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-09847

Type - Initial Exploration Plan

Lease(s) - OCS-G11080 Block - 644 Green Canyon Area

OCS-G11081 Block - 645 Green Canyon Area

OCS-G34999 Block - 600 Green Canyon Area

Operator - Freeport-McMoRan Oil & Gas LLC

Drill,test,and complete Wells A&B (G11080), Wells C&D 

(G11081), and Wells E&F (G34999)

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.

Tommy Hoke

Plan Coordinator

Description -

Rig Type -

Subject:

From:

December 16, 2014
PUBLIC COPY 

November 20, 2014 

JOINT INITIAL EXPLORATION PLAN 

Green Canyon Blocks 600 / 644 / 645 

OCS-G 34999 / 11080 / 11081 

Holstein Deep Prospect 

Affected State: Louisiana 

Estimated Startup Date: March 8, 2017 

SUBMITTED BY: 

Freeport-McMoRan Oil & Gas LLC 

400 E. Kaliste Saloom Road, Suite 1100 

Lafayette, LA 70508 

Paul Landry 

Office: (337) 354-5065 

Mobile: (337) 349-7781 

paul_landry@fmi.com 

AUTHORIZED REPRESENTATIVE:

Kim Sayre 

J. Connor Consulting, Inc. 

16225 Park Ten Place, Suite 700 

Houston, Texas 77084 

(281) 578-3388 

kim.sayre@jccteam.com 
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 .......................................................................... 2

1.6 ADDITIONAL MEASURES .................................................................................................. 2

1.7 COST RECOVERY FEE ..................................................................................................... 2

SECTION 2 GENERAL INFORMATION ..................................................................................... 3

2.1 APPLICATIONS AND PERMITS ......................................................................................... 3

2.2 DRILLING FLUIDS ............................................................................................................. 3

2.3 NEW OR UNUSUAL TECHNOLOGY ................................................................................. 3

2.4 BONDING STATEMENT .................................................................................................... 3

2.5 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR)........................................................... 3

2.6 DEEPWATER WELL CONTROL STATEMENT................................................................. 3

2.7 BLOWOUT SCENARIO AND WORST CASE DISCHARGE CALCULATIONS ................ 4

SECTION 3 GEOLOGICAL AND GEOPHYSICAL INFORMATION .......................................... 7

3.1 GEOLOGICAL DESCRIPTION ........................................................................................... 7

3.2 STRUCTURE CONTOUR MAPS ........................................................................................ 7

3.3 INTERPRETED SEISMIC LINES ........................................................................................ 7

3.4 GEOLOGICAL STRUCTURE CROSS-SECTIONS ............................................................ 7

3.5 SHALLOW HAZARDS REPORT ......................................................................................... 7

3.6 SHALLOW HAZARDS ASSESSMENT ............................................................................... 7

3.7 HIGH-RESOLUTION SEISMIC LINES ................................................................................ 7

3.8 STRATIGRAPHIC COLUMN ............................................................................................... 7

3.9 TIME VERSUS DEPTH TABLES ........................................................................................ 7

SECTION 4 HYDROGEN SULFIDE INFORMATION ................................................................. 8

4.1 CONCENTRATION ............................................................................................................. 8

4.2 CLASSIFICATION ............................................................................................................... 8
TOC Pg 2 of 3 

SECTION 5 BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION ................... 9

5.1 DEEPWATER BENTHIC COMMUNITIES .......................................................................... 9

5.2 TOPOGRAPHIC FEATURES (BANKS) .............................................................................. 9

5.3 TOPOGRAPHIC FEATURES STATEMENT (SHUNTING) ................................................. 9

5.4 LIVE BOTTOMS (PINNACLE TREND FEATURES) ........................................................... 9

5.5 LIVE BOTTOMS (LOW RELIEF) ......................................................................................... 9

5.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP ............................................. 9

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

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND MARINE 

MAMMAL INFORMATION ............................................................................................... 10

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

8.6 MODELING REPORT ....................................................................................................... 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

10.1 MILITARY WARNING AREA (MWA) .............................................................................. 17

10.2 MARINE PROTECTED SPECIES ................................................................................... 17

SECTION 11 ENVIRONMENTAL MITIGATION MEASURES INFORMATION ........................ 19
TOC Pg 3 of 3 

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

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

SECTION 15 ENVIRONMENTAL IMPACT ANALYSIS ............................................................ 23

SECTION 16 ADMINISTRATIVE INFORMATION .................................................................... 24

16.1 EXEMPTED INFORMATION DESCRIPTION ................................................................. 24

16.2 BIBLIOGRAPHY .............................................................................................................. 24
 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 3 Geological, Geophysical Information 

3-A Shallow Hazard Assessment 

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 

6-B Wastes and Discharges Modeling Report 

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 Certifications 

Section 15 Environmental Impact Analysis (EIA) 

15-A Environmental Impact Analysis (EIA) 
Freeport-McMoRan Oil & Gas LLC Section 1 – Pg. 1 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 1 

PLAN CONTENTS 

1.1 PLAN INFORMATION 

Under this Initial Joint Exploration Plan, Freeport-McMoRan Oil & Gas LLC (FM O&G) proposes 

to drill, test, complete, flare and install subsea trees for two wells in Green Canyon Block 600, 

two wells in Green Canyon Block 644, and two wells in Green Canyon Block 645 with a 

dynamically positioned drillship similar to the Deepwater Champion. 

Per DOCD (Control No. R-5914) FM O&G established production from Leases OCS-G 11080 

(Green Canyon Block 644) and OCS-G 11081 (Green Canyon Block 645) effective February 20, 

2014. FM O&G was designated operator of Lease OCS-G 34999 (Green Canyon Block 600) 

effective November 29, 2013. 

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

1.2 LOCATION 

A Well Location Plat depicting the proposed surface locations of the proposed wells, measured 

depth/true vertical depth and water depth for each location is included as Attachment 1-B.

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

well is included as Attachment 1-C. 

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

1.3 SAFETY AND POLLUTION PREVENTION FEATURES 

FM O&G proposes to drill the wells with a dynamically positioned drillship which is equipped 

with a Subsea BOP. Once a rig is determined, 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). 

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. 
Freeport-McMoRan Oil & Gas LLC Section 1 – Pg. 2 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

1.4 STORAGE TANKS AND PRODUCTION VESSELS 

The table below provides storage tanks with capacity of 25 barrels or more that will store fuels, 

oil and lubricants. 

Type of 

Storage Tank 

Type of 

Facility 

Tank 

Capacity 

(bbl) 

Number 

of Tanks 

Total 

Capacity 

(bbl) 

Fluid 

Gravity 

(API) 

Fuel oil DPDS 4,135.6 2 8,271.2 33° 

Fuel oil DPDS 9,340.4 2 18,680.8 33° 

Fuel Oil DPDS 9,048.5 1 9,048.5 33° 

Fuel Oil DPDS 9,043.5 1 9,043.5 33° 

Fuel Oil DPDS 445.3 2 830.6 33° 

Fuel Oil DPDS 320.2 2 640.3 33° 

Fuel Oil DPDS 359.8 1 359.8 33° 

Fuel Oil DPDS 435.3 1 435.3 33° 

Fuel Oil DPDS 59.8 1 59.8 33° 

Base Oil DPDS 3,683.9 1 3,683.9 31° 

Base Oil DPDS 3,687.1 1 3,687.1 31° 

Lube Oil DPDS 429.6 1 429.6 22.3° 

Waste Oil DPDS 132.1 1 132.1 20° 

Waste Oil DPDS 44 1 44 20° 

Waste Oil DPDS 143.4 1 143.4 20° 

Waste Oil DPDS 1,366.2 1 1,366.2 6.5° 

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 

FM O&G 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 $14,692.00 cost recovery fee payment is included as Attachment 1-D. 
U.S. Department of the Interior OMB Control Number: 1010-0151 

OMB Approval Expires: 12/31/14 

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, install subsea tree 03/08/2017 09/04/2017 180 

Drill and Complete Well Location B, install subsea tree 09/05/2017 03/04/2018 180 

Drill and Complete Well Location C, install subsea tree 03/05/2018 09/11/2018 190 

Drill and Complete Well Location D, install subsea tree 09/12/2018 03/21/2019 190 

Drill and Complete Well Location E, install subsea tree 03/22/2019 09/08/2019 170 

Drill and Complete Well Location F, install subsea tree 09/09/2019 02/26/2020 170 

 

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 

 DP Semisubmersible Other (Attach description) Floating production 

system Other (Attach description) 

Drilling Rig Name (If known): Similar to Deepwater Champion 

Description of Lease Term Pipelines 

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

 

General Information 

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

Company Name: Freeport-McMoRan Oil & Gas LLC BOEM Operator Number: 03280 

Address: 400 E. Kaliste Saloom Road, Suite 1100 Contact Person: Paul Landry 

 Lafayette, LA 70508 Phone Number: (Office) 337-354-5065; (Mobile) 337-349-7781 

E-Mail Address: paul_landry@fmi.com 

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $14,692 Receipt No. 25IGTOU7 

Project and Worst Case Discharge (WCD) Information 

Lease(s): OCS-G 34999/11080/11081 Area: Green Canyon Block(s) 600/644/645 Project Name: Holstein Deep 

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

Platform / Well Name: NA Total Volume of WCD: 10,057,060 bbls API Gravity: 25.8° 

Distance to Closest Land (Miles): 118 miles Volume from uncontrolled blowout: 77,362 bbls/day 

OCS PLAN INFORMATION FORM 

ATTACHMENT 1-A
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): 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): 77,362 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): N/A API Gravity of fluid 25.8° 

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

separate lines) 

Lease No. OCS-G 11080 OCS 

OCS 

Area Name Green Canyon 

Block No. 644 

Blockline 

Departures 

(in feet) 

N/S Departure 4,400’ FSL N/S Departure 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 5,799’ FEL E/W Departure 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 2,433,561’ X: 

X: 

X: 

X: 

Y: 9,920,240’ Y: 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 27° 18’ 59.608” N Latitude 

Latitude 

Latitude 

Latitude 

Longitude 90° 33’ 25.078” W Longitude 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 4,205’ 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

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): B 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): 77,362 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): N/A API Gravity of fluid 25.8° 

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

separate lines) 

Lease No. OCS-G 11080 OCS 

OCS 

Area Name Green Canyon 

Block No. 644 

Blockline 

Departures 

(in feet) 

N/S Departure 6,000’ FSL N/S Departure 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 2,999’ FEL E/W Departure 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 2,436,361’ X: 

X: 

X: 

X: 

Y: 9,921,840’ Y: 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 27° 19’ 14.901” N Latitude 

Latitude 

Latitude 

Latitude 

Longitude 90° 32’ 53.705” W Longitude 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 4,255’ 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
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): C 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): 77,362 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): N/A API Gravity of fluid 25.8° 

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

separate lines) 

Lease No. OCS-G 11081 OCS 

OCS 

Area Name Green Canyon 

Block No. 645 

Blockline 

Departures 

(in feet) 

N/S Departure 1,587’ FNL N/S Departure 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 5,280’ FWL E/W Departure 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 2,444,640’ X: 

X: 

X: 

X: 

Y: 9,930,093’ Y: 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 27° 20’ 34.967” N Latitude 

Latitude 

Latitude 

Latitude 

Longitude 90° 31’ 20.151” W Longitude 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 4,460’ 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
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): 77,362 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): N/A API Gravity of fluid 25.8° 

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

separate lines) 

Lease No. OCS-G 11081 OCS 

OCS 

Area Name Green Canyon 

Block No. 645 

Blockline 

Departures 

(in feet) 

N/S Departure 1,501’ FNL N/S Departure 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 5,341’ FWL E/W Departure 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 2,444,701’ X: 

X: 

X: 

X: 

Y: 9,930,179’ Y: 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 27° 20’ 35.806” N Latitude 

Latitude 

Latitude 

Latitude 

Longitude 90° 31’ 19.456” W Longitude 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 4,460’ 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
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): E 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): 77,362 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): N/A API Gravity of fluid 25.8° 

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

separate lines) 

Lease No. OCS-G 34999 OCS 

OCS 

Area Name Green Canyon 

Block No. 600 

Blockline 

Departures 

(in feet) 

N/S Departure 4,290’ FNL N/S Departure 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 730’ FEL E/W Departure 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 2,438.630’ X: 

X: 

X: 

X: 

Y: 9,943,230’ Y: 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 27° 22’ 46.170” N Latitude 

Latitude 

Latitude 

Latitude 

Longitude 90° 32’ 23.884” W Longitude 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 4,485’ 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 
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): F 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): 77,362 

bbls/day 

For structures, volume of all storage and pipelines 

(Bbls): N/A API Gravity of fluid 25.8° 

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

separate lines) 

Lease No. OCS-G 34999 OCS 

OCS 

Area Name Green Canyon 

Block No. 600 

Blockline 

Departures 

(in feet) 

N/S Departure 4,370’ FNL N/S Departure 

N/S Departure F __ L 

N/S Departure F __ L 

N/S Departure F __ L 

E/W Departure 660’ FEL E/W Departure 

E/W Departure F __ L 

E/W Departure F __ L 

E/W Departure F __ L 

Lambert X-Y 

coordinates 

 

X: 2,438,700’ X: 

X: 

X: 

X: 

Y: 9,943,150’ Y: 

Y: 

Y: 

Y: 

Latitude/ 

Longitude 

Latitude 27° 22’ 45.364” N Latitude 

Latitude 

Latitude 

Latitude 

Longitude 90° 32’ 23.126” W Longitude 

Longitude 

Longitude 

Longitude 

Water Depth (Feet): 4,485’ 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
OCS-G-11080

FREEPORT-McMoRan

GC688 GC645

GC644 GC643

GC600

OCS-G-11080

Well #1

OCS-G-11080

BLOCK 644, GREEN CANYON AREA

GC644 "A" 4,400' FSL 5,799' FEL 2,433,561' 9,920,240' 
1 
:

PROPOSED SURFACE LOCATIONS

BLOCK WELL CALLS X COORDINATE Y COORDINATE LATITUDE LONGITUDE

JOB No: REVISED: DATE:

FILENAME:

140501 Jul. 11, 2014

GC644 "B" 6,000' FSL 2,999' FEL 2,436,361' 9,921,840' 
1 
:

WELL "A" LOCATION

OCS-G-11080

WELL "B" LOCATION

OCS-G-11080

2000 0 2000

SCALE IN US SURVEY FEET

NAD27

ZONE 15 NORTH

4,255'

4,205'
OCS-G-11081

FREEPORT-McMoRan GC644

OCS-G-11081

BLOCK 645, GREEN CANYON AREA

GC645 "C" 1,587' FNL 5,280' FWL 2,444,640' 9,930,093' 
1 
:

PROPOSED SURFACE LOCATIONS

BLOCK WELL CALLS X COORDINATE Y COORDINATE LATITUDE LONGITUDE

JOB No: REVISED: DATE:

FILENAME:

140501 Jul. 11, 2014

GC645 "D" 1,501' FNL 5,341' FWL 2,444,701' 9,930,179' 
1 
:

WELL "C" LOCATION

OCS-G-11081 WELL "D" LOCATION

OCS-G-11081

2000 0 2000

SCALE IN US SURVEY FEET

NAD27

ZONE 15 NORTH

GC689

GC645

GC601 GC646

4,460'

4,460'
OCS-G-34999

FREEPORT-McMoRan GC599

GC644

OCS-G-34999

BLOCK 600, GREEN CANYON AREA

GC600 "E" 4,290' FNL 730' FEL 2,438,630' 9,943,230' 
1 
:

PROPOSED SURFACE LOCATIONS

BLOCK WELL CALLS X COORDINATE Y COORDINATE LATITUDE LONGITUDE

JOB No: REVISED: DATE:

FILENAME:

140501 Jul. 11, 2014

GC600 "F" 4,370' FNL 660' FEL 2,438,700' 9,943,150' 
1 
:

WELL "E" LOCATION

OCS-G-34999

WELL "F" LOCATION

OCS-G-34999

2000 0 2000

SCALE IN US SURVEY FEET

NAD27

ZONE 15 NORTH

GC556 GC601

GC600

4,485'

4,485'
...\600_644_Bathy.dgn
...\GC\Holstein Deep\645_Bathy.dgn
1

Favaloro, Katharine

From: pay.gov.clev@clev.frb.org

Sent: Wednesday, November 19, 2014 10:55 AM

To: Favaloro, Katharine

Subject: Pay.gov Payment Confirmation: BOEM Exploration Plan - BF

Your payment has been submitted to Pay.gov and the details are below. If you have any questions regarding this 

payment, please contact Brenda Dickerson at (703) 787-1617 or by email at BseeAccountsReceivable@bsee.gov. 

 Application Name: BOEM Exploration Plan - BF 

 Pay.gov Tracking ID: 25IGTOU7 

 Agency Tracking ID: 74709945340 

 Transaction Type: Sale 

 Transaction Date: 11/19/2014 11:55:09 AM EST 

 

 Account Holder Name: Katharine Favaloro 

 Transaction Amount: $14,692.00 

 Billing Address: 700 Milam, Suite 3100 

 City: Houston 

 State/Province: TX 

 Zip/Postal Code: 77002 

 Country: USA 

 Card Type: MasterCard 

 Card Number: ************6901 

 Region: Gulf of Mexico 

 Contact: Paul Landry 337-354-5065 

 Company Name/No: Freeport-McMoRan Oil Gas LLC, 03280 

 Lease Number(s): 34999, 11080, 11081, , 

 Area-Block: Green Canyon GC, 600: Green Canyon GC, 644: Green Canyon GC, 645: , : , 

 Surface Locations: 4 

THIS IS AN AUTOMATED MESSAGE. PLEASE DO NOT REPLY.
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 3 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 2 

GENERAL INFORMATION 

2.1 APPLICATIONS AND PERMITS 

The table below provides 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 

Application for Permit to Modify 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 FM O&G plans 

to use to drill the proposed wells. 

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

Used per Well (bbl) 

Water-based (seawater, freshwater, barite) 60,000 

Oil-based (diesel, mineral oil) NA 

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.

2.4 BONDING STATEMENT 

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

area-wide bond, furnished and maintained according to 30 CFR 556, Subpart I; NTL No. 2000-

G16, "Guidelines for General Lease Surety Bonds;" and a current BOEM-approved deferment 

from providing additional security under 30 CFR 556.53(d) and National NTL No. 2008-N07, 

“Supplemental Bond Procedures.” If at any point Freeport-McMoRan Oil & Gas LLC no longer 

qualifies for a supplemental bonding deferment, Freeport-McMoRan Oil & Gas LLC will either 

provide the required additional security or a third party guarantee within 60 days after such 

disqualification. 

2.5 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR) 

Freeport-McMoRan Oil & Gas LLC (Company No. 03280) has demonstrated 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. 

2.6 DEEPWATER WELL CONTROL STATEMENT 

Freeport-McMoRan Oil & Gas LLC (Company No. 03280) has the financial capability to drill a 

relief well and conduct other emergency well control operations. 
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 4 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

2.7 BLOWOUT SCENARIO AND WORST CASE DISCHARGE CALCULATIONS 

The Worst Case Discharge is defined as an uncontrolled blowout through the drilling string 

during drilling operations.

Estimated initial flow rate: The calculated Worst Case Discharge estimate for Green Canyon 

Block 645 Well Location C is 77,362 bbl of crude. 

Maximum duration/total volume that could occur if the Green Canyon Block 645 Well 

Location C sustained a blowout: 

Scenario Maximum Discharge 

Rate (bbl/day) 

Discharge Duration 

(days) 

Total Volume 

Condensate (bbl) 

Relief well 77,362 130 10,057,060 

Potential of wellbore to bridge over during a blowout: 

While the sands anticipated to be encountered by the wells listed in this EP are expected to be 

somewhat consolidated FM O&G does NOT assume that the proposed wells would bridge over 

in a blowout scenario. This assumption is based on work in association with SPE Paper # 

163438 on the analysis of potential bridging scenarios during blowout events in the deep water 

GoM. FM O&G agrees with the conclusions of this SPE paper that the only instances in which a 

deep water well could potentially bridge over is a complete loss of the marine riser hydrostatic 

column resulting in a sharp pressure reduction downhole leading to wellbore collapse before a 

blowout can fully develop. This bridging would occur quickly before large volumes of 

hydrocarbons could escape. As FM O&G does not consider this bridging event to cover all 

blowout scenarios. The Worst Case Discharge calculations for this proposed well will be based 

upon a well flowing until a relief well can be completed. 

Likelihood for surface intervention to stop blowout: 

Location “A” will be drilled in the Green Canyon Block 644 as a subsea well in 4,205 ft of water 

with the wellhead and BOP equipment located on the seabed. Surface intervention would be the 

preferred method in an uncontrolled blowout; however, the technique used is contingent upon 

the rig condition, marine riser system and BOP equipment. Surface intervention is quicker than 

a relief well but actual well control operations would be determined based on site‐specific 

conditions. 

Prior to surface intervention operations, a team of specialists would be mobilized immediately to 

assess the situation and determine a course of action. Well control specialists would assess the 

on-site conditions either by helicopter and/or surface vessel. FM O&G has Master Service 

Agreements with both Wild Well Control (a Superior Energy Services company) and Boots and 

Coots (a Halliburton company). Additionally a ROV capable of manipulating the rig’s BOP 

hot‐stab functions would be mobilized to location and, if appropriate, an attempt would be made 

to shut in the well by closing the blind shear rams, if not done previously. These actions would 

take place within 24 ‐ 48 hours of the incident. Initial assessment activities are projected to take 

3 – 5 days. During this period, the well control team would analyze the blowout situation, devise 

an intervention strategy and mobilize service company specialists, supplies and equipment. FM 

O&G would establish a field support base and secondary command center in the company 
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 5 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

shore base facility in Port Fourchon, LA. Communications would be established with the support 

base and command center. 

