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-07707

Type - Supplemental Exploration Plan

Lease(s) - OCS-G06894 Block - 915 Viosca Knoll Area

Operator - Freeport-McMoRan Oil & Gas LLC

Wells G & F

Drillship

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.

Ronald O'Connor
Plan Coordinator Description -

Rig Type - Subject: From: November 25, 2014Record of Changes-PUBLIC COPY S-7707, Exploration Plan, Freeport-McMoRan Oil Gas LLC, (OCS-G 06894, Viosca Knoll Block 915)

Date Section Page Remarks 9/19/2014 All All Plan received by BOEM 10/8/2014 10 p. 2 0 Section 10.3 Cultural Resources added. 11/3/2014 All All Final Copy to BOEM.

### PUBLIC COPY September 18, 2014 Final Copy November 3, 2014



## SUPPLEMENTAL UNIT

EXPLORATION PLAN

Viosca Knoll Block 915 OCS

- G 06894 Viosca Knoll Block 915 Unit & Unit Agreement # 754396011 Dorado Prospect Affected State: Alabama and Louisiana

Estimated Startup Date: February 21, 2016

SUBMITTED BY : Freeport

- McMoRan Oil & Gas LLC 400 E. Kaliste Saloom, Suite 1100 Lafayette, Louisiana 70508

Paul Landry Office: (337) 354

- 5065 Mobile: (337) 349

- 7781 paul_landry@fmi.com

AUTHORIZED REPRES ENTATIVE: 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 SPIL L FINANCIAL RESPONSIBILITY (OSFR)

............................................... 3

2.6 DEEPWATER WELL CONTROL STATEMENT

.................................................... 4

2.7 BLOWOUT SCENARIO AND WORST CASE DISCHARGE CALCULATIONS

..... 4

SECTION 3 GEOLOGICAL AND GEOPHYSICAL INFORMATION

............................. 8

3.1 GEOLOGICAL DESCRIPTION

.............................................................................. 8

3.2 STRUCTURE CONTOUR MAP

............................................................................. 8

3.3 INTERPRETED SEISMIC LINES

........................................................................... 8

3.4 GEOLOGICAL STRUCTURE CROSS

- SECTIONS

............................................... 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

### TOC Pg 2 of 3 4.1 CONCENTRATION

................................................................................................ 9

4.2 CLASSIFICATION

................................................................................................ . 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)

......................................................................... 11

5. 6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP

.............................. 11

5.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS

....................................... 11

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND
MARINE MAMMAL INFORMATION

.................................................................... 11

5.9 ARCHAEOLOGICAL REPORT

............................................................................ 13

5.10 AIR AND WATER QUALITY INFORMATION

.................................................... 13

5.11 SOCIOECONOMIC INFORMATION

.................................................................. 13

SECTION 6 WASTES AND DISCHARGES INFORMATION

...................................... 14

6.1 PROJECTED GENERATED WASTES

................................................................ 14

6.2 MODELING REPORT

.......................................................................................... 14

SECTION 7 A IR EMISSIONS INFORMATION

............................................................ 15

7.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS

.......................... 15

7.2 SUMMARY INFORMATION

................................................................................. 15

SECTION 8 OIL SPILL INFORMATION

................................ ...................................... 16

8.1 OIL SPILL RESPONSE PLANNING

.................................................................... 16

8.2 SPILL RESPONSE SITES

................................................................................... 16

8.3 OSRO INFORMATION

........................................................................................ 16

8.4 WORST CASE SCENARIO DETERMINATION

................................................... 17

8.5 OIL SPILL RESPONSE DISCUSSION

................................................................ 17

SECTION 9 ENVIRONMENTAL MONITORING INFORMATION

................................ 18

9.1 MONITORING SYSTEMS

.................................................................................... 18

9.2 INCIDENTAL TAKES

........................................................................................... 18

9.3 FLOWER G ARDEN BANKS NATIONAL MARINE SANCTUARY

....................... 18

### TOC Pg 3 of 3 SECTION 10 LEASE STIPULATIONS INFORMATION

.............................................. 19

10.1 MILITARY WARNING AREA (MWA)

................................................................ . 19

10.2 MARINE PROTECTED SPECIES

..................................................................... 19

SE CTION 11 ENVIRONMENTAL MITIGATION MEASURES INFORMATION

........... 21

11.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS

.......... 21

11.2 INCIDENTAL TAKES

......................................................................................... 21

SECTION 12 SUPPORT VESSELS AND AIRCRAFT INFORMATION

...................... 22

12.1 GENERAL

.......................................................................................................... 22

12.2 DIESEL OIL SUPPLY VESSELS

....................................................................... 22

12.3 DRILLING FLUID TRANSPORTATION

............................................................. 22

12.4 SOLID AND LIQUID WASTE TRANSPORTATION

........................................... 22

12.5 VICINITY MAP

................................................................................................... 22

SECTION 13 ONSHORE SUPPORT FACILITIES INFORMATION

............................ 23

13.1 GENERAL

.......................................................................................................... 23

13.2 SUPPORT BASE CONSTRUCTION OR EXPANSION

..................................... 23

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE

................ 23

13.4 WASTE DISPOSAL

........................................................................................... 23

SECTION 14 COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION

........ 24

SECTION 15 ENVIRONMENTAL IMPACT ANALYSIS

.............................................. 26

SECTION 16 ADMINISTRATIVE INFORMATION

....................................................... 27

16.1 EXEMPTED INFORMATION DESCRIPTION

.................................................... 27

16.2 BIBLIOGRAPHY

................................................................................................ 27

### Attachments Pg 1 of 1 SECTION ATTACHMENTS

Section 1 Plan Contents
1

- A OCS Plan Information Form
1

- B Well Location Plat
1

- C Bathymetry Map

1

- D Pay.gov Receipt Section 3 Geological, Geophysical Information
3

- A Structure Contour Maps
3

- B Interpreted Seismic Lines
3

- C Geological Structure Cross Sections
3

- D Shallow Hazard Assessment and High

- Resolution Seismic Lines
3

- E Stratigraphic Column Section 5 Biological, Physical and Socioeconomic Information
5

- A Biologically Sensitive Underwater Features and Areas Map Section 6 Wastes and Discharges Information
6

- A Wastes You Will Generate, Treat and Downhole Dispose or Discharge to the GOM Section 7 Air Emissions Information
7

- A Emissions Worksheets Section 8 Oil Spill Information
8

- A Oil Spill Response Discussion Section 12 Support Vessels and Aircraft Information
12

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

- B Vicinity Map Section 14 Coastal Zone Management Act Information
14

- A Coastal Zone Consistency Certification Section 15 Environmental Impact Analysis (EIA)
15

- A Environmental Impact Analysis (EIA)

### Freeport

- McMoRan Oil & Gas LLC Section 1 – Pg. 1 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 1
PLAN CONTENTS

1.1 PLAN INFORMATION
Lease OCS

- G 06894

, for Viosca Knoll Block 915, was awarded on June 1, 1981 in
Lease S ale 81. The Viosca Knoll Block 915 Unit (Unit Agreement N o. 754396011) was approved on May 31, 1996. The unit is currently held by production.

