UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - S-07731

Type - Supplemental Exploration Plan

Lease(s) - OCS-G32500 Block - 393 Green Canyon Area

Operator - Freeport-McMoRan Oil & Gas LLC

Drill, test, flare, and install subsea wellhead for Well F

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.

Madonna Montz

Plan Coordinator

Description -

Rig Type -

Subject:

From:

March 3, 2015
Record of Changes-PUBLIC INFORMATION COPY

S-7731, Exploration Plan, Freeport-McMoRan Oil Gas LLC, (OCS-G 32500, Mississippi Canyon Block 393)

Date Section Page Remarks

1/23/2015 All All Plan received by BOEM

1/29/2015 7 Attachment 7-A Added. 

2/18/2015 All All Final copies provided. 
PUBLIC COPY

January 22, 2015

SUPPLEMENTAL

EXPLORATION PLAN

Green Canyon Block 393

OCS-G 32500

Giverny Prospect

Affected State: Louisiana

Estimated Startup Date: February 19, 2017

SUBMITTED BY:

Freeport-McMoRan Oil & Gas LLC

400 E. Kaliste Saloom Road, Suite 1100

Lafayette, Louisiana 70508

Paul Landry 

Office: 337-354-5065

Mobile: 337-349-7781

paul_landry@fmi.com

AUTHORIZED REPRESENTATIVE:

Jean Martin

J. Connor Consulting, Inc.

16225 Park Ten Place, Suite 700

Houston, Texas 77084

281-698-8544

jean.martin@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.................................................................................................... 4

SECTION 3 GEOLOGICAL AND GEOPHYSICAL INFORMATION..........................................8

3.1 GEOLOGICAL DESCRIPTION......................................................................................... 8

3.2 STRUCTURE CONTOUR MAPS...................................................................................... 8

3.3 INTERPRETED SEISMIC LINE........................................................................................ 8

3.4 GEOLOGICAL STRUCTURE CROSS-SECTION............................................................. 8

3.5 SHALLOW HAZARDS REPORT ...................................................................................... 8

3.6 SHALLOW HAZARDS ASSESSMENT............................................................................. 8

3.7 HIGH-RESOLUTION SEISMIC LINES ............................................................................. 8

3.8 STRATIGRAPHIC COLUMN ............................................................................................ 8

3.9 TIME VERSUS DEPTH TABLES...................................................................................... 8

SECTION 4 HYDROGEN SULFIDE INFORMATION ................................................................9

4.1 CONCENTRATION .......................................................................................................... 9

4.2 CLASSIFICATION............................................................................................................ 9
TOC Pg 2 of 3

4.3 H2S CONTINGENCY PLAN.............................................................................................. 9

4.4 MODELING REPORT....................................................................................................... 9

SECTION 5 BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION.................10

5.1 DEEPWATER BENTHIC COMMUNITIES .......................................................................10

5.2 TOPOGRAPHIC FEATURES (BANKS)...........................................................................10

5.3 TOPOGRAPHIC FEATURES STATEMENT (SHUNTING)..............................................10

5.4 LIVE BOTTOMS (PINNACLE TREND FEATURES) ........................................................10

5.5 LIVE BOTTOMS (LOW RELIEF) .....................................................................................10

5.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP..........................................10

5.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS ...................................................10

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT AND MARINE 

MAMMAL INFORMATION ..............................................................................................11

5.9 ARCHAEOLOGICAL REPORT........................................................................................12

5.10 AIR AND WATER QUALITY INFORMATION ................................................................12

5.11 SOCIOECONOMIC INFORMATION..............................................................................12

SECTION 6 WASTES AND DISCHARGES INFORMATION...................................................13

6.1 PROJECTED GENERATED WASTES............................................................................13

6.2 MODELING REPORT......................................................................................................13

SECTION 7 AIR EMISSIONS INFORMATION ........................................................................14

7.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS ......................................14

7.2 SUMMARY INFORMATION ............................................................................................14

SECTION 8 OIL SPILL INFORMATION ..................................................................................15

8.1 OIL SPILL RESPONSE PLANNING ................................................................................15

8.2 SPILL RESPONSE SITES...............................................................................................15

8.3 OSRO INFORMATION....................................................................................................15

8.4 WORST CASE SCENARIO DETERMINATION...............................................................15

8.5 OIL SPILL RESPONSE DISCUSSION ............................................................................16

8.6 MODELING REPORT......................................................................................................16

SECTION 9 ENVIRONMENTAL MONITORING INFORMATION ............................................17

9.1 MONITORING SYSTEMS ...............................................................................................17

9.2 INCIDENTAL TAKES.......................................................................................................17

9.3 FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY....................................17

SECTION 10 LEASE STIPULATIONS INFORMATION ..........................................................18
TOC Pg 3 of 3

10.1 MILITARY WARNING AREA (MWA) .............................................................................18

10.2 MARINE PROTECTED SPECIES .................................................................................18

SECTION 11 ENVIRONMENTAL MITIGATION MEASURES INFORMATION .......................20

11.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS ......................20

11.2 INCIDENTAL TAKES.....................................................................................................20

SECTION 12 SUPPORT VESSELS AND AIRCRAFT INFORMATION ...................................21

12.1 GENERAL .....................................................................................................................21

12.2 DIESEL OIL SUPPLY VESSELS...................................................................................21

12.3 DRILLING FLUID TRANSPORTATION .........................................................................21

12.4 SOLID AND LIQUID WASTE TRANSPORTATION .......................................................21

12.5 VICINITY MAP...............................................................................................................21

SECTION 13 ONSHORE SUPPORT FACILITIES INFORMATION.........................................22

13.1 GENERAL .....................................................................................................................22

13.2 SUPPORT BASE CONSTRUCTION OR EXPANSION .................................................22

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE.............................22

13.4 WASTE DISPOSAL.......................................................................................................22

SECTION 14 COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION.....................23

SECTION 15 ENVIRONMENTAL IMPACT ANALYSIS...........................................................24

SECTION 16 ADMINISTRATIVE INFORMATION...................................................................25

16.1 EXEMPTED INFORMATION DESCRIPTION................................................................25

16.2 BIBLIOGRAPHY............................................................................................................25
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-D 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 

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 15 Environmental Impact Analysis (EIA)

15-A Environmental Impact Analysis (EIA)
Freeport-McMoRan Oil & Gas LLC Section 1 – Pg. 1 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

SECTION 1

PLAN CONTENTS

1.1 PLAN INFORMATION

The drilling, evaluation and temporary abandonment of five wells in Green Canyon Blocks 349 

and 393 was approved in Initial EP (Control No. N-9739) March 31, 2014. No wells have been 

drilled.

Under this Supplemental EP, Freeport-McMoRan Oil & Gas LLC (FM O&G) proposes to drill, 

complete, test, flare and install a subsea wellhead for one additional well location in 3,803 feet 

of water in Green Canyon Block 393 (OCS-G Lease 32500) using a dynamically positioned 

drillship with a subsea BOP.

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

1.2 LOCATION

A Well Location Plat depicting the surface location of the proposed well and water depth is 

included as Attachment 1-B.

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

A Bathymetry Map depicting the surface location and water depth of the proposed well is 

included as Attachment 1-C.

1.3 SAFETY AND POLLUTION PREVENTION FEATURES

FM O&G proposes to drill the well 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 (EPA) and the 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 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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 2 890.6 33 ̊

Fuel oil DPDS 320.2 2 640.4 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 44.0 1 44.0 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 $3,673 cost recovery fee payment is included as Attachment 1-D.
U.S. Department of the Interior 

Bureau of Ocean Energy Management

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

If so, provide the Control Number of the EP or DOCD with which this information was provided N-9739

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

Well Location F: Drill, complete, test, flare and install subsea 

wellhead 2/19/2017 6/4/2017 105

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): NA

Description of Lease Term Pipelines

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

NA NA NA NA

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

General Information

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

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

Address: 400 E. Kaliste Saloom Road, Suite 1100 Contact Person: Jean Martin

 Lafayette, Louisiana 70508 Phone Number: (281) 698-8544

E-Mail Address: jean.martin@jccteam.com

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $3,673 Receipt No. 25JDE82J

Project and Worst Case Discharge (WCD) Information

Lease: OCS-G 32500 Area: Green Canyon Block: 393 Project Name: Giverny

Objective(s) X Oil X Gas Sulphur Salt Onshore Support Base: Fourchon, Louisiana

Platform / Well Name: Well Location B Total Volume of WCD: 63,667,520 bbl API Gravity: 25o

Distance to Closest Land: 97 miles Volume from uncontrolled blowout: 397,922 bbl/day

OCS PLAN INFORMATION FORM

OMB Control Number: 1010-0151

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

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

Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): Well Location 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): 202,000 

bbl/day

For structures, volume of all storage and pipelines 

(Bbls): NA API Gravity of fluid 25o

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

separate lines)

Lease No. OCS-G 32500 OCS-G 32500

Area Name Green Canyon Green Canyon 

Block No. 393 393

Blockline 

Departures 

(in feet)

N/S Departure: 3,595.00’ FNL N/S Departure:

N/S Departure F __ L

N/S Departure F __ L

N/S Departure F __ L

E/W Departure: 10,360.00’ FWL E/W Departure: 

E/W Departure F __ L

E/W Departure F __ L

E/W Departure F __ L

Lambert X-Y 

coordinates

X: 2,639,800.00’ X: 

X:

X:

X:

Y: 10,023,125.00’ Y:

Y:

Y:

Y:

Latitude/

Longitude

Latitude: 27o 35’ 12.232” N Latitude:

Latitude

Latitude

Latitude

Longitude: 89 o 54’ 52.252” W Longitude:

Longitude

Longitude

Longitude

Water Depth (Feet): 3,803’ MD (Feet): TVD (Feet): MD (Feet):

MD (Feet):

MD (Feet):

TVD (Feet): 

TVD (Feet): 

Anchor Radius (if applicable) in feet: NA 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

NA NA NA X: NA Y: NA NA

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

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

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OCS-G-18578

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AT310

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AT398

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SURVEY VESSEL:

JOB NO.: 2414-5050

POSITIONING BY: STARFIX

INTERPRETATION BY: D. MATTE / M. SAMSON

DATE: DECEMBER 29, 2014

SURVEY DATES:

DWG NO.: 24145050-B.dwg

REVISION NO.: 0

CHECKED BY: D. GRESHAM

DRAFTED BY: K. LEMAIRE

CHART 1 OF 1

3D SHALLOW HAZARDS STUDY

SEAFLOOR FEATURES & BATHYMETRY MAP

"GIVERNEY" PROSPECT

PROPOSED WELL "F"

BLOCKS GC 349, GC 393 & AT 353

GREEN CANYON & ATWATER VALLEYAREA

GULF OF MEXICO

200 DULLES DRIVE - LAFAYETTE, LOUISIANA 70506 - (337) 237-2636

Fugro GeoServices, Inc.

3,000 4,000

FEET

0 1,000 2,000

SCALE = 1:12,000

5,000

GEODETIC DATUM: NAD27

PROJECTION: UTM GRID UNITS: US SURVEY FEET

ZONE: U.T.M. 15 (NORTH)

 *** IMPORTANT - PLEASE NOTE ***

ANY COMMUNICATION AND/OR POWER CABLES THAT MAY BE PRESENT

IN THE AREA CANNOT BE LOCATED BY INSTRUMENTS UTILIZED DURING

THIS SURVEY. INQUIRIES SHOULD BE MADE TO INTERESTED PARTIES AS TO

THE PRESENCE OF SUCH OBSTRUCTIONS.

ZONE 15

ZONE 14

ZONE 16

ZONE 15

 T E X A S

 A L A B A M A M I S S I S S I P P I

 L O U I S I A N A Pascagoula

Gulfport

Biloxi

Mobile

EWING BANK

VERMILION

Port O'Conner

Port

Lavaca

Matagorda

Freeport

Galveston

Houston

Port

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Grand

Cheniere

Intracoastal

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Water City

Morgan City

Amelia

Houma

Dulac

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Isle

Fourchon

Lake Charles Lafayette

Pensacola

Destin

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PADRE

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NORTH

PADRE

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MUSTANG

ISLAND

MATAGORDA

ISLAND

BRAZOS

GALVESTON

HIGH

ISLAND

EAST BREAKS

CORPUS

CHRISTI

PORT

ISABEL

ALAMINOS CANYON

GARDEN BANKS

KEATHLEY CANYON

GREEN CANYON

WALKER RIDGE

ATWATER VALLEY

LUND

HENDERSON

LLOYD RIDGE

DESOTO CANYON

MISSISSIPPI CANYON

DESTIN DOME

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MOBILE

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CAMERON

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TEXAS SOUTH

NUMBER X COORDINATE Y COORDINATE

NUMBER X COORDINATE Y COORDINATE

PROJECT

LOCATION

STUDY AREA (JOB NO. 2412-5023)

10'

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CONTOUR INTERVAL = 10 FEET

ZERO DATUM = MEAN LOWER LOW WATER

-3750'

HIGHLY FAULTED ZONE

LINE 101 >>> HUGIN AUV TRACKLINE NUMBER AND DIRECTION (JOB NO. 2412-5023)

POSSIBLE CHEMOSYNTHETIC AREA (BOEM DATABASE 5/2014)

HARD-BOTTOM AREA (POSSIBLE CHEMOSYNTHETIC COMMUNITY)

2,000' AVOIDANCE FOR MUD & CUTTINGS DISCHARGE;

250' AVOIDANCE FOR ALL OTHER BOTTOM-DISTURBING ACTIVITIES

(NTL 2009-G40)

SUBSIDENCE FEATURE

EXISTING WELL LOCATION (FUGRO DATABASE)

2

PROPOSED WELL LOCATION WITH A 2,000 FT RADIUS FOR CHEMOSYNTHETIC

COMMUNITY ASSESSMENT (AS PER MMS NTL 2009-G40).

LINE 101 >>> HUGIN AUV TRACKLINE NUMBER AND DIRECTION (JOB NO. 2414-5050)

2

STUDY AREA (JOB NO. 2414-5050)

RELICT MUD MOUND

SIDE SCAN SONAR CONTACT WITH REFERENCE NUMBER

(MINIMUM AVOIDANCE BOUNDARY WHERE APPLICABLE)

(FGSI JOB NO. 2412-5023)

SIDE SCAN SONAR CONTACT WITH REFERENCE NUMBER

(MINIMUM AVOIDANCE BOUNDARY WHERE APPLICABLE

(FGSI JOB NO. 2414-5050)

FAULT SCARP WITH SEAFLOOR OFFSET IN FEET,

HACHURES ON DOWNTHROWN SIDE
1

Favaloro, Katharine

From: notification@pay.gov

Sent: Tuesday, January 20, 2015 2:36 PM

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 BseeAccountsReceivable@bsee.gov. 

 Application Name: BOEM Exploration Plan - BF 

 Pay.gov Tracking ID: 25JDE82J 

 Agency Tracking ID: 74739867958 

 Transaction Type: Sale 

 Transaction Date: 01/20/2015 03:35:48 PM EST 

 Account Holder Name: Katharine Favaloro 

 Transaction Amount: $3,673.00 

 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, 03280 

 Lease Number(s): 32500, , , , 

 Area-Block: Green Canyon GC, 393: , : , : , : , 

 Surface Locations: 1 

THIS IS AN AUTOMATED MESSAGE. PLEASE DO NOT REPLY. 

