UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - N-09824

Type - Initial Exploration Plan

Lease(s) - OCS-G34441 Block - 521 Mississippi Canyon Area

Operator - Deep Gulf Energy II, LLC

Wells A and D

Not Found

Attached is a copy of the subject plan for public comments on issues that 

should be addressed in an Environmental Assessment.

It has been deemed submitted as of this date and is under review for approval.

Michelle Griffitt

Plan Coordinator

Description -

Rig Type -

Subject:

From:

October 1, 2014
PUBLIC COPY 

July, 2014 

INITIAL EXPLORATION PLAN 

Mississippi Canyon Block 521 

OCS-G 34441 

Barataria Prospect 

Affected State(s): Alabama, Louisiana, Texas 

Estimated Startup Date: January, 2015 

SUBMITTED BY: 

Deep Gulf Energy II, LLC 

738 Highway 6 South 

Suite 800 

Houston, Texas 77079 

Thomas E. Young 

(281) 596-0933 

tyoung@deepgulfenergy.com

AUTHORIZED REPRESENTATIVE:

Kelley Pisciola 

J. Connor Consulting, Inc. 

16225 Park Ten Place, Suite 700 

Houston, Texas 77084 

(281) 698-8519 

kelley.pisciola@jccteam.com
Records of Changes – PUBLIC COPY 

N-9824, Initial EP, Deep Gulf Energy II, LLC, (OCS-G 34441, Mississippi Canyon Block 521) 

Date Section Page Remarks 

07/24/14 All All Plan received by BOEM. 08/14/14 1 (1.4) Page 2 Updated Discrepancy on Storage Tanks and Produc09/11/14 8 Pages 14-15 Updated to reflect review and acceptance of WCD c

reflect submittal of revision to Regional OSRP and utable. 
TOC Pg 1 of 3 

TABLE OF CONTENTS 

SECTION 1 PLAN CONTENTS ..................................................................................... 1

1.1 PLAN INFORMATION ............................................................................................ 1

1.2 LOCATION ............................................................................................................. 1

1.3 SAFETY AND POLLUTION PREVENTION FEATURES ....................................... 1

1.4 STORAGE TANKS AND PRODUCTION VESSELS .............................................. 2

1.5 POLLUTION PREVENTION MEASURES ............................................................. 3

1.6 ADDITIONAL MEASURES .................................................................................... 3

1.7 COST RECOVERY FEE ........................................................................................ 3

SECTION 2 GENERAL INFORMATION ........................................................................ 4

2.1 APPLICATIONS AND PERMITS ........................................................................... 4

2.2 DRILLING FLUIDS ................................................................................................. 4

2.3 NEW OR UNUSUAL TECHNOLOGY .................................................................... 4

2.4 BONDING STATEMENT ........................................................................................ 4

2.5 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR) ............................................... 4

2.6 DEEPWATER WELL CONTROL STATEMENT .................................................... 5

2.7 BLOWOUT SCENARIO AND WORST CASE DISCHARGE CALCULATIONS ..... 5

SECTION 3 GEOLOGICAL AND GEOPHYSICAL INFORMATION ............................. 6

3.1 GEOLOGICAL DESCRIPTION .............................................................................. 6

3.2 STRUCTURE CONTOUR MAP [PROPRIETARY] ................................................ 6

3.3 INTERPRETED SEISMIC LINE(S) [PROPRIETARY] ............................................ 6

3.4 GEOLOGICAL STRUCTURE CROSS-SECTIONS [PROPRIETARY] ................... 6

3.5 SHALLOW HAZARDS REPORT ........................................................................... 6

3.6 SHALLOW HAZARDS ASSESSMENT .................................................................. 6

3.7 HIGH-RESOLUTION SEISMIC LINES [PROPRIETARY] ...................................... 6

3.8 STRATIGRAPHIC COLUMN [PROPRIETARY] ..................................................... 6

3.9 TIME VERSUS DEPTH TABLES [PROPRIETARY] .............................................. 6

SECTION 4 HYDROGEN SULFIDE INFORMATION .................................................... 7
TOC Pg 2 of 3 

4.1 CONCENTRATION ................................................................................................ 7

4.2 CLASSIFICATION ................................................................................................. 7

SECTION 5 BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION ...... 8

5.1 DEEPWATER BENTHIC COMMUNITIES ............................................................. 8

5.2 TOPOGRAPHIC FEATURES (BANKS) ................................................................. 8

5.3 TOPOGRAPHIC FEATURES STATEMENT (SHUNTING) .................................... 8

5.4 LIVE BOTTOMS (PINNACLE TREND FEATURES) .............................................. 8

5.5 LIVE BOTTOMS (LOW RELIEF) ........................................................................... 8

5.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP ................................ 8

5.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS ......................................... 9

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND 

MARINE MAMMAL INFORMATION ...................................................................... 9

5.9 ARCHAEOLOGICAL REPORT ............................................................................ 11

5.10 AIR AND WATER QUALITY INFORMATION .................................................... 11

SECTION 6 WASTES AND DISCHARGES INFORMATION ...................................... 12

6.1 PROJECTED GENERATED WASTES ................................................................ 12

6.2 MODELING REPORT .......................................................................................... 12

SECTION 7 AIR EMISSIONS INFORMATION ............................................................ 13

7.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS .......................... 13

7.2 SUMMARY INFORMATION ................................................................................. 13

SECTION 8 OIL SPILL INFORMATION ...................................................................... 14

8.1 OIL SPILL RESPONSE PLANNING .................................................................... 14

8.2 SPILL RESPONSE SITES ................................................................................... 14

8.3 OSRO INFORMATION ........................................................................................ 14

8.4 WORST CASE SCENARIO DETERMINATION ................................................... 14

8.5 OIL SPILL RESPONSE DISCUSSION ................................................................ 15

SECTION 9 ENVIRONMENTAL MONITORING INFORMATION ................................ 16

9.1 MONITORING SYSTEMS .................................................................................... 16

9.2 INCIDENTAL TAKES ........................................................................................... 16

9.3 FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY ....................... 16

SECTION 10 LEASE STIPULATIONS INFORMATION .............................................. 17
TOC Pg 3 of 3 

10.1 MARINE PROTECTED SPECIES ..................................................................... 17

SECTION 11 ENVIRONMENTAL MITIGATION MEASURES INFORMATION ........... 19

11.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS .......... 19

11.2 INCIDENTAL TAKES ......................................................................................... 19

SECTION 12 SUPPORT VESSELS AND AIRCRAFT INFORMATION ...................... 20

12.1 GENERAL .......................................................................................................... 20

12.2 DIESEL OIL SUPPLY VESSELS ....................................................................... 20

12.3 DRILLING FLUID TRANSPORTATION ............................................................. 20

12.4 SOLID AND LIQUID WASTE TRANSPORTATION ........................................... 20

12.5 VICINITY MAP ................................................................................................... 20

SECTION 13 ONSHORE SUPPORT FACILITIES INFORMATION ............................ 21

13.1 GENERAL .......................................................................................................... 21

13.2 SUPPORT BASE CONSTRUCTION OR EXPANSION ..................................... 21

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE ................ 21

13.4 WASTE DISPOSAL ........................................................................................... 21

SECTION 14 COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION ........ 22

SECTION 15 ENVIRONMENTAL IMPACT ANALYSIS .............................................. 30

SECTION 16 ADMINISTRATIVE INFORMATION ....................................................... 31

16.1 EXEMPTED INFORMATION DESCRIPTION .................................................... 31

16.2 BIBLIOGRAPHY ................................................................................................ 31
 Attachments Pg 1 of 1 

SECTION ATTACHMENTS

Section 1 Plan Contents 

 1-A OCS Plan Information Form 

 1-B Well Location Plat 

 1-C Bathymetry Map 

 1-D Pay.gov Receipt 

Section 2 General Information 

 2-A Blowout Scenario 

Section 3 Geological, Geophysical Information 

 3-A Structure Contour Maps (Proprietary Copy Only)

 3-B Interpreted Seismic Lines (Proprietary Copy Only)

 3-C Geological Structure Cross Sections (Proprietary Copy Only)

 3-D Shallow Hazard Assessment 

 3-E Stratigraphic Column (Proprietary Copy Only)

 3-F Time Versus Depth Table (Proprietary Copy Only)

Section 5 Biological, Physical and Socioeconomic Information 

 5-A Biologically Sensitive Underwater Features and Areas Map 

Section 6 Wastes and Discharges Information 

 6-A Wastes You Will Generate, Treat and Downhole Dispose or 

Discharge to the GOM 

Section 7 Air Emissions Information 

 7-A Emissions Worksheets 

Section 8 Oil Spill Information 

 8-A Oil Spill Response Discussion 

Section 12 Support Vessels and Aircraft Information 

 12-A Waste You Will Transport and/or Dispose Onshore 

 12-B Vicinity Map 

Section 14 Coastal Zone Management Act Information 

 14-A Coastal Zone Consistency Certification - Louisiana 

 14-B Coastal Zone Consistency Certification - Texas 

 14-C Coastal Zone Consistency - Alabama 

Section 15 Environmental Impact Analysis (EIA) 

 15-A Environmental Impact Analysis (EIA) 
Deep Gulf Energy II, LLC Section 1 – Pg. 1 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 1 

PLAN CONTENTS 

1.1 PLAN INFORMATION 

Under this Exploration Plan, Deep Gulf Energy II, LLC (“DGE II”) proposes to drill and 

complete one well, Location A (Location D is a mirror location of the A well and is 

included to provide an alternate well site should complications occur while drilling the 

planned A Location). The wells will be drilled with a dynamically positioned semisubmersible drilling unit or a dynamically positioned drillship, and are located in 

approximately 6,772 feet of water. 

The OCS Plan Information Form BOEM-137 is included as Attachment 1-A. 

1.2 LOCATION 

A Well Location Plat depicting the proposed surface and bottomhole locations of the 

proposed wells, measured depth/true vertical depth and water depth for each location is 

included as Attachment 1-B.

No anchors are associated with the proposed activities in this plan.

A Bathymetry Map depicting the proposed surface locations and water depth of each 

proposed well is included as Attachment 1-C. 

1.3 SAFETY AND POLLUTION PREVENTION FEATURES 

DGE II proposes to drill the wells with a dynamically positioned semi-submersible 

drilling unit or a dynamically positioned drillship which will be equipped with a Subsea 

BOP. Once a rig is contracted, BOP information and schematics will be included as a 

part of the Application for Permit to Drill. 

The rig will be equipped with safety and fire-fighting equipment required to comply with 

United States Coast Guard (USCG) regulations. Appropriate life saving equipment such 

as life rafts, life jackets, ring buoys, etc. as prescribed by the USCG, will be maintained 

on the rig at all times. 

Safety features on the drilling unit will include well control, pollution prevention, and 

blowout prevention equipment as described in BSEE regulations 30 CFR 250 C, D, E, 

O, Q and S; and as further clarified by BSEE Notices to Lessees, and current policy 

making invoked by the BSEE, Environmental Protection Agency and the U.S. Coast 

Guard (USCG). 
Deep Gulf Energy II, LLC Section 1 – Pg. 2 of 32 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

Pollution prevention measures include installation of curbs, gutters, drip pans, and 

drains on drilling deck areas to collect all contaminants and debris. Compliance will be 

maintained with the EPA NPDES Permit. The rig will be monitored daily and any waste 

or fuel resulting in pollution of the Gulf waters will be reported to the representative in 

charge for immediate isolation and correction of the problem. Any spill will be reported 

to the appropriate governmental agencies. 

1.4 STORAGE TANKS AND PRODUCTION VESSELS 

DP Semisubmersible and DP Drillship 

Type of 

Storage Tank 

Type of 

Facility 

Tank Capacity 

(bbls) 

Number 

of Tanks 

Total Capacity 

(bbls) 

Fluid Gravity

(API) 

Fuel Oil 

(day/settling 

tanks) 

DP 

Semisubmersible 360/256/161 3 777 No.2 Diesel 

Emergency 

Generator 

Fuel Oil 

DP 

Semisubmersible 31 1 31 No. 2 Diesel 

Fuel Oil 

(port) 

DP 

Semisubmersible 4541/3396 2 7937 No. 2 Diesel 

Fuel Oil 

(stb) 

DP 

Semisubmersible 4541/3396 2 7937 No. 2 Diesel 

Lube Oil DP 

Semisubmersible 116 1 116 26° 

Waste Oil DP 

Semisubmersible 38/28 2 66 26° 

Oily Water 

(port) 

DP 

Semisubmersible 186/178 2 364 N/A 

Oily Water 

(stb) 

DP 

Semisubmersible 186/178 2 364 N/A 

Fuel Oil 

(Marine 

Diesel) 

DP Drillship 901 4 3,604 0.35 

Fuel Oil 

(Marine 

Diesel) 

DP Drillship 19,386.8 2 38,773.6 0.35 

Fuel Oil 

(Marine 

Diesel) 

DP Drillship 988 2 1,976 0.35 

Fuel Oil 

(Marine 

Diesel) 

DP Drillship 4,400 1 4,400 0.35 

Fuel Oil 

(Marine DP Drillship 1.26 4 5.04 0.35 
Deep Gulf Energy II, LLC Section 1 – Pg. 3 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

Diesel) 

Fuel Oil 

(Marine 

Diesel) 

DP Drillship 1.58 1 1.58 0.35 

Fuel Oil 

(Marine 

Diesel) 

DP Drillship 4.76 1 4.76 0.35 

Fuel Oil 

(Marine 

Diesel) 

DP Drillship 225 2 450 0.35 

Liquid Mud DP Drillship 51.3 1 51.3 -- 

Drill Water DP Drillship 559 1 559 -- 

Potable 

Water DP Drillship 199.6 1 199.6 -- 

1.5 POLLUTION PREVENTION MEASURES 

These operations do not propose activities for which the State of Florida is an affected 

state. 

1.6 ADDITIONAL MEASURES 

DGE II does not propose any additional safety, pollution prevention, or early spill 

detection measures beyond those required by 30 CFR 250. 

1.7 COST RECOVERY FEE 

Documentation of the $3,673.00 cost recovery fee payment is included as Attachment 

1-D 
U.S. Department of the Interior

Bureau of Ocean Energy Management 

Have you previously provided information to verify the calculations and assumptions for your WCD? Yes X No 

If so, provide the Control Number of the EP or DOCD with which this information was provided 

Do you propose to use new or unusual technology to conduct your activities? Yes X No 

Do you propose to use a vessel with anchors to install or modify a structure? Yes X No 

Do you propose any facility that will serve as a host facility for deepwater subsea development? Yes X No 

Description of Proposed Activities and Tentative Schedule (Mark all that apply) 

Proposed Activity Start Date End Date No. of Days 

Drill and Complete Well Location A 01/01/2015 04/30//2015 120 

Drill and Complete Well Location D (Alternate Well Location) 05/01/2015 08/28/2015 120 

 

Description of Drilling Rig Description of Structure 

 Jackup X Drillship Caisson Tension leg platform 

 Gorilla Jackup Platform rig Fixed platform Compliant tower 

 Semisubmersible Submersible Spar Guyed tower 

X DP Semisubmersible Other (Attach description) Floating production 

system Other (Attach description) 

Drilling Rig Name (If known): 

Description of Lease Term Pipelines 

From (Facility/Area/Block) To (Facility/Area/Block) Diameter (Inches) Length (Feet) 

 

Form BOEM- 0137 (December 2011 – Supersedes all previous editions of this form which may not be used.) Page 1 of 4 

General Information 

Type of OCS Plan: X Exploration Plan (EP) Development Operations Coordination Document (DOCD) 

Company Name: Deep Gulf Energy II, LLC BOEM Operator Number: 02985 

Address: 738 Highway 6 South, Suite 800 Contact Person: Kelley Pisciola 

 Houston, Texas 77079 Phone Number: 281.698.8519 

E-Mail Address: kelleypisciola@jccteam.com 

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $3,673.00 Receipt No. 

Project and Worst Case Discharge (WCD) Information 

Lease(s): G-34441 Area: Mississippi Canyon Block(s) 521 Project Name: Barataria 

Objective(s) x Oil x Gas Sulphur Salt Onshore Support Base(s): Fourchon, LA 

Platform / Well Name: A and D Total Volume of WCD: 2,336,430 bbls API Gravity: 29° 

Distance to Closest Land (Miles): 65 Volume from uncontrolled blowout: 155,762 bbls/day 

OCS PLAN INFORMATION FORM 

OMB Control Number: 1010-0151

OMB Approval Expires: 12/31/14 
OCS PLAN INFORMATION FORM (CONTINUED) 

Include one copy of this page for each proposed well/structure 

Proposed Well/Structure Location 

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): Location A Previously reviewed under an approved EP or DOCD? Yes X No 

Is this an existing well or 

structure? Yes X No If this is an existing well or structure, list the Complex ID or API No. 

Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? X Yes No 

WCD Info 

For wells, volume of uncontrolled 

blowout (Bbls/Day): 155,762 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): API Gravity of fluid 29° 

Surface Location Bottom-Hole Location (For Wells) Completion (For multiple completions, enter 

separate lines) 

Lease No. OCS-G 34441 OCS 

OCS 

Area Name Mississippi Canyon 

Block No. 521 

Blockline 

Departures 

(in feet) 

N/S Departure 7,193’ FSL 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 3,620’ FWL 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 1,270,820’ 

X: 

X: 

X: 

Y: 10,334,873’ 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 28° 28’ 26.3452” 

Latitude 

Latitude 

Latitude 

Longitude 88° 09’ 2.7459” 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 6,768’ MD (Feet): TVD (Feet) MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

Anchor Radius (if applicable) in feet: N/A TVD (Feet): 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

Form BOEM- 0137 (December 2011 – Supersedes all previous editions of this form which may not be used.) Page 2 of 4 
OCS PLAN INFORMATION FORM (CONTINUED) 

Include one copy of this page for each proposed well/structure 

Proposed Well/Structure Location 

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): D Previously reviewed under an approved EP or DOCD? Yes X No 

Is this an existing well or 

structure? Yes X No If this is an existing well or structure, list the Complex ID 

or API No. 

Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? X Yes No 

WCD Info 

For wells, volume of uncontrolled 

blowout (Bbls/Day): 155,762 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): API Gravity of fluid 29° 

Surface Location Bottom-Hole Location (For Wells) Completion (For multiple completions, enter 

separate lines) 

Lease No. OCS-G 34441 OCS 

OCS 

Area Name Mississippi Canyon 

Block No. 521 

Blockline 

Departures 

(in feet) 

N/S Departure 7,193’ FSL 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 3,820’ FWL 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 1,271,020’ 

X: 

X: 

X: 

Y: 10,334,873’ 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 28° 28’ 26.3642” 

Latitude 

Latitude 

Latitude 

Longitude 88° 09’ 00.5045” 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 6,772’ MD (Feet): TVD (Feet): MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

Anchor Radius (if applicable) in feet: N/A TVD (Feet): 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

Form BOEM- 0137 (December 2011 – Supersedes all previous editions of this form which may not be used.) Page 2 of 4 
MC0521

Loc_A

Loc_D

1267700 1272700 1277700 1282700

10330500

10335500

10340500

Deep Gulf Energy II, LLC

Barataria MC 521

Well Surface Locations

Base Map 

0 6000 ft 2000 4000

Scale = 1:24000

1267700 1272700 1277700 1282700 X/Y:

Feet

10330500

10335500

10340500

Y = 10,343,520.00

Y = 10,327,680.00

X = 1,283,040.00

X = 1,267,200.00

Surface Location

OCS‐G 34441 Location A

X = 1,270,820

Y = 10,334,873

Lat: 28° 28’ 26.345237’’

Long: ‐88° 9’ 2.745893’’

3620’ FWL of MC 521

7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD

Water Depth: 6768’

Surface Location

OCS‐G 34441 Location D

X = 1,271,020

Y = 10,334,873

Lat: 28° 28’ 26.3642’’

Long: ‐88° 9’ 00.5045’’

3820’ FWL of MC 521

7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD

Water Depth: 6772’
0

0

0

6

0

8

9

0

6

7

0

9 6

6

6 7

0 0

0 0

0

096

MC0521

Loc_A

Loc_D

1267700 1272700 1277700 1282700

10330500

10335500

10340500

Deep Gulf Energy II, LLC

Barataria MC 521

Bathymetry Map

Contour: waterbottom_Justice_WAZ_Bara_RTM (mike) 

(Black), Data Type: Depth, Version: 7.5

0 6000 ft 2000 4000

Scale = 1:24000

1267700 1272700 1277700 1282700 X/Y:

Feet

10330500

10335500

10340500

Surface Location

OCS‐G 34441 Location A

X = 1,270,820

Y = 10,334,873

Lat: 28° 28’ 26.345237’’

Long: ‐88° 9’ 2.745893’’

3620’ FWL of MC 521

7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD

Water Depth: 6768’

Y = 10,343,520.00

Y = 10,327,680.00

X = 1,283,040.00

X = 1,267,200.00

Surface Location

OCS‐G 34441 Location D

X = 1,271,020

Y = 10,334,873

Lat: 28° 28’ 26.3642’’

Long: ‐88° 9’ 00.5045’’

3820’ FWL of MC 521

7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD

Water Depth: 6772’

Deep Gulf Energy II, LLC Section 2 – Pg. 4 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 2 

GENERAL INFORMATION 

2.1 APPLICATIONS AND PERMITS 

Listed in the table below are all additional applications to be filed covering operations 

proposed in this EP. 

Application/Permit Issuing Agency Status 

Application for Permit to Drill BSEE To Be Submitted 

Emergency Evacuation Plan USCG To Be Submitted 

2.2 DRILLING FLUIDS 

The table below provides the types and estimated volumes of the drilling fluids DGE II 

plans to use to drill the proposed wells. 

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

Used per Well (bbls) 

Water-based (seawater, freshwater, barite) 35,000 

Oil-based (diesel, mineral oil) N/A 

Synthetic-based (internal olefin, ester) 20,000 

2.3 NEW OR UNUSUAL TECHNOLOGY 

No new or unusual technology is proposed to carry out activities in this Initial 

Exploration Plan as defined by 30 CFR 550.200. 

2.4 BONDING STATEMENT 

The bond requirements for the activities and facilities proposed in this EP are satisfied 

by a lease bond, furnished and maintained according to 30 CFR 556, Subpart I; NTL 

No. 2000-G16, "Guidelines for General Lease Surety Bonds"; and additional security 

under 30 CFR 556.53(d) and National NTL No. 2008-N07, “Supplemental Bond 

Procedures” as required by BOEM. 

2.5 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR) 

Deep Gulf Energy II, LLC Operator Number 02985, will demonstrate oil spill financial 

responsibility for the facilities proposed in this EP according to 30 CFR 553; and NTL 

No. 2008-N05, "Guidelines for Oil Spill Financial Responsibility for Covered Facilities" 

prior to conducting operations covered in this EP. 
Deep Gulf Energy II, LLC Section 2 – Pg. 5 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

2.6 DEEPWATER WELL CONTROL STATEMENT 

Deep Gulf Energy II, LLC, Operator number 02985 has the financial capability to drill a 

relief well and conduct other emergency well control operations. 

2.7 BLOWOUT SCENARIO AND WORST CASE DISCHARGE CALCULATIONS 

The calculated Worst Case Discharge estimate for Mississippi Canyon Well Location A 

is 155,762 bbls of oil. 

In accordance with NTL No. 2010-N06, “Information Requirements for Exploration 

Plans, Development and Production Plans, and Development Operations Coordination 

Documents on the OCS,” the Blowout Scenario is included as Attachment 2-A. The 

Worst Case Discharge Volume calculations and assumptions were provided in the 

Proprietary copy of this plan.
ATTACHMENT 2-A 

Blowout Scenario 

Estimated maximum flow rate 

The estimated maximum flow rate would occur in the objective section, if a kick were 

taken and the well blew out. The maximum Worst Case Discharge (WCD) modeled for 

this scenario is 155,762 BOPD. 

Maximum duration of blowout (days) 

The duration of the blowout will be a function of the well bridging over, the ability of 

surface intervention to shut or contain the well or, as a last resort, drilling a relief well to 

kill the blowout. The expected maximum time frames for uncontrolled flow in each of the 

different operational outcomes would be as follows: 

 Bridging Over in 2 Days, 

 Surface Intervention in 15 Days, 

 A Relief Well in 71 Days. 

Maximum discharge volume 

The following table is a linear estimate of the maximum discharge volume for each of 

the aforementioned operational outcomes assuming no reservoir depletion. 

Operational 

Outcome 

Maximum 

Discharge 

Rate 

(bbl/day) 

Discharge 

Duration 

(days) 

Maximum 

Discharge 

Volume (bbl) 

Bridging Over 155,762 2 311,524 

Surface 

Intervention 155,762 15 2,336,430

Relief Well 155,762 71 11,059,102 

Potential of wellbore to bridge over during a blowout 

There is potential for the wellbore to bridge over during the WCD blowout. Bridging may 

occur due to the drawdown calculated between the formation and the open hole section. 

A Merlin reservoir simulation model was used to investigate the well conditions during 

the WCD blowout scenario. The estimated initial reservoir pressure is 9,438 psi. The 

reservoir model estimates bottom hole flowing pressures, based upon reservoir 

properties and flow rates. The calculated delta reservoir pressure (initial reservoir 

pressure minus flowing BHP at Day 1 WCD rate) is modeled to be 4,470 psi. 
In our experience in the deepwater GOM, we strive to limit the estimated total 

drawdown on a producing interval to reduce the risk of wellbore collapse and sand/fines 

migration into a well. There is a potential for the wellbore bridging over as: 

 Drawdown is estimated to be above 3,300 psi; 

 The blowout occurs in a long open hole section of the well, with no benefit 

of casing or a frac-pack completion, 

 If any water zones are exposed this will accelerate wellbore collapse and 

bridging, 

Surface intervention to stop the blowout 

In the event of a blowout and assuming the blowout prevention equipment is still intact; 

the subsea BOP will be used for successful shut-in of the well. The well would then be 

killed and re-entered to either abandon or return to normal operations. Surface 

intervention would be the first line of defense after a blowout occurs. The specific 

intervention technique chosen will depend on actual conditions and ability to access the 

existing well. 

In the event that the subsea BOP is inoperable, the surface intervention would employ 

the Helix Well Containment Group (HWCG) containment system to achieve successful 

containment of the well. The system will be employed, while simultaneously initiating 

relief well planning and operations. Specifics will be submitted within the Well 

Containment Plan. 

Typically blowouts can be controlled with surface intervention, with a good likelihood of 

success and in a relatively short time frame, as long as, the subsea casing, wellhead 

and BOP’s are not damaged beyond use. The intervention technique chosen will 

depend on actual conditions and ability to access the existing well. There can be simple 

solutions such as rig up and bullhead kill mud or more complex solutions, but the 

solution will depend on wellbore conditions. 

Surface intervention time estimate 

The assumption is that the well has an uncontrolled blowout and the MODU has sunk 

with displacement from the wellhead. Additionally, it assumes that debris removal will be 

required to gain access to the subsea BOP system. The ROV has been deployed and 

was unsuccessful in shutting in the well, using the existing subsea BOP control panel. 

The scenario employs one of the aforementioned containment system’s capping BOP. 

The table on the next page describes the estimated time required to shut in and secure 

the well using the containment system or capping stack. Note that these operations all 

basically start at the same point in time and are performed in parallel. The entire 

operation is estimated to take 15 days from start of site assessment until the capping 

stack has been deployed and the well shut in. 

Duration of a well capping operation 

Operation Incremental 

Duration 

(days) 

Cumulative Time Since 

Event Start 

(days) 
Assess wellbore conditions for 

surface intervention requirements. 

Conduct notifications to the 

regulatory agencies and primary 

contractors. 

2 2 

Site Preparation which includes 

mobilizing and deployment of the 

IWOCS system and Dispersant 

system. 

3 5 

Debris removal including 

mobilization of ROV boat and 

construction support vessel and 

execution of debris removal plan. 

2 7 

Well capping and/or cap and flow 

operations which include 

mobilization, deployment, and 

installation of the well containment 

system. 

8 15 

Relief Well 

It is preferred to drill relief wells from an open water location, rather than a platform 

location. Open water locations provide the best option on designing a simpler intercept 

well and allow a greater choice on rig availability. There are not any platforms in the 

immediate vicinity, therefore it is not feasible to consider as a relief well location. 

Relief well location and drilling strategy 

The surface location for a relief well(s) is a function of seabed bottom and shallow 

hazard conditions, current, wind direction and wellbore access. The relief well surface 

location for the MC 521 Well No. 001 (drilled from Well Site A surface location) could be 

drilled from an appropriately cleared-of-hazards surface location to the south-southeast 

of the Well Site A location. 

A relief well for MC 521 Well No. 001 would be designed to intersect the blowout well 

below the16” casing point. Once the well is intersected, kill pumping operations would 

be initiated to kill the blowout well. 

Relief well rig availability 

As of the date of this EP submittal, the rigs listed below have Gulf of Mexico area of 

operations, and could be available for relief well operations: 
Rig Name Contractor

Rated 

Water 

Depth 

MODU Type Rig Status 

Ensco 8500 Ensco 8,500’ DP Semisubmersible Contracted 

GOM

Ensco 8501 Ensco 8,500’ DP Semisubmersible Contracted 

GOM

Ensco 8505 Ensco 8,500’ DP Semisubmersible Contracted 

GOM

West Sirius Seadrill 10,000’ DP Semisubmersible Contracted 

GOM

Maersk Developer Maersk 10,000’ DP Semisubmersible Contracted 

GOM

Danny Adkins Noble 12,000’ DP Semisubmersible Contracted 

GOM

C.R. Luigs Transocean 10,000’ DP Drill Ship Contracted 

GOM 

Discoverer Deep 

Seas 

Transocean 10,000’ DP Drill Ship Contracted 

GOM 

Relief well package constraints 

The proposed rigs for relief well operations have suitable drilling packages with 

sufficient capabilities to work in the subject water depths and drill to the required relief 

well depth. The BOP systems have met the BSEE certification requirements and will be 

re-inspected in transit, prior to drilling a relief well to the required true vertical depth. 

Relief well rig contract and mobilization timing 

A suitable rig could be selected and a contract finalized in 48 hours after undertaking 

the decision to begin relief well operations. Backup tubulars and wellhead systems are 

maintained in stock for each well. Mobilization of equipment and services to the rig for 

the relief well could be completed while operations required to suspend the rig’s current 

activity were taking place. The time required to contract, mobilize, drill a relief well and 

kill the blowout well is estimated at 71 days and is summarized on the next page. 

 
Duration of relief well 

Description Days Cumulative Days 

Well Control Assessment. Identify suitable 

MODU for relief well operations 2 2 

MODU suspends operations from current 

well. Contract to be executed and Well 

Spud Equipment is mobilized 

14 16 

Mobilize Rig and install 36” Structural 

Casing 6 22 

Spud and drill to the top of the zone of 

interest and set casing. 38 60

Mag-Range relief well into intersecting 

position. 6 66 

R/U pumping equipment and kill well. 5 71 

R/D Pumping Equipment, PA Wellbore, Pull 

Riser, and Demobilize 12 83 

Blowout Prevention and Intervention 

Summary of prevention measures 

DGE II has maintained a safe track record of prudent operations in the GOM deepwater 

environment. It will continue to implement its safe operating practices to enhance its 

operating risk reduction program. In addition to the safe operating practices, the 

following measures will be implemented into well design, drilling and completion 

operations. 

 BOP Certification, BOP Drills, Pit Drill’s and all other required BSEE testing 

requirements, 

 Current Well Control Certification for all Drilling and Completion Rig Site 

Supervisors, 

 Taking Slow Pump Rate measurements during all open hole operations and 

critical cased hole operations, 

 Updating Kill Sheets during each tour and posting the same on the rig floor, 

 Maintain a current BOP to RKB spaceout Chart, 

 Monitoring wellbore fill-ups and displacements during trips, by the Well Site 

Supervisor, 

 Maintain the necessary circulating swages, TIW Valves and IBOP on the rig 

floor at all times during operations and function test these valves during each 

tour. 

The utilization of Pre-Job Safety meetings will continue to be implemented prior to each 

operation with all of the rig crews. These are intended to create a behavior based safety 

program and promote an atmosphere within the and rig crew interface, such that a 
“Stop the Job” mentality is promoted across the rig contractor’s crew, empowering every 

crew member to question the safety of each operation. 

Early well control intervention 

In the event of a blowout situation, due to failed BOP equipment and uncontrolled flow 

at the seafloor or at surface, assuming all other surface controlled actuation measures 

have failed or are inaccessible, a ROV will fly into position at the BOP subsea actuation 

panel and actuate the shear ram or pipe rams to establish containment. 

If the riser system and rig have been compromised, then debris removal will be initiated 

to obtain clear access to the BOP. A Capping Stack will be employed to achieve 

successful containment of the well. Once containment is established and wellbore 

pressure testing and assessment is completed by DGE II and Well Control Specialist, 

well kill operations can be initiated through the existing wellbore. 

Well control engineering services 

DGE II will have service agreements in place with Wild Well Control and Boots and 

Coots International Well Control prior to commencement of well operations. In the event 

of a blowout situation, these companies will be contacted to assist in the detailed design 

and implementation of well control and/or relief well operations. 

Additional prevention & mitigation techniques 

Pursuant to wellbore cementing and zonal isolation techniques, all cementing 

operations will be modeled and designed under the guidelines set forth in API 

Recommended Practice 65 Part 1 & 2. Operations will be dictated by the rules and 

requirements set forth in Federal Regulations, under the wellbore cementing 

requirements. 

API Standard 53 Blowout Prevention Equipment Systems for Drilling Wells and 

Recommended Practice 16Q for Marine Drilling Risers will be used as the guidelines for 

installation, testing and maintenance of the surface and subsea Marine Risers and BOP 

systems. The purpose of these recommended practices is to provide information that 

can serve as a guide for installation and testing of blowout prevention systems has 

contracted for floating marine drilling rigs. 

The goal of using these recommended practices is to assist DGE II operations in 

promoting personnel safety, public safety, and integrity of the drilling equipment and 

preservation of the environment for floating marine drilling operations. These 

recommended practices help to facilitate the broad availability of proven, sound 

engineering and operating practices. 

These practices are considered acceptable for accomplishing BOP and Marine Riser 

associated operations. However, equivalent alternative installations and practices may 

be utilized to accomplish the same objectives. When using these recommended 

practices or other alternatives, DGE II will insure that operations comply with 

requirements of Federal Regulations. 
Deep Gulf Energy II, LLC Section 3 – Pg. 6 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 3 

GEOLOGICAL AND GEOPHYSICAL INFORMATION 

3.1 GEOLOGICAL DESCRIPTION 

Proprietary Information. 

3.2 STRUCTURE CONTOUR MAP 

Proprietary Information.

3.3 INTERPRETED SEISMIC LINE(S) 

Proprietary Information. 

3.4 GEOLOGICAL STRUCTURE CROSS-SECTIONS 

Proprietary Information. 

3.5 SHALLOW HAZARDS REPORT 

A shallow hazards survey was conducted over Mississippi Canyon Block 521. 

In accordance with NTL No. 2008-G05, “Shallow Hazards Program” (Extended by NTL 

NTL No. 2014-G03, “Extension of Prior Notices to Lessees”), a shallow hazards survey 

evaluating seafloor and subsurface geological and manmade features and conditions 

that may adversely affect drilling operations, was conducted by Geoscience Earth & 

Marine Services (GEMS). The shallow hazards report is provided with this plan. 

3.6 SHALLOW HAZARDS ASSESSMENT 

In accordance with NTL No. 2008-G05, “Shallow Hazards Program,” (Extended by NTL 

No. 2014-G03, “Extension of Prior Notices to Lessees”), a shallow hazards assessment 

has been prepared for the proposed surface locations evaluating seafloor and 

subsurface geological and manmade features and conditions that may adversely affect 

drilling operations. The shallow hazards survey and archaeological assessment is 

included as Attachment 3-D. 

3.7 HIGH-RESOLUTION SEISMIC LINES 

Proprietary Information. 

3.8 STRATIGRAPHIC COLUMN 

Proprietary Information. 

3.9 TIME VERSUS DEPTH TABLES 

Proprietary Information.
10344 Sam Houston Park Drive 

HOUSTON, TEXAS 77043 

Phone: (713) 351-7900 

www.gemsinc.com

Geoscience Earth & Marine Services // 1 

FORUM ENERGY TECHNOLOGIES, INC.

July 2, 2014 Project No. 0613-2255b 

Deep Gulf Energy Companies 

738 Highway 6 South 

Houston, TX 77079 

Attention: Mr. Richard Brainard 

Site Clearance Letter 

Proposed Wellsites A and D 

Block 521 (OCS-G-34441) 

Mississippi Canyon Area 

Gulf of Mexico 

Deep Gulf Energy Companies, (DGE) contracted Geoscience Earth & Marine Services, (GEMS) to provide 

an assessment of the shallow geologic conditions and to determine the favorability of drilling operations for 

the Proposed Wellsites A and D in Block 521 (OCS-G-34441), Mississippi Canyon Area (MC), Gulf of 

Mexico. This letter addresses specific seafloor and subsurface geologic conditions to the Top of Salt at 

approximately 1,551 ft below the mudline (bml) at the proposed locations. 

This letter is based on findings provided within the main body of the geohazard report “Geologic, 

Stratigraphic, and Archaeological Assessment Block 521 (OCS-G-34441), Mississippi Canyon Area, Gulf of 

Mexico” (GEMS Report No. 0613-2255bc). The text, maps, and figures included in the geohazard report 

provide detail on the regional geology of the MC 521 Survey Area. This letter is intended to supplement 

that report with details pertaining directly to the proposed wellsites. 

The following sections provide details specific to the well location, including: available data, Notice to 

Lessees (NTL) requirements, obstructions, archaeological assessment, and wellsite conditions. 