Relief Well 

Rig type capable of drilling relief well at water depth and to TD: 

There are more than 10 drilling rigs currently working in the Gulf of Mexico in 2014 that are 

capable of drilling a relief well at these locations. 

The rig chosen to drill the relief well must be: 

 Rated and equipped for water depths > 5,000 ft due to Green Canyon Block 

locations. 

 Dynamically‐positioned to eliminate anchoring issues due to nearby subsea 

infrastructure. 

 Have a BOP package acceptable and certified under current BSEE regulations.

Time to acquired rig, move onsite and drill relief well: 

Activity Duration (days) 

Assess the situation and obtain the optimum 

MODU 

5 

Secure the well at current location of MODU 14 

Mobilization time to relief well location 3 

Drill the relief well 80 

Wellbore intersection (of blown out well) 21 

Dynamic kill operations 7 

Total anticipated time 130 

Statement whether possibility of using nearby platform was considered: 

The Holstein Spar is located in GC Block 645 and is owned and operated by FM O&G. The 

Holstein Spar has a permanent drilling rig installed and has been commissioned for duty. The 

drilling rig is equipped with a derrick rated to 1.0 MM lbs and 3 x 1,600hp mud pumps. 

However, considering the distance required to drill relief well targets, the Holstein Spar rig was 

not deemed practical for relief well operations. All relief well operations will be completed by 

mobilizing a dynamically positioned drilling rig to GC 600/644/645.

Other measures to enhance ability to prevent a blowout: 

 FM O&G will verify with contractor that all BOPs have been certified, maintained and 

are capable of operating in the anticipated conditions required for operations. 

 FM O&G representatives will review and witness the installation, testing, function 

testing and operation of the diverter system and diverter outlets. 

 Key personnel on the rig will have a valid well control certificate. 

 Wiper trips will be performed as hole conditions dictate in order to quantify the 

stability of the wellbore and to determine whether sufficient mud weights are being 

utilized. 

 Connections will be simulated as needed while drilling into pressure transition areas 

in order to properly assess the current wellbore conditions. 
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 6 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

Measures to reduce the likelihood of a blowout: 

 A liner top packer or equivalent expandable will be run on all liner laps as an 

additional barrier for well safety. 

 Lost circulation material will be added to the mud system in order to assist the mud 

system’s ability to prevent lost circulation. Sweeps and concentrated pills will be 

used to prevent uncontrolled mud losses. 

 Every effort will be made to review all offset and seismic data in order to prepare a 

mud weight schedule that will allow for safe drilling margin without putting excess 

hydrostatics pressures on known zones previously encountered. 

 Mudloggers may be utilized during critical drilling operations to monitor gas content 

of mud returns, formation characteristics and abnormalities of cuttings and to 

estimate paleo aging of cuttings. 

 Logging While Drilling (LWD) tools will be utilized as much as possible to evaluate 

formations, formation pressures and fluid content in the critical sections of the well. 

 Log data will be continuously reviewed by FM O&G’s drilling and geological 

departments 

Measures to enhance ability to conduct effective and early intervention in event of a 

blowout: 

 FM O&G is a member of the Helix Well Containment Group (HWCG) and has full 

access to a subsea capping stack and a complete suite of oil recovery equipment as 

required. This subsea capping stack has been deployed successfully to a well 

location with oversight from BSEE. 

Arrangements for drilling relief wells: 

 FM O&G has Master Service Agreements with both Wild Well Control (a Superior 

Energy Services company) and Boots and Coots (a Halliburton company) who would 

assist in detailed relief well planning including the identification of required equipment 

and services.

Any other measures: No
Freeport-McMoRan Oil & Gas LLC Section 3 – Pg. 7 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 3 

GEOLOGICAL AND GEOPHYSICAL INFORMATION 

3.1 GEOLOGICAL DESCRIPTION 

[PROPRIETARY] 

3.2 STRUCTURE CONTOUR MAPS 

[PROPRIETARY] 

3.3 INTERPRETED SEISMIC LINES 

[PROPRIETARY] 

3.4 GEOLOGICAL STRUCTURE CROSS-SECTIONS 

[PROPRIETARY] 

3.5 SHALLOW HAZARDS REPORT 

A shallow hazards survey was conducted over Green Canyon Blocks 600, 644 and 645. 

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

2014-G05, “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 C & C Technologies Survey Services. 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-G05, “Extension of Prior Notices to Lessees”), a shallow hazards assessment has been 

prepared for each proposed surface location 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-A. 

3.7 HIGH-RESOLUTION SEISMIC LINES 

[PROPRIETARY] 

3.8 STRATIGRAPHIC COLUMN 

[PROPRIETARY] 

3.9 TIME VERSUS DEPTH TABLES 

[PROPRIETARY] 
Wellsite Report

C&C Project No. 140501

1

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

July 9, 2014

Freeport-McMoRan Oil & Gas

400 East Kaliste Saloom Road

Suite 1100

Lafayette, LA 70508

Attn: Ms. Mary Broussard

Site Clearance Letter

Proposed Well “A”

Block 644 (OCS-G-11080), Green Canyon Area

Dear Ms. Broussard,

INTRODUCTION

Freeport-McMoRan Oil & Gas (FMOG) contracted C & C Technologies, Inc. (C&C) to prepare 

a wellsite clearance letter for the proposed drilling location of Well “A” in Block 644 (OCS-G11080), Green Canyon (GC) Area. The data used for the site clearance letter is based on the 

interpretation of high-resolution AUV datasets collected by C&C and an exploration-quality 3D 

seismic volume licensed by FMOG. C&C completed the reports titled “3D Seismic Shallow 

Geohazard Report, Blocks 599 (OCS-G-34998) and 643 (OCS-G-35001), Green Canyon Area” 

in July 2013 and “Archaeological Assessment, Blocks 599 (OCS-G-34998), 600 (OCS-G-34999), 

643 (OCS-G-35001), 644 (OCS-G-11080), 645 (OCS-G-11081), 689 (OCS-G-35002), 733 

(OCS-G-35004), and 777 (OCS-G-35007), Green Canyon Area” in August, 2013. This site 

clearance letter is based on the findings provided within these reports. A drill ship is being 

proposed for drilling this well. 

This letter provides a top-hole drilling prognosis and addresses seafloor conditions within a 

2,000-foot radius of the proposed Well “A” location. The depth limit of this investigation is 

approximately 4,000 feet below the seafloor (BSF). This assessment and enclosures presented 

with this letter comply with the U.S. Department of Interior’s Bureau of Ocean Energy 

Management (BOEM) and Bureau of Safety and Environmental Enforcement (BSEE) Notice To 

Lessees (NTL) No. 2008-G05 (Shallow Hazards Program), NTL No. 2005-G07 (Archaeology),

and NTL No. 2009-G40 (Deepwater Benthic Communities).

METHODS

The high-resolution AUV datasets were collected using C & C Technologies’ C-Surveyor IIITM

AUV. The AUV remote-sensing instruments include a Simrad EM2000 Swath Bathymetric 

Mapping System (200 kHz), an EdgeTech Dynamically-Focused Side Scan Sonar (230 kHz), 

and an EdgeTech Subbottom Profiler System (1.5 to 4.5 kHz). In general, the AUV survey grid 

pattern consisted of parallel north-south primary tracklines and parallel east-west tie lines. The 

primary trackline spacing was 200 meters (656.17 feet) and the tie lines were spaced at 900 

meters (2,952.75 feet). 
Wellsite Report

C&C Project No. 140501

2

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

FMOG provided an exploration-quality 3D seismic data volume in SEG-Y format. The 3D data 

were acquired by CGG in December 2003 to February 2004. The time volume dataset was 

processed at a 4-millisecond sample rate. The inlines and crosslines of the 3D data volume run 

east to west and north to south, respectively. The inlines are spaced 65.62-foot (20-meter) 

intervals, while the crosslines are spaced 82.02 feet (25 meters). The inlines and crosslines are 

depicted in panel 4 on the study map. The 3D seismic dataset is a zero phase wavelet with a zero 

phase rotation and the seafloor reflector is represented by a strong, positive amplitude peak 

flanked by troughs with absolute amplitude values of approximately one-half of the peak value. 

Amplitude values are represented by IBM 32-bit floating-point numbers, identified during data 

loading. The seismic data provided were adequate for regional screening of the seafloor and 

shallow geologic conditions, and large scale geohazards (faults, salt, high acoustic impedance, 

stratigraphic horizons, etc.).

The 3D seismic data used for this wellsite assessment were provided in SEG-Y format. The data 

were loaded into IHS’s Kingdom Suite 2D/3D Pak, Version 8.8 for interpretation. Spectral 

whitening was applied to the 3D seismic dataset to amplify the higher frequencies. After 

applying the spectral whitening, a power spectrum generated at the wellsite proposed location 

indicated the seismic data volume contains sufficiently high frequency content for a shallow 

hazards assessment (Figure No. 1).

WELL LOCATION

The coordinates and calls for Well “A” surface location is tabulated below: 

Table 1. Proposed GC644 Well “A”

Well XCoordinate

YCoordinate

Latitude Longitude Calls From Block 644,

Green Canyon Area

“A” 2,433,561 9,920,240’ 27°18’59.608” N 90°33’25.078” W 5,799’ FEL 4,400’ FSL

The geodetic datum used to generate the study maps is the North American Datum of 1927 

(NAD27) on the Clarke 1866 ellipsoid, and projected using the Universal Transverse Mercator 

(UTM), Zone 15 North (15N). All coordinates given are presented in this projection on the study 

map and included with this letter. All grid units, as well as scales and measurements are in U.S. 

survey feet. The proposed surface hole location of Well “A” and the 2,000-foot radius are 

displayed on the study map. 

BATHYMETRY AND SEAFLOOR GRADIENTS

Bathymetry was processed using the AUV multibeam and shown on the study map (Panel 1) at 

10-foot contour intervals. The bathymetry indicates the water depth at the proposed Well “A”

location is 4,205 feet Mean Seal Level (MSL). Within the 2,000-foot radius, the seafloor depth 

ranges from 4,125 feet MSL in the northwest to 4,260 feet MSL in the east (Panel 1). The 

seafloor is smooth within the vicinity of the proposed well. The seafloor at the proposed Well 

“A” location slopes to the southeast at an average gradient of 1.8°. 
Wellsite Report

C&C Project No. 140501

3

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

SEAFLOOR SEDIMENTS AND HAZARDS

The side scan sonar images (Panel 2; Figure No. 2) exhibit primarily low to moderate acoustic 

reflectivity. Additionally, the 3D seafloor amplitude image (Panel 3) displays a range of low to 

moderate acoustic amplitudes within the 2,000-foot radius. These low to moderate acoustic 

reflectivity and seafloor amplitudes indicate finely textured seafloor sediments likely comprised 

of hemipelagic clay (very soft silty clay). 

There are no seafloor drilling hazards detected on the side scan sonar images and 3D data within 

the 2,000-foot radius of the proposed well. The side scan sonar images (Figure No. 2) show an 

anchor scar or fishing trawl crossing the proposed Well “A” location.

POTENTIAL BENTHIC COMMUNITIES

High-amplitude seismic seafloor anomalies are a potential indicator of carbonates and benthic 

community habitats. The seafloor at the proposed Well “A” location and surrounding 2,000-foot 

radius contains no high negative or positive amplitude anomalies associated with fluid expulsion 

or mounded carbonates representing potential benthic communities (Panels 3 and 4). 

MAN-MADE HAZARDS

A review of the C&C database shows an existing well, a permitted pipeline, several proposed 

pipelines and several mooring lines within the vicinity of the proposed Well “A” location. Well 

No. 1 (OCS-G-11080) is located 6,800 feet northeast of the proposed well. The permitted S18958 Enbridge 20-Inch Pipeline is located greater than 4,000 feet north of the proposed well. 

The proposed FMOG Production Flowline and Riser are located greater than 2,700 feet north of 

the proposed well. The existing Holstein mooring lines are greater than 4,000 feet east of the 

proposed well. 

SUBSURFACE GEOHAZARDS AND STRATIGRAPHY

Six (6) units (Units A to F), each consisting of one or more distinctive sequences, were 

interpreted within the study area from the 3D seismic data to approximately 4,000 feet BSF. Six 

horizons mark the upper and / or lower contacts of each of the successive units (Figure Nos. 3, 4

and 5). FMOG provided C&C with a checkshot dataset consisting of time-depth pairs for the 

sediment column at the GC643 Well No. 1 (OCS-G-16772). The following polynomial equation 

was derived from Total Vertical Depth (TVD) and the corresponding two-way traveltime (TWT) 

using the time-depth values to calculate depths below the sea level:

Y = 516.29T

2

+ 1570.4T

Where Y = depth below seafloor in feet and T = two-way traveltime below sea level in seconds.

A detailed description of the sequence units can be found in the 2013 3D Seismic Shallow 

Geohazard Report. The Top-Hole Prognosis Chart (Figure No. 6) summarizes the stratigraphy. 

Unit A (Seafloor to Event 1): Unit A consists of continuous, low to moderate amplitude seismic 

reflectors (Figure Nos. 3, 4, and 5). Amplitudes and acoustic impedance contrasts tend to be 

moderate to low. These reflection patterns are likely comprised of hemipelagic clay, laid down 

as a drape deposit, and interbedded with fine-grained turbidites and some sands. Additionally, 
Wellsite Report

C&C Project No. 140501

4

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

the AUV subbottom profiler shows the drape deposits are interbedded with shallow buried mass 

transport deposits (Figure No. 3) and are greater than 81 feet BSF. At the proposed Well “A”

location, the clay sequence is 429 feet thick. 

Unit B (Event 1 to Event 2): Unit B consists of low to moderate amplitude, semi-continuous to 

chaotic reflectors that are 525 feet thick at the proposed Well “A” location (Figure Nos. 4 and 5). 

These reflection patterns are likely comprised of hemipelagic clay, laid down as a drape deposit 

with interbedded mud-prone mass movement deposits and turbidite channels at the base of the 

unit.

Unit C (Event 2 to Event 3): At the proposed Well “A” location, Unit C is 949 feet thick of 

variable amplitude, semi-continuous to chaotic acoustic reflections (Figure Nos. 4 to 5). Unit C 

sediments are interpreted as sediments of muds interbedded with thin mud-prone mass 

movement deposits and channeling that may contain sands. 

Unit D (Event 3 to Event 4): Unit D consists of low to moderate amplitude, continuous to 

chaotic reflectors and is 929 feet thick at the proposed Well “A” location. The sediments in Unit 

D are interpreted as thin sequences of turbidite mud and sands with interlayered muds and thin 

mud-prone mass movement deposits that may contain sands.

Unit E (Event 4 to Event 5): At the proposed Well “A” location, Unit E is 1,909 feet thick of 

low to moderate amplitude, parallel continuous to chaotic reflectors with isolated high amplitude 

reflectors (Figure Nos. 4 and 5). Unit E sediments are interpreted as muds interbedded with thin 

mud-prone mass movement deposits and channeling that may contain sands. 

Unit F (Horizon 5 to Horizon 6): Unit F consists of low to moderate amplitude, semi-continuous 

to chaotic reflectors that are 4,340 feet thick at the proposed Well “A” location (Figure Nos. 4

and 5). The sediments in Unit F are interpreted as interbedded silts and clays with thin mudprone mass movement deposits and channeling that may contain sands. 

FAULTS

Several buried faults are located within the proposed Well “A” 2,000-feet radius. The proposed 

well bore path does cross a fault at 6,743 BSL (2,538 BSF).

SHALLOW GAS AND GAS HYDRATES

Very high-amplitude seismic anomalies are interpreted as potential regions of fluid / gas 

saturation usually associated with porous sands. Shallow gas is interpreted with the seismic 

amplitude levels and the gas risk is assessed as being at one of the following four levels. 

 Negligible - No amplitude anomalies or other gas indicators present.

 Low risk of gas - Generally indicated by increased amplitude (2-3x background 

level) and phase reversal. This may also include diffuse areas of gas blanking.

 Moderate risk of gas - Generally indicated by high amplitude (3-4x background 

level) and phase reversal.

 High risk of gas - Generally indicated by the highest amplitudes (in excess of 

4x background level), phase reversal, and a combination of other attributes 
Wellsite Report

C&C Project No. 140501

5

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

indicative of the presence of gas, particularly velocity pull-down and masking of 

underlying sediments. Stratigraphic and structural settings may also be taken 

into account.

Within 2,000 feet of the proposed Well “A” location, several subsurface amplitude anomalies are 

noted within Unit E at depths ranging from 5,334 to 10,199 feet BSF. These anomalies are 

located greater than 300 feet west and greater than 1,600 feet northeast of the proposed well bore 

path (Panel 4). A negligible to low risk of shallow gas (Figure No. 6) exists along the shallow 

section of the well bore for Well “A”. The well bore path will not penetrate any high-amplitude 

anomalies between the seafloor and the base of the study (Figure No. 6). 

There is no indication of BSRs within the study area.

SHALLOW WATER FLOW

The BOEM database does indicate GC644 Well No. 1 (OCS-G-11080) at a water depth of 4,292 

feet BSL experienced a minor SWF at 638 feet BSF.

The overall risk of shallow water flow is negligible to moderate at the proposed Well “A”

location (Figure No. 6). An examination of the 3D seismic dataset indicates Units B, E, and F

are comprised of chaotic reflectors showing high impedance contrast, suggesting a moderate 

potential for SWF. Unit C and D exhibit a low risk of SWF, and Unit A shows a negligible risk 

of SWF. At present there is no method of quantifying the risk of SWFs, so caution is 

recommended when drilling through the potential SWF units. 

CONCLUSIONS

The proposed Well “A” surface location has a water depth of 4,205 MSL and is clear of 

geological constraints. No significant seafloor features are located at or within 2,000 feet of the 

proposed well that could interfere with drilling activities. 

No high or low seafloor amplitude anomalies indicating the occurrence of hardgrounds, 

carbonates, benthic communities, or potential expulsions, are found within 2,000 feet of the 

proposed Well “A” location. 

No infrastructure exists, permitted, or proposed within 2,000 feet of the proposed Well “A”

location. 

At the proposed well location, the well bore path will intersect a fault plane at 6,743 feet BSF 

(2,538 feet BSF). 

The assessment of seismic profiles suggests stratigraphic units exhibit a negligible to moderate 

(Units B, E, and F) risk for SWF and a negligible to low (Units E and F) potential for gas at the 

Well “A” drill site. 

Thank you for this opportunity to be of service. Please contact us if you have any questions 

concerning this assessment.
Wellsite Report

C&C Project No. 140501

6

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Sincerely yours,

James Cox

Geophysicist

Enclosures

Figure No. 1. Extracted wavelet and power spectrum at the proposed Well “A” location.

Figure No. 2. Nearest side scan sonar image (Line 140) from the proposed Well “A” location.

Figure No. 3. Nearest subbottom profile record (Line 140) from the proposed Well “A” location.

Figure No. 4. Nearest 3D seismic Inline (3622) from the proposed Well “A” location.

Figure No. 5. Nearest 3D seismic Crossline (5869) from the proposed Well “A” location.

Figure No. 6. Top-hole Prognosis Chart for the proposed Well “A” location.

Sheet 1. Proposed Well “A” & “B” Locations 

Wellsite Report

C&C Project No. 140501

1

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

July 9, 2014

Freeport-McMoRan Oil & Gas

400 East Kaliste Saloom Road

Suite 1100

Lafayette, LA 70508

Attn: Ms. Mary Broussard

Site Clearance Letter

Proposed Well “B”

Block 644 (OCS-G-11080), Green Canyon Area

Dear Ms. Broussard,

INTRODUCTION

Freeport-McMoRan Oil & Gas (FMOG) contracted C & C Technologies, Inc. (C&C) to prepare 

a wellsite clearance letter for the proposed drilling location of Well “B” in Block 644 (OCS-G11080), Green Canyon (GC) Area. The data used for the site clearance letter is based on the 

interpretation of high-resolution AUV datasets collected by C&C and an exploration-quality 3D 

seismic volume licensed by FMOG. C&C completed the reports titled “3D Seismic Shallow 

Geohazard Report, Blocks 599 (OCS-G-34998) and 643 (OCS-G-35001), Green Canyon Area” 

in July 2013 and “Archaeological Assessment, Blocks 599 (OCS-G-34998), 600 (OCS-G-34999), 

643 (OCS-G-35001), 644 (OCS-G-11080), 645 (OCS-G-11081), 689 (OCS-G-35002), 733 

(OCS-G-35004), and 777 (OCS-G-35007), Green Canyon Area” in August, 2013. This site 

clearance letter is based on the findings provided within these reports. A drill ship is being 

proposed for drilling this well. 

This letter provides a top-hole drilling prognosis and addresses seafloor conditions within a 

2,000-foot radius of the proposed Well “B” location. The depth limit of this investigation is 

approximately 4,000 feet below the seafloor (BSF). This assessment and enclosures presented 

with this letter comply with the U.S. Department of Interior’s Bureau of Ocean Energy 

Management (BOEM) and Bureau of Safety and Environmental Enforcement (BSEE) Notice To 

Lessees (NTL) No. 2008-G05 (Shallow Hazards Program), NTL No. 2005-G07 (Archaeology),

and NTL No. 2009-G40 (Deepwater Benthic Communities).