ATTACHMENT 1-D
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 3 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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 well. 

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be

Used per Well (bbl)

Water-based (seawater, freshwater, barite) 50,000 

Oil-based (diesel, mineral oil) 0 

Synthetic-based (internal olefin, ester) 31,000

2.3 NEW OR UNUSUAL TECHNOLOGY

[PROPRIETARY]

2.4 BONDING STATEMENT

The bond requirements for the activities and facilities proposed in this EP are satisfied by 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) will demonstrate oil spill financial 

responsibility for the facilities proposed in this EP according to 30 CFR 553; and NTL No. 2008-

N05, "Guidelines for Oil Spill Financial Responsibility for Covered Facilities" (Extended by NTL 

No. 2014-N01, “Elimination of Expiration Dates on Certain Notices to Lessees and Operators 

Pending Review and Reissuance”), 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 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

2.7 BLOWOUT SCENARIO 

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

during drilling operations. 

The highest Worst Case Discharge in this Exploration Plan is for Green Canyon Block 393 Well 

Location B accepted under Exploration Plan (Control No. N-9739) approved March 31, 2014. 

Estimated Initial Flow Rate (bbls/day): 397,922 bbls

Maximum duration of potential blowout (days): 160 days

Total Volume (bbls) (flow rate x duration): 63,667,520 bbls

Discussion of potential for well to bridge over: While the sands to be encountered by the 

well in this EP are expected to be slightly consolidated, FM O&G does NOT assume that the 

proposed well would bridge over in a blowout scenario. The basis for this assumption comes 

from work done in association with SPE Paper # 163438 on the analysis of potential bridging 

scenarios during blowout events in the deepwater GoM. FM O&G agrees with the conclusions 

of this SPE paper that the only instances in which a deepwater 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 method to cover all potential blowout scenarios in the proposed well, all 

Worst Case Discharge calculations will be based upon a well blowing out unimpeded until a 

relief well can be completed.

Discussion of likelihood for surface intervention to stop blowout: Well Location “B” will be 

drilled in the Green Canyon (GC) Block 393 as a subsea well in approximately 3,800’ of water 

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

preferred method of intervention pending an uncontrolled blowout, however the technique used 

would be contingent upon the condition of the rig, marine riser system and BOP equipment. 

Surface intervention is a quicker solution than drilling a relief well, but actual methodology of 

controlling the blowout would have to be determined pending an analysis of the site‐specific 

conditions at the location. 

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

immediately to assess the situation and determine a corrective course of action to control the 

blowout. Well control specialists would perform either a fly‐by via helicopter and/or surface 

vessel to assess conditions at the site. 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, an 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 
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 5 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

strategy and mobilize additional service company specialists, supplies and equipment. FM 

O&G would establish a field support base and secondary command center in the company 

owned shore base facility in Fourchon, LA. Communication would simultaneously be 

established with the support base and command center.

Relief Well

Discussion of Drilling a Relief Well: FM O&G has the financial capability to drill a relief well 

and conduct other emergency well control operations. Should a relief well be necessary, there 

are deepwater rigs rated and equipped to drill in water depth of 4,000' or greater actively 

working in the Gulf of Mexico. Since all rigs proposed for drilling a relief well are dynamically 

positioned MODUs, the time necessary to mobilize the rig to location is minimal. The time 

required to drill the relief well is dependent on many factors, chief among them is the required 

depth of the relief well. The deepest anticipated depth of the relief well would be when an 

intersection is required with the blown‐out well at its final target depth (TD). The total days 

estimated to drill an example well to potential target depth (PTD) is 95 days. The probable 

directional nature of the relief well could nominally increase its measured depth compared to the

blown‐out well. The time required to drill this extra distance is anticipated to be more than offset 

by the better understanding of the optimum drilling parameters learned while drilling the 

blown‐out well. In order to intersect the blowout well, numerous ranging runs will be required 

which will add approximately three weeks to the drilling program. The steps and time required to 

accomplish the dynamic kill are also dependent on the particular circumstances of the blown‐out 

well. 

Rig type capable of drilling relief well at water depth and to TD: The Noble Tom Madden, 

under contract to FM O&G and scheduled to be in Mississippi Canyon Blocks 84, 127 and 129 

in 2017, is capable of drilling a relief well at this location.

Rig package constraints: The rig chosen to drill the relief well must:

• Be rated and equipped to work in water depths of 4,000’ due to Green Canyon Block

393 deepwater location near the Sigsbee Escarpment.

• Be dynamically positioned to eliminate anchoring issues caused by potential subsea 

debris.

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

Time to acquire rig, move onsite and drill relief well (days): 

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 relief well 110

Wellbore intersection (of blown out well) 21

Dynamic kill operations 7

Total Anticipated Time 160
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 6 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

Statement whether possibility of using nearby platform was considered: No production 

platforms exist in the area and could not be used to drill a relief well. 

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.

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 hydrostatic 

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 cooperation 

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 
Freeport-McMoRan Oil & Gas LLC Section 2 – Pg. 7 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

company) who would assist in detailed relief well planning including the identification of required 

equipment and services. 

Any other measures: No

In accordance with NTL No. 2015-N01, “Information Requirements for Exploration Plans, 

Development and Production Plans, and Development Operations Coordination Documents on 

the OCS for Worst Case Discharge and Blowout Scenarios” the Blowout Scenario and Worst 

Case Discharge Assumptions and Calculations were submitted with Exploration Plan (Control 

No. N-9739) approved March 31, 2014.
Freeport-McMoRan Oil & Gas LLC Section 3 – Pg. 8 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

SECTION 3

GEOLOGICAL AND GEOPHYSICAL INFORMATION

3.1 GEOLOGICAL DESCRIPTION

[PROPRIETARY]

3.2 STRUCTURE CONTOUR MAPS

[PROPRIETARY]

3.3 INTERPRETED SEISMIC LINE

[PROPRIETARY]

3.4 GEOLOGICAL STRUCTURE CROSS-SECTION

[PROPRIETARY]

3.5 SHALLOW HAZARDS REPORT

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

2014-N01, “Elimination of Expiration Dates on Certain Notices to Lessees and Operators 

Pending Review and Reissuance”), shallow hazards and archaeological surveys were

conducted over Green Canyon Blocks 349 and 393 evaluating seafloor and subsurface 

geological and manmade features and conditions that may adversely affect drilling operations. 

The report was submitted with Exploration Plan (Control No. N-9739) approved March 31, 2014. 

Additional shallow hazards and archaeological surveys over Atwater Valley Blocks 353 and 

portions of the eight surrounding blocks: Atwater Valley Blocks 309, 310, 354, 397, 398, and 

Green Canyon Blocks 349, 393 and 437, were conducted by Fugro Geoservices, Inc. The 

report, supplemental to the report provided with N-9739, 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-N01, “Elimination of Expiration Dates on Certain Notices to Lessees and Operators 

Pending Review and Reissuance”), a shallow hazards assessment has been prepared for the 

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-D.

3.7 HIGH-RESOLUTION SEISMIC LINES

[PROPRIETARY]

3.8 STRATIGRAPHIC COLUMN

[PROPRIETARY]

3.9 TIME VERSUS DEPTH TABLES 

[PROPRIETARY]
Report No. 2414-5050 1

Report No. 2414-5050-F 

December 29, 2014 

Freeport McMoRan Oil & Gas 

717 Texas Avenue, Suite 2100 

Houston, Texas 77002 

Attention: Mr. Riley Bates 

Wellsite Clearance Letter 

Giverny Prospect, Proposed Wellsite F 

Block 393 (OCS-G-32500) 

Green Canyon Area, Gulf of Mexico 

Introduction. Fugro GeoServices, Inc. (FGSI) was contracted by Freeport McMoRan Oil & Gas (FMOG) 

to prepare a geohazards assessment of Proposed Wellsite F (Giverny Prospect). The proposed borehole 

has a surface location in Green Canyon (GC) Block 393 ( OCS-G-32500) and i s planned to be vertical 

through the tophole section. T he principal scope of the assessment is to address specific seafloor and 

shallow geologic conditions in the vicinity of the proposed surface location. Potential drilling hazards in the 

tophole section are identified and as sessed to 1.5 seconds two-way time (TWT) below mudline (BML) 

(approximately 4,740 feet BML) at this location. 

This site-specific assessment is a s upplement to FGSI Report No. 2412-5023 (“Shallow Hazards and 

Archaeological Assessment, Giverny Prospect, Blocks 349 & 393, Green Canyon Area, Gulf of Mexico”) 

and FGSI Report No. 2414-5050 (“Shallow Hazards and A rchaeological Assessment, Giverny Prospect, 

Block 353 & Vicinity, Atwater Valley Area, Gulf of Mexico”). These reports correspond to geophysical data 

collected by FGSI in 2012 and 2014, respectively, as well as a 3D exploration seismic dataset provided by 

FMOG. Please refer to the above-referenced documents for a comprehensive assessment of geohazards 

within GC393, GC349, Atwater Valley (AT) Block 353 and vicinity as well as a description of the data used 

in this study, its limitations, time-depth conversions, and a c omplete list of references used in this 

investigation. The study areas from both surveys are displayed on the enclosed Study Chart (Chart 1) and 

the Multibeam Bathymetry Rendering (Figure 2). A summary of each geophysical survey is provided in the 

archaeological portion of this assessment. 

This wellsite clearance assessment, together with the above-referenced geohazards and archaeological 

assessments, comply with the latest guidelines established by the Bureau of Ocean Energy Management 

(BOEM) and t he Bureau of Safety and En vironmental Enforcement (BSEE) for shallow drilling hazards 

(NTLs 2008-G04 & 2008-G05), archaeological resources (NTLs 2005-G07, 2011-JOINT-G01, and 

Mitigation 3.20), and chemosynthetic community assessment (NTL 2009-G40). 

This wellsite clearance assessment is based on the interpretation of 3D seismic data and high-resolution 

Autonomous Underwater Vehicle (AUV) data. T he AUV dat aset includes side scan sonar (SSS), 

multibeam echosounder bathymetry (MBES), MBES backscatter, and s ub-bottom profiler records. 

Subsurface depths referenced in this letter were calculated with a fifth order polynomial function that was 

derived by FGSI and is based on checkshot survey data for AT398 Well No. 1. 

3D Seismic Frequency and Resolution. Based on frequency spectra analysis of the 3D seismic data at 

50% power (within the upper 1.0 second two-way travel time below the seafloor), the frequency bandwidth 

for data covering Proposed Wellsite F ranges from 29 to 63 Hz (Figure 1). T his frequency bandwidth 

corresponds to a limit of separability of about 26.9 feet, assuming a dominant frequency of 29 Hz and an 

average velocity of 5,328 ft/sec in the tophole section. The 3D seismic data used in this wellsite clearance 

FUGRO GEOSERVICES, INC.

200 Dulles Drive

P.O. Box 740010

Lafayette, Louisiana 70506

T (337) 237-2636

F (337) 268-3221
Report No. 2414-5050 2

assessment were post-processed (spectrally whitened) with IHS Kingdom software for the purpose of 

frequency enhancement in the tophole section. A dditional details regarding the data descriptions and 

limitations are documented in FGSI Report Nos. 2412-5023 & 2414-5050. Overall, the data used in this 

study are judged to be of adequate quality and r esolution to make an as sessment of the geologic 

conditions and potential hazards that may constrain exploratory drilling operations within the study area. 

Graphics. A Seafloor Features and B athymetry Chart (Chart 1; 1:12,000-scale) showing the proposed 

wellsite, water depth contours, and seafloor features accompanies this wellsite assessment. A 2,000 foot 

chemosynthetic community clearance radius around the proposed wellsite is shown on t he chart (as per 

BOEM NTL 2009-G40). The enclosed 3D seismic frequency spectrum illustrates that the 3D seismic data 

are in compliance with the BOEM’s minimum frequency requirements (Figure 1). An 8.5” x 11” multibeam 

rendering figure is attached to provide a regional view of the seafloor bathymetry (Figure 2). 8. 5” x 11” 

multibeam backscatter and side scan sonar images (Figures 3 and 4, respectively) are included to show 

surface conditions within a 2 ,000’ radius of the proposed wellsite. The nearest 3D s eismic inline and 

crossline profiles (Figures 5 and 6, respectively) are also attached to illustrate shallow geologic conditions 

in the vicinity of the proposed location. In addition, shallow geologic conditions at the proposed wellsite are 

summarized on the attached Tophole Prognosis Chart (Figure 7). A figure of the nearest AUV sub-bottom 

profiler line is provided to provide a high-resolution image of the shallow subsurface in the vicinity of the 

proposed wellbore (Figure 8). Finally, an 8.5” x 11”, 1:12,000-scale Subsurface Geologic Features Map 

(Figure 9) is included to show shallow geologic features near the wellsite in plan view. 

Proposed Well Location. The surface location for Proposed Wellsite F is in the northeastern portion of 

GC393 as follows: 

Proposed Wellsite F

Block 393, Green Canyon Area 

UTM Zone 15, NAD 1927 

X = 2,639,800’ Y = 10,023,125’ 

Latitude: 27° 35’ 12.232” N Longitude: 89° 54’ 52.252” W 

3D Inline: 6664 3D Crossline: 2050 

Block Call 1: 3,595’ From North Line of GC393 Block Call 2: 10,360’ From West Line of GC393 

Water Depth and Seafloor Gradient. The water depth at Proposed Wellsite F is about -3,803’ (based on 

MBES data and assuming zero datum at Mean Lower Low Water [MLLW]), and the local seafloor gradient 

is about 3.4o (~7.3%) to the southeast (Chart 1 & Figure 2). S urficial soils appear to be stable at this 

location; however, a s eabed investigation utilizing sediment cores would be r equired to accurately 

determine the sediment type, soil stability, and precise geotechnical properties for this location. 

Seafloor Features. Several seafloor faults lie within a 2,000 foot radius of the proposed wellsite (Chart 1). 

These fault scarps are associated with increased seafloor gradients, and di fficulties with placement of 

bottom-founded infrastructure may be encountered during lease development. The closest seafloor fault 

lies approximately 165 f eet to the southwest, strikes northwest-southeast, and i s downthrown to the 

southwest. The proposed wellbore will not penetrate this fault, as it is cited on the upthrown fault block. 

The seafloor expression of a shallow-buried mudmound is located approximately 625 feet to the southwest 

of the Proposed F location. This topographic anomaly is about 350 feet in diameter and displays about 

seven feet of relief above the ambient seafloor (Figures 2 & 9; Chart 1). The buried mudmound is located 

along a seafloor fault and is interpreted to represent a relict fluid expulsion feature. MBES Backscatter and 

SSS records display uniform seafloor reflectivity in the location of the buried mudmound and do not indicate 

the presence of authigenic carbonates or other hardbottom material (Figures 3 & 4). A sub-bottom profiler 

line does not transect the buried mudmound, and the feature is not fully resolvable in the 3D seismic data. 
Report No. 2414-5050 3

For these reasons, the precise depth of burial is unclear; however, it is apparant that this feature is covered 

by a t hin veneer of hemipelagic clay drape, which indicates that it has been dor mant for hundreds or 

thousands of years. This feature should not present a hazard or constraint to exploratory drilling activity at 

the Proposed F Location. 