Proposed Well Locations

The surface locations for the Proposed Wellsites A and D are in the west-central portion of Block 521, 

Mississippi Canyon Area, Gulf of Mexico. DGE plans to drill this well using a dynamically positioned drilling 

vessel. This assessment addresses the seafloor conditions within a 2,000 ft radius around the proposed 

wellsite locations. DGE provided the following coordinates: 

Proposed Wellsite A 

Spheroid & Datum: Clarke 1866, NAD27 

Projection: UTM Zone 16 North Line Reference Block Calls 

MC 521 

X: 1,270,820 ft Latitude: 28° 28' 26.3452" N Inline 12045 3,620 ft FWL 

Y: 10,334,873 ft Longitude: 88° 09' 02.7459" W Crossline 11308 7,193 ft FSL 

Proposed Wellsite D 

Spheroid & Datum: Clarke 1866, NAD27 

Projection: UTM Zone 16 North Line Reference Block Calls 

MC 521 

X: 1,271,020 ft Latitude: 28° 28' 26.3642" N Inline 12048 3,820 ft FWL 

Y: 10,334,873 ft Longitude: 88° 09' 00.5045" W Crossline 11305 7,193 ft FSL 
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Project No. 0613-2255b Proposed Wellsites A and D 

Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 3 

FORUM ENERGY TECHNOLOGIES, INC.

NTL Requirements 

The following report complies with the Bureau of Ocean Energy Management (BOEM, formerly MMS) 

Notice to Lessees (NTL’s) 2008-G04, 2008-G05, and 2009-G40 (MMS, 2008a, b, and 2010). BOEM’s 

NTL 2014-G05 (BOEM, 2014a) extends the expiration of NTL 2008-G04 and -G05. The operator will be 

required to follow NTL’s 2008-G04 and -G06 with respect to an ROV monitoring survey as well as pre- and 

post-spud ROV visual inspection surveys (MMS, 2008a and 2008c). The Federal lease Block MC 521 is 

considered archaeologically significant (NTL 2011-JOINT-G01, BOEM, 2011). Any seabed disturbing 

activities within this designated block will be subject to the archaeological survey and reporting 

requirements according to NTL 2005-G07 (MMS, 2005). A high-resolution geophysical survey was 

conducted in the area by C & C Technologies, Inc., (C & C) in August 2013 using an autonomous 

underwater vehicle (AUV). The data collected were analyzed by a marine archaeologist at GEMS and an 

archaeological assessment is included in the MC 521 geohazard report (GEMS, 2014). 

Power Spectrum. According to NTL 2008-G05 (MMS, 2008b), 3-D seismic reflection data may be used 

for shallow hazard assessments with approval from the BOEM, Gulf of Mexico Region. A power spectrum 

analysis was conducted from the 3-D seismic data cube provided by DGE to illustrate the data parameters. 

The power spectrum curve (below) was generated within a 500-ft radius of the intersection of the inline and 

crossline at the proposed wellsite location. We converted the amplitude vs. frequency spectrum, generated 

by the SMT software, to power vs. frequency by squaring the amplitude values as described by J. A. 

Coffeen, 1978.

Illustration 2. Power Spectrum Analysis Curve, MC 521, Proposed Wellsites A and D

Obstructions

There are no existing exploration or development wells within MC 521. Several existing pipelines and 

umbilicals are present near the proposed well locations in MC 521 (BOEM, 2014b, Table 1). These 

pipelines are associated with BP’s Na Kika platform located in MC 474, about 9.0 miles northwest of the 

proposed wellsite. Table 1 provides a summary of the pipelines and umbilicals located within MC 521. 

0

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Project No. 0613-2255b Proposed Wellsites A and D 

Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 4 

FORUM ENERGY TECHNOLOGIES, INC.

Table 1: Existing Pipelines Within MC 521 

Operator Pipeline Type Origin Destination

Distance/ 

Direction to 

Proposed Wellsite A

BP Exploration & Production Inc.* 8-inch Bulk Oil MC 522 SLED MC 474 Na Kika Platform 3,279 ft/S 

BP Exploration & Production Inc.* 8-inch Bulk Oil MC 522 SLED MC 520 SLED 4,072 ft/S 

BP Exploration & Production Inc.* 8-inch Bulk Gas MC 522 SLED MC 474 Na Kika Platform 1,380 ft/S 

BP Exploration & Production Inc.* 5-inch Umbilical MC 474 Na Kika 

Platform MC 522 #F5, #F6 1,638 ft/S 

Shell Offshore Inc.* 1-inch Umbilical MC 474 Na Kika 

Platform MC 522 #F3, #F4 2,558 ft/S 

*Illustrated on Maps 1 through 5 

Archaeological Assessment

High-resolution digital side-scan sonar, subbottom profiler, multibeam bathymetry, and multibeam backscatter 

data were collected in 2013 over the primary survey area using C & C’s C-Surveyor III Hugin 4500 AUV.

An Edgetech Dual Frequency Side-Scan Sonar system was used on all survey lines at 200-m (656 ft) 

range. The AUV collected 230 kHz side-scan sonar data at 200-m (656 ft) line spacing on the primary lines 

ensuring 200% coverage on all lines. The AUV survey lines also collected 1.5-4.5 kHz Chirp subbottom 

profiler data, 3-m (9.8 ft) bin multibeam bathymetry data, and 1-m (3.28 ft) bin multibeam backscatter data. 

The 2014 GEMS assessment delineated a total of eight unidentified side-scan sonar contacts in the AUV 

data within the Survey Area. An unidentified side-scan sonar contact was discovered within 610 m 

(2,000 ft) of the proposed wells (Illustration 3). Sonar Contact 8, an unknown object interpreted to represent 

modern debris from shipping, storm, fishing, or exploration activities, is located approximately 206 m 

(676 ft) southeast of Proposed Wellsite A and 157 m (516 ft) southeast of Proposed Wellsite D. According 

to the sonar data, the object is irregular in shape and measures approximately 7.3 m (23.9 ft) long 

and 1.8 m (5.8 ft) wide. 

No potential submerged cultural resources were identified in the subbottom, bathymetry, or backscatter 

data sets. 

Illustration 3. Side-Scan Sonar Contact No. 8 

Archaeological Avoidance. No archaeological avoidances exist within the area of potential effect for the 

Proposed Wellsites A and D. No known shipwrecks lie within the area of potential effect. A 30.5-m (100 ft) 

geohazard avoidance is recommended for Sonar Contact 8. 

 
Project No. 0613-2255b Proposed Wellsites A and D 

Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 5 

FORUM ENERGY TECHNOLOGIES, INC.

Wellsite Conditions

A gas pipeline and an umbilical exist within 2,000 ft of the proposed well locations (Map 1). The shallow 

stratigraphy at the proposed well reflects alternating deposition of mass-transport, turbidite, and slope-fan 

deposits interbedded with pelagic and hemipelagic clays and silts. Overpressured sands and minor 

amounts of shallow gas are possible within the sand-prone sequences. Precautions should be made when 

drilling through potentially overpressured intervals. 

Water Depth, Gradient, and Seabed Sediments. The water depth is about -6,767 ft below sea level (bsl) 

at Proposed Wellsite A and about -6,771 ft bsl at Proposed Wellsite D (Map 1). The seafloor slopes to the 

southeast at about 0.9° at Proposed Wellsite A and 1.8° at Proposed Wellsite D. The proposed wellsites 

are situated along the southern flank of a shallow salt dome in the west-central portion of MC 521 

(Illustration 1). Slightly irregular seafloor conditions associated with shallow mass-transport deposits are 

expected at the proposed sites (Map 2). A surficial drape of soft, high-water content silty clays covers the 

seafloor surrounding the proposed wellsites (Figure 1). 

Deepwater Benthic Communities. There is no evidence of hydrocarbon seepage, authigenic carbonates, 

or hardbottom conditions that could support high-density, deepwater chemosynthetic or coral communities 

near the proposed surface locations. The Side-Scan Sonar Mosaic and Seafloor Amplitude Rendering 

(Maps 3 and 4) shows low reflective and normal or ambient amplitudes along the seafloor at the proposed 

wellsites. The potential for high-density chemosynthetic or other deepwater benthic communities is 

negligible. 

Stratigraphy

Stratigraphic conditions are shown on Figures 1, 2, and 3. The surficial interval from the seafloor to 

about 125 ft bml (upper portion of Unit 1), likely consists of very soft surficial clays (<15 ft) overlying 

stratified, normally consolidated hemipelagic clays and silty clays (Figure 1). Shallow mass-transport 

deposits are expected below about 125 ft bml. These amalgamated sediments likely represent 

dewatered clays and could be stiffer than a normal or standard sediment profile. 

The seismic character of the interval between 125 ft and 242 ft bml (lower portion of Unit 1) consists of 

interlayered chaotic, low-amplitude reflectors and continuous, low to moderate-amplitude reflectors 

(Figures 1 through 3). The overall sequence likely represents interlayered mud-rich, mass-transport 

deposits with bedded pelagic and hemipelagic clays and silty clays. Mass-transport deposits within the 

lower portion of Unit 1 are expected to range between 35 ft to 55 ft thick. 

Unit 2 (242 ft to 462 ft bml) consists of bedded, low to high-amplitude reflectors interlayered with chaotic, 

transparent to low-amplitude zones (Figures 2 and 3). This sequence is identified as the “MC Blue Unit” 

basin floor fan. The Blue Unit interval is a sand-rich, slope-fan complex with hemipelagic muds and 

mud-rich, mass-transport deposits. The transparent to low-amplitude zones within the unit likely 

represent hemipelagic muds and mass-transport deposits. The moderate to high-amplitude reflectors 

within this interval represent sand-rich, slope-fan deposits. 

Unit 3 (462 ft to 659 ft bml) consists of low-amplitude, continuous to semi-continuous reflectors 

interbedded with low-amplitude, chaotic reflectors (Figures 2 and 3). This sequence likely represents 

stratified, clay-dominated turbidites interlayered with thin mass-transport deposits. Thin sand seams are 

possible within the turbidite and mass-transport deposits in this unit. 

Unit 4 (659 ft to 1,092 ft bml) consists of chaotic, amorphous, low-amplitude reflectors overlying, 

continuous to discontinuous moderate to high-amplitude reflectors (Figures 2 and 3). This interval likely 

corresponds to interbedded clay-prone turbidites and sand-rich, slope-fan deposits overlain by clay-rich, 

mass-transport deposits. Potentially thick sand layers are possible within the lower portion of the unit. 

Unit 5 (1,092 ft to 1,551 ft bml) consists of amorphous, low-amplitude reflectors interlayered with 

semi-continuous, moderate to high-amplitude reflectors (Figures 2 and 3). This interval likely represents 

clay-dominated turbidite and mass-transport deposits interbedded with sand-prone, slope-fan sediments. 

Potential sand layers may be encountered within slump deposits in the mid portion of the unit. 

 
Project No. 0613-2255b Proposed Wellsites A and D 

Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 6 

FORUM ENERGY TECHNOLOGIES, INC.

Faults

A vertical well bore at the proposed wellsites is not expected to intersect any seafloor or buried faults in 

the shallow section to the Top of Salt (1,551 ft bml), Map 5 and Figures 1 through 3. Various buried faults 

exist near the proposed well location within Unit 5 (1,092 ft to 1,551 ft bml), Map 5 and Figure 2. These 

faults are normal adjustment faults mostly confined to Unit 5 and the lower portion of Unit 4. The faults 

generally trend northwest-southeast and are downthrown to the southwest toward the wellsite, but do not 

appear to be intersected by the proposed wellsite and are not expected to impact drilling operations. The 

closest buried fault is about 3,600 ft northeast of the proposed wellsite. 

Shallow Gas 

The well path will not penetrate any interpreted high-amplitude events from the seafloor to the Top of Salt 

(1,551 ft bml), Map 5 and Figures 2 and 3. There is a low potential for encountering shallow gas below 

Horizon 10 (242 ft bml) to the Top of Salt (1,551 ft bml). Moderate-amplitude reflectors within the turbidite 

and slope-fan deposits may indicate coarse grained sediments within the predominantly clay-rich 

intervals. Minor amounts of biogenic gas may be encountered within isolated sands. A negligible 

potential for encountering shallow gas exists within the clay-prone units between the seafloor and 

Horizon 10 (242 ft bml) and from Horizon 20 (462 ft bml) to 976 ft bml. 

Shallow Water Flow

There is a moderate potential for shallow water flow within the MC Blue Unit slope-fan complex from 

Horizon 10 to Horizon 20 (242 ft to 462 ft bml, Unit 2). The Blue Unit contains sand-rich intervals and has 

sourced shallow water flow problems in the Mississippi Canyon region (BOEM, 2014c). Three incidents 

of low severity water flow are reported from wells within a 10-mile radius of the proposed locations. 

Reported depths below the mudline to the flows vary from 448 ft to 2,371 ft. Potential sands within this 

unit may be thick and continuous; however, the Blue Unit is relatively shallow with thin sediment 

overburden at the proposed well location. Any sand layers encountered within this shallow section may 

not be significantly overpressured. 

There is a moderate potential for encountering shallow water flow within the lower portion of Unit 4 (976 ft 

to 1,092 ft bml), Figure 3. Potentially thick and continuous sand deposits may exist within the turbidite 

and slope-fan deposits within this interval. 

A low potential for water flow exists in the upper portion of Unit 4 from Horizon 30 (659 ft bml) to 

976 ft bml and within Unit 5 from Horizon 40 to the Top of Salt (1,092 ft to 1,551 ft bml), Figure 3. Any 

sands encountered within the turbidite and mass-transport deposits within these intervals are expected to 

be thin seams and not likely to produce sustained flows. There is a negligible potential for encountering 

shallow water flow within Unit 1 from the seafloor to Horizon 10 (242 ft bml) and within Unit 3 from 

Horizon 20 to Horizon 30 (462 ft to 659 ft bml). 

Closing

No potential submerged cultural resources were found in the area of potential effect (GEMS, 2014). Sonar 

Contact No. 8 is the closest unidentified sonar contact and is located approximately 206 m (676 ft) southeast of 

Proposed Wellsite A and 157 m (516 ft) southeast of Proposed Wellsite D. This contact likely represents 

modern debris. Contact No. 8 is not recommended for archaeological avoidance or investigation; however, a 

100 ft geohazard avoidance of all sonar contacts is recommended to avoid damage to equipment and 

infrastructure. Should any potentially historic materials such as textiles, wood, ceramics, or other items be 

uncovered during operations in the area, all operations must cease and BOEM be notified within 48 hours. 

An active pipeline and umbilical exist within 2,000 ft of the proposed wellsites. The subsurface 

interpretation concluded a moderate potential for shallow water flow within the MC Blue Unit slope-fan 

complex (242 ft to 462 ft bml) and within the turbidite and slope-fan interval in the lower portion of Unit 4 

(976 ft to 1,092 ft bml). These units are associated with shallow water flow events throughout the 

Mississippi Canyon Area. We advise using caution while drilling through the potentially overpressured 

sands within these units, some of which may contain minor amounts of biogenic gas. Shallow 
Project No. 0613-2255b Proposed Wellsites A and D 

Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 7 

FORUM ENERGY TECHNOLOGIES, INC.

mass-transport deposits are expected below about 125 ft bml. Drillers should be aware that the deposits 

are anticipated to vary between 35 ft and 55 ft thick, and variable soil conditions are likely. 

We appreciate the opportunity to be of service to Deep Gulf Energy Companies, and look forward to working 

with DGE on future projects. 

 Sincerely, 

 GEOSCIENCE EARTH & MARINE 

 SERVICES 

Carla Cleveland George Schwarz, Ph.D. 

Geoscientist Marine Archaeologist 

Erin Williams Janes Daniel Lanier 

Project Manager - Senior Geoscientist Director - GEMS 

Attachments (4 Maps, 3 Figures) 

Distribution: Mr. Richard Brainard, DGE, Houston, TX. (10 Copies) 

References: 

Bureau of Ocean Energy Management, 2011, Notice to lessees and operators of federal oil and gas leases and 

pipeline right-of-way holders on the outer continental shelf, revisions to the list of OCS lease blocks requiring 

archaeological resource surveys and reports: U. S. Department of the Interior, Bureau of Ocean Energy 

Management, Bureau of Safety and Environmental Enforcement, Gulf of Mexico OCS Region, NTL 2011-JOINTG01. 

Bureau of Ocean Energy Management, 2014a, Notice to lessees and operators of federal oil, gas, and sulphur leases 

in the outer continental shelf, Gulf of Mexico OCS region: Extension of prior notice to lessees, NTL 2014-G05. 

Bureau of Ocean Energy Management, 2014b, ASCII data files, published on the BOEM Gulf of Mexico Region 

homepage, <http://www.gomr.boemre.gov/homepg/pubinfo/freeasci/freedesc.html>, accessed July, 2014. 

Bureau of Ocean Energy Management, 2014c, Safety performance review - shallow waterflows can pose significant 

hazards to deepwater drilling, http://www.gomr/boemre.gov/homepg/offshore/sftey/watrflow.html website accessed 

July, 2014. 

Coffeen, J. A., 1978, Seismic exploration fundamentals: Tulsa, the Petroleum Publishing Co., p. 125. 

GEMS, 2014, Geologic, stratigraphic, and archaeological assessment, block 521, Mississippi Canyon Area, Gulf of 

Mexico: GEMS Report No. 0613-2255bc. 

Minerals Management Service, 2005, Notice to lessees and operators of federal oil, gas, and sulphur leases and 

pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, Archaeological resource 

surveys and reports: U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2005-G07. 

Effective Date July 1, 2005. 

Minerals Management Service, 2008a, Notice to lessees and operators of federal oil, gas, and sulphur leases in the 

outer continental shelf, Gulf of Mexico OCS region, information requirements for exploration plans and development 

operations coordination documents: U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, 

NTL 2008-G04. Effective Date May 1, 2008. 

Minerals Management Service, 2008b, Notice to lessees and operators of federal oil, gas, and sulphur leases and 

pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, shallow hazards requirements: 

U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G05. 
Project No. 0613-2255b Proposed Wellsites A and D 

Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 8 

FORUM ENERGY TECHNOLOGIES, INC.

Minerals Management Service, 2008c, Notice to lessees and operators of federal oil, gas, and sulphur leases in the 

outer continental shelf, Gulf of Mexico OCS region; remotely operated vehicle surveys in deepwater, U. S. 

Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G06. 

Minerals Management Service, 2010, Notice to lessees and operators of federal oil and gas leases in the outer 

continental shelf, Gulf of Mexico OCS region, deepwater benthic communities: U. S. Department of the Interior, 

Minerals Management Service, Gulf of Mexico, NTL 2009-G40. 
Deep Gulf Energy II, LLC Section 4 – Pg. 7 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 4 

HYDROGEN SULFIDE INFORMATION 

4.1 CONCENTRATION 

DGE II anticipates encountering zero H2S during the proposed operations. 

4.2 CLASSIFICATION 

In accordance with Title 30 CFR 250.490(c), DGE II requests that the area of proposed 

operations be classified by the BOEM as H2S absent. 
Deep Gulf Energy II, LLC Section 5 – Pg. 8 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 5 

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION 

5.1 DEEPWATER BENTHIC COMMUNITIES 

The seafloor disturbing activities proposed in this plan are in water depths greater than 

300 meters (984’). Geoscience Earth & Marine Services (GEMS) was contracted to 

provide an assessment of the shallow conditions at the proposed surface locations. 

The purpose of the assessment was to address seafloor conditions that may impact 

exploratory drilling operations within 2,000 feet of the proposed well sites. DGE II will 

avoid all high-density deepwater benthic communities by 2,000 feet from each proposed 

mud and cuttings discharge location and 250 feet from the location of all other seafloor 

disturbances. As per NTL No. 2009-G40, “Deepwater Benthic Communities,” a map 

showing the 2,000 foot radius around the well sites is included as Attachment 5-A. 

5.2 TOPOGRAPHIC FEATURES (BANKS) 

Activities proposed in this EP do not fall within 305 meters (1000 feet) of a topographic 

“No Activity Zone;” therefore, no map is required per NTL No. 2009-G39, “Biologically 

Sensitive Underwater Features and Areas.” 

5.3 TOPOGRAPHIC FEATURES STATEMENT (SHUNTING) 

All activities proposed under this EP will be conducted outside all Topographic Feature 

Protective Zones; therefore shunting of drill cuttings and drilling fluids is not required per 

NTL No. 2009-G39, “Biologically Sensitive Underwater Features and Areas.” 

5.4 LIVE BOTTOMS (PINNACLE TREND FEATURES) 

Mississippi Canyon Block 521 is not located within 61 meters (200 feet) of any pinnacle 

trend feature; therefore, a separate bathymetric map is not required per NTL No. 2009-

G39, “Biologically Sensitive Underwater Features and Areas.” 

5.5 LIVE BOTTOMS (LOW RELIEF) 

Mississippi Canyon Block 521 is not located within 30 meters (100 feet) of any live 

bottom (low relief) feature with vertical relief equal to or greater than 8 feet; therefore, 

live bottom (low relief) maps are not required per NTL No. 2009-G39, “Biologically 

Sensitive Underwater Features and Areas.” 

5.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP 

Mississippi Canyon Block 521 is not located within 30 meters (100 feet) of potentially 

sensitive biological features; therefore, biologically sensitive area maps are not 

required. 
Deep Gulf Energy II, LLC Section 5 – Pg. 9 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

5.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS 

Pursuant to NTL No. 2008-G06, “Remotely Operated Vehicle Surveys in Deepwater” 

(Extended by NTL No. 2014-N01, “Elimination of Expiration Dates on Certain Notices to 

Lessees and Operators Pending Review and Reissuance”), operators may be required 

to conduct remotely operated vehicle (ROV) surveys during pre-spudding and postdrilling operations for the purpose of biological and physical observations. 

If required, surveys will be conducted immediately prior and upon completion of drilling 

operations. A rig-based ROV equipped with video imaging capabilities will be used. The 

survey pattern will consist of six transects centered on the well location with tracks 

extending approximately 100 meters away from the well on bearings of 30 degrees, 90 

degrees, 150 degrees, 210 degrees, 270 degrees and 330 degrees. The seafloor will 

be videotaped continuously along each track. 

Biological and physical observations as described in the subject NTL and Form BOEM0141 will be made prior to commencing drilling operations and also following the 

completion of drilling operations, but prior to moving the rig off location. The 

observations will be documented using Form BOEM-0141 or a facsimile and submitted 

to the BOEM within 60 days after the second survey is completed. 

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND 

MARINE MAMMAL INFORMATION 

There are five (5) species of sea turtles that may be found in the Gulf of Mexico (see 

table below). NOAA fisheries currently list all five of these turtles as endangered (E) or 

threatened (T). 

Species Scientific Name Status Potential 

Presence 

Critical 

Habitat 

Designated in 

the Gulf of 

Mexico 

Lease 

Area 

Coastal 

Sea Turtles 

Loggerhead Carettsa caretta T x x None 

Green Chelonia mydas T,E x x None 

Leatherback Dermochelys coriacea E x x None 

Hawksbill Eretmochelys 

imbricata 

E x x None 

Kemp’s 

Ridley 

Lepidochelys kempli E x x None 
Deep Gulf Energy II, LLC Section 5 – Pg. 10 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

In addition, there are 28 species of marine mammals that may be found in the Gulf of 

Mexico. The table provided below identifies the seven (7) species of marine mammals 

that are listed as endangered or threatened. Currently, there are no designated critical 

habitats for the listed species in the Gulf of Mexico Outer Continental Shelf; however, it 

is possible that one or more of these species could be seen in the area during 

operations. 

Species Scientific Name Status Potential 

Presence 

Critical 

Habitat 

Designated in 

the Gulf of 

Mexico 

Lease 

Area 

Coastal 

Marine Mammals 

Sperm 

Whale 

Physeter 

macrocephalus 

E x -- None 

West Indian 

Manatee 

Trichechus manatus 

latirostris 

E -- x Florida 

Blue Whale Balaenoptera 

masculus 

E x -- None 

Fin Whale Balaenoptera 

physalus 

E x -- None 

Humpback 

Whale 

Megaptera 

novaeangliae 

E x -- None 

NorthAtlantic 

Right Whale 

Eubalaena glacialis E x -- None 

Sei Whale Balaenopiera borealis E x -- None 

There is one (1) species of fish that NOAA fisheries currently list as threatened (T) that 

may be found in the Gulf of Mexico. The Gulf sturgeon, also known as the Gulf of 

Mexico sturgeon, is an anadromous (breeding in freshwater after migrating up rivers 

from marine and estuarine environments) fish overwintering in estuaries, bays, and the 

Gulf of Mexico (see table below). 

Species Scientific Name Status Potential 

Presence 

Critical 

Habitat 

Designated 

in the Gulf of 

Mexico 

Lease 

Area Coastal 

Fish 
Deep Gulf Energy II, LLC Section 5 – Pg. 11 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

Gulf Sturgeon Acipenser 

oxyrinchus 

(=oxyrhynchus) 

desotoi 

T X X None 

5.9 ARCHAEOLOGICAL REPORT 

Mississippi Canyon Block 521 has been determined to have a high potential for 

containing archaeological properties. In accordance with NTL No. 2005-G07 

“Archaeological Surveys and Reports,” and NTL No. 2011-JOINT-G01, “Revisions to 

the List of OCS Lease Blocks Requiring Archaeological Resource Surveys and 

Reports”, an Archaeological Survey Report is provided with this plan. 

5.10 AIR AND WATER QUALITY INFORMATION 

Air and water quality information is not required to be included in this plan per NTL No. 

2008-G04, “Information requirements for Exploration Plans and Development 

Operations Coordination Documents” (Extended by NTL No. BOEM 2014-G03, 

“Extension of Prior Notices to Lessees”). 

5.11 SOCIOECONOMIC INFORMATION 

Socioeconomic Information is not required to be included in this plan per NTL No. 2008-

G04, “Information Requirements for Exploration Plans and Development Operations 

Coordination Documents.” 

Deep Gulf Energy II, LLC Section 6 – Pg. 12 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 6 

WASTES AND DISCHARGES INFORMATION 

6.1 PROJECTED GENERATED WASTES 

“Wastes You Will Generate, Treat and Downhole Dispose or Discharge to the Gulf of 

Mexico” is included as Attachment 6-A.

6.2 MODELING REPORT 

Modeling reports are not required for the activities proposed in this plan. 
ATTACHMENT 6‐A

Domestic waste Gray water (laundry, galley, 

lavatory) 12,000 bbl/well 5 bbl/hr/well Discharged overboard. Associated food waste will be processed using an approved grinder

Will humans be there? If yes, expect conventional waste

Drill Cuttings wetted with synthetic-based fluid Cuttings coated with synthetic 

based drilling mud 2459 bbl/well 137 bbl/day/well

Drill cuttings from the wellbore are processed using solids 

control equipment (shakers, cuttings dryer) which 

substantially reduces ROC percentage, and processed 

cuttings are discharged through shunt pipe to 25' below 

water's surface.

Will drilling occur? If yes, you should list muds and cuttings

Drill Cuttings wetted with water-based fluid Cuttings coated with water based 

drilling mud 1999 bbl/well 222 bbl/day/well Discharged at mudline prior to BOP & riser installation

Well treatment fluids KCL/HCL/NaCL/NaBr 2,000 bbls/well 10 bbl/min/well Oily water is treated in Oily Water Separator

Water-based Drilling Fluids Water based drilling fluid 35,000 bbl/well 7,778 bbl/day/well Discharged at mudline prior to BOP & riser installation

Waste you will generate, treat and downhole dispose or discharge to the GOM

Projected Generated Waste Projected Ocean Discharges

Type of Waste Composition Projected Amount Discharge Rate Discharge Method

Treated human body waste from 

toilets 12,000 bbl/well 5 bbl/hr/well USCG approved MSD

Will you conduct well treatment, completion or workover? If yes, only fill in those associated with your activity

Is there a deck? If yes, there will be Deck Drainage

Deck Drainage Platform washings and rainwater 163.2 bbl/well 0.1 bbl/hr/well Oily water is treated in Oily Water Separator

Sanitary waste

Blowout prevent fluid

Stackmagic 200/0/5% glycol 

based on 2% mixture with 

potable water

132 bbl/well 12 bbl/week with 

function test Discharged from BOP near mudline

Miscellaneous discharges? If yes, only fill in those associated with your activity

Desalinization unit discharge Rejected water from water 

maker unit 136,800 bbl/well 57 bbl/hr Cuttings chute

Bilge Water Bilge water 240 bbl/well 0.1 bbl/hr Discharged overboard

Ballast water Uncontaminated seawater used 

to maintain proper draft 21,000 bbl/well 9 bbl/hr Discharged overboard

Wash water Wash water, sink drainage, etc 12,000 bbl/well 5 bbl/hr Discharged overboard

Excess cement at seafloor Cement slurry 912 bbl/well 19 bbl/hr Discharged at the mudline during cementing conductor 

Cooling water Seawater with no addition of 4,000,800 bbl/well 1667 bbl/hr Discharged overboard

Firewater Seawater with no addition of 

chemicals

N/A N/A Discharged overboard

Will you be covered by an individual or general NPDES permit:

General - NPDES ID GMG290356

NOTE: IF YOU WILL NOT HAVE A TYPE OF WASTE, ENTER “NA” IN THE ROW.

Will you produce hydrocarbons? If yes, fill in for produced water

Produced water N/A N/A N/A N/A 
Deep Gulf Energy II, LLC Section 7 – Pg. 13 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 7 

AIR EMISSIONS INFORMATION 

7.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS 

 Screen Questions for EP’s Yes No 

Is any calculated Complex Total (CT) Emission amount (tons) associated 

with your proposed exploration activities more than 90% of the amounts 

calculated using the following formulas: CT = 3400D2/3 for CO, and CT = 

33.3D for the other air pollutants (where D = distance to shore in miles)? 

 X 

Do your emission calculations include any emission reduction measures or 

modified emission factors? 

 X 

Are your proposed exploration activities located east of 87.5° W longitude? X 

Do you expect to encounter H2S at concentrations greater than 20 parts 

per million (ppm)? 

 X 

Do you propose to flare or vent natural gas for more than 48 continuous 

hours from any proposed well? X 

Do you propose to burn produced hydrocarbon liquids? X 

7.2 SUMMARY INFORMATION 

There are no existing facilities or activities co-located with the currently proposed 

activities; therefore, the Complex Total Emissions are the same as the Plan Emissions. 

Air Emissions Worksheets which show the emission calculations for each of the 

proposed rig types, DP Semisubmersible Drilling Unit and DP Drillship, with related 

support vessel information are included as Attachment 7-A. 

This information was calculated by: Kelley Pisciola 

 (281) 698-8519 

 kelley.pisciola@jccteam.com
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Approv

COMPANY Deep Gulf Energy II, LLC

AREA Mississippi Canyon

BLOCK 521

LEASE OCS-G 34441PLATFORMWELL Locations A and D (Alternate Location)

COMPANY CONTACT Kelley PisciolaTELEPHONE NO. 281.698.8519REMARKS Drill and Complete with a DP Semi (AQR for DP Semi calculated using

Ensco 8500 Series Specific Horsepower.)

Form MMS-138 (August 2003)Page 1 of 8
EMISSIONS FACTORS

Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine RE

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 

Equipment/Emission Factors units PM SOx NOx VOC CO RENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 1NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 1Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-Tank Vapors lbs/bbl 0.03 E&P FFugitives lbs/hr/comp. 0.0005 API SGlycol Dehydrator Vent lbs/mmscf 6.6 La. DGas Venting lbs/scf 0.0034

Sulfur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight

Form MMS-138 (August 2003)Page 2 of 8
EMISSIONS CALCULATIONS 1ST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Deep Gulf Energy II, LLC Mississippi Canyon 521 OCS-G 34441 0 Locations A and D (Alternate Location) Kelley Pisciola 281.698.8519 

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR 

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

Burners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM 

DRILLING PRIME MOVER>600hp diesel 21739 1049.9937 25199.85 24 240 15.32 70.29 526.72 15.80 114.92 44.13 

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 68 1.46 6.68 50.03 1.50 10.92 0.40 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 68 3.10 14.23 106.61 3.20 23.26 1.05 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 

2015 YEAR TOTAL 19.88 91.20 683.36 20.50 149.10 45.58 

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2164.50 

65.0

Form MMS-138 (August 2003)Page 3 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELL

Deep Gulf EnergMississippi Canyon 521 OCS-G 34441 0 Locations A and D 

Emitted Substance

Year

 PM SOx NOx VOC CO

2015 45.58 209.10 1566.80 47.00 341.85

Allowable 2164.50 2164.50 2164.50 2164.50 54965.20

Form MMS-138 (August 2003)Page 8 of 8
Rig 1/1/2013

Fuel On Board, Bbl

7/1/2013

Fuel On Board, Bbl Fuel Taken On, Bbl Total Fuel Used, Bbl

Daily Ave. Fuel, 

Bbl

8500 6580.0 10836.0 50858.0 46602.0 257.47

8501 6870.0 9284.0 48936.0 46522.0 257.03

8503 11812.0 9295.0 39202.0 41719.0 230.49

8505 10618.0 10205.0 43477.0 43890.0 242.49

246.87 bbl/day

12.95 1 Std. deviation

8500, 8501, 8503, 8505 reported fuel-on-board at beginning (01 Jan. 2013) and ending (01 July 2013) dates, also all fuel taken onbaord that period

8502.0 36582.0 202.11

8506.0 40791.0 225.36

213.74 (bbl/day)

16.44 1 Std. deviation

8502 and 8506 reported total fuel consumption for the period 01 Jan. - 01 July 2013

Rig Total Fuel Used, Bbl Daily Ave. Fuel, Bbl

6 x 8500 

Series Rigs 256106.0 235.83 bbl/day

21.15 1 Std. Deviation

63.5 3 std. deviation

299.28 bbls/day, Mean + 3 std. 

deviations (99.73%)

0.0483 gal/hp-hr (diesel recip. 

Factor, AQE)

10843.47 HP

21686.94 HP x 2

21739.00 HP used in AQE 

reporting

600.00 bbl/day used in AQE 

reporting

257.47

257.03

230.49

242.49

202.11

225.36

Daily Fuel Consumption 8500 series January 1, 2013 to July 1, 2013 (181 days)
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Approv

COMPANY Deep Gulf Energy II, LLC

AREA Mississippi Canyon

BLOCK 521

LEASE OCS-G 34441PLATFORMWELL Locations A and D (Alternate Location)

COMPANY CONTACT Kelley PisciolaTELEPHONE NO. 281.698.8519REMARKS Drill and Complete with a DP Drillship

Form MMS-138 (August 2003)Page 1 of 8
EMISSIONS FACTORS

Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine RE

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 

Equipment/Emission Factors units PM SOx NOx VOC CO RENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 1NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 1Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-Tank Vapors lbs/bbl 0.03 E&P FFugitives lbs/hr/comp. 0.0005 API SGlycol Dehydrator Vent lbs/mmscf 6.6 La. DGas Venting lbs/scf 0.0034

Sulfur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight

Form MMS-138 (August 2003)Page 2 of 8
EMISSIONS CALCULATIONS 1ST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Deep Gulf Energy II, LLC Mississippi Canyon 521 OCS-G 34441 0 Locations A and D (Alternate Location) Kelley Pisciola 281.698.8519 

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR 

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

Burners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM 

DRILLING PRIME MOVER>600hp diesel 29566 1428.0378 34272.91 24 240 20.84 95.60 716.36 21.49 156.30 60.02 

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 68 1.46 6.68 50.03 1.50 10.92 0.40 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 68 3.10 14.23 106.61 3.20 23.26 1.05 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 

2015 YEAR TOTAL 25.40 116.51 873.00 26.19 190.47 61.47 

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2164.50 

65.0

Form MMS-138 (August 2003)Page 3 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELL

Deep Gulf EnergMississippi Canyon 521 OCS-G 34441 0 Locations A and D 

Emitted Substance

Year

 PM SOx NOx VOC CO

2015 61.47 281.98 2112.96 63.39 461.01

Allowable 2164.50 2164.50 2164.50 2164.50 54965.20

Form MMS-138 (August 2003)Page 8 of 8
Deep Gulf Energy II, LLC Section 8 – Pg. 14 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 8 

OIL SPILL INFORMATION 

8.1 OIL SPILL RESPONSE PLANNING 

All the proposed activities and facilities in this EP will be covered by the Regional Oil 

Spill Response Plan (OSRP) filed by Deep Gulf Energy LP (BOEM Operator Number 

02815) which includes Deep Gulf Energy II, LLC (BOEM Operator Number 02985) 

dated May, 2013 and last approved on June 24, 2014 (OSRP Control Number O-578). 

8.2 SPILL RESPONSE SITES 

Primary Response Equipment 

Location 

Preplanned Staging Location 

Houma, LA Houma, LA 

Harvey, LA Harvey, LA 

Venice, LA Venice, LA 

8.3 OSRO INFORMATION 

DGE II’s primary equipment provider is Clean Gulf Associates (CGA). Clean Gulf 

Associates Services, LLC (CGAS) will provide closest available personnel, as well as a 

CGAS supervisor to operate the equipment. 

8.4 WORST CASE SCENARIO DETERMINATION 

Category Regional OSRP 

WCD - Drilling 

EP 

WCD - Drilling 

Type of Activity Drilling Drilling 

Facility Location 

(Area/Block) MC 521 MC 521 

Facility Designation A A 

Distance to Nearest 

Shoreline (miles) 65 65 

Volume 

 Storage Tanks 

(Total) 

 Uncontrolled 

blowout 

Total Volume 155,762 155,762 
Deep Gulf Energy II, LLC Section 8 – Pg. 15 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

Type of Oil(s) 

(crude, condensate, 

diesel) 

Oil Oil 

API Gravity 29° 29° 

The WCD calculations and assumptions for the regional OSRP WCD, MC521 Well No. 