An Initial Exploration Plan for BP America P roduction Company (Control N o. N- 2908) was approved on March 4, 1998. A Revised Exploration Plan for Freeport

- McMoRan Oil & Gas LLC (FM O&G), Control N o. R- 6011, provided for the revision of Well Locations A and B, the rig type from a semisubmersible to a d rillship and change of operator. The Revised EP was approved on March 21, 2014 and neither well has been drilled.

Under this Supplemental Exploration Plan, FM O&G proposes to drill, test, complete,
flare and install subsea wellheads for two additional we ll locations in approximately 3,562 feet of water in Viosca Knoll Block 915 (OCS

- G 06894) using a dynamically positioned drillship similar to the Transocean Deepwater Champion

.

The OCS Plan Information Form BOEM

- 137 is included as Attachment 1 -A

.

1.2 LOCATION

A Well Location Plat depicting the proposed surface and bottom h ole locations of the proposed well s. measured depth/t rue vertical depth and water depth for each location is

included as Attachment 1 -B

.
A Bathymetry Map depicting the proposed surface locations and water depth of each proposed well in included as Attachment 1 -C

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

1.3 SAFETY AND POLLUTION PREVENTION FEATURES FM O&G proposes to drill the wells with a dynamically positioned drillship similar to the Transocean Deepwater Champion which is equipped with a Subsea BOP. Once a rig is

determined , BOP information and schematics will be included as part of the Application
for Permit t o 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

### Freeport

- McMoRan Oil & Gas LLC Section 1 – Pg. 2 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) as life rafts, life jackets, ring buoys, etc. as prescribed by the USCG, will be maintained on the rig at all times.

Safety features on the drilling unit will include well control, pollution prevention, and blowout prevention equipment as described in BSEE regulations 30 CFR 250 C, D, E, O, Q and S; and as further clarified by BSEE Notices to Lessees, and current policy making invoked by the BSEE, Environmental Protection Agency and the U.S. Coast
Guard (USCG)

.
Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on drilling deck areas to collect all contaminants and debris. Compliance will be maintained with the EPA NPDES Permit. The rig will be monitored daily and any waste or fuel resulting in pollution of the Gulf waters will be reported to the representative in charge for immediate isolation and correction of the problem. Any spill will be reported to the appropriate governmental agencies.

1.4 STORAGE TANKS AND PRODUCTION VESSELS Only includes storage tanks with capacity of 25 barrels or more that will store fuels , oil and lubrican ts.

Type of Storage Tank Type of Facility Tank Capacity

(bbls) Number of Tanks Total Capacity

(bbls) Fluid Gravity

(API) Fuel Oil (Marine Diesel) Drillship 33,188 bbls 13 47,371 bbls 35 o



### 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 d oes not propose any additional safety, pollution prevention, or early spill detection measures beyond those required by 30 CFR 250.

1.7 COST RECOVERY FE E Documentation of the $ 3673 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 R- 6011

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 Loc. G: Drill, test, complete, flare & install subsea wellhead 2/21/2016 5/31/2016 100

Well Loc. F: Drill, test, complete, flare & install subsea wellhead 6/1/2016 9/8/2016 100

Well completion

Well test flaring (for more than 48 hours)

Installation or modification of structure

Installation of production facilities

Installation of subsea wellheads and/or manifolds

Installation of lease term pipelines

Commence production

Other (Specify and attach description ) 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)

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, Suite 1100 Contact Person: Paul Landry

Lafayette, Louisiana 70508 Phone Number (office) 337

- 354

- 5065 (mobile) 337

- 349

- 7781

E- Mail Address: paul_landry@fmi.com

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $ 3673 Receipt No. 74676050486 Project and Worst Case Discharge (WCD) Information

Lease(s): OCS

- G 06894 Area: Viosca Knoll Block(s) 915 Project Name (If Applicable): Dorado

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

Platform / Well Name: A Total Volume of WCD: 21,897,360 bbls API Gravity: 35.4 o

Distance to Closest Land (Miles): 65.8 miles Volume from uncontrolled blowout: 182,478 bbls/day 

### OCS PLAN INFORMATION FORM OMB Control Number: 1010

- 0151 OMB Approval Expires: 12/31/14OCS 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): Loc. 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): 1 07,958 bbls/day For structures, volume of all storage and pipelines (Bbls) : NA API Gravity of fluid 35.4 o

Surface Location Bottom

- Hole Location (For Wells) Completion (For multiple completions, enter separate lines)

Lease No. OCS

- G 06894 OCS

- G 06894 OCS
OCS

Area Name Viosca Knoll Viosca Knoll

Block No. 915 915

Blockline Departures (in feet) N/S Departure 6,635.00 FSL N/S Departure N/S Departure F __ L N/S Departure F __ L N/S Departure F __ L

E/W Departure 3,000.00 FWL E/W Departure E/W Departure F __ L E/W Departure F __ L E/W Departure F __ L

Lambert X

- Y
coordinates X: 1,333,560.00 X: X:
X:
X:

Y: 10,556,075.00 Y: Y:
Y:
Y:

Latitude/ Longitude Latitude 29 o 05’ 02.4304” N Latitude Latitude
Latitude
Latitude

Longitude 87 o 57’ 39.6140” W Longitude Longitude Longitude Longitude

Water Depth (Feet): 3,561’ MD (Feet): TVD (Feet): MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet): Anchor Radius (if applicable) in feet: NA

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

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

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

Form BOEM - 0137 (December 2011 – Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS 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): Loc. G 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. Is this an existing well or structure?

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): 107,958 bbls/day For structures, volume of all storage and pipelines (Bbls): NA API Gravity of fluid 35.4 o

Surface Location Bottom

- Hole Location (For Wells) Completion (For multiple completions, enter separate lines)

Lease No. OCS

- G 06894 OCS

- G 06894 OCS
OCS

Area Name Viosca Knoll Viosca Knoll

Block No. 915 915

Blockline Departures (in feet) N/S Departure 6,635.00 FSL N/S Departure N/S Departure F __ L N/S Departure F __ L N/S Departure F __ L

E/W Departure 2,900.00 FWL E/W Departure E/W Departure F __ L E/W Departure F __ L E/W Departure F __ L

Lambert X

- Y
coordinates X: 1,333,460.00 X: X:
X:
X:

Y: 10,556,075.00 Y: Y:
Y:
Y:

Latitude/ Longitude Latitude 29 o 05’ 02.4223” N Latitude Latitude
Latitude
Latitude

Longitude 87 o 57’ 40.7413” W Longitude Longitude Longitude Longitude

Water Depth (Feet): 3,562’ MD (Feet): TVD (Feet): MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet): Anchor Radius (if applicable) in feet: NA

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

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

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

Form BOEM - 0137 (December 2011 – Supersedes all previous editions of this form which may not be used.) Page 2 of 4HHHHHHHH"!.!.FM (SN-13387) 12" CSNG (ACT)FM (SN-13386) 8" BLKO (ACT)FM (SN-13384) 8" BLKO (ACT)FM (SN-13385) 12" METH (ACT)FM (SN-11765) 10" OIL (ACT)VK 915OCS-G-06894Freeport-McMoRan Oil & Gas LLCA-Marlin TLPFM #A001-003,A006 (G06894)FM #SS1(G06894)FM #SS2(G06894)FM #SS3(G06894)FM #SS4(G06894)FM #SS5(G06894)FM #A004-005 (G08469) F M ( S N - 1 3 7 6 3 )

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1,335,000 1,340,000 1,345,00010,550,00010,555,00010,560,00010,565,000EXISTING PIPELINE LOCATION,AS REPORTED BY BOEM."EXISTING PLATFORM LOCATION,AS REPORTED BY BOEM.HEXISTING WELL LOCATION,AS REPORTED BY BOEM.!.PROPOSED WELL LOCATION.FREEPORT-MCMORANOIL & GAS LLCATTACHMENT CFIGURE 1WELL LOCATION PLATPUBLIC COPYWELL F AND GBLOCK 915OCS-G 06894VIOSCA KNOLL AREAGULF OF MEXICOJOB NO.: 0614-2414DATE: 16 JULY 2014DATUM: NAD 27PROJECTION: UTMZONE 160 1,000 2,0005001 inch = 2,000 feet1:24,000Proposed Locations- VK 915Location CallE/W CallN/S XCoordinate YCoordinate Latitude Longitude WDFSL 3,000.00FWL 6,635.00FSL 1,333,560.00 10,556,075.00 29°05'02.4304"N 87°57'39.6140"W 3,561'GSL 2,900.00FWL 6,635.00FSL 1,333,460.00 10,556,075.00 29°05'02.4223"N 87°57'40.7413"W 3,562'

## H ! . FM #SS4 (G06894)

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OCS-G-06894 Freeport-McMoRan Oil & Gas LLC



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10,552,500 10,555,000 10,557,500 10,560,000

3D SURVEY LINE.

EXISTING PIPELINE LOCATION, AS REPORTED BY BOEM. 

## H EXISTING WELL LOCATION, AS REPORTED BY BOEM. 

## ! . PROPOSED WELL LOCATION.

CIRCLE REPRESENTS 2000 FT RADIUS AROUND PROPOSED WELLSITE.

WATER DEPTH CONTOUR IN FEET. PROJECT NO.: 0614-2414 FILE NAME: 2414_WELL_F_1.MXD



### FREEPORT-MCMORAN OIL & GAS LLC

BATHYMETRY MAP

BLOCK 915 VIOSCA KNOLL AREA GULF OF MEXICO

MAP F-1 0 500 1000 1500 2000

1:12,000 SCALE 1 " = 1,000 ' OR

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10,552,500 10,555,000 10,557,500 10,560,000

3D SURVEY LINE.

EXISTING PIPELINE LOCATION, AS REPORTED BY BOEM. 

## H EXISTING WELL LOCATION, AS REPORTED BY BOEM. 

## ! . PROPOSED WELL LOCATION.

CIRCLE REPRESENTS 2000 FT RADIUS AROUND PROPOSED WELLSITE.

WATER DEPTH CONTOUR IN FEET. PROJECT NO.: 0614-2414 FILE NAME: 2414_WELL_G_1.MXD



### FREEPORT-MCMORAN OIL & GAS LLC

BATHYMETRY MAP

BLOCK 915 VIOSCA KNOLL AREA GULF OF MEXICO

MAP G-1 0 500 1000 1500 2000

1:12,000 SCALE 1 " = 1,000 ' OR1 

### Favaloro, Katharine

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

Sent: Wednesday, September 10, 2014 1:12 PM

To: Favaloro, Katharine Subject: Pay.gov Payment Confirmation: BOEM Exploration Plan - BF

Yo u r payment has been submitted to Pay.gov and the details are below. If you have any questions regarding this payment, please contact Brenda Dickerson at (703) 787-1617 or by email at BseeAccountsReceivable@bsee.gov

.

Application Name: BOEM Exploration Plan - BF Pay.gov Tracking ID: 25HGJS7D Agency Tracking ID: 74676050486 Transaction Type: Sale Transaction Date: 09/10/2014 02:11:56 PM EDT

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 LLC, 03280 Lease Number(s): 06894, , , , Area-Block: Viosca Knoll VK, 915: , : , : , : ,
Surface Locations: 1

THIS IS AN AUTOMATED MESSAGE. PLEASE DO NOT REPLY.

### Freeport

- McMoRan Oil & Gas LLC Section 2 – Pg. 3 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 2
GENERAL INFORMATION

2.1 APPLICATIONS AND PERMITS

T he table below provides all addi tional applications t o be filed covering operations proposed in this EP

.
Application/Permit Issuing Agency Status Application for Permit to Drill BSEE To be submitted

2.2 DRILLING FLUIDS

The table below provide s t he types and estimated volumes of the drilling fluids FM O&G plan s to use to drill the proposed wells.

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be Used per Well (bbls)
Water

- based (seawater, freshwater, barite) 50,000 bbls Oil

- based (diesel, mineral oil ) 0 bbls Synthetic

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

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 b ond, furnished and maintained according to 30 CFR 5 56, S ubpart I;
NTL No. 2000

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

- approved deferment from providing additional security under 30 CFR 5 56.53(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

, Operator N o. 03280, has demonstrate d oil s pill financial responsibility for the facilities proposed in this EP according to 30 CFR 5 53;

and NTL No. 2008

- N05, "Guidelines for Oil Spill Financial Responsibility for Covered

Facilities" prior t o conducting operations covered in this EP.

### Freeport

- McMoRan Oil & Gas LLC Section 2 – Pg. 4 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 2.6 DEEPWATER WELL CONTROL STATEMENT
FM O&G

, Operator No. 03280, has the financial capability to drill a relief well and conduct other emergency well control operations.

2.7 BLOWOUT SCENARIO AND WORST CASE DISCHARGE CALCULATIONS The Worst Case Discharge is defined as a n uncontrolled blowout through the drilling string during drilling operations.

The highest Worst Case Discharge in this Exploration Plan is for VK 915 Well Location A accepted under Plan Contro l No. R

- 6011 approved on March 21, 2014.

Estimated Initial Flow Rate (bbls/day): 182,478 bbls /day

Maximum duration of potential blowout (days): 120 days

Total Volume (bbls) (flow rate x duration): 21,897,360 bbls

Discussion of potential for well to bridge ov er: While the sands to be encountered by the wells in this EP are expected to be slightly consolidated Freeport

- McMoRan Oil &
Gas LLC (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 Society of Petroleum Engineers (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 “A” will be drilled in the Viosca Knoll (VK) Block 915 as a subsea well in approximately 3,560’ 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.

### Freeport

- McMoRan Oil & Gas LLC Section 2 – Pg. 5 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 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 cond itions 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 t o take 3 – 5 days. During this period, the well control team would analyze the blowout situation, devise an intervention 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 Port 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 5,000' 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 70 days.

Rig type capable of drilling relief well at water depth and to TD: There are more than 10 drilling rigs currently working or slated to begin work in the Gulf of Mexico that are capable of drilling a relief well at these locations.

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

• Be rated and equipped to work in water depths of 5,000’ due to VK Block 9 15 deepwater location.

• Dynamically

‐ positioned to eliminate anchoring issues due to nearby subsea
infrastructure.

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

### Freeport

- McMoRan Oil & Gas LLC Section 2 – Pg. 6 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) Ti me 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 70 Wellbore intersection (of blown out well) 21 Dynamic kill operations 7 Total Anticipated Time 120



### Statement whether possibility of using nearby platform was considered: The

Marlin Tension

- Leg Platform (TLP) is located in the northern portion of the VK Block 915 and is owned and operated FM O&G . The Marlin TLP has the ability to accommodate a completion rig which has been mobilized to Marlin in the past for completion/workover operations. Limited hookload and pumping capability of the completion rig combined
with the time associated for mobiliz ing and rig up of the completion rig makes drilling a relief well from the Marlin TLP not practical. All relief wells will be based upon mobilizing a dynamically positioned drilling rig to VK Block 915.

Other Measures to enhance ability to prevent a blow out:

• 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

te sting 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 lin er top packer or equivalent expandable will be run on all liner laps as an additional barrier for well safety.

### Freeport

- McMoRan Oil & Gas LLC Section 2 – Pg. 7 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) • 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 con centrated pills will be used to prevent uncontrolled mud losses.

• Every effort will be made to review all offset and seismic data in order to prepare a mud weight schedule that will allow for safe drilling margin without putting excess hydrostatics pressures on known zones previously encountered.

• Mudloggers may be utilized during critical drilling operations to monitor gas content of mud returns, formation characteristics and abnormalities of cuttings and to estimate paleo aging of cuttings.

• Logging While Drilling (LWD) tools will be utilized as much as possible to evaluate formations, formation pressures and fluid content in the critical sections
of the well.

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

Measures t o 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 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 2010

- N06, “Information Requirements for Exploration Plans, Development and Production Plans, and Development Operations Coordination Documents on the OCS,” the blowout scenario and worst case discharge calculations
were verified and approved in Exploration Plan R

- 6011.

### Freeport

- McMoRan Oil & Gas LLC Section 3 – Pg. 8 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 3
GEOLOGICAL AND GEOPHYSICAL INFORMATION

3.1 GEOLOGICAL DESCRIPTION Proprietary

3.2 STRUCTURE CONTOUR MAP Proprietary

3.3 INT ERPRETED SEISMIC LINE S Proprietary

3.4 GEOLOGICAL STRUCTURE CROSS

- SECTIONS Proprietary

3.5 SHALLOW HAZARDS REPORT A shallow hazards survey was conducted over Viosca Knoll Block 915

.

In accordance with NTL No. 2008

- G05, “Shallow Hazards Program” (Extended by NTL

NTL No. 2014

- G05 , “Extension of Prior Notices to Lessees”), a shallow hazards survey evaluating seafloor and subsurface geological and manmade features and conditions that may adversely affect drilling operations, was conducted by Geoscience Earth & Marine Services, Inc. The shallow hazards report was provided with Exploration Plan

R- 6011.

3.6 SHALLOW HAZARDS ASSESSMENT

In accordance with NTL No. 2008

- G05, “ Shallow Hazards Program

, ” (Extended by NTL

No. 2014

- G05 , “Ext ension of Prior Notices to Lessees” ), a shallow hazards assessment has been prepared for each proposed surface location e valuating seafloor and subsurface geological and manmade features and conditions that may adversely affect drilling operations. The shallow hazards assessment is included as Attachment 3 -D

.

3.7 HIGH

- RESOLUTION SEISMIC LINES Proprietary

3.8 STRATIGRAPHIC COLUMN Proprietary

3.9 TIME V ERSUS DEPTH TABLES Proprietary**103 44 Sam Houston Park Dr.**  **Houston, Texas 77064 713**  **.351.7900 [o] 713.351.7996 [f]**

**www.gemsinc.com**

**July 16, 2014 Project No. 0614-2414** 

**Freeport-McMoRan Oil & Gas 400 East Kaliste Saloom Road**  **Suite 1100 Lafayette, LA 70508** 

**Attention: Mr. Kaare Egedahl**



### Site Clearance Letter for
Pr opos ed Wellsite VK 915-F Block 915 (OCS-G-06894)
Viosca Knoll Area Gulf of Mexico

**Freeport-McMoRan Oil & Gas (FMI) contracted Geoscience Earth & Marine Services (GEMS) to provide**

**an assessment of the seafloor and shallow geologic conditions to determine the favorability of drilling**  **operations for the proposed location VK 915-F in Block 915 (OCS G-06894), Viosca Knoll Area, Gulf of Mexico. This letter addresses specific seafloor and subsurface conditions around the proposed location**  **to the limit of investigation, a depth of about 3,930 ft below the mudline (bml).**

**This letter is based on findings provided within four separate investigations of VK 915. The main source for this assessment comes from the geohazard report compiled by Geoscience Earth & Marine Services**  **(GEMS, 2013). This report is supplemented with the geohazard and archaeological assessments performed by C & C Technologies over VK 915 and vicinity (C&C, 2002 and 2007) and a site specific**  **benthic community investigation in VK 915 (C&C, 2014). This letter uses those investigations to provide details pertaining directly to the proposed wellsite.** 



### Proposed Well Location

**The surface location for the Proposed Exploration Wellsite VK 915-F lies in the south-central portion of**
**VK 915. FMI provided the following coordinates:** 

Table 1. Proposed Location Coordinates
Proposed Wellsite VK 915-F

Spheroid & Datum: Clarke 1866, NAD27 Projection: UTM Zone 16 North Line Reference Block Calls (VK 915)

**X: 1,333,560 ft Latitude: 29o 05’ 02.430” N Inline 12050 3,000 ft FWL**
**Y: 10,556,075 ft Longitude: 87o 57’ 39.614” W Crossline 1238 6,635 ft FSL**

**FMI will drill this well using a dynamically positioned drilling vessel. Our assessment addresses the seafloor conditions within a 2,000-ft radius around the proposed wellsite location.** 



### Available Data

**The following discussion is based on the findings provided within three reports**

**1. G eohazard report “Geologic and Stratigraphic Assessment, Block 915, Viosca Knoll Area, Gulf of**  **Mexico” (GEMS Project No. 0413-2236) submitted to Plains Exploration and Production Company (PXP) in August 2013. The text, maps, and figures included in the report provide detail**  **on the regional geology of the Study Area. An exploration 3-D seismic time volume was provided Proposed Wellsite VK 915-F Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 2
FO RUM ENERGY TECHNOLOGIES, INC. **for the geohazard analysis, covering an approximate 23 square-mile "Survey Area" that includes**  **all or portions of Federal lease Blocks VK 871, 914, 915, and 959 (Figure F-1). These data were used to create surface renderings and detailed sub-seafloor mapping.** 
**2. A**  **C & C Technologies, Inc., (C & C) geohazard assessment using high-resolution, AUV (A**  **u tonomous Underwater Vehicle) data covered all or portions of blocks 914, 915, 916, 959, and**  **960 of the Viosca Knoll Area, (C & C, Project No.: 3042/3077, 2002). The report was submitted to BP Exploration & Production Inc. in August, 2002.**  **3. A C & C archaeological report based on high-resolution AUV geophysical data collected by C & C was also provided for this assessment of wellsites. The survey covered VK 915. These data**  **included 1.5-4.5 kHz subbottom profiler, 230-kHz side-scan sonar, and 3-meter bin multibeam bathymetry data. The assessment was originally submitted to BP Exploration in 2007 (C & C**  **Project 072217, 2007). 4. The most recent data provided for this wellsite assessment were from the C & C “Deepwater** **Benthic Community Investigation Block 915 (OCS-G-06894)”. This study was based on high resolution geophysical data and camera imagery. The data and report were submitted to FMI in**  **June, 2014 (C & C, Project 130909, 2014).**

Figure F-1. **Seafloor Rendering of the Viosca Knoll Survey Area.**



### Attachments

**Wellsite maps are centered on the Proposed Exploration Wellsite VK 915-F location and are displayed at a 1**  **inch = 1,000 ft scale (1:12,000). The maps included in this letter are as follows:**

**Map No. VK 915-F-1: Bathymetry Map Map No. VK 915-F-2: Seafloor Features Map**  **Map No. VK 915-F-3: Amplitude-Enhanced Seafloor Rendering Proposed Wellsite VK 915-F Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 3
FO RUM ENERGY TECHNOLOGIES, INC. **Map N o. VK 915-F-4: Geologic Features Map** 

**The illustrations accompanying this letter were extracted from the available datasets and are listed below:**

**Illustration VK 915-F-1: Portions of Inline 12050 and Crossline 1238 Showing Conditions Beneath Proposed Wellsite VK 915-F**  **Illustration VK 915-F-2: Tophole Prognosis Chart, Proposed Wellsite VK 915-F, Viosca Knoll,**
**Block 915**



### NTL Requirements

**The following report complies with the Bureau of Ocean Energy Management (BOEM) Notice to Lessees (N**  **T L’s) 2009-G40, 2008-G04, and 2008-G05 (MMS, 2010 and 2008a, b). BOEM’S NTL 2014-G03**  **(BOEM, 2014a) extends the expiration of NTL 2008-G04 and 2008-G05. The Federal lease Block VK 915 is considered archaeologically significant (NTL 2011-JOINT-G01, BOEM, 2011); therefore, requirements set**  **forth in NTL 2005-G07 (MMS, 2005) are applicable in terms of high-probability for historic resources. C & C prepared an archaeological assessment to comply with the Archaeological Resource Surveys and**  **Reports requirements and submitted the report to BP in April 2007 (C & C, 2007).**

**As specified in NTL 2008-G05 (MMS, 2008b), GEMS extracted the power spectrum diagram from the 3-D seismic data cube at the proposed wellsite (Figure F-2). The extraction was generated within a 1,000-ft**  **radius of the intersection of the inline and crossline at the proposed wellsite. The extraction time interval consisted of the seafloor to a depth of 1.0 seconds, two-way travel time below the mudline (bml). We**  **converted the amplitude vs. frequency spectrum, generated by the SMT software, to power vs. frequency by squaring the amplitude values as described by J. A. Coffeen, 1978.** 

Figure F-2. **Power Spectrum Curve, Proposed Wellsite VK 915-F**



### Man-Made Features

**The Proposed Wellsite VK 915-F is located in the Marlin development area (Figure F-1). Several wells**
**ha v**  **e previously been drilled in VK 915 and the surrounding area. The Marlin production platform is located approximately 10,200 ft to the northeast. Table 2 provides a summary of existing wells drilled**  **within 7,500 feet of the proposed VK 915-F well: Proposed Wellsite VK 915-F Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 4
FO RUM ENERGY TECHNOLOGIES, INC.

Tab le 2. Existing Well Locations Near the Proposed Wellsite

Surface Area / Block Well

Name Operator Well Status Distance / Direction from Proposed Surface Location

**MC 915 #SS 004**  **Freeport McMoRan Oil & Gas LLC**  **Development 130 ft/Northeast** 

**MC 915 #SS 003**  **Freeport McMoRan Oil & Gas LLC**  **Development 7,422 ft /Southeast** 

**Note: Latest infrastructure update from the BOEM database on May, 2014 (BOEM, 2014b).**

**Numerous pipelines and umbilicals exist within VK 915. Table 3 lists the lines within 2,000 ft of the**

**pro posed wellsite. The structures appear on Maps 1 through 4.** 

Table 3. Existing Pipelines/Umbilicals Near the Proposed Wellsite

Structure Segment No. Operator Distance / Direction from Proposed Surface Location

**4” Umbilical SN17662**  **BP 175 ft/Northeast** 
**8” BLKO 12” CSNG**  **SN 16151 SN 16152**  **BP 75 ft /Northeast** 

**Note: Latest infrastructure update from the BOEM database on May, 2014 (BOEM, 2014b).**

Archaeological Assessment

**Based on the information provided in the C & C Archaeological Assessment Report (C & C, 2007), no**
**kno wn shipwrecks and no archaeological avoidances exist within 2,000 ft of the proposed wellsite. The**  **2007 archaeological assessment noted 25 unidentified sonar contacts within the area. The most recent 2014 survey noted one target about 1,305 ft southwest of the proposed site (Sonar Contact #1, Map**  **VK 915-F-2). The object is not archaeologically significant and no avoidance has been placed on this**
**contact**

**The sonar targets within C & C’s AUV survey areas are interpreted as a debris zone, broken pipe sections, unknown modern debris, a possible shipwreck site, and a known shipwreck with associated**  **debris fields (C & C, 2002, 2007, 2014).**

**Sonar Contact No. 4, from the 2007 report, is a possible shipwreck site located in the central portion of VK 915 about 2,370 ft northeast of the proposed wellsite. The sonar target is identified as having an oval**  **shape and acoustic signatures similar to known shipwreck sites (C & C, 2007). The BOEM examined the target with an ROV; however the investigation was inconclusive. The BOEM has designated a 1,000 ft**  **avoidance zone surrounding Sonar Contact No. 4.**

**Sonar Contact No. 8, from the 2002 survey, is a known shipwreck identified as the historic steam yacht**
Anona **(C & C, 2002, 2007). This wreck lies in the northwestern corner of VK 960 about 3.1 miles east southeast of the proposed wellsite. A 1,300 ft archaeological avoidance is assigned to this shipwreck.** 



### Wellsite Conditions

**A well (#SS004), pipeline, and umbilical occur within a few hundred feet of the proposed VK 915-F site.**
**Th e**  **se structures will need to be avoided by the new well emplacement. Geologically, the proposed location is clear of any constraining seafloor conditions as defined by the AUV and 3-D seismic datasets.**  **The proposed wellbore will likely penetrate interbedded sand layers within a faulted unit below 987 ft bml. The PXP #A001 well in VK 915 experienced a “moderate” shallow water flow that was believed to**  **originate from sands at 768 ft bml. This well was drilled in 1993. However, the existing nearby Freeport McMoRan #SS004 well, with four side-tracks completions, achieved depths of 7,905 to 10,954 ft (TVD).**  **These wells were drilled in 2002. No gas accumulations or shallow water flows were reported from these**
**wells. Proposed Wellsite VK 915-F Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 5
FO RUM ENERGY TECHNOLOGIES, INC. Water Depth and Seafloor Conditions

**T he water depth at the proposed surface location is –3,561 ft (Map VK 915-F-1). The seafloor slopes to** 
**the s outheast at 2.4°.** 

**The Proposed Wellsite, VK 915-F is situated within the Fuji Channel, a shallow buried channel-levee complex (Illustration F-1). The edge of the Fuji Channel lies about 1,800 ft southwest of the proposed**  **location (Illustration F-1). The seafloor at the proposed site is slightly irregular along the southwestern flank of the channel (Map F-2). AUV subbottom profiler data in the area indicate a surficial drape of soft,**  **high-water content silty clays covering the seafloor surrounding the proposed wellsite.**

Deepwater Benthic Communities

**T he Amplitude-Enhanced Seafloor Rendering (Map F-3) shows three areas of high-amplitude returns** 

**sou th, southwest, and west of the proposed location. These anomalous areas range from 980 ft to**  **2,090 ft from VK 915-F. The AUV subbottom profiler data identified near-surface zones of gas charged sediment in the vicinity of the amplitude events identified by the 3-D data set (C & C, 2002, 2007). The**  **zones of gas-charged sediments were buried by 5 ft to 30 ft of sediment. One small zone of gas-charged sediments identified on the subbottom profiler data appeared to extend up to the seabed. This small gas**  **charged zone roughly corresponds to the area of highest seafloor amplitude returns on the 3-D rendering (Map F-3). However, sonar and MBE backscatter showed minor variations in seafloor reflectivity within** 
**these areas.**

**The GEMS (2013) report placed a high-potential for high-density benthic communities in the areas of high-amplitude returns (Map F-3). These anomalies are within the 2,000 ft radius of the proposed**  **wellsite. Therefore, FMI commissioned C & C to conduct a Benthic Community Investigation (C & C, 2014). A survey using C & C’s C-Surveyor VI was conducted over the area of anomalous amplitudes**  **(Map F-3). The survey grid consisted of 87 northwest-southeast survey lines with 12-ft spacing. The AUV instruments included a high-resolution digital camera along with the standard multibeam (Kongsberg**  **EM2040), side-scan sonar (Edge Tech DF4500), and subbottom profiler (EdgeTech Chirp DW106).**

**The main area of high-amplitude south-southwest of the proposed location, corresponded to a zone of irregular seafloor with a lightened seafloor reflectivity and buried shallow gas zones on the subbottom**  **profiler. Camera images showed small pockmarks and undulations of less than 1 foot but no benthic communities were observed (C & C, 2014).** 

**Overall the 2014 survey showed a seafloor with low- to moderate-reflectivity indicative of fine grained sediments. A well-splay from the #SS 004 well was identified as a zone of contrasting sediment type with**  **distinct backscatter properties relative to the ambient sediment type. The splay had an east-west trend across the survey. No benthic communities were identified within the 2014 survey area.** 

**One sonar target (#1) was identified by the 2014 survey. The target was an object 2.1 ft long. 0.9 ft wide, and 0.2 ft high. Digital photographs showed this object was not archaeologically significant and may in**  **fact be a natural feature (C & C, 2014).**

Stratigraphy

**S tratigraphic conditions are shown on Illustrations F-1 and F-2. The surficial interval from the seafloor to** 
**221 ft bml, will likely consist of very soft silty clays overlying stratified, normally consolidated hemipelagic**  **and turbidite clays and silty clays (Illustration F-1). These shallow sediments should provide adequate foundation for bottom-founded structures.** 

**The seismic character of the interval between 221 ft and 423 ft bml indicates mud-rich turbidite deposits. These sediments were the last phase in the Fuji Channel deposition prior to burial by hemipelagic and**  **pelagic sediments.**

**The interval between 423 ft to 631 ft bml consists of chaotic channel fill sediments. The sediments will be a mixture of clay and silt with scattered layers and pockets of sand and silty sand.** **Proposed Wellsite VK 915-F Clearance Letter**

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 6
FO RUM ENERGY TECHNOLOGIES, INC. **The base of Unit 2 (631 ft to 987 ft) consists of continuous, moderate-amplitude reflectors overlying semi**  **continuous to continuous, low-amplitude reflectors. The overall sequence likely represents stratified turbidites interlayered intercalated with thin mud-rich mass-transport deposits. Well logs from the**  **Freeport McMoRan #SS5 Well in VK 915 indicate a generally clay-rich unit with thin sand seams interspersed throughout the interval. An increase in sand thickness occurs near the base of the unit.** 

**Unit 3 (987 ft to 2,047 ft bml) consists of low- to moderate-amplitude reflectors of varying continuity interlayered with units of low-amplitude, continuous, discontinuous, and chaotic reflections (Illustration F**  **2). This unit corresponds to a sand-prone, slope-fan sequence. Low-amplitude stratified reflectors within the unit likely represent hemipelagic clays and silts interlayered with clay-rich turbidite and mass-transport**  **deposits. The moderate-amplitude reflectors within this interval likely represent slope-fan and turbidite deposits. The well logs indicate thin sand seams interspersed throughout the slope-fan sequence with an**  **increase in sand layers in the lower portion of the unit.**

**Unit 4 (2,047 ft to 3,930 ft bml) consists of low-amplitude, continuous to semi-continuous reflectors interbedded with low-amplitude, chaotic reflectors. This sequence likely represents stratified turbidites**  **interlayered with thin mass-transport deposits. The MWD logs show a relatively clay-rich interval with intermittent thin sand seams throughout the unit.** 

Faults

**A seafloor fault will be penetrated by the proposed wellsite (Illustrations VK 915-F-1 through VK 915-F-2).**
**Th e**  **fault intersection will be near the center of Unit 3 at about 1,408 ft bml. The fault intersects the seafloor about 1,700 ft to the southwest of the proposed location (Map F-2). In addition, a vertical**  **wellbore at the proposed location will intersect a buried fault at a depth of approximately 3,197 ft bml (-6,758 ft bsl), Illustration VK 915-F-1. Engineers should be aware of the potential for lost circulation**  **across fault planes.**

**The base of the Fuji Channel will be intersected about 631 ft bml (Illustrations VK 915-F-1, VK 915-F-2). The interface is not a fault; however, but will be a significant change in sediment type and geotechnical**  **properties across this boundary.**

Shallow Gas

**The well path will not penetrate any interpreted high-amplitude events from the seafloor to the limit of**
**in v**  **estigation (3,930 ft bml), Map No. F-4 and Illustrations VK 915-F-1, VK 915-F-2.**

**A negligible potential for encountering shallow gas exists within the clay-prone units between the seafloor and Horizon 10 (221 ft bml).** 

**In general, there is a low potential for encountering shallow gas within the units below Horizon 10 (221 ft bml) to the limit of investigation (3,930 ft bml). A zone of slightly elevated amplitude returns occur**  **in Unit 2 at about 750 ft bml (Illustrations VK 915-F-1, VK 915-F-2). This zone is about 200 ft, north of the proposed VK 915-F wellsite. The nearby #SS4 well was drilled within 115 ft of the elevated amplitude**  **zone and did not report any with gas at that level. Therefore, the proposed wellsite should have a lower potential for gas than the existing well at the 750 ft bml level.** 

Shallow Water Flow

**Based on the seismic character, the potential for sand-rich sediments is considered likely within the**
**cha nnel fill interval within Unit 2 (423-631 ft bml) (Illustrations VK 915-F-1, VK 915-F-2). Because of the**  **presence of sand, we assign a moderate potential for overpressures. Overall, the well conditions at the Proposed Wellsite VK 915-F appear to be similar to the nearby #SS4 Well. If sand was encountered, the**  **drilling practices employed for #SS4 well mitigated any overpressure. Therefore, we recommend examining the drilling methods employed at #SS4 and determine if they are applicable to the proposed** 
**VK 915-F well.**

**There is a moderate potential for encountering shallow water flow within Unit 3 (987 ft to 2,047 ft bml), Illustrations VK 915-F-1, VK 915-F-2. Potentially thick and continuous sand deposits may exist within the** **Proposed Wellsite VK 915-F Clearance Letter**

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 7
FO RUM ENERGY TECHNOLOGIES, INC. **turb idite and slope-fan deposits within these units. The sands within this interval are the source for water**  **flow in wells within the Viosca Knoll Area; however, no wells within the Survey Area have reported shallow water flow conditions within this unit (BOEM, 2013b).** 

**A low potential for water flow exists within Unit 4 from Horizon 40 to the limit of investigation (2,047 ft to 3,930 ft bml), Illustrations VK 915-F-1, VK 915-F-2. Any sands encountered within the turbidite and**  **mass-transport deposits within these intervals are expected to be thin seams and not likely to produce sustained flows. There is a negligible potential for encountering shallow water flow within Unit 1 from the**  **seafloor to Horizon 10 (0 ft to 221 ft bml).**



### Results

**Based on the data and reports from the C & C geohazard, archaeological, and benthic community**

**as s**  **essments, and the GEMS geohazard assessment we conclude that no high-density deepwater benthic communities occur within 2,000 ft of the proposed VK 915-F wellsite. In addition, no potential submerged**  **cultural resources are within 2,000 ft of the Proposed Wellsite F in VK 915.**

**An existing production well, an active pipeline, and one umbilical exist within 200 ft of the Proposed Wellsite VK 915-F. Therefore, extreme care will need to be taken when installing bottom-founded**  **equipment.**

**The subsurface interpretation concluded a moderate potential for shallow water flow within the channel fill interval in the upper portion of Unit 2 (427 ft to 631 ft bml) and within the slope-fan sequence in Unit 3**  **(987 ft to 2,047 ft bml). The drilling practices executed in the nearby #SS4 Well successfully mitigated these sand-prone sections.** 



### Closing

**We appreciate the opportunity to be of service to Freeport-McMoRan Oil & Gas and look forward to**

**wor king with FMI on future projects.** 

**Sincerely,**

GEOSCIENCE EARTH & MARINE SERVICES

**Thomas W. Neurauter, Ph.D. Daniel Lanier**  **Project Manager/Senior Geoscientist Director** 

**Attachments (4 Maps and 2 Figures)**

**Distribution: Mr. Kaare Egedahl, Freeport-McMoRan Oil & Gas, (6 copies)** 

REFERENCES

**BOEM (Bureau of Ocean Energy Management), 2011, Notice to lessees and operators (NTL) of federal oil and gas leases**

**an d**  **pipeline right-of-way (ROW) holders on the outer continental shelf (OCS), Revisions to the list of OCS lease blocks requiring archaeological resource surveys and reports: U. S. Department of the Interior, Bureau of Ocean Energy**  **Management, Bureau of Safety and Environmental Enforcement Gulf of Mexico Region (GOMR), NTL 2011-JOINT-G01. Effective Date December 29, 2011.** 

**Bureau of Ocean Energy Management, 2014a, Notice to lessees and operators of federal oil, gas, and sulphur leases in the outer continental shelf, Gulf of Mexico OCS region: Extension of prior notice to lessees, NTL 2014-G03.** 

**Bureau of Ocean Energy Management, 2014b, ASCII Data Files, published on the BOEM Gulf of Mexico Region Homepage, <http://www.gomr.boem.gov/homepg/pubinfo/freeasci/freedesc.html>, accessed May, 2014.** **Proposed Wellsite VK 915-F Clearance Letter**

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 8
FO RUM ENERGY TECHNOLOGIES, INC. **Bureau of Ocean Energy Management, 2014c, Seismic Water Bottom Anomalies Map Gallery, published on the BOEM Gulf of**  **Mexico Region Homepage, <http://www.boem.gov/Oil-and-Gas-Energy-Program/Mapping-and-Data/Map Gallery/Seismic-Water-Bottom-Anomalies-Map-Gallery.aspx>, accessed May, 2014.** 

**C & C Technologies Survey Services, 2002, Geohazard assessment, block study, blocks 914, 915, 916, 959, and 960, Viosca Knoll Area, Project No.: 3042/3077. Report submitted to BP Exploration & Production Inc. in August, 2002.** 

**C & C Technologies Survey Services, 2007, Archaeological assessment report block 915 (OCS-G-06894) and vicinity, Viosca Knoll Area, Job No.: 072217. Report submitted to BP Exploration Inc., in April 2007.** 

**C & C Technologies, Inc., (C & C), 2014, Deepwater Benthic Community Investigation, Block 915 (OCS G-06894) Viosca Knoll Area, report No., 130909.** 

**Coffeen, J. A., 1978, Seismic Exploration Fundamentals: Tulsa, the Petroleum Publishing Co., p. 125.**

**Geoscience Earth & Marine Services, 2013, Geologic and Stratigraphic Assessment Block 915 (OCS G-06894) Viosca Knoll Area, Gulf of Mexico: report submitted to Plains Exploration & Production Company, August 5, 2013. GEMS Job No. 0413-**  **2236.**

**Minerals Management Service, 2005, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, Archaeological resource surveys and reports:**  **U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2005-G07.**

**Minerals Management Service, 2008a, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, information requirements for exploration plans**  **and development operations coordination documents: U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G04.** 

**Minerals Management Service, 2008b, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, shallow hazards requirements: U. S.**  **Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G05.**

**Minerals Management Service, 2010, Notice to lessees and operators of federal oil and gas leases in the outer continental shelf, Gulf of Mexico OCS region, deepwater benthic communities: U. S. Department of the Interior, Minerals Management**  **Service, Gulf of Mexico, NTL 2009-G40. Effective Date January 27, 2010. 103**  **44 Sam Houston Park Dr. Houston, Texas 77064**  **713 .351.7900 [o] 713.351.7996 [f]** 

**www.gemsinc.com**

**July 16, 2014 Project No. 0614-2414** 

**Freeport-McMoRan Oil & Gas 400 East Kaliste Saloom Road**  **Suite 1100 Lafayette, LA 70508** 

**Attention: Mr. Kaare Egedahl**



### Site Clearance Letter for
Pr opos ed Wellsite VK 915-G Block 915 (OCS-G-06894)
Viosca Knoll Area Gulf of Mexico

**Freeport-McMoRan Oil & Gas (FMI) contracted Geoscience Earth & Marine Services (GEMS) to provide**

**an assessment of the seafloor and shallow geologic conditions to determine the favorability of drilling**  **operations for the proposed location VK 915-G in Block 915 (OCS G-06894), Viosca Knoll Area, Gulf of Mexico. This letter addresses specific seafloor and subsurface conditions around the proposed location**  **to the limit of investigation, a depth of about 3,931 ft below the mudline (bml).**

**This letter is based on findings provided within four separate investigations of VK 915. The main source for this assessment comes from the geohazard report compiled by Geoscience Earth & Marine Services**  **(GEMS, 2013). This report is supplemented with the geohazard and archaeological assessments performed by C & C Technologies over VK 915 and vicinity (C&C, 2002 and 2007) and a site specific**  **benthic community investigation in VK 915 (C&C, 2014). This letter uses those investigations to provide details pertaining directly to the proposed wellsite.** 



### Proposed Well Location

**The surface location for the Proposed Exploration Wellsite VK 915-G lies in the south-central portion of**
**VK 915. FMI provided the following coordinates:** 

Table 1. Proposed Location Coordinates
Proposed Wellsite VK 915-G

Spheroid & Datum: Clarke 1866, NAD27 Projection: UTM Zone 16 North Line Reference Block Calls (VK 915)

**X: 1,333,460 ft Latitude: 29o 05’ 02.422” N Inline 12060 2,900 ft FWL**
**Y: 10,556,075 ft Longitude: 87o 57’ 40.741” W Crossline 1237 6,635 ft FSL**

**FMI will drill this well using a dynamically positioned drilling vessel. Our assessment addresses the seafloor conditions within a 2,000-ft radius around the proposed wellsite location.** 



### Available Data

**The following discussion is based on the findings provided within three reports**

**1. G eohazard report “Geologic and Stratigraphic Assessment, Block 915, Viosca Knoll Area, Gulf of**  **Mexico” (GEMS Project No. 0413-2236) submitted to Plains Exploration and Production Company (PXP) in August 2013. The text, maps, and figures included in the report provide detail**  **on the regional geology of the Study Area. An exploration 3-D seismic time volume was provided Proposed Wellsite VK 915-G Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 2
FO RUM ENERGY TECHNOLOGIES, INC. **for the geohazard analysