be able18

to get it back.

19

this fail.

20

But, I guess,We see projects like

It's not in the public's

21

interest, of course, to locate such a22dangerous facility in an area that23

regularly experiences catastrophic

24

flooding, on top of a socially25

vulnerable population.

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Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-5
Alternative sites are discussed in section 3.0 of the EIS.

Page 6

1

And I think that we2

understand, you know, they made the land3deal with certain people in Louisiana

4and we know how that goes.

5

people in Louisiana get the money

6

because they own the land, but the7Federal government shouldn't follow that8kind of corruption.

9

alternative sites that aren't vulnerable

10

if the United States considers this part11of the national interest.

12

CertainIt should look at

0004-5

You know, this has a big

13

climate impact, of course.

14

God's own refrigerator, each one of15

these things, tremendous power needs,

16

tremendous temperature fluctuations, in

17

a time when we're really oscillating

18

down here.

19

oscillations, you know, week to week,

20

much less season to season.

21

the existing LNG export failed because

22

it froze, in Louisiana.

23

And then, of course, the increasing need24

for power to keep this stuff cold or it

25

gets really explosive or very dangerous.

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It's like

We have temperature

You know,

Who thought?

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 710004-6

And then, of course, the2impacts of climate to the facilities.

3

You know, we know that the SASOL GTL

4proposal -- you know, after Harvey, I

5flew over that facility and I saw, you

6know, what happens when you don't

7

look at -- you don't engineer a facility

8in the right spot, when you just go

9

with, you know, the corrupt way and you

10

just say, "Hey, this guy's giving us the11land; that's where we're going to build

12

it."

13

You know, SASOL North America

14

didn't have an Environmental Impact

15

Statement at all actually, and lo and16behold, they found there was lots of17wetlands underneath their site.

18

increased capital costs from 8 to 14

19

billion.

20

dropped 15 inches of rain on top of it

21

and they wrote off the whole project, so

22

it's --

23That

And then, of course, Harvey

You know, and what do we lose,

24

in Louisiana?

25

know.

We lost our wetlands, you

They scoured the site.

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0004-6
As noted in section 4.13.2.14 impacts on climate change froman individual project cannot be determined using current
climate modeling tools.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 81

it up.

We lost a whole town.

We lost2

our population base, which is our tax

3base, and then, what, it's just a big

4

scar.

There's nothing there.
0004-7

5

You know, it's not in the6public's interest to exploit ecological7

and economic vulnerabilities of this8

area with such a dangerous facility.

9

Climate change is the primary driver.

10Which, you know, climate change is

11caused by facilities like this, as a

12

primary driver of wetland loss across13

the New Orleans area, south Louisiana,

14

and we think there should be a

15

full-cycle quantitative carbon analysis

16of, like, how much is this facility

17

facilitating.

18

for gas is one of the big climate bombs.

19

It's one of the big reasons that the20earth could warm over the next 20 years.

21

So this is causing all of that

Because we know fracking

22and it's going to cause, you know,

23

driving the population of the United

24

States away from the coast, so there25

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0004-7
As noted in section 4.13.2.14 impacts on climate change froman individual project cannot be determined using current
climate modeling tools. Wetlands at the proposed Project site
provide a limited carbon sink for atmospheric CO2; wetlands
may also produce methane and emit it to the atmosphere. We
considered the change in surface conditions from vegetatedwetland to that of an industrial facility and its effect on the local
carbon balance. With implementation of the Project's
compensatory wetland mitigation plan, we conclude the local
carbon balance would not change. Socially vulnerable
populations are discussed in Section 4.9.9 of the EIS.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-8
As noted in section 4.13.2.14 there is no standard
methodology to determine whether, and to what extent, aproject's incremental contribution to GHG emissions would
result in physical effects on the environment for the purposes of
evaluating the Project's impacts on climate change, either
locally or nationally. Further, we cannot find a suitable method
to attribute discrete environmental effects to GHG emissions.

Page 91

this project.

2know, millions and millions of people is3

not in the economic interests of the

4

United States.

5

Because displacing, you

And then we also want -- you

0004-86

know, this facilitates fracking.

7

want the climate impacts of methane from8

the feedstock as well to be computed.

9

Also, the wetlands.

That pipeline is10

really interesting.

Impacting wetlands

11

impacts the carbon.

12We0004-9We want a marine traffic

0004-1013analysis, especially for the increasing

14

high water events on the river.

15

due to climate change, everything is

16

more vulnerable.

17

Again,

And we think, you know, we see

18

500-year rains annually on the Gulf

19

Coast now, so that's -- you know, the20

facility should be planned to get that21

amount of rain onto the facility.

22

lose power, which starts that chain of

23

potential even explosions from a24

facility like this.

25

You

We do think the project isProfessional Shorthand Reporters, Inc.
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0004-9The Applicant's compensatory mitigation plan (section 4.4.4) as
required by the Clean Water Act, Section 404 ensures no net
loss of wetlands and therefore would not impact carbon levels.

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0004-10The levee and floodwall design were evaluated against
500-year still water elevation with a 500-year wave crest andsea level rise. See section 4.12.4.5. Also marine transportation
is discussed in section 4.9.8.2. We also note that theequivalent return period for a storm event is specific to the spotor area where the storm hit and should not be compared to thetotal number of 500-year events that occur across the country
or region of the country.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-10 cont'dPage 101inconsistent with the State Master Plan.

2

There's a sandbar in the river in this3

place, so, you know, that sand is the4

future of the State, you know.

5

unclear whether this land is going to be6

here in 20 or 30 years, but if it is,7

the land's going to be here because we8

are going to dredge the sand resources

9of the Mississippi River and place10

wetlands back into place.

11

terminal on top of those sand resources

12

kind of precludes that restoration of13

the land, going forward.

14

But to put a

And just -- and it's not justthe land itself.

16

Sand resources are limited and they must17

not be squandered, given the already18

limited ability of the State and the19

Corps to reduce flood risks and20

implement our restoration plans.

21

mention the saltwater sill around here,22

around Belle Chasse, which is drinking

23

water for New Orleans.

25

It's money and time.

Not toSo the impacts of the sandbar,
you know, CPRA is looking at Belle

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Coastal Information Management System (CIMS) provided by
the Coastal Protection and Restoration Authority (CPRA),
Plaquemines LNG's Terminal site and marine facilities are not
located over mapped sand resources. The nearest potential
borrow area within the Mississippi River is located on the riverbottom about 1,000 feet off the west bank. Further,
Plaquemines LNG's marine facilities will be in an area that has
been previously been modified by placement of riprap andconcrete revetment blankets, likely precluding its consideration
as a potential borrow area. In short, the Venture Global Projectwill not affect the potential use of the river as a sand borrow
area for future use in wetland restoration projects.

It's

15

24

0004-110004-10
According to the LASARD Deposit Borrow Areas layer on theContinued

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0004-11

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-11 cont'dPage 11

1

Chasse and south for Louisiana's future,2

so that is actually important, and it's

3

important we don't lock those resources4

down with pilings.

5

the ports in deepwater locations, but to6

put them on sand resources is kind of a7silly thing to do for a deepwater port,

8

and it's also sabotaging the restoration

9

program, so --10within the Barataria Basin (i.e., those land/water interfaces witha hydrological connection to the open waters of the Gulf) thathave high re-oiling potential (i.e., areas that have experienced
periodic remobilization of weathered oil). The report indicates
all of the Project's shoreline crossings have a reoiling potential
classification of "no oil observed." If weathered oil is
encountered during construction, the Applicant would take theappropriate precautions to prevent resuspension ofcontaminated media and notify the appropriate authorities. This
information has been added to the EIS in Sections 4.6.3.2 and
4.7.1

You know, we can put

The pipeline.

You know, those11

wetlands were really oiled in BP, so any

12construction, digging up those -- you

13

know, of course, that's gone down and14

down every year, you know, it sinks a15little more, so you've got, you know,

16

oil that could be remobilized by ripping

17

up those marshes in northern Barataria

18

Bay.

19

remobilization of the DEEPWATER HORIZON

20

oiling, and that's a place where we get

21

oil spills all the time.

22

one this week from the Hilcorp drilling,23

right.

24

lives there is in critical condition.

25

The remaining stock will take decades to

So you've got to have a plan for

0004-12

We just had

And the dolphin population that

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0004-120004-11The Applicant prepared a report identifying shoreline areas
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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-12 cont'dPage 12

1

recover already, from 2010, and then the2four or more NRDAs that are ongoing in

3

Barataria Bay.

4

sediments while the remaining animals

5

are sick is not acceptable when that's

6been the main cause for decline in the7stock.

80004-130004-12
The resuspension of oiled sediments is discussed in the EIS in
Continued

Sections 4.6.3.2 and 4.7.1.

So re-oiling these oil

0004-14
Although several existing gas pipelines are located in
Plaquemines Parish and surrounding waters they do not carryenough available capacity to supply feed gas to the LNG
terminal. This is addressed in Section 3.2.2 of the FEIS.

And impact to the essential

0004-139fish habitat is unacceptable.

We have a10

lot of oysters in Barataria Bay, and11

that's a big part of the Louisiana

12

economy, the restaurant economy in New

13

Orleans.

14

oil on the oyster leases in the area,15

you know, when we've lost a lot of

16

oyster production on the east side;

17

Barataria Bay is now more important for

18

those fisheries, and it's really on the19applicant to avoid these wetlands and20

not remobilize that oil, when it can be

21

easily done, you know -- we want a

22

no-pipeline option.

23

completely understand the purpose of24

having a gas pipeline into the shallow

25

water of Barataria Bay.

So ripping up the bay, putting

Like why -- I don't
0004-14

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-14 cont'dPage 13really make a lot of sense, when you

2have tremendous numbers of gas pipelines

3

all over the area.

40004-150004-14
In section 4.9.9, Environmental Justice, we defined theContinued1

affected area and explain the use of available data to analyze
the subject. Overall, there is no trend toward placing facilities
near minority populations or populations below the poverty
level. We have determined that the Project would notdisproportionately affect low-income or minority populations.

So, you know, we've seen a lot

5of these things.

6

really badly built.

7

flooded.

8

to the temperature fluctuations that are9

not going to get any better, and then10

after 2040, everything goes off the

11chart.

Some of them areSome of them haveSome of them have failed due

12

So the location and residents

13

will be made all the more vulnerable by14

the climate impacts of the proposal, and15

then specifically, this is in an

16

Environmental Justice Community,

17

determined by a block group analysis, so

18

we need that kind of reckoning of,

19

like -- you know, we need a block group20of parish comparison to see, you know,21

who is impacted by this, and we want a

22site that, you know, doesn't

23

disproportionately impact minorities,

24particularly African-Americans and25

native Americans that live in this area.

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0004-15

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-15 cont'dPage 141

Because when we consider the2

future of Louisiana, those communities

3

have a lot of knowledge, to keep us fed.

4

And the communities within the block's

5

range of the terminal are

6

disproportionately minorities, so we

7want to have a different site.

0004-15
Continued

8

So, yeah, this site is one of9

the worst sites for this kind of thing10

across Texas to Mississippi, so -- and11

really, rather than build tens of these12

dangerous facilities without a proven13

market and, you know, the proposal, have14

the proposal succeed on the basis of15

cost-cutting and what land deals they16

can make with rich folks, in whatever17

state they're in, or how fast they can

18

build it, we do think that FERC needs to

19

look at a Programmatic EIS for all of

20

these things, and such a process would,

21

you know, provide a lot of guidance to22

an industry currently that's being run

23

like a casino.

24

best ideas for LNG export to rise to the25

top rather than have a race to theProfessional Shorthand Reporters, Inc.
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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 15

1bottom.
0004-16

2

So, yeah, to sum up, a3

Programmatic Environmental Impact

4

Statement would also work to ensure that5

this LNG export is something that the6

United States actually needs and it's

7

built to withstand the climate impacts,

8

and we're talking 500-year rains.

9is the new 100-year.

10of rain we see every year, from Texas to11

Mississippi, somewhere.

That

That's the amount

12

So, you know, it needs to be

13

built to withstand that kind of water

14

coming, and built in a way it does not15

target African-American and Native

16

American communities with17

disproportionate impacts, and built in a18

way that does not threaten marine

19

mammals with habitat impacts or

20

hazardous waste.

21
22

25

Furthermore, we recognize that a 500-year flood event has
been recommended as the basis of design for criticalinfrastructure in publications, including ASCE 24, Flood
Resistant Design and Construction. Therefore, we believe it isgood practice to design critical energy infrastructure towithstand 500-year event from a safety and reliability
standpoint for both SWEL and wave crests. See section
4.12.4.5. We also note that the equivalent return period for astorm event is specific to the spot or area where the storm hit
and should not be compared to the total number of 500-year
events that occur across the country or region of the country.
The proposed design would be able to withstand a 500-year
flood event.

0004-180004-19

So I think that's all I've

0004-17
We recognize that a 500-year flood event has been
recommended as the basis of design for critical infrastructure
in publications, including ASCE 24, Flood Resistant Design
and Construction. Therefore, we believe it is good practice todesign critical energy infrastructure to withstand 500-year
event from a safety and reliability standpoint for both SWEL
and wave crests. See section 4.12.4.5
The proposed design would be able to withstand a 500-year
flood event.

got.

23
24

0004-170004-16
Because the Commission does not have a program for or
direct the development of the natural gas industry's
infrastructure, either on a broad regional basis or in the designof specific projects, and does not engage in regional planning
exercises that would result in the selection of one project overanother, we have determined that it would not be appropriate
to prepare a programmatic EIS. This EIS analyzes the
project-specific impacts of Plaquemines LNG, and includes a
discussion of cumulative impacts associated with other nearby
actions affecting the environment in the same geographic
scope. See section 1.2.

*

*

*

MAYNARD JACKSON "SANDY" SANDERS
MR. SANDERS:

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0004-18
Executive Order 12898 (59 Federal Register [FR] 7629)
established a federal policy under which federal agencies must
identify and address, as appropriate, disproportionately highand adverse human health or environmental effects of its

0004
programs, policies, and activities on minority or low-income
populations.
In section 4.9.9, Environmental Justice, we defined theaffected area and explain the use of available data to analyze
the subject. Overall, there is no trend toward placing facilities
near minority populations or populations below the poverty
level. We have determined that the Project would notdisproportionately affect low-income or minority populations.

0004-19
Potential impacts on marine mammals are discussed in
Sections 4.6.3, 4.6.4, and 4.7.1 of the EIS. Generally, in
coordination with USFWS, NMFS, and LDWF regarding impact
minimization and mitigation measures described above, we
conclude that impacts on aquatic resources would be
temporary and minor.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-20Thank you for your comment.

Page 16

1

I'm Sandy Sanders.

I work for2

the Port.

3

Plaquemines Port Harbor and Terminal

4

District.

5

I'm the Executive Director,

I'm the Executive Director of

6

Plaquemines Port and I am very

7

responsible for Venture Global locating

8

on our shoulders, and I'm very excited

9about their arrival.

10

excited about the high paying jobs that11

they're going to bring.

I'm extremely

12

I have been accused of being

13

an environmentalist, and I don't mind

14

wearing that moniker.

15

always a happy medium where industry and16

environment and community can live with17

each other, and I love the way that --18

the thought of LNG is that we can do

19away with, you know, coal plants by20

having cleaner energy.

21

I think there's

I'm also promoting another LNG

22

here on the east bank.

23

tear for the last five years, inviting

24

industry here.

25

plants that are coming here, and they'reProfessional Shorthand Reporters, Inc.
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I have been on a

We've got two methanol

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0004-20

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 171clean, and I am a custodian of our2

environment here at the Port, and if it3

is bad business, I would not even4entertain them coming to our shores.

5So, obviously, I'm all for

6them, 100 percent.

7
8
9
10

*

*

0004-21Thank you for your comment.

*

GARY SILBERT,
MR. SILBERT:Good afternoon.

My name is

Gary Silbert.

12

Business Development for GNO, Inc.,

13

Greater New Orleans, Inc.

14

10-parish regional economic development

15

group serving Southeast Louisiana,

16

including Plaquemines Parish.

17

involved in helping Venture Global

18

identify and locate in Plaquemines

19

Parish, and it just makes perfect sense20

for them to be here to take advantage of21

the natural assets in Plaquemines

22

Parish, particularly, the infrastructure23

and natural gas.

250004-20
Continued

Thank you very much.

11240004-20 cont'd
Thank you for your comment.

I'm the Manager ofIt's theWe wereIt truly helps diversify the0004-21economy in Plaquemines Parish, which has

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Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-21 cont'd
Thank you for your comment.

Page 180004-21
Continued

1

been so dependent on oil, and it will2

create high paying jobs, it's a clean

3

industry, and this is a good company.

4

I've worked with representatives of the5company over the last couple of years

6and find them to be honest and7trustworthy and I feel good about

8

Venture Global.

9So, in summary, this will10

benefit the region, the parish, and will

11

serve to, as I say, create jobs,

12

diversify the economy.

13

industry and they'll be in the community

14

to stay.

It's a clean

15Well, I thank you for your16

interest, ensuring that this is done17

correctly, and if there is anything my

18organization or I can do personally to19

help FERC, as they further consider this20

project, I'm happy to help, and I just21urge you folks to approve the project.

22

Thank you so much.

23
24
25

*

*

*

MICHELLE HERBERTMS. HERBERT:

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-22
Thank you for your comment.

Page 19

1Okay.

As Chairperson of the2

Plaquemines Association of Business and3

Industry, my goals are to work toward

4

economic diversity and development for5

our parish.

6

it is especially fitting that I write

7

here to publicly express PABI's full

8

support for a multi-billion-dollar

9project that stands to not only10

diversify our local economy, but also

11

provide jobs and long-term stability.