METHODS

The high-resolution AUV datasets were collected using C & C Technologies’ C-Surveyor IIITM

AUV. The AUV remote-sensing instruments include a Simrad EM2000 Swath Bathymetric 

Mapping System (200 kHz), an EdgeTech Dynamically-Focused Side Scan Sonar (230 kHz), 

and an EdgeTech Subbottom Profiler System (1.5 to 4.5 kHz). In general, the AUV survey grid 

pattern consisted of parallel north-south primary tracklines and parallel east-west tie lines. The 

primary trackline spacing was 200 meters (656.17 feet) and the tie lines were spaced at 900 

meters (2,952.75 feet). 
Wellsite Report

C&C Project No. 140501

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

FMOG provided an exploration-quality 3D seismic data volume in SEG-Y format. The 3D data 

were acquired by CGG in December 2003 to February 2004. The time volume dataset was 

processed at a 4-millisecond sample rate. The inlines and crosslines of the 3D data volume run 

east to west and north to south, respectively. The inlines are spaced 65.62-foot (20-meter) 

intervals, while the crosslines are spaced 82.02 feet (25 meters). The inlines and crosslines are 

depicted in panel 4 on the study map. The 3D seismic dataset is a zero phase wavelet with a zero 

phase rotation and the seafloor reflector is represented by a strong, positive amplitude peak 

flanked by troughs with absolute amplitude values of approximately one-half of the peak value. 

Amplitude values are represented by IBM 32-bit floating-point numbers, identified during data 

loading. The seismic data provided were adequate for regional screening of the seafloor and 

shallow geologic conditions, and large scale geohazards (faults, salt, high acoustic impedance, 

stratigraphic horizons, etc.).

The 3D seismic data used for this wellsite assessment were provided in SEG-Y format. The data 

were loaded into IHS’s Kingdom Suite 2D/3D Pak, Version 8.8 for interpretation. Spectral 

whitening was applied to the 3D seismic dataset to amplify the higher frequencies. After 

applying the spectral whitening, a power spectrum generated at the wellsite proposed location 

indicated the seismic data volume contains sufficiently high frequency content for a shallow 

hazards assessment (Figure No. 1).

WELL LOCATION

The coordinates and calls for Well “B” surface location is tabulated below: 

Table 1. Proposed GC644 Well “B”

Well XCoordinate

YCoordinate

Latitude Longitude Calls From Block 644,

Green Canyon Area

“B” 2,436,361’ 9,921,840’ 27°19’14.901” N 90°32’53.705” W 2,999’ FEL 6,000’ FSL

The geodetic datum used to generate the study maps is the North American Datum of 1927 

(NAD27) on the Clarke 1866 ellipsoid, and projected using the Universal Transverse Mercator 

(UTM), Zone 15 North (15N). All coordinates given are presented in this projection on the study 

map and included with this letter. All grid units, as well as scales and measurements are in U.S. 

survey feet. The proposed surface hole location of Well “B” and the 2,000-foot radius are 

displayed on the study map. 

BATHYMETRY AND SEAFLOOR GRADIENTS

Bathymetry was processed using the AUV multibeam and shown on the study map (Panel 1) at 

10-foot contour intervals. The bathymetry indicates the water depth at the proposed Well “B”

location is 4,255 feet Mean Seal Level (MSL). Within the 2,000-foot radius, the seafloor depth 

ranges from 4,205 feet MSL in the northwest to 4,315 feet MSL in the east (Panel 1). The 

seafloor is smooth within the vicinity of the proposed well. The seafloor at the proposed Well 

“B” location slopes to the southeast at an average gradient of 1.7°. 
Wellsite Report

C&C Project No. 140501

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

SEAFLOOR SEDIMENTS AND HAZARDS

The side scan sonar images (Panel 2; Figure No. 2) exhibit primarily low to moderate acoustic 

reflectivity. Additionally, the 3D seafloor amplitude image (Panel 3) displays a range of low to 

moderate acoustic amplitudes within the 2,000-foot radius. These low to moderate acoustic 

reflectivity and seafloor amplitudes indicate finely textured seafloor sediments likely comprised 

of hemipelagic clay (very soft silty clay). 

There are no seafloor drilling hazards detected on the side scan sonar images and 3D data within 

the 2,000-foot radius of the proposed well. 

POTENTIAL BENTHIC COMMUNITIES

High-amplitude seismic seafloor anomalies are a potential indicator of carbonates and benthic 

community habitats. The seafloor at the proposed Well “B” location and surrounding 2,000-foot 

radius contains no high negative or positive amplitude anomalies associated with fluid expulsion 

or mounded carbonates representing potential benthic communities (Panels 3 and 4). 

MAN-MADE HAZARDS

A review of the C&C database shows an existing well, a permitted pipeline, several proposed 

pipelines and several mooring lines within the vicinity of the proposed Well “B” location. Well 

No. 1 (OCS-G-11080) is located 4,600 feet northeast of the proposed well. The permitted S18958 Enbridge 20-Inch Pipeline is located greater than 5,800 feet north of the proposed well. 

The proposed FMOG Production Flowline and Riser are located greater than 600 feet north of 

the proposed well. The existing Holstein mooring lines are greater than 4,000 feet east of the 

proposed well. 

SUBSURFACE GEOHAZARDS AND STRATIGRAPHY

Six (6) units (Units A to F), each consisting of one or more distinctive sequences, were 

interpreted within the study area from the 3D seismic data to approximately 4,000 feet BSF. Six 

horizons mark the upper and / or lower contacts of each of the successive units (Figure Nos. 3, 4

and 5). FMOG provided C&C with a checkshot dataset consisting of time-depth pairs for the 

sediment column at the GC643 Well No. 1 (OCS-G-16772). The following polynomial equation 

was derived from Total Vertical Depth (TVD) and the corresponding two-way traveltime (TWT) 

using the time-depth values to calculate depths below the sea level:

Y = 516.29T

2

+ 1570.4T

Where Y = depth below seafloor in feet and T = two-way traveltime below sea level in seconds.

A detailed description of the sequence units can be found in the 2013 3D Seismic Shallow 

Geohazard Report. The Top-Hole Prognosis Chart (Figure No. 6) summarizes the stratigraphy. 

Unit A (Seafloor to Event 1): Unit A consists of continuous, low to moderate amplitude seismic 

reflectors (Figure Nos. 3, 4, and 5). Amplitudes and acoustic impedance contrasts tend to be 

moderate to low. These reflection patterns are likely comprised of hemipelagic clay, laid down 

as a drape deposit, and interbedded with fine-grained turbidites and some sands. Additionally, 

the AUV subbottom profiler shows the drape deposits are interbedded with shallow buried mass 
Wellsite Report

C&C Project No. 140501

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

transport deposits (Figure No. 3) and are buried greater than 81 feet BSF. At the proposed Well 

“B” location, the clay sequence is 480 feet thick. 

Unit B (Event 1 to Event 2): Unit B consists of low to moderate amplitude, semi-continuous to 

chaotic reflectors that are 590 feet thick at the proposed Well “B” location (Figure Nos. 4 and 5). 

These reflection patterns are likely comprised of hemipelagic clay, laid down as a drape deposit 

with interbedded mud-prone mass movement deposits and turbidite channels at the base of the 

unit.

Unit C (Event 2 to Event 3): At the proposed Well “B” location, Unit C is 1,000 feet thick of 

variable amplitude, semi-continuous to chaotic acoustic reflections (Figure Nos. 4 to 5). Unit C 

sediments are interpreted as sediments of muds interbedded with thin mud-prone mass 

movement deposits and channeling that may contain sands. 

Unit D (Event 3 to Event 4): Unit D consists of low to moderate amplitude, continuous to 

chaotic reflectors and is 1,102 feet thick at the proposed Well “B” location. The sediments in 

Unit D are interpreted as thin sequences of turbidite mud and sands with interlayered muds and 

thin mud-prone mass movement deposits that may contain sands.

Unit E (Event 4 to Event 5): At the proposed Well “B” location, Unit E is 1,853 feet thick of 

low to moderate amplitude, parallel continuous to chaotic reflectors with isolated high amplitude 

reflectors (Figure Nos. 4 and 5). Unit E sediments are interpreted as muds interbedded with thin 

mud-prone mass movement deposits and channeling that may contain sands. 

Unit F (Horizon 5 to Horizon 6): Unit F consists of low to moderate amplitude, semi-continuous 

to chaotic reflectors that are 4,850 feet thick at the proposed Well “B” location (Figure Nos. 4

and 5). The sediments in Unit F are interpreted as interbedded silts and clays with thin mudprone mass movement deposits and channeling that may contain sands. 

FAULTS

Several buried faults are located within the proposed Well “B” 2,000-feet radius. However, the 

proposed well bore path does not cross any major faults.

SHALLOW GAS AND GAS HYDRATES

Very high-amplitude seismic anomalies are interpreted as potential regions of fluid / gas 

saturation usually associated with porous sands. Shallow gas is interpreted with the seismic 

amplitude levels and the gas risk is assessed as being at one of the following four levels. 

 Negligible - No amplitude anomalies or other gas indicators present.

 Low risk of gas - Generally indicated by increased amplitude (2-3x background 

level) and phase reversal. This may also include diffuse areas of gas blanking.

 Moderate risk of gas - Generally indicated by high amplitude (3-4x background 

level) and phase reversal.

 High risk of gas - Generally indicated by the highest amplitudes (in excess of 

4x background level), phase reversal, and a combination of other attributes 

indicative of the presence of gas, particularly velocity pull-down and masking of 
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C&C Project No. 140501

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

underlying sediments. Stratigraphic and structural settings may also be taken 

into account.

Within 2,000 feet of the proposed Well “B” location, several subsurface amplitude anomalies are 

noted within Unit E at depths ranging from 5,334 to 10,199 feet BSF. These anomalies are 

located greater than 300 feet west and greater than 1,600 feet northeast of the proposed well bore 

path (Panel 4). A negligible to low risk of shallow gas (Figure No. 6) exists along the shallow 

section (Units A to D) of the well bore for Well “B”. The Top-Hole Prognosis Chart (Figure No. 

6) shows the bottom of Unit D has a moderate risk of shallow gas due to channeling at the base 

of the unit. The well bore path will not penetrate any high-amplitude anomalies between the 

seafloor and the base of the study (Figure No. 6). 

There is no indication of BSRs within the study area.

SHALLOW WATER FLOW

The BOEM database does indicate GC644 Well No. 1 (OCS-G-11080) at a water depth of 4,292 

feet BSL experienced a minor SWF at 638 feet BSF.

The overall risk of shallow water flow is negligible to moderate at the proposed Well “B”

location (Figure No. 6). An examination of the 3D seismic dataset indicates Units B, E, and F

are comprised of chaotic reflectors showing high impedance contrast, suggesting a moderate 

potential for SWF. Unit C and D exhibit a low risk of SWF, and Unit A shows a negligible risk 

of SWF. At present there is no method of quantifying the risk of SWFs, so caution is 

recommended when drilling through the potential SWF units. 

CONCLUSIONS

The proposed Well “B” surface location has a water depth of 4,255 MSL and is clear of 

geological constraints. No significant seafloor features are located at or within 2,000 feet of the 

proposed well that could interfere with drilling activities. 

No high or low seafloor amplitude anomalies indicating the occurrence of hardgrounds, 

carbonates, benthic communities, or potential expulsions, are found within 2,000 feet of the 

proposed Well “B” location. 

No infrastructure exists, permitted, or proposed within 2,000 feet of the proposed Well “B”

location. 

The proposed well location will not intersect any major faults along the well bore path. 

The assessment of seismic profiles suggests stratigraphic units exhibit a negligible to moderate 

(Units B, E, and F) risk for SWF and a negligible to moderate (Unit D) potential for gas at the 

Well “B” drill site. 
Wellsite Report

C&C Project No. 140501

6

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Thank you for this opportunity to be of service. Please contact us if you have any questions 

concerning this assessment.

Sincerely yours,

James Cox

Geophysicist

Enclosures

Figure No. 1. Extracted wavelet and power spectrum at the proposed Well “B” location.

Figure No. 2. Nearest side scan sonar image (Line 179) from the proposed Well “B” location.

Figure No. 3. Nearest subbottom profile record (Line 179) from the proposed Well “B” location.

Figure No. 4. Nearest 3D seismic Inline (3651) from the proposed Well “B” location.

Figure No. 5. Nearest 3D seismic Crossline (5903) from the proposed Well “B” location.

Figure No. 6. Top-hole Prognosis Chart for the proposed Well “B” location.

Sheet 1. Proposed Well “A” & “B” Locations 

Wellsite Report

C&C Project No. 140501

1

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

July 9, 2014

Freeport-McMoRan Oil & Gas

400 East Kaliste Saloom Road

Suite 1100

Lafayette, LA 70508

Attn: Ms. Mary Broussard

Site Clearance Letter

Proposed Well “C”

Block 645 (OCS-G-11081), Green Canyon Area

Dear Ms. Broussard,

INTRODUCTION

Freeport-McMoRan Oil & Gas (FMOG) contracted C & C Technologies, Inc. (C&C) to prepare 

a wellsite clearance letter for the proposed drilling location of Well “C” in Block 645 (OCS-G11081), Green Canyon (GC) Area. The data used for the site clearance letter is based on the 

interpretation of high-resolution AUV datasets collected by C&C and an exploration-quality 3D 

seismic volume licensed by FMOG. C&C completed the reports titled “3D Seismic Shallow 

Geohazard Report, Blocks 599 (OCS-G-34998) and 643 (OCS-G-35001), Green Canyon Area” 

in July 2013 and “Archaeological Assessment, Blocks 599 (OCS-G-34998), 600 (OCS-G-34999), 

643 (OCS-G-35001), 644 (OCS-G-11080), 645 (OCS-G-11081), 689 (OCS-G-35002), 733 

(OCS-G-35004), and 777 (OCS-G-35007), Green Canyon Area” in August, 2013. This site 

clearance letter is based on the findings provided within these reports. A drill ship is being 

proposed for drilling this well. 

This letter provides a top-hole drilling prognosis and addresses seafloor conditions within a 

2,000-foot radius of the proposed Well “C” location. The depth limit of this investigation is 

approximately 4,000 feet below the seafloor (BSF). This assessment and enclosures presented 

with this letter comply with the U.S. Department of Interior’s Bureau of Ocean Energy 

Management (BOEM) and Bureau of Safety and Environmental Enforcement (BSEE) Notice To 

Lessees (NTL) No. 2008-G05 (Shallow Hazards Program), NTL No. 2005-G07 (Archaeology),

and NTL No. 2009-G40 (Deepwater Benthic Communities).

METHODS

The high-resolution AUV datasets were collected using C & C Technologies’ C-Surveyor IIITM

AUV. The AUV remote-sensing instruments include a Simrad EM2000 Swath Bathymetric 

Mapping System (200 kHz), an EdgeTech Dynamically-Focused Side Scan Sonar (230 kHz), 

and an EdgeTech Subbottom Profiler System (1.5 to 4.5 kHz). In general, the AUV survey grid 

pattern consisted of parallel north-south primary tracklines and parallel east-west tie lines. The 

primary trackline spacing was 200 meters (656.17 feet) and the tie lines were spaced at 900 

meters (2,952.75 feet). 
Wellsite Report

C&C Project No. 140501

2

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

FMOG provided an exploration-quality 3D seismic data volume in SEG-Y format. The 3D data 

were acquired by CGG in December 2003 to February 2004. The time volume dataset was 

processed at a 4-millisecond sample rate. The inlines and crosslines of the 3D data volume run 

east to west and north to south, respectively. The inlines are spaced 65.62-foot (20-meter) 

intervals, while the crosslines are spaced 82.02 feet (25 meters). The inlines and crosslines are 

depicted in panel 4 on the study map. The 3D seismic dataset is a zero phase wavelet with a zero 

phase rotation and the seafloor reflector is represented by a strong, positive amplitude peak 

flanked by troughs with absolute amplitude values of approximately one-half of the peak value. 

Amplitude values are represented by IBM 32-bit floating-point numbers, identified during data 

loading. The seismic data provided were adequate for regional screening of the seafloor and 

shallow geologic conditions, and large scale geohazards (faults, salt, high acoustic impedance, 

stratigraphic horizons, etc.).

The 3D seismic data used for this wellsite assessment were provided in SEG-Y format. The data 

were loaded into IHS’s Kingdom Suite 2D/3D Pak, Version 8.8 for interpretation. Spectral 

whitening was applied to the 3D seismic dataset to amplify the higher frequencies. After 

applying the spectral whitening, a power spectrum generated at the wellsite proposed location 

indicated the seismic data volume contains sufficiently high frequency content for a shallow 

hazards assessment (Figure No. 1).

WELL LOCATION

The coordinates and calls for Well “C” surface location is tabulated below: 

Table 1. Proposed GC645 Well “C”

Well XCoordinate

YCoordinate

Latitude Longitude Calls From Block 645,

Green Canyon Area

“C” 2,444,640’ 9,930,093’ 27°20’34.967” N 90°31’20.151” W 5,280’ FWL 1,587’ FNL

The geodetic datum used to generate the study maps is the North American Datum of 1927 

(NAD27) on the Clarke 1866 ellipsoid, and projected using the Universal Transverse Mercator 

(UTM), Zone 15 North (15N). All coordinates given are presented in this projection on the study 

map and included with this letter. All grid units, as well as scales and measurements are in U.S. 

survey feet. The proposed surface hole location of Well “C” and the 2,000-foot radius are 

displayed on the study map. 

BATHYMETRY AND SEAFLOOR GRADIENTS

Bathymetry was processed using the AUV multibeam and shown on the study map (Panel 1) at 

10-foot contour intervals. The bathymetry indicates the water depth at the proposed Well “C”

location is 4,460 feet Mean Seal Level (MSL). Within the 2,000-foot radius, the seafloor depth 

ranges from 4,435 feet MSL in the southwest to 4,475 feet MSL in the north (Panel 1). The 

seafloor is smooth within the vicinity of the proposed well. The seafloor at the proposed Well 

“C” location slopes to the south at an average gradient of 0.7°. 
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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

SEAFLOOR SEDIMENTS AND HAZARDS

The side scan sonar images (Panel 2; Figure No. 2) exhibit primarily low to moderate acoustic 

reflectivity. Additionally, the 3D seafloor amplitude image (Panel 3) displays a range of low to 

moderate acoustic amplitudes within the 2,000-foot radius. These low to moderate acoustic 

reflectivity and seafloor amplitudes indicate finely textured seafloor sediments likely comprised 

of hemipelagic clay (very soft silty clay). 

There are no seafloor drilling hazards detected on the side scan sonar images and 3D data within 

the 2,000-foot radius of the proposed well. The side scan sonar images (Figure No. 2) show an 

anchor scar or fishing trawl north of the proposed Well “C” location.

POTENTIAL BENTHIC COMMUNITIES

High-amplitude seismic seafloor anomalies are a potential indicator of carbonates and benthic 

community habitats. The seafloor at the proposed Well “C” location and surrounding 2,000-foot 

radius contains no high negative or positive amplitude anomalies associated with fluid expulsion 

or mounded carbonates representing potential benthic communities (Panels 3 and 4). 

MAN-MADE HAZARDS

A review of the C&C database shows two existing pipelines, a permitted pipeline, and several 

mooring lines within the vicinity of the proposed Well “C” location. The S-13677 BP 24 to 28-

Inch and S-13676 BP 16-20-Inch Pipelines are located greater than 4,600 feet south of the 

proposed well. The permitted S-18958 Enbridge 20-Inch Pipeline is located greater than 3,500 

feet north of the proposed well. The existing Holstein mooring lines are greater than 3,400 feet 

southwest of the proposed well. 

SUBSURFACE GEOHAZARDS AND STRATIGRAPHY

Five (6) units (Units A to E), each consisting of one or more distinctive sequences, were 

interpreted within the study area from the 3D seismic data to approximately 4,000 feet BSF. 

Figure Nos. 3, 4, and 5 show five (5) horizons marking the upper and / or lower contacts of each 

of the successive units (Units A to E). FMOG provided C&C with a checkshot dataset 

consisting of time-depth pairs for the sediment column at the GC643 Well No. 1 (OCS-G16772). The following polynomial equation was derived from Total Vertical Depth (TVD) and 

the corresponding two-way traveltime (TWT) using the time-depth values to calculate depths 

below the sea level:

Y = 516.29T

2

+ 1570.4T

Where Y = depth below seafloor in feet and T = two-way traveltime below sea level in seconds.

A detailed description of the sequence units can be found in the 2013 3D Seismic Shallow 

Geohazard Report. The Top-Hole Prognosis Chart (Figure No. 6) summarizes the stratigraphy. 

Unit A (Seafloor to Event 1): Unit A consists of continuous, low to moderate amplitude seismic 

reflectors (Figure Nos. 3, 4, and 5). Amplitudes and acoustic impedance contrasts tend to be 

moderate to low. These reflection patterns are likely comprised of hemipelagic clay, laid down 

as a drape deposit, and interbedded with fine-grained turbidites and some sands. Additionally, 
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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

the AUV subbottom profiler shows the drape deposits are interbedded with shallow buried mass 

transport deposits (Figure No. 3) and are buried greater than 14 feet BSF. At the proposed Well 

“C” location, the clay sequence is 1,503 feet thick. 

Unit B (Event 1 to Event 2): Unit B consists of low to moderate amplitude, semi-continuous to 

chaotic reflectors that are 1,505 feet thick at the proposed Well “C” location (Figure Nos. 4 and 

5). These reflection patterns are likely comprised of hemipelagic clay, laid down as a drape 

deposit with interbedded mud-prone mass movement deposits and turbidite channels at the base 

of the unit.

Unit C (Event 2 to Event 3): At the proposed Well “C” location, Unit C is 1,682 feet thick of 

variable amplitude, semi-continuous to chaotic acoustic reflections (Figure Nos. 4 to 5). Unit C 

sediments are interpreted as sediments of muds interbedded with thin mud-prone mass 

movement deposits and channeling that may contain sands. 

Unit D (Event 3 to Event 4): Unit D consists of low to moderate amplitude, continuous to 

chaotic reflectors and is 2,232 feet thick at the proposed Well “C” location. The sediments in 

Unit D are interpreted as thin sequences of turbidite mud and sands with interlayered muds and 

thin mud-prone mass movement deposits that may contain sands.

Unit E (Event 4 to Event 5): At the proposed Well “C” location, Unit E consists of low to 

moderate amplitude, parallel continuous to chaotic reflectors with isolated high amplitude 

reflectors (Figure Nos. 4 and 5). Unit E sediments are interpreted as muds interbedded with thin 

mud-prone mass movement deposits and channeling that may contain sands. 

FAULTS

Several buried faults are located south of the proposed Well “C” 2,000-foot radius. However, 

the proposed well bore path does not cross any major faults.

SHALLOW GAS AND GAS HYDRATES

Very high-amplitude seismic anomalies are interpreted as potential regions of fluid / gas 

saturation usually associated with porous sands. Shallow gas is interpreted with the seismic 

amplitude levels and the gas risk is assessed as being at one of the following four levels. 

 Negligible - No amplitude anomalies or other gas indicators present.

 Low risk of gas - Generally indicated by increased amplitude (2-3x background 

level) and phase reversal. This may also include diffuse areas of gas blanking.

 Moderate risk of gas - Generally indicated by high amplitude (3-4x background 

level) and phase reversal.

 High risk of gas - Generally indicated by the highest amplitudes (in excess of 

4x background level), phase reversal, and a combination of other attributes 

indicative of the presence of gas, particularly velocity pull-down and masking of 

underlying sediments. Stratigraphic and structural settings may also be taken 

into account.
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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Within 2,000 feet of the proposed Well “C” location, several subsurface amplitude anomalies are 

noted within Unit E at depths ranging from 5,334 to 10,199 feet BSF. These anomalies are 

located greater than 3,400 feet southwest of the proposed well bore path (Panel 4). A negligible 

to low risk of shallow gas (Figure No. 6) exists along the shallow section of the well bore for 

Well “C”. The well bore path will not penetrate any high-amplitude anomalies between the 

seafloor and the base of the study (Figure No. 6). 

There is no indication of BSRs within the study area.

SHALLOW WATER FLOW

The BOEM database does indicate GC645 Well No. 1 (OCS-G-11080) at a water depth of 4,292 

feet BSL experienced a minor SWF at 638 feet BSF.

The overall risk of shallow water flow is negligible to moderate at the proposed Well “C”

location (Figure No. 6). An examination of the 3D seismic dataset indicates Units B and E are 

comprised of chaotic reflectors showing high impedance contrast, suggesting a moderate 

potential for SWF. Unit C and D exhibit a low risk of SWF, and Unit A shows a negligible risk 

of SWF. At present there is no method of quantifying the risk of SWFs, so caution is

recommended when drilling through the potential SWF units. 

CONCLUSIONS

The proposed Well “C” surface location has a water depth of 4,460 feet MSL and is clear of 

geological constraints. No significant seafloor features are located at or within 2,000 feet of the 

proposed well that could interfere with drilling activities. 

No high or low seafloor amplitude anomalies indicating the occurrence of hardgrounds, 

carbonates, benthic communities, or potential expulsions, are found within 2,000 feet of the 

proposed Well “C” location. 

No infrastructure exists, permitted, or proposed within 2,000 feet of the proposed Well “C”

location. 

The proposed well location will not intersect any major faults along the well bore path. 

The assessment of seismic profiles suggests stratigraphic units exhibit a negligible to moderate 

risk (Units B and E) for SWF and a negligible to low (Unit E) potential for gas at the Well “C”

drill site. 

Thank you for this opportunity to be of service. Please contact us if you have any questions 

concerning this assessment.

Sincerely yours,

James Cox

Geophysicist
Wellsite Report

C&C Project No. 140501

6

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Enclosures

Figure No. 1. Extracted wavelet and power spectrum at the proposed Well “C” location.

Figure No. 2. Nearest side scan sonar image (Line 157) from the proposed Well “C” location.

Figure No. 3. Nearest subbottom profile record (Line 157) from the proposed Well “C” location.

Figure No. 4. Nearest 3D seismic Inline (3777) from the proposed Well “C” location.

Figure No. 5. Nearest 3D seismic Crossline (6005) from the proposed Well “C” location.

Figure No. 6. Top-hole Prognosis Chart for the proposed Well “C” location.

Sheet 1. Proposed Well “C” & “D” Locations 

Wellsite Report

C&C Project No. 140501

1

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

July 9, 2014

Freeport-McMoRan Oil & Gas

400 East Kaliste Saloom Road

Suite 1100

Lafayette, LA 70508

Attn: Ms. Mary Broussard

Site Clearance Letter

Proposed Well “D”

Block 645 (OCS-G-11081), Green Canyon Area

Dear Ms. Broussard,

INTRODUCTION

Freeport-McMoRan Oil & Gas (FMOG) contracted C & C Technologies, Inc. (C&C) to prepare 

a wellsite clearance letter for the proposed drilling location of Well “D” in Block 645 (OCS-G11081), Green Canyon (GC) Area. The data used for the site clearance letter is based on the 

interpretation of high-resolution AUV datasets collected by C&C and an exploration-quality 3D 

seismic volume licensed by FMOG. C&C completed the reports titled “3D Seismic Shallow 

Geohazard Report, Blocks 599 (OCS-G-34998) and 643 (OCS-G-35001), Green Canyon Area” 

in July 2013 and “Archaeological Assessment, Blocks 599 (OCS-G-34998), 600 (OCS-G-34999), 

643 (OCS-G-35001), 644 (OCS-G-11080), 645 (OCS-G-11081), 689 (OCS-G-35002), 733 

(OCS-G-35004), and 777 (OCS-G-35007), Green Canyon Area” in August, 2013. This site 

clearance letter is based on the findings provided within these reports. A drill ship is being 

proposed for drilling this well. 

This letter provides a top-hole drilling prognosis and addresses seafloor conditions within a 

2,000-foot radius of the proposed Well “D” location. The depth limit of this investigation is 

approximately 4,000 feet below the seafloor (BSF). This assessment and enclosures presented 

with this letter comply with the U.S. Department of Interior’s Bureau of Ocean Energy 

Management (BOEM) and Bureau of Safety and Environmental Enforcement (BSEE) Notice To 

Lessees (NTL) No. 2008-G05 (Shallow Hazards Program), NTL No. 2005-G07 (Archaeology),

and NTL No. 2009-G40 (Deepwater Benthic Communities).

METHODS

The high-resolution AUV datasets were collected using C & C Technologies’ C-Surveyor IIITM

AUV. The AUV remote-sensing instruments include a Simrad EM2000 Swath Bathymetric 

Mapping System (200 kHz), an EdgeTech Dynamically-Focused Side Scan Sonar (230 kHz), 

and an EdgeTech Subbottom Profiler System (1.5 to 4.5 kHz). In general, the AUV survey grid 

pattern consisted of parallel north-south primary tracklines and parallel east-west tie lines. The 

primary trackline spacing was 200 meters (656.17 feet) and the tie lines were spaced at 900 

meters (2,952.75 feet). 
Wellsite Report

C&C Project No. 140501

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

FMOG provided an exploration-quality 3D seismic data volume in SEG-Y format. The 3D data 

were acquired by CGG in December 2003 to February 2004. The time volume dataset was 

processed at a 4-millisecond sample rate. The inlines and crosslines of the 3D data volume run 

east to west and north to south, respectively. The inlines are spaced 65.62-foot (20-meter) 

intervals, while the crosslines are spaced 82.02 feet (25 meters). The inlines and crosslines are 

depicted in panel 4 on the study map. The 3D seismic dataset is a zero phase wavelet with a zero 

phase rotation and the seafloor reflector is represented by a strong, positive amplitude peak 

flanked by troughs with absolute amplitude values of approximately one-half of the peak value. 

Amplitude values are represented by IBM 32-bit floating-point numbers, identified during data 

loading. The seismic data provided were adequate for regional screening of the seafloor and 

shallow geologic conditions, and large scale geohazards (faults, salt, high acoustic impedance, 

stratigraphic horizons, etc.).

The 3D seismic data used for this wellsite assessment were provided in SEG-Y format. The data 

were loaded into IHS’s Kingdom Suite 2D/3D Pak, Version 8.8 for interpretation. Spectral 

whitening was applied to the 3D seismic dataset to amplify the higher frequencies. After 

applying the spectral whitening, a power spectrum generated at the wellsite proposed location 

indicated the seismic data volume contains sufficiently high frequency content for a shallow 

hazards assessment (Figure No. 1).

WELL LOCATION

The coordinates and calls for Well “D” surface location is tabulated below: 

Table 1. Proposed GC645 Well “D”

Well XCoordinate

YCoordinate

Latitude Longitude Calls From Block 645,

Green Canyon Area

“D” 2,444,701’ 9,930,179’ 27°20’35.806” N 90°31’19.456” W 5,341’ FWL 1,501’ FNL

The geodetic datum used to generate the study maps is the North American Datum of 1927 

(NAD27) on the Clarke 1866 ellipsoid, and projected using the Universal Transverse Mercator 

(UTM), Zone 15 North (15N). All coordinates given are presented in this projection on the study 

map and included with this letter. All grid units, as well as scales and measurements are in U.S. 

survey feet. The proposed surface hole location of Well “D” and the 2,000-foot radius are 

displayed on the study map. 

BATHYMETRY AND SEAFLOOR GRADIENTS

Bathymetry was processed using the AUV multibeam and shown on the study map (Panel 1) at 

10-foot contour intervals. The bathymetry indicates the water depth at the proposed Well “D”

location is 4,460 feet Mean Seal Level (MSL). Within the 2,000-foot radius, the seafloor depth 

ranges from 4,435 feet MSL in the southwest to 4,475 feet MSL in the north (Panel 1). The 

seafloor is smooth within the vicinity of the proposed well. The seafloor at the proposed Well 

“D” location slopes to the south at an average gradient of 0.7°. 
Wellsite Report

C&C Project No. 140501

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

SEAFLOOR SEDIMENTS AND HAZARDS

The side scan sonar images (Panel 2; Figure No. 2) exhibit primarily low to moderate acoustic 

reflectivity. Additionally, the 3D seafloor amplitude image (Panel 3) displays a range of low to 

moderate acoustic amplitudes within the 2,000-foot radius. These low to moderate acoustic 

reflectivity and seafloor amplitudes indicate finely textured seafloor sediments likely comprised 

of hemipelagic clay (very soft silty clay). 

There are no seafloor drilling hazards detected on the side scan sonar images and 3D data within 

the 2,000-foot radius of the proposed well. The side scan sonar images (Figure No. 2) show an 

anchor scar or fishing trawl north of the proposed Well “D” location.

POTENTIAL BENTHIC COMMUNITIES

High-amplitude seismic seafloor anomalies are a potential indicator of carbonates and benthic 

community habitats. The seafloor at the proposed Well “D” location and surrounding 2,000-foot 

radius contains no high negative or positive amplitude anomalies associated with fluid expulsion 

or mounded carbonates representing potential benthic communities (Panels 3 and 4). 

MAN-MADE HAZARDS

A review of the C&C database shows two existing pipelines, a permitted pipeline, and several 

mooring lines within the vicinity of the proposed Well “D” location. The S-13677 BP 24 to 28-

Inch and S-13676 BP 16-20-Inch Pipelines are located greater than 4,600 feet south of the 

proposed well. The permitted S-18958 Enbridge 20-Inch Pipeline is located greater than 3,500 

feet north of the proposed well. The existing Holstein mooring lines are greater than 3,400 feet 

southwest of the proposed well. 

SUBSURFACE GEOHAZARDS AND STRATIGRAPHY

Five (5) units (Units A to E), each consisting of one or more distinctive sequences, were 

interpreted within the study area from the 3D seismic data to approximately 4,000 feet BSF. 

Figure Nos. 3, 4, and 5 show five (5) horizons marking the upper and / or lower contacts of each 

of the successive units (Units A to E). FMOG provided C&C with a checkshot dataset 

consisting of time-depth pairs for the sediment column at the GC643 Well No. 1 (OCS-G16772). The following polynomial equation was derived from Total Vertical Depth (TVD) and 

the corresponding two-way traveltime (TWT) using the time-depth values to calculate depths 

below the sea level:

Y = 516.29T

2

+ 1570.4T

Where Y = depth below seafloor in feet and T = two-way traveltime below sea level in seconds.

A detailed description of the sequence units can be found in the 2013 3D Seismic Shallow 

Geohazard Report. The Top-Hole Prognosis Chart (Figure No. 6) summarizes the stratigraphy. 

Unit A (Seafloor to Event 1): Unit A consists of continuous, low to moderate amplitude seismic 

reflectors (Figure Nos. 3, 4, and 5). Amplitudes and acoustic impedance contrasts tend to be 

moderate to low. These reflection patterns are likely comprised of hemipelagic clay, laid down 

as a drape deposit, and interbedded with fine-grained turbidites and some sands. Additionally, 
Wellsite Report

C&C Project No. 140501

4

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

the AUV subbottom profiler shows the drape deposits are interbedded with shallow buried mass 

transport deposits (Figure No. 3) and buried greater than 20 feet BSF. At the proposed Well “D”

location, the clay sequence is 1,503 feet thick. 

Unit B (Event 1 to Event 2): Unit B consists of low to moderate amplitude, semi-continuous to 

chaotic reflectors that are 1,505 feet thick at the proposed Well “D” location (Figure Nos. 4 and 

5). These reflection patterns are likely comprised of hemipelagic clay, laid down as a drape 

deposit with interbedded mud-prone mass movement deposits and turbidite channels at the base 

of the unit.

Unit C (Event 2 to Event 3): At the proposed Well “D” location, Unit C is 1,682 feet thick of 

variable amplitude, semi-continuous to chaotic acoustic reflections (Figure Nos. 4 to 5). Unit C 

sediments are interpreted as sediments of muds interbedded with thin mud-prone mass 

movement deposits and channeling that may contain sands. 

Unit D (Event 3 to Event 4): Unit D consists of low to moderate amplitude, continuous to 

chaotic reflectors and is 2,232 feet thick at the proposed Well “D” location. The sediments in 

Unit D are interpreted as thin sequences of turbidite mud and sands with interlayered muds and 

thin mud-prone mass movement deposits that may contain sands.

Unit E (Event 4 to Event 5): At the proposed Well “D” location, Unit E consists of low to 

moderate amplitude, parallel continuous to chaotic reflectors with isolated high amplitude 

reflectors (Figure Nos. 4 and 5). Unit E sediments are interpreted as muds interbedded with thin 

mud-prone mass movement deposits and channeling that may contain sands. 

FAULTS

Several buried faults are located south of the proposed Well “D” 2,000-foot radius. However, 

the proposed well bore path does not cross any major faults.

SHALLOW GAS AND GAS HYDRATES

Very high-amplitude seismic anomalies are interpreted as potential regions of fluid / gas 

saturation usually associated with porous sands. Shallow gas is interpreted with the seismic 

amplitude levels and the gas risk is assessed as being at one of the following four levels. 

 Negligible - No amplitude anomalies or other gas indicators present.

 Low risk of gas - Generally indicated by increased amplitude (2-3x background 

level) and phase reversal. This may also include diffuse areas of gas blanking.

 Moderate risk of gas - Generally indicated by high amplitude (3-4x background 

level) and phase reversal.

 High risk of gas - Generally indicated by the highest amplitudes (in excess of 

4x background level), phase reversal, and a combination of other attributes 

indicative of the presence of gas, particularly velocity pull-down and masking of 

underlying sediments. Stratigraphic and structural settings may also be taken 

into account.
Wellsite Report

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Within 2,000 feet of the proposed Well “D” location, several subsurface amplitude anomalies are 

noted within Unit E at depths ranging from 5,334 to 10,199 feet BSF. These anomalies are 

located greater than 3,400 feet southwest of the proposed well bore path (Panel 4). A negligible 

to low risk of shallow gas (Figure No. 6) exists along the shallow section of the well bore for 

Well “D”. The well bore path will not penetrate any high-amplitude anomalies between the 

seafloor and the base of the study (Figure No. 6). 

There is no indication of BSRs within the study area.

SHALLOW WATER FLOW

The BOEM database does indicate GC645 Well No. 1 (OCS-G-11080) at a water depth of 4,292 

feet BSL experienced a minor SWF at 638 feet BSF.

The overall risk of shallow water flow is negligible to moderate at the proposed Well “D”

location (Figure No. 6). An examination of the 3D seismic dataset indicates Units B and E are 

comprised of chaotic reflectors showing high impedance contrast, suggesting a moderate 

potential for SWF. Unit C and D exhibit a low risk of SWF, and Unit A shows a negligible risk 

of SWF. At present there is no method of quantifying the risk of SWFs, so caution is 

recommended when drilling through the potential SWF units. 

CONCLUSIONS

The proposed Well “D” surface location has a water depth of 4,460 feet MSL and is clear of 

geological constraints. No significant seafloor features are located at or within 2,000 feet of the 

proposed well that could interfere with drilling activities. 

No high or low seafloor amplitude anomalies indicating the occurrence of hardgrounds, 

carbonates, benthic communities, or potential expulsions, are found within 2,000 feet of the 

proposed Well “D” location. 

No infrastructure exists, permitted, or proposed within 2,000 feet of the proposed Well “D”

location. 

The proposed well location will not intersect any major faults along the well bore path. 

The assessment of seismic profiles suggests stratigraphic units exhibit a negligible to moderate 

(Units B and E) risk for SWF and a negligible to low (Unit E) potential for gas at the Well “D”

drill site. 

Thank you for this opportunity to be of service. Please contact us if you have any questions 

concerning this assessment.

Sincerely yours,

James Cox

Geophysicist
Wellsite Report

C&C Project No. 140501

6

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Enclosures

Figure No. 1. Extracted wavelet and power spectrum at the proposed Well “D” location.

Figure No. 2. Nearest side scan sonar image (Line 157) from the proposed Well “D” location.

Figure No. 3. Nearest subbottom profile record (Line 157) from the proposed Well “D” location.

Figure No. 4. Nearest 3D seismic Inline (3777) from the proposed Well “D” location.

Figure No. 5. Nearest 3D seismic Crossline (6005) from the proposed Well “D” location.

Figure No. 6. Top-hole Prognosis Chart for the proposed Well “D” location.

Sheet 1. Proposed Well “C” & “D” Locations 

Wellsite Report

C&C Project No. 140501

1

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

July 9, 2014

Freeport-McMoRan Oil & Gas

400 East Kaliste Saloom Road

Suite 1100

Lafayette, LA 70508

Attn: Ms. Mary Broussard

Site Clearance Letter

Proposed Well “E”

Block 600 (OCS-G-34999), Green Canyon Area

Dear Ms. Broussard,

INTRODUCTION

Freeport-McMoRan Oil & Gas (FMOG) contracted C & C Technologies, Inc. (C&C) to prepare 

a wellsite clearance letter for the proposed drilling location of Well “E” in Block 600 (OCS-G34999), Green Canyon (GC) Area. The data used for the site clearance letter is based on the 

interpretation of high-resolution AUV datasets collected by C&C and an exploration-quality 3D 

seismic volume licensed by FMOG. C&C completed the reports titled “3D Seismic Shallow 

Geohazard Report, Blocks 599 (OCS-G-34998) and 643 (OCS-G-35001), Green Canyon Area” 

in July 2013 and “Archaeological Assessment, Blocks 599 (OCS-G-34998), 600 (OCS-G-34999), 

643 (OCS-G-35001), 644 (OCS-G-11080), 645 (OCS-G-11081), 689 (OCS-G-35002), 733 

(OCS-G-35004), and 777 (OCS-G-35007), Green Canyon Area” in August, 2013. The AUV 

datasets do not provide coverage in the eastern portion of the 2,000-foot radius but the 3D 

seismic dataset does provide complete coverage. This site clearance letter is based on the 

findings provided within these reports. A drill ship is being proposed for drilling this well. 

This letter provides a top-hole drilling prognosis and addresses seafloor conditions within a 

2,000-foot radius of the proposed Well “E” location. The depth limit of this investigation is 

approximately 4,000 feet below the seafloor (BSF). This assessment and enclosures presented 

with this letter comply with the U.S. Department of Interior’s Bureau of Ocean Energy 

Management (BOEM) and Bureau of Safety and Environmental Enforcement (BSEE) Notice To 

Lessees (NTL) No. 2008-G05 (Shallow Hazards Program), NTL No. 2005-G07 (Archaeology),

and NTL No. 2009-G40 (Deepwater Benthic Communities).

METHODS

The high-resolution AUV datasets were collected using C & C Technologies’ C-Surveyor IIITM

AUV. The AUV remote-sensing instruments include a Simrad EM2000 Swath Bathymetric 

Mapping System (200 kHz), an EdgeTech Dynamically-Focused Side Scan Sonar (230 kHz), 

and an EdgeTech Subbottom Profiler System (1.5 to 4.5 kHz). In general, the AUV survey grid 

pattern consisted of parallel north-south primary tracklines and parallel east-west tie lines. The 

primary trackline spacing was 200 meters (656.17 feet) and the tie lines were spaced at 900 

meters (2,952.75 feet). 
Wellsite Report

C&C Project No. 140501

2

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

FMOG provided an exploration-quality 3D seismic data volume in SEG-Y format. The 3D data 

were acquired by CGG in December 2003 to February 2004. The time volume dataset was 

processed at a 4-millisecond sample rate. The inlines and crosslines of the 3D data volume run 

east to west and north to south, respectively. The inlines are spaced 65.62-foot (20-meter) 

intervals, while the crosslines are spaced 82.02 feet (25 meters). The inlines and crosslines are 

depicted in panel 4 on the study map. The 3D seismic dataset is a zero phase wavelet with a zero 

phase rotation and the seafloor reflector is represented by a strong, positive amplitude peak 

flanked by troughs with absolute amplitude values of approximately one-half of the peak value. 

Amplitude values are represented by IBM 32-bit floating-point numbers, identified during data 

loading. The seismic data provided were adequate for regional screening of the seafloor and 

shallow geologic conditions, and large scale geohazards (faults, salt, high acoustic impedance, 

stratigraphic horizons, etc.).

The 3D seismic data used for this wellsite assessment were provided in SEG-Y format. The data 

were loaded into IHS’s Kingdom Suite 2D/3D Pak, Version 8.8 for interpretation. Spectral 

whitening was applied to the 3D seismic dataset to amplify the higher frequencies. After 

applying the spectral whitening, a power spectrum generated at the wellsite proposed location 

indicated the seismic data volume contains sufficiently high frequency content for a shallow 

hazards assessment (Figure No. 1).

WELL LOCATION

The coordinates and calls for Well “E” surface location is tabulated below: 

Table 1. Proposed GC600 Well “E”

Well X-Coordinate Y-Coordinate Latitude Longitude Calls From Block 600,

Green Canyon Area

“E” 2,438,630’ 9,943,230’ 27°22’46.170” N 90°32’23.884” W 730’ FEL 4,290’ FNL

The geodetic datum used to generate the study maps is the North American Datum of 1927 

(NAD27) on the Clarke 1866 ellipsoid, and projected using the Universal Transverse Mercator 

(UTM), Zone 15 North (15N). All coordinates given are presented in this projection on the study 

map and included with this letter. All grid units, as well as scales and measurements are in U.S. 

survey feet. The proposed surface hole location of Well “E” and the 2,000-foot radius are 

displayed on the study map. 

BATHYMETRY AND SEAFLOOR GRADIENTS

Bathymetry was processed using the AUV multibeam and shown on the study map (Panel 1) at 

10-foot contour intervals. The bathymetry indicates the water depth at the proposed Well “E”

location is 4,485 feet Mean Seal Level (MSL). Within the 2,000-foot radius, the seafloor depth 

ranges from 4,440 feet MSL in the southwest to 4,490 feet MSL in the east (Panel 1). The 

seafloor is smooth within the vicinity of the proposed well. The seafloor at the proposed Well 

“E” location slopes to the northeast at an average gradient of 1.3°. 
Wellsite Report

C&C Project No. 140501

3

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

SEAFLOOR SEDIMENTS AND HAZARDS

The side scan sonar images (Panel 2; Figure No. 2) exhibit primarily low to moderate acoustic 

reflectivity. Additionally, the 3D seafloor amplitude image (Panel 3) displays a range of low to 

moderate acoustic amplitudes within the 2,000-foot radius. These low to moderate acoustic 

reflectivity and seafloor amplitudes indicate finely textured seafloor sediments likely comprised 

of hemipelagic clay (very soft silty clay). 

There are no seafloor drilling hazards detected on the side scan sonar images and 3D data within 

the 2,000-foot radius of the proposed well. 

POTENTIAL BENTHIC COMMUNITIES

High-amplitude seismic seafloor anomalies are a potential indicator of carbonates and benthic

community habitats. The seafloor at the proposed Well “E” location and surrounding 2,000-foot 

radius contains no high negative or positive amplitude anomalies associated with fluid expulsion 

or mounded carbonates representing potential benthic communities (Panels 3 and 4). 

MAN-MADE HAZARDS

A review of the C&C database shows no existing infrastructure within the vicinity of the 

proposed Well “E” location. 

SUBSURFACE GEOHAZARDS AND STRATIGRAPHY

Five (5) units (Units A to E), each consisting of one or more distinctive sequences, were 

interpreted within the study area from the 3D seismic data to approximately 4,000 feet BSF. 

Figure Nos. 3, 4, and 5 show four (4) horizons marking the upper and / or lower contacts of each 

of the successive units (Units A to E). FMOG provided C&C with a checkshot dataset 

consisting of time-depth pairs for the sediment column at the GC643 Well No. 1 (OCS-G16772). The following polynomial equation was derived from Total Vertical Depth (TVD) and 

the corresponding two-way traveltime (TWT) using the time-depth values to calculate depths 

below the sea level:

Y = 516.29T

2

+ 1570.4T

Where Y = depth below seafloor in feet and T = two-way traveltime below sea level in seconds.

A detailed description of the sequence units can be found in the 2013 3D Seismic Shallow 

Geohazard Report. The Top-Hole Prognosis Chart (Figure No. 6) summarizes the stratigraphy. 

Unit A (Seafloor to Event 1): Unit A consists of continuous, low to moderate amplitude seismic 

reflectors (Figure Nos. 3, 4, and 5). Amplitudes and acoustic impedance contrasts tend to be 

moderate to low. These reflection patterns are likely comprised of hemipelagic clay, laid down 

as a drape deposit, and interbedded with fine-grained turbidites and some sands. Additionally, 

the AUV subbottom profiler shows the drape deposits are interbedded with shallow buried mass 

transport deposits (Figure No. 3) and are greater than 14 feet BSF. At the proposed Well “E”

location, the clay sequence is 1,894 feet thick. 
Wellsite Report

C&C Project No. 140501

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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Unit B (Event 1 to Event 2): Unit B consists of low to moderate amplitude, semi-continuous to 

chaotic reflectors that are 1,655 feet thick at the proposed Well “E” location (Figure Nos. 4 and 

5). These reflection patterns are likely comprised of hemipelagic clay, laid down as a drape 

deposit with interbedded mud-prone mass movement deposits and turbidite channels at the base 

of the unit.

Unit C (Event 2 to Event 3): At the proposed Well “E” location, Unit C is 2,031 feet thick of 

variable amplitude, semi-continuous to chaotic acoustic reflections (Figure Nos. 4 to 5). Unit C 

sediments are interpreted as sediments of muds interbedded with thin mud-prone mass 

movement deposits and channeling that may contain sands. 

Unit D (Event 3 to Event 4): Unit D consists of low to moderate amplitude, continuous to 

chaotic reflectors and is 2,477 feet thick at the proposed Well “E” location. The sediments in 

Unit D are interpreted as thin sequences of turbidite mud and sands with interlayered muds and 

thin mud-prone mass movement deposits that may contain sands.

Unit E (Event 4 to Event 5): At the proposed Well “E” location, Unit E consists of low to 

moderate amplitude, parallel continuous to chaotic reflectors with isolated high amplitude 

reflectors (Figure Nos. 4 and 5). Unit E sediments are interpreted as muds interbedded with thin 

mud-prone mass movement deposits and channeling that may contain sands. 

FAULTS

No buried faults are located within the vicinity of the proposed Well “E” location. The proposed 

well bore path does not cross any major faults.

SHALLOW GAS AND GAS HYDRATES

Very high-amplitude seismic anomalies are interpreted as potential regions of fluid / gas 

saturation usually associated with porous sands. Shallow gas is interpreted with the seismic 

amplitude levels and the gas risk is assessed as being at one of the following four levels. 

 Negligible - No amplitude anomalies or other gas indicators present.

 Low risk of gas - Generally indicated by increased amplitude (2-3x background 

level) and phase reversal. This may also include diffuse areas of gas blanking.

 Moderate risk of gas - Generally indicated by high amplitude (3-4x background 

level) and phase reversal.

 High risk of gas - Generally indicated by the highest amplitudes (in excess of 

4x background level), phase reversal, and a combination of other attributes 

indicative of the presence of gas, particularly velocity pull-down and masking of 

underlying sediments. Stratigraphic and structural settings may also be taken 

into account.

No subsurface amplitude anomalies are noted within the vicinity of the proposed Well “E” 

location, A negligible to low risk of shallow gas (Figure No. 6) exists along the shallow section 

of the well bore for Well “E”. The well bore path will not penetrate any high-amplitude 

anomalies between the seafloor and the base of the study (Figure No. 6). 
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730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

There is no indication of BSRs within the study area.

SHALLOW WATER FLOW

The BOEM database does indicate GC644 Well No. 1 (OCS-G-11080) at a water depth of 4,292 

feet BSL experienced a minor SWF at 638 feet BSF.

The overall risk of shallow water flow is negligible to moderate at the proposed Well “E”

location (Figure No. 6). The 3D seismic dataset shows transgressive marine sediments are 

present at the base of Unit A, suggesting a moderate potential for SWF. An examination of the 

3D seismic dataset indicates Units B and E are comprised of chaotic reflectors showing high 

impedance contrast, suggesting a moderate potential for SWF. Unit C and D exhibit a low risk 

of SWF, and Unit A shows a negligible risk of SWF. At present there is no method of 

quantifying the risk of SWFs, so caution is recommended when drilling through the potential 

SWF units. 

CONCLUSIONS

The proposed Well “E” surface location has a water depth of 4,485 MSL and is clear of 

geological constraints. No significant seafloor features are located at or within 2,000 feet of the 

proposed well that could interfere with drilling activities. 

No high or low seafloor amplitude anomalies indicating the occurrence of hardgrounds, 

carbonates, benthic communities, or potential expulsions, are found within 2,000 feet of the 

proposed Well “E” location. 

No infrastructure exists, permitted, or proposed within 2,000 feet of the proposed Well “E”

location. 

The proposed well location will not intersect any major faults along the well bore path. 

The assessment of seismic profiles suggests stratigraphic units exhibit a negligible to moderate 

(Units A, B, and E) risk for SWF and a negligible to low (Unit E) potential for gas at the Well 

“E” drill site. 

Thank you for this opportunity to be of service. Please contact us if you have any questions 

concerning this assessment.

Sincerely yours,

James Cox

Geophysicist

Enclosures

Figure No. 1. Extracted wavelet and power spectrum at the proposed Well “E” location.

Figure No. 2. Nearest side scan sonar image (Line 302) from the proposed Well “E” location.

Figure No. 3. Nearest subbottom profile record (Line 302) from the proposed Well “E” location.
Wellsite Report

C&C Project No. 140501

6

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Figure No. 4. Nearest 3D seismic Inline (3976) from the proposed Well “E” location.

Figure No. 5. Nearest 3D seismic Crossline (5931) from the proposed Well “E” location.

Figure No. 6. Top-hole Prognosis Chart for the proposed Well “E” location.

Sheet 1. Proposed Well “E” & “F” Locations 

Wellsite Report

C&C Project No. 140501

1

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

July 9, 2014

Freeport-McMoRan Oil & Gas

400 East Kaliste Saloom Road

Suite 1100

Lafayette, LA 70508

Attn: Ms. Mary Broussard

Site Clearance Letter

Proposed Well “F”

Block 600 (OCS-G-34999), Green Canyon Area

Dear Ms. Broussard,

INTRODUCTION

Freeport-McMoRan Oil & Gas (FMOG) contracted C & C Technologies, Inc. (C&C) to prepare 

a wellsite clearance letter for the proposed drilling location of Well “F” in Block 600 (OCS-G34999), Green Canyon (GC) Area. The data used for the site clearance letter is based on the 

interpretation of high-resolution AUV datasets collected by C&C and an exploration-quality 3D 

seismic volume licensed by FMOG. C&C completed the reports titled “3D Seismic Shallow 

Geohazard Report, Blocks 599 (OCS-G-34998) and 643 (OCS-G-35001), Green Canyon Area” 

in July 2013 and “Archaeological Assessment, Blocks 599 (OCS-G-34998), 600 (OCS-G-34999), 

643 (OCS-G-35001), 644 (OCS-G-11080), 645 (OCS-G-11081), 689 (OCS-G-35002), 733 

(OCS-G-35004), and 777 (OCS-G-35007), Green Canyon Area” in August, 2013. The AUV 

datasets do not provide coverage in the eastern portion of the 2,000-foot radius but the 3D 

seismic dataset does provide complete coverage. This site clearance letter is based on the 

findings provided within these reports. A drill ship is being proposed for drilling this well. 

This letter provides a top-hole drilling prognosis and addresses seafloor conditions within a 

2,000-foot radius of the proposed Well “F” location. The depth limit of this investigation is 

approximately 4,000 feet below the seafloor (BSF). This assessment and enclosures presented 

with this letter comply with the U.S. Department of Interior’s Bureau of Ocean Energy 

Management (BOEM) and Bureau of Safety and Environmental Enforcement (BSEE) Notice To 

Lessees (NTL) No. 2008-G05 (Shallow Hazards Program), NTL No. 2005-G07 (Archaeology),

and NTL No. 2009-G40 (Deepwater Benthic Communities).

METHODS

The high-resolution AUV datasets were collected using C & C Technologies’ C-Surveyor IIITM

AUV. The AUV remote-sensing instruments include a Simrad EM2000 Swath Bathymetric 

Mapping System (200 kHz), an EdgeTech Dynamically-Focused Side Scan Sonar (230 kHz), 

and an EdgeTech Subbottom Profiler System (1.5 to 4.5 kHz). In general, the AUV survey grid 

pattern consisted of parallel north-south primary tracklines and parallel east-west tie lines. The 

primary trackline spacing was 200 meters (656.17 feet) and the tie lines were spaced at 900 

meters (2,952.75 feet). 
Wellsite Report

C&C Project No. 140501

2

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

FMOG provided an exploration-quality 3D seismic data volume in SEG-Y format. The 3D data 

were acquired by CGG in December 2003 to February 2004. The time volume dataset was 

processed at a 4-millisecond sample rate. The inlines and crosslines of the 3D data volume run 

east to west and north to south, respectively. The inlines are spaced 65.62-foot (20-meter) 

intervals, while the crosslines are spaced 82.02 feet (25 meters). The inlines and crosslines are 

depicted in panel 4 on the study map. The 3D seismic dataset is a zero phase wavelet with a zero 

phase rotation and the seafloor reflector is represented by a strong, positive amplitude peak 

flanked by troughs with absolute amplitude values of approximately one-half of the peak value. 

Amplitude values are represented by IBM 32-bit floating-point numbers, identified during data 

loading. The seismic data provided were adequate for regional screening of the seafloor and 

shallow geologic conditions, and large scale geohazards (faults, salt, high acoustic impedance, 

stratigraphic horizons, etc.).

The 3D seismic data used for this wellsite assessment were provided in SEG-Y format. The data 

were loaded into IHS’s Kingdom Suite 2D/3D Pak, Version 8.8 for interpretation. Spectral 

whitening was applied to the 3D seismic dataset to amplify the higher frequencies. After 

applying the spectral whitening, a power spectrum generated at the wellsite proposed location 

indicated the seismic data volume contains sufficiently high frequency content for a shallow 

hazards assessment (Figure No. 1).

WELL LOCATION

The coordinates and calls for Well “F” surface location is tabulated below: 

Table 1. Proposed GC600 Well “F”

Well XCoordinate

YCoordinate

Latitude Longitude Calls From Block 600,

Green Canyon Area

“F” 2,438,700’ 9,943,150’ 27°22’45.364” N 90°32’23.126” W 660’ FEL 4,370’ FNL

The geodetic datum used to generate the study maps is the North American Datum of 1927 

(NAD27) on the Clarke 1866 ellipsoid, and projected using the Universal Transverse Mercator 

(UTM), Zone 15 North (15N). All coordinates given are presented in this projection on the study 

map and included with this letter. All grid units, as well as scales and measurements are in U.S. 

survey feet. The proposed surface hole location of Well “F” and the 2,000-foot radius are 

displayed on the study map. 

BATHYMETRY AND SEAFLOOR GRADIENTS

Bathymetry was processed using the AUV multibeam and shown on the study map (Panel 1) at 

10-foot contour intervals. The bathymetry indicates the water depth at the proposed Well “F”

location is 4,485 feet Mean Seal Level (MSL). Within the 2,000-foot radius, the seafloor depth 

ranges from 4,440 feet MSL in the southwest to 4,490 feet MSL in the east (Panel 1). The 

seafloor is smooth within the vicinity of the proposed well. The seafloor at the proposed Well 

“F” location slopes to the northeast at an average gradient of 1.3°. 
Wellsite Report

C&C Project No. 140501

3

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

SEAFLOOR SEDIMENTS AND HAZARDS

The side scan sonar images (Panel 2; Figure No. 2) exhibit primarily low to moderate acoustic 

reflectivity. Additionally, the 3D seafloor amplitude image (Panel 3) displays a range of low to 

moderate acoustic amplitudes within the 2,000-foot radius. These low to moderate acoustic 

reflectivity and seafloor amplitudes indicate finely textured seafloor sediments likely comprised 

of hemipelagic clay (very soft silty clay). 

There are no seafloor drilling hazards detected on the side scan sonar images and 3D data within 

the 2,000-foot radius of the proposed well. 

POTENTIAL BENTHIC COMMUNITIES

High-amplitude seismic seafloor anomalies are a potential indicator of carbonates and benthic

community habitats. The seafloor at the proposed Well “F” location and surrounding 2,000-foot 

radius contains no high negative or positive amplitude anomalies associated with fluid expulsion 

or mounded carbonates representing potential benthic communities (Panels 3 and 4). 

MAN-MADE HAZARDS

A review of the C&C database shows no existing infrastructure within the vicinity of the 

proposed Well “F” location. 

SUBSURFACE GEOHAZARDS AND STRATIGRAPHY

Five (5) units (Units A to E), each consisting of one or more distinctive sequences, were 

interpreted within the study area from the 3D seismic data to approximately 4,000 feet BSF. 

Figure Nos. 3, 4, and 5 show four (4) horizons marking the upper and / or lower contacts of each 

of the successive units (Units A to E). FMOG provided C&C with a checkshot dataset 

consisting of time-depth pairs for the sediment column at the GC643 Well No. 1 (OCS-G16772). The following polynomial equation was derived from Total Vertical Depth (TVD) and 

the corresponding two-way traveltime (TWT) using the time-depth values to calculate depths 

below the sea level:

Y = 516.29T

2

+ 1570.4T

Where Y = depth below seafloor in feet and T = two-way traveltime below sea level in seconds.

A detailed description of the sequence units can be found in the 2013 3D Seismic Shallow 

Geohazard Report. The Top-Hole Prognosis Chart (Figure No. 6) summarizes the stratigraphy. 

Unit A (Seafloor to Event 1): Unit A consists of continuous, low to moderate amplitude seismic 

reflectors (Figure Nos. 3, 4, and 5). Amplitudes and acoustic impedance contrasts tend to be 

moderate to low. These reflection patterns are likely comprised of hemipelagic clay, laid down 

as a drape deposit, and interbedded with fine-grained turbidites and some sands. Additionally, 

the AUV subbottom profiler shows the drape deposits are interbedded with shallow buried mass 

transport deposits (Figure No. 3) and are buried greater than 14 feet BSF. At the proposed Well 

“F” location, the clay sequence is 1,921 feet thick. 
Wellsite Report

C&C Project No. 140501

4

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Unit B (Event 1 to Event 2): Unit B consists of low to moderate amplitude, semi-continuous to 

chaotic reflectors that are 1,655 feet thick at the proposed Well “F” location (Figure Nos. 4 and 

5). These reflection patterns are likely comprised of hemipelagic clay, laid down as a drape 

deposit with interbedded mud-prone mass movement deposits and turbidite channels at the base 

of the unit.

Unit C (Event 2 to Event 3): At the proposed Well “F” location, Unit C is 2,033 feet thick of 

variable amplitude, semi-continuous to chaotic acoustic reflections (Figure Nos. 4 to 5). Unit C 

sediments are interpreted as sediments of muds interbedded with thin mud-prone mass 

movement deposits and channeling that may contain sands. 

Unit D (Event 3 to Event 4): Unit D consists of low to moderate amplitude, continuous to 

chaotic reflectors and is 2,736 feet thick at the proposed Well “F” location. The sediments in 

Unit D are interpreted as thin sequences of turbidite mud and sands with interlayered muds and 

thin mud-prone mass movement deposits that may contain sands.

Unit E (Event 4 to Event 5): At the proposed Well “F” location, Unit E consists of low to 

moderate amplitude, parallel continuous to chaotic reflectors with isolated high amplitude 

reflectors (Figure Nos. 4 and 5). Unit E sediments are interpreted as muds interbedded with thin 

mud-prone mass movement deposits and channeling that may contain sands. 

FAULTS

No buried faults are located within the vicinity of the proposed Well “F” location. The proposed 

well bore path does not cross any major faults.

SHALLOW GAS AND GAS HYDRATES

Very high-amplitude seismic anomalies are interpreted as potential regions of fluid / gas 

saturation usually associated with porous sands. Shallow gas is interpreted with the seismic 

amplitude levels and the gas risk is assessed as being at one of the following four levels. 

 Negligible - No amplitude anomalies or other gas indicators present.

 Low risk of gas - Generally indicated by increased amplitude (2-3x background 

level) and phase reversal. This may also include diffuse areas of gas blanking.

 Moderate risk of gas - Generally indicated by high amplitude (3-4x background 

level) and phase reversal.

 High risk of gas - Generally indicated by the highest amplitudes (in excess of 

4x background level), phase reversal, and a combination of other attributes 

indicative of the presence of gas, particularly velocity pull-down and masking of 

underlying sediments. Stratigraphic and structural settings may also be taken 

into account.

No subsurface amplitude anomalies are noted within the vicinity of the proposed Well “F”

location, A negligible to low risk of shallow gas (Figure No. 6) exists along the shallow section 

of the well bore for Well “F”. The well bore path will not penetrate any high-amplitude 

anomalies between the seafloor and the base of the study (Figure No. 6). 
Wellsite Report

C&C Project No. 140501

5

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

There is no indication of BSRs within the study area.

SHALLOW WATER FLOW

The BOEM database does indicate GC644 Well No. 1 (OCS-G-11080) at a water depth of 4,292 

feet BSL experienced a minor SWF at 638 feet BSF.

The overall risk of shallow water flow is negligible to moderate at the proposed Well “F”

location (Figure No. 6). The 3D seismic dataset shows transgressive marine sediments are 

present at the base of Unit A, suggesting a moderate potential for SWF. An examination of the 

3D seismic dataset indicates Units B and E are comprised of chaotic reflectors showing high 

impedance contrast, suggesting a moderate potential for SWF. Unit C and D exhibit a low risk 

of SWF. At present there is no method of quantifying the risk of SWFs, so caution is 

recommended when drilling through the potential SWF units. 

CONCLUSIONS

The proposed Well “F” surface location has a water depth of 4,485 feet MSL and is clear of 

geological constraints. No significant seafloor features are located at or within 2,000 feet of the 

proposed well that could interfere with drilling activities. 

No high or low seafloor amplitude anomalies indicating the occurrence of hardgrounds, 

carbonates, benthic communities, or potential expulsions, are found within 2,000 feet of the 

proposed Well “F” location. 

No infrastructure exists, permitted, or proposed within 2,000 feet of the proposed Well “F”

location. 

The proposed well location will not intersect any major faults along the well bore path. 

The assessment of seismic profiles suggests stratigraphic units exhibit a negligible to moderate 

(Units A, B, and E) risk for SWF and a negligible to low (Unit E) potential for gas at the Well 

“F” drill site. 

Thank you for this opportunity to be of service. Please contact us if you have any questions 

concerning this assessment.

Sincerely yours,

James Cox

Geophysicist

Enclosures

Figure No. 1. Extracted wavelet and power spectrum at the proposed Well “F” location.

Figure No. 2. Nearest side scan sonar image (Line 302) from the proposed Well “F” location.

Figure No. 3. Nearest subbottom profile record (Line 302) from the proposed Well “F” location.

Figure No. 4. Nearest 3D seismic Inline (3975) from the proposed Well “F” location.
Wellsite Report

C&C Project No. 140501

6

730 E. KALISTE SALOOM ROAD, LAFAYETTE, LA 70508

Figure No. 5. Nearest 3D seismic Crossline (5932) from the proposed Well “F” location.

Figure No. 6. Top-hole Prognosis Chart for the proposed Well “F” location.

Sheet 1. Proposed Well “E” & “F” Locations 
Freeport-McMoRan Oil & Gas LLC Section 4 – Pg. 8 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 4 

HYDROGEN SULFIDE INFORMATION 

4.1 CONCENTRATION 

FM O&G anticipates encountering 0 ppm H2S during the proposed operations. 

4.2 CLASSIFICATION 

In accordance with Title 30 CFR 250.490(c), FM O&G requests that the area of proposed 

operations be classified by the BOEM as H2S absent. 
Freeport-McMoRan Oil & Gas LLC Section 5 – Pg. 9 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

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’). C & C Technologies Survey Services 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. FM O&G 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 site 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) 

Green Canyon Blocks 600, 644 and 645 are 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) 

Green Canyon Blocks 600, 644 and 645 are 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 

Green Canyon Blocks 600, 644 and 645 are not located within 30 meters (100 feet) of 

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

required. 

5.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS 

BOEM has determined there is enough data gathered in Grid Area Number 10; therefore, we 

will not be conducting any ROV surveys either pre-spud or post-drill operations per NTL No. 

2008-G06, “Remotely Operated Vehicle Surveys in Deepwater” (Extended by NTL No. 2014-
Freeport-McMoRan Oil & Gas LLC Section 5 – Pg. 10 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

N01, “Elimination of Expiration Dates on Certain Notices to Lessees and Operators Pending 

Review and Reissuance”).

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND MARINE 

MAMMAL INFORMATION 

The federally listed endangered and threatened species potentially occurring in the lease area 

and along the Gulf Coast are provided in the table below. 

Species Scientific Name Status Potential 

Presence 

Critical Habitat Designated 

in the Gulf of Mexico 

Lease 

Area 

Coastal

Marine Mammals 

Manatee, West 

Indian 

Trichechus manatus latirostris E -- X Florida (peninsular) 

Whale, Blue Balaenoptera masculus E Xa -- None 

Whale, Finback Balaenoptera physalus E Xa -- None 

Whale, 

Humpback 

Megaptera novaeangliae E Xa

 -- None 

Whale, North 

Atlantic Right 

Eubalaena glacialis E Xa

 -- None 

Whale, Sei Balaenopiera borealis E Xa -- None 

Whale, Sperm Physeter catodon 

(=macrocephalus) 

E X -- None 

Terrestrial Mammals 

Mouse, Beach 

(Alabama, 

Choctawatchee, 

Perdido Key, St. 

Andrew) 

Peromyscus polionotus E - X Alabama, Florida 

(panhandle) beaches 

Birds 

Plover, Piping Charadrius melodus T - X Coastal Texas, Louisiana, 

Mississippi, Alabama and 

Florida (panhandle) 

Crane, Whooping Grus Americana E - X Coastal Texas 

Reptiles 

Sea Turtle, 

Green 

Chelonia mydas T,Eb

 X X None 

Sea Turtle, 

Hawksbill 

Eretmochelys imbricata E X X None 

Sea Turtle, 

Kemp’s Ridley 

Lepidochelys kempli E X X None 

Sea Turtle, 

Leatherback 

Dermochelys coriacea E X X None 

Sea Turtle, 

Loggerhead 

Caretta caretta T X X Texas, Louisiana, 

Mississippi, Alabama, 

Florida 

Fish 

Sturgeon, Gulf Acipenser oxyrinchus 

(=oxyrhynchus) desotoi 

T X X Coastal Louisiana, 

Mississippi, Alabama and 

Florida (p anhandle) 

Corals 

Coral, Elkhorn Acopora palmate T - X Florida Keys and Dry 

Tortugas 

Coral, Staghorn Acopora cervicornis T ‐  X Florida 

Abbreviations: E = Endangered; T = Threatened 
Freeport-McMoRan Oil & Gas LLC Section 5 – Pg. 11 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

a The Blue Fin, Humpback, North Atlantic Right, and Sei Whales are rare or extralimital in the Gulf of Mexico and are 

unlikely to be present in the lease area. b Green Sea turtle is threatened, except for the Florida breeding population, which is listed as endangered.

5.9 ARCHAEOLOGICAL REPORT 

Green Canyon Blocks 600, 644 and 645 have been determined as potentially containing historic 

or prehistoric cultural resources. 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 was provided with EP (Control No. N-9750). 

FM O&G, as a prudent operator, will avoid all sites, structures, or objects of historical or 

archaeological significance. Such findings will be reported and every reasonable effort will be 

made to preserve and protect the cultural or archaeological resource. 

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-G05, “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” (Extended by NTL No. BOEM 2014-G05, “Extension of Prior Notices to Lessees”). 
-80'

-81' -7600'

-8525'

-8250'

-8100'

-8000'-475'

-525'

-600'

-575'

-900'

PROP. FLEXIBLE

PROD. RISER 2 -600'

MILITARY

WARNING

AREA W-92

X= 2,433,561.00'

Y= 9,920,240.00'


1


:

GC644

OCS-G-11080

FREEPORT-McMoRan

HOLSTEIN

MOORING

LINES

104

99

UTM15N

GRID NORTH

JOB No: REVISED: DATE:

FILENAME:

140501 Aug. 13, 2014

1,000' 0' 1,000'

SCALE IN US SURVEY FEET

Normal fault with depth of burial below seafloor

(Hachures on downthrown side) -177'

Fault scarp with seafloor displacement in feet

(Hachures on downthrown side)

99 Sonar contact & reference number

Amplitude anomalies within Unit E (2.035 to 3.988 sec/BSL)

Depth below seafloor = 5,334 - 10,199 feet

Navigation trackline with name, direction run, fix, and

fix number (Job No. 130277)

-80' Buried Mass Transport Deposit 2 with depth below seafloor

Drag scar

Inline number for 3D seismic data Spacing = 20 meters

(65.62 feet)

Crossline number for 3D seismic data Spacing = 25 meters

(82.01 feet)

HAZARD MAP

PROPOSED WELL "A" LOCATION

Block 644 (OCS-G-11080)

Green Canyon Area

104 16.9'x1.0'x0.0' 2,432,443' 9,918,999'

99 6.0'x4.1'x0.4' 2,431,909' 9,919,582'

SONAR CONTACTS

NUM. DESCRIPTION X COORDINATE Y COORDINATE

PROP. FLEXIBLE

PROD. F/L 2
-80'

-81'

-8525'

-8250'

-8100'

-8000'

-4600' -475'

-275'

P14

P13

OCS-G-11080

Well No. 1

HOLSTEIN MOORING LINES

HOLSTEIN MOORING LINES PROD. RISER 1 FLEXIBLE PROP.

PROP. FLEXIBLE

PROD. RISER 2

X= 2,436,361.00'

Y= 9,921,840.00'


1


:

GC644

OCS-G-11080

FREEPORT-McMoRan

104

90

88

87

UTM15N

GRID NORTH

PROP. FLEXIBLE PROD. F/L 2

MILITARY

WARNING

AREA W-92

JOB No: REVISED: DATE:

FILENAME:

140501 Aug. 13, 2014

1,000' 0' 1,000'

SCALE IN US SURVEY FEET

Normal fault with depth of burial below seafloor

(Hachures on downthrown side) -177'

Fault scarp with seafloor displacement in feet

(Hachures on downthrown side)

79 Sonar contact & reference number

Amplitude anomalies within Unit E (2.035 to 3.988 sec/BSL)

Depth below seafloor = 5,334 - 10,199 feet

Navigation trackline with name, direction run, fix, and

fix number (Job No. 130277)

-80' Buried Mass Transport Deposit 2 with depth below seafloor

Drag scar

Inline number for 3D seismic data Spacing = 20 meters

(65.62 feet)

Crossline number for 3D seismic data Spacing = 25 meters

(82.01 feet)

HAZARD MAP

PROPOSED WELL "B" LOCATION

Block 644 (OCS-G-11080)

Green Canyon Area

All infrastructure shown is from company file information only.

Amplitude anomalies within Unit D (1.840 to 3.828 sec/BSL)

Depth below seafloor = 4,637 - 8,828 feet

Seafloor surface location of well

Debris zone 104 16.9'x1.0'x0.0' 2,432,443' 9,918,999' 90 6.3'x3.1'x0.9' 2,437,791' 9,921,833' 88 7.7'x2.9'x0.5' 2,438,356' 9,922,155' 87 8.7'x3.9'x0.0' 2,437,977' 9,922,473' SONAR CONTACTS

NUM. DESCRIPTION X COORDINATE Y COORDINATE
-17'

-20'

-153'

P1

P2

GC601

GC645

S-18958 ENBRIDGE 20" (Permitted)

MILITARY

WARNING

AREA W-92

OCS-G-33846

BHP

OCS-G-11081

FREEPORT-McMoRan

X= 2,444,640.00'

Y= 9,930,093.00'


1


:

HOLSTEIN

MOORING

LINES

S-13677

BP 24"-28"

59

58

51

50

48

43

UTM15N

GRID NORTH

JOB No: REVISED: DATE:

FILENAME:

140501 Aug. 13, 2014

1,000' 0' 1,000'

SCALE IN US SURVEY FEET

43 Sonar contact & reference number

Amplitude anomalies within Unit E (2.035 to 3.988 sec/BSL)

Depth below seafloor = 5,334 - 10,199 feet

Navigation trackline with name, direction run, fix, and

fix number (Job No. 130277)

-80' Buried Mass Transport Deposit 2 with depth below seafloor

Drag scar

Inline number for 3D seismic data Spacing = 20 meters

(65.62 feet)

Crossline number for 3D seismic data Spacing = 25 meters

(82.01 feet)

HAZARD MAP

PROPOSED WELL "C" LOCATION

Block 645 (OCS-G-11081)

Green Canyon Area

All infrastructure shown is from company file information only.

59 8.4'x4.1'x0.5' 2,443,236' 9,927,860'

58 6.0'x5.0'x1.8' 2,447,195' 9,927,957'

51 5.1'x4.0'x0.0' 2,442,117' 9,930,606'

50 7.3'x5.0'x0.0' 2,441,843' 9,930,798'

48 6.7'x2.2'x0.0' 2,443,927' 9,931,094'

43 7.2'x4.2'x0.0' 2,442,864' 9,932,078'

SONAR CONTACTS

NUM. DESCRIPTION X COORDINATE Y COORDINATE

-17' Buried Mass Transport Deposit 1 with depth below seafloor

Existing pipeline or umbilical

Permitted pipeline or umbilical
-17'

-20'

-153'

P1

P2

GC601

GC645

S-18958 ENBRIDGE 20" (Permitted)

MILITARY

WARNING

AREA W-92

OCS-G-33846

BHP

OCS-G-11081

FREEPORT-McMoRan

X= 2,444,701.00'

Y= 9,930,179.00'


1


:

HOLSTEIN

MOORING

LINES

S-13677

BP 24"-28"

59

58

51

50

48

43

JOB No: REVISED: DATE:

FILENAME:

140501 Aug. 13, 2014

1,000' 0' 1,000'

SCALE IN US SURVEY FEET

43 Sonar contact & reference number

Amplitude anomalies within Unit E (2.035 to 3.988 sec/BSL)

Depth below seafloor = 5,334 - 10,199 feet

Navigation trackline with name, direction run, fix, and

fix number (Job No. 130277)

-80' Buried Mass Transport Deposit 2 with depth below seafloor

Drag scar

Inline number for 3D seismic data Spacing = 20 meters

(65.62 feet)

Crossline number for 3D seismic data Spacing = 25 meters

(82.01 feet)

HAZARD MAP

PROPOSED WELL "D" LOCATION

Block 645 (OCS-G-11081)

Green Canyon Area

-17' Buried Mass Transport Deposit 1 with depth below seafloor

59 8.4'x4.1'x0.5' 2,443,236' 9,927,860'

58 6.0'x5.0'x1.8' 2,447,195' 9,927,957'

51 5.1'x4.0'x0.0' 2,442,117' 9,930,606'

50 7.3'x5.0'x0.0' 2,441,843' 9,930,798'

48 6.7'x2.2'x0.0' 2,443,927' 9,931,094'

43 7.2'x4.2'x0.0' 2,442,864' 9,932,078'

SONAR CONTACTS

NUM. DESCRIPTION X COORDINATE Y COORDINATE

Existing pipeline or umbilical

Permitted pipeline or umbilical

UTM15N

GRID NORTH
-16'

-14'

-11'

GC601

GC600

OCS-G-33846

BHP

OCS-G-34999

FREEPORT-McMoRan

UTM15N

GRID NORTH

X= 2,438,630.00'

Y= 9,943,230.00'


1


:

MILITARY

WARNING

AREA W-92

JOB No: REVISED: DATE:

FILENAME:

140501 Aug. 13, 2014

1,000' 0' 1,000'

SCALE IN US SURVEY FEET

Navigation trackline with name, direction run, fix, and

fix number (Job No. 130277)

-80' Buried Mass Transport Deposit 2 with depth below seafloor

Inline number for 3D seismic data Spacing = 20 meters

(65.62 feet)

Crossline number for 3D seismic data Spacing = 25 meters

(82.01 feet)

HAZARD MAP

PROPOSED WELL "E" LOCATION

Block 600 (OCS-G-34999)

Green Canyon Area

-17' Buried Mass Transport Deposit 1 with depth below seafloor
-16'

-14'

-11'

GC601

GC600

OCS-G-33846

BHP

OCS-G-34999

FREEPORT-McMoRan

UTM15N

GRID NORTH

X= 2,438,700.00'

Y= 9,943,150.00'


1


:

MILITARY

WARNING

AREA W-92

Navigation trackline with name, direction run, fix, and

fix number (Job No. 130277)

-80' Buried Mass Transport Deposit 2 with depth below seafloor

Inline number for 3D seismic data Spacing = 20 meters

(65.62 feet)

Crossline number for 3D seismic data Spacing = 25 meters

(82.01 feet)

HAZARD MAP

PROPOSED WELL "F" LOCATION

Block 600 (OCS-G-34999)

Green Canyon Area

All infrastructure shown is from company file information only.

-17' Buried Mass Transport Deposit 1 with depth below seafloor

JOB No: REVISED: DATE:

FILENAME:

140501 Aug. 13, 2014

1,000' 0' 1,000'

SCALE IN US SURVEY FEET
Freeport-McMoRan Oil & Gas LLC Section 6 – Pg. 12 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

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. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM

Projected

Projected generated waste Projected ocean discharges Downhole Disposal

Type of Waste Composition Projected Amount Discharge Rate Discharge Method

Cuttings wetted with water-based fluid Cuttings coated while drilling with WBM 2,200 BBLS/WELL 314 BBLS/DAY Discharged to mudline prior to riser installation. Based on seven total 

days of drilling with WBM. No

Answer yes or no

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

Water-based drilling fluid Water, NaCI (salt), PHPA polymer and Barium

Sulfate (Barite) 60,000 BBLS/WELL 8,571 BBLS/DAY

Discharge at the mudline prior to the riser installation.

Nominal amount of unused fluid may be discharged at the

surface. Based on seven days of drilling with WBM.

No

Will humans be there? If yes, expect conventional waste

30,020 BBLS/WELL 158 BBLS/DAY USCG approved MSD with chlorination

Cuttings wetted with synthetic-based fluid Cuttings coated with synthetic drilling fluids,

including drilled out cement 7,500 BBLS/WELL 77 BBLS/DAY

Discharged to surface. Treated cutting will be discharged

overboard during drilling of the SBM intervals. Discharge rate is based 

upon 98 days of drilling. Cuttings will

be processed through a cuttings dryer, substantially reducing

the ROC percentage.

No

Domestic waste

Sanitary

Gray water from living quarters 65,740 BBLS/WELL 346 BBLS/DAY Chlorinate and discharge overboard No

Sanitary waste from living quarters, control 

rooms and change rooms.

Will you conduct well treatment, completion, or workover?

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

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

N/A N/A N/A N/A N/A

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

Deck Drainage Deck drainage from drilling floor 950 BBLS/WELL 5 BBLS/DAY No drill floor drainage routed to sea. All retained on board and 

processed to <15ppm or sent to shore for disposal No

No

N/A

Will you be covered by an individual or general NPDES permit? General NPDES Permit # GMG290534

Well treatment fluids

Well completion fluids

Workover fluids

Desalinization unit discharge

Blowout prevent fluid

Ballast water

Bilge water

Excess cement at seafloor

Fire water 

Cooling water Sea Water with no additional chemicals 112,546,310 BBLS/WELL 592,349 BBLS/DAY Hull discharge overboard No

N/A

N/A

N/A

Rejected water from the watermaker. 286,900 BBLS/WELL 1,510 BBLS/DAY Hull discharge overboard No

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

Sea Water with no additional chemicals 380 BBLS/WELL 2 BBLS/DAY Hull discharge overboard No

Cement Slurry 495 BBLS/WELL 495 BBLS/DAY Discharge at seafloor during riserless operations. Discharge rate based 

upon 1 day (22" cement returns) No

N/A N/A N/A N/A No

Potable Water with

4% Stack-Magic ECO-Fv2 1,200 BBLS/WELL 6 BBLS/DAY Discharge at the seafloor or with deck drainage when testedat surface No

Uncontaminated seawater used to maintain 

proper draft 27,000 BBLS/WELL 142 BBLS/DAY Hull discharge overboard. Based upon 5 major ballast operations, with rig at operating draft minimal ballast change is required No
Freeport-McMoRan Oil & Gas LLC Section 7 – Pg. 13 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

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 

Included as Attachment 7-A are Air Emission Worksheets which show the emissions 

calculations for the Plan Emissions and if different, a set of worksheets showing the emissions 

calculations for the Complex Total emissions. 

This information was calculated by: Kim Sayre 

281-578-3388 

kim.sayre@jccteam.com 
ATTACHMENT 7-A

EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB 

COMPANY Freeport-McMoRan Oil & Gas LLC

AREA Green Canyon BLOCKS 600/644/645

LEASE OCS-G 34999/11080/11081PLATFORM NAWELL Locations A, B, C, D, E, FCOMPANY CONTACT Kim SayreTELEPHONE NO. 281-578-3388REMARKS

FM O&G will use a drillship similar to the Deepwater Champion. Total horsepower is calculated at 82% of actual horsepower of Deepwater Champion (Total horsepower = 60,348 hp). Actual fuel usage calculated ahighest monthly average in 6 month fuel usage data for Deepwater Champion.

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). 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

Sulphur 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 BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 2 of 8
EMISSIONS CALCULATIONS 1ST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Freeport-McMoRan Oil & Green Canyon 600/644/645 OCS-G 34999/1 NA Locations A, B, C, D, E, F Kim Sayre 281-578-3388 

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 (Drill Rig - 82%) Deepwater Champion

49486 2390.1738 14179.00 24 298 34.88 160.01 1199.00 35.97 261.60 30.83 

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 6 129 1.46 6.68 50.03 1.50 10.92 0.56 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 129 3.10 14.23 106.61 3.20 23.26 2.00 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 129 3.10 14.23 106.61 3.20 23.26 2.00 

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 208,333.33 24 2 0.12 14.87 12.56 80.94 

2017 YEAR TOTAL 42.54 195.27 1477.12 56.43 399.97 35.39 

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 3929.40 

118.0

PXP will use a drillship similar to the Deepwater Champion. Total horsepower is calculated at 82% of actual horsepower of Deepwater Champion (Total horsepower = 60,348 hp). Actual fuel usage calculausage data for Deepwater Champion. 

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 3 of 8
EMISSIONS CALCULATIONS 2ND YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Freeport-McMoRan Oil &Green Canyon 600/644/645 OCS-G 34999/1 NA Locations A, B, C, D, E, F Kim Sayre 281-578-3388 

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 S

DRILLING

PRIME MOVER>600hp diesel (Drill Rig - 82%) Deepwater Champion

49486 2390.1738 14179.00 24 365.00 34.88 160.01 1199.00 35.97 261.60 37.76 17

PRIME MOVER>600hp diesel 0 0 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 156.00 1.46 6.68 50.03 1.50 10.92 0.68 3VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 156.00 3.10 14.23 106.61 3.20 23.26 2.42 1VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 156.00 3.10 14.23 106.61 3.20 23.26 2.42 1

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

VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0MISC. 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 0WELL TEST GAS FLARE 208,333.33 24 2 0.12 14.87 12.56 80.94 0

2018 YEAR TOTAL 42.54 195.27 1477.12 56.43 399.97 43.28 19

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 3929.40 39

118.0

PXP will use a drillship similar to the Deepwater Champion. Total horsepower is calculated at 82% of actual horsepower of Deepwater Champion (Total horsepower = 60,348 hp). Actual fuel usage calculat

usage data for Deepwater Champion. 

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 4 of 8
EMISSIONS CALCULATIONS 3RD YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Freeport-McMoRan Oil &Green Canyon 600/644/645 OCS-G 34999/1 NA Locations A, B, C, D, E, F Kim Sayre 281-578-3388 

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 S

DRILLING

PRIME MOVER>600hp diesel (Drill Rig - 82%) Deepwater Champion

49486 2390.1738 14179.00 24 365 34.88 160.01 1199.00 35.97 261.60 37.76 17

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 156 1.46 6.68 50.03 1.50 10.92 0.68 3VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 156 3.10 14.23 106.61 3.20 23.26 2.43 1VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 156 3.10 14.23 106.61 3.20 23.26 2.43 1

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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0WELL TEST GAS FLARE 208,333.33 24 2 0.12 14.87 12.56 80.94 0

2019 YEAR TOTAL 42.54 195.27 1477.12 56.43 399.97 43.30 19

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 3929.40 39

118.0

PXP will use a drillship similar to the Deepwater Champion. Total horsepower is calculated at 82% of actual horsepower of Deepwater Champion (Total horsepower = 60,348 hp). Actual fuel usage calculat

usage data for Deepwater Champion. 

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 5 of 8
EMISSIONS CALCULATIONS 4TH YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Freeport-McMoRan Oil & Green Canyon 600/644/645 OCS-G 34999/1 NA Locations A, B, C, D, E, F Kim Sayre 281-578-3388 

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 (Drill Rig - 82%) Deepwater Champion

49486 2390.1738 14179.00 24 56 34.88 160.01 1199.00 35.97 261.60 5.79 

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 6 24 1.46 6.68 50.03 1.50 10.92 0.10 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 24 3.10 14.23 106.61 3.20 23.26 0.37 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 24 3.10 14.23 106.61 3.20 23.26 0.37 

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 COUNT

TANK- 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 208,333.33 24 2 0.12 14.87 12.56 80.94 

2020 YEAR TOTAL 42.54 195.27 1477.12 56.43 399.97 6.64 

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 3929.40 

118.0

PXP will use a drillship similar to the Deepwater Champion. Total horsepower is calculated at 82% of actual horsepower of Deepwater Champion (Total horsepower = 60,348 hp). Actual fuel usage calculatedata for Deepwater Champion. 

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 6 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELLFreeport-McMoRGreen Canyon 600/644/645 OCS-G 34999/11080/1NA Locations A, B, C, 

E, F

Emitted Substance

Year

 PM SOx NOx VOC CO

2017 35.39 162.37 1217.04 36.80 267.402018 43.28 198.56 1488.15 44.94 326.552019 43.30 198.63 1488.67 44.95 326.672020 6.64 30.48 228.70 7.15 51.76

Allowable 3929.40 3929.40 3929.40 3929.40 81796.29

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 8 of 8
Day 1 2 3 4 5 6

1 11,174 gal 16,299 gal 11,042 gal 17,594 gal 13,605 gal 17,383 gal

2 14,133 gal 8,321 gal 11,095 gal 20,843 gal 12,786 gal 20,658 gal

3 17,409 gal 13,816 gal 11,941 gal 15,296 gal 8,612 gal 14,318 gal

4 5,733 gal 12,073 gal 14,529 gal 14,292 gal 12,231 gal 22,032 gal

5 34,818 gal 13,658 gal 11,359 gal 23,353 gal 12,231 gal 12,443 gal

6 16,775 gal 11,386 gal 9,510 gal 31,886 gal 12,469 gal 20,658 gal

7 14,662 gal 12,865 gal 10,223 gal 10,725 gal 13,103 gal 11,016 gal

8 16,167 gal 17,726 gal 11,016 gal 12,495 gal 11,174 gal 15,824 gal

9 14,133 gal 18,043 gal 10,567 gal 14,741 gal 14,556 gal 10,699 gal

10 12,046 gal 13,209 gal 10,514 gal 12,627 gal 18,017 gal 6,789 gal

11 12,733 gal 14,952 gal 13,182 gal 12,760 gal 17,752 gal 11,280 gal

12 12,812 gal 9,880 gal 10,567 gal 12,390 gal 13,895 gal 12,944 gal

13 15,190 gal 23,141 gal 10,752 gal 10,857 gal 12,046 gal 9,722 gal

14 14,001 gal 9,801 gal 11,359 gal 9,695 gal 11,412 gal 13,763 gal

15 10,223 gal 7,819 gal 10,910 gal 8,638 gal 12,073 gal 16,114 gal

16 7,661 gal 5,072 gal 11,069 gal 12,575 gal 10,039 gal 14,080 gal

17 14,635 gal 10,540 gal 12,786 gal 12,099 gal 14,397 gal 15,613 gal

18 11,650 gal 14,107 gal 10,884 gal 7,661 gal 13,314 gal 15,771 gal

19 15,005 gal 18,334 gal 15,692 gal 9,537 gal 14,080 gal 15,401 gal

20 14,899 gal 14,450 gal 7,899 gal 9,827 gal 11,650 gal 14,160 gal

21 13,473 gal 12,495 gal 10,646 gal 18,386 gal 11,967 gal 10,620 gal

22 12,575 gal 19,364 gal 8,189 gal 11,095 gal 14,979 gal 18,439 gal

23 10,778 gal 16,854 gal 11,174 gal 10,778 gal 13,552 gal 15,375 gal

24 10,857 gal 6,234 gal 9,642 gal 10,250 gal 10,725 gal 18,862 gal

25 12,786 gal 12,944 gal 12,443 gal 16,009 gal 10,250 gal 14,477 gal

26 10,805 gal 8,586 gal 11,069 gal 12,786 gal 12,944 gal 10,963 gal

27 12,469 gal 12,760 gal 14,899 gal 12,284 gal 9,589 gal 11,597 gal

28 11,148 gal 14,556 gal 10,673 gal 12,231 gal 11,016 gal 12,125 gal

29 13,684 gal 9,193 gal 9,827 gal 11,148 gal 11,359 gal

30 13,552 gal 13,869 gal 15,375 gal 14,688 gal 11,307 gal

31 13,499 gal 15,507 gal 13,763 gal

Average 13,596 gal 12,734 gal 11,290 gal 13,691 gal 12,677 gal 14,179 gal

Transit Days

Daily Fuel Usage for a 6 month period

Month
Freeport-McMoRan Oil & Gas LLC Section 8 – Pg. 14 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

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 Oil Spill Response Plan 

(OSRP) filed by Freeport-McMoRan Oil & Gas LLC (Company No. 03280) dated January 2014 

and last approved on February 4, 2014 (OSRP Control No. O-713). 

8.2 SPILL RESPONSE SITES 

Primary Response Equipment Location Preplanned Staging Location 

Houma, LA Houma, LA 

Harvey, LA Harvey, LA 

Leeville, LA Fourchon, LA 

8.3 OSRO INFORMATION 

FM O&G’s primary equipment providers are Clean Gulf Associates (CGA) and Marine Spill 

Response Corporation (MSRC), and National Response Corporation (NRCC). Clean Gulf 

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

supervisor to operate the equipment. MSRC personnel are responsible for operating MSRC 

response equipment. Through its Independent Contractor Network (ICN), NRCC will also 

provide closest available personnel, as well as an NRCC ICN supervisor to operate the 

equipment. 

8.4 WORST CASE SCENARIO DETERMINATION 

Category Regional OSRP 

WCD - Drilling 

EP 

WCD - Drilling 

Type of activity Exploratory Drilling Exploratory Drilling 

Facility location (area/block) GC 393 GC 645 

Facility designation Well Location B Well Location C 

Distance to nearest shoreline (miles) 96.5 mi. 118 mi. 

Storage tanks (bbl) 0 0 

Uncontrolled blowout (bbl) 400,000 77,362 

Total volume (bbl) 400,000 77,362 

Type of oil(s) 

(crude, condensate, diesel) 

Crude Crude 

API gravity 25° 25.8° 

The Regional OSRP Drilling WCD calculations of 400,000 bbls were accepted under Plan 

Control No. N-9739 approved March 31, 2014. 

FM O&G has determined that the worst-case scenario from the activities proposed in this EP 

does not supersede the worst-case scenario from our approved Regional OSRP.

Since Freeport-McMoRan Oil & Gas LLC has the capability to respond to the worst-case spill 

scenario included in our Regional OSRP approved on February 4, 2014, and since the worst-
Freeport-McMoRan Oil & Gas LLC Section 8 – Pg. 15 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

case scenario determined for our DOCD does not replace the worst-case scenario in our 

Regional OSRP, Freeport-McMoRan Oil & Gas LLC hereby certifies that Freeport-McMoRan Oil 

& Gas LLC has the capability to respond, to the maximum extent practicable, to a worst-case 

discharge, or a substantial threat of such a discharge, resulting from the activities proposed in 

this DOCD.

8.5 OIL SPILL RESPONSE DISCUSSION 

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

8.6 MODELING REPORT 

Modeling reports are not required for the activities proposed in this plan.
 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 77,362 barrels of crude oil with an API gravity of 25.8°. 

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 3% probability of impact to the shorelines of Cameron Parish 

and/or Plaquemines Parish, Louisiana within 30 days. Cameron Parish includes the east side of 

Sabine Lake, Sabine National Wildlife Refuge, Calcasieu Lake, Lacassine National Wildlife 

Refuge (inland) and Grand Lake. Cameron Parish also includes the area along the coastline from 

Sabine Pass to Big Constance Lake in Rockefeller Wildlife Refuge. This region is composed of 

open public beaches, marshlands and swamps. It serves as a habitat for numerous birds, finfish 

and other animals, including several rare, threatened and endangered species. 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 

FM O&G 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 12% or 

approximately 9,283 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 68,079 barrels remaining. 

Spill Response GC 645, Well Location C Barrels of Oil 

WCD Volume 77,362 

Less 12% natural evaporation/dispersion 9,283 

Remaining volume 68,079 

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. 
FM O&G’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, insitu 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 spill response equipment, with a total derated skimming capacity of 126,819 

barrels. Temporary storage associated with skimming equipment equals 9,700 barrels. If 

additional storage is needed, various tank barges with a total of 245,000+ barrels of storage 

capacity 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 Cameron and/or 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 100,626 barrels. Temporary storage associated with skimming equipment equals 1,667 

barrels. If additional storage is needed, various tank barges with a total of 116,000+ barrels of 

storage capacity 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. Master Service Agreements with AMPOL, Miller Environmental, and OMI 

Environmental will ensure access to more than 161,000 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 Cameron Parish and 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. FM O&G’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, FM O&G 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 

60 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 to include but not 

be 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 

FM O&G 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 normally be supervised by the Operations Section as 

necessary for close quarter vessel response activities. A Simultaneous Operations (SIMOPS) 

unit may be established in the Source Control Section to control operations if events require a 

significant number of large vessels to operate independently, but in coordination with each other. 

This unit would normally monitor the subsurface activities of each vessel (ROV, dispersant 

application, well control support, etc.), as well. 

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 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 
Offshore Response Actions 

Equipment Deployment

Surveillance 

 Surveillance Aircraft: within two hours of 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 ASI on standby 

 With the FOSC, conduct analysis to determine appropriateness of dispersant application 

(refer to Section 18) 

 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 situational status 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 

Oceangoing Boom Barge 

 Containment at the source 

 Increased/enhanced skimmer encounter rate 

 Protection booming 

In-situ Burn assets 

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

affected 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 
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 95’ Fast Response Vessels (FRVs) 

 Designed to be a first vessel on scene

 Capable of maintaining the initial Command and Control function for on water recovery 

operations

 24 hour oil spill detection capability 

 Highly mobile and efficient skimming capability 

 Use as far off-shore as safely possible 

CGA FRUs 

 To the area of the thickest oil 

 Use as far off-shore as allowed 

 VOOs 100’ minimum 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 (See Appendix E) 

 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 FM O&G’s contracted resources as applicable 

 Industry vessels are ideal 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 for ISB operations or boom 

tending 

 Expect mission specific and safety training to be required 

 Plan with the US Coast Guard for vessel inspections 

 Place VOOs in Division or Groups as needed 

 Use organic on-board storage if appropriate 

 Maximize non-organic storage appropriate to vessel limitations 

 Decant as appropriate after approval to do so has been granted 

 Assign bulk storage barges to each Division/Group 

 Position bulk storage barges as close to skimming units as possible 

 Utilize large skimming vessel (e.g. barges) storage for smaller vessel offloading 

 Maximize skimming area (swath) to the optimum width given sea conditions and 

available equipment 

 Maximize use of oleophilic skimmers in all operations, but especially offshore 

 Nearshore, use shallow water barges and shuttle to skimming units to minimize 

offloading time 

 Plan and equip to use all offloading capabilities of the storage vessel to minimize 

offloading time 

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. KOSEQ Arm systems are 

built for rough conditions, and they should be used until their operational limit (9.8’ seas) is met. 

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. 

Surface Oil Recovery Considerations and Tactics 

(Offshore and Near-shore Operations) 

Maximization of skimmer-oil encounter rate

 Place barges in skimming task forces, groups, etc., to reduce recovered oil offloading 

time 

 Place barges alongside skimming systems for immediate offloading of recovered oil 

when practicable 

 Use two vessels, each with heavy sea boom, in an open-ended “V” configuration to 

funnel surface oil into a trailing skimming unit’s organic, V-shaped boom and skimmer 

(see page 7, CGA Equipment Guide Book and Tactic Manual (CGATM) 

 Use secondary vessels and heavy sea boom to widen boom swath beyond normal 

skimming system limits (see page 15, CGATM) 

 Consider night-time operations, first considering safety issues 
 Utilize all available advanced technology systems ( IR, X-Band Radar, etc.) to determine 

the location of, and move to, recoverable oil 

 Confirm the presence of recoverable oil prior to moving to a new location 

Maximize skimmer system efficiency 

 Place weir skimming systems in areas of calm seas and thick oil 

 Maximize the use of oleophilic skimming systems in heavier seas 

 Place less mobile, high EDRC skimming systems (e.g. HOSS Barge) in the largest 

pockets of the heaviest oil 

 Maximize onboard recovered oil storage for vessels. 

 Obtain authorization for decanting of recovered water as soon as possible 

 Use smaller, more agile skimming systems to recover streamers of oil normally found 

farther from the source. Place recovered oil barges nearby 

Recovered Oil Storage 

 Smaller barges in larger quantities will increase flexibility for multi-location skimming 

operations 

 Place barges in skimming task forces, groups, etc., to reduce recovered oil offloading 

time 

 Procure and deploy the maximum number of portable tanks to support Vessel of 

Opportunity Skimming Systems if onboard storage is not available 

 Maximize use of the organic recovered oil storage capacity of the skimming vessel 

Command, Control, and Communications (C3) 

 Publish, implement, and fully test an appropriate communications plan 

 Design an operational scheme, maintaining a manageable span of control 

 Designate and mark C3

 vessels for easy aerial identification 

 Designate and employ C3 aircraft for task forces, groups, etc. 

 Use reconnaissance air craft and Rapid Response Teams (RAT) to confirm the presence 

of recoverable oil 
On Water Recovery Group 

When the first skimming vessel arrives on scene, a complete site assessment will be conducted 

before recovery operations begin. Once it is confirmed that the air monitoring readings for O2, 

LEL, H2S, CO, VOC, and Benzene are all within the permissible limits, oil recovery operations 

may begin. 

As skimming vessels arrive, they will be organized to work in areas that allow for the most 

efficient vessel operation and free vessel movement in the recovery of oil. Vessel groups will 

vary in structure as determined by the Operations Section of the Unified Command, but will 

generally consist, at a minimum, of the following dedicated assets: 

 3 to 5 – Offshore skimming vessels (recovery) 

 1 – Tank barge (temporary storage) 

 1 – Air asset (tactical direction) 

 2 – Support vessels (crew/utility for supply) 

 6 to 10 – Boom vessels (enhanced booming ) 

Example (Note: Actual organization of TFs will be dependent on several factors including, asset 

availability, weather, spilled oil migration, currents, etc.) 

The 95’ FRV Breton Island out of Venice arrives on scene and conducts an initial site 

assessment. Air monitoring levels are acceptable and no other visual threats have been observed. 

The area is cleared for safe skimming operations. The Breton Island assumes command and 

control (CoC) of on-water recovery operations until a dedicated non-skimming vessel arrives to 

relieve it of those duties. 

A second 95’ FRV arrives and begins recovery operations alongside the Breton Island. Several 

more vessels begin to arrive, including a third 95’ FRV out of Galveston, the HOSS Barge (High 

Volume Open Sea Skimming System) out of Harvey, a boom barge (CGA 300) with 25,000’ of 

42” auto boom out of Leeville, and 9 Fast Response Units (FRUs) from the load-out location at 

C-Port in Port Fourchon. 

As these vessels set up and begin skimming, they are grouped into task forces (TFs) as directed 

by the Operations Section of the Unified Command located at the command post. 

Initial set-up and potential actions: 

 A 1,000 meter safety zone has been established around the incident location for vessels 

involved in Source Control 

 The HOSS Barge is positioned facing the incident location just outside of this safety zone 

or at the point where the freshest oil is reaching the surface 

 The HOSS Barge engages its Oil Spill Detection (OSD) system to locate the heaviest oil 

and maintains that ability for 24-hour operations 
 The HOSS Barge deploys 1,320’ of 67” Sea Sentry boom on each side, creating a swath 

width of 800’ 

 The Breton Island and H.I. Rich skim nearby, utilizing the same OSD systems as the 

HOSS Barge to locate and recover oil 

 Two FRUs join this group and it becomes TF1 

 The remaining 7 FRUs are split into a 2 and 3 vessel task force numbered TF2 and TF3 

 A 95’ FRV is placed in each TF 

 The boom barge (CGA 300) is positioned nearby and begins deploying auto boom in 

sections between two utility vessels (1,000’ to 3,000’ of boom, depending on conditions) 

with chain-link gates in the middle to funnel oil to the skimmers 

 The initial boom support vessels position in front of TF2 and TF3 

 A 100,000+ barrel offshore tank barge is placed with each task force as necessary to 

facilitate the immediate offload of skimming vessels 

The initial task forces (36 hours in) may be structured as follows: 

TF 1 

 1 – 95’ FRV 

 1 – HOSS Barge with 3 tugs 

 2 – FRUs 

 1 – 100,000+ barrel tank barge and associated tug(s) 

 1 – Dedicated air asset for tactical direction 

 8 – 500’ sections of auto boom with gates 

 8 – Boom-towing vessels 

 2 – Support vessels (crew/utility) 

TF 2 

 1 – 95’ FRV 

 4 – FRUs 

 1 – 100,000+ barrel tank barge and associated tug(s) 

 1 – Dedicated air asset for tactical direction 

 10 – 500’ sections of auto boom with gates 

 10 – Boom-towing vessels 

 2 – Support vessels (crew/utility) 

TF 3 

 1 – 95’ FRV 

 3 – FRUs 

 1 – 100,000+ barrel tank barge and associated tug(s) 

 1 – Dedicated air asset for tactical direction 

 8 – 500’ sections of auto boom with gates 

 8 – Boom-towing vessels 

 2 – Support vessels (crew/utility) 
Offshore skimming equipment continues to arrive in accordance with the ETA data listed in 

figure H.3a; this equipment includes 2 AquaGuard skimmers and 11 sets of Koseq Rigid 

Skimming Arms. These high volume heavy weather capable systems will be divided into 

functional groups and assigned to specific areas by the Operations Section of the Unified 

Command. 

At this point of the response, the additional TFs may assume the following configurations: 

TF 4 

 2 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs 

 1 – AquaGuard Skimmer 

 1 – 100,000+ barrel tank barge and associated tug(s) 

 1 – Dedicated air asset for tactical direction 

 2 – Support vessels (crew/utility) 

 6 – 500’ sections of auto boom with gates 

 6 – Boom-towing vessels 

TF 5 

 3 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs 

 1 – AquaGuard Skimmer 

 1 – 100,000+ barrel tank barge and associated tug(s) 

 1 – Dedicated air asset for tactical direction 

 2 – Support vessels (crew/utility) 

 8 – 500’ sections of auto boom with gates 

 8 – Boom-towing vessels 

TF 6 

 3 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs 

 1 – 100,000+ barrel tank barge and associated tug(s) 

 1 – Dedicated air asset for tactical direction 

 2 – Support vessels (crew/utility) 

 6 – 500’ sections of auto boom with gates 

 6 – Boom-towing vessels 

TF 7 

 3 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs 

 1 – 100,000+ barrel tank barge and associated tug(s) 

 1 – Dedicated air asset for tactical direction 

 2 – Support vessels (crew/utility) 

 6 – 500’ sections of auto boom with gates 

 6 – Boom-towing vessels 
Near Shore Response Actions 

Timing 

 Put near shore assets on standby and deployment 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 

 Sea state 

 Tides 

 Currents 

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 

 Dispersants are pre-approved with FOSC approval outside of 3 miles and the 10 meter 

depth curve and requires RRT VI approval inside 3 mile and/or 10 meter curve 

 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) 

Dedicated Near Shore skimming systems 

 FRVs 

 56’ shallow water skimmers 

 Egmopol and Marco SWS (protected waters) 

 Operate with aerial spotter directing systems to observed oil slicks 

VOO 

 Use FM O&G’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 

 Shoreline Cleanup Assessment Team (SCAT) assessments 

 Time to acquire personnel and equipment and their availability 

 Previous contingency planning contained in the appropriate ACP, Geographic Response 

Plan (GRP), 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 or GRP. 

 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 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 FM O&G’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, test, complete, 

flare and install subsea 

trees for 2 wells in 

GC600, 2 wells in 

GC644 and 2 wells in 

GC645 

GC 645, 

Well Location C 

118 miles from shore 

G11081 C46 Matagorda County, TX 

Brazoria County, TX 

Galveston County, TX 

Jefferson County, TX 

Cameron Parish, LA 

Vermilion Parish, LA 

Terrebonne Parish, LA 

Lafourche Parish, LA 

Plaquemines Parish, LA 

1 

1 

2 

1 

3 

1 

1 

1 

3
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (118 miles from s

68,079 bbls of crude oil (Volume considering natural weathering) 

API Gravity 25.8° 

FIGURE 2 – Equipment Response Time to GC 645, Well Location C 

Dispersants/Surveillance 

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

site 

ASI 

Basler 67T 2000 NA 2 Houma 2 2 0.8 DC 3 1200 NA 2 Houma 2 2 1 DC 3 1200 NA 2 Houma 2 2 1 Aero Commander NA NA 2 Houma 2 2 0.8 

Offshore Response

Offshore Equipment No 

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

S

CGA 

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 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 T

S

Kirby Offshore (available through contract with CGA) 

RO Barge NA 80000+ 1 Tug 6 Venice 41.75 2 0 RO Barge NA 80000+ 1 Tug 6 Venice 41.75 2 0 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 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: Fourchon

Offshore Equipment With 

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

T&T Marine (available through contract with CGA) 

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 11.4 

CGA 

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 2 2 11.4 FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 2 2 2.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 16.5 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 2 6.8 FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 2 2 0.4 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 2 2.7 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 2 2 4.7 Hydro-Fire Boom NA NA 8 Utility 40 Harvey 2 4 2.7 
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 Lake Charles 2 0 1 46’ FRV 5000 65 NA 4 Venice 2 0 1 Trinity SWS 21500 249 NA 4 Leeville 6 2 N/A Trinity SWS 21500 249 NA 4 Morgan City 6 2 N/A Trinity SWS 21500 249 NA 4 Venice 6 2 N/A 

Enterprise Marine Services LLC (available through contract with CGA) 

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: Cameron

Nearshore and Inland Skimmers 

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

CGA 

SWS Egmopol 3000 100 NA 3 Galveston 2 2 3.6 SWS Marco 3588 20 NA 3 Lake Charles 2 2 1.5 SWS Marco 3588 34 NA 3 Leeville 2 2 6.8 Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 2 2 1.5 Foilex Skim Package (TDS 150) 891 45 NA 3 Galveston 2 2 3.6 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 2 2 1.5 2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Lake Charles 2 2 1.5 

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 

CGA 

SWS Egmopol 3000 100 NA 3 Morgan City 2 2 4.9 SWS Marco 3588 34 NA 3 Venice 2 2 0 Rope Mop 77 2 0 3 Harvey 2 2 2.1 Foilex Skim Package (TDS 150) 891 45 NA 3 Harvey 2 2 2.1 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 2 2 2.1 
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 

Miller (available through MSA) 

14,000’ 18” Boom 6 Crew 12 Sulphur, LA 1 1 8.3 2 

OMI Environmental (available through MSA) 

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 

Staging Area: Cameron 

Shoreline Protection 

Boom VOO Persons Req. Storage/Warehouse Location Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Site 

OMI Environmental (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 3.8 2 10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 1.4 2 
Staging Area: Cameron 

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

Deploy

CGA 

Wildlife Support Trailer NA NA NA 2 Harvey 2 2 7 1 Bird Scare Guns (48) NA NA NA 2 Harvey 2 2 7 1 Bird Scare Guns (12) NA NA NA 2 Galveston 2 2 3.6 1 Bird Scare Guns (12) NA NA NA 2 Aransas Pass 2 2 9.9 1 Bird Scare Guns (24) NA NA NA 2 Lake Charles 2 2 1.5 1 Bird Scare Guns (24) NA NA NA 2 Leeville 2 2 6.8 1 

Response Asset Total 

Offshore EDRC 126,819 

Offshore Recovered Oil Storage 254,700+ 

Nearshore / Shallow Water EDRC 100,626 

Nearshore / Shallow Water Recovered Oil Storage 117,667 
Freeport-McMoRan Oil & Gas LLC Section 9 – Pg. 16 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 9 

ENVIRONMENTAL MONITORING INFORMATION 

9.1 MONITORING SYSTEMS 

FM O&G will monitor loop currents per the requirements as set forth in NTL No. 2009-G02, 

“Ocean Current Monitoring” (Extended by NTL No. 2014-G05, “Extension of Prior Notices to 

Lessees”). FM O&G subscribes to Wilkens Weather Technologies for weather forecasts and 

monitoring. Horizon Marine, Inc. provides Gulf of Mexico loop and eddy current forecasts. 

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. 

FM O&G 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 

Green Canyon Blocks 600, 644 and 645 are not located in the Flower Garden Banks National 

Marine Sanctuary; therefore, relevant information is not required in this EP. 
Freeport-McMoRan Oil & Gas LLC Section 10 – Pg. 17 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 10 

LEASE STIPULATIONS INFORMATION 

10.1 MILITARY WARNING AREA (MWA) 

Green Canyon Blocks 600, 644 and 645 are located within designated Military Warning Area W92. The Fleet Area Control Surveillance Facility in Jacksonville, Florida, was contacted on May 

29, 2014 in order to coordinate and control the electromagnetic emissions use of vessels and 

aircraft during the proposed operations. 

10.2 MARINE PROTECTED SPECIES 

In accordance with the Federal Endangered Species Act and the Marine Mammal Protection 

Act, FM O&G 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 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 
Freeport-McMoRan Oil & Gas LLC Section 10 – Pg. 18 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

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. 
Freeport-McMoRan Oil & Gas LLC Section 11 – Pg. 19 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 11 

ENVIRONMENTAL MITIGATION MEASURES INFORMATION 

11.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS 

Green Canyon Blocks 600, 644 and 645 are not located within Florida; therefore, mitigation 

information is not required for the activities proposed in this plan. 

11.2 INCIDENTAL TAKES 

FM O&G 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” 
Freeport-McMoRan Oil & Gas LLC Section 12 – Pg. 20 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 12 

SUPPORT VESSELS AND AIRCRAFT INFORMATION 

12.1 GENERAL 

The most practical, direct route from the shorebase as permitted by weather and traffic 

conditions will be utilized. Information regarding the vessels and aircraft to be used to support 

the proposed activities is provided in the table below. 

Type Maximum Fuel 

Tank Capacity 

Maximum Number 

in Area at Any 

Time 

Trip Frequency or 

Duration 

Crew boat 1,800 bbls 1 3/Week 

Supply boat 9,000 bbls 1 3/Week 

Supply boat 5,800 bbls 1 3/Week 

Helicopter 1050 gal 1 2/Day 

12.2 DIESEL OIL SUPPLY VESSELS 

Information regarding vessels to be used to supply diesel oil for fuel and other purposes is 

provided in the table below. 

Size of Fuel Supply 

Vessel (ft) 

Capacity of Fuel 

Supply Vessel 

Frequency of Fuel 

Transfers 

Route Fuel Supply 

Vessel Will Take 

245 9,000 Bi-weekly Shortest route from 

Shorebase to block 

312 5,800 Bi-weekly Shortest route from 

Shorebase to block 

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 routes 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. 
OBM/ZnBr2/CaBr2 & KCl/ZnBr2/CaBr2 Vessel to truck or MPT tanks

Newpark Environmental Services

145 17th St

Port Fourchon, LA

500 bbl All will go to a 

disposal well

Attachment 12-A. WASTE YOU WILL TRANSPORT AND/OR DISPOSE OF ONSHORE

Transport Method Name/Location of

Facility

Amount Disposal

Method

Solid and Liquid

Wastes

Transportation

Waste Disposal

Synthetic-based drilling fluid

Cuttings wetted with Water-based fluid

Recycled

N/A

N/A

SBM Cuttings Boxes on Supply Boat

Newpark Environmental Services

145 17th St

Port Fourchon, LA

1,700 BBLS/Well

Will drilling occur? If yes, fill in the muds and cuttings.

Composition

Projected Generated

Wastes

Oil-based drilling fluid or mud N/A N/A N/A N/A

Produced sand

Will you have additional wastes that are not permitted for discharge? If yes, fill in the appropriate rows.

Trash and debris

Used oil

N/A N/A

No production is proposed under this Initial Exploration Plan

Refuse generated during operations: 

paper, cardboard, metal, and glass

Compactor bags in storage bins on 

Supply/Crew Boat

Gulf Offshore Logistics

Fourchon, LA 350,000 lbs/Well

Recycled if possible, 

transported to 

landfill otherwise

Used Engine Oil Proper DOT containers on supply boat Univar

Carencro, LA 115 bbl/Well

N/A

N/A

N/A

Cuttings wetted with oil-based fluids

Will you produce hydrocarbons? If yes fill in produced sand.

Cuttings wetted with Synthetic-based

fluid

N/A N/A

N/A N/A

N/A

N/A

N/A

N/A

N/A

Well completion fluids

Recycled or 

Incinerated

N/A N/A N/A N/A N/A

N/A N/A N/A N/A N/A

Wash water

Chemical product wastes
!!

!!

!!

!!

!!

!!

!!

! !!

!

!! !!

!

Houma

Dulac

Venice

Lafitte

Fourchon

Galliano

Cocodrie

Grand Isle

River Ridge

Morgan City

Fort Jackson

Green Canyon

Ship Shoal

Atwater Valley

South Timbalier

Mississippi Canyon

West Delta

Ewing Bank

Grand Isle

Ship Shoal South

South Timbalier South

West Delta South

Main Pass

South Pelto

New Orleans

Houma

Terrebonne

St. Mary Lafourche

Plaquemines

St. Charles

St. Martin

Freeport-McMoRan Oil & Gas LLC Vicinity Map

Green Canyon 600/644/645

~153.9 Miles t

o H

o

u

ma, LA Aircraft S

h

orebas

e

~

1

23.4

Miles

to

Fo

u

rcho

n, LA

Vessel Shorebase

!! Leeville

GC600-644-645

~118

Mile

s to

S

h

ore
Freeport-McMoRan Oil & Gas LLC Section 13 – Pg. 21 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 13 

ONSHORE SUPPORT FACILITIES INFORMATION 

13.1 GENERAL 

The onshore facilities that will be used to provide supply and service support for the proposed 

activities are provided in the table below. 

Name Location Existing/New/Modified 

Freeport-McMoRan Oil & 

Gas LLC Shorebase 

Fourchon, Louisiana Existing 

MI-Swaco Mud Plants 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 

shorebase as a result of the operations proposed in this EP. 

13.3 WASTE DISPOSAL 

The Table, “Wastes You Will Transport and/or Dispose of Onshore, “is included as Attachment 

12-A. 
Freeport-McMoRan Oil & Gas LLC Section 14 – Pg. 22 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 14 

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION 

Under direction of the Coastal Zone Management Act (CZMA), the state of Louisiana developed 

a Coastal Zone Management Programs (CZMP) to allow for the supervision of significant land 

and water use activities that take place within or that could significantly affect their respective 

coastal zones. 

Proposed activities are 118 miles from the Louisiana shore. Measures will be taken to avoid or 

mitigate the probable impacts. FM O&G will operate in compliance with existing federal and 

state laws, regulations, and resultant enforceable program policies in Louisiana’s Coastal Zone 

Management Program. 

The OCS related oil and gas exploratory and development activities having potential impact on 

the Louisiana 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. 

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.

Freeport-McMoRan Oil & Gas LLC Section 15 – Pg. 23 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 15 

ENVIRONMENTAL IMPACT ANALYSIS 

The Environmental Impact Analysis is included as Attachment 15-A.
 ATTACHMENT 15-A

Freeport-McMoran Oil & Gas, LLC (FM O&G)

Joint Initial Exploration Plan 

Green Canyon Blocks 600, 644, & 645 

OCS-G 34999, 110800, & 11081

(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 (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 Green Canyon Blocks 600, 644, and 645 

Proposed operations consist of the drilling, testing, completion, flaring, and installation of subsea 

trees for 2 wells in Green Canyon Block 600, 2 wells in Green Canyon Block 644, and 2 wells in 

Green Canyon Block 645. 

The operations will be conducted with a dynamically positioned drillship. 

1. Designated Topographic Features 

Potential IPFs on topographic features include effluents, and accidents. 

Effluents: Green Canyon Blocks 600, 644, and 645 are 53 miles from the closest designated 

Topographic Features Stipulation Block (Diaphus 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 FM O&G’s Regional 

OSRP (refer to information submitted in Appendix H). 

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: Green Canyon Blocks 600, 644, and 645 are 181 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 FM O&G’s 

Regional OSRP (refer to information submitted in Appendix H). 

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: Green Canyon Blocks 600, 644, and 645 are 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 FM O&G’s Regional OSRP (refer to information submitted in 

Appendix H). 

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 dynamically positioned drillship 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 dynamically positioned drillship, FM O&G’s proposed 

operations in Green Canyon Blocks 600, 644, and 645 would not cause impacts to benthic 

communities. 
5. Water Quality 

IPFs that could result in water quality degradation from the proposed operations in Green 

Canyon Blocks 600, 644, and 645 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 FM O&G’s Regional Oil Spill Response Plan (refer to information submitted in 

Appendix H). 

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 Green Canyon 

Blocks 600, 644, and 645 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 FM O&G’s Regional 

OSRP (refer to information submitted in Appendix H). 

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 Green Canyon 

Blocks 600, 644, and 645 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). 

FM O&G 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 FM O&G 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@bsee.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 FM O&G’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 FM O&G’s OSRP (refer to 

information submitted in accordance with Appendix H). 

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). FM O&G 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 FM O&G 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@bsee.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 FM O&G’s Regional Oil Spill Response Plan (refer to 

information submitted in accordance with Appendix H). 

There are no other IPFs (including physical disturbances to the seafloor) from the proposed 

activities which could impact sea turtles. 

9. Air Quality 

The projected air emissions identified in Appendix G are not expected to affect the OCS air 

quality primarily due to distance to the shore or to any Prevention of Significant Deterioration 

Class I air quality area such as the Breton Wilderness Area. Green Canyon Blocks 600, 644, and 

645 are beyond the 200 kilometer (124 mile) buffer for the Breton Wilderness Area and are 118 

miles from the coastline. Therefore, no special mitigation, monitoring, or reporting requirements 

apply with respect to air emissions. 

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 Green 

Canyon Blocks 600, 644, and 645 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 could 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 Green Canyon Blocks 600, 644, and 645 include disturbances to the seafloor. 

Physical disturbances to the seafloor: A dynamically positioned drillship 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 dynamically 

positioned drillship, FM O&G’s proposed operations in Green Canyon Blocks 600, 644, and 645 

would not cause impacts to shipwreck sites. 
Additionally, Green Canyon Blocks 600, 644, and 645 are 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. 

FM O&G 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 FM O&G 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, FM O&G 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 

Potential IPFs that could cause impacts to prehistoric archaeological sites as a result of the 

proposed operations in Green Canyon Blocks 600, 644, and 645 include disturbances to the 

seafloor. 

Physical disturbances to the seafloor: A dynamically positioned drillship 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 dynamically 

positioned drillship, FM O&G’s proposed operations in Green Canyon Blocks 600, 644, and 645 

would not cause impacts to prehistoric archaeological sites. 

FM O&G 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 FM O&G 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, FM O&G will contact the BOEM immediately and make every 

reasonable effort to preserve and protect that cultural resource. 

Additionally, Green Canyon Blocks 600, 644, and 645 are located outside the Archaeological 

Prehistoric high probability line, therefore, no adverse impacts are expected. 

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or 

disposal, or accidents) 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 Green Canyon 

Blocks 600, 644, and 645 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 FM O&G’s Regional OSRP (refer to information 

submitted in Appendix H). 

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 FM 

O&G’s Regional OSRP (refer to information submitted in Appendix H). 
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). FM O&G 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 FM O&G 

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 Appendix 

D 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 (118 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 FM O&G’s Regional OSRP (refer to 

information submitted in Appendix H). 

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). FM O&G 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 FM O&G 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 (118 miles) and the response capabilities that 

would be implemented, no impacts are expected. The activities proposed in this plan will be 

covered by FM O&G’s Regional OSRP (refer to information submitted in Appendix H). 

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). FM O&G 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 FM O&G 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 (118 miles) and the response capabilities that would be 

implemented, no impacts are expected. The activities proposed in this plan will be covered by 

FM O&G’s Regional OSRP (refer to information submitted in Appendix H). 

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). FM O&G 

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 FM O&G 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 (118 miles) and the response 

capabilities that would be implemented, no impacts are expected. The activities proposed in this 

plan will be covered by FM O&G’s Regional OSRP (refer to information submitted in Appendix 

H). 

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). FM O&G 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 FM O&G 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 (166 

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 FM O&G’s Regional OSRP 

(refer to information submitted in Appendix H).

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). FM O&G 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 FM O&G 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 their location in the gulf, Green Canyon Blocks 600, 644, and 645 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) 

Jami Christley 

J. Connor Consulting, Inc. 

16225 Park Ten Place, Suite 700 

Houston, TX 77084 

(281) 578-3388 

jami.christley@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. 
Freeport-McMoRan Oil & Gas LLC Section 16 – Pg. 24 of 24 

Joint Initial Exploration Plan November 2014 

Green Canyon Blocks 600/644/645 (OCS-G 34999/11080/11081) 

SECTION 16 

ADMINISTRATIVE INFORMATION 

16.1 EXEMPTED INFORMATION DESCRIPTION 

The proposed bottomhole 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. C & C Technologies Survey Services. 3D Seismic Shallow Geohazard Report: 

“Holstein” Prospect Block 600 (OCS-G-34999), Block 644 (OCS-G-11080) and 

Block 645 (OCS-G-11081) Green Canyon Area October, 2013, C & C Project 

#130276. 

2. C & C Technologies Survey Services. Archaeological Assessment Report: 

Blocks 599 (OCS-G-34998), 600 (OCS-G-34999), 643 (OCS-G-35001), 644 

(OCS-G-11080), 645 (OCS-G-11081), 689 (OCS-G-35002), 733 (OCS-G35004), and 777 (OCS-G-35007) Green Canyon Area August, 2013, C & C 

Project #130227. 

3. C & C Technologies Survey Services. Well Site Clearance Proposed Well 

Locations “A”, “B”, “C”, “D”, “E” and “F” Block 600, Block 644 & Block 645 Green 

Canyon Area July, 2014, C & C Project #140501. 

4. Regional Oil Spill Response Plan, Freeport-McMoRan Oil & Gas LLC (Control 

Number O-713).