Potential for Chemosynthetic Communities. No BOEM-designated “potential chemosynthetic zones” 

are located within a 2, 000 foot radius of the proposed wellsite (Chart 1). A dditionally, no e vidence of 

chemosynthetic communities was observed in the AUV data within 2,000 feet of Proposed Wellsite F. 

Analysis of the 3D seismic seafloor horizon, AUV MBES backscatter data, and SSS record s indicate a 

seafloor of uniform reflectivity; therefore, the potential for encountering chemosynthetic communities or 

authigenic carbonates in this vicinity is considered to be very low (Figures 3 & 4). 

Man-Made Obstructions. T he proposed wellsite lies within a z one designated as archaeologically 

sensitive by the BOEM (NTLs 2005-G07 & 2011-JOINT-G01). No man-made features such as pipelines, 

wellheads, or other infrastructure are reported within 2,000 feet of the proposed location. No evidence of 

man-made infrastructure was observed in the geophysical data that were interpreted for this project. 

Additionally, no side scan sonar targets were identified within 2,000 feet of Proposed Well Location F. This 

interpretation is supported by FGSI’s regional Giverny Archaeological Assessment (FGSI Report Nos. 

2412-5023 and 2414-5050) and by the site-specific archaeological assessment included herein. 

Mooring Considerations. FMOG plans to utilize a dynamically positioned (DP) drilling vessel at the proposed 

wellsite; thus, seafloor clearance for anchor locations will not be addressed at this time. 

Stratigraphy. The mapped horizons (Horizons 10, 20, and 30) divide the shallow section into four 

stratigraphic sequences (Sequences 1 through 4) of distinct seismic character and inferred lithology (Figures 5 

and 6). This stratigraphic characterization is consistent with the 2012 Giverny geohazards assessment 

(FGSI Report No. 24125023). The 2014 Giverny geohazards assessment breaks Sequence 4 into three 

additional stratigraphic units (Sequences 5 t hrough 7); however, for practical purposes, Sequences 5 

through 7 are collectively referred to as “Sequence 4” in this wellsite clearance assessment (as outlined in 

FGSI Report No. 24125023). Predicted depths of Horizons 10, 20, and 30 (and the intervening sequence 

thicknesses) are displayed on t he attached Tophole Prognosis Chart for Proposed Wellsite F (Figure 7). 

All stratigraphic intervals in the tophole were interpreted from the 3D seismic data volume, unless otherwise 

noted. 

Sequence 1 is about 410 feet thick and is divided into two subunits. Sub-bottom profiler data indicate that 

the surficial subunit (Sequence 1a) is 65 feet thick at the wellsite location and consists of parallel-stratified 

clays that accumulated from the normal gravitational settling of suspended material in a marine 

environment (normal marine deposits) (Figure 8). The basal subunit (Sequence 1b) is about 345 feet thick 

and is composed of fine-grained normal marine deposits with thin, interbedded mass transport deposits 

(MTDs). Occasional silt lenses may be encountered in Sequence 1b. 

Sequence 2 is approximately 394 feet thick and is similar in seismic character to Sequence 1b. This 

interval is composed of fine-grained normal marine deposits with interbedded MTDs. P oorly developed 

silts may be encountered in this interval, with Horizon 20 (the base of Sequence 2) interpreted as sandprone. 

Sequence 3 is about 465 feet thick and is divided into two subunits. The upper subunit (Sequence 3a) is 

138 feet thick at the wellsite location and consists of fine-grained, chaotically-bedded MTDs. T he basal 

subunit (Sequence 3b) is about 327 feet thick and i s a m ixed-lithology interval of fine sands, silts, and 

clays. This interval is interpreted to consist of submarine channel-levee deposits and MTDs. 

Sequence 4 i s a g eologically complex, 3,470-foot thick package of chaotically-bedded, fine-grained 

channel/levee deposits with interbedded MTDs. T his interval is divided into eight subunits. T he upper 
Report No. 2414-5050 4

subunit (Sequence 4a) is a 561- foot thick package of discontinuous to semi-continuous, fine-grained 

channel/levee complexes with interbedded MTDs. The second subunit of Sequence 4 (Sequence 4b) is a 

696-foot thick mixed-lithology interval of submarine channel/levee deposits and MTDs. The third subunit 

(Sequence 4c) is a 331-foot thick package of semi-continuous, fine-grained channel/levee complexes with 

interbedded MTDs. P oorly-developed sands or silts may be enc ountered in this interval. The fourth 

subunit (Sequence 4d) is a 194- foot thick mixed-lithology interval of submarine channel/levee deposits. 

The fifth subunit (Sequence 4e) is a 246-foot thick package of semi-continuous, fine-grained channel/levee 

complexes with interbedded MTDs. The sixth subunit of Sequence 4 ( Sequence 4f) is a 212- foot thick 

mixed-lithology interval of submarine channel/levee deposits. The seventh subunit (Sequence 4g) is a 429 

foot-thick package of semi-continuous, fine-grained channel/levee complexes with interbedded MTDs. 

Minor silt or sand stringers may be enc ountered within this interval. T he basal portion of Sequence 4 

(Sequence 4h) is about 802 feet thick and is a mixed-lithology interval of submarine channel/levee deposits 

and MTDs to the depth of the tophole investigation (~4,740 feet BML). 

Fault Penetrations. One major seafloor fault will be crossed by the proposed wellbore at a depth of about 

2,963 feet BML (-6,766 feet MLLW). The top of this fault is located approximately 3,630 feet to the 

northeast of Proposed Well F. The fault strikes northwest-southeast, is downthrown to the southwest, and 

is interpreted to be active due to significant stratigraphic offset at the seafloor. Continued movement may 

have long-term effects on subsurface installations that penetrate this fault and should be a c onsideration 

during wellbore design. 

In addition, the drill string will intersect one mapped buried fault at a depth of approximately 1,537 feet BML 

(-5,340 feet MLLW). Nu merous unresolved buried faults may also be i ntersected by the drill string 

throughout the tophole section. Due to the inactive nature of these buried features, fault plane movement 

is not expected to present a haz ard to drilling operations. How ever, possible drilling fluid circulation 

interruptions should be expected when penetrating major faults and/or highly faulted zones. 

Salt Penetration. The top of salt exists below the depth of investigation of this wellsite clearance 

assessment; however, a general description of shallow salt conditions is provided below. T he proposed 

wellsite will penetrate a salt structure at approximately 7,214 feet BML (-11,017 feet MLLW). The top of salt 

gradient at this location is approximately 23.4o (43.3%) to the northeast. 

Drilling complications that may be enc ountered with salt penetration include bit wander, rapid salt 

dissolution (uncontrolled borehole enlargement), major temperature and/or pressure fluctuations, drilling 

fluid circulation problems, casing collapse, and stuck bits. In addition, unresolved sub-salt geohazards may 

exist and should be taken into consideration. The salt body at this location is considered to be active and 

gradual, continued movement is likely. Ongoing halokinetic activity may have a significant impact on both 

surface and subsurface infrastructure installations. These problems should be anticipated, and mitigating 

measures should be incorporated into borehole design, equipment selection, and drilling techniques. 

Potential for Lost Circulation or Caving. The proposed wellbore will intersect two major faults within the 

tophole section. Secondary porosity and permeability may exist that could cause drilling fluid loss to the 

formation surrounding the borehole. The attached tophole prognosis chart displays an assessment of lost 

circulation/caving potential for each sedimentary unit. Designations of “negligible”, “low”, “moderate”, and 

“high” are used to indicate lost circulation and caving potential. 

Unit 1a does not contain any resolvable faults; however, due t o the likelihood of encountering looselyconsolidated sediments within this interval, borehole integrity may be difficult to maintain. For this reason, 

a (slightly elevated) lost circulation/caving potential of “low” is assessed for Unit 1a. Units 1b through 4a 

are assessed a l ost circulation/caving potential of “negligible”. Problems with jetted installation of 

conductor pipe are not expected, as near-surface soils appear to be normally consolidated and relatively 

fine-grained. How ever, geotechnical data would be required to accurately define the soil type in the 

shallow section at the proposed wellbore. Washouts and caving are possible if unresolved sandy sections 
Report No. 2414-5050 5

are encountered. T hese problems could affect the verticality and load-carrying capacity of the surface 

conductor. In addition, if dewatered/compacted MTDs are encountered, pipe refusal during jet-in of the 36-

inch conductor may be experienced by the drilling contractor. 

A major fault will be penet rated in Unit 4a; therefore, this interval is assessed a drilling fluid circulation 

loss/caving potential of “low to moderate”. Unit 4b may contain intraformational faults that are below the 

resolution of the 3D seismic data and is also assessed a lost circulation/caving potential of “low”. A major 

fault will be penet rated in Unit 4d; thus, this interval is assessed a dr illing fluid circulation loss/caving 

potential of “low to moderate”. Dr illing fluid interruptions and/or problems with borehole caving are not 

anticipated in the remainder of the tophole section; for this reason, these intervals are assessed a l ost 

circulation/caving potential of “negligible”. The drilling mud program should be des igned with these 

assessments as a consideration. 

Potential for Sub-Seafloor Gas Hydrates. No evidence of a bottom-simulating-reflector (BSR) that may 

indicate the base of the gas hydrate stability zone (BGHSZ) was observed in the shallow seismic data near 

the proposed wellbore (Figures 5 & 6). It is important to note that the presence of a BSR is not a requisite 

for the existence of gas hydrates, nor is a BSR alone necessarily indicative of gas hydrates. The seismic 

data cannot help directly predict the distribution and quantity of hydrates within the stability zone. However, 

it is reasonable to expect that accumulations of gas hydrates are more likely to occur near accumulations of 

free-phase gas. If gas hydrates are present in the shallow sediments, they would likely occur within the 

predominately fine-grained interval between the seafloor and t he BGHSZ in localized and di sseminated 

accumulations of small crystals and nod ules, lenses and partings, or thin veins. Although disseminated 

gas hydrates are possible, it is unlikely that this condition would constrain exploratory drilling. 

Potential for Free-Phase Gas Accumulations. No subsurface seismic amplitude anomalies that were 

interpreted to represent probable free-phase gas accumulations will be intersected by the proposed vertical 

wellbore within the depth of this geophysical investigation. Amplitude anomalies that were delineated in the 

Giverny regional geohazards studies (FGSI Job Nos. 2412-5023 & 2414-5050) are annotated on t he 

attached 8.5” x 11” Subsurface Geologic Features Map (Figure 9). 

The closest amplitude anomaly within the depth of investigation is located approximately 238 feet to the 

south of Proposed Wellsite F. This anomaly falls within Stratigraphic Sequence 3 and i s buried 

approximately 1,103 feet BML (-4,906 feet MLLW). This anomaly and several others exist within 500 feet 

of the proposed wellsite; however, they are limited in lateral extent and should not pose a hazard to vertical 

drilling activity at the proposed surface location. 

Stratigraphic Sequences 4b, 4d, and 4f are assessed a shallow gas potential of “low” due to the presence 

of relatively high amplitude, sand-prone, potentially gas-charged sediment. However, seismic amplitudes 

within these intervals are below the respective anomaly picking thresholds and were not mapped as 

hazards. A lthough problems with shallow gas are not likely within these intervals, mitigation measures 

should be considered as a risk-reduction measure. The remainder of the tophole section is primarily finegrained and is assessed a shallow gas potential of “negligible”. 

Seismic amplitude analysis is a subjective process; therefore, any additional seismic records collected near 

the proposed well location should be inspected for evidence of shallow gas. Possible shallow gas 

accumulations should be avoided or otherwise mitigated by proper well design. Additionally, the possibility 

of penetrating unresolved gas-charged sands within the riserless section should be c arefully considered 

and incorporated into the wellbore design. 

Potential for Shallow Water-Flow (SWF). Shallow geologic conditions are conducive for the induction 

and preservation of geopressure within sand-prone deposits in the vicinity of the proposed wellbore. Based 

on regional analysis, the study area lies within a zone of high risk for SWF (Ostermeier et al, 2002). This 

classification is based on t he number of local SWF occurrences and t heir severity. The closest shallow 
Report No. 2414-5050 6

water flow event that was reported in the vicinity of the study area was at the AT398 No. 1 well, which is 

located approximately 5.8 miles southeast of the proposed wellsite. This SWF event was reported to the 

BOEM at a depth of 4,473 feet below sea surface (BSS) (854 feet BML) with a severity of “minor”. The 

AT398 No. 1 SWF sand was seismically correlated with Horizon 20 in the Giverny prospect area. Horizon 

20 is a sand-prone reflector that forms the base of Stratigraphic Sequence 2 and the top of Stratigraphic 

Sequence 3. 

All SWF problems that were reported to the BOEM within a 15 m ile radius of the proposed Giverny “F” 

Location are summarized in the table below. The seismic dataset that was used for the regional Giverny 

geohazards analysis (FGSI Report Nos. 2412-5023 and 2414- 5050) did not encompass offset wells 

GC435-1, AT267-1, and AT222-1; therefore, a direct stratigraphic correlation of the SWF-prone intervals 

encountered at these locations was not attempted. 

Well Name 

Distance from 

Proposed Giverny 

“F” Location 

Depth BML 

of SWF 

Sand 

Depth BSS 

of SWF 

Sand 

SWF Severity Spud Date Well Integrity 

AT398-1 ~5.8 miles SE 854’ 4,473’ Minor 6/18/2005 Maintained 

GC435-1 ~7.4 miles SW 1,400’ 5,125’ Moderate 7/13/2003 Not Maintained

AT267-1 ~10.8 miles NE 934’ 4,275’ Minor 1/6/2005 Maintained 

AT222-1 ~9.3 miles NE 1,204’ 4,374’ Low 3/14/1992 Maintained 

Sediments within Stratigraphic Sequence 1 ( -3,803’ MLLW to -4,213’ MLLW) are interpreted to consist 

primarily of fine-grained material with relatively low overburden; thus, the likelihood for SWF within these 

intervals is deemed “negligible”. The remainder of the tophole sediment sequences may contain silt or 

sand-prone, loosely-consolidated material that is overlain by rapidly-deposited, fine-grained overburden 

and are assigned elevated SWF potentials. Det ails regarding these assessments are provided in the 

Tophole Prognosis Chart (Figure 7). In addition, the following table summarizes the SWF assessments for 

potential problem intervals within the riserless section. 