001 (155,762) were previously reviewed and accepted under Plan control No. N-9824. 

DGE II has determined that the worst-case scenario from the activities proposed in this 

EP does supersede the worst-case scenario from our approved Regional OSRP. DGE II 

will submit the new worst-case scenario to the BSEE GOMR for inclusion in our 

Regional OSRP on or before September 12, 2014. 

8.5 OIL SPILL RESPONSE DISCUSSION 

The Oil Spill Response Discussion is included as Attachment 8-A. 

 
SPILL RESPONSE DISCUSSION 

For the purpose of NEPA and Coastal Zone Management Act analysis, the largest spill volume 

originating from the proposed activity would be a well blowout during drilling operations, 

estimated to be 155,762 barrels of crude oil with an API gravity of 29°. 

Land Segment and Resource Identification 

Trajectories of a spill and the probability of it impacting a land segment have been projected 

utilizing information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and 

Western Gulf of Mexico available on the BOEM website. The results are shown in Figure 1.

The BOEM OSRAM identifies a 21% probability of impact to the shorelines of Plaquemines 

Parish, Louisiana within 30 days. Plaquemines Parish includes Barataria Bay, the Mississippi 

River Delta, Breton Sound and the affiliated islands and bays. This region is an extremely 

sensitive habitat and serves as a migratory, breeding, feeding and nursery habitat for numerous 

species of wildlife. Beaches in this area vary in grain particle size and can be classified as fine 

sand, shell or perched shell beaches. Sandy and muddy tidal flats are also abundant. 

Response 

DGE II will make every effort to respond to the Worst Case Discharge as effectively as 

practicable. A description of the response equipment under contract to contain and recover the 

Worst Case Discharge is shown in Figure 2.

Using the estimated chemical and physical characteristics of crude oil, an ADIOS weathering 

model was run on a similar product from the ADIOS oil database. The results indicate 11% or 

approximately 17,134 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 138,628 barrels remaining. 

Spill Response MC 521, Well Location A Barrels of Oil 

WCD Volume 155,762 

Less 20% natural evaporation/dispersion 17,134 

Remaining volume 138,628 

Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary 

storage equipment available to respond to the worst case discharge. The volume accounts for the 

amount remaining after evaporation/dispersion at 24 hours. The list estimates individual times 

needed for procurement, load out, travel time to the site and deployment. Figure 2 also indicates 

how operations will be supported. 

DGE II’s Oil Spill Response Plan includes alternative response technologies such as dispersants 

and in-situ burn. Strategies will be decided by Unified Command based on the size of the spill, 

weather and potential impacts. If aerial dispersants are utilized, 8 sorties (9,600 gallons) from 

two of the DC-3 aircrafts and 4 sorties (8,000 gallons) from the Basler aircraft would provide a 
daily dispersant capability of 7,540 barrels. If the conditions are favorable for in-situ burning, the 

proper approvals have been obtained and the proper planning is in place, in-situ burning of oil 

may be attempted. Slick containment boom would be immediately called out and on-scene as 

soon as possible. Offshore response strategies may include attempting to skim utilizing CGA’s 

spill response equipment, with a total derated skimming capacity of 258,477 barrels. Temporary 

storage associated with skimming equipment equals 22,198 barrels. If additional storage is 

needed, a 107,285 barrel storage barge, a 47,000 barrel storage barge, a 25,000 barrel storage 

barge, and three 23,000 barrel storage barges may be mobilized and centrally located to provide 

temporary storage allowing the skimmers to stay in the area of operations as much as possible. 

Safety is first priority. Air monitoring will be accomplished and operations deemed safe 

prior to any containment/skimming attempts. 

If the spill went unabated, shoreline impact in Plaquemines Parish, Louisiana would depend 

upon existing environmental conditions. Shoreline protection would include the use of CGA’s 

near shore and shallow water skimmers with a totaled derated skimming capacity of 45,264 

barrels. Temporary storage associated with skimming equipment equals 567 barrels. If additional 

storage is needed, three 20,000 barrel storage barges may be mobilized and centrally located to 

provide temporary storage allowing the skimmers to stay in the area of operations as much as 

possible. Onshore response may include the deployment of shoreline boom on beach areas, or 

protection and sorbent boom on vegetated areas. Letters of Intent from AMPOL and OMI 

Environmental will ensure access to 147,000 feet of 18” shoreline protection boom. Figure 2

outlines individual times needed for procurement, load out, travel time to the site and 

deployment. Strategies would be based upon surveillance and real time trajectories that depict 

areas of potential impact given actual sea and weather conditions. The State of Louisiana Initial 

Oil Spill Response Plan for Plaquemines Parish and Unified Command would be consulted to 

ensure that environmental and special economic resources would be correctly identified and 

prioritized to ensure optimal protection. Shoreline protection strategies depict the protection 

response modes applicable for oil spill clean-up operations. The State of Louisiana Initial Oil 

Spill Response Plan provides detailed shoreline protection strategies for this area, and it 

describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands, based 

on the assumption that removal of the released oil will be much easier and less damaging to 

fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. Supervisory 

personnel have the option to modify the deployment and operation of equipment allowing a more 

effective response to site-specific circumstances. DGE II’s contract Spill Management Team 

holds a copy of the State of Louisiana Initial Oil Spill Response Plan. 

Based on the anticipated worst case discharge scenario, DGE II can be onsite with contracted oil 

spill recovery equipment with adequate response capacity to contain and recover surface 

hydrocarbons, and prevent land impact, to the maximum extent practicable, within an estimated 

78 hours (based on the equipment’s Effective Daily Recovery Capacity (EDRC)). 
Initial Response Considerations 

Actual actions taken during an oil spill response will be based on many factors which include but 

are not limited to: 

 Weather 

 Equipment and materials availability 

 Ocean currents and tides 

 Location of the spill 

 Product spilled 

 Amount spilled 

 Environmental risk assessments 

 Trajectory and product analysis 

 Well status, i.e., shut in or continual release 

DGE II will take action to provide a safe, aggressive response to contain and recover as much of 

the spilled oil as quickly as it is safe to do so. In an effort to protect the environment, response 

actions will be designed to provide an “in-depth” protection strategy meant to recover as much 

oil as possible as far from environmentally sensitive areas as possible. Safety will take 

precedence over all other considerations during these operations. 

Coordination of response assets will be supervised by the designation of a SIMOPS group as 

necessary for close quarter vessel response activities. Most often, this group will be used during 

source control events that require a significant number of large vessels operating independently, 

but in coordination to complete a common objective, in a small area and in close coordination 

and support of each other. This group must also monitor the subsurface activities of each vessel 

(ROV, dispersant application, well control support, etc.). The SIMOPS group leader reports to 

the Source Control Section Chief. 

In addition, these activities will be monitored by the spill management team (SMT) and Unified 

Command via a structured Common Operating Picture (COP) established to track resource and 

slick movement in real time. 

Upon notification of a spill, the following actions will be taken: 

 Information will be confirmed 

 An assessment will be made and initial objectives set 

 OSROs and appropriate agencies will be notified 

 ICS 201, Initial Report Form will be completed 

 Initial Safety plan will be written and published 

 Unified Command will be established 

o Overall safety plan developed to reflect the operational situation and coordinated 

objectives 

o Areas of responsibility established for Source Control and each surface operational 

site 

o On-site command and control established 
Decanting Strategy 

Recovered oil and water mixtures will typically separate into distinct phases when left in a 

quiescent state. When separation occurs, the relatively clean water phase can be siphoned or 

decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases 

the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval 

will be requested prior to decanting operations. This practice is routinely used for oil spill 

recovery. 

Offshore Response Actions 

Equipment Deployment

Surveillance 

 Surveillance Aircraft will be deployed within two hours of Qualified Individual (QI) 

notification, or at first light

 Provide trained observer to provide on site status reports 

 Provide command and control platform at the site if needed 

 Continual surveillance of oil movement by remote sensing systems, aerial photography 

and visual confirmation 

 Continual monitoring of vessel assets using vessel monitoring systems 

Dispersant application assets 

 Put Airborne Support Inc. (ASI) on standby 

 With the Federal On-Scene Coordinator (FOSC), conduct analysis to determine 

appropriateness of dispersant application 

 Gain FOSC approval for use of dispersants on the surface 

 Deploy aircraft in accordance with a plan developed for the actual situation 

 Coordinate movement of dispersants, aircraft, and support equipment and personnel 

 Confirm dispersant availability for current and long range operations 

 Start ordering dispersant stocks required for expected operations 

Containment boom 

 Call out early and expedite deployment to be on scene ASAP 

 Ensure boom handling and mooring equipment is deployed with boom 

 Provide continuing reports to vessels to expedite their arrival at sites that will provide for 

their most effective containment 

 Use Vessels of Opportunity (VOO) to deploy and maintain boom 

Dedicated off-shore skimming systems 

General 

 Deployed to the highest concentration of oil 

 Assets deployed at safe distance from aerial dispersant and in-situ burn operations 
CGA HOSS Barge 

 Use in areas with heaviest oil concentrations 

 Consider for use in areas of known debris (seaweed, and other floating materials) 

CGA FRUs 

 To the area of the thickest oil 

 Use as far off-shore as allowed 

 VOOs 140’ – 180’ in length 

 VOOs with minimum of 18’ x 38’ or 23’ x 50’ of optimum deck space 

 VOOs in shallow water should have a draft of <10 feet when fully loaded 

T&T Koseq Skimming Systems 

 To the area of the thickest oil 

 Use as far off-shore as allowed 

 VOOs with a minimum of 2,000 bbls storage capacity 

 VOOs at least 200’ in length 

 VOOs with deck space of 100’ x 40’ to provide space for arms, tanks, and crane 

 VOOs for shallow water should be deck barges with a draft of <10 feet when fully loaded 

Storage Vessels 

 Establish availability of CGA contracted assets 

 Early call out (to allow for tug boat acquisition and deployment speeds) 

 Phase mobilization to allow storage vessels to arrive at the same time as skimming 

systems 

 Position as closely as possible to skimming assets to minimize offloading time 

Vessels of Opportunity (VOO) 

 Use DGE II’s contracted resources as applicable 

 Industry vessels are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS) 

 Acquire additional resources as needed 

 Consider use of local assets, i.e. fishing and pleasure craft 

 Expect mission specific and safety training to be required 

 Plan with the US Coast Guard for vessel inspections 
In-situ Burn assets 

 Determine appropriateness of in-situ burn operation in coordination with the FOSC and 

affected State On-Scene Coordinator (SOSC) 

 Determine availability of fire boom and selected ignition systems 

 Start ordering fire boom stocks required for expected operations 

 Contact boom manufacturer to provide training if required 

 Determine assets to perform on water operation 

 Build operations into safety plan 

 Conduct operations in accordance with an approved plan 

Adverse Weather Operations: 

In adverse weather, when seas are > 3 feet, the use of larger recovery and storage vessels, 

oleophilic skimmers, and large offshore boom will be maximized. Safety will be the overriding 

factor in all operations and will cease at the order of the Unified Command, vessel captain, or in 

an emergency, ”stop work” may be directed by any crew member. 
Near Shore Response Actions 

Timing 

 Place near shore assets on standby and deploy in accordance with planning based on the 

actual situation, actual trajectories and oil budgets 

 VOO identification and training in advance of spill nearing shoreline if possible 

 Outfitting of VOOs for specific missions 

 Deployment of assets based on actual movement of oil 

Considerations 

 Water depth, vessel draft 

 Shoreline gradient 

 State of the oil 

 Use of VOOs 

 Distance of surf zone from shoreline 

Equipment Deployment 

Surveillance 

 Provide trained observer to direct skimming operations 

 Continual surveillance of oil movement by remote sensing systems, aerial photography 

and visual confirmation 

 Continual monitoring of vessel assets 

Dispersant Use 

 Generally will not be approved within 3 miles of shore or with less than 10 meters of 

water depth 

 Approval would be at Regional Response Team level (Region 6) 

Vessel Deployment 

Dedicated Near Shore skimming systems 

 Fast Response Vessels (FRV) 

 Egmopol and Marco Shallow Water Skimmer (SWS) 

 Operate with aerial spotter directing systems to observed oil slicks 

VOO 

 Use DGE II’s contracted resources as applicable 

 Industry vessels are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS) 

 Acquire additional resources as needed 

 Consider use of local assets, i.e. fishing and pleasure craft 

 Expect mission specific and safety training to be required 

 Plan with the US Coast Guard for vessel inspections 

 Operate with aerial spotter directing systems to oil patches 
Shoreline Protection Operations 

Response Planning Considerations 

 Environmental risk assessments (ERA) to determine priorities for area protection 

 Time to acquire personnel and equipment and their availability 

 Previous contingency planning contained in the appropriate Area Contingency Plan, and 

currently for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep 

Water Horizon, dated 2 May 2010 

Actions 

Placement of boom 

 Position boom in accordance with the ERA based on the actual situation or the 

appropriate ACP 

 Assess timing of booming operations to ensure it is where it needs to be at time of 

impact. Consider: 

o Trajectories 

o Weather forecast 

o Oil Impact forecast 

o Verified spill movement 

o Boom, manpower and vessel (shallow draft) availability 

o Near shore boom and support material, (stakes, anchors, line) 

Beach Preparation 

Considerations and Actions 

 Use of a 10 mile go/no go line to determine timing of beach cleaning 

 Shoreline Cleanup and Assessment Team Reports and recommendations 

 Determination of Archeological sites and gaining authority to enter 

 Monitoring of tide tables and weather to determine extent of high tides 

 Pre cleaning of beaches by moving waste above high tide lines to minimize waste 

 Staging of equipment and housing of response personnel as close to the job site as 

possible to maximize on-site work time 

 Boom tending, repair, replacement and security (use of local assets may be advantageous) 

 Constant awareness of weather and oil movement for resource redeployment as necessary 

 In-situ burn may be considered when marshes have been impacted 

 Passive clean up of marshes should be considered and appropriate stocks of sorbent boom 

and/or sweep obtained 

 Earthen berms and shoreline protection boom may be considered to protect sensitive 

inland areas 
Decanting Strategy 

Recovered oil and water mixtures will typically separate into distinct phases when left in a 

quiescent state. When separation occurs, the relatively clean water phase can be siphoned or 

decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases 

the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval 

will be requested prior to decanting operations. This practice is routinely used for oil spill 

recovery. 

CGA Equipment Limitations 

The capability for any spill response equipment, whether a dedicated or portable system, to 

operate in differing weather conditions will be directly in relation to the capabilities of the vessel 

the system in placed on. Most importantly, however, the decision to operate will be based on the 

judgment of the Unified Command and/or the Captain of the vessel, who will ultimately have the 

final say in terminating operations. Skimming equipment listed below may have operational 

limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil 

spill response, vessel skimming operations ceased when seas reached 5-6 feet and vessels were 

often recalled to port when those conditions were exceeded. Systems below are some of the 

most up-to-date systems available and were employed during the DWH spill. 

Boom 3 foot seas, 20 knot winds 

Dispersants Winds more than 25 knots 

Visibility less than 3 nautical miles 

Ceiling less than 1,000 feet. 

FRU 8 foot seas 

HOSS Barge/OSRB 8 foot seas 

Koseq Arms 8 foot seas 

OSRV 4 foot seas 
Environmental Conditions in the GOM

Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences 

westerly winds during the winter and easterly winds in the summer. Average wind speed is 

generally 14-15 mph along the coast. Wave heights average 4 and 5 feet. However, during 

hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and 

winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, 

flooding is prominent. 

Surface water temperature ranges between 70 and 80 ̊F during the summer months. During the 

winter, the average temperature will range from 50 and 60 ̊F. 

The Atlantic and Gulf of Mexico hurricane season is officially from 1 June to 30 November. 

97% of all tropical activity occurs within this window. The Atlantic basin shows a very peaked 

season from August through October, with 78% of the tropical storm days, 87% of the minor 

(Saffir-Simpson Scale categories 1 and 2) hurricane days, and 96% of the major (Saffir-Simpson 

categories 3, 4 and 5) hurricane days occurring then. Maximum activity is in early to mid 

September. Once in a few years there may be a hurricane occurring "out of season" - primarily in 

May or December. Globally, September is the most active month and May is the least active 

month. 
FIGURE 1 

TRAJECTORY BY LAND SEGMENT 

Trajectory of a spill and the probability of it impacting a land segment have been projected 

utilizing DGE II’s WCD and information in the BOEM Oil Spill Risk Analysis Model 

(OSRAM) for the Central and Western Gulf of Mexico available on the BOEM website 

using 30 day impact. The results are tabulated below. 

Area/Block OCS-G Launch 

Area 

Land Segment and/or 

Resource 

Conditional 

Probability (%) 

within 30 days 

Drill and Complete 

Well Location B 

MC 521, 

Well Location A 

65 miles from shore 

G34441 C57 Cameron, LA 

Vermilion, LA 

Terrebonne, LA 

Lafourche, LA 

Plaquemines, LA 

St. Bernard, LA 

Hancock & Harrison, MS 

Jackson, MS 

Mobile, AL 

Baldwin, AL 

Escambia, AL 

Okaloosa, FL 

Walton, FL 

Bay, FL 

1 

1 

2 

2 

21 

3 

1 

1 

1 

1 

1 

1 

1 

1 
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (65 miles from sh

138,628 bbls of crude oil (Volume considering natural weathering) API Gravity 29° 

FIGURE 2 – Equipment Response Time to MC 521, Well Location A 

Dispersants/Surveillance

Dispersant/Surveillance Dispersant Capacity (gal) Storage Capacity Persons Req. From Hrs to Procure Hrs to Loadout Trav

si

ASI 

Basler 67T 2000 NA 2 Houma 2 2 0DC 3 1200 NA 2 Houma 2 2 1DC 3 1200 NA 2 Houma 2 2 1Aero Commander NA NA 2 Houma 2 2 0

Offshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

CGA 

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 95’ FRV 12342 249 NA 4 Leeville 2 0 2 95’ FRV 12342 249 NA 4 Venice 2 0 1 Boom Barge (CGA-300) 42” Auto Boom (25000’) NA NA 1 Tug 50 Crew 4 (Barge) 2 (Per Crew) Leeville 4 0 6 

Recovered Oil Storage No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

K-Sea Operating (available through contract with CGA) 

DBL 101 1119760 NA 107285 1 Tug 6 Venice 4 12 4 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 
Staging Area: Venice

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging 

CGA 

FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 2 2 12.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 2 2 2.1 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 17.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 2 8 FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 2 2 4.4 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 2 4.9 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 2 2 0 Hydro-Fire Boom NA NA 8 Utility 40 Harvey 2 4 2.1 

T&T Marine (available through contract with CGA) 

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 12.7 Koseq Skimming Arms (4) 71316 8000 4 Utility 24 Galliano 24 24 4.25 Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey 24 24 2.1 
Nearshore Response

Nearshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

CGA 

46’ FRV 5000 65 NA 4 Morgan City 2 0 2 46’ FRV 5000 65 NA 4 Venice 2 0 1 Trinity SWS 21500 249 NA 4 Venice 2 2 2 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 

Staging Area: Venice

Nearshore and Inland 

Skimmers With Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Trav

Deplo

CGA 

SWS Egmopol 3000 100 NA 3 Morgan City 2 2 4.9 SWS Marco 3588 20 NA 3 Lake Charles 2 2 8 SWS Marco 3588 34 NA 3 Leeville 2 2 4.4 SWS Marco 3588 34 NA 3 Venice 2 2 0 
Shoreline Protection 

Staging Area: Venice 

Shoreline Protection 

Boom VOO Persons Req. Storage/Warehouse Location Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Site 

AMPOL (available through MSA) 

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 6 2 20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2.2 2 

OMI Environmental (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 6 2 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 12.1 2 10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 9.7 2 20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.9 2 10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 4.5 2 10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.8 2 15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.1 2 

Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Trav

Deplo

CGA 

Wildlife Support Trailer NA NA NA 2 Harvey 2 2 2.1 Bird Scare Guns (48) NA NA NA 2 Harvey 2 2 2.1 Bird Scare Guns (12) NA NA NA 2 Galveston 2 2 12.7 Bird Scare Guns (12) NA NA NA 2 Aransas Pass 2 2 17.7 Bird Scare Guns (24) NA NA NA 2 Lake Charles 2 2 8 Bird Scare Guns (24) NA NA NA 2 Leeville 2 2 4.4 

Response Asset Total 

Offshore EDRC 258,477 

Offshore Recovered Oil Storage 270,483 

Nearshore / Shallow Water EDRC 45,264 

Nearshore / Shallow Water Recovered Oil Storage 60,567 
Deep Gulf Energy II, LLC Section 9 – Pg. 16 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 9 

ENVIRONMENTAL MONITORING INFORMATION 

9.1 MONITORING SYSTEMS 

DGE II subscribes to Wilkens Weather Service which provides access to real time 

weather conditions and provides periodic updates on impending weather conditions 

such as tropical depressions, storms, and/or hurricanes entering the Gulf of Mexico. 

DGE II also relies on the National Weather Service to support the aforementioned 

subscribed service. During impending inclement weather conditions, DGE II closely 

coordinates the activity with our contractors and field personnel to ensure the safety of 

people for evacuation to ensure protection of the environment and the 

facility/equipment. 

DGE II will monitor loop currents per the requirements as set forth in NTL 2009-G02, 

“Ocean Current Monitoring.” 

9.2 INCIDENTAL TAKES 

There is no reason to believe that any of the endangered species or marine mammals 

as listed in the ESA will be “taken as a result of the operations proposed under this plan. 

It has been documented that the use of explosives and or seismic devices can affect 

marine life. Operations proposed in this plan will not be utilizing either of these devices. 

DGE II will adhere to the requirements as set forth in the following documents, as 

applicable, to avoid or minimize impacts to any of the species listed in the Endangered 

Species Act (ESA) as a result of the operations conducted herein: 

 NTL No. 2012-BSEE-G01, “Marine Trash and Debris Awareness and 

Elimination” 

 NTL No. 2012-JOINT-G01, “Vessel Strike Avoidance and Injured/Dead Protected 

Species Reporting” 

 NTL No. 2012-JOINT-G02, “Implementation of Seismic Survey Mitigation 

Measures and Protected Species Observer Program” 

9.3 FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY 

Mississippi Canyon Block 521 is not located in the Flower Garden Banks National 

Marine Sanctuary; therefore, relevant information is not required in this EP. 
Deep Gulf Energy II, LLC Section 10 – Pg. 17 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 10 

LEASE STIPULATIONS INFORMATION 

Exploration activities are subject to the following stipulations attached to Lease OCS-G 

34441, Mississippi Canyon Block 521. 

10.1 MARINE PROTECTED SPECIES 

In accordance with the Federal Endangered Species Act and the Marine Mammal 

Protection Act, DGE II will: 

(a) collect and remove flotsam resulting from activities related to exploration, 

development, and production of this lease; 

(b) post signs in prominent places on all vessels and platforms used as a result of 

activities related to exploration, development, and production of this lease detailing the 

reasons (legal and ecological) why release of debris must be eliminated; 

(c) observe for marine mammals and sea turtles while on vessels, reduce vessel speed 

to 10 knots or less when assemblages of cetaceans are observed, and maintain a 

distance of 90 meters or greater from whales, and a distance of 45 meters or greater 

from small cetaceans and sea turtles; 

(d) employ mitigation measures prescribed by BOEM/BSEE or the National Marine 

Fisheries Service (NMFS) for all seismic surveys, including the use of an “exclusion 

zone” based upon the appropriate water depth, ramp-up and shutdown procedures, 

visual monitoring, and reporting; 

(e) identify important habitats, including designated critical habitat, used by listed 

species (e.g., sea turtle nesting beaches, piping plover critical habitat), in oil spill 

contingency planning and require the strategic placement of spill cleanup equipment to 

be used only by personnel trained in less-intrusive cleanup techniques on beaches and 

bay shores; and 

(f) immediately report all sightings and locations of injured or dead protected species 

(e.g., marine mammals and sea turtles) to the appropriate stranding network. If oil and 

gas industry activity is responsible for the injured or dead animal (e.g., because of a 

vessel strike), the responsible parties should remain available to assist the stranding 
Deep Gulf Energy II, LLC Section 10 – Pg. 18 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

network. If the injury or death was caused by a collision with the lessee’s vessel, the 

lessee must notify BOEM within 24 hours of the strike. 

BOEM and BSEE issue Notices to Lessees (NTLs), which more fully describe measures 

implemented in support of the above-mentioned implementing statutes and regulations, 

as well as measures identified by the U.S. Fish and Wildlife Service and NMFS arising 

from, among others, conservation recommendations, rulemakings pursuant to the 

MMPA, or consultation. The lessee and its operators, personnel, and subcontractors, 

while undertaking activities authorized under this lease, must implement and comply 

with the specific mitigation measures outlined in NTL No. 2012-JOINT-G01, “Vessel 

Strike Avoidance and Injured/Dead Protected Species Reporting;” NTL No. 2012-

JOINT-G02, “Implementation of Seismic Survey Mitigation Measures and Protected 

Species Observer Program;” and NTL No. 2012-BSEE-G01, “Marine Trash and Debris 

Awareness and Elimination.” At the lessee’s option, the lessee, its operators, 

personnel, and contractors may comply with the most current measures to protect 

species in place at the time an activity is undertaken under this lease, including but not 

limited to new or updated versions of the NTLs identified in this paragraph. The lessee 

and its operators, personnel, and subcontractors will be required to comply with the 

mitigation measures, identified in the above referenced NTLs, and additional measures 

in the conditions of approvals for their plans or permits. 
Deep Gulf Energy II, LLC Section 11 – Pg. 19 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 11 

ENVIRONMENTAL MITIGATION MEASURES INFORMATION 

11.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS 

Mississippi Canyon Block 521 is not located within Florida; therefore, mitigation 

information is not required for the activities proposed in this plan. 

11.2 INCIDENTAL TAKES 

DGE II will adhere to the requirements as set forth in the following documents, as 

applicable, to avoid or minimize impacts to any of the species listed in the Endangered 

Species Act (ESA) as a result of the operations conducted herein: 

 NTL No. 2012-BSEE-G01, “Marine Trash and Debris Awareness and 

Elimination” 

 NTL No. 2012-JOINT-G01, “Vessel Strike Avoidance and Injured/Dead Protected 

Species Reporting” 

 NTL No. 2012-JOINT-G02, “Implementation of Seismic Survey Mitigation 

Measures and Protected Species Observer Program” 
Deep Gulf Energy II, LLC Section 12 – Pg. 20 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 12 

SUPPORT VESSELS AND AIRCRAFT INFORMATION 

12.1 GENERAL 

The most practical, direct route from the shore base as permitted by weather and traffic 

conditions will be utilized. 

Type Maximum Fuel Tank 

Capacity 

Maximum 

Number in Area 

at Any Time 

Trip 

Frequency 

or Duration 

Crew Boat 1500 bbls 2 2 per week 

Supply Boat 1500 bbls 2 2 per week 

Helicopter 600 gals 1 6 per week 

12.2 DIESEL OIL SUPPLY VESSELS 

Size of Fuel 

Supply Vessel 

Capacity of Fuel 

Supply Vessel 

Frequency of Fuel 

Transfers 

Route Fuel Supply 

Vessel Will Take 

240’ 2500 bbls 1 per week Direct to Fourchon 

12.3 DRILLING FLUID TRANSPORTATION 

Drilling fluid transportation information is not required to be submitted with this plan. 

12.4 SOLID AND LIQUID WASTE TRANSPORTATION 

A table, “Wastes You Will Transport and/or Dispose of Onshore,” is included as 

Attachment 12-A. 

12.5 VICINITY MAP 

A vicinity map showing the location of the activities proposed herein relative to the 

shoreline with the distance of the proposed activities from the shoreline and the primary 

route(s) of the support vessels and aircraft that will be used when traveling between the 

onshore support facilities and the drilling unit is included as Attachment 12-B.
please specify whether the amount reported is a total or per well

Solid and Liquid Wastes 

transportation 

Type of Waste Composition Transport Method

Name/Location of Facility Amount 

Will drilling occur ? If yes, fill in the muds and cuttings.

Oil-based drilling fluid or mud N/A N/A N/A N/A 

Synthetic-based drilling fluid or mud internal olefin Below-deck storage tanks on offshore support vessels M-I Swaco, Port Fourchon, LA 20,000 bbls/we

Cuttings wetted with Synthetic-based fluid Cuttings generated using synthetic based fluid Below-deck storage tanks on offshore support vessels Newport Environmental Services Inc., Ingleside, TX 1,000 bbls/wel

Cuttings wetted with oil-based fluids N/A N/A N/A N/A 

Will you produce hydrocarbons? If yes fill in for produced sand.

Produced sand N/A N/A N/A N/A Well Completion Fluids NaCL/NaBr Below-deck storage tanks on offshore support vessels Newport Environmental Services, Inc., Ingleside, TX 6,000 bbls/wel

Workover Fluids NaCL/NaBr Below-deck storage tanks on offshore support vessels Newport Environmental Services, Inc., Ingleside, TX 6,000 bbls/welTrash and debris Non-hazardous trash & debris (non recyclables) Transport in DOT containers on supply vessels to shorebase Progressive Waste Solutions of LA, Houma, LA 700 lbs/well 

Used oil Used oil and glycol Transport in DOT containers on supply vessels to shorebase Safety Kleen System, Baton Rouge, LA 420 gal/well (10 bbls/well) Chemical product wastes Paints, solvents, unused chemicals, etc Transport in DOT containers on supply vessels to shorebase Safety Kleen System, Baton Rouge, LA 130 lbs/well 

NOTE: If you will not have a type of waste, enter NA in the row.

TABLE 12-A WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHORE 

Waste Di

Will you have additional wastes that are not permitted for discharge? If yes, fill in the appropriate rows. 

Projected generated waste
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South Marsh Island 

North

Lun

Garden Banks Green Canyon Atwater 

Mississippi 

Keathley Canyon Walker Ridge

High Island

Vermilion

East Breaks

Ship Shoal

West Cameron

Main 

South Timbalier

West Delta

Ewing Bank

Baton Rouge

Lafayette

Beaumont

Lake Charles

Gulfport

Port Arthur

49 59

10

55

11

De Soto NF

Angelina NF

Sabine NF

Homochitto NF

Kisatchie NF

Big Thicket NPRES

Deep Gulf Energy II. LLC 

~131.9 Miles to Fourchon, LA Sh

65 

~357 Miles to Texas
Deep Gulf Energy II, LLC Section 13 – Pg. 21 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 13 

ONSHORE SUPPORT FACILITIES INFORMATION 

13.1 GENERAL 

Name Location Existing/New/Modified 

Fourchon C-Port Port Fourchon, Louisiana Existing 

13.2 SUPPORT BASE CONSTRUCTION OR EXPANSION 

There will be no new construction of an onshore support base, nor will we expand the 

existing shore base as a result of the operations proposed in this EP. 

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE 

A support base construction or expansion timetable is not required for the activities 

proposed in this plan. 

13.4 WASTE DISPOSAL 

The Table, “Wastes You Will Transport and/or Dispose of Onshore, “is included as

Attachment 12-A. 
Deep Gulf Energy II, LLC Section 15 – Pg. 22 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 14 

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION 

Relevant enforceable policies were considered in certifying consistency for Louisiana. 

A certificate of Coastal Zone Management Consistency for the state of Louisiana is 

included as Attachment 14-A. 

Relevant enforceable policies were considered in certifying consistency for Texas. A 

certificate of Coastal Zone Management Consistency for the state of Texas is included 

as Attachment 14-B. 

Relevant enforceable policies were considered in certifying consistency for Alabama. A 

certificate of Coastal Zone Management Consistency for the state of Alabama is 

included as Attachment 14-C.

 

Deep Gulf Energy II, LLC Section 15 – Pg. 23 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

As authorized by the Federal Coastal Zone Management Act (CZMA), the State of 

Texas developed a Coastal Management Program (CMP) to allow for the review of 

proposed Federal license and permit activities affecting any coastal use or resource, in 

or outside of the Texas Coastal Zone.

The OCS related oil and gas exploratory and development activities having potential 

impact on the Texas Coastal Zone are based on the location of the proposed facilities, 

access to those sites, best practical techniques for drilling locations, drilling equipment 

guidelines for the prevention of adverse environmental effects, effective environmental 

protection, emergency plans and contingency plans. 

Listed below are the policies and corresponding sections within this Exploration Plan 

identified by the State of Texas CMP as being related to OCS Plans: 

Policy of the Texas Coastal Management Plan (TCMP) 

(Texas Administrative Code, Title 31, Park 16, Chapter 501, Subchapter B) 

Policies EP Section Evaluation 

Category 2: 

Construction, Operation 

and Maintenance of Oil 

and Gas Exploration and 

Production Facilities 

(501.17) 

1 Plan Contents 

2 General 

The proposed activities are 

located approximately 357 

miles from the nearest Texas 

coastline, 

No adverse impacts on Texas 

submerged lands, critical 

areas, wetlands, beaches, or 

other coastal resources from 

routine activities are 

anticipated. 

Category 3: 

Discharges of Wastewater 

and Disposal of Waste 

from Oil and Gas 

Exploration and Production 

Activities (501.18) 

6 Wastes and 

Discharges 

No adverse impacts on the 

Texas coastal zone are 

anticipated. The proposed 

activities do not involve any 

discharges to the Texas 

coastal zone as the project is 

approximately 357 miles from 

the nearest Texas coastline, 

All offshore discharges 

associated with the proposed 

activities, as summarized in 
Deep Gulf Energy II, LLC Section 15 – Pg. 24 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

Section 6 and evaluated in 

Section 15, will be conducted 

in accordance with 

regulations implemented by 

the United States 

Environmental Protection 

Agency (USEPA), the U. S. 

Coast Guard (USCG), and 

the Bureau of Ocean Energy 

Management (BOEM). All 

wastes generated during 

drilling that do not meet 

discharge regulations will be 

properly transported to City, 

State, and disposed of as 

summarized in Section 12. 

Category 4: 

Construction and 

Operation of Solid Waste 

Treatment, Storage, and 

Disposal Facilities (501.19) 

6 Wastes and 

Discharges 

13 Onshore Support 

Facilities 

All solid wastes generated by 

the activities proposed in this 

plan will be treated, stored, 

and disposed of in State 

following applicable rules and 

regulations as described in 

Section 12. 

Category 5: 

Prevention, Response, and 

Remediation of Oil Spills 

(501.20) 

2 General 

8 Oil Spill 

The proposed activities 

summarized in Section 8 will 

comply with all applicable 

laws and regulations 

concerning oil spill 

prevention, response, and 

remediation. The proposed 

activities will be covered 

under Deep Gulf Energy LP’s 

approved Regional Oil Spill 

Response Plan (OSRP), 

which includes Deep Gulf 

Energy II, LLC. The proposed 

activities are located 

approximately 357 miles from 
Deep Gulf Energy II, LLC Section 15 – Pg. 25 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

the nearest Texas coastline 

and no significant impacts on 

the Texas coastal zone are 

expected. 

Category 6: 

Discharge of Municipal and 

Industrial Waste Water to 

Coastal Waters (501.21) 

6 Wastes and 

Discharges 

No discharges to Texas 

coastal waters are proposed 

(Section 6) and no adverse 

impacts are expected. The 

proposed activities are 

located approximately 357 

miles from the nearest Texas 

coastline and will be 

conducted in accordance with 

discharge regulations 

implemented by the USEPA, 

the USCD, and BOEM. 

Category 7: 

Non Point Source Pollution 

(501.22) 

6 Wastes and 

Discharges 

The proposed activities do not 

include nonpoint sources of 

water pollution and no 

adverse impacts are 

expected. 

Category 8: 

Development in Critical 

Areas (501.23) 

5 Biological, Physical 

and Socioeconomic 

10 Lease Stipulations 

11 Environmental 

Mitigation Measures 

13 Onshore Support 

Facilities 

15 Environmental Impact 

Analysis 

No activities are proposed in 

critical areas and no adverse 

impacts on critical areas from 

routine activities are 

expected. 

Category 9: 

Construction of Waterfront 

Facilities and Other 

Structures on Submerge 

lands (501.24) 

2 General 

7 Air Emissions 

13 Onshore Support 

Facilities 

15 Environmental Impact 

Analysis 

No construction of waterfront 

facilities or other structures on 

Texas submerged lands is 

proposed and no adverse 

impacts from routine activities 

are expected. 

Category 10: 

Dredging and Dredged 

13 Onshore Support 

Facilities 

No dredging or dredged 

material disposal or 
Deep Gulf Energy II, LLC Section 15 – Pg. 26 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

Material Disposal and 

Placement (501.25) 

 placement is proposed and 

no adverse impacts are 

expected. 

Category 11: 

Construction in the Beach / 

Dune System (501.26) 

13 Onshore Support 

Facilities 

No construction in the 

beach/dune system is 

proposed and no adverse 

impacts from routine activities 

are expected. 

Category 12: 

Development in Coastal 

Hazard Area (501.27) 

13 Onshore Support 

Facilities 

No development in coastal 

hazard areas is proposed and 

no adverse impacts are 

expected. 

Category 13: 

Development within 

Coastal Barrier Resource 

(501.28) 

13 Onshore Support 

Facilities 

No development within the 

Texas coastal barrier 

resource system is proposed 

and no adverse impacts from 

routine activities are 

expected. 

Category 14: 

Development in State 

Parks, Wildlife 

Management Areas or 

Preserves (501.29) 

13 Onshore Support 

Facilities 

No development in Texas 

state parks, wildlife 

management areas, or 

preserves is proposed and no 

adverse impacts from routine 

activities are expected. 

Category 15: 

Alteration of Coastal 

Historic Areas (501.30) 

5 Biological, Physical, 

and Socioeconomic 

15 Environmental Impact 

Analysis 

The proposed activities do not 

include any development that 

would alter or disturb coastal 

historic areas and no adverse 

impacts from routine activities 

are expected. 

Category 16: 

Transportation Projects 

(501.31) 

13 Onshore Support 

Facilities 

No transportation construction 

or maintenance projects are 

proposed and no adverse 

impacts are expected. 

Category 17: 

Emission of Air Pollutants 

(501.32) 

7 Air Emissions 

15 Environmental Impact 

Analysis 

Air emissions associated with 

project activities are 

summarized in Section 7. The 

proposed activities will be 
Deep Gulf Energy II, LLC Section 15 – Pg. 27 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

conducted in conformance 

with applicable air quality 

laws, standards, and 

regulations. No adverse 

impacts on onshore air quality 

are expected based on the 

emission rates, prevailing 

atmospheric conditions, and 

the distance from the nearest 

Texas coastline 

(approximately 357 miles) as 

discussed in Section 15. 

Category 18: 

Appropriations of Water 

(501.33) 

13 Onshore Support 

Facilities 

No appropriations, 

impoundments, or diversions 

of water resources are 

proposed and no adverse 

impacts are expected. 

Category 19: 

Levee and Control Projects 

(501.34) 

13 Onshore Support 

Facilities 

No levee or flood control 

projects are proposed and no 

adverse impacts are 

expected. 

Category 20: 

Marine Fishery 

Management 

15 Environmental Impact 

Analysis 

No adverse impacts on 

marine fisheries are 

anticipated. 

Category 22: 

Policies for Major Actions 

(501.15) 

15 Environmental Impact 

Analysis 

The proposed activities are 

not a “major action” as 

defined by 501.15 

 

Deep Gulf Energy II, LLC Section 15 – Pg. 28 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

The OCS related oil and gas development activities having potential impact on the 

Alabama Coastal Zone are based on the location of the proposed facilities, access to 

those sites, best practical technique for operations and production equipment, 

guidelines for the prevention of adverse environmental effects, effective environmental 

protection, emergency plans and contingency plans. Alabama policies have been 

addressed below or are cross referenced to the appropriate sections of the plan: 

Topic Cross 

Reference 

Comments 

Coastal 

Resource Use 

Policies 

 

Coastal 

Development 

 Dock and port facilities in Louisiana will be used. There 

will be no new construction, dredging, or filling in 

Alabama state waters. There will be no new commercial 

development or capital improvements in Alabama’s 

coastal zone, nor will there be any employment effects.

Mineral 

Resource 

Exploration 

and Extraction 

 Proposed exploration operations will take place 

approximately 121.8 miles from Alabama’s coastline. 

Commercial 

Fishing 

Section 8 

Hazard 

Management 

Section 3 A Shallow Hazards Report has been prepared and 

submitted to BOEM in order to identify and assess the 

seafloor and shallow geologic conditions in this block. 

Shoreline 

Erosion 

Section 8 Proposed exploration operations will take place 

approximately 121.8 miles from Alabama’s coastline. 

Recreation Section 8 

Transportation Section 12 

Natural 

Resource 

Protection 

Policies 

 

Biological 

Productivity 

Section 8 

Water Quality Section 8 

Water 

Resources 

Section 8 

Air Quality Section 7 

Wetlands and 

Submerged 

Grassbeds 

Section 8 
Deep Gulf Energy II, LLC Section 15 – Pg. 29 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

Beach and 

Dune 

Protection 

Section 8 

Wildlife Habitat 

Protection 

Section 8 

Endangered 

Species 

Section 8 

Cultural 

Resources 

Protection 

Section 5 Mississippi Canyon Block 521 is not located in an area 

where historic shipwrecks may exist. An archaeological 

report was prepared by Geoscience Earth & Marine 

Services, Inc. (GEMS) and it was determined that there 

are no known historic shipwrecks located in the block. 

The report is submitted with this EP. 

The proposed activities described in detail in this Plan comply with Alabama’s approved 

Coastal Zone Management Programs and will be conducted in a manner consistent with 

such Programs. 

Deep Gulf Energy II, LLC Section 15 – Pg. 30 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 15 

ENVIRONMENTAL IMPACT ANALYSIS 

The Environmental Impact Analysis is included as Attachment 15-A.
Deep Gulf Energy II, LLC (DGE II)

Initial Exploration Plan 

Mississippi Canyon Block 521 

OCS-G 34441

(A) IMPACT PRODUCING FACTORS 

ENVIRONMENTAL IMPACT ANALYSIS WORKSHEET 

Environment 

Resources 

Impact Producing Factors (IPFs) 

Categories and Examples 

Refer to recent GOM OCS Lease Sale EIS for a more complete list of IPFs 

Emissions 

(air, noise, 

light, etc.) 

Effluents 

(muds, 

cutting, other 

discharges to 

the water 

column or 

seafloor) 

Physical 

disturbances to the 

seafloor (rig or 

anchor 

emplacements, 

etc.) 

Wastes sent 

to shore for 

treatment 

or disposal 

Accidents 

(e.g., oil 

spills, 

chemical 

spills, H2S 

releases) 

Discarded 

Trash & 

Debris 

Site-specific at Offshore 

Location 

Designated topographic features (1) (1) (1) 

Pinnacle Trend area live bottoms (2) (2) (2) 

Eastern Gulf live bottoms (3) (3) (3) 

Benthic communities (4) 

Water quality X X 

Fisheries X X 

Marine Mammals X(8) X X(8) X 

Sea Turtles X(8) X X(8) X 

Air quality X(9) 

Shipwreck sites (known or 

potential) 

 (7) 

Prehistoric archaeological sites X(7) 

Vicinity of Offshore Location 

Essential fish habitat X X(6) 

Marine and pelagic birds X X 

Public health and safety (5) 

Coastal and Onshore 

Beaches X(6) X 

Wetlands X(6) 

Shore birds and coastal nesting 

birds 

 X6) 

Coastal wildlife refuges 

Wilderness areas 
Footnotes for Environmental Impact Analysis Matrix 

1) Activities that may affect a marine sanctuary or topographic feature. Specifically, if the well or platform site or 

any anchors will be on the seafloor within the: 

o 4-mile zone of the Flower Garden Banks, or the 3-mile zone of Stetson Bank; 

o 1000-m, 1-mile or 3-mile zone of any topographic feature (submarine bank) protected by the Topographic 

Features Stipulation attached to an OCS lease; 

o Essential Fish Habitat (EFH) criteria of 500 ft. from any no-activity zone; or 

o Proximity of any submarine bank (500 ft. buffer zone) with relief greater than 2 meters that is not protected 

by the Topographic Features Stipulation attached to an OCS lease. 

2) Activities with any bottom disturbance within an OCS lease block protected through the Live Bottom (Pinnacle 

Trend) Stipulation attached to an OCS lease. 

3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (LowRelief) Stipulation attached to an OCS lease. 

4) Activities on blocks designated by the BOEM as being in water depths 300 meters or greater. 

5) Exploration or production activities where H2S concentrations greater than 500 ppm might be encountered. 

6) All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that you 

determine would impact these environmental resources. If the proposed action is located a sufficient distance 

from a resource that no impact would occur, the EIA can note that in a sentence or two. 

7) All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block designated 

by the BOEM as having high-probability for the occurrence of shipwrecks or prehistoric sites, including such 

blocks that will be affected that are adjacent to the lease block in which your planned activity will occur. If the 

proposed activities are located a sufficient distance from a shipwreck or a prehistoric site that no impact would 

occur, the EIA can note that in a sentence or two. 

8) All activities that you determine might have an adverse effect on endangered or threatened marine mammals or 

sea turtles or their critical habitats. 

9) Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges. 
(B) Analysis 

Site-Specific at Mississippi Canyon 521 

Proposed operations consist of the drilling and completion of Well Locations A and D. The 

operations will be conducted with a drillship or dynamically positioned semisubmersible. 

1. Designated Topographic Features 

Potential IPFs on topographic features include effluents, and accidents. 

Effluents: Mississippi Canyon Block 521 is 86 miles from the closest designated Topographic 

Features Stipulation Block (Sackett Bank); therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to 

benthic organisms only if the oil contacts the organisms. Oil from a surface spill can be driven 

into the water column; measurable amounts have been documented down to a 10 m depth. At 

this depth, the oil is found only at concentrations several orders of magnitude lower than the 

amount shown to have an effect on corals. Because the crests of topographic features in the 

Northern Gulf of Mexico are found below 10 m, no oil from a surface spill could reach their 

sessile biota. Oil from a subsurface spill is not applicable due to the distance of these blocks from 

a topographic area. The activities proposed in this plan will be covered by DGE II’s Regional 

OSRP (refer to information submitted in Section 8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities, which could impact topographic features. 

2. Pinnacle Trend Area Live Bottoms 

Potential IPFs on pinnacle trend area live bottoms include effluents and accidents. 

Effluents: Mississippi Canyon Block 521 is 49.5 miles from the closest live bottom (pinnacle 

trend) area; therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills have the potential to 

foul benthic communities and cause lethal and sublethal effects on live bottom organisms. Oil 

from a surface spill can be driven into the water column; measurable amounts have been 

documented down to a 10 m depth. At this depth, the oil is found only at concentrations several 

orders of magnitude lower than the amount shown to have an effect on marine organisms. Oil 

from a subsurface spill is not applicable due to the distance of these blocks from a live bottom 
(pinnacle trend) area. The activities proposed in this plan will be covered by DGE II’s Regional 

OSRP (refer to information submitted in Section 8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities which could impact a live bottom 

(pinnacle trend) area. 

3. Eastern Gulf Live Bottoms 

Potential IPFs on Eastern Gulf live bottoms include effluents and accidents. 

Effluents: Mississippi Canyon Block 521 is not located in an area characterized by the 

existence of live bottoms; therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to live 

bottom organisms only if the oil contacts the organisms. Oil from a surface spill can be driven 

into the water column; measurable amounts have been documented down to a 10 m depth. At 

this depth, the oil is found only at concentrations several orders of magnitude lower than the 

amount shown to have an effect on marine invertebrates. Oil from a subsurface spill is not 

applicable due to the distance of these blocks from a live bottom area. The activities proposed in 

this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 

8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities which could impact an Eastern Gulf live 

bottom area. 

4. Benthic Communities 

There are no IPFs (including emissions, physical disturbances to the seafloor, wastes sent to 

shore for disposal, or accidents) from the proposed activities that could cause impacts to benthic 

communities. 

A drillship or dynamically positioned semisubmersible is being used for the proposed activities; 

therefore, only an insignificant amount of seafloor will be disturbed. Because physical 

disturbances to the seafloor will be minimized by the use of a drillship or dynamically positioned 

semisubmersible, DGE II’s proposed operations in Mississippi Canyon Block 521 would not 

cause impacts to benthic communities. 

5. Water Quality 

IPFs that could result in water quality degradation from the proposed operations in Mississippi 

Canyon Block 521 include effluents and accidents. 
 

Effluents: Levels of contaminants in drilling muds and cuttings and produced water discharges, 

discharge-rate restrictions and monitoring and toxicity testing are regulated by the EPA NPDES 

permit, thereby eliminating many significant biological or ecological effects. Operational 

discharges are not expected to cause significant adverse impacts to water quality. 

Accidents: Oil spills have the potential to alter offshore water quality; however, it is unlikely 

that an accidental surface or subsurface spill would occur from the proposed activities. Between 

1980 and 2000, OCS operations produced 4.7 billion barrels of oil and spilled only 0.001 percent 

of this oil, or 1 bbl for every 81,000 bbl produced. The spill risk related to a diesel spill from 

drilling operations is even less. Between 1976 and 1985, (years for which data were collected), 

there were 80 reported diesel spills greater than one barrel associated with drilling activities. 

Considering that there were 11,944 wells drilled, this is a 0.7 percent probability of an 

occurrence. If a spill were to occur, the water quality of marine waters would be temporarily 

affected by the dissolved components and small oil droplets. Dispersion by currents and 

microbial degradation would remove the oil from the water column and dilute the constituents to 

background levels. Historically, changes in offshore water quality from oil spills have only been 

detected during the life of the spill and up to several months afterwards. Most of the components 

of oil are insoluble in water and therefore float. The activities proposed in this plan will be 

covered by DGE II’s Regional Oil Spill Response Plan (refer to information submitted in 

Section 8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor, and wastes 

sent to shore for disposal) from the proposed activities which could cause impacts to water 

quality. 

6. Fisheries 

IPFs that could cause impacts to fisheries as a result of the proposed operations in Mississippi 

Canyon Block 521 include effluents and accidents. 

Effluents: Effluents such as drilling fluids and cuttings discharges contain components and 

properties which are detrimental to fishery resources. Moderate petroleum and metal 

contamination of sediments and the water column can occur out to several hundred meters downcurrent from the discharge point. Offshore discharges are expected to disperse and dilute to very 

near background levels in the water column or on the seafloor within 3,000 m of the discharge 

point, and are expected to have negligible effect on fisheries. 

Accidents: An accidental oil spill has the potential to cause some detrimental effects on 

fisheries; however, it is unlikely that such an event would occur from the proposed activities 

(refer to Item 5, Water Quality). The effects of oil on mobile adult finfish or shellfish would 

likely be sublethal and the extent of damage would be reduced to the capacity of adult fish and 

shellfish to avoid the spill, to metabolize hydrocarbons, and to excrete both metabolites and 
parent compounds. The activities proposed in this plan will be covered by DGE II’s Regional 

OSRP (refer to information submitted in Section 8). 

There are no IPFs from emissions, physical disturbances to the seafloor or wastes sent to shore 

for disposal from the proposed activities which could cause impacts to fisheries. 

7. Marine Mammals 

GulfCet II studies revealed that cetaceans of the continental shelf and shelf-edge were almost 

exclusively bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and 

pygmy killer whale, Risso’s dolphin, rough-toothed dolphin, and Cuvier’s beaked whale, 

occurred most frequently along the upper slope in areas outside of anticyclones. IPFs that could 

cause impacts to marine mammals as a result of the proposed operations in Mississippi Canyon 

Block 521 include emissions, effluents, discarded trash and debris, and accidents. 

Emissions: Noises from drilling activities, support vessels and helicopters may elicit a startle 

reaction from marine mammals. This reaction may lead to disruption of marine mammals’ 

normal activities. Stress may make them more vulnerable to parasites, disease, environmental 

contaminants, and/or predation (Majors and Myrick, 1990). There is little conclusive evidence 

for long-term displacements and population trends for marine mammals relative to noise. 

Effluents: Drilling fluids and cuttings discharges contain components which may be detrimental 

to marine mammals. Most operational discharges are diluted and dispersed upon release. Any 

potential impact from drilling fluids would be indirect, either as a result of impacts on prey items 

or possibly through ingestion in the food chain (API, 1989). 

Discarded trash and debris: Both entanglement in, and ingestion of debris have caused the 

death or serious injury of marine mammals (Laist, 1997; MMC, 1999). The limited amount of 

marine debris, if any, resulting from the proposed activities is not expected to substantially harm 

marine mammals. Operators are prohibited from deliberately discharging debris as mandated by 

MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations 

imposed by various agencies including the United States Coast Guard (USCG) and the 

Environmental Protection Agency (EPA). 

DGE II will operate in accordance with the regulations and also avoid accidental loss of solid 

waste items by maintaining waste management plans, manifesting trash sent to shore, and using 

special precautions such as covering outside trash bins to prevent accidental loss of solid waste. 

Special caution will be exercised when handling and disposing of small items and packaging 

materials, particularly those made of non-biodegradable, environmentally persistent materials 

such as plastic or glass. 

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 
services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from DGE II management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

Accidents: Collisions between support vessels and cetaceans would be unusual events, however 

should one occur, death or injury to marine mammals is possible. Contract vessel operators can 

avoid marine mammals and reduce potential deaths by maintaining a vigilant watch for marine 

mammals and maintaining a safe distance when they are sighted. Vessel crews should use a 

reference guide to help identify the twenty-eight species of whales and dolphins, and the single 

species of manatee that may be encountered in the Gulf of Mexico OCS. Vessel crews must 

report sightings of any injured or dead protected marine mammal species immediately, 

regardless of whether the injury or death is caused by their vessel, to the Marine Mammal and 

Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional Office at (727) 

824-5312, or the Marine Mammal Stranding Network at (305) 862-2850. In addition, if the 

injury or death was caused by a collision with a contract vessel, the BOEM must be notified 

within 24 hours of the strike by email to protectedspecies@boemre.gov. If the vessel is the 

responsible party, it is required to remain available to assist the respective salvage and stranding 

network as needed. 

Oil spills have the potential to cause sublethal oil-related injuries and spill-related deaths to 

marine mammals. However, it is unlikely that an accidental oil spill would occur from the 

proposed activities (refer to Item 5, Water Quality). Oil spill response activities may increase 

vessel traffic in the area, which could add to changes in cetacean behavior and/or distribution, 

thereby causing additional stress to the animals. The effect of oil dispersants on cetaceans is not 

known. The acute toxicity of oil dispersant chemicals included in DGE II’s OSRP is considered 

to be low when compared with the constituents and fractions of crude oils and diesel products. 

The activities proposed in this plan will be covered by DGE II’s OSRP (refer to information 

submitted in accordance with Section 8). 

There are no other IPFs (including physical disturbances to the seafloor) from the proposed 

activities which could impact marine mammals. 

8. Sea Turtles 

IPFs that could cause impacts to sea turtles as a result of the proposed operations include 

emissions, effluents, discarded trash and debris, and accidents. GulfCet II studies sighted most 

loggerhead, Kemp’s ridley and leatherback sea turtles over shelf waters. Historically these 

species have been sighted up to the shelf’s edge. They appear to be more abundant east of the 

Mississippi River than they are west of the river (Fritts et al., 1983b; Lohoefener et al., 1990). 

Deep waters may be used by all species as a transitory habitat. 
Emissions: Noise from drilling activities, support vessels, and helicopters may elicit a startle 

reaction from sea turtles, but this is a temporary disturbance. 

Effluents: Drilling fluids and cuttings discharges are not known to be lethal to sea turtles. Most 

operational discharges are diluted and dispersed upon release. Any potential impact from 

drilling fluids would be indirect, either as a result of impacts on prey items or possibly through 

ingestion in the food chain (API, 1989). 

Discarded trash and debris: Both entanglement in, and ingestion of, debris have caused the 

death or serious injury of sea turtles (Balazs, 1985). The limited amount of marine debris, if any, 

resulting from the proposed activities is not expected to substantially harm sea turtles. Operators 

are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the 

Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies 

including the United States Coast Guard (USCG) and the Environmental Protection Agency 

(EPA). DGE II will operate in accordance with the regulations and also avoid accidental loss of 

solid waste items by maintaining waste management plans, manifesting trash sent to shore, and 

using special precautions such as covering outside trash bins to prevent accidental loss of solid 

waste. Special caution will be exercised when handling and disposing of small items and 

packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass. 

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from DGE II management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

Accidents: Collisions between support vessels and sea turtles would be unusual events, however 

should one occur, death or injury to sea turtles is possible. Contract vessel operators can avoid 

sea turtles and reduce potential deaths by maintaining a vigilant watch for sea turtles and 

maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to 

help identify the five species of sea turtles that may be encountered in the Gulf of Mexico OCS. 

Vessel crews must report sightings of any injured or dead protected sea turtle species 

immediately, regardless of whether the injury or death is caused by their vessel, to the Marine 

Mammal and Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional 

Office at (727) 824-5312, or the Marine Mammal Stranding Network at (305) 862-2850. In 

addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must 

be notified within 24 hours of the strike by email to protectedspecies@boemre.gov. If the vessel 
is the responsible party, it is required to remain available to assist the respective salvage and 

stranding network as needed. 

All sea turtle species and their life stages are vulnerable to the harmful effects of oil through 

direct contact or by fouling of their food. Exposure to oil can be fatal, particularly to juveniles 

and hatchlings. However, it is unlikely that an accidental oil spill would occur from the proposed 

activities (refer to Item 5, Water Quality). Oil spill response activities may increase vessel traffic 

in the area, which could add to the possibility of collisions with sea turtles. The activities 

proposed in this plan will be covered by DGE II’s Regional Oil Spill Response Plan (refer to 

information submitted in accordance with Section 8). 

There are no other IPFs (including physical disturbances to the seafloor) from the proposed 

activities which could impact sea turtles. 

9. Air Quality 

Mississippi Canyon Block 521 is located 93 miles from the Breton Wilderness Area and 65 miles 

from shore. Applicable emissions data is included in Section 7 of the Plan. 

There would be a limited degree of air quality degradation in the immediate vicinity of the 

proposed activities. Plan Emissions for the proposed activities do not exceed the annual 

exemption levels as set forth by BOEM. Accidents and blowouts can release hydrocarbons or 

chemicals, which could cause the emission of air pollutants. However, these releases would not 

impact onshore air quality because of the prevailing atmospheric conditions, emission height, 

emission rates, and the distance of Mississippi Canyon Block 521 from the coastline. There are 

no other IPFs (including effluents, physical disturbances to the seafloor, wastes sent to shore for 

treatment or disposal) from the proposed activities which would impact air quality. 

10. Shipwreck Sites (known or potential) 

Potential IPFs that could impact known or unknown shipwreck sites as a result of the proposed 

operations in Mississippi Canyon Block 521 include disturbances to the seafloor. 

Physical disturbances to the seafloor: A drillship or dynamically positioned semisubmersible 

is being used for the proposed activities; therefore, only an insignificant amount of seafloor will 

be disturbed. Because physical disturbances to the seafloor will be minimized by the use of a 

drillship or dynamically positioned semisubmersible, DGE II’s proposed operations in 

Mississippi Canyon Block 521 would not cause impacts to shipwreck sites. 

Additionally, Mississippi Canyon Block 521 is not located in or adjacent to an OCS block 

designated by BOEM as having a high probability for occurrence of shipwrecks, therefore, no 

adverse impacts are expected. 
DGE II will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning 

sonar within a minimum 500’ radius of the proposed well location(s) prior to or upon 

commencement of operations. These locations will be certified by an authorized marine 

archaeologist and by DGE II to be clear of seafloor archaeological resources, including historic 

shipwrecks. Copies of the certifications and a circle radius plat of the survey area will be 

submitted to the BOEM. Should a resource be encountered, DGE II will contact the BOEM 

immediately and make every reasonable effort to preserve and protect that cultural resource. 

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or 

disposal, or accidents) from the proposed activities that could cause impacts to shipwreck sites. 

11. Prehistoric Archaeological Sites 

IPFs that could cause impacts to prehistoric archaeological sites as a result of the proposed 

operations in Mississippi Canyon Block 521 are physical disturbances to the seafloor and 

accidents (oil spills). 

Physical Disturbances to the seafloor: Although the operations proposed will be conducted by 

utilizing a drillship or dynamically positioned semisubmersible, which would cause only an 

insignificant amount of seafloor to be disturbed, Mississippi Canyon Block 521 is located inside 

the Archaeological Prehistoric high probability lines. DGE II will report to BOEM the discovery 

of any object of prehistoric archaeological significance and make every reasonable effort to 

preserve and protect that cultural resource. 

DGE II will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning 

sonar within a minimum 500’ radius of the proposed well location(s) prior to or upon 

commencement of operations. These locations will be certified by an authorized marine 

archaeologist and by DGE II to be clear of seafloor archaeological resources. Copies of the 

certifications and a circle radius plat of the survey area will be submitted to the BOEM. Should 

a resource be encountered, DGE II will contact the BOEM immediately and make every 

reasonable effort to preserve and protect that cultural resource. . 

Accidents: An accidental oil spill has the potential to cause some detrimental effects to 

prehistoric archaeological sites if the release were to occur subsea. However, it is unlikely that 

an accidental oil spill would occur from the proposed activities (refer to Item 5, Water Quality). 

The activities proposed in this plan will be covered by DGE II’s Regional Oil Spill Response 

Plan (refer to information submitted in accordance with Section 8). 

There are no other IPFs (including emissions, effluents or wastes sent to shore for treatment or 

disposal) from the proposed activities which could impact prehistoric archeological sites. 
Vicinity of Offshore Location 

1. Essential Fish Habitat (EFH) 

IPFs that could cause impacts to EFH as a result of the proposed operations in Mississippi 

Canyon Block 521 include effluents and accidents. EFH includes all estuarine and marine waters 

and substrates in the Gulf of Mexico. 

Effluents: The Live Bottom Low Relief Stipulation, the Live Bottom (Pinnacle Trend) 

Stipulation, and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential 

impacts on live-bottom communities and EFH from operational waste discharges. Levels of 

contaminants in drilling muds and cuttings and produced-water discharges, discharge-rate 

restrictions, and monitoring and toxicity testing are regulated by the EPA NPDES permit, 

thereby eliminating many significant biological or ecological effects. Operational discharges are 

not expected to cause significant adverse impacts to EFH. 

Accidents: An accidental oil spill has the potential to cause some detrimental effects on EFH. 

Oil spills that contact coastal bays and estuaries, as well as OCS waters when pelagic eggs and 

larvae are present, have the greatest potential to affect fisheries. However, it is unlikely that an 

oil spill would occur from the proposed activities (refer to Item 5, Water Quality). The activities 

proposed in this plan will be covered by DGE II’s Regional OSRP (refer to information 

submitted in Section 8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for treatment or disposal) from the proposed activities which could impact essential 

fish habitat. 

2. Marine and Pelagic Birds 

IPFs that could impact marine birds as a result of the proposed activities include air emissions, 

accidental oil spills, and discarded trash and debris from vessels and the facilities. 

Emissions: Emissions of pollutants into the atmosphere from these activities are far below 

concentrations which could harm coastal and marine birds. 

Accidents: An oil spill would cause localized, low-level petroleum hydrocarbon contamination. 

However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, 

Water Quality). Marine and pelagic birds feeding at the spill location may experience chronic, 

nonfatal, physiological stress. It is expected that few, if any, coastal and marine birds would 

actually be affected to that extent. The activities proposed in this plan will be covered by DGE 

II’s Regional OSRP (refer to information submitted in Section 8). 
Discarded trash and debris: Marine and pelagic birds could become entangled and snared in 

discarded trash and debris, or ingest small plastic debris, which can cause permanent injuries and 

death. Operators are prohibited from deliberately discharging debris as mandated by MARPOLAnnex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by 

various agencies including the United States Coast Guard (USCG) and the Environmental 

Protection Agency (EPA). DGE II will operate in accordance with the regulations and also avoid 

accidental loss of solid waste items by maintaining waste management plans, manifesting trash 

sent to shore, and using special precautions such as covering outside trash bins to prevent 

accidental loss of solid waste. Special caution will be exercised when handling and disposing of 

small items and packaging materials, particularly those made of non-biodegradable, 

environmentally persistent materials such as plastic or glass. Informational placards will be 

posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore 

personnel, including contractors and other support services-related personnel (e.g. helicopter 

pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view 

the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from DGE II 

management or the designated lease operator management that emphasizes their commitment to 

waste management in accordance with NTL No. 2012-G01. Debris, if any, from these proposed 

activities will seldom interact with marine and pelagic birds; therefore, the effects will be 

negligible. 

There are no other IPFs (including effluents, physical disturbances to the seafloor, or wastes sent 

to shore for treatment or disposal) from the proposed activities which could impact marine and 

pelagic birds. 

3. Public Health and Safety Due to Accidents. 

There are no IPFs (emissions, effluents, physical disturbances to the seafloor, wastes sent to 

shore for treatment or disposal or accidents, including an accidental H2S release) from the 

proposed activities which could cause impacts to public health and safety. In accordance with 

NTL No.’s 2008-G04, 2009-G27, and 2009-G31, sufficient information is included in Section 4

to justify our request that our proposed activities be classified by BSEE as H2S absent. 

Coastal and Onshore 

1. Beaches 

IPFs from the proposed activities that could cause impacts to beaches include accidents (oil 

spills) and discarded trash and debris. 

Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches 

and associated resources. Due to the distance from shore (65 miles) and the response capabilities 
that would be implemented, no significant adverse impacts are expected. The activities proposed 

in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in 

Section 8). 

Discarded trash and debris: Trash on the beach is recognized as a major threat to the 

enjoyment and use of beaches. There will only be a limited amount of marine debris, if any, 

resulting from the proposed activities. Operators are prohibited from deliberately discharging 

debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and 

Control Act, and regulations imposed by various agencies including the United States Coast 

Guard (USCG) and the Environmental Protection Agency (EPA). DGE II will operate in 

accordance with the regulations and also avoid accidental loss of solid waste items by 

maintaining waste management plans, manifesting trash sent to shore, and using special 

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as 

plastic or glass. 

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from DGE II management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities which could impact beaches. 

2. Wetlands 

IPFs from the proposed activities that could cause impacts to wetlands include accidents (oil 

spills) and discarded trash and debris. 

Accidents: It is unlikely that an oil spill would occur from the proposed activities (refer to Item 

5, Water Quality). Due to the distance from shore (65 miles) and the response capabilities that 

would be implemented, no impacts are expected. The activities proposed in this plan will be 

covered by DGE II’s Regional OSRP (refer to information submitted in Section 8). 

Discarded trash and debris: There will only be a limited amount of marine debris, if any, 

resulting from the proposed activities. Operators are prohibited from deliberately discharging 

debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and 
Control Act, and regulations imposed by various agencies including the United States Coast 

Guard (USCG) and the Environmental Protection Agency (EPA). DGE II will operate in 

accordance with the regulations and also avoid accidental loss of solid waste items by 

maintaining waste management plans, manifesting trash sent to shore, and using special 

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as 

plastic or glass. 

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from DGE II management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities which could impact 

wetlands. 

3. Shore Birds and Coastal Nesting Birds 

Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. However, it is 

unlikely that an oil spill would occur from the proposed activities (refer to Item 5, Water 

Quality). Given the distance from shore (65 miles) and the response capabilities that would be 

implemented, no impacts are expected. The activities proposed in this plan will be covered by 

DGE II’s Regional OSRP (refer to information submitted in Section 8). 

Discarded trash and debris: Coastal and marine birds are highly susceptible to entanglement 

in floating, submerged, and beached marine debris: specifically plastics. Operators are prohibited 

from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic 

Pollution Research and Control Act, and regulations imposed by various agencies including the 

United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). DGE II 

will operate in accordance with the regulations and also avoid accidental loss of solid waste 

items by maintaining waste management plans, manifesting trash sent to shore, and using special 

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as 

plastic or glass. 

 

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 
services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from DGE II management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities that could cause impacts to 

shore birds and coastal nesting birds. 

4. Coastal Wildlife Refuges 

Accidents: An accidental oil spill from the proposed activities could cause impacts to coastal 

wildlife refuges. However, it is unlikely that an oil spill would occur from the proposed activities 

(refer to Item 5, Water Quality). Due to the distance from shore (65 miles) and the response 

capabilities that would be implemented, no impacts are expected. The activities proposed in this 

plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8). 

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and 

the Environmental Protection Agency (EPA). DGE II will operate in accordance with the 

regulations and also avoid accidental loss of solid waste items by maintaining waste management 

plans, manifesting trash sent to shore, and using special precautions such as covering outside 

trash bins to prevent accidental loss of solid waste. Special caution will be exercised when 

handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass. 

 

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from DGE II management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities that could cause impacts to 

coastal wildlife refuges. 
5. Wilderness Areas 

Accidents: An accidental oil spill from the proposed activities could cause impacts to wilderness 

areas. However, it is unlikely that an oil spill would occur from the proposed activities (refer to 

Item 5, Water Quality). Due to the distance from the nearest designated Wilderness Area (93 

miles) and the response capabilities that would be implemented, no significant adverse impacts 

are expected. The activities proposed in this plan will be covered by DGE II’s Regional OSRP 

(refer to information submitted in Section 8).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and 

the Environmental Protection Agency (EPA). DGE II will operate in accordance with the 

regulations and also avoid accidental loss of solid waste items by maintaining waste management 

plans, manifesting trash sent to shore, and using special precautions such as covering outside 

trash bins to prevent accidental loss of solid waste. Special caution will be exercised when 

handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass. 

 

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from DGE II management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities that could cause impacts to 

wilderness areas. 

6. Other Environmental Resources Identified 

There are no other environmental resources identified for this impact assessment. 

(C) IMPACTS ON PROPOSED ACTIVITIES 

The site–specific environmental conditions have been taken into account for the proposed 

activities. No impacts are expected on the proposed activities from site-specific environmental 

conditions. 
(D) ENVIRONMENTAL HAZARDS 

During the hurricane season, June through November, the Gulf of Mexico is impacted by an 

average of ten tropical storms (39-73 mph winds), of which six become hurricanes ( > 74 mph 

winds). Due to its location in the gulf, Mississippi Canyon Block 521 may experience hurricane 

and tropical storm force winds, and related sea currents. These factors can adversely impact the 

integrity of the operations covered by this plan. A significant storm may present physical hazards 

to operators and vessels, damage exploration or production equipment, or result in the release of 

hazardous materials (including hydrocarbons). Additionally, the displacement of equipment may 

disrupt the local benthic habitat and pose a threat to local species. 

The following preventative measures included in this plan may be implemented to mitigate these 

impacts: 

1. Drilling & completion 

a. Secure well 

b. Secure rig / platform 

c. Evacuate personnel 

Drilling activities will be conducted in accordance with NTL No.’s 2008-G09, 2009-G10, and 

2010-N10. 

2. Structure Installation 

 Operator will not conduct structure installation operations during Tropical Storm or 

 Hurricane threat. 

(E) ALTERNATIVES 

No alternatives to the proposed activities were considered to reduce environmental impacts. 

(F) MITIGATION MEASURES 

No mitigation measures other than those required by regulation will be employed to avoid, 

diminish, or eliminate potential impacts on environmental resources. 

(G) CONSULTATION 

No agencies or persons were consulted regarding potential impacts associated with the proposed 

activities. Therefore, a list of such entities has not been provided. 

(H) PREPARER(S) 

Trinity Howell 

J. Connor Consulting, Inc. 

16225 Park Ten Place, Suite 700 

Houston, TX 77084 

(281) 578-3388 

trinity.howell@jccteam.com 
(I) REFERENCES 

Authors: 

American Petroleum Institute (API). 1989. Effects of offshore petroleum operations on cold 

water marine mammals: a literature review. Washington, DC: American Petroleum 

Institute. 385 pp. 

Balazs, G.H. 1985. Impact of ocean debris on marine turtles: entanglement and ingestion. In: 

Shomura, R.S. and H.O. Yoshida, eds. Proceedings, Workshop on the Fate and Impact of 

Marine Debris, 26-29 November 1984, Honolulu, HI. U.S. Dept. of Commerce. NOAA 

Tech. Memo. NOAA-TM-NMFS-SWFC-54. Pp 387-429. 

Burke, C.J. and J.A. Veil. 1995. Potential benefits from regulatory consideration of synthetic 

drilling muds. Environmental Assessment Division, Argonne National Laboratory, 

ANL/EAD/TM-43. 

Daly, J.M. 1997. Controlling the discharge of synthetic-based drilling fluid contaminated 

cuttings in waters of the United States. U.S. Environmental Protection Agency, Office of 

Water. Work Plan, June 24, 1997. 

Hansen, D.J. 198l. The relative sensitivity of seabird populations in Alaska to oil pollution. U.S. 

Dept. of the Interior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLMYK-ES-81-006-1792. 

Laist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris 

including a comprehensive list of species with entanglement and ingestion records. In: Coe, 

J.M. and D.B. Rogers, eds. Marine debris: sources, impacts, and solutions. New York, NY: 

Springer-Verlag. Pp. 99-139. 

Majors, A.P. and A.C. Myrick, Jr. 1990. Effects of noise on animals: implications for dolphins 

exposed to seal bombs in the eastern tropical Pacific purse-seine fishery–an annotated 

bibliography. NOAA Administrative Report LJ-90-06. 

Marine Mammal Commission. 1999. Annual report to Congress – 1998. 

Piatt, J.F., C.J. Lensink, W. Butler, M. Kendziorek, and D.R. Nysewander. 1990. Immediate 

impact of the Exxon Valdez oil spill on marine birds. The Auk. 107 (2): 387-397 

Vauk , G., E. Hartwig, B. Reineking, and E. Vauk-Hentzelt. 1989. Losses of seabirds by oil 

pollution at the German North Sea coast. Topics in Marine Biology. Ros, J.D, ed. Scient. 

Mar. 53 (2-3): 749-754. 

Vermeer, K. and R. Vermeer, 1975 Oil threat to birds on the Canadian west coast. The Canadian 

Field-Naturalist. 89:278-298. 
Although not cited, the following were utilized in preparing this EIA: 

 Hazard Surveys 

 BOEM EIS’s: 

o GOM Deepwater Operations and Activities. Environmental Assessment. BOEM 2000-

001 

o GOM Central and Western Planning Areas Sales 166 and 168 Final Environmental 

Impact Statement. BOEM 96-0058. 
Deep Gulf Energy II, LLC Section 16 – Pg. 31 of 31 

Initial EP July, 2014 

Mississippi Canyon Block 521 (OCS-G 34441) 

SECTION 16 

ADMINISTRATIVE INFORMATION 

16.1 EXEMPTED INFORMATION DESCRIPTION 

The proposed bottom-hole locations of the planned wells have been removed from the 

Public Information copy of this EP as well as any discussions of the target objectives, 

geologic or geophysical data, and any interpreted geology.

16.2 BIBLIOGRAPHY 

1. Regional Oil Spill Response Plan (Control Number O-578). 

2. Geoscience Earth & Marine Services, Inc. Geologic, Stratigraphic and 

Archaeological Assessment, Block 521, Mississippi Canyon Area Gulf of Mexico, 

Project No. 0613-2255b / 0613-2255c. 

3. Geoscience Earth & Marine Services, Inc. Site Clearance Letter, Proposed 

Wellsites A and D, Block 521 (OCS-G 34441), Mississippi Canyon Area, Gulf of 

Mexico, Project No. 0613-2255b.