12

With those goals in mind,

I'm referring to Venture

13

Global LNG's Planned Liquefied Natural

14

Gas Export Project, Plaquemines LNG,

15

that is poised to bring American natural

16

gas to markets around the world, from17

facilities right here in Plaquemines

18

Parish.

19

Plaquemines LNG has our0004-2220

support, because it stands to create as21

many as 1500 jobs during each of its two

22

construction phases, as well as 300

23

long-term permanent and good paying

24

jobs.

25

It also has our support,

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 201

because I know, firsthand, that2

Plaquemines LNG is dedicated to being a3

good neighbor.

4

moves through the early regulatory5

approval stages, from it's careful6

consideration to minimize the project's

7

environmental impact, to engaging the

8community in open dialogue to address

9questions or concerns, Plaquemines LNG

10

has shown a commitment to community that

11

goes well beyond economic benefits.

Even now, as the project12

I've met with many community

13

leaders in recent months, and a common

14

theme was the necessity of Plaquemines

15

Parish not relying on just one industry.

16

I believe Plaquemines LNG will bring a

17

new dynamic industry to our parish.

18

look forward to seeing the economic

19

development and all the benefits that20

will be created.

I

21

PABI has supported the22

Plaquemines Port's expansion plans since23

first presented to us.

24

to see a major project under way with a25

company like Venture Global.

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0004-22 cont'd
Thank you for your comment.
0004-22
Continued

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-23
Thank you for your comment.

Page 21

1
2
3
4

*

*

*

0004-24Thank you for your comment.

PAUL MATTHEWS
MR. MATTHEWS:
My name is Paul Matthews.

I

5

am Deputy Port Director at Plaquemines

6

Port Harbor and Terminal District.

7

I'm here to speak on behalf of

8

Port staff and to say that I'm

9

supportive of this project.

10

project that will have significant

11

economic impact, not only for the12parish, but the region and the state, as

13

an $8.5 billion project, between the14amount of jobs, the revenues to the Port15

for further Port development, and also,

16

the secondary tertiary tax dollars that17

it will create for the parish will be

18significant.

190004-23

This is aThis parish has lost a0004-2420

significant amount of revenues over the21

last few years due to their dependence

22

on oil and gas production.

23

the tax base has decreased in

24

Plaquemines Parish over the last four

25

years, each of the last four years, andProfessional Shorthand Reporters, Inc.
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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-24 cont'd
Thank you for your comment.

Page 220004-24
Continued

1

so this project is really paramount to2

the survival of this parish, in an3

economic manner, whether it's revenues

4

to the parish government, to the taxing

5

bodies, and also for job creation and6

wages, for those in the parish.

7

For someone who's from

8

Southeast Louisiana, born and raised in

9

New Orleans, I recognize the10significance of this project to the11

region, as it will also create indirect

12

jobs for the region.

13

As you may or may not know,

14for every one direct job that's created15

in the Port, you have three to four16

indirect jobs that are created within

17

this jurisdiction and region.

18

not just impactful for the local

19

economy, but for the regional economy

20

and for the state.

21
22
23

*

*

So it's*

FOSTER A. CREPPEL
MR. CREPPEL:

24

Foster Creppel.

25

Woodland Plantation and I'm also theProfessional Shorthand Reporters, Inc.
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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 23

1

President of Plaquemines Parish Tourism

2

Commission.

3

this things from two points of view.

4

I'm the owner of Woodland

5

Plantation, sole ownership, and the6

President of the Plaquemines Parish

7

Tourism Commission, and my mission is to8

promote tourism, ecotourism,

9

nature-based tourism, and any kind of10

tourism to Plaquemines Parish.

11
12
13
14
15
16
17
18
19

So I am concerned about

MR. WISNIEWSKI:
You're president of what?
MR. CREPPEL:The Plaquemines Parish Tourism
Commission.
MR. WISNIEWSKI:
Oh, the Tourism Commission.
MR. CREPPEL:The Plaquemines Tourism

20

Commission.

It's an independent

21

commission.

And I'm also the President

22

and Owner of Woodland Plantation, sole

23

proprietor.

24

After reading the article that25

came out in the paper, I felt compelled

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-25
The LNG terminal would permanently effect approximately 370
acres of wetland while the pipeline system would permanently
effect 2.8 acres as shown in Section 4.4.2.1 and 4.2.2.2. All
permanent loss is compensated for in the Applicant's
compensatory mitigation plan as required by the Clean Water
Act, Section 404 and the USACE permit. A detailed discussionof greenhouse gases can be found in section 4.11. and4.13.2.14.

Page 241

to come and visit and talk a little bit2

about this, because I know you all are

3

conducting an Environmental Impact

4

Study.

5

I see the effects that will be

6caused by the LNG plant.

7

new major emitter of greenhouse gases.

8

It will destroy 800 valuable acres of9wetlands.

10of pipeline canals, causing more erosion

11

and subsidence.

12

drilling for natural gas.

13

negative effects on the air and water

14

quality in the area.

15

for mitigation at this point, from what16

I've read.

17

It will be a

0004-25

There will be more dredging

0004-26

There will be more
There will be

0004-270004-280004-27
As shown in Section 1.2 this EIS focuses on the facilities thatare under FERC's jurisdiction, thus scope of this EIS is to lookat potential impacts that may be directly associated with the
Project. Any potential indirect drilling activities are not in thescope and, therefore, are not addressed by this EIS.

There is no plan

Venture Global would not

18

respond to repeated requests for

19

information.

20

migrant workers passing through Belle

21

Chasse, most days, and we can barely

22

absorb what we have passing through23

there now.

There will be 22 to 3200
0004-2924
250004-26
Adverse impacts are expected in marsh habitats due topipeline installation. The Applicant would coordinate with the
LDWF, USACE, and LDNR to identify bank stabilization
specifications and the specific locations to be installed as partof the ongoing review of the Project's applications for a Clean
Water Act (CWA) Section 404 Permit and a Coastal Use
Permit. See Section 4.2.2.2.

Five of these export
facilities are already approved andProfessional Shorthand Reporters, Inc.
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0004-28
Section 4.4.4 discussed the details of Venture Global's
compensatory mitigation plan (CMP) which was developed
through coordination with the USACE to offset impacts perpermitting requirements.

0004-29
The applicant estimates that during peak construction 2,380
personnel would originate from locations north of the LNG
terminal, passing through Belle Chasse. LADOTD traffic dataat points located in the northern part of Belle Chasse and thesouthern part of Belle Chasse along SH 23 indicate between
22,520 and 33,146 traffic counts per day, respectively. To
estimate the potential increase in traffic as a result ofconstruction activities the LADOTD recorded data were0004
averaged for each point and used as the average daily traffic
for that point. Project-related traffic was then added to thosedaily counts and a percent increase was calculated.
Project-related traffic would result in an increase, of 7.2
percent of daily trips at the southern location and 10.5 percent
increase at the northern location in Belle Chasse. These
numbers represent the potential peak increase in traffic andwould not be representative for the entire duration of
construction activities. See section 4.9.8.1 for detailed
discussion and mitigation measures.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-30
Venture Global does not have any plans to abandon any
aspect of the Project. If the Project facilities are abandoned in
the future, Venture Global would need to comply with theappropriate federal, state, and local regulations in effect at thattime.

Page 25

1

under construction.

Five more are2

approved, but not under construction

3

yet.

4

are proposed, but not approved or5licensed, of which this is one.

They're approved and licensed.

6

Many won't be built, in my7

opinion, and I predict a few will be

8brown fields within 25 years.

9

the plan for abandonment?

10

ground level ozone, which includes

11

nitrogen oxides, carbon monoxide and12volatile organic compounds.

180004-30

What'sThere will be

0004-31

13

The FERC warns that air

14emissions from the new industrial

15

facilities in the area may cause

16

problems for this project, and that17

7.75 million tons of carbon dioxide will18

be emitted from the new facility.

19

Braithwaite Methane

20

Manufacturing and NOLA Oil Terminal also21

are coming online.

22

Global, nor IGP Methanol included the23

other development in its modeling.

24
25

Neither Venture

Also not listed in the
recently announced is the recently

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0004-31
The EIS has appropriately included all projects reasonably
planned in the cumulative impacts analysis in Section 4.13.
Five other projects within the area of the proposed Venture
Global facility for the purpose of analyzing the potential
cumulative impact on air quality of these projects with the VGL
project. These 5 projects are: Gulf Coast Methanol (a/k/a IGP
Methanol); NOLA Oil Terminal, Braithwaite Methanol, Pointe
Celeste Container Terminal, and Pointe LNG Terminal. FERC
acknowledged that the Applicant did include the NOLA Oil
Terminal and Braithwaite Methanol in its refined air dispersion
modeling analysis and that the results showed that Venture
Global's terminal would not cause or contribute to any federal
Clean Air Act National Ambient Air Quality Standard(NAAQS). The draft EIS also acknowledged that neither the
Pointe Celeste Container or Pointe LNG projects had yet
submitted any permit applications to the LDEQ. When they doapply, LDEQ would need to evaluate their cumulative impact
with the facilities that already obtained permits.
The Applicant was not required to include the proposed IGP
Methanol facility in its modeling because such modeling was
conducted well before IGP Methanol submitted permit
applications for the facility. Further, although VGL did notinclude IGP Methanol emissions in its refined modeling, VGL's
modeling indicated that VGL's projected emissions would not
significantly contribute to any projected exceedance of the
NAAQS because the Applicant's projected emissions did notcontribute more than the Significant Impact Level at any
modeled receptor over the respective NAAQS. Thus even if
area emissions increased by an amount more than predictedby such modeling, due to the IGP Methanol facility operation,
Venture Global's contributions to those modeled receptors
would not increase, and would still be considered as
insignificant under EPA guidance. See section 4.13.11.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-31 cont'dPage 26

1announced 20-million-barrel Plaquemines

2

Liquid Export Terminal just north of3

Myrtle Grove.

40004-32
As described in section 4.5.4 the Coastal Live Oak-Hackberry
Forest occurs within the proposed pipeline construction andoperational footprint. Complete avoidance of this area is notpossible due to the necessity of constructing a pipe bridge over
the adjacent levee and for the HDD entry location associatedwith installing the pipelines under the floodwall. Venture Global
plans to sequence installation of the pipe bridge and pipelines
at this location to allow the same workspace to be utilized forconstruction of the pipe bridge and HDD entry locations thus
minimizing impacts on the forested area. A temporary accessroute located within the pipelines' permanentright-of-way would be required to reach the construction
workspace.

The Sierra Club has partnered5with the Old-Growth Forest Network to

6preserve, protect and promote the7

country's few remaining stands of8

old-growth forests.

9

have one dedicated old-growth forest in

10

each parish in the state.

11

Their goal is to

Lieutenant Governor Billy

0004-32

12Nungesser, whose job it is to promote

13

tourism to our state, owns a beautiful

14

stand of old-growth forest of oaks along

15

Bayou Grande Chenière.

16

forest of oaks and it's beautiful.

17

just behind the proposed site of the LNG

18plant.

19

it.

20

compromised if this development is

21

allowed.

220004-31
Continued

It's a virgin
It's

It's basically contiguous with

It would, without a doubt, be

I'm the President of the

23

Plaquemines Parish Tourism Commission,24

and our mission is to promote tourism to25

our beautiful parish, its history,

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According to Venture Global's construction and restoration
plan, most of the area disturbed by construction would berestored to pre-construction contours and allowed to revert toits current vegetative cover. No permanent vegetation
maintenance would occur between the entry and exit of theHDDs; vegetation maintenance would be limited to the uplandpermanent right-of-way located between the levee and HDD
entry locations. Of the Coastal Live Oak-Hackberry forest, tobe affected by construction and located interior of the levee,
about 2.1 acres would be cleared for temporary workspace and0.7 acre would be permanently maintained in a shrub
vegetative state following installation of the pipelines. The area
to be permanently maintained in a shrub vegetative state
makes up a small proportion, less than 1 percent, of the portionof the forest located interior of the levee.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-33
Construction of the pipeline system would impact EFH for
post-larval and juvenile life stages of white shrimp, brown
shrimp, and lane snapper, all life stages of red drum, and adultgray snapper. Affected EFH includes benthic substrates
and/or water column habitats in estuarine open water(collectively referred to in this assessment as estuarine open
water) and estuarine emergent wetlands. Potential adverse
impacts on EFH would primarily be temporary, while somepermanent impacts may be beneficial. Temporary adverse
impacts during construction would be minimized throughadherence to Venture Global's Project-specific Procedures,
SWPPP, and SPCC Plan. Vessel transits for commercial
fishing would be impacted negligibly resulting in negligible
effects to catch. Further discussion can be found in the EIS in
Sections 4.6.4 and 4.9.3.1. Also, marine transportation is
discussed in section 4.9.8.2.

Page 27

1

natural beauty, fishing, ecology, eco

2and birding tours, food, et cetera.

3

Creating an industrial corridor is not4going to help that.

5

I've built a beautiful

6

successful business, as many others

7

have, selling our natural beauty,

8hospitality, food and unparalleled9fishing.

10

fishermen make a living off the land.

11

think they will be negatively impacted

12

as well.

13

will be, but I know they will be.

14

Many other commercial

0004-33I

0004-34
A visual assessment from locations up to 2 miles from the LNG
terminal is provided in section 4.8.6.1. Woodland is locatedover 3 miles from where the LNG tanks would be located.
Impacts described in section 4.8.6.1 would be similar to thoseexperienced at Woodland.

And I'm not sure how much that

Woodland is a historic site on

15

the west bank, in Plaquemines Parish.

16

employ 25 people and contract with 30

17fishing guides.

18

two miles north of me.

19

like it if you had spent 22 years

20

building and beautifying an historic

21

site just to have an ugly polluting site

22

built within view?

23

I

The proposed site is
How would you

People, the peninsula we love,24

Plaquemines Parish, is eroding due to

25

man.

Subsiding is part due to man, andProfessional Shorthand Reporters, Inc.
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0004-34

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 28

1

sea levels are rising due to global

2

warming.

3

existence.

4

engineered its destruction.

5

to redesign and engineer its

6

restoration.

I did it at Woodland

7

Plantation.

Together we can save our8parish.

9

you.

10

We've designed andIt's timeThat's basically it.

Thank

MR. WISNIEWSKI:

11
12

We're in a fight for ourThank you very much.
MR. CREPPEL:13

I hope you guys make the right14

decision about this thing.

15

vanishing little place where we live.

16

don't know if you all know this parish

17very well, but I know it very well.

18This is aI

It's the newest land of all

19

America -- I don't know how well you all20

know Plaquemines Parish, but my21

ancestors are from the bayou.

22

great-grandfather was named Jacques

23

Creppel.

24

Jefferson Parish, on the bayou.

25

functionally illiterate.

My

He grew up down in Lower

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-35
As stated in section 4.12.4.5, a large portion of the facility
would be supported by pile foundations, which draw their
bearing capacity from a combination of tip bearing and side
friction. Fugro recommends in their geotechnical investigationthat piles would be installed to depths of 80 to 220 feet below
grade to ensure adequate bearing capacities were achieved.
While shallow foundations are proposed for some structures,the structures that would use shallow foundations are lightly
loaded and would not be sensitive to settlements (bothdifferential or total). In addition, a storm levee and floodwall
would be installed that takes into account a 500 year storm as
well as sea level rise and we recommend that the levee height
be maintained throughout the life of the facility.

Page 29

1kids.

My grandfather was one of 11.

2

And he moved up from Lower Jefferson to3

Crown Point, which is uptown to them,4but it's along the banks of Bayou

5

Barataria.

6

tributary of the main river at one time.

7

We got rid of the tributaries

Bayou Barataria was a8when we built the levee in 1928.

9

levee is only 90 years old.

10

re-introduce this river to our delta.

11

We need to lower our levees.

12change the way we're living down here or13

we won't exist.

14

That

We need to

We need toI have no idea why they're0004-35

15

here, thinking about building it on this16

narrow strip of dangerous land.

17

eroding rapidly, it's subsiding, and sea

18levels are rising, and I know it because

19

I see it.

20

It's

One of my dad's good friends

21is -- who I couldn't talk into coming to22this tonight, and I wanted him to -- Ed

23

Perrin, from Lafitte; he lives at the24very end of the Lafitte Highway down

25

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-36
A large portion of the facility would be supported by pilefoundations, which draw their bearing capacity from a
combination of tip bearing and side friction. In addition, Venture
Global has proposed in its application the installation of afloodwall that would protect the site from the impacts of storm
surges as well as sea level rise. Lastly, the shoreline of the
facility would armoring that would help mitigate shoreline
erosion.

Page 30

1been wanting to buy land from him for a2long time to build his house.

3"Grandpa, when are you going to sell me

4that land?"5

selling you that land."

6

not?

7

there."

8

build your house here."9

see that little levee over there, that10

two-foot high levee?"

11

been looking at this water for 70

12years."

13high levee wasn't there, that water

14

would be up to our steps."

He said,

And Ed says, "I'm not
He says, "Why

Because I want to build my house15

He says, "Because you can't
He says, "YouHe says, "I've

He says, "Now, if that two-footThis delta is eroding and0004-36

16

sinking.

17

things that weigh millions of tons, and18

they are built out of concrete and iron,

19

that are going to help sink it.

It doesn't make sense to build

20

One of my friends says,

21"Foster, we have a bad economy."

22

that's on the politicians and the powers

23that be, in my opinion, because we've

24

had a lot of natural resources in

25

Plaquemines Parish.

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 311commercial seafood.

We've had the Port.

2

We've had oil and gas.

3

agriculture, timber and tourism, but yet

4

we're broke.

We've had5

That's not because we haven't

6

developed enough industry or business.

7

It's because we've mismanaged it.

8this is another example of9mismanagement.

And

10

He said, "Well, give me

11some -- we need a life preserver."I

12

said, "That's more like an anchor.

It's

13

not going to float you.

14

to help you."15

few jobs on the early end, but nothing

16

in the end.

17

It's not going

It's going to provide a

I just took a field trip out

18

to Lake Charles, Sunday, to look at19these new plants, the ones that are20

being built, the ones that are built,

21

and to look at Lake Charles.

22

industrial corridor.

23

It's anAfter they build these things,

24

it becomes -- I don't know if you all25

have ever visited Lake Charles.

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-37
Louisiana does not have a renewable portfolio standard policy
for electric utility providers. Further, the power produced by
Venture Global at the LNG terminal site would be used for
operation of the facility; no interconnection with thetransmission grid is planned.

Page 32

1

you haven't, you should.

2

look at that eyesore.

3

there and there won't be money there.

4

It's one of the dirtiest places in the5state and it's all industry, and they6

welcomed it with open arms.

7

not see that here.

8
9

12

There's no money

And that's that.

0004-38
Pipelines are typically at a minimum depth of 3 feet. Given a
42-inch diameter pipe would be installed a typical trench depth
would be a minimum of 10 feet. At road, utility, and othercrossings, the pipeline may be buried at greater depths toaccommodate the linear feature being crossed. See section
2.5.2.3.

I'd rather

So thank

you.

10
11

You should go

*

*

*

COLETTE PICHON BATTLE
MS. BATTLE:

13

I have a couple questions, for14

the record, please.

15

Pichon Battle.

16

and I work with the Gulf Coast Center17

For Law & Policy.

18

My name is Colette

I live in St. Tammany

So I'm just going to ask my

19question.

My first question is, on the20

air-cooled electric power generation

21

facilities, are there any renewable

22energy standards for new construction?

0004-37

23

My second question is, how

24deep does the pipeline run under water25

or in the wetlands?

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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 33

10004-39

My third question, does this2

new LNG project address a public need or3is this just a company desire?

4

example, are we low on our gas exports,

5

is our nation low on gas exports and6this will help our nation, or is this7

just a company doing business?

8For

Are there any proactive

0004-40

9requirements for cleanup of the area

10

that has been impacted by the BP oil

11

drilling disaster?

12

map.

13

is, are there any proactive requirements

14

for cleanup of that area before they

15

start digging, moving soil?

And it's on theirIt's the same area.

16

My question

And is there an Environmental
0004-41

17

Justice Review of the black and18

indigenous communities in that area, or

19

on behalf of the impact of the black and20

indigenous communities in that area?

21

Those are my questions.

22

much.

23

*

*

Thank you very*

24

REVEREND TYRONNE EDWARDS

25

REVEREND EDWARDS:

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0004-39
Under Section 3 of the NGA, FERC considers as part of its
decision to authorize natural gas facilities all circumstances
bearing on the public interest. Specifically, regarding whether
to authorize natural gas facilities used for importation orexportation, FERC shall authorize the proposal unless it findsthat the proposed facilities would not be consistent with the
public interest. See section 1.2.

0004-40
The Applicant prepared a report identifying shoreline areas
within the Barataria Basin (i.e., those land/water interfaces witha hydrological connection to the open waters of the Gulf) thathave high re-oiling potential (i.e., areas that have experienced
periodic remobilization of weathered oil). The report indicates
all of the Project's shoreline crossings have a reoiling potential
classification of "no oil observed." If weathered oil is
encountered during construction, the Applicant would take theappropriate precautions to prevent resuspension ofcontaminated media and notify the appropriate authorities. This
information has been added to the EIS in Section 4.6.3.2.

0004-41
Section 4.9.9, Environmental Justice, defines the affected area
as the census tract occupied by the Project facilities and thecensus tracts south of the Project that depend on SH 23 foregress and ingress. The census tract, which generallycomprises between 600 and 3,000 residents, was selectedbased on guidance from the EPA (1998) that each area underinvestigation should be an "appropriate unit of geographic
analysis" that does not "artificially dilute or inflate the affectedminority population."
Overall, there is no trend toward placing facilities near minority
populations or populations below the poverty level. We havedetermined that the Project would not disproportionately affectlow-income or minority populations.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-42
We have included over 120 conditions (found in section 5 of
the EIS) Venture Global would have to adhere to before they
could start initial site preparation, construction of the final
design, commissioning, introducing hazardous fluids, andcommencement of service. The Commission would not allow
Venture Global to start these different steps in the construction
process until we are satisfied with their answers to theconditions.

Page 34

1

Reverend Tyronne Edwards.

I2

live in Phoenix, Louisiana, on the east3bank of Plaquemines Parish.

4

Some of the concerns that I

5

had were really around the environmental

6

issues.

7

Environmental Impact Statement yet.

8

They just gave me the website.

9

I haven't been able to read the0004-42

But that's one of the bigger

10

concerns we had, because we have had

11other industry come into Plaquemines,

12

and so they'll say one thing, and then13

when BP -- I mean, when the hurricane

14came, we find out they had all other15

kind of chemicals.

16

this site, because the natural gas --17

I'm concerned about the gas emission, in

18

terms of do they have that under19

control.

I'm concerned about

20

The other part is, is how far

21

are they digging under water in the area

22

that they're in, because there's a23

history of a lot of old gas pipes that24

been under water for a long time, and25

being in contact with them could cause

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0004-430004-43
Table 4.3-7 identifies all foreign pipelines that are to be
crossed by the project pipelines. Standard industry
construction practice incudes searching for and identifying all
existing utilities, notifying the utility owner, and uncovering andexposing the existing utility prior to installation of the projectpipeline. According to Venture Global, Project pipelines would
generally be buried below all existing lines that would becrossed.

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-43 cont'dPage 35

1
2

So that's one of the biggest

3

concerns, the environmental impacts, so

4

I have to look at the Environmental

5

Impact Statement and see what safeguard

6

they're doing to ensure that the7emission is under control, that it8

doesn't contaminate and affect the area

9

that we live in.

10

I'm going to be sending

11

something in writing after I see the12Environmental Impact Statement.

13
14

*

*

*

BENNY ROUSSELLE

15

MR. ROUSSELLE:

16

Okay.

As you see, my name is17

Benny Rousselle and I'm an elected18

public official, serving in the capacity

19

of a Council Member and the Port Harbor

20

and Terminal District Commissioner, and21

I'm here today to support the VG LNG

22

facility project.

230004-440004-43
Thank you for your comment.
Continued

some serious problems.

I think it would be a great

24

asset to the parish.

25

location is ideal.

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0004-44

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

0004-44 cont'd
Thank you for your comment.

Page 36

1of the parish, basically in undeveloped

2

area, and as long as the mitigation of3

the impacts are dealt with, through the4

EIS process, I believe it will be a very

5

successful project and very beneficial

6

to Plaquemines, the state and the7nation.

8

*

*

*

9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
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0004-44
Continued

0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 37

1

REPORTER'S CERTIFICATE

2
34This certification is valid only for atranscript accompanied by my original
signature and original required seal on this
page.

5
6
7
8
9
10
11
12
13
14
15

I, Linda G. Griffin, RPR,
Certified Court Reporter in and for theState of Louisiana, as the officer before
whom these comments were taken, do hereby
certify that this was reported by me in the
stenotype reporting method, was prepared andtranscribed by me or under my personal
direction and supervision, and is a true andcorrect transcript to the best of my ability
and understanding; that the transcript has
been prepared in compliance with transcript
format guidelines required by statute or byrules of the board, that I have acted incompliance with the prohibition oncontractual relationships, as defined by
Louisiana Code of Civil Procedure Article
1434 and in rules and advisory opinions of
the board; that I am not related to counsel
or the parties herein, nor am I otherwiseinterested in the outcome of this matter.

16
17
18
19
20

_____________________________
LINDA G. GRIFFIN, RPR
CERTIFIED COURT REPORTER

21
22
23
24
25
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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 38
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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 39
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0004
Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 40
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Draft Environmental Impact Statement
In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

Page 41
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In the Matter of: Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC

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0005-1Thank you for your comment.

0005-2Thank you for your comment.

0005-10005-2

20181227-5141 FERC PDF (Unofficial) 12/27/2018 12:37:01 PM

0006
144 Gator Road
Deer Range Subdivision
DATE:
TO:
FROM:
SUBJECT:

December 20, 2018
FERC OEP/DG2E/Gas Branch 1
Stephen Hourcade

Venture Global Plaquemines LNG, LLC and Venture Global Gator Express, LLC
Plaquemines LNG and Gator Express Pipeline Project Docket Nos. CP17-66-000 and CP17-67000
I received the referenced Environmental Impact Statement regarding the above projects and I havecomments reflected in the body of this letter.
I own a house at 144 Gator Road located on Deer Range Canal, which is less than one mile from thisnew LNG plant and pipeline.
I am currently retired. I worked in the oilfield for 40 years, finishing my career as an engineer with anoil company 3 years ago. I worked hard over the years to get to retirement, to be at my house on Deer
Range to live, fish, and enjoy the peace and quiet of the marsh and tranquility of life away from thenoise of the city. Now here comes this LNG plant and pipeline which will ruin the peace and quiet andsolitude I have worked for 40 years to achieve. On top of this, I will not get compensated one penny forthis and will likely lose money.
As far as I’m concerned, this plant will have ruined the purpose of my retirement home and certainly
devalued my property if built and operated as in the permit. And the sad part is that there are so few
people living in close proximity to this plant that I feel our concerns will be ignored or devalued and nottaken because we are so few in number.
I fear from a safety perspective. In section 4.12.4.1, you list LNG Facility Accident History where you
described 4 LNG facility accidents domestically and internationally and how you applied those lessons
learned to this new LNG facility. I did a simple google search and found an article describing all past
LNG facility accidents with description at https://www.laohamutuk.org/Oil/LNG/app4.htm and.
https://timrileylaw.com/LNG.htm and http://citizensagainstlng.com/wp/wpcontent/uploads/2014/11/Cabrillo-Port-EIR-Appendix-C3_List-of-LNG-Accidents.pdf . These articles
describe 15 plant accidents including 2 LNG tanker accidents while moored at the facility. From thesearticles, I compiled the below list of past LNG accidents. The ones shaded in yellow are the ones you
identified in your report and the ones not shaded were the ones I found that you did not show.
1.
2.
3.
4.

USA 1944 Cleveland plant fire that killed 128 people, injured 200-400.
Algeria 1964 Arzew LNG ship parked at plant – explosion, no injuries
USA 1968 Portland Oregon plant explosion that killed 4 people.
Italy 1971 La Spezia plant significant release of 200,000 cubic meters of gas through tank vents,
no ignition.
5. Canada 1972 Montreal plant explosion, no one killed or injured.
6. U.A.E. 1978 Das Island plant failure and gas release, no explosion or injuries.
7. USA 1979 Cove Point Maryland explosion that killed 1 person.
8. Indonesia 1983 Bontang plant vessel rupture, gas release, 3 injured
9. UK 1989 Thurley plant explosion, 2 injured
10. Maryland 1992 Baltimore LNG plant failure, spill of 25,000 gallons LNG, no injuries

0006-10006-1
Some of the incidents, such as the Methane Progress LNG
carrier that lightning struck and ignited vapor being routinely
vented, which was extinguished by purging with nitrogen, were
not considered as significant as those included in the NEPA
document. Other incidents, such as the La Spezia rollover
incident, we were not directly involved in the investigation as
we were for Cove Point, Skikda, and the Plymouth Northwest
incident. However, we still apply lessons learned from thoseincidents as we do for a number of other incidents that haveoccurred throughout the U.S. and world that are relevant to
LNG facilities. For example, FERC staff ensure tank crack
contingency plans are developed, typically as part of theemergency response plan, as a result of the tank crack thatdeveloped in the LNG peakshaver in Baltimore, MD. FERC
staff also evaluate measures to prevent or mitigate rollover,which resulted in the venting at the La Spezia LNG facility.
FERC staff also requires pre-startup safety reviews to be
conducted, which better ensure flanges and valves are in thecorrect position prior to starting a facility up, which would have
reduced the likelihood of the 1983 Bontang LNG plant incident
and 1989 Thurley LNG plant incident. FERC staff applies
lessons learned as well as from other related industries too,such as requiring the use of inert nonflammable mediums
unless specifically authorized after the Kleen Energy power
plant that performed cleanout and dry out activities using
natural gas in a congested area that ignited. We also
understand that multiple layers of protection are needed toreduce the risk of an incident occurring and impacting the
public. Our review of the preliminary engineering design
focuses on these layers of protection to reduce the risk of anincident while also ensuring lessons learned are applied frompast incidents and abnormalities determined through ourreporting requirements.

20181227-5141 FERC PDF (Unofficial) 12/27/2018 12:37:01 PM

0006
11. Malaysia 2003 Bintulu plant major fire, no injuries
12. Algeria 2004 plant explosion that killed 27 people, injured 56.
13. Trinidad/Tobago 2004 plant explosion, 1 injury
14. Jordan 2006 Amman tanker caught fire while unloading, 4 injured.
15. USA 2014 Washington plant explosion, no deaths, 1 injured.

0006-10006-1 cont'dContinued

There are 15 accidents listed above but you only listed 4 accidents in your report. Why didn’t you
address all past LNG accidents? Also, on page 4-214 and 4-215 you list past LNG vessel incidents. But
the two vessel incidents I found in the list above were not identified and listed in your report.
At this point I do not feel that safety for me was adequately researched and addressed, in such a way thatwill ensure I will never experience adverse effects. And I don’t think that’s possible given I live lessthan a mile away from this proposed facility. Safety accident #15 above in Washington involved
evacuating everyone in a 2 mile radius of the plant for days. These plants should not be built unless they
are located more than 2 miles away from anyone in the public.
In your analysis of alternative LNG facility locations, on page 3-13, you describe the South Carlyss Site
II as being not acceptable location, you state “Residences are located 0.2 miles to the southwest, 0.5
miles to the west, and immediately adjacent to the north of the site; therefore, the buffer is insufficient”.
On page 4-136, you state that “lots in the Deer Range camp community range from 750 feet(0.14 mile)
to 3000 feet (0.6 mile) from the terminal boundary”. These “lots” happen to have homes where people
live, and if the buffer at South Carlyss is insufficient, how can our subdivision distance be sufficient?
Looks like the same distance in both locations to me. You have us described as “lots” instead of“people”.

0006-2

In your document, you describe that the DOT will be providing a facility siting study to you that will
determine minimum distance of the exclusion zone from LNG plant equipment to the public where thepublic will be safe. Please advise DOT that we are not “lots” but are people that will live far less than amile from this facility’s equipment.

0006-3
References to the Deer Range Camp Community throughout
the EIS have been updated to reflect that it is a community thatconsists of recreational hunting and fishing campsites as wellas permanent homes.

In the Environmental Impact Statement, there are lots of references that diminish the significance of the
population so close to this facility which includes me. On page ES-13, third paragraph down, it is stated“The proposed site is also well separated from area residences and population centers”. Is it now? My
home is less than a mile from the proposed plant location and pipeline. On page 4-114, 4th paragraphdown, it is stated “Some low density residential areas are located approximately 0.2 miles off Lake
Hermitage Road to the west and southwest of the terminal site”. That’s me. So is 0.2 miles yourdefinition of “well separated from area residences”?
In the first paragraph of page 4-138, you state that most of the houses in the “Deer Range Camp
Community” are not likely year round residences, but rather seasonal or recreational homes forrecreational and commercial fishermen. I have lived in this community for over 60 years. There aremany year round residents that live in the area and are not recreational nor commercial fishermen.
These residences are not camps, they are houses. My house neighbor next door just sold his house for$150,000 and the house across the canal is listed for $250,000. By you all describing our community inthis manner, it gives the appearance of diminishing the social standing of the people who live there. It
also diminishes the value of the opinions of people who live there due to low numbers of people and thetype casting of people who live there.
At the bottom of page 4-150 and top of page 4-151, it is stated “The camp communities southwest andsouth of the LNG terminal access SH23 north of it, but other subdivisions in Census Tract 504 access

0006-2A primary factor in choosing a location for the Terminal was theavailability of sufficient waterfront footage to support multiple
LNG carriers. The Applicant determined that the waterway
frontage available at the South Carlyss Sites were insufficient
to support the three LNG loading docks for the proposed
facility. Other concerns noted for the South Carlyss Sites
included:
The Sites would require a very long and expensive gas lateral,
which would reduce the economic competitiveness of the sitefor LNG production.
The overall acreage of the Sites are insufficient and theboundary configuration would make the siting of the Terminal
facilities impractical.
The safety and maneuverability challenges associated withSites are significant given its proximity to the intersection of theIntracoastal Waterway and the Calcasieu Ship Channel, andthe heavy waterway congestion that occurs in this area.

0006-30006-40006-4
See revised section 4.9.9. The EIS was revised so thatspecific subdivisions were not type-cast as minority or
low-income. Several census tracts were identified as potential
environmental justice communities based on their percentagesof minority and low-income residents, but the percentage ofminorities and low-income residents in any given subdivision is
unknown.

20181227-5141 FERC PDF (Unofficial) 12/27/2018 12:37:01 PM

0006
SH23 south of LNG terminal. We find this vulnerability on minority and low income communities inthe southern west bank indicates the need for targeted outreach to these communities”. So this statement
has type casted our community as minority and low income people who live in camp shacks. I know allof my neighbors and the vast majority are not minority and the vast majority are not low income. You
think low income people can afford $150,000 to $250,000 homes?

0006-40006-4 cont'dContinued

0006-5In the first paragraph on page 4-137 it is stated “The closest residential development on the westbank
that is not a camp community is a subdivision around a canal approximately 2.3 miles northwest on
SH23”. So now you have made a distinction between a camp community and a subdivision. The
subdivision you reference is Myrtle Grove subdivision. So we are not residential development? And weare not in a subdivision? We have homes just as big as theirs with owned property lot sizes that are
similar. I thought the name of our community was the Deer Range Subdivision. You referred to us as
the Deer Range Subdivision at the top of page 4-123.
Again, statement after statement is showing that we have been labeled wrongly, our opinions
diminished, and therefore our safety and well-being will be greatly negatively affected if this project iscompleted.
On the financial side, we would gain nothing and our property values would drop if this project iscompleted. Everyone in our subdivision owns their land and no one leases any property. On lastparagraph on page 4-136, it is stated “Likewise, proximity is a chief factor influencing whether a facility
could impact residential property values”. On page 4-137, last 2 paragraphs, it is stated “Perceived
health risks could also factor into property values of nearby residences”. Also stated “We estimate thatthe terminal and pipe bridge could have a long term minor effect at the community level on property
values, although we cannot predict the effects on any individual property”. These statements prove thatmy property value will drop.
nd

You address the visibility issues (what we can see from our homes) on the 2 paragraph on page 4-122“Although the area is considered industrial in nature, there are presently no industrial facilities of thismagnitude visible from the nearby residences. Therefore the LNG facility could have an adverse impact
on the residences, drivers, and recreational/commercial users of the area”. What you are saying is thatfrom ground level, I will experience an adverse impact on me personally as well as my property becauseof the view from my home.
And my property in particular could drop in value more than others. My house is elevated 12 feet as is
the case for most homes in our subdivision. I have an elevated back deck facing the east and northeast,
where I spend lots of time enjoying the scenery of the back marsh. But now less than a mile from myhouse directly to the east and northeast, which will be visible from my elevated deck, there will be afacility terminal and pipe bridge that will ruin my view. In your document you spend a lot of timetalking about view of the facility from homes close-by, but the perspective is from ground level. All of
the homes in our subdivision are elevated, most with decks, and therefore can view more of thesefacilities at an elevated level rather than at ground level. And at night the lights from the facility could
light up the inside of my house at night and make it difficult for me to sleep. Your document addresses
none of this perspective from an elevated point of view.
And what do you think will happen to my property values after evacuation orders are given to us when
the first accident or near miss occurs? That’s the first thing that potential buyers will want to know
besides the view and sound issues.

0006-60006-70006-5
References to the Deer Range Camp Community throughout
the EIS have been revised to reflect that it is a community thatconsists of recreational hunting and fishing campsites as wellas permanent homes. Deer Range is not a recorded
subdivision with Plaquemines Parish government.

0006-6
The LNG Facility would be visible from nearby residential
areas, as described in section 4.9.6. We assume individual
properties in the Deer Range community could experience a
property value change if the terminal is constructed; however,
it would be similar to any change accompanying any "portterminal complex" and "major industries" according to theParish's Master Plan that could be constructed.

0006-7
With regard to the nearby view shed, the EIS states "LNG
facility could have a minor adverse impact on the residences,drivers, and recreational/commercial users of the area." Thisconclusion was reached while analyzing ground level views.
Views from elevated areas nearby the LNG terminal would also
experience a minor adverse impact as any ground level
vegetation and the floodwall mitigating ground levels views
would be reduced from higher elevations. The EIS has been
updated to reflect this determination from elevated areas. See
section 4.8.6.1.

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0006-80006-8The Applicant would coordinate construction of the pipe bridgewith the USACE in accordance with the Section 408 Permit
issued by the USACE for the pipe bridge over the levee. The
timing of the USACE's planned construction activities iscurrently unknown. See section 4.13.2.12.

Another negative factor is noise pollution. In the first paragraph on page 5-24, it is stated “Thecumulative noise effects near certain residences in the Deer Range camp community could be adverse
for a few days or weeks if Venture Global’s pile driving and/or HDD construction activities overlap with
USACE (Corps of Engineers) upgrades of the adjacent levee, but overlap of these activities is unlikely.
We recommend that Venture Global coordinate its construction with the USACE”. Ok so now we areback to being a camp community instead of a subdivision. If my residence will be negatively affectedby the cumulative noise pollution, why didn’t you make it a condition of the permit that they cannot
conduct pile driving or HDD construction activities if the USACE is upgrading the levee? Venture will
be pile driving 10 hours a day for over a year, how can you say that overlap of these activities isunlikely? I think it to be very likely. We will be negatively affected even if Venture uses mitigation
steps to lower noise levels on their part.
0006-9At the top of page 4-202, table 4.11-17 shows the predicted noise levels of pile driving by Venture in
their plant. My home is located in monitoring point NSA2. It shows that without noise mitigation, thepredicted noise level would rise from ambient of 46.9 dB to 69.9 dB, for a rise of 23 dB. The table also
shows the predicted noise level of 62.9 dB with no mitigation using a “20% usage factor”, because piledriving is not a constant noise. Why is this allowed? You should expose your ears to pile driving andtell me if the noise is reduced because it is not a constant noise. That level would be unbearable for us.
Think of the worst headache you’ve ever had with pounding in your head like pile driving, then tell me
if you think it is not a constant feeling. The 20% usage factor should not be allowed.
In the middle of page 4-202, you state that Venture Global could construct 5 meter (15 feet) high noise
protection walls around piling rigs for noise mitigation that would lower noise levels to 2.2 dB above
ambient noise levels. Then you describe alternative mitigation steps that would be allowed. You
describe that if noise protection walls are not a feasible option, you list 3 other options that would beallowed but you don’t state what the models would predict on noise levels at my house if any of those 3
alternative options are used. You should not allow these other options if you can’t model the predicted
noise levels for them and you should force Venture Global to use noise protection walls as a result.

0006-10

So you say that flaring doesn’t happen that often. At the bottom of page 2-9, flaring is described as
being usually associated with system start up, planned maintenance and shutdown scenarios, and LNG
carrier gas up/cool down operations. It is also stated that 3 separate flare structures will be installed. At

0006-9Impact pile driving is an intermittent noise source (i.e.,
non-constant), so a usage factor was applied to the calculated
maximum noise level (Lmax). In accordance with the Federal
Highway Administration (FHA) Roadway Construction Noise
Model (RCNM) (FHA, 2006), Venture Global applied a usage
factor of 20 percent to the predicted Lmax levels from piledriving. Calculating pile-driving noise without a usage factor
would not be an appropriate way of estimating noise impacts
from an intermittent noise source for comparison to ambient
background noise levels.

0006-10Venture Global has committed to not increasing noise morethan 10dba as stated in section 4.11.2.4. Pile installation at thepipe bridge would involve an auger type drill rig instead of an
impact rig as discussed in LNG terminal construction. An
auger drill rig has an Lmax of 85 dBA at a distance of 50 feet.
Use of an auger drill for pipe bridge pile installation would be
estimated to produce a noise level of 54.3 dBA at NSA 2,
located approximately 1,713 feet to the west. This would be a
7.9 dBA increase during daytime ambient noise levels.

Also, in your recommendations, you state that Venture Global should be forced to conduct noiseassessments at all NSA’s while pile driving is taking place and also pipeline HDD operations and makeadjustments to their noise mitigation methods if noise levels are too high. This recommendation isabsolutely critical and should be a requirement, and the same should be done after the facility is put into
operation if allowed to be constructed. In fact, all of your recommendations stated in section 4.12.5 andsection 5.2 should be requirements in the permit assuming no one can convince you to deny the permit.
As you stated in the bottom of page ES-5, Venture Global has not yet committed to any specificmitigation measures, so if you don’t put it as requirements in the permit, it won’t get done.
Flaring inside the facility is also a concern to me, regarding sight, sound, and light. At the top of page 4122, your report states that views of the flaring would be visible to some viewers, but would be partiallyobscured by the floodwall. So, the floodwall is 26 feet tall, while the flares are 280 feet tall, and theflame is at the top of the flare. So how many miles away does it take for a 26 foot wall to partiallyobscure a flare 280 feet high? Sure isn’t happening at my house, less than a mile away. So I will get towatch and listen to each and every flare unless I am sleeping at night, for which it wakes me up from thesound and the light generated from the flare. And if it is not flaring, I get to see all 3 flare stacks every
day year round.

0006

0006-110006-11
The flares associated with the LNG terminal would likely
generate noise when used, however, Venture Global does notconsider the flares to be significant contributors to the noise
generated by the facility due to their infrequent use. To theextent practical, use of the flares during initial facility start-up
would be limited to daytime hours, limiting potential impacts onnoise-sensitive areas (NSAs). Given that flaring would be
limited to initial facility start-up and then infrequent LNG carrier
gas up / cool down operations, we have determined that
potential impacts on NSAs or other residents in the vicinity of
the LNG terminal would be of short duration, temporary,0006
intermittent and would less than 10 dBA above ambient Leq
level. See section 4.11.2.4.

20181227-5141 FERC PDF (Unofficial) 12/27/2018 12:37:01 PM

the top of page 4-122, it is stated that flaring would occur twice per year for startup and shutdown
purposes, and that marine flaring would occur up to 12 times per year. At the bottom of page 4-205, it isstated that flaring may occur up to 40 times per year during LNG carrier gas up/cool down operations.
So it’s going to happen a lot, and that doesn’t include any operational upset flaring.

0006-11
Continued

0006-12

Concerning storm water and hydrostatic test water, in the middle of page 4-300, it is stated this water
will drain into adjacent industrial canals that flow to a pumping station, where it is pumped into themarshes that lead to Lake Hermitage. This document notes in several spots this body of water as Lake
Judge Perez, but its’ name has been changed back to Lake Hermitage for many years. For example thisdocument notes the fire department as Lake Hermitage fire department which is adjacent to Lake
Hermitage.
For this hydrostatic test water, for facility vessels, it is written in 2nd to last paragraph that water fromnearby drainage canal will be used to hydrostatically test the LNG storage tanks, and that chemical
additives may be required during the testing process to neutralize bacteria and other components that canbe corrosive. For the hydrostatic testing of the pipelines, in the middle of page 4-35, it is stated that if
necessary, corrosion inhibitor would be added to protect the pipe. In both cases, it is stated that prior todischarge into the adjacent industrial canals that flow to a pumping station that will be pumped into themarshes that lead to Lake Hermitage, the water would flow through 25 to 50 micron filters to remove
solids and an active carbon medium to remove chemical contaminants. It is stated that they will befollowing the guidelines of LPDES general permit LAG670000.
I review this general permit for requirements and found that common additives to test water such as
corrosion inhibitors, bactericides, and dyes may not be added to the test water to be discharged without
prior approval from LDEQ. Written requests for approval must include toxicity data for each additive
proposed for use and levels of each additive to be added to make sure that the added levels do not
exceed levels specified in aquatic toxicity data that they must submit. I also researched the ability ofactivated carbon medium to remove these particular chemicals and could not find any supporting data. I
am concerned that Venture Global will ignore the requirements of this permit and a fish or wildlife killmight occur. This needs to be addressed. I would recommend that all hydrostatic test water be gathered
in a tank and sent to a water disposal site rather than discharging to sensitive marsh areas.
I am finished addressing facility issues and now I will address pipeline issues.
The first issue is method of installation and its effect on dredging and marsh destruction.
On page 4-26, the table shows that the Barge Lay method will be used in open waters from Barataria
Bay through Bay Wilkerson through North Bay Wilkerson (Upper Wilkinson Bay) through Bay
Raquette to Bay Laurier. It also shows that the Push/Pull method will be used in marsh areas from Bay
Laurier to the Pipe Bridge on land.
On page 2-27, the barge lay process is described where a 300 foot construction right of way would be
required. A spud barge 100 feet wide using a barge mounted clam bucket is used to dig a float channel
trench deep enough to at least 8 feet to float this dredge barge, then a pipe trench is dug in the float
trench deep enough to bury the pipelines. On page 2-28, the push lay process is described where a 130
foot right of way would be required and an excavator digging a 30 foot wide push ditch.
At the top of page ES-3, it is stated that the barge lay method will be used in open water areas and thepush/pull method in marsh or inundated wetlands. However, there is a solid area of marsh between
North Bay Wilkerson(Upper Wilkinson Bay) and Bay Raquette. At the bottom of page 2-27, it is stated0006-130006
0006-11 cont'd

0006-12
Approximately 26,200,000 gallons of water would be required
during hydrostatic testing of the LNG storage tanks andapproximately 50,000 gallons of water for testing piping andnon-LNG tanks. It would not be feasible to transport thisvolume of water for disposal due to the limited capacity oftanker trucks. Chemical additives may be required during thetesting process to neutralize bacteria and other componentsthat can be corrosive. Before returning hydrostatic water to its
surface water source, Venture Global would pass the water
through 25-50 micron filters and an active carbon medium toremove suspended solids and neutralize or biodegrade thechemical additives. Following completion of the hydrostatic
testing and prior to discharge, the test water would beanalyzed for total suspended solids, oil and grease, and pH inaccordance with LDEQ Louisiana Pollution Discharge
Elimination System (LPDES) general permit LAG670000. In
accordance with general permit LAG670000, Venture Global
would seek authorization from the LDEQ to use additives andwould provide the specific additives and the intended
concentrations as part of the permitting process. The
withdrawal, testing, and discharge of hydrostatic test water
would be conducted in accordance with LPDES permit
requirements. See section 4.3.2.2.

0006-13
The installation of the pipeline Between North Bay Wilkerson(Upper Wilkinson Bay) and Bay Raquette by use of thepush/pull method is not practical given the saturation of themarsh and surrounding area making push/pull equipment
ineffective. Approximately 1,100 feet of the 2,500 feetbetween the two waterbodies generally follow an existing
conduit. Therefore, about 1,400 feet of the pipeline route
impacts the saturated marsh located between open water. To
facilitate restoration of this segment of construction
right-of-way, Venture Global would temporarily store material
excavated from the barge flotation channel to facilitate
restoration of the marsh to pre-construction contours to ensure
no new permanent channel is created. See section 2.5.2.4.

20181227-5141 FERC PDF (Unofficial) 12/27/2018 12:37:01 PM

that the barge lay method will be used for this “relatively short” section of marsh that I’ve described.
These statements are in direct conflict. Why would you allow destruction of a 300 foot wide
construction right of way on this section of marsh when it can be done by the push/pull method with
only a 130 foot wide right of way and a 30 foot wide push ditch? I’ve been fishing this marsh for over ahalf century and that section of marsh is healthy and solid regardless of its length. And by the way, this
supposed “relatively short” section of marsh is nearly ½ mile long.

0006-13
Continued

Regardless of which method is used, if the trench is not refilled and marsh restored to its original
condition as best as can be done, this new channel will serve as a direct conduit for storm surge andcause higher flooding at my home.
0006-14

So what about marsh restoration for this project? Will Venture Global fill in all channels and trenches
dug to access and bury the pipeline? Will Venture Global place the dug spoil in open water back into
the access channels and trenches they dug both along the pipeline and in access channels across Bay
Laurier and Barataria Bay to restore the original contour of the water bottoms? Appears that the answer
is no. At the bottom of page 4-85, it is stated that Venture Global will backfill the pipeline trenches withdredged material. And material dredged from the barge access channels would be “sidecast”. What issidecast? They could just knock off the tops of the underwater spoil banks back into the access channels
and that would be good enough for sidecast?

The last issue I have revolves around the timing of pipeline installation. On page 4-36, you state that inyour section V.B.1 of your procedures require that instream work like installing this pipeline must occur
from June 1 to November 1. On page 4-80, Global Venture states that it would not adopt this time
restriction for the pipeline project because of the length of the construction period. In the document, it isstated that the push/pull section will require 27 days and the barge lay section will require 31 days. For
myself, the worst time of the year to install this pipeline is during shrimp and crab season in the summer
and early fall. I typically get my year’s supply of shrimp by pulling a bottom trawl in Bay Laurier in thechannels in May and June. Also, the best crabbing from June through October is in the channels of Bay
Laurier. The La. Wildlife and Fisheries has established crabbing restrictions from September to
October, where the possession of female crabs will be prohibited in order for the immature female crabs
to mate for life. The inland bays are typically full of marine life at their most during the May to Octobertime period. For those who crab and shrimp, the late fall, winter, and spring are the best times to0006-13 cont'd

0006-14
Spoil resulting from the excavation of the flotation channel andpipe trenches would be temporarily placed on either side of theright-of-way centerline, keeping the spoil below the water
surface, where feasible, to minimize wave generated turbidity.
After the pipe is lowered into the trench, the pipeline trench
and flotation channel would be backfilled with previously
excavated material. The trench and construction workspace
would be returned to its previous contours to match theadjacent undisturbed portions of the wetland upon completionof restoration. The applicant would also install bank line
stabilization at the water/marsh interface to facilitate
restoration.
Restoration of the temporarily impacted areas would bemonitored and the successful achievement of pre-construction
conditions would be determined after one full growing season
post construction. For locations where pre-construction
conditions are not achieved after one full growing season,
Venture Global would work with the USACE and LDNR todetermine the appropriate follow-up measures to restore theconstruction right-of-way. See section 4.6.4.2.

It is also stated that upon project completion, the dredged and excavated portions of the channels would
be allowed to backfill naturally over time to original contour bottoms. This tells me that Venture Global
will allow underwater spoil mounds on each side of the access channels to remain in place and will behazards to navigation and also to shrimp trawlers like myself. This to me is unacceptable. The original
contours of the water bottoms should be restored, or better yet take the spoil that will not be used tobackfill channels, and build up the small open pond areas of the marsh by depositing the dredged
material there. That could pay for some of the wetlands they will destroy at the facility site.
So how will Venture Global pay to restore the marsh and water bottoms they are destroying? On page
4-48, second paragraph, it states that Venture Global proposes to use mitigation banks, an in-lieu fee
program, or a combination of the two to offset, or mitigate impacts of the project. So what will happen
is some farmer to the north of Louisiana to dam off some of his farmland to create new wetlands that hecan sell into the mitigation bank from which Venture Global will buy. Also, this farmer’s new wetlands
up north will capture most of the ducks flying south and make our duck season terrible as it has been thisyear, and Venture Global can buy from the mitigation bank and destroy our marsh with no restoration.
Sounds like we are getting screwed from both directions.

0006

0006-150006-15The Applicant is developing a compensatory mitigation plan
per USACE permit requirements and the Clean Water Act,
Section 404. See Section 4.4.4 of the EIS.

0006-160006-16
The Applicant is currently consulting with the LDWF receive
permission to install the pipeline during the summer months. If
granted by LDWF, impacts on commercial and recreational
fisheries associated with construction activities is expected to
be temporary and short-term and localized to the immediate
vicinity of construction activities. Although the construction ofeach pipeline and deepening of discrete segments of barge
access channels would take place over an extended duration,
the construction activity at any single location along thepipeline route or barge access channels is likely to be limited toseveral days or weeks minimizing potential impacts oncommercial and recreational fishing. Access to theconstruction right-of-way and barge access channels would not

0006
be prohibited for fishing/crabbing/shrimping, except in theimmediate vicinity of construction activities where necessary
for safety reasons. See section 4.6.3.2.

20181227-5141 FERC PDF (Unofficial) 12/27/2018 12:37:01 PM

construct a pipeline like this. It would also disturb the least marine life to build the pipeline between
November and April.
In summary, I have outlined a large number of issues with this project. If it were just a pipeline, andwould follow the requested changes I have made, I would have no problem. But, the LNG facility is adeal breaker and I respectfully request this permit be denied. I live less than a mile away from thisfacility if it is built. In order for a permit like this to be approved, there should be a several mile bufferzone around every facility like this where no one has residence of any kind, and if that can’t beaccomplished, the facility permit should be denied.
Thank you for your consideration.

______________
Steve Hourcade

0006-16
Continued

0006
0006-16 cont'd

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Document Content(s)Letter to FERC LNG Plant EIS Statement.DOC............................1-7

0006

0008

0008-10008-1
Some of the incidents, such as the Methane Progress LNG
carrier that lightning struck and ignited vapor being routinely
vented, which was extinguished by purging with nitrogen, were
not considered as significant as those included in the NEPA
document. Other incidents, such as the La Spezia rollover
incident, we were not directly involved in the investigation as
we were for Cove Point, Skikda, and the Plymouth Northwest
incident. However, we still apply lessons learned from thoseincidents as we do for a number of other incidents that haveoccurred throughout the U.S. and world that are relevant to
LNG facilities. For example, FERC staff ensure tank crack
contingency plans are developed, typically as part of theemergency response plan, as a result of the tank crack thatdeveloped in the LNG peakshaver in Baltimore, MD. FERC
staff also evaluate measures to prevent or mitigate rollover,which resulted in the venting at the La Spezia LNG facility.
FERC staff also requires pre-startup safety reviews to be
conducted, which better ensure flanges and valves are in thecorrect position prior to starting a facility up, which would have
reduced the likelihood of the 1983 Bontang LNG plant incident
and 1989 Thurley LNG plant incident. FERC staff applies
lessons learned as well as from other related industries too,such as requiring the use of inert nonflammable mediums
unless specifically authorized after the Kleen Energy power
plant that performed cleanout and dry out activities using
natural gas in a congested area that ignited. We also
understand that multiple layers of protection are needed toreduce the risk of an incident occurring and impacting the
public. Our review of the preliminary engineering design
focuses on these layers of protection to reduce the risk of anincident while also ensuring lessons learned are applied frompast incidents and abnormalities determined through ourreporting requirements.

0008
0008-10008-1 cont'dContinued

0008-20008-2A primary factor in choosing a location for the Terminal was theavailability of sufficient waterfront footage to support multiple
LNG carriers. The Applicant determined that the waterway
frontage available at the South Carlyss Sites were insufficient
to support the three LNG loading docks for the proposed
facility. Other concerns noted for the South Carlyss Sites
included:
The Sites would require a very long and expensive gas lateral,
which would reduce the economic competitiveness of the sitefor LNG production.
The overall acreage of the Sites are insufficient and theboundary configuration would make the siting of the Terminal
facilities impractical.
The safety and maneuverability challenges associated withSites are significant given its proximity to the intersection of theIntracoastal Waterway and the Calcasieu Ship Channel, andthe heavy waterway congestion that occurs in this area.

0008-3
References to the Deer Range Camp Community throughout
the EIS have been updated to reflect that it is a community thatconsists of recreational hunting and fishing campsites as wellas permanent homes.

0008-30008-40008-4
See revised section 4.9.9. The EIS was revised so thatspecific subdivisions were not type-cast as minority or
low-income. Several census tracts were identified as potential
environmental justice communities based on their percentagesof minority and low-income residents, but the percentage ofminorities and low-income residents in any given subdivision is
unknown.

0008
0008-40008-4 cont'dContinued

0008-50008-60008-70008-5
References to the Deer Range Camp Community throughout
the EIS have been revised to reflect that it is a community thatconsists of recreational hunting and fishing campsites as wellas permanent homes. Deer Range is not a recorded
subdivision with Plaquemines Parish government.

0008-6
The LNG Facility would be visible from nearby residential
areas, as described in section 4.9.6. We assume individual
properties in the Deer Range community could experience a
property value change if the terminal is constructed; however,
it would be similar to any change accompanying any "portterminal complex" and "major industries" according to theParish's Master Plan that could be constructed.

0008-7
With regard to the nearby view shed, the EIS states "LNG
facility could have a minor adverse impact on the residences,drivers, and recreational/commercial users of the area." Thisconclusion was reached while analyzing ground level views.
Views from elevated areas nearby the LNG terminal would also
experience a minor adverse impact as any ground level
vegetation and the floodwall mitigating ground levels views
would be reduced from higher elevations. The EIS has been
updated to reflect this determination from elevated areas. See
section 4.8.6.1

0008-80008
0008-8The Applicant would coordinate construction of the pipe bridgewith the USACE in accordance with the Section 408 Permit
issued by the USACE for the pipe bridge over the levee. The
timing of the USACE's planned construction activities iscurrently unknown. See section 4.13.2.12.

0008-90008-100008-9Impact pile driving is an intermittent noise source (i.e.,
non-constant), so a usage factor was applied to the calculated
maximum noise level (Lmax). In accordance with the Federal
Highway Administration (FHA) Roadway Construction Noise
Model (RCNM) (FHA, 2006), Venture Global applied a usage
factor of 20 percent to the predicted Lmax levels from piledriving. Calculating pile-driving noise without a usage factor
would not be an appropriate way of estimating noise impacts
from an intermittent noise source for comparison to ambient
background noise levels.

0008-10Venture Global has committed to not increasing noise morethan 10dba as stated in section 4.11.2.4. Pile installation at thepipe bridge would involve an auger type drill rig instead of an
impact rig as discussed in LNG terminal construction. An
auger drill rig has an Lmax of 85 dBA at a distance of 50 feet.
Use of an auger drill for pipe bridge pile installation would be
estimated to produce a noise level of 54.3 dBA at NSA 2,
located approximately 1,713 feet to the west. This would be a
7.9 dBA increase during daytime ambient noise levels.

0008-110008-11
The flares associated with the LNG terminal would likely
generate noise when used, however, Venture Global does notconsider the flares to be significant contributors to the noise
generated by the facility due to their infrequent use. To theextent practical, use of the flares during initial facility start-up
would be limited to daytime hours, limiting potential impacts onnoise-sensitive areas (NSAs). Given that flaring would be
limited to initial facility start-up and then infrequent LNG carrier
gas up / cool down operations, we have determined that
potential impacts on NSAs or other residents in the vicinity of
the LNG terminal would be of short duration, temporary,0008
intermittent and would less than 10 dBA above ambient Leq
level. See section 4.11.2.4.

0008-11
Continued

0008-120008-130008
0008-11 cont'd

0008-12
Approximately 26,200,000 gallons of water would be required
during hydrostatic testing of the LNG storage tanks andapproximately 50,000 gallons of water for testing piping andnon-LNG tanks. It would not be feasible to transport thisvolume of water for disposal due to the limited capacity oftanker trucks. Chemical additives may be required during thetesting process to neutralize bacteria and other componentsthat can be corrosive. Before returning hydrostatic water to its
surface water source, Venture Global would pass the water
through 25-50 micron filters and an active carbon medium toremove suspended solids and neutralize or biodegrade thechemical additives. Following completion of the hydrostatic
testing and prior to discharge, the test water would beanalyzed for total suspended solids, oil and grease, and pH inaccordance with LDEQ Louisiana Pollution Discharge
Elimination System (LPDES) general permit LAG670000. In
accordance with general permit LAG670000, Venture Global
would seek authorization from the LDEQ to use additives andwould provide the specific additives and the intended
concentrations as part of the permitting process. The
withdrawal, testing, and discharge of hydrostatic test water
would be conducted in accordance with LPDES permit
requirements. See section 4.3.2.2.

0008-13
The installation of the pipeline Between North Bay Wilkerson(Upper Wilkinson Bay) and Bay Raquette by use of thepush/pull method is not practical given the saturation of themarsh and surrounding area making push/pull equipment
ineffective. Approximately 1,100 feet of the 2,500 feetbetween the two waterbodies generally follow an existing
conduit. Therefore, about 1,400 feet of the pipeline route
impacts the saturated marsh located between open water. To
facilitate restoration of this segment of construction
right-of-way, Venture Global would temporarily store material
excavated from the barge flotation channel to facilitate
restoration of the marsh to pre-construction contours to ensure
no new permanent channel is created. See section 2.5.2.4.

0008-13
Continued

0008-140008
0008-13 cont'd

0008-14
Spoil resulting from the excavation of the flotation channel andpipe trenches would be temporarily placed on either side of theright-of-way centerline, keeping the spoil below the water
surface, where feasible, to minimize wave generated turbidity.
After the pipe is lowered into the trench, the pipeline trench
and flotation channel would be backfilled with previously
excavated material. The trench and construction workspace
would be returned to its previous contours to match theadjacent undisturbed portions of the wetland upon completionof restoration. The applicant would also install bank line
stabilization at the water/marsh interface to facilitate
restoration.
Restoration of the temporarily impacted areas would bemonitored and the successful achievement of pre-construction
conditions would be determined after one full growing season
post construction. For locations where pre-construction
conditions are not achieved after one full growing season,
Venture Global would work with the USACE and LDNR todetermine the appropriate follow-up measures to restore theconstruction right-of-way. See section 4.6.4.2.

0008-150008-15The Applicant is developing a compensatory mitigation plan
per USACE permit requirements and the Clean Water Act,
Section 404. See Section 4.4.4 of the EIS.

0008-160008-16
On January 24, 2019, Venture Global receieved approval fromthe LDWF to conduct instream work within the warmwater
fisheries associated with the Project year-round. Impacts oncommercial and recreational fisheries associated withconstruction activities is expected to be temporary andshort-term and localized to the immediate vicinity of
construction activities. Although the construction of eachpipeline and deepening of discrete segments of barge accesschannels would take place over an extended duration, theconstruction activity at any single location along the pipeline
route or barge access channels is likely to be limited to several
days or weeks minimizing potential impacts on commercial andrecreational fishing. Access to the construction right-of-way

0008
and barge access channels would not be prohibited forfishing/crabbing/shrimping, except in the immediate vicinity of
construction activities where necessary for safety reasons. See
section 4.6.3.2.

0008-16
Continued

0008
0008-16 cont'd

0009

0009-10009-20009-30009-40009-1
As discussed in Section 2.2.2 of the EIS, a wider construction
right-of-way is necessary given the large diameter pipeline(42-inch-diameter pipeline with a 6-inch-thick concrete
coating), the soils along the pipeline route, and the need forsufficient space to store spoil during trench excavations. In
areas where the push method is used to install the pipeline,
including in wetlands, a 130-foot-wide construction right-of-way
would be used due to the need for a relatively wide and deep
trench to ensure the required depth of cover in the wet, poorly
cohesive, and easily sloughed substrate, and the consequent
need for increased space to sidecast the high volume of spoil.
In areas where the barge lay method is used to install the
pipeline in open waters, a 300-foot-wide construction
right-of-way would be required for each pipeline toaccommodate an about 100-foot-wide floatation channel for lay
barge and supply barge access, and up to about 100 feet on
either side of the floatation channel for construction workspace
to deposit sidecast trench material. The permanent operational
easement width of 80 feet (where the two pipelines arecollocated) reflects a legal agreement between Gator Express
Pipeline and individual landowners that grants access rights forinspection and maintenance during pipeline operation.
Following workspace restoration in wetlands, only 60 feet of
this 80-foot width would be subject to any further disturbancethrough potential periodic vegetation maintenance (i.e., a30-foot-wide corridor centered over each pipeline). Of this,
only a 10-foot-wide corridor centered on each pipeline would
be subject to the level of clearing necessary to ensure acontinued herbaceous state required by PHMSA to facilitate
aerial surveys of the pipeline corridor for safety purposes. If
any vegetation maintenance is needed, it is expected to be
infrequent and localized, given the existing herbaceousconditions that characterize the majority of the onshore
pipeline route. Temporary and permanent impacts to wetlands
or waters of the U.S. would be mitigated as provided for in the
Clean Water Act Section 404 Permit and the Coastal Use
Permit via the compensatory mitigation plan.

0009-2The pipeline route was chosen to maximize the use of open
water areas to the extent practical minimizing impacts on
wetlands. About 75 percent (11.4 of 15.1 miles) of the SW
Lateral TGP pipeline and 68 percent (8.0 of 11.7 miles) of the
SW Lateral TETCO pipeline will be installed in open water
areas, which is the greatest extent practicable for each

0009
pipeline. Additionally, the Applicant notes that the SW Lateral
TETCO pipeline will be installed adjacent to the SW Lateral
TGP pipeline along its entire length, which will minimize
impacts to wetlands. As discussed in Section 2.5.2.6-1, both
pipelines will be installed using the HDD method over a portionof thier route which will avoid impacts on two wetlands and one
waterbody.

0009-3The Applicant will coordinate with the LDWF, USACE,
and LDNR to identify bank stabilization specifications and thespecific locations to be installed as part of the ongoing reviewof the Applicant's applications for a Clean Water Act (CWA)
Section 404 Permit and a Coastal Use Permit.

0009-4The Applicant would require water access for barges and othervessels involved in dredging, pipe laying, equipment andmaterials deliveries, and spoil storage. Access to and within
portions of the pipeline construction workspace would require
dredging and excavation to increase the minimum water depth
to allow free passage of construction-related barges and othervessels. The majority of these channels would be constructedusing a clam shell dredge, allowing the dredged material to be
sidecast adjacent to the channel. Where this method is
employed, the material would be used to backfill the channel
following installation of the pipelines, as such, most of thematerial would only be temporarily displaced. The permanent
displacement of dredged materials associated with the barge
access channels where the prop-washing method would be
employed would involve less than 25,000 cubic yards ofdredged material. This permanently displaced material would
be spread out along the barge access channel system.
Venture Global does not believe this material can be effectively
used to create/restore marsh due to the small volume andlogistical challenges of collecting and transporting the material.
See section 4.4.2.2.

0009

0009-50009-60009-70009-80009-90009-5
As stated throughout the EIS. Venture Global would implement
the erosion and sediment control measures described in the
project-specific Upland Erosion Control, Revegetation, andMaintenance Plan (Plan), the project-specific Procedures, andconstruction-specific Stormwater Pollution Prevention Plans(SWPPPs) for the Terminal and Pipeline System.

0009-6
As shown in Section 4.4.2.2 the Applicant would install one
permanent access road within wetlands to reach the mainline
valve site located adjacent to Hermitage Road and would installa culvert at this location per the LDWF's request. The
remainder of the permanent access roads associated with the
project are located in upland areas; however, the Applicant
would install culverts where necessary to maintain existingdrainage. A temporary access road around the LNG terminal
floodwall to facilitate pipeline construction is planned. This roadwould be constructed of timber mats with sufficient spacing tomaintain cross flow of storm water, eliminating the need for
temporary culverts, except at crossings of existing canals anddrainage ways.

0009-7The Applicant is required to develop a compensatory mitigation
plan per USACE permit requirements and the Clean Water Act,
Section 404. As part of the section 10/404 process, Venture
Global would be required to develop a Compensatory
Mitigation Plan to mitigate unavoidable wetland impacts.
Venture Global proposes to use mitigation banks, an in-lieu fee
program, and/or permittee-responsible to mitigate for thewetland impacts of the Project. The plan would be subject tothe review and approval by the USACE, New Orleans District,as part of the section 10/404 process. We would require that all
federal authorizations, including these permits, be received
prior to construction of the Project.

0009-8As shown in Section 4.5.4 the Coastal Live Oak-Hackberry
Forest occurs within the proposed pipeline construction andoperational footprint. Complete avoidance of this area is notpossible due to the necessity of constructing a pipe bridge over
the adjacent levee and for the HDD entry location associated0009
with installing the pipelines under the floodwall. Venture Global
plans to sequence installation of the pipe bridge and pipelines
at this location to allow the same workspace to be utilized forconstruction of the pipe bridge and HDD entry locations thus
minimizing impacts on the forested area. A temporary accessroute located within the pipelines' permanentright-of-way would be required to reach the construction
workspace.
According to the project specific Plan and Procedures, most of
the area disturbed by construction would be restored topre-construction contours and allowed to revert to its current
vegetative cover. No permanent vegetation maintenance would
occur between the entry and exit of the HDDs; vegetation
maintenance would be limited to the upland permanentright-of-way located between the levee and HDD entry
locations. Of the Coastal Live Oak-Hackberry forest, to beaffected by construction and located interior of the levee, about
2.1 acres would be cleared for temporary workspace and 0.7
acre would be permanently maintained in a shrub/vegetative
state following installation of the pipelines. The area to bepermanently maintained in a shrub/vegetative state makes up
a small proportion, less than 1 percent, of the portion of theforest located interior of the levee.

0009-9Venture Global has stated it is completing an assessment ofoyster leases crossed by the pipeline route and barge accesschannels and would submit its report to the LDWF early in
2019. This statement was submitted to docket No.
CP17-66-000 on February 4, 2019. See section 4.6.3.2.

APPENDIX I
LIST OF PREPARERSAPPENDIX I
LIST OF PREPARERS

Federal Energy Regulatory Commission
Wisniewski, John – Environmental Project Manager
B.S., Mineral Economics, 1975, Pennsylvania State University
Allen, Christine –Deputy Project Manager, Surface Water, Fisheries, Wetlands,
Vegetation, Wildlife, T&E Species
B.S., Marine Biology, 2005, University of North Carolina at Wilmington
Howard, Eric – Cultural Resources
M.A., Anthropology, 1998, University of Tennessee
B.A., Anthropology, 1992, University of Tennessee
Tomasi, Eric – Air Quality and Noise, Pipeline Safety
B.S., Aerospace Engineering, 1994, Boston University
Wachholder, Joanne
M.S., Crop and Soil Sciences/Environmental Toxicology, 1997, Michigan State
University
B.S., Environmental Biology, 1994, University of Wisconsin, Stevens Point
Busch, Steven - LNG Reliability and Safety
M.E., Engineering, 2003, University of Maryland at College Park;
B.S., Mechanical Engineering, 1999, University of Maryland at College Park
Hoogendoorn, Wimberly
B.S.M.E, Mechanical Engineering, 2017, Baylor University
Peng, Andrew – LNG Reliability and Safety
B.C.E., Civil Engineering, 2014, University of Delaware
McCullough, Erin – LNG Reliability and Safety
B.S. Mining Engineering, 2014, South Dakota School of Mines and Technology
M.Eng Mining Engineering, 2016, Virginia TechRodgers, J. Keith – Geology, Groundwater, HDD
Professional Geologist, 2008, North Carolina Board for the Licensing of Geologists
M.E., Master of Engineering in Water Resources, 2008, University of Arizona
B.S., Geological Sciences, 2004, Virginia Tech
Federal Energy Regulatory Commission LNG Consultants
Bachman, Robert – LNG Reliability and Safety
M.S., Structural Engineering, University of California at Berkeley, 1968
B.S., Civil Engineering, University of California at Berkeley, 1967
Bhushan, Kul – LNG Reliability and Safety
Ph.D., Geotechnical Engineering, Duke University, 1970
M.S., Highway Engineering, Panjab University, India, 1963
B.S., Civil Engineering, Panjab University, India, 1962
Stebbing, Roger – LNG Reliability and Safety
B.S., Chemical Engineering, University of Salford, England, 1968
Ecology and Environment, Inc.
Gartman, Michael – Project Manager, Introduction, Proposed Action, Land Use
M.S., Geography, The University of Alabama, 2000
B.S., Environmental Science, Troy State University, 1997
Casey, Justin – Deputy Project Manager, Alternatives, Water and Wetland Resources
B.S., Biology/Environmental Science, Delta State University, 1999
Boyle, Michael – Principle In Charge, NEPA Guidance, Quality Assurance and Control
B.A., Environmental Sciences, University of Virginia, 1978
Mollow, Kathleen – Socioeconomics, Cumulative Impacts
M.S., Environmental Science, Texas A&M University at Corpus Christi, 2011
B.A., Urban Studies, Stanford University, 2000
Trimm, David – Aquatic Resources, T&E Species, EFH
M.S., Invertebrate Zoology/ Marine Biology, Southwest Texas State University, 1981
B.S., Aquatic Biology/ Chemistry, Southwest Texas State University, 1977
Siener, Thomas – Noise Quality
B.S., Biology, Purdue University, 1971

Kirchler-Owen, Leslie – Cultural Resources, Visual Resources
Ph.D., Landscape Architecture and Urban Technological and Environmental Planning,
University of Michigan
M.A., Landscape Archaeology, University of Sheffield
B.S., City and Regional Planning, Cornell University
B.A., Archaeology and Anthropology, Cornell University
Wattle, Bruce – Air Quality
B.S., Atmospheric Science, University of Michigan, 1979
Hoffman, Hilary – Editor, Quality Assurance
M.F.A., Creative Writing, University of Washington, 2004
B.A., English Literature and Writing, Whitworth College, 1994

Ecology and Environment, Inc. is a third-party contractor assisting the Commission staff inreviewing the environmental aspects of the project application and preparing the environmental
documents required by NEPA. Third-party contractors are selected by Commission staff andfunded by project applicants. Per the procedures in 40 CFR 1506.5(c), third-party contractors
execute a disclosure statement specifying that they have no financial or other conflicting interestin the outcome of the project. Third-party contractors are required to self-report any changes infinancial situation and to refresh their disclosure statements annually. The Commission staff
solely directs the scope, content, quality, and schedule of the contractor’s work. The
Commission staff independently evaluates the results of the third-party contractor’s work andthe Commission, through its staff, bears ultimate responsibility for full compliance with therequirements of NEPA.

APPENDIX JINDEXAPPENDIX J
INDEXBald and Golden Eagle Protection Act(BGEPA), 1-14, 1-15, 1-20, 4-59, 4-61,
4-91

access road, ES-4, 2-3, 2-16, 2-20, 2-21,
2-24, 2-30, 3-10, 3-11, 4-41, 4-42, 4-47, 4-53,
4-109, 4-112, 4-113, 4-140, 4-153, 4-157,
4-158, 4-174, 4-312, 5-28

bald eagle, 4-61, 4-65, 4-105, 5-13

additional temporary workspace (ATWS),
ES-4, 2-19, 4-35, 4-36, 4-37, 4-40, 4-44,
4-46, 4-107, 4-108, 4-113, 4-158

Bay Batiste, 4-3, 4-21, 4-25, 4-33
Best Available Control Technology (BACT),
4-166, 4-167, 4-181, 4-334, 5-20, 5-21

Advisory Council on Historic Preservation(ACHP), 1-18, 4-155

best management practice (BMP), 4-59,
4-87, 5-13

Air Quality Control Regions (AQCR), 4-162,
4-164

biological assessment (BA), ES-8, 1-14,
4-89, 4-118, 4-305

alternative, ES-1, ES-3, ES-13, ES-14,
ES-15, 1-3, 1-9, 1-10, 1-12, 2-9, 2-29,
2-32, 2-33, 3-1, 3-2, 3-3, 3-6, 3-7, 3-8, 3-9,
3-11, 3-12, 3-13, 3-14, 3-15, 3-16, 4-13,
4-14, 4-35, 4-38, 4-45, 4-46, 4-47, 4-167,
4-214, 4-226, 4-247, 4-276, 4-295, 5-1,
5-3, 5-6, 5-7, 5-25, 5-26, 5-27, 5-43

Bird Conservation Region (BCR), 4-60
Birds of Conservation Concern (BCC), 4-60
blasting, 4-5, 5-2
blue whale, 4-96

American Petroleum Institute (API), 2-9,
4-226, 4-234, 4-239, 4-241, 4-244, 4-245,
4-251, 4-273, 4-277, 4-278, 5-39, 5-43,
5-45

Boiler and Pressure Vessel Code (BPVC),
4-234, 4-245, 4-246
boiling liquid expanding vapor explosion(BLEVE), 4-228, 4-260, 4-261, 4-263

aquifer, 4-14, 4-15, 4-16, 4-17, 4-167, 4-292,
5-3, 5-4

booster compressor, 4-230

archaeological, 4-155, 4-156, 4-157, 4-158,
4-159, 4-160, 4-323, 4-334

brazed aluminum heat exchanger (BAHX),
4-230

area of influence (AOI), 4-191

brown pelican, 4-57, 4-105, 4-106, 5-13

Area of Potential Effect (APE), 4-156, 4-157,
4-158, 4-159, 4-160, 4-161, 4-293

Captain of the Port (COTP), 1-5, 4-148,
4-218, 4-219, 4-221, 4-225

A-weighted decibels (dBA), ES-11, ES-12,
4-154, 4-200, 4-201, 4-203, 4-204, 4-205,
4-206, 4-207, 4-208, 4-209, 4-210, 4-329,
5-22, 5-32, 5-33

carbon dioxide (CO2), 2-6, 4-162, 4-167,
4-174, 4-176, 4-178, 4-180, 4-230, 4-244,
4-275, 4-326, 4-333, 5-41
J-1

Compression Ignition Internal Combustion
Engines CI ICE, 4-168

carbon dioxide equivalents (CO2e), 4-162,
4-166, 4-167, 4-170, 4-172, 4-174, 4-179,
4-180, 4-326

compressor station, 4-153, 4-228

carbon monoxide (CO), ES-10, 4-162, 4-163,
4-165, 4-166, 4-168, 4-170, 4-172, 4-174,
4-179, 4-180, 4-181, 4-187, 4-189, 4-191,
4-195, 4-326, 5-20

cone penetration test (CPT), 4-2, 4-249
cooperating agency(ies), ES-1, ES-12, 1-3,
1-4, 1-6, 1-9, 1-18, 3-1, 4-211, 4-212,
4-281, 4-282, 5-1, 5-23

cathodic protection, 2-25, 2-26, 2-34, 4-287

Council on Environmental Quality (CEQ),
1-4, 1-13, 3-1, 4-149, 4-150, 4-154, 4-291,
5-23

Certificate of Inspection (COI), 4-217
Clean Air Act of 1970 (CAA), ES-13, 1-7,
1-8, 1-14, 1-17, 4-163, 4-168, 4-170,
4-326, 4-327, 4-328, 5-25

critical habitat, 1-14, 4-89, 4-92, 4-98, 4-99,
4-101, 4-102, 5-13

Clean Water Act (CWA), 1-4, 1-7, 1-10,
1-14, 1-16, 1-17, 1-19, 3-2, 4-27, 4-28,
4-38, 4-42, 4-56, 4-81, 4-309, 4-310, 4-312

cultural resources, ES-3, ES-13, 1-3, 2-21,
4-155, 4-156, 4-159, 4-160, 4-161, 4-291,
4-295, 4-306, 4-323, 4-333, 4-334, 5-19,
5-24, 5-28, 5-29

climate change, 1-12, 4-330, 4-331, 4-332,
4-333, 5-24

cumulative impact, ES-3, ES-13, ES-15, 1-3,
1-4, 4-115, 4-116, 4-291, 4-292, 4-293,
4-294, 4-301, 4-303, 4-306, 4-307, 4-312,
4-314, 4-315, 4-318, 4-320, 4-323, 4-324,
4-327, 4-328, 4-330, 4-333, 4-334, 5-23,
5-24

Coastal Protection Restoration Authority(CPRA), 4-149, 4-294, 4-304, 4-305,
4-323
Coastal Use Permit (CUP), ES-7, 1-18, 1-21,
4-27, 4-38, 4-42, 4-56, 4-124, 5-17

deposition analysis threshold (DAT), 4-185

Coastal Zone Management Act of 1972
(CZMA), 1-4, 1-14, 1-18, 4-123, 4-124
Coastal Zone Management(CZMP), ES-7, 1-18, 4-123

dolphin, 1-16, 2-12, 2-13, 4-27, 4-87, 4-88,
4-94, 4-309, 4-310

Programdraft environmental impact statement (draft
EIS), ES-2, ES-5, 1-1, 1-3, 1-12, 1-13,
1-15, 2-18, 3-13, 3-16, 4-35, 4-42, 4-43,
4-92, 4-104, 4-144, 4-158, 4-208, 4-233,
4-236, 4-247, 4-305

collocated, ES-3, ES-14, 2-18, 2-19, 2-26,
3-13, 3-14, 4-40, 4-109, 4-112, 4-143
collocation, 3-15, 5-8

dredging, ES-6, ES-7, ES-8, ES-9, ES-11,
ES-12, 2-3, 2-17, 2-19, 2-25, 3-10, 4-26,
4-27, 4-32, 4-56, 4-71, 4-79, 4-81, 4-85,
4-86, 4-93, 4-94, 4-100, 4-103, 4-104,
4-118, 4-129, 4-134, 4-156, 4-206, 4-207,
4-294, 4-303, 4-307, 4-328, 5-4, 5-5, 5-10,
5-21, 5-22, 5-24, 5-26

Combined cycle gas turbine (CCGT), 4-176
Comprehensive Air Quality Model with
Extension (CAMx), 4-198, 4-199

J-2

erosion control, 2-22, 2-27, 4-11, 4-12, 4-13,
4-28, 4-53, 4-54, 4-55, 4-309, 5-8

dust, ES-10, 4-12, 4-17, 4-113, 4-147, 4-162,
4-171, 4-172, 4-173, 4-174, 4-175, 4-176,
4-179, 4-293, 5-19

erosion control measures, 2-22, 4-11, 4-12,
4-53, 4-54, 5-8

eastern black rail, ES-7, 4-92, 4-96, 4-97,
4-104, 5-13

essential fish habitat (EFH), ES-7, 1-3, 1-10,
1-11, 1-15, 1-20, 4-71, 4-82, 4-83, 4-85,
4-86, 4-87, 5-5, 5-12, 5-13

Electron Data Management System (EDMS),
4-191
emergency response, 4-155, 4-229, 4-235,
4-236, 4-261, 4-263, 4-267, 4-268, 4-269,
4-272, 4-278, 4-283, 4-285, 4-330, 5-19,
5-34, 5-38, 5-44

estuarine emergent (EEM), ES-7, 3-15, 4-39,
4-44, 4-51, 4-53, 4-57, 4-66, 4-85, 4-87,
5-9, 5-10, 5-13
estuarine scrub/shrub (ESS), 4-39, 4-41,
4-44, 5-7, 5-9, 5-10

Emergency Response Plan (ERP), 4-142,
4-222, 4-266, 4-267, 4-269, 4-330, 5-34,
5-35

estuarine subtidal unconsolidated bottom(E1UB), 4-40

emergency shutdown (ESD), 2-5, 2-14, 2-16,
2-30, 4-218, 4-229, 4-232, 4-235, 4-236,
4-240, 4-242, 4-243, 4-245, 4-266, 4-271,
4-272, 4-274, 5-37, 5-38, 5-40

Facility Security Assessment (FSA), 4-225
Facility Security Plan (FSP), 4-225
faults, 4-3, 4-250, 4-251, 4-252, 4-255,
4-268, 5-33

eminent domain, 3-6, 4-115, 5-28
Emissions Reporting and Inventory Center(ERIC), 4-191

Federal Aviation Administration (FAA), 1-7,
1-17, 1-20, 4-264, 4-265

Endangered Species Act of 1973 (ESA),
ES-7, ES-15, 1-4, 1-14, 1-15, 1-16, 1-20,
4-59, 4-60, 4-83, 4-87, 4-88, 4-89, 4-92,
4-93, 4-96, 4-97, 4-98, 4-99, 4-100, 4-105,
5-13

FederalEmergency
Management
Administration (FEMA), 1-18, 4-4, 4-257,
4-258
Federal Energy Regulatory Commission(FERC), ES-1, ES-2, ES-7, ES-12, ES-14,
ES-15, 1-1, 1-2, 1-3, 1-4, 1-5, 1-6, 1-7, 1-8,
1-9, 1-12, 1-13, 1-14, 1-15, 1-18, 1-19, 2-5,
2-15, 2-20, 2-21, 2-23, 2-31, 2-32, 2-33,
3-2, 3-4, 3-5, 3-13, 3-14, 4-1, 4-13, 4-34,
4-35, 4-42, 4-45, 4-60, 4-80, 4-85, 4-89,
4-92, 4-97, 4-99, 4-104, 4-115, 4-124,
4-140, 4-154, 4-155, 4-158, 4-159, 4-160,
4-161, 4-202, 4-207, 4-208, 4-209, 4-211,
4-212, 4-215, 4-219, 4-220, 4-221, 4-222,
4-227, 4-228, 4-229, 4-232, 4-233, 4-235,
4-237, 4-238, 4-239, 4-241, 4-242, 4-244,
4-245, 4-246, 4-248, 4-250, 4-253, 4-259,

Energy Policy Act of 2005 (EPAct 2005),
1-3, 1-6, 1-18, 4-155, 4-212, 4-267
environmental justice, 4-125, 4-143, 4-149,
4-150, 4-151, 4-152, 4-154, 5-19
erosion, 1-10, 2-15, 2-21, 2-22, 2-27, 4-3,
4-4, 4-7, 4-10, 4-11, 4-12, 4-13, 4-19, 4-28,
4-31, 4-40, 4-43, 4-53, 4-54, 4-55, 4-56,
4-75, 4-78, 4-82, 4-87, 4-162, 4-258,
4-307, 4-309, 4-333, 5-2, 5-3, 5-5, 5-6, 5-7,
5-8, 5-11

J-3

giant manta ray, 4-92, 4-100, 4-101, 5-13

4-260, 4-261, 4-263, 4-264, 4-265, 4-266,
4-267, 4-268, 4-269, 4-279, 4-280, 4-281,
4-282, 4-283, 4-288, 4-293, 4-303, 4-310,
5-1, 5-2, 5-3, 5-6, 5-13, 5-19, 5-23, 5-27,
5-31, 5-32, 5-34, 5-35, 5-45, 5-46, 5-47,
5-48

global warming potential (GWP), 4-162
green sea turtle, 4-101
greenhouse gas (GHG), 4-162, 4-166, 4-167,
4-170, 4-172, 4-326, 4-331, 4-333, 4-334,
5-19, 5-24

Federal Land Manager (FLM), 4-182, 4-185,
4-186

groundwater, 1-10, 1-14, 2-13, 4-2, 4-4, 4-9,
4-15, 4-16, 4-17, 4-18, 4-38, 4-254, 4-291,
4-295, 4-306, 5-3, 5-4, 5-24

fin whale, 4-96
final environmental impact statement (finalEIS), 1-4, 1-8, 1-13, 4-95

Gulf sturgeon, ES-7, 4-92, 4-98, 4-99, 5-13

fire, 2-8, 2-14, 4-56, 4-97, 4-140, 4-141,
4-142, 4-143, 4-168, 4-211, 4-214, 4-216,
4-218, 4-219, 4-220, 4-227, 4-229, 4-235,
4-236, 4-239, 4-240, 4-242, 4-243, 4-244,
4-245, 4-246, 4-247, 4-248, 4-254, 4-261,
4-263, 4-266, 4-267, 4-269, 4-270, 4-271,
4-272, 4-273, 4-275, 4-276, 4-280, 4-282,
4-285, 4-286, 4-287, 4-290, 4-311, 5-34,
5-37, 5-38, 5-39, 5-41, 5-43, 5-46, 5-47

hawksbill sea turtle, 4-101, 4-102, 4-104
hazard and operability review (HAZOP),
4-233, 4-271, 5-37
hazardous air pollutant (HAP), 4-162, 4-169,
4-170, 4-174, 4-180, 5-19
heat recovery steam generator (HRSG),
4-154, 4-177, 4-209

flare, ES-9, 1-17, 2-9, 4-64, 4-119, 4-121,
4-166, 4-167, 4-176, 4-178, 4-180, 4-208,
4-231, 4-234, 4-243, 4-249, 4-259, 4-272,
4-274, 4-317, 5-9, 5-16, 5-38, 5-40high consequence area (HCA), 4-284, 4-285
historic properties, 4-155, 4-157, 4-158,
4-161, 4-323, 4-334

floodplain, 1-10, 1-18, 4-125, 4-157

horizontal directional drill (HDD), ES-3,
ES-4, ES-7, ES-11, ES-12, ES-15, 2-19,
2-20, 2-26, 2-28, 2-29, 2-30, 2-31, 2-32,
4-2, 4-17, 4-25, 4-32, 4-34, 4-41, 4-42,
4-46, 4-47, 4-55, 4-80, 4-81, 4-122, 4-205,
4-206, 4-208, 4-209, 4-293, 4-328, 4-329,
4-330, 4-334, 5-21, 5-22, 5-24, 5-32

forested wetland, 4-50, 4-53, 4-57, 4-299,
4-312Free Trade Agreement (FTA), 1-6, 1-19, 3-3,
3-4, 3-5, 3-6
front-end engineering and design (FEED),
4-228, 4-232, 4-233, 4-241, 4-243, 4-244,
4-267, 5-2hydrogen sulfide (H2S), 2-6, 4-176, 4-178,
4-181, 4-230, 4-274, 4-277, 5-40, 5-44

geologic hazard, 4-3, 4-287, 5-2hydrologic unit code (HUC), 4-19, 4-292,
4-293, 4-299, 4-301, 4-307, 4-310, 4-312,
4-313, 4-314, 4-315

geology, ES-3, ES-13, 1-3, 4-13, 4-333
geotechnical, 2-30, 4-2, 4-16, 4-248, 4-249,
4-250, 4-253, 4-254
J-4

4-153, 4-163, 4-164, 4-166, 4-167, 4-169,
4-170, 4-181, 4-190, 4-191, 4-196, 4-197,
4-198, 4-199, 4-293, 4-295, 4-296, 4-301,
4-304, 4-310, 4-312, 4-323, 4-324, 4-326,
4-327, 4-328, 4-334, 5-20, 5-21, 5-25hydrostatic testing, 2-27, 4-16, 4-17, 4-26,
4-31, 4-34, 4-78, 4-80, 4-82, 4-306, 4-311,
5-3, 5-4, 5-6, 5-10
International Building Code (IBC), 4-251,
4-253, 4-254

Louisiana Department of Natural Resources(LDNR), ES-4, ES-7, 1-9, 1-16, 1-18,
1-21, 2-23, 2-26, 4-3, 4-15, 4-27, 4-38,
4-42, 4-56, 4-66, 4-81, 4-86, 4-87, 4-116,
4-123, 4-124, 4-132, 5-12, 5-18, 5-32

International Maritime Organization (IMO),
ES-13, 4-29, 4-77, 4-217, 4-328, 5-25
Intracoastal Waterway (ICW), 2-17, 3-11,
3-13, 4-23, 4-26, 4-112

Louisiana Department of Transportation andDevelopment (DOTD), 1-8, 1-21, 2-15,
2-25, 2-30, 2-33, 4-38, 4-144, 4-262,
4-299, 4-300, 4-320

Joint Permit Application (JPA), 1-21, 4-27,
4-38, 5-17
karst, 4-3, 4-4

Louisiana Department of Wildlife andFisheries (LDWF), ES-5, ES-6, 1-8, 1-9,
1-21, 2-18, 4-35, 4-38, 4-42, 4-43, 4-49,
4-51, 4-52, 4-54, 4-55, 4-56, 4-57, 4-58,
4-61, 4-66, 4-70, 4-75, 4-80, 4-81, 4-86,
4-95, 4-103, 4-104, 4-132, 4-134, 4-309,
4-310, 5-4, 5-7, 5-12, 5-13, 5-15, 5-18

key observation point (KOP), 4-120, 4-123
Lake Hermitage, ES-4, ES-8, 2-16, 2-17,
2-26, 2-30, 2-32, 4-2, 4-3, 4-4, 4-15, 4-32,
4-34, 4-41, 4-46, 4-113, 4-114, 4-118,
4-120, 4-122, 4-123, 4-138, 4-140, 4-142,
4-146, 4-147, 4-153, 4-202, 4-203, 4-206,
4-207, 4-312, 4-317, 5-15, 5-18, 5-22, 5-32

Louisiana Natural Heritage(LNHP), 4-49, 4-55, 4-105

leatherback sea turtle, 4-101, 4-102

ProgramLouisiana Pollutant Discharge Elimination
System (LPDES), 1-21, 4-11, 4-28, 4-31,
4-34, 4-76, 4-78, 4-82, 4-295, 4-301,
4-309, 4-311, 4-312, 4-321, 5-4, 5-6

Letter of Determination (LOD), ES-12, 1-7,
1-20, 4-154, 4-211, 4-215, 4-250, 4-256,
4-269, 4-281, 5-23, 5-34
Letter of Intent (LOI), 1-5, 1-19, 4-219,
4-221

Magnuson-Stevens Fishery Conservationand Management Act (MSA), 1-4, 1-5,
1-11, 1-14, 1-15, 1-20, 4-82, 4-85

Letter of Recommendation (LOR), ES-12,
ES-15, 1-5, 1-18, 1-19, 4-148, 4-154,
4-215, 4-219, 4-220, 4-221, 4-222, 4-282,
4-321, 5-23

mainline valve (MLV), ES-1, ES-4, ES-10,
ES-14, 2-16, 2-19, 2-30, 3-16, 4-33, 4-34,
4-41, 4-42, 4-46, 4-47, 4-82, 4-107, 4-123,
4-312

loggerhead sea turtle, 4-92, 4-101, 4-102,
5-13

Manilla Village Southeast, 4-3

Louisiana Department of Environmental
Quality (LDEQ), ES-10, ES-13, 1-7, 1-17,
1-19, 1-20, 1-21, 2-9, 4-15, 4-18, 4-19,
4-21, 4-24, 4-31, 4-38, 4-65, 4-66, 4-116,

Marine Mammal Protection Act (MMPA),
1-14, 1-16, 1-20, 4-59, 4-87, 4-89, 4-91,
4-93, 4-94, 4-96, 4-309

J-5

4-294, 4-299, 4-305, 4-306, 4-309, 4-310,
4-311, 4-312, 4-313, 4-319, 4-323, 4-329,
5-1, 5-2, 5-3, 5-6, 5-7, 5-8, 5-10, 5-11,
5-12, 5-13, 5-18, 5-20, 5-21, 5-22, 5-23,
5-24, 5-27, 5-28, 5-29, 5-30, 5-32, 5-41

Maritime Transportation Security Act of2002 (MTSA), 1-5, 1-14, 1-17, 4-218,
4-225, 4-279, 5-46
material offloading facility (MOF), 2-3, 2-12,
2-13, 2-25, 4-6, 4-27, 4-72, 4-147, 5-5,
5-11National Ambient Air Quality Standards(NAAQS), ES-11, ES-13, ES-15, 4-153,
4-163, 4-164, 4-165, 4-170, 4-176, 4-182,
4-187, 4-189, 4-191, 4-192, 4-193, 4-194,
4-195, 4-196, 4-197, 4-198, 4-199, 4-323,
4-327, 4-334, 5-21, 5-25

maximum allowable operating pressure(MAOP), 4-281, 4-284, 4-285, 5-47
Memorandum of Understanding (MOU), 1-6,
1-7, 1-15, 4-60, 4-101, 4-211, 4-212,
4-215, 4-256, 4-283

National Emission Standards for Hazardous
Air Pollutants (NESHAP), 1-7, 4-169

meter station, ES-4, ES-6, ES-7, ES-9,
ES-10, 2-16, 2-17, 2-19, 2-30, 4-3, 4-16,
4-33, 4-36, 4-37, 4-63, 4-64, 4-74, 4-79,
4-81, 4-82, 4-85, 4-87, 4-88, 4-93, 4-94,
4-95, 4-101, 4-103, 4-123, 4-135, 4-171,
4-177, 4-178, 4-180, 4-210, 4-271, 4-311,
5-2, 5-10, 5-11, 5-12, 5-37

National Environmental Policy Act of 1969
(NEPA), ES-1, ES-12, 1-1, 1-3, 1-4, 1-6,
1-8, 1-13, 1-15, 3-1, 4-83, 4-118, 4-150,
4-155, 4-183, 4-211, 4-259, 4-281, 4-291,
4-324, 4-328, 5-23
National Fire Protection Association(NFPA), 1-6, 2-9, 2-23, 4-168, 4-213,
4-214, 4-215, 4-228, 4-231, 4-232, 4-234,
4-235, 4-237, 4-238, 4-241, 4-242, 4-244,
4-245, 4-246, 4-245, 4-247, 4-248, 4-250,
4-253, 4-257, 4-260, 4-262, 4-272, 4-273,
4-275, 4-276, 4-279, 5-38, 5-39, 5-41,
5-42, 5-45

metering station, 4-5, 4-41, 4-72, 4-207,
4-210, 4-244, 4-275, 4-307, 4-328, 5-22,
5-41
methane (CH4), 2-5, 4-162, 4-167, 4-231,
4-274, 4-282, 5-40
migratory bird, ES-5, 1-15, 4-60, 4-63, 4-64,
5-9

National Flood Insurance Act of 1968
(NFIA), 1-14, 1-18

Migratory Bird Treaty Act of 1918 (MBTA),
1-14, 1-15, 1-16, 1-20, 4-60, 4-61, 4-91

National Historical Preservation Act(NHPA), 1-4, 1-12, 1-14, 1-18, 1-21,
4-155, 5-19

mitigation, ES-1, ES-3, ES-4, ES-5, ES-6,
ES-9, ES-11, ES-12, ES-15, ES-16, 1-3,
1-5, 1-10, 1-11, 2-20, 2-21, 2-32, 2-33, 3-6,
3-8, 3-9, 3-10, 4-1, 4-6, 4-10, 4-11, 4-12,
4-13, 4-32, 4-38, 4-41, 4-48, 4-53, 4-54,
4-58, 4-59, 4-63, 4-64, 4-65, 4-79, 4-81,
4-82, 4-83, 4-103, 4-104, 4-105, 4-118,
4-122, 4-138, 4-144, 4-145, 4-146, 4-147,
4-151, 4-154, 4-205, 4-206, 4-208, 4-209,
4-210, 4-222, 4-227, 4-228, 4-230, 4-236,
4-239, 4-240, 4-246, 4-250, 4-258, 4-259,
4-260, 4-262, 4-265, 4-267, 4-275, 4-282,

National Marine Fisheries Service (NMFS),
ES-6, ES-7, 1-8, 1-9, 1-11, 1-15, 1-16,
1-20, 4-38, 4-73, 4-74, 4-75, 4-81, 4-82,
4-83, 4-85, 4-87, 4-89, 4-92, 4-93, 4-94,
4-95, 4-96, 4-99, 4-101, 4-103, 4-104,
4-309, 4-310, 5-11, 5-12, 5-13, 5-32
National
Oceanic
Atmospheric
Administration (NOAA), 4-29, 4-83, 4-92,

J-6

4-93, 4-96, 4-101, 4-102, 4-163, 4-257,
4-258, 4-260, 4-261, 4-263, 4-290, 5-5

noise sensitive area (NSA), ES-11, ES-12,
4-154, 4-201, 4-202, 4-203, 4-204, 4-205,
4-206, 4-207, 4-208, 4-209, 4-210, 4-293,
4-328, 4-329, 4-330, 5-22, 5-32, 5-33

National Park Service (NPS), 1-8, 4-30,
4-157, 4-182, 4-183, 4-186, 5-5

non-jurisdictional facilities, 1-13, 4-294

National Pollutant Discharge Elimination
System (NPDES), 1-7, 1-16

Notice of Intent (NOI), ES-2, 1-8, 1-9, 1-17

National Register of Historic Places (NRHP),
1-18, 4-155, 4-156, 4-157

noxious weeds, 2-22, 4-54, 4-55
oceanic white-tip shark, 4-100, 5-13

National Wetland Inventory (NWI), 3-2, 3-9,
3-10, 3-11, 3-14, 3-15, 4-39

Office of Coastal Management (OCM), 1-16,
1-21, 4-38, 4-49, 4-123, 4-124, 5-17

National Wildlife Refuge (NWR), ES-8,
ES-11, 4-101, 4-116, 4-166, 4-182, 4-183,
4-185, 4-196, 5-15, 5-20

Office of Energy Projects (OEP), ES-1, 1-1,
4-5, 4-104, 4-206, 4-268, 4-279, 4-281,
5-27, 5-28, 5-29, 5-30, 5-31, 5-32, 5-34,
5-45, 5-46, 5-48

Natural Gas Act (NGA), ES-1, 1-1, 1-2, 1-4,
1-5, 1-6, 1-13, 1-18, 1-19, 3-6, 4-115,
4-212, 4-267, 5-28

operating basis earthquake (OBE), 4-253,
4-254

Natural Resources Conservation Service(NRCS), 4-6, 4-8, 4-54, 4-63, 4-305, 5-3oxides of nitrogen (NOx), 4-162, 4-164,
4-166, 4-168, 4-180, 4-181, 4-185, 4-198,
4-231

New Source Performance Standards (NSPS),
1-7, 4-168, 4-169

ozone (O3), ES-10, ES-11, 1-17, 4-162,
4-163, 4-164, 4-165, 4-197, 4-198, 4-199,
5-21

New Source Review (NSR), 4-165, 4-170
nitrogen dioxide (NO2), ES-10, 4-163, 4-164,
4-165, 4-184, 4-189, 4-190, 4-191, 4-192,
4-193, 4-195

pallid sturgeon, ES-7, 4-92, 4-99, 4-100, 5-13
palustrine emergent (PEM), ES-3, ES-4,
4-39, 4-40, 4-41, 4-44, 4-48, 4-50, 4-51,
4-53, 4-65, 4-80, 5-7, 5-9, 5-10

nitrous oxide (N2O), 4-162
noise, ES-3, ES-5, ES-6, ES-11, ES-12,
ES-13, 1-3, 4-58, 4-59, 4-63, 4-71, 4-72,
4-73, 4-75, 4-78, 4-79, 4-81, 4-82, 4-94,
4-95, 4-100, 4-103, 4-105, 4-113, 4-114,
4-139, 4-154, 4-200, 4-201, 4-202, 4-203,
4-204, 4-205, 4-206, 4-207, 4-208, 4-209,
4-210, 4-293, 4-310, 4-311, 4-328, 4-329,
4-330, 4-333, 4-334, 5-9, 5-11, 5-12, 5-15,
5-21, 5-22, 5-24, 5-32, 5-33

palustrine forested (PFO), ES-3, ES-4, 4-39,
4-40, 4-41, 4-48, 4-50, 4-53, 4-65, 5-7, 5-9palustrine scrub-shrub (PSS), 4-39, 4-40,
4-41, 4-44, 4-48, 4-50, 4-51, 4-53, 4-80,
5-7, 5-9, 5-10
peregrine falcon, 4-105, 5-13

J-7

4-42, 4-45, 4-78, 4-80, 4-85, 4-87, 4-312,
5-5, 5-13

pig launcher, ES-1, ES-10, ES-14, 2-16,
3-16, 4-177, 4-178, 4-241, 4-244, 4-273,
4-275, 5-39, 5-41

property value, 4-137, 4-138, 4-139, 4-140,
5-18

pile-driving, ES-11, 4-58, 4-72, 4-73, 4-75,
4-95, 4-103, 4-204, 4-205, 4-293, 4-309,
4-310, 4-328, 4-329, 4-330, 4-334, 5-11,
5-12, 5-21, 5-24

public comment, ES-2, ES-3, 1-8, 1-9, 1-12,
1-13, 3-1, 3-16
radius of influence (ROI), 4-190, 4-191

Pipeline and Hazardous Materials Safety
Administration (PHMSA), 1-3, 1-7, 1-20,
2-9, 2-23, 2-25, 4-215, 4-238, 4-242,
4-250, 4-260, 4-261, 4-263, 4-265, 4-269,
4-273, 4-281, 4-283, 4-287, 4-288, 4-289,
5-23, 5-34, 5-39

recreation, ES-3, ES-8, 1-3, 4-20, 4-24, 4-65,
4-66, 4-82, 4-129, 4-153, 4-291, 4-292,
4-295, 4-306, 4-311, 5-24
red knot, ES-7, 4-92, 4-97, 4-98, 5-13

piping plover, ES-7, 4-92, 4-98, 5-13

reseeding, 4-63

Plaquemines Parish Comprehensive Master
Plan (Parish Plan), ES-8, 4-130, 4-138,
4-153, 4-316, 4-334

residence, ES-11, ES-14, 3-10, 3-11, 3-12,
3-16, 4-121, 4-122, 4-123, 4-127, 4-138,
4-139, 4-140, 4-153, 4-154, 4-201, 4-202,
4-317, 4-318, 4-329, 4-334, 5-15, 5-24,
5-26

potential impact radius, 4-285
potential noise receptor (PNR), ES-12,
4-202, 4-203, 4-206, 4-207, 4-210
Prevention of Significant Deterioration(PSD), ES-10, 1-7, 1-17, 1-21, 4-165,
4-166, 4-170, 4-182, 4-186, 4-187, 4-188,
4-189, 4-193, 4-194, 4-195, 4-199, 4-293,
4-326, 5-21

restoration, ES-8, 1-10, 2-18, 2-22, 2-23,
2-27, 3-9, 3-10, 4-10, 4-11, 4-12, 4-27,
4-28, 4-38, 4-45, 4-47, 4-48, 4-54, 4-55,
4-63, 4-64, 4-86, 4-87, 4-115, 4-116,
4-118, 4-135, 4-285, 4-294, 4-303, 4-306,
4-309, 4-312, 4-313, 4-315, 4-318, 5-3,
5-6, 5-7, 5-8, 5-24, 5-28, 5-29, 5-30, 5-31

prime farmland, 4-7, 4-9, 4-12, 4-112, 4-306,
4-316, 5-2

revegetation, 4-7, 4-10, 4-12, 4-28, 4-42,
4-53, 4-54, 4-312, 5-2, 5-8

Project-specific Upland Erosion Control,
Revegetation, and Maintenance Plan
(Project-specific Plan), ES-4, ES-5, ES-9,
ES-15, 2-15, 2-23, 2-24, 2-32, 4-4, 4-11,
4-13, 4-17, 4-33, 4-34, 4-40, 4-42, 4-53,
4-54, 4-59, 4-64, 4-76, 4-78, 4-81, 4-82,
4-123, 5-3, 5-6, 5-7, 5-8, 5-9, 5-17

riparian, 3-9, 3-10, 4-34
Rivers and Harbors Act (RHA), 1-4, 1-14,
1-16, 1-19, 4-27, 4-310, 5-4
Road Safety and Reliability Impact Study(RSRIS), 4-262
route alternatives, ES-14, 3-1, 3-12, 3-14,
5-26

Project-specific Wetland and Waterbody
Construction and Mitigation Procedures(Project-specific Procedures), ES-3, ES-4,
ES-6, ES-7, 2-31, 2-32, 2-33, 4-33, 4-34,
J-8

4-171, 4-174, 4-195, 4-196, 4-248, 4-249,
4-253, 4-254, 4-284, 4-287, 4-332, 5-2,
5-3, 5-7, 5-8, 5-19, 5-24

safe shutdown earthquake (SSE), 4-253,
4-254
safety instrument system (SIS), 4-270, 4-272,
4-278, 5-36, 5-37, 5-45

Soil
SurveyGeographic
Database(SSURGO), 4-6, 4-7, 4-10, 4-11

Saturday Island, 4-3

sperm whale, 4-96

scoping meeting, 1-4, 1-8, 1-13, 4-155

Spill
Prevention,
Control,andCountermeasures (SPCC), ES-7, ES-15,
2-23, 2-33, 4-11, 4-12, 4-13, 4-17, 4-18,
4-32, 4-33, 4-35, 4-40, 4-42, 4-45, 4-46,
4-59, 4-64, 4-78, 4-81, 4-82, 4-85, 4-87,
4-119, 4-310, 5-6, 5-7, 5-12, 5-13

scour, ES-6, 3-10, 4-78, 4-82, 4-258
sea turtle, ES-6, ES-7, 4-75, 4-88, 4-92,
4-101, 4-102, 4-103, 4-104, 4-307, 5-13
Sea, Lake, and Overland Surge from
Hurricanes (SLOSH), 4-258

spoil, 1-11, 2-17, 2-18, 2-19, 2-27, 2-28,
2-32, 4-36, 4-37, 4-43, 4-45, 4-46, 4-86,
4-119, 4-207, 5-7

Section 7 of the ESA, 1-14, 4-89, 4-104, 5-13
sedimentation, ES-6, 2-15, 4-11, 4-12, 4-28,
4-32, 4-33, 4-43, 4-70, 4-75, 4-79, 4-303,
4-308, 5-3, 5-6, 5-12

staging yard, 4-146
State Historic Preservation Office (SHPO),
1-18, 1-21, 4-38, 4-157, 4-158, 4-161,
4-323, 5-19

seismic, 2-31, 4-2, 4-3, 4-4, 4-5, 4-103,
4-229, 4-249, 4-250, 4-251, 4-252, 4-253,
4-254, 4-255, 4-268, 5-33

State Implementation Plan (SIP), 4-170,
4-198

seismic cone penetration tests (SCPT), 4-2,
4-249

Stormwater Pollution Prevention Plan
(SWPPP), 2-15, 2-23, 4-11, 4-28, 4-31,
4-40, 4-42, 4-64, 4-76, 4-81, 4-85, 4-87,
4-309, 5-4, 5-7, 5-13

seismicity, 4-3, 4-4, 4-255
selective catalytic reduction (SCR), 4-177,
4-181, 4-197, 5-20

Strategic
OnlineNaturalResources
Information System (SONRIS), 4-3, 4-15

Significant Impact Level (SIL), 4-182, 4-183,
4-184, 4-186, 4-187, 4-189, 4-190, 4-191,
4-192, 4-193, 4-195, 4-196, 4-197, 4-199

submerged aquatic vegetation (SAV), ES-7,
4-52, 4-85, 4-86

significant monitoring concentration (SMC),
4-189, 4-190, 4-191

subsidence, 4-3, 4-4, 4-56, 4-87, 4-248,
4-250, 4-251, 4-257, 4-258, 4-268, 4-288,
4-332, 5-33

slope breaker, 2-21, 4-11

sulfur dioxide (SO2), 2-6, 4-162, 4-163,
4-165, 4-168, 4-170, 4-172, 4-174, 4-179,
4-180, 4-181, 4-182, 4-184, 4-185, 4-187,

soil, 2-8, 2-22, 2-24, 2-27, 2-28, 4-2, 4-3, 4-4,
4-6, 4-7, 4-9, 4-10, 4-11, 4-12, 4-16, 4-28,
4-36, 4-38, 4-42, 4-43, 4-45, 4-53, 4-54,
4-64, 4-75, 4-112, 4-113, 4-146, 4-162,
J-9

4-188, 4-189, 4-190, 4-191, 4-193, 4-195,
4-326, 4-327

4-312, 4-313, 4-330, 4-334, 5-1, 5-8, 5-14,
5-17, 5-24

system alternatives, ES-13, 3-1, 3-2, 3-3, 3-6,
3-7, 5-25, 5-26

U.S. Coast Guard (USCG), ES-1, ES-12,
ES-15, 1-3, 1-5, 1-6, 1-18, 1-19, 2-23,
2-33, 4-29, 4-77, 4-131, 4-133, 4-148,
4-154, 4-155, 4-211, 4-212, 4-215, 4-216,
4-217, 4-218, 4-219, 4-220, 4-221, 4-222,
4-225, 4-226, 4-227, 4-237, 4-241, 4-250,
4-260, 4-262, 4-267, 4-269, 4-279, 4-282,
4-310, 4-316, 4-321, 4-323, 5-1, 5-23, 5-24

taxes, ES-9, 4-135, 4-136, 4-301, 5-17
temporary threshold shift (TTS), 4-72
Tennessee Gas Pipeline, LLC (TGP), ES-2,
ES-3, ES-8, ES-14, 1-2, 2-1, 2-5, 2-16,
2-17, 2-19, 2-20, 2-26, 2-28, 2-30, 2-32,
3-7, 3-13, 3-14, 4-3, 4-8, 4-25, 4-32, 4-33,
4-34, 4-37, 4-44, 4-45, 4-46, 4-51, 4-52,
4-55, 4-58, 4-66, 4-80, 4-82, 4-101, 4-107,
4-109, 4-112, 4-113, 4-115, 4-118, 4-171,
4-172, 4-180, 5-6, 5-31

U.S. Department of Agriculture (USDA),
1-16, 4-6, 4-7, 4-8, 4-10, 4-54
U.S. Department of Defense (DoD), 1-18,
4-118, 4-212
U.S. Department of Energy (DOE), ES-1,
1-2, 1-3, 1-5, 1-6, 1-19, 3-1, 3-3, 3-6,
4-212, 4-257, 4-265, 5-1

Texas Eastern Transmission, LP (TETCO),
ES-2, ES-14, 1-2, 2-1, 2-5, 2-16, 2-17,
2-19, 2-20, 2-26, 2-28, 2-30, 2-32, 3-7,
3-13, 3-14, 3-15, 4-3, 4-8, 4-25, 4-33, 4-34,
4-37, 4-44, 4-45, 4-46, 4-80, 4-82, 4-101,
4-107, 4-109, 4-112, 4-113, 4-115, 4-171,
4-173, 5-6, 5-31

U.S. Department of Transportation (DOT),
ES-1, ES-12, ES-15, 1-3, 1-6, 1-7, 1-20,
2-9, 2-23, 2-25, 2-26, 2-34, 4-34, 4-46,
4-154, 4-155, 4-211, 4-212, 4-213, 4-214,
4-215, 4-226, 4-227, 4-235, 4-236, 4-237,
4-238, 4-241, 4-242, 4-248, 4-250, 4-253,
4-256, 4-260, 4-261, 4-262, 4-263, 4-264,
4-265, 4-266, 4-269, 4-273, 4-281, 4-283,
4-284, 4-285, 4-286, 5-1, 5-7, 5-19, 5-23,
5-34, 5-39

topsoil, 2-19, 2-22, 4-5, 4-12, 4-47, 4-53,
4-54, 5-8
toxic air pollutant (TAP), 4-180, 4-196,
4-197, 4-323, 4-327, 5-20, 5-21
travel corridor, 4-18

U.S. Environmental Protection Agency(EPA), ES-1, ES-2, ES-11, ES-13, 1-3,
1-7, 1-8, 1-9, 1-10, 1-12, 1-13, 1-16, 1-17,
1-19, 3-13, 4-14, 4-15, 4-19, 4-31, 4-38,
4-49, 4-116, 4-118, 4-150, 4-155, 4-163,
4-164, 4-165, 4-166, 4-169, 4-170, 4-182,
4-183, 4-186, 4-188, 4-189, 4-192, 4-193,
4-197, 4-198, 4-199, 4-201, 4-260, 4-261,
4-263, 4-266, 4-293, 4-328, 4-333, 4-334,
5-1, 5-3, 5-21, 5-24, 5-25

tribe, ES-2, ES-15, 1-8, 1-12, 4-155, 4-158,
4-159, 4-160, 4-161, 4-323, 4-334, 5-1,
5-19
U.S. Army Corps of Engineers (USACE),
ES-1, ES-4, ES-15, 1-3, 1-4, 1-5, 1-7, 1-10,
1-16, 1-19, 1-21, 2-3, 2-25, 3-2, 3-13, 4-23,
4-27, 4-28, 4-33, 4-38, 4-39, 4-41, 4-42,
4-47, 4-48, 4-53, 4-56, 4-81, 4-86, 4-87,
4-114, 4-115, 4-116, 4-124, 4-128, 4-147,
4-157, 4-258, 4-293, 4-295, 4-296, 4-298,
4-299, 4-301, 4-303, 4-304, 4-305, 4-310,

U.S. Fish and Wildlife Service (FWS), ES-5,
ES-6, ES-7, 1-15, 1-16, 1-20, 3-2, 4-38,
4-60, 4-63, 4-65, 4-75, 4-81, 4-89, 4-92,

J-10

Water Quality Certification, 1-20, 4-27, 4-38,
4-310

4-93, 4-95, 4-96, 4-97, 4-98, 4-99, 4-100,
4-101, 4-103, 4-104, 4-182, 4-305, 4-309,
4-310, 5-10, 5-11, 5-13, 5-32

Waterway Suitability Assessment (WSA),
ES-12, 1-5, 1-19, 4-148, 4-219, 4-220,
4-221, 4-222, 4-282, 4-321, 5-23

U.S. Geological Survey (USGS), ES-8, 3-2,
4-3, 4-4, 4-13, 4-14, 4-19, 4-29, 4-57, 4-58,
4-106, 4-110, 4-111, 4-187, 4-251, 4-252,
4-254, 4-255, 4-257, 4-259, 4-313, 5-8,
5-14

well, ES-3, ES-6, ES-8, ES-9, ES-10, ES-11,
ES-14, ES-15, 1-13, 1-14, 2-6, 2-8, 2-13,
2-15, 2-21, 2-23, 2-24, 2-33, 3-1, 3-11,
3-12, 3-13, 4-3, 4-6, 4-14, 4-15, 4-16, 4-17,
4-18, 4-19, 4-30, 4-31, 4-39, 4-52, 4-58,
4-59, 4-64, 4-76, 4-78, 4-82, 4-85, 4-93,
4-94, 4-96, 4-99, 4-102, 4-105, 4-115,
4-116, 4-119, 4-121, 4-122, 4-133, 4-134,
4-138, 4-153, 4-155, 4-162, 4-163, 4-167,
4-174, 4-180, 4-204, 4-211, 4-212, 4-218,
4-226, 4-231, 4-237, 4-244, 4-245, 4-252,
4-260, 4-266, 4-272, 4-273, 4-277, 4-284,
4-286, 4-287, 4-307, 4-315, 4-318, 4-320,
4-327, 4-332, 5-1, 5-3, 5-4, 5-12, 5-16,
5-19, 5-26, 5-27, 5-28, 5-30, 5-32, 5-38,
5-39, 5-44

Venture Global Gator Express, LLC (Gator
Express Pipeline), ES-1, ES-2, 1-1, 1-4,
1-12, 1-13, 4-3, 4-35, 4-38, 4-132, 4-206,
4-295, 5-1, 5-18, 5-28, 5-31, 5-32
Venture Global Plaquemines LNG, LLC(Plaquemines LNG), ES-1, ES-2, 1-1, 1-4,
1-6, 1-7, 1-12, 1-13, 2-13, 3-5, 4-38, 4-138,
4-139, 4-154, 4-210, 4-211, 4-212, 4-215,
4-218, 4-221, 4-222, 4-225, 4-226, 4-227,
4-228, 4-230, 4-232, 4-233, 4-234, 4-235,
4-236, 4-237, 4-238, 4-239, 4-240, 4-241,
4-242, 4-243, 4-244, 4-245, 4-246, 4-247,
4-248, 4-249, 4-250, 4-251, 4-252, 4-253,
4-254, 4-255, 4-257, 4-258, 4-259, 4-261,
4-262, 4-263, 4-264, 4-265, 4-266, 4-267,
4-268, 4-269, 4-270, 4-271, 4-272, 4-273,
4-274, 4-275, 4-276, 4-277, 4-278, 4-279,
4-281, 4-282, 4-286, 4-295, 4-304, 4-318,
4-324, 5-4, 5-23, 5-31, 5-32, 5-33, 5-34,
5-35, 5-36, 5-37, 5-38, 5-39, 5-40, 5-41,
5-42, 5-43, 5-44, 5-45, 5-46

wetland, ES-3, ES-4, ES-5, ES-6, ES-7,
ES-8, ES-13, ES-14, ES-15, 1-3, 1-4, 1-5,
1-10, 1-11, 1-19, 2-18, 2-19, 2-20, 2-21,
2-22, 2-28, 2-29, 2-31, 2-32, 3-2, 3-6, 3-8,
3-9, 3-10, 3-11, 3-12, 3-13, 3-14, 3-15,
4-11, 4-12, 4-13, 4-19, 4-23, 4-25, 4-27,
4-32, 4-34, 4-35, 4-38, 4-39, 4-40, 4-41,
4-42, 4-45, 4-46, 4-47, 4-48, 4-50, 4-51,
4-52, 4-53, 4-54, 4-57, 4-58, 4-59, 4-65,
4-66, 4-79, 4-80, 4-81, 4-85, 4-86, 4-87,
4-94, 4-96, 4-97, 4-106, 4-109, 4-112,
4-125, 4-140, 4-202, 4-258, 4-292, 4-294,
4-299, 4-300, 4-303, 4-305, 4-306, 4-312,
4-313, 4-314, 4-315, 4-318, 4-323, 4-333,
5-1, 5-3, 5-6, 5-7, 5-8, 5-9, 5-10, 5-12,
5-13, 5-14, 5-24, 5-26, 5-29

vessel traffic, ES-6, ES-9, ES-13, 3-6, 4-26,
4-71, 4-82, 4-131, 4-133, 4-135, 4-143,
4-149, 4-203, 4-222, 4-225, 4-303, 4-309,
4-310, 4-312, 4-318, 4-321, 4-322, 4-323,
4-328, 4-333, 5-5, 5-10, 5-11, 5-15, 5-18,
5-19, 5-24
visual resources, ES-3, ES-9, ES-13, 1-3,
4-119, 4-121, 4-122, 4-123, 4-317, 4-333,
4-334, 5-15, 5-16, 5-17

whale, ES-7, 1-16, 4-87, 4-88, 4-91, 4-92,
4-96, 4-309, 5-13

volatile organic compound (VOC), 4-162,
4-170, 4-172, 4-174, 4-179, 4-180, 4-181,
4-197, 4-198, 4-326

wind erodibility group (WEG), 4-10

J-11