Stratigraphic Designation SWF Potential Qualitative Reasoning for Assessment 

Sequence 2 (-4213’ to -4,607’ MLLW) Low to 

Moderate 

Potentially contains unresolved sand lenses sealed by rapidly 

deposited, fine-grained MTDs; additionally, the base of this 

interval (Horizon 20) is stratigraphically correlative with the 

AT398-1 SWF event 

Sequence 3a (-4607’ to -4,745’ MLLW) Low to 

Moderate 

Potentially contains unresolved sand lenses sealed by rapidly 

deposited, fine-grained MTDs; additionally, the top of this 

interval (Horizon 20) is stratigraphically correlative with the 

AT398-1 SWF event 

Sequence 3b (-4,745’ to -5,072’ MLLW) Moderate Sand-prone interval sealed by rapidly deposited, fine-grained 

MTDs 

Sequence 4a (-5,072’ to -5,633’ MLLW) Low to 

Moderate 

Generally fine-grained interval; however, unresolved, 

overpressured sands may be encountered 

Sequence 4b (-5,633’ to -6,329’ MLLW) Moderate to 

High 

High-amplitude, laterally continuous sand-prone interval sealed 

by rapidly deposited, fine-grained MTDs 

Sequence 4c (-6,329’ to -6660’ MLLW) Low to 

Moderate 

Generally fine-grained interval; however, unresolved, 

overpressured sands may be encountered 

Sequence 4d (-6660’ to -6854’ MLLW) Moderate Sand-prone interval sealed by rapidly deposited, fine-grained 

MTDs 

Sequence 4e (-6,854’ to -7,100’ MLLW) Low to 

Moderate 

Generally fine-grained interval; however, unresolved, 

overpressured sands may be encountered 

Sequence 4f (-7,100’ to -7,312’ MLLW) Moderate Sand-prone interval sealed by rapidly deposited, fine-grained 

MTDs 

Sequence 4g (-7,312’ to -7,741’ MLLW) Low to 

Moderate 

Generally fine-grained interval; however, unresolved, 

overpressured sands may be encountered 

Sequence 4h (-7,741’ to -8,543’ MLLW) Moderate to 

High 

Moderate to high-amplitude, laterally continuous sand-prone 

interval sealed by rapidly deposited, fine-grained MTDs 
Report No. 2414-5050 7

Given the regional geologic setting and the reported shallow water flow issues with offset wells in the 

vicinity of this location, it is recommended that mitigation measures are planned as a precaution against 

potential SWF events. Real -time remotely operated vehicle (ROV) monitoring at the wellhead is 

recommended for early detection of SWF problems. Additionally, the drilling contractor should maintain an 

adequate supply of kill mud to maintain control of the well in the event that a SWF problem occurs. A 

small-diameter pilot hole through the riserless section is an optional pre-spud mitigation measure that may 

be employed to reduce the risks associated with drilling in areas with known SWF problems. A 

contingency plan for SWF containment should be developed so that problems can be contained as quickly 

as possible. 

Archaeological Assessment. Findings submitted in this archaeological assessment are based on the 

interpretation of AUV side scan sonar and AUV bathymetric data sets. FGSI acquired the high-resolution 

geophysical survey data utilizing a Hugin 3000 AUV aboard the Fugro Enterprise on October 9-11, 2012 

(described in FGSI Report No. 2412-5023) and on October 7-9, 2014 (described in FGSI Report No. 2414-

5050). T he quality of the collected geophysical data for both surveys was excellent, and t he data were 

suitable for interpretation. 

Horizontal positioning of the survey vessel was accomplished with the FUGRO STARFIX Differential 

Global Positioning System, which has a field accuracy of <1 meter. T he AUV navigates using a gl obal 

positioning system (GPS) while on the surface and an inertial navigation system (INS) coupled with a 

Doppler velocity logger when submerged. In addition, the AUV is tracked with a super-short baseline 

(SSBL) system and s ent position updates via an acoustic modem to continually augment the INS 

navigation. During the 2012 survey, the AUV performed pre-programmed survey missions collecting 120 

kilohertz (kHz) and 410 kHz chirp side scan sonar data. The sonar sensor on the AUV was upgraded 

subsequent to the 2012 survey; for this reason, 230 kHz and 5 40 kHz chirp side scan sonar data were 

collected during the 2014 survey. 200 kHz multibeam bathymetry data were collected during both surveys. 

During data acquisition, the AUV was maintained at an al titude of approximately 40 m eters above the 

seafloor. 

The survey grid for the 2012 dat aset (FGSI report No. 2412-5023) consists of twenty-two (22) primary 

north-south tracklines (Lines 100-121) spaced 200 meters apart and eleven (11) east-west tie-lines (Lines 

200-210) spaced 900 meters apart. Maritime conditions during portions of the 2012 survey used for this 

study were variable, with seas ranging from 2 to 5 feet and winds ranging from 5 to 20 knots. 

The survey grid for the 2014 dataset consists of twenty-six (26) primary north-south tracklines (Lines 301-

326) spaced at 200-meter intervals and seven (7) east-west tie lines (Lines 400-406) spaced at 900-meter 

intervals. Sea conditions during data acquisition were moderate, with winds ranging from approximately 

five to 15 knots and seas ranging from one to five feet. Tracklines from the 2012 and 2014 s urveys are 

shown on Chart 1 in green and blue, respectively. 

For both surveys, side scan sonar, sub-bottom profiler, and multibeam bathymetric systems were run on all 

AUV tracklines. Navigational fixes (shot points) were recorded at 410-foot (125 meter) intervals and were 

annotated on al l data. The survey grids provide complete coverage of the seafloor with the sonar and 

multibeam bathymetry systems and a representative sampling of the subsurface with the sub-bottom 

profiler. 

An archaeological assessment of the proposed well location is summarized below: 

 This Archaeological Assessment was written to satisfy the Bureau of Ocean Energy 

Management/Bureau of Safety and Environmental Enforcement (BOEM/BSEE) regulations set forth by 

NTLs 2005-G07, 2011-JOINT-G01, and Mitigation 3.20 (Avoidance of Archaeological Resources). 
Report No. 2414-5050 8

 The regional probability for shipwrecks in this area is considered to be low; preservation of a wreck 

would be moderate to good (Pearson et al. 2003). Analyses of available shipwreck sources, as well as 

the FUGRO CHANCE database, indicate that no shipwrecks have been reported in the vicinity of the 

proposed well location. 

 The seafloor within close proximity to the proposed “F” surface location is relatively flat and featureless. 

Regionally, the seafloor displays some irregularities due t o seafloor fault scarps and a b uried 

mudmound. The closest fault scarp is approximately 165 feet to the southwest of the proposed surface 

location. There were no i rregular seafloor features identified on the multibeam bathymetry data that 

could represent unidentified shipwreck remains. 

 The water depth at the proposed “F” surface location is approximately -3,803 feet with zero datum at 

Mean Lower Low Water. 

 In general, the side scan sonar images exhibit low to moderate reflectivity, which is indicative of 

relatively homogenous, fine-grained seafloor sediments. 

 Eighteen (18) sonar contacts were mapped in the 2012 regional Giverny study area (FGSI Report No. 

2412-5023). Sonar Contact No. 13 was recommended for avoidance by 1,000 feet. This contact is 

located within the eastern portion of GC349 (approximately 2.4 miles from the Proposed “F” Location). 

Sonar Contact No. 13 measures 6.6 feet x 21.9 feet and exhibits a hei ght of approximately 2.7 feet 

above the ambient seafloor. This contact could not be reliably identified by the sonar records. The 

remaining seventeen (17) sonar contacts were interpreted to represent modern anthropogenic debris or 

geologic features and are not deemed archaeologically significant. All sonar contacts from the 2012 

survey are displayed on Chart 1 in orange. 

 Sixteen (16) additional sonar contacts were mapped from the survey data collected in 2014. These 

contacts were interpreted to represent modern anthropogenic debris or geologic features and are not 

deemed archaeologically significant. All sonar contacts from the 2014 survey data are displayed on 

Chart 1 in green. 

 No side scan sonar contacts were noted within 2,000 feet of the proposed “F” surface location.

 The evaluation of the high-resolution geophysical survey data indicates that there were no unus ual 

depressions, scours, sediment changes, or unidentified seafloor targets observed within 2,000 feet of 

the proposed surface location that could represent unidentified shipwreck remains. 

It is possible that small features representing high probability areas for historic shipwreck materials may not 

be detected by the geophysical instruments or may not be det ected during interpretation of the data. If 

evidence of historic cultural remains is encountered during subsequent work, the BOEM/BSEE 

archaeologists must be contacted within 48 hour s to provide an as sessment of these artifacts, and al l 

operations must cease within 1,000 feet of the exposed objects. 
Report No. 2414-5050 9

Closing. We appreciate the opportunity to work with you on this project and look forward to continuing as 

your geohazards consultants. I f you have any questions concerning this assessment, please do not 

hesitate to contact us (337-268-3236). 

Sincerely, 

FUGRO GEOSERVICES, INC. 

Dean Gresham 

Geoscience Group Manager 

Ray Blackmon 

Supervising Archaeologist 

Attachments: 

 Wellsite-Specific Seafloor Features & Bathymetry Chart (1:12,000)

 3D Seismic Frequency Spectrum, Proposed Wellsite F, Block 393, Green Canyon Area (Figure 1)

 Multibeam Bathymetry Rendering, Proposed Wellsite F, Block 393, Green Canyon Area (Figure 2)

 MBES Backscatter Mosaic, Proposed Wellsite F, Block 393, Green Canyon Area (Figure 3)

 Side Scan Sonar Mosaic, Proposed Wellsite F, Block 393, Green Canyon Area (Figure 4)

 3D Seismic Inline 6664 Proposed Wellsite F, Block 393, Green Canyon Area (Figure 5)

 3D Seismic Crossline 2050, Proposed Wellsite F, Block 393, Green Canyon Area (Figure 6)

 Tophole Prognosis Chart, Proposed Wellsite F, Block 393, Green Canyon Area (Figure 7)

 Sub-bottom Profiler Section, Line 117, Wellsite F, Block 393, Green Canyon Area (Figure 8)

 Subsurface Geologic Features Map, Proposed Wellsite F (8.5” x 11”, 1:12,000) (Figure 9)
Freeport-McMoRan Oil & Gas LLC Section 4 – Pg. 9 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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 550.215, FM O&G requests that Green Canyon Block 393 be 

classified by the BOEM as H2S absent. 

4.3 H2S CONTINGENCY PLAN 

An H2S Contingency Plan is not required for the activities proposed in this plan. 

4.4 MODELING REPORT 

Modeling reports are not required for the activities proposed in this plan. 
Freeport-McMoRan Oil & Gas LLC Section 5 – Pg. 10 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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’). Fugro Geoservices, Inc. was contracted to provide an assessment of the shallow 

conditions at the proposed surface location. The purpose of the assessment was to address 

seafloor conditions that may impact exploratory drilling operations within 2,000 feet of the 

proposed well site. 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 Block 393 is not located within 61 meters (200 feet) of any pinnacle trend 

feature; therefore, a separate bathymetric map is not required per NTL No. 2009-G39, 

“Biologically Sensitive Underwater Features and Areas.”

5.5 LIVE BOTTOMS (LOW RELIEF) 

Green Canyon Block 393 is not located within 30 meters (100 feet) of any live bottom (low relief)

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

are not required per NTL No. 2009-G39, “Biologically Sensitive Underwater Features and 

Areas.”

5.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP

Green Canyon Block 393 is 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 13; therefore, FM O&G 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-N01, 

“Elimination of Expiration Dates on Certain Notices to Lessees and Operators Pending Review 

and Reissuance”).
Freeport-McMoRan Oil & Gas LLC Section 5 – Pg. 11 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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 X* -- None

Whale, Finback Balaenoptera physalus E X* -- None

Whale, 

Humpback

Megaptera novaeangliae E X* -- None

Whale, North 

Atlantic Right

Eubalaena glacialis E X* -- None

Whale, Sei Balaenopiera borealis E X* -- 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,E** 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 (panhandle)

Corals

Coral, Elkhorn Acopora palmate T - X Florida Keys and Dry 

Tortugas

Coral, Staghorn Acopora cervicornis T - X Florida

Abbreviations: E = Endangered; T = Threatened

* 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. 
Freeport-McMoRan Oil & Gas LLC Section 5 – Pg. 12 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

** Green Sea turtle is threatened, except for the Florida breeding population, which is listed as endangered.

5.9 ARCHAEOLOGICAL REPORT

Green Canyon Block 393 has been determined to have a high potential for containing 

archaeological properties.

In accordance with NTL No. 2005-G07 “Archaeological Surveys and Reports,” and NTL No. 

2011-JOINT-G01, “Revisions to the List of OCS Lease Blocks Requiring Archaeological 

Resource Surveys and Reports,” a Shallow Hazard and Archaeological Assessment was 

included with Exploration Plan (Control No. N-9739) approved March 31, 2014. A supplement 

to the previously submitted report is provided with this plan. 

5.10 AIR AND WATER QUALITY INFORMATION

Air and water quality information is not required to be included in this plan per NTL No. 2008-

G04, “Information Requirements for Exploration Plans and Development Operations 

Coordination Documents” (Extended by NTL No. 2014-N01, “Elimination of Expiration Dates on 

Certain Notices to Lessees and Operators Pending Review and Reissuance”).

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. 2014-N01, “Elimination of Expiration Dates on Certain 

Notices to Lessees and Operators Pending Review and Reissuance”).
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 WELL NO. 1

 WELL NO. 2

OCS-G-18578

OCS-G-18578

AT310

AT354

OCS-G-34580

AT398

OCS-G-31796

AT397

OCS-G-33287

AT353

OCS-G-35022

AT309

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1

GC393

OCS-G-32500

GC437

GC349

OCS-G-31717

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<<< LIN

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<<< LINE 400

<<< LINE 406

LINE 405 >>>

<<< LINE 404

LINE 403 >>>

<<< LINE 401

LINE 402 >>>

SURVEY VESSEL:

JOB NO.: 2414-5050

POSITIONING BY: STARFIX

INTERPRETATION BY: D. MATTE / M. SAMSON

DATE: DECEMBER 29, 2014

SURVEY DATES:

DWG NO.: 24145050-B.dwg

REVISION NO.: 0

CHECKED BY: D. GRESHAM

DRAFTED BY: K. LEMAIRE

CHART 1 OF 1

3D SHALLOW HAZARDS STUDY

SEAFLOOR FEATURES & BATHYMETRY MAP

"GIVERNEY" PROSPECT

PROPOSED WELL "F"

BLOCKS GC 349, GC 393 & AT 353

GREEN CANYON & ATWATER VALLEYAREA

GULF OF MEXICO

200 DULLES DRIVE - LAFAYETTE, LOUISIANA 70506 - (337) 237-2636

Fugro GeoServices, Inc.

3,000 4,000

FEET

0 1,000 2,000

SCALE = 1:12,000

5,000

GEODETIC DATUM: NAD27

PROJECTION: UTM GRID UNITS: US SURVEY FEET

ZONE: U.T.M. 15 (NORTH)

 *** IMPORTANT - PLEASE NOTE ***

ANY COMMUNICATION AND/OR POWER CABLES THAT MAY BE PRESENT

IN THE AREA CANNOT BE LOCATED BY INSTRUMENTS UTILIZED DURING

THIS SURVEY. INQUIRIES SHOULD BE MADE TO INTERESTED PARTIES AS TO

THE PRESENCE OF SUCH OBSTRUCTIONS.

ZONE 15

ZONE 14

ZONE 16

ZONE 15

 T E X A S

 A L A B A M A M I S S I S S I P P I

 L O U I S I A N A Pascagoula

Gulfport

Biloxi

Mobile

EWING BANK

VERMILION

Port O'Conner

Port

Lavaca

Matagorda

Freeport

Galveston

Houston

Port

Arthur

Sabine

Pass

Cameron

Grand

Cheniere

Intracoastal

City

Fresh

Water City

Morgan City

Amelia

Houma

Dulac

Grand

Isle

Fourchon

Lake Charles Lafayette

Pensacola

Destin

SOUTH

PADRE

ISLAND

NORTH

PADRE

ISLAND

MUSTANG

ISLAND

MATAGORDA

ISLAND

BRAZOS

GALVESTON

HIGH

ISLAND

EAST BREAKS

CORPUS

CHRISTI

PORT

ISABEL

ALAMINOS CANYON

GARDEN BANKS

KEATHLEY CANYON

GREEN CANYON

WALKER RIDGE

ATWATER VALLEY

LUND

HENDERSON

LLOYD RIDGE

DESOTO CANYON

MISSISSIPPI CANYON

DESTIN DOME

PENSACOLA

MOBILE

WEST

CAMERON EAST

CAMERON

SOUTH MARSH ISLAND

EUGENE

ISLAND SHIP

SHOAL

SOUTH

TIMBALIER

GRAND

ISLE

WEST

DELTA

SOUTH

PELTO

BAY

MARCHAND

SOUTH

PASS

VIOSCA

KNOLL

MAIN PASS

CHANDELEUR

SOUND

CHANDELEUR

BRETON

SOUND

New

Orleans

Venice

LA SOUTH

TEXAS SOUTH CENTRAL

TEXAS SOUTH CENTRAL

TEXAS SOUTH

NUMBER X COORDINATE Y COORDINATE

NUMBER X COORDINATE Y COORDINATE

PROJECT

LOCATION

STUDY AREA (JOB NO. 2412-5023)

10'

l

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WATER DEPTH CONTOURS

CONTOUR INTERVAL = 10 FEET

ZERO DATUM = MEAN LOWER LOW WATER

-3750'

HIGHLY FAULTED ZONE

LINE 101 >>> HUGIN AUV TRACKLINE NUMBER AND DIRECTION (JOB NO. 2412-5023)

POSSIBLE CHEMOSYNTHETIC AREA (BOEM DATABASE 5/2014)

HARD-BOTTOM AREA (POSSIBLE CHEMOSYNTHETIC COMMUNITY)

2,000' AVOIDANCE FOR MUD & CUTTINGS DISCHARGE;

250' AVOIDANCE FOR ALL OTHER BOTTOM-DISTURBING ACTIVITIES

(NTL 2009-G40)

SUBSIDENCE FEATURE

EXISTING WELL LOCATION (FUGRO DATABASE)

2

PROPOSED WELL LOCATION WITH A 2,000 FT RADIUS FOR CHEMOSYNTHETIC

COMMUNITY ASSESSMENT (AS PER MMS NTL 2009-G40).

LINE 101 >>> HUGIN AUV TRACKLINE NUMBER AND DIRECTION (JOB NO. 2414-5050)

2

STUDY AREA (JOB NO. 2414-5050)

RELICT MUD MOUND

SIDE SCAN SONAR CONTACT WITH REFERENCE NUMBER

(MINIMUM AVOIDANCE BOUNDARY WHERE APPLICABLE)

(FGSI JOB NO. 2412-5023)

SIDE SCAN SONAR CONTACT WITH REFERENCE NUMBER

(MINIMUM AVOIDANCE BOUNDARY WHERE APPLICABLE

(FGSI JOB NO. 2414-5050)

FAULT SCARP WITH SEAFLOOR OFFSET IN FEET,

HACHURES ON DOWNTHROWN SIDE
Freeport-McMoRan Oil & Gas LLC Section 6 – Pg. 13 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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. 
N/A N/A N/A N/A No

Potable Water with

4% Stack-Magic ECO-Fv2 105 BBL/WELL 1 BBL/DAY/WELL Discharge at the seafloor or with deck drainage when testedat surface No

Uncontaminated seawater used to 

maintainproper draft 1,208,550 BBL/WELL 11,510 BBL/DAY/WELL Hull discharge overboard. Based upon 5 major ballast operations, with rig at operating draft minimal ballast change is required No

Sea Water with no additional chemicals 3,360 BBL/WELL 32 BBL/DAY/WELL Hull discharge overboard No

Cement Slurry 36,488 BBL/WELL 348 BBL/DAY/WELL Discharge at seafloor during riserless operations. Dicharge rate based 

upon 2 days (28" & 22" cement returns) No

Hull discharge overboard No

333 BBL/DAY/WELL

833 BBL/DAY/WELL

N/A

Overboard upon samples passing the Static Sheen Test per Region 6 

GOM GMG 290000 regulations

Overboard upon samples passing the Static Sheen Test per Region 6 

GOM GMG 290000 regulations

N/A

Brines, NaCl, KCl, CaBr2, CaCl2

N/A

2,000 BBL/WELL

5,000 BBL/WELL

N/A

N/A

Will you be covered by an individual or general NPDES permit? General NPDES Permit No. 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 62,196,645 BBL/WELL 592,349 BBL/DAY/WELL Hull discharge overboard No

No

No

N/A

Rejected water from the watermaker. 158,550 BBL/WELL 1510 BBL/DAY/WELL

Gray water from living quarters 36,330 BBL/WELL 346 BBL/DAY/WELL Chlorinate and discharge overboard No

Sanitary waste from living quarters, control 

rooms and change rooms.

Will you conduct well treatment, completion, or workover?

Micellaneous 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 525 BBL/WELL 5 BBL/DAY/WELL No drillfloor drainage routed to sea. All retained on board and 

processed to <15ppm or sent to shore for disposal No

No

Brines, NaCl, KCl, CaBr2, CaCl2

Will humans be there? If yes, expect conventional waste

16,590 BBL/WELL 158 BBL/DAY/WELL USCG approved MSD with chlorination

Cuttings wetted with synthetic-based fluid Cuttings coated with synthetic drilling fluids,

including drilled out cement 4,939 BBL/WELL 140 BBBL/DAY/WELL

Discharged to surface. Treated cutting will be discharged

overboard during drilling of the SBM intervals. Discharge rate is based 

upon 35 days of drilling. Cuttings will

be processed through a cuttings dryer, substantially reducing

the ROC percentage.

No

Domestic waste

Sanitary

Cuttings wetted with water-based fluid Cuttings coated while drilling with WBM 2,607 BBL/WELL 372 BBL/DAY/WELL Discharged to mudline prior to riser installation. Based on 7 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) 50,000 BBL/WELL 7,143 BBL/DAY/WELL

Discharge at the mudline prior to the riser installation.

Nominal amount of unused fluid may be discharged at the

surface. Based on 7 days of drilling with WBM.

No

 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
Freeport-McMoRan Oil & Gas LLC Section 7 – Pg. 14 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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

Summary information regarding the peak year emissions that will be generated by and 

associated with the Plan Emissions and Complex Total Emissions are provided in the table 

below. This information is compiled on the summary form of the two sets of worksheets. There 

are no existing facilities or activities co-located with the currently proposed activities; therefore, 

the Complex Total Emissions are the same as the Plan Emissions and are provided in the table 

below. 

Air Pollutant Plan Emission 

Amounts (T)

Calculated

Exemption

Amounts (T)

Calculated 

Complex

Total Emission 

Amounts (T)

Carbon monoxide (CO) 425.52 71,778.34 425.52

Particular matter (PM) 56.48 3,230.10 56.48

Sulphur dioxide (SO2) 259.09 3,230.10 259.09

Nitrogen oxides (NOx) 1,941.75 3,230.10 1,941.75

Volatile organic compounds (VOC) 58.54 3,230.10 58.54

This information was calculated by:

 Jean Martin 

281-698-8544

jean.martin@jccteam.com
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2011

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 1 of 8

COMPANY Freeport-McMoRan Oil & Gas LLC

AREA Green Canyon 

BLOCK 393

LEASE OCS-G 32500

PLATFORM NA

WELL Well Loc. F

COMPANY CONTACT Jean Martin 

TELEPHONE NO. 281-698-8544

REMARKS

FM O&G will drill, complete, test, flare and install subsea wellheads using a 

dp drillship. 
EMISSIONS FACTORS

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 2 of 8

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

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

Equipment/Emission Factors units PM SOx NOx VOC CO REF. DATE

NG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96

NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96

NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96

NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 3.3-1 10/96

Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96

Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3-12,14 9/98

NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 14-2, & 14 7/98

NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91

Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98

Tank Vapors lbs/bbl 0.03 E&P Forum 1/93

Fugitives lbs/hr/comp. 0.0005 API Study 12/93

Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991

Gas 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
EMISSIONS CALCULATIONS 1ST YEAR

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 3 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Freeport-McMoRan Oil & Green Canyon 393 OCS-G 32500 NA Well Loc. F Jean Martin 281-698-8544

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

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 SOx NOx VOC CO

DRILLING PRIME MOVER>600hp diesel 61800 2984.94 71638.56 24 105 43.56 199.83 1497.36 44.92 326.70 54.88 251.78 1886.67 56.60 411.64

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

VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 45 1.46 6.68 50.03 1.50 10.92 0.20 0.90 6.75 0.20 1.47

VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 45 3.10 14.23 106.61 3.20 23.26 0.70 3.20 23.99 0.72 5.23

VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 45 3.10 14.23 106.61 3.20 23.26 0.70 3.20 23.99 0.72 5.23

VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 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 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 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 0.00 0.00 0.00 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

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

WELL TEST GAS FLARE 208333.33 24 2 0.12 14.87 12.56 80.94 0.00 0.36 0.30 1.94

2017 YEAR TOTAL 51.22 235.08 1775.48 65.38 465.07 56.48 259.09 1941.75 58.54 425.52

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 3230.10 3230.10 3230.10 3230.10 71778.34

97.0
SUMMARY

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 8 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL

Freeport-McMoR Green Canyon 393 OCS-G 32500 NA Well Loc. F

Emitted Substance

Year

PM SOx NOx VOC CO

2017 56.48 259.09 1941.75 58.54 425.52

Allowable 3230.10 3230.10 3230.10 3230.10 71778.34
Freeport-McMoRan Oil & Gas LLC Section 8 – Pg. 15 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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 December 19, 2014 (OSRP Control No. O-713). 

8.2 SPILL RESPONSE SITES

Primary Response Equipment Location Preplanned Staging Location

Houma, Louisiana

Harvey, Louisiana

Leeville, Louisiana

Houma, Louisiana

Harvey, Louisiana

Fourchon, Louisiana

8.3 OSRO INFORMATION

FM O&G’s primary equipment providers are Clean Gulf Associates (CGA), 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 equipment.

8.4 WORST CASE SCENARIO DETERMINATION 

Category Regional OSRP

WCD - Drilling

EP

WCD - Drilling

Type of activity Exploratory Drilling

>10 miles

Exploratory Drilling

>10 miles

Facility location (area/block) GC 393 GC 393

Facility designation Well Location B Well Location B

Distance to nearest shoreline (miles) 96.5 mi 96.5 mi

Uncontrolled blowout (bbl) 400,000 bbl 397,922 bbl

Total volume (bbl) 400,000 bbl 397,922 bbl

Type of oil(s)

(crude, condensate, diesel)

Crude Crude

API gravity 25o 25o

The Regional OSRP Drilling WCD calculations were approved December 19, 2014 (OSRP O713). The EP Drilling WCD calculations were accepted under Exploration Plan (Control No. N9739) 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 December 19, 2014, and since the worst-
Freeport-McMoRan Oil & Gas LLC Section 8 – Pg. 16 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

case scenario determined for our EP 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 EP.

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.
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 397,922 barrels of crude oil with an API gravity of 25°.

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 5% probability of impact to the shorelines of Cameron 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.

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 7% or 

approximately 27,855 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 370,067 barrels remaining.

Spill Response GC 393, Well Location B Barrels of Oil 

WCD Volume 397,922

Less 7% natural evaporation/dispersion 27,855

Remaining volume 370,067

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 an 

operations safety analysis, the size of the spill, weather and potential impacts. If aerial 
dispersants are utilized, 8 sorties (9,600 gallons) from two of the DC-3 aircrafts and 4 sorties 

(8,000 gallons) from the Basler aircraft would provide a daily dispersant capability of 7,540 

barrels. If the conditions are favorable for in-situ burning, the proper approvals have been 

obtained and the proper planning is in place, in-situ burning of oil may be attempted. Slick 

containment boom would be immediately called out and on-scene as soon as possible. Offshore 

response strategies may include attempting to skim utilizing CGA’s, MSRC’s, and NRCC’s spill 

response equipment, with a total derated skimming capacity of 1,046,754 barrels. Temporary 

storage associated with skimming equipment equals 317,687 barrels. If additional storage is 

needed, various tank barges with a total of 1.4 million+ barrels of storage capacity may be 

mobilized and centrally located to provide temporary storage and minimize off-loading time. 

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

prior to any containment/skimming attempts. 

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

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

and NRCC’s near shore and shallow water skimmers with a totaled derated skimming capacity of 

147,605 barrels. Temporary storage associated with skimming equipment equals 2,393 barrels. If 

additional storage is needed, a 47,000 barrel storage barge, a 25,000 barrel storage barge, three 

20,000 barrel storage barges, and three 23,000 barrel storage barges may be mobilized and 

centrally located to provide temporary storage and minimize off-loading time. 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 and OMI Environmental will 

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

times needed for procurement, load out, travel time to the site and deployment. Strategies would 

be based upon surveillance and real time trajectories that depict areas of potential impact given 

actual sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan, 

applicable Area Contingency and Geographical Response Plans 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 

77 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 be supervised by the designation of a SIMOPS group as 

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

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

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

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

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

the Source Control Section Chief.

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

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

slick movement in real time.

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

• Information will be confirmed

• An assessment will be made and initial objectives set

• OSROs and appropriate agencies will be notified 

• ICS 201, Initial Report Form 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 aerial dispersant providers 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 reports to vessels to expedite their arrival at sites that will provide for 

their most effective containment 

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

Dedicated off-shore skimming systems

General

• Deployed to the highest concentration of oil

• Assets deployed at safe distance from aerial dispersant and in-situ burn operations

CGA HOSS Barge

• Use in areas with heaviest oil concentrations

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

CGA 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

T&T Koseq Skimming Systems

• To the area of the thickest oil

• Use as far off-shore as allowed

MSRC PSV-VOO Skimming Systems

• To the area of the thickest oil

• Use as near-shore as allowed by draft of vessel

• Use as far off-shore as needed

• Expected 24-hour mobilization

• Expected length of 200 foot or greater

• PSV-VOO with deck space of 150’ x 40’ to provide space for skimmer, marine storage 

tanks and boom

• PSV-VOO with 2,000-20,000 bbl below deck storage supplemented with 2 or more 500 

bbl marine portable tanks, if necessary, depending on below deck storage

MSRC Oil Spill Response Vessels (OSRV)

• Use in areas with heaviest oil concentrations

• Use as near-shore as allowed by draft of vessel

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

• Use as far off-shore as needed

MSRC Fast Response Vessels (FRV)

• Use in areas with heaviest oil concentrations

• Use as far off-shore as allowed

MSRC Responders

• Use in areas with heaviest oil concentrations

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

NRCC Oil Spill Response Barge (OSRB)

• Use in areas with heaviest oil concentrations

NRCC Oil Spill Response Vessel (OSRV)

• To the area of the thickest oil

• Use as far off-shore as allowed
NRCC Vessel of Opportunity Skimming System (VOSS)

• To the area of the thickest oil

• Use as far off-shore as allowed

• VOOs minimum 110’ in length

• VOOs with minimum of 8x15 of optimum deck space

• VOOs with 200-400 ft of boom

• Storage tanks of 100 bbls or more

Storage Vessels

• Establish availability of 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

• Expect mission specific and safety training to be required

• Plan with the US Coast Guard/ABS 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 

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

• Ensure VOO crew members are trained prior to operations
• Determine assets to perform on water operation

• Build operations into safety plan

• Conduct operations in accordance with an approved plan

• Initial test burn to ensure effectiveness

Adverse Weather Operations:

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

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

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

an emergency, ”stop work” may be directed by any crew member.
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
CGA Minimum Acceptable Capabilities for Vessels of Opportunity (VOO)

Minimum acceptable capabilities of Petroleum Industry Designed Vessels (PIDV) for conducting 

Vessel of Opportunity (VOO) skimming operations are shown in the table below. PIDVs are 

“purpose-built” to provide normal support to offshore oil and gas operators. They include but 

are not limited to utility boats, offshore supply vessels, etc. They become VOOs when tasked 

with oil spill response duties.

Capability FRU KOSEQ AquaGuard

Type of Vessel Utility Boat Offshore Supply 

Vessel Utility Boat

Operating parameters

Sea State 3-5 ft max 9.8 ft max 3-5 ft max

Skimming speed ≤1 kt ≤3 kts ≤1 kt

Vessel size

Minimum Length 100 ft 200 ft 100 ft

Deck space for:

• Tank(s)

• Crane(s)

• Boom Reels

• Hydraulic Power Units

• Equipment Boxes

18x32 ft 100x40 ft 18x32 ft

Communication Assets Marine Band 

Radio Marine Band Radio Marine Band Radio

Tactical use of Vessels of Opportunity (VOO): FM O&G will take all possible measures to 

maximize the oil-to-skimmer encounter rate of all skimming systems, to include VOOs, as 

discussed in this section. VOOs will normally be placed within an On-water recovery unit as 

shown in figures below.

Skimming Operations: PIDVs are the preferred VOO skimming platform. OSROs are more 

versed in operating on these platforms and the vessels are generally large enough with crews 

more likely versed in spill response operations. They also have a greater possibility of having 

on-board storage capacity and the most likely vessels to be under contract, and therefore more 

readily available to the operator. These vessels would normally be assigned to an on-water 

recovery group/division (see figure below) and outfitted with a VOSS suited for their size and 

capabilities. Specific tactics used for skimming operations would be dependent upon many 

parameters which include, but are not limited to, safety concerns, weather, type VOSS on board, 

product being recovered, and area of oil coverage. Planners would deploy these assets with the 

objective of safely maximizing oil- to-skimmer encounter rate by taking actions to minimize 

non-skimming time and maximizing boom swath. Specific tactical configurations are shown in 

figures below.

The Fast Response Unit (FRU): A self-contained, skid based, skimming system that is 

deployed from the right side of a vessel of opportunity (VOO). An outrigger holds a 75’ long 
section of air inflatable boom in place that directs oil to an apex for recovery via a Foilex 250 

weir skimmer. The outrigger creates roughly a 40’ swath width dependent on the VOO beam. 

The lip of the collection bowl on the skimmer is placed as close to the oil and water interface as 

possible to maximize oil recovery and minimize water retention. The skimmer then pumps all 

fluids recovered to the storage tank where it is allowed to settle, and with the approval of the 

Coast Guard, the water is decanted from the bottom of the tank back into the water ahead of the 

containment boom to be recycled through the system. Once the tank is full of as much pure 

recovered oil as possible it is offloaded to a storage barge for disposal in accordance with an 

approved disposal plan. A second 100 barrel storage tank can be added if the appropriate 

amount of deck space is available to use as secondary storage. 
Tactical Overview

Mechanical Recovery – The FRU is designed to provide fast response skimming capability in the 

offshore and nearshore environment in a stationary or advancing mode. It provides a rated daily 

recovery capacity of 4,100 barrels. An additional boom reel with 440’ of offshore boom can be 

deployed along with the FRU, and a second support vessel for boom towing, to extend the swath 

width when attached to the end of the fixed boom. The range and sustainability offshore is 

dependent on the VOO that the unit is placed on, but generally these can stay offshore for 

extended periods. The FRU works well independently or assigned with other on-water recovery 

assets in a task force. In either case, it is most effective when a designated aircraft is assigned to 

provide tactical direction to ensure the best placement in recoverable oil. 

Maximum Sea Conditions – Under most circumstances the FRU can maintain standard oil spill 

recovery operations in 2’ to 4’ seas. Ultimately, the Coast Guard licensed Captain in charge of 

the VOO (with input from the CGAS Supervisor assigned) will be responsible to determine when 

the sea conditions have surpassed the vessel’s safe operating capabilities. 

Possible Task Force Configuration (Multiple VOOs can be deployed in a task force)

1 – VOO (100’ to 165’ Utility or Supply Vessel) 

1 – Boom reel w/support vessel for towing

1 – Tank barge (offshore) for temporary storage

1 – Utility/Crewboat (supply)

1 – Designated spotter aircraft

The VOSS (yellow) is being deployed and connected to an out-rigged arm. This is 

suitable for collection in both large pockets of oil and for recovery of streaming oil. 

The oil-to-skimmer encounter rate is limited by the length of the arm. Skimming 

pace is < 1 knot.
Through the use of an additional VOO, and using extended sea boom, the swath of 

the VOSS is increased therefore maximizing the oil-to-skimmer encounter rate. 

Skimming pace is < 1 knot.
The Koseq Rigid Sweeping Arm: A skimming system deployed on a vessel of opportunity. It 

requires a large Offshore or Platform Supply Vessel (OSV/PSV), greater than 200’ with at least 

100’ x 50’ of free deck space. On each side of the vessel, a 50’ long rigid framed Arm is 

deployed that consists of pontoon chambers to provide buoyancy, a smooth nylon face, and a 

hydraulically adjustable mounted weir skimmer. The Arm floats independently of the vessel and 

is attached by a tow bridle and a lead line. The movement of the vessel forward draws the rubber 

end seal of the arm against the hull to create a collection point for free oil directed to the weir by 

the Arm face. The collection weir is adjusted to keep the lip as close to the oil water interface as 

possible to maximize oil recovery while attempting to minimize excess water collection. A 

transfer pump (combination of positive displacement, screw type and centrifuge suited for highly 

viscous oils) pump the recovered liquid to portable tanks and/or dedicated fixed storage tanks 

onboard the vessel. After being allowed to sit and separate, with approval from the Coast Guard, 

the water can be decanted (pumped off) in front of the collection arm to be reprocessed through 

the system. Once full with as much pure recovered oil as possible, the oil is transferred to a 

temporary storage barge where it can be disposed of in accordance with an approved disposal 

plan. 

Tactical Overview

Mechanical Recovery – Deployed on large vessels of opportunity (VOO) the Koseq Rigid 

Sweeping Arms are high volume surge capacity deployed to increase recovery capacity at the 

source of a large oil spill in the offshore and outer nearshore environment of the Gulf of Mexico. 

They are highly mobile and sustainable in rougher sea conditions than normal skimming vessels 

(9.8’ seas). The large Offshore Supply Vessels (OSV) required to deploy the Arms are able to 

remain on scene for extended periods, even when sea conditions pick up. Temporary storage on

deck in portable tanks usually provides between 1,000 and 3,000 bbls. In most cases, the OSV 

will be able to pump 20% of its deadweight into the liquid mud tanks in accordance with the 

vessels Certificate of Inspection (COI). All storage can be offloaded utilizing the vessels liquid 

transfer system. 

Maximum Sea Conditions - Under most circumstances the larger OSVs are capable of remaining 

on scene well past the Skimming Arms maximum sea state of 9.8’. Ultimately it will be the 

decision of the VOO Captain, with input from the T&T Supervisor onboard, to determine when 

the sea conditions have exceeded the safe operating conditions of the vessel. 

Command and Control – The large OSVs in many cases have state of the art communication and 

electronic systems, as well as the accommodations to support the function of directing all 

skimming operations offshore and reporting back to the command post. 

Possible Task Force Configuration (Multiple Koseq VOOs can be deployed in a task force)

1 – > 200’ Offshore Supply Vessels (OSV) with set of Koseq Arms 

2 to 4 portable storage tanks (500 bbl)

1 – Modular Crane Pedestal System set (MCPS) or 30 cherry picker (crane) for deployment

1 – Tank barge (offshore) for temporary storage

1 – Utility/Crewboat (supply)

1 – Designated spotter aircraft

4 – Personnel (4 T&T OSRO)
Scattered oil is “caught” by two VOO and collected at the apex of the towed sea 

boom. The oil moves thought a “gate” at that apex, forming a larger stream of oil 

which moves into the boom of the skimming vessel. Operations are paced at >1. A 

recovered oil barge stationed nearby to minimize time taken to offload recovered 

oil.

This is a depiction of the same operation as above but using KOSEQ Arms. In this 

configuration, the collecting boom speed dictates the operational pace at > 1 knot to 

minimize entrainment of the oil.
Clean Gulf Associates (CGA) Procedure for Accessing Member-Contracted and other 

Vessels of Opportunity (VOOs) for Spill Response

• CGA has procedures in place for CGA member companies to acquire vessels of 

opportunity (VOOs) from an existing CGA member’s contracted fleet or other sources 

for the deployment of CGA portable skimming equipment including Koseq Arms, Fast 

Response Units (FRUs) and any other portable skimming system(s) deemed appropriate 

for the response for a potential or actual oil spill, WCD oil spill or a Spill of National 

Significance (SONS). 

• CGA uses Port Vision, a web-based vessel and terminal interface that empowers CGA to 

track vessels through Automatic Identification System (AIS) and terminal activities using 

a Geographic Information System (GIS). It provides live AIS/GIS views of waterways 

showing current vessel positions, terminals, created vessel fleets, and points-of-interest. 

Through this system, CGA has the ability to get instant snapshots of the location and 

status of all vessels contracted to CGA members, day or night, from any web-enabled PC.
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 

Equipment Deployment

Surveillance

• Provide trained observer to direct skimming operations

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

and visual confirmation 

• Continual monitoring of vessel assets 

Dispersant Use

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

water depth 

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

Dedicated Near Shore skimming systems

• FRVs 

• Egmopol and Marco SWS 

• Operate with aerial spotter directing systems to observed oil slicks

VOO

• Use FM O&G’s contracted resources as applicable

• Industry vessel are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS)

• Acquire additional resources as needed 

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

• Expect mission specific and safety training to be required

• Plan with the US Coast Guard for vessel inspections

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

Response Planning Considerations

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

• Time to acquire personnel and equipment and their availability

• Previous contingency planning contained in the appropriate ACP, and currently for 

Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep Water Horizon, 

dated 2 May 2010

Actions

Placement of boom

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

appropriate ACP 

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

impact. Consider:

o Trajectories

o Weather forecast

o Oil Impact forecast

o Verified spill movement

o Boom, manpower and vessel (shallow draft) availability

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

Beach Preparation

Considerations and Actions

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

• Shoreline Cleanup and Assessment Team Reports and recommendations

• Determination of Archeological sites and gaining authority to enter 

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

• Pre cleaning of beaches by moving waste above high time 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, complete, test, 

flare and install subsea 

wellhead

GC 393, 

Well Location B

96.5 miles from shore

G32500 C44 Matagorda, TX

Galveston, TX

Jefferson, TX

Cameron, LA

Vermilion, LA

Terrebonne, LA

Lafourche, LA

Jefferson, LA

Plaquemines, LA

1

2

1

5

2

2

1

1

4
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (96.5 miles from shore)

370,067 bbls of crude oil (Volume considering natural weathering)

API Gravity 25°

FIGURE 2 – Equipment Response Time to GC 393, Well Location B

Dispersants/Surveillance

Dispersant/Surveillance Dispersant 

Capacity (gal)

Persons 

Req. From Hrs to Procure

Hrs to 

Loadout Travel to site Total Hrs

ASI

Basler 67T 2000 2 Houma, LA 2 2 0.7 4.7

DC 3 1200 2 Houma, LA 2 2 0.9 4.9

DC 3 1200 2 Houma, LA 2 2 0.9 4.9

Aero Commander NA 2 Houma, LA 2 2 0.7 4.7

MSRC

C-130 Spray AC 3,250 2 Kiln, MS 3 0.2 0.6 3.8

King Air BE90 Spray AC 250 2 Kiln, MS 3 0.3 1 4.3

Offshore Response

Offshore Equipment 

Pre-Determined Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure

Hrs to 

Loadout Hrs to GOM Travel to Spill Site

Hrs to

Deploy

Total 

Hrs

CGA

95’ FRV 12342 249 NA 4 Venice, LA 2 0 2 3.6 0 7.6

95’ FRV 12342 249 NA 4 Leeville, LA 2 0 2 4 0 8

95’ FRV 12342 249 NA 4 Galveston, TX 2 0 1 12.6 0 15.6

HOSS Barge 43000 4000 3 Tugs 8 Harvey, LA 7 0 5 11.3 1 24.3

Boom Barge (CGA-300)

42” Auto Boom (25000’) NA NA 1 Tug50 Crew

4 (Barge)

2 (Per Crew) Leeville, LA 4 0 6 14.3 1.5 25.8
Recovered Oil Storage PreDetermined Staging EDRC Storage 

Capacity VOO Persons Required From Hrs to Procure

Hrs to 

Loadout

Hrs to 

GOM

Travel to 

Spill Site

Hrs to 

Deploy

Total 

Hrs

Kirby Offshore (available through contract with CGA)

RO Barge NA 80000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 80000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 80000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 80000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 100000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 100000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 100000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 100000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 110000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 130000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 140000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 150000+ 1 Tug 6 Venice 46 0 2 12 0 60

RO Barge NA 150000+ 1 Tug 6 Venice 46 0 2 12 0 60
Offshore Equipment 

Pre-determined Staging EDRC Storage Capacity VOO Persons Req From Hrs to Procure

Hrs to 

Loadout

Hrs to 

GOM

Travel to 

Spill Site

Hrs to 

Deploy

Total 

Hrs

NRCC

OSRV Energy

Vikoma Sea 50 1509 300 NA

4-6 Grand Isle, LA221 111 17

OSRV Admiral

Marco Class XI AB

8 Band Rope Mop

24000

2283

300 NA4-6 Galveston, TX221 321 38

OSRB Defender

Marco Class XI AB

Vikoma Cascade

24000

5520

16500 2 Tugs4-6 Bayou La Batre, AL423 291 39

OSRB Valiant

Marco Class XI AB 24000 20892 2 Tugs

4-6 Aransas Pass, TX423 611 71

OSRB Valor N/A 19000 2 Tugs4-6 Tampa, FL427 631 77
Offshore Equipment 

Pre-determined Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure

Hrs to 

Loadout

Hrs to 

GOM

Travel to 

Spill Site

Hrs to 

Deploy

Total 

Hrs

MSRC

Louisiana Responder 

Transrec 350 + OSRV

2,640’ 67” Curtain Pressure Boom

10567 4000 NA 14 Fort Jackson, LA20 4.5 7.21 14.7

MSRC 452 Offshore Barge

1 Crucial Disk 88/30

1 Desmi Ocean

2,640‘ 67” Curtain Pressure Boom

11122

3017 45000 3 Tugs

6 Fort Jackson, LA 2.506 14.21 23.7

Mississippi Responder 

Transrec 350 + OSRV

2,640’ 67” Curtain Pressure Boom

10567 4000 NA 14 Pascagoula, MS202 15.21 20.2

MSRC 402 Offshore Barge

2 Crucial Disk 88/30

2,640‘ 67” Curtain Pressure Boom

22244 40300 3 Tugs6 Pascagoula, MS 2.503 301 36.5

Deep Blue Responder 

LFF 100 Brush + OSRV

2,640’ 67” Curtain Pressure Boom

18086 4000 NA 14 Fourchon, LA201 7.21 11.2

Gulf Coast Responder 

Transrec 350 + OSRV

2,640’ 67” Curtain Pressure Boom

10567 4000 NA 14 Lake Charles, LA204 18.51 25.5

Texas Responder 

Transrec 350 + OSRV

2,640’ 67” Curtain Pressure Boom

10567 4000 NA 14 Galveston, TX201 22.91 26.9

MSRC 570 Offshore Barge

2 Crucial Disk 88/30

2,640’ 67” Curtain Pressure Boom

22244 56900 3 Tugs6 Galveston, TX 2.502 451 50.5

Southern Responder 

Transrec 350 + OSRV

2,640’ 67” Curtain Pressure Boom

10567 4000 NA 14 Ingleside, TX201 31.51 35.5

MSRC 403 Offshore Barge

1 Crucial Disk 88/30

2,640’ 67” Curtain Pressure Boom

11122 40300 3 Tugs6 Ingleside, TX 2.502 62.11 67.6
Staging Area: Venice

Offshore Equipment 

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

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Site

Hrs to 

Deploy

Total 

Hrs

T&T Marine (available through direct contract with CGA)

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston, TX 4 12 13 7.5 2 38.5

Koseq Skimming Arms (6) 106974 12000 6 Utility 36 Galveston, TX 24 24 13 7.5 2 70.5

Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Galliano, LA 24 24 1 7.5 2 58.5

Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey, LA 24 24 2 7.5 2 59.5

CGA

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City, LA 2 2 5 7.5 1 17.5

FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey, LA 2 2 2 7.5 1 14.5

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston, TX 2 2 13 7.5 1 25.5

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass, TX 2 2 18 7.5 1 30.5

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles, LA 2 2 8 7.5 1 20.5

FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Leeville, LA 2 2 5 7.5 1 17.5

FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice, LA 2 2 0 7.5 1 12.5

Offshore Equipment Preferred 

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

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Site

Hrs to 

Deploy

Total 

Hrs

MSRC

WP 1 Skimmer (1) 3017 400 1 

ili

6 Ingleside, TX 1 2 18 7.5 1 29.5

Stress I Skimmer (1) 15840 400 1 

ili

6 Ingleside, TX 1 2 18 7.5 1 29.5

GT-185 Skimmer w Adaptor (1) 1371 400 1 

ili

6 Ingleside, TX 1 2 18 7.5 1 29.5

Foilex 250 Skimmer (1) 3977 400 1 

ili

6 Ingleside, TX 1 2 18 7.5 1 29.5

Crucial Disk 56/30 Skimmer (1) 5671 400 1 

ili

6 Ingleside, TX 1 2 18 7.5 1 29.5

GT-185 Skimmer w Adaptor (2) 2742 400 2 

ili

12 Galveston, TX 1 2 13 7.5 1 24.5

Walosep 4 Skimmer (1) 3017 400 1 

ili

6 Galveston, TX 1 2 13 7.5 1 24.5

Queensboro Skimmer (1) 905 400 1 

ili

6 Galveston, TX 1 2 13 7.5 1 24.5

Foilex 250 Skimmer (1) 3977 400 1 

ili

6 Galveston, TX 1 2 13 7.5 1 24.5

Stress I Skimmer (1) 15840 400 1 

ili

6 Galveston, TX 1 2 13 7.5 1 24.5

GT-185 Skimmer w Adaptor (1) 1371 400 1 

ili

6 Port Arthur, TX 1 2 10 7.5 1 21.5

Queensboro Skimmer (5) 4525 400 5 

ili

30 Lake Charles, LA 1 2 8 7.5 1 19.5

Desmi Skimmer (1) 3017 400 1 

ili

6 Lake Charles, LA 1 2 8 7.5 1 19.5

Foilex 250 Skimmer (1) 3977 400 1 

ili

6 Lake Charles, LA 1 2 8 7.5 1 19.5
Offshore Equipment Preferred 

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

Hrs to LoadoutTravel to 

Staging

Travel to 

Site

Hrs to 

Deploy

Total 

Hrs

MSRC

Stress I Skimmer (1) 15840 400 1 

ili

6 Lake Charles, LA128 7.51 19.5

GT-185 Skimmer w Adaptor (1) 1371 400 1 

ili

6 Lake Charles, LA128 7.51 19.5

AardVac Skimmer (1) 3840 400 1 

ili

6 Lake Charles, LA128 7.51 19.5

Transrec 350 Skimmer (1) 10567 400 1 

ili

6 Lake Charles, LA128 7.51 19.5

Crucial Disk 88/30 Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 11122 400 1 PSV 14 Lake Charles, LA

128 7.51 19.5

Crucial Disk 88/30 Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 11122 400 1 PSV 14 Lake Charles, LA

128 7.51 19.5

Transrec 350 Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 11122 400 1 PSV 14 Lake Charles, LA

128 7.51 19.5

GT-185 Skimmer w Adaptor (1) 1371 400 1 

ili

6 Baton Rouge, LA125 7.51 16.5

Transrec 350 Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 10567 400 1 PSV 14 Houma, LA

124 7.51 15.5

Stress I Skimmer (1) 15840 400 1 

ili

6 Port Fourchon, LA125 7.51 16.5

LFF 100 Brush Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 18086 400 1 PSV 14 Port Fourchon, LA

125 7.51 16.5

LFF 100 Brush Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 18086 400 1 PSV 14 Port Fourchon, LA

125 7.51 16.5

LFF 100 Brush Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 18086 400 1 PSV 14 Port Fourchon, LA

125 7.51 16.5

LFF 100 Brush Skimmer (1)

1,320‘ 67” Curtain Pressure Boom 18086 400 1 PSV 14 Port Fourchon, LA

125 7.51 16.5

GT-185 Skimmer w Adaptor (1) 1371 400 1 

ili

6 Belle Chasse, LA122 7.51 13.5

Walosep W4 Skimmer (1) 3017 400 1 

ili

6 Belle Chasse, LA122 7.51 13.5

Foilex 250 Skimmer (1) 3977 400 1 

ili

6 Belle Chasse, LA122 7.51 13.5

Stress I Skimmer (1) 15840 400 1 

ili

6 Belle Chasse, LA122 7.51 13.5

Queensboro Skimmer (1) 905 400 1 

ili

6 Belle Chasse, LA122 7.51 13.5

Foilex 200 Skimmer (1) 1989 400 1 

ili

6 Belle Chasse, LA122 7.51 13.5

Crucial Disk 56/30 Skimmer (1) 5671 400 1 

ili

6 Belle Chasse, LA122 7.51 13.5

Stress I Skimmer (1) 15840 400 1 

ili

6 Pascagoula, MS126 7.51 17.5

GT-185 Skimmer (1) 1371 400 1 

ili

6 Pascagoula, MS126 7.51 17.5
Offshore Equipment Preferred 

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

Hrs to 

Loadout

Travel to StagingTravel to 

Site

Hrs to 

Deploy

Total 

Hrs

MSRC

AardVac Skimmer (1) 3840 400 1 

ili

6 Pascagoula, MS126 7.51 17.5

WP 1 Skimmer (1) 3017 400 1 

ili

6 Pascagoula, MS126 7.51 17.5

Queensboro Skimmer (1) 905 400 1 

ili

6 Pascagoula, MS126 7.51 17.5

Stress II Skimmer (1) 3017 400 1 

ili

6 Pascagoula, MS126 7.51 17.5

Stress I Skimmer (1) 15840 400 1 

ili

6 Tampa, FL12 21 7.51 32.5

GT-185 Skimmer w Adaptor (1) 1371 400 1 

ili

6 Tampa, FL12 21 7.51 32.5

WP 1 Skimmer (1) 3017 400 1 

U ili

6 Tampa, FL12 21 7.51 32.5

Crucial Disk 56/30 Skimmer (1) 5671 400 1 

ili

6 Tampa, FL12 21 7.51 32.5

GT-185 Skimmer w Adaptor (1) 1371 400 1 

ili

6 Miami, FL12 27 7.51 38.5

Stress I Skimmer (1) 15840 400 1 

ili

6 Miami, FL12 27 7.51 38.5

Walosep W4 Skimmer (1) 3017 400 1 

U ili

6 Miami, FL12 27 7.51 38.5

AardVac Skimmer (2) 7680 400 2 

ili

12 Miami, FL12 27 7.51 38.5

WP 1 Skimmer (1) 3017 400 1 

ili

6 Miami, FL12 27 7.51 38.5

Desmi Skimmer (1) 3017 400 1 

ili

6 Miami, FL12 27 7.51 38.5
Offshore Equipment Preferred 

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

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Site

Hrs to 

Deploy

Total 

Hrs

NRCC

Marco Class XI AB 24000 100 1 Offshore 

Vessel

4-8 Ft. Lauderdale, FL44 26 17.21 52.2

Marco Class XI AB 24000 100 1 Offshore 

Vessel

4-8 Belle Chasse, LA442 17.21 28.2

Marco Class XI AB 24000 100 1 Offshore 

Vessel

4-8 New Iberia, LA446 17.21 32.2

Action 48 Skimmer 2414 100 1 Offshore 

Vessel

4-8 Key West, FL44 31 17.21 57.2

Hoyle Disc Skimmer 1632 100 1 Offshore 

Vessel

4-8 Tampa, FL44 21 17.21 47.2

4-Band Rope Mop Skimmer 1509 100 1 Offshore 

Vessel

4-8 Ft. Lauderdale, FL44 26 17.21 52.2

4-Band Rope Mop Skimmer 1509 100 1 Offshore 

Vessel

4-8 Mobile, AL447 17.21 33.2

4-Band Rope Mop Skimmer (2) 3018 200 1 Offshore 

Vessel

8-16 New Iberia, LA446 17.21 32.2

4-Band Rope Mop Skimmer (2) 3018 200 1 Offshore 

Vessel

8-16 Corpus Christi, TX44 18 17.21 44.2

Vikoma Cascade Skimmer 5520 100 1 Offshore 

Vessel

4-8 Baytown, TX44 12 17.21 38.2

Vikoma Cascade Skimmer 5520 100 1 Offshore 

Vessel

4-8 Sulphur, LA449 17.21 35.2

VTU w/weir head skimmer 6857 24 1 Offshore 

Vessel

4-8 Port Arthur, TX44 10 17.21 36.2

VTU w/weir head skimmer 6857 24 1 Offshore 

Vessel

4-8 La Porte, TX44 12 17.21 38.2
Offshore Equipment Preferred 

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

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Site

Hrs to 

Deploy

Total 

Hrs

CGA

1000’ Hydro-Fire Boom NA NA 8 Utility 40 Harvey, LA 1 4 2.1 7.5 6 20.6

MSRC

67” Curtain Pressure Boom (18480’) NA NA 14* 7 Lake Charles 1 2 8 7.1 1 19.1

67” Curtain Pressure Boom (8895’) NA NA 12* 6 Pascagoula 1 2 5.5 7.1 1 16.6

2000’ Hydro Fire Boom NA NA 8* 8 Lake Charles 1 4 8 7.1 6 19.1

NRCC

42” Boom (1000’) NA NA 1 Offshore 

Vessel 4-8 Bayou La Batre, AL 4 4 6 7.5 1 22.5

42” Boom (3300’) NA NA 2 Offshore 

Vessels 8-16 Tampa, FL 4 4 21 7.5 1 37.5

42” Boom (2000’) NA NA 1 Offshore 

Vessel 4-8 Baytown, TX 4 4 12 7.5 1 28.5

42” Boom (1000’) NA NA 1 Offshore 

Vessel 4-8 Port Arthur, TX 4 4 10 7.5 1 26.5

42” Boom (4000’) NA NA 2 Offshore 

Vessels 8-16 Corpus Christi, TX 4 4 18 7.5 1 34.5

1000’ Hydro-Fire Boom NA NA 6 Utility 20 New Iberia, LA 4 4 6 7.5 1 22.5

* Utility Boats, Crew Boats, Supply Boats, or Fishing Vessels
Nearshore Response

Nearshore Equipment 

Pre-determined Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure

Hrs to 

Loadout

Hrs to 

GOM

Travel to 

Spill Site

Hrs to 

Deploy

Total 

Hrs

CGA

Trinity SWS 21500 249 NA 4 Galveston 1 2 2 3.6 1 9.6

Trinity SWS 21500 249 NA 4 Morgan City 1 2 2 4.4 1 10.4

Trinity SWS 21500 249 NA 4 Leeville 1 2 2 7.2 1 13.2

Trinity SWS 21500 249 NA 4 Venice 1 2 2 9.2 1 15.2

46’ FRV 5000 65 NA 4 Aransas Pass 1 0 2 10.4 0 13.4

46’ FRV 5000 65 NA 4 Morgan City 1 0 2 4.4 0 7.4

46’ FRV 5000 65 NA 4 Lake Charles 1 0 1 2 0 4

46’ FRV 5000 65 NA 4 Venice 1 0 1 9.2 0 11.2

Enterprise Marine Services LLC (Available through contract with CGA)

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75
Staging Area: Cameron

Nearshore Equipment With Staging EDRC Storage 

Capacity VOO Persons Req. From Hrs to Procure

Hrs to 

Load Out

Travel to 

Staging

Travel to 

Deployment

Hrs to 

Deploy

Total 

Hrs

CGA

SWS Egmopol 3000 100 NA 3 Galveston 1 2 4 2 0 9

SWS Egmopol 3000 100 NA 3 Morgan City 1 2 5.3 2 0 10.3

SWS Marco 3588 20 NA 3 Lake Charles 1 2 1.5 2 0 6.5

SWS Marco 3588 34 NA 3 Leeville 1 2 6.8 2 0 11.8

SWS Marco 3588 34 NA 3 Venice 1 2 9.2 2 0 14.2

Rope Mop 77 2 0 3 Harvey 1 2 7 2 0 12

Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 1 2 1.5 2 0 6.5

Foilex Skim Package (TDS 150) 891 45 NA 3 Galveston 1 2 4 2 0 9

Foilex Skim Package (TDS 150) 891 45 NA 3 Harvey 1 2 7 2 0 12

4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 1 2 1.5 2 0 6.5

4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 1 2 7 2 0 12

2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Lake Charles 1 2 1.5 2 0 6.5

2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Harvey 1 2 7 2 0 12
Nearshore Equipment With 

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

Hrs to 

Load Out

Travel to 

Staging

Travel to 

Deployment

Hrs to 

Deploy

Total 

Hrs

NRCC

Action 24 Skimmer 823 24 1 Nearshore 

Vessel

4-8 Baytown, TX44321 14

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 Tampa, FL44 2521 36

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 Ft. Lauderdale, FL44 3121 42

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 New Iberia, LA44321 14

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 Corpus Christi, TX44 1321 24

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 La Porte, TX44721 18

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 Port Arthur, TX44221 13

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 Cocoa, FL44 4121 52

NRC Weir Disk Skimmer 1371 24 1 Nearshore 

Vessel

4-8 Pensacola, FL44 1221 23

Vikoma Fasflo Skimmer 2112 24 1 Nearshore 

Vessel

4-8 Belle Chasse, LA44721 18

Vikoma Fasflo Skimmer 2112 24 1 Nearshore 

Vessel

4-8 New Iberia, LA44321 14

Vikoma Fasflo Skimmer 2112 24 1 Nearshore 

Vessel

4-8 Sulphur, LA44221 13

Vikoma Fasflo Skimmer 2112 24 1 Nearshore 

Vessel

4-8 Atlantic Beach, FL44 2221 33
Shoreline Protection

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

Hrs to 

Deploy Total Hrs

OMI Environmental (Available through MSA)

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 3 11

10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 3.8 2 3 10.7

10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 1.4 2 3 8.4

Wildlife Response EDRC Storage 

Capacity VOO Persons Req. From Hrs to Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Deployment

Hrs to 

Deploy Total Hrs

CGA

Wildlife Support Trailer NA NA NA 2 Harvey 2 2 7.5 1 2 14.5

Bird Scare Guns (48) NA NA NA 2 Harvey 2 2 7.5 1 2 14.5

Bird Scare Guns (12) NA NA NA 2 Galveston 2 2 5 1 2 12

Bird Scare Guns (12) NA NA NA 2 Aransas Pass 2 2 9.5 1 2 16.5

Bird Scare Guns (24) NA NA NA 2 Lake Charles 2 2 1.5 1 2 8.5

Bird Scare Guns (24) NA NA NA 2 Leeville 2 2 8 1 2 15

Response Asset Total

Offshore EDRC 1,046,754

Offshore Recovered Oil Capacity 1,717,687+

Nearshore / Shallow Water EDRC 147,605

Nearshore / Shallow Water Recovered Oil Capacity 203,393
Freeport-McMoRan Oil & Gas LLC Section 9 – Pg. 17 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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-N01, “Elimination of Expiration Dates 

on Certain Notices to Lessees and Operators Pending Review and Reissuance”).

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 Block 393 is 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. 18 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

SECTION 10

LEASE STIPULATIONS INFORMATION

Exploration activities are subject to the following stipulations attached to Lease OCS-G 32500,

Green Canyon Block 393. 

10.1 MILITARY WARNING AREA (MWA)

Green Canyon Block 393 is not located in a MWA; however, vessels and helicopters associated 

with exploration activities may traverse MW-92. The Airspace Officer, Fleet Area Control 

Surveillance Facility, Jacksonville, Florida was contacted March 3, 2014 in order to coordinate 

and control the electromagnetic emissions and 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. 
Freeport-McMoRan Oil & Gas LLC Section 10 – Pg. 19 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

BOEM and BSEE issue Notices to Lessees (NTLs), which more fully describe measures 

implemented in support of the above-mentioned implementing statutes and regulations, as well 

as measures identified by the U.S. Fish and Wildlife Service and NMFS arising from, among 

others, conservation recommendations, rulemakings pursuant to the MMPA, or consultation. 

The lessee and its operators, personnel, and subcontractors, while undertaking activities 

authorized under this lease, must implement and comply with the specific mitigation measures 

outlined in NTL No. 2012-JOINT-G01, “Vessel Strike Avoidance and Injured/Dead Protected 

Species Reporting;” NTL No. 2012-JOINT-G02, “Implementation of Seismic Survey Mitigation 

Measures and Protected Species Observer Program;” and NTL No. 2012-BSEE-G01, “Marine 

Trash and Debris Awareness and Elimination.” At the lessee’s option, the lessee, its operators, 

personnel, and contractors may comply with the most current measures to protect species in 

place at the time an activity is undertaken under this lease, including but not limited to new or 

updated versions of the NTLs identified in this paragraph. The lessee and its operators, 

personnel, and subcontractors will be required to comply with the mitigation measures, identified 

in the above referenced NTLs, and additional measures in the conditions of approvals for their 

plans or permits.
Freeport-McMoRan Oil & Gas LLC Section 11 – Pg. 20 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

SECTION 11

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

11.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS

Green Canyon Block 393 is 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. 21 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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 500 bbl 1 3/week

Supply boat 500 bbl 2 3/week

Helicopter 560 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

265’ 9,000 bbl Bi-weekly Shortest route from 

Shorebase to block

312’ 5,800 bbl 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 well is included as Attachment 12-B.
Recycled or 

Inceretated

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

N/A

N/A

N/A

Cuttings wetted with oil-based fluids

Wll 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

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 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 130,000 LB/WELL

Recycled if possible, 

transported to 

landfill otherwise

Used Engine Oil Proper DOT containers on supply boat Univar

Carencro, LA 215 BBL/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

Synthetic-based drilling fluid

Cuttings wetted with Water-based fluid

Recycled

N/A

N/A

SBM Tanks in Support Vessel Newpark Enviromental Services Fourchon, 

LA 1,500 BBL/WELL

TABLE 2. 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

Freeport-McMoRan Oil & Gas LLC Section 13 – Pg. 22 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

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 is provided in the table below.

Name Location Existing/New/Modified

Freeport-McMoRan Oil & 

Gas LLC Shorebase

Fourchon, Louisiana Existing

MI Drilling Fluids Fourchon, Louisiana Existing

13.2 SUPPORT BASE CONSTRUCTION OR EXPANSION

There will be no new construction of an onshore support base, nor will FM O&G expand the 

existing shorebase as a result of the operations proposed in this EP.

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE

A support base construction or expansion timetable is not required for the activities proposed in 

this plan. 

13.4 WASTE DISPOSAL

The Table, “Wastes You Will Transport and/or Dispose of Onshore, “is included as Attachment 

12-A.
Freeport-McMoRan Oil & Gas LLC Section 14– Pg. 23 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

SECTION 14

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION

Coastal Zone Management certification is not required for activities proposed in this plan. 
Freeport-McMoRan Oil & Gas LLC Section 15– Pg. 24 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

SECTION 15

ENVIRONMENTAL IMPACT ANALYSIS 

The Environmental Impact Analysis is included as Attachment 15-A.
Freeport-McMoRan Oil & Gas LLC (FM O&G)

Supplemental Exploration Plan

Green Canyon Block 393

OCS-G 32500

(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 Block 393

Proposed operations consist of the drilling, completion, testing, flaring, and installation of a 

subsea wellhead for Well Location F.

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 Block 393 is 58 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 Section 8).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities, which could impact topographic features.

2. Pinnacle Trend Area Live Bottoms

Potential IPFs on pinnacle trend area live bottoms include effluents and accidents. 

Effluents: Green Canyon Block 393 is 144 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 Section 8).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities which could impact a live bottom 

(pinnacle trend) area. 

3. Eastern Gulf Live Bottoms

Potential IPFs on Eastern Gulf live bottoms include effluents and accidents.

Effluents: Green Canyon Block 393 is not located in an area characterized by the existence of

live bottoms; therefore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to live 

bottom organisms only if the oil contacts the organisms. Oil from a surface spill can be driven 

into the water column; measurable amounts have been documented down to a 10 m depth. At

this depth, the oil is found only at concentrations several orders of magnitude lower than the 

amount shown to have an effect on marine invertebrates. Oil from a subsurface spill is not 

applicable due to the distance of these blocks from a live bottom area. The activities proposed in 

this plan will be covered by FM O&G’s Regional OSRP (refer to information submitted in 

Section 8).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities which could impact an Eastern Gulf live 

bottom area. 

4. Benthic Communities 

There are no IPFs (including emissions, physical disturbances to the seafloor, wastes sent to 

shore for disposal, or accidents) from the proposed activities that could cause impacts to benthic 

communities.

A 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 Block 393 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 Block 393 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 

Section 8).

There are no other IPFs (including emissions, physical disturbances to the seafloor, and wastes 

sent to shore for disposal) from the proposed activities which could cause impacts to water 

quality.

6. Fisheries

IPFs that could cause impacts to fisheries as a result of the proposed operations in Green Canyon 

Block 393 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 Section 8). 
There are no IPFs from emissions, physical disturbances to the seafloor or wastes sent to shore 

for disposal from the proposed activities which could cause impacts to fisheries.

7. Marine Mammals

GulfCet II studies revealed that cetaceans of the continental shelf and shelf-edge were almost 

exclusively bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and 

pygmy killer whale, Risso’s dolphin, rough-toothed dolphin, and Cuvier’s beaked whale, 

occurred most frequently along the upper slope in areas outside of anticyclones. IPFs that could 

cause impacts to marine mammals as a result of the proposed operations in Green Canyon Block 

393 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 Section 8).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed 

activities which could impact marine mammals.

8. Sea Turtles

IPFs that could cause impacts to sea turtles as a result of the proposed operations include 

emissions, effluents, discarded trash and debris, and accidents. GulfCet II studies sighted most 

loggerhead, Kemp’s ridley and leatherback sea turtles over shelf waters. Historically these 

species have been sighted up to the shelf’s edge. They appear to be more abundant east of the 

Mississippi River than they are west of the river (Fritts et al., 1983b; Lohoefener et al., 1990).

Deep waters may be used by all species as a transitory habitat.

Emissions: Noise from drilling activities, support vessels, and helicopters may elicit a startle 

reaction from sea turtles, but this is a temporary disturbance.
Effluents: Drilling fluids and cuttings discharges are not known to be lethal to sea turtles. Most 

operational discharges are diluted and dispersed upon release. Any potential impact from 

drilling fluids would be indirect, either as a result of impacts on prey items or possibly through 

ingestion in the food chain (API, 1989).

Discarded trash and debris: Both entanglement in, and ingestion of, debris have caused the 

death or serious injury of sea turtles (Balazs, 1985). The limited amount of marine debris, if any, 

resulting from the proposed activities is not expected to substantially harm sea turtles. Operators 

are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the 

Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies 

including the United States Coast Guard (USCG) and the Environmental Protection Agency 

(EPA). 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 Section 8).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed 

activities which could impact sea turtles.

9. Air Quality

The projected air emissions identified in Section 7 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 Block 393 is beyond the 200

kilometer (124 mile) buffer for the Breton Wilderness Area and is 97.2 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 Block 393 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 Block 393 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 Block 393 would not 

cause impacts to shipwreck sites.

Additionally, Green Canyon Block 393 is not located in or adjacent to an OCS block designated 

by BOEM as having a high probability for occurrence of shipwrecks, therefore, no adverse 

impacts are expected.

According to BOEM’s Grid EA and ROV Survey Status Report, Green Canyon Block 393, 

which is located in Grid 13, has adequate ROV coverage and a complete EA. Additional surveys 

are not planned unless requested (per NTL 2008-G04). 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

IPFs that could cause impacts to prehistoric archaeological sites as a result of the proposed 

operations in Green Canyon Block 393 are physical disturbances to the seafloor and accidents

(oil spills). 

Physical Disturbances to the seafloor: Although the operations proposed will be conducted by 

utilizing a dynamically positioned drillship, which would cause only an insignificant amount of 

seafloor to be disturbed, Green Canyon Block 393 is located inside the Archaeological 

Prehistoric high probability lines. FM O&G will report to BOEM the discovery of any object of 

prehistoric archaeological significance and make every reasonable effort to preserve and protect 

that cultural resource.

According to BOEM’s Grid EA and ROV Survey Status Report, Green Canyon Block 393,

which is located in Grid 13, has adequate ROV coverage and a complete EA. Additional surveys 

are not planned unless requested (per NTL 2008-G04). 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.

Accidents: An accidental oil spill has the potential to cause some detrimental effects to 

prehistoric archaeological sites if the release were to occur subsea. However, it is unlikely that 

an accidental oil spill would occur from the proposed activities (refer to Item 5, Water Quality). 

The activities proposed in this plan will be covered by FM O&G’s Regional Oil Spill Response 

Plan (refer to information submitted in accordance with Section 8).

There are no other IPFs (including emissions, effluents or wastes sent to shore for treatment or 

disposal) from the proposed activities which could impact prehistoric archeological sites.

Vicinity of Offshore Location

1. Essential Fish Habitat (EFH)

IPFs that could cause impacts to EFH as a result of the proposed operations in Green Canyon 

Block 393 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 Section 8).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for treatment or disposal) from the proposed activities which could impact essential 

fish habitat.

2. Marine and Pelagic Birds 

IPFs that could impact marine birds as a result of the proposed activities include air emissions, 

accidental oil spills, and discarded trash and debris from vessels and the facilities.

Emissions: Emissions of pollutants into the atmosphere from these activities are far below 

concentrations which could harm coastal and marine birds.

Accidents: An oil spill would cause localized, low-level petroleum hydrocarbon contamination. 

However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, 

Water Quality). Marine and pelagic birds feeding at the spill location may experience chronic, 

nonfatal, physiological stress. It is expected that few, if any, coastal and marine birds would 

actually be affected to that extent. The activities proposed in this plan will be covered by FM 

O&G’s Regional OSRP (refer to information submitted in Section 8).

Discarded trash and debris: Marine and pelagic birds could become entangled and snared in

discarded trash and debris, or ingest small plastic debris, which can cause permanent injuries and 

death. Operators are prohibited from deliberately discharging debris as mandated by MARPOLAnnex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by 

various agencies including the United States Coast Guard (USCG) and the Environmental 

Protection Agency (EPA). 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 Section 4

to justify our request that our proposed activities be classified by BSEE as H2S absent. 

Coastal and Onshore

1. Beaches

IPFs from the proposed activities that could cause impacts to beaches include accidents (oil 

spills) and discarded trash and debris. 

Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches 

and associated resources. Due to the distance from shore (97.2 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 Section 8).

Discarded trash and debris: Trash on the beach is recognized as a major threat to the 

enjoyment and use of beaches. There will only be a limited amount of marine debris, if any, 

resulting from the proposed activities. Operators are prohibited from deliberately discharging 

debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and 

Control Act, and regulations imposed by various agencies including the United States Coast 

Guard (USCG) and the Environmental Protection Agency (EPA). 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 (97.2 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 Section 8). 

Discarded trash and debris: There will only be a limited amount of marine debris, if any, 

resulting from the proposed activities. Operators are prohibited from deliberately discharging 

debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and 

Control Act, and regulations imposed by various agencies including the United States Coast 

Guard (USCG) and the Environmental Protection Agency (EPA). 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 (97.2 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 Section 8). 

Discarded trash and debris: Coastal and marine birds are highly susceptible to entanglement

in floating, submerged, and beached marine debris: specifically plastics. Operators are prohibited 

from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic 

Pollution Research and Control Act, and regulations imposed by various agencies including the 

United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). 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 (97.2 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 Section 

8).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and 

the Environmental Protection Agency (EPA). 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 (136

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 Section 8).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and 
the Environmental Protection Agency (EPA). 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 its location in the gulf, Green Canyon Block 393 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. 25 of 25

Supplemental EP January, 2015

Green Canyon Block 393 (OCS-G 32500)

SECTION 16

ADMINISTRATIVE INFORMATION

16.1 EXEMPTED INFORMATION DESCRIPTION

The proposed bottomhole location of the planned well has 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. Fugro Geoservices, Inc. Shallow Hazards and Archaeological Assessment Giverny 

Prospect Block 353 and Vicinity Atwater Valley Area Gulf of Mexico Report No. 2414-

5050. 

2. Fugro Geoservices, Inc. Shallow Hazards Survey and Archaeological Assessment 

Giverny Prospect Blocks 349 & 393 Green Canyon Area Gulf of Mexico Report No. 

2412-5023.

3. Initial Exploration Plan (Control Number N-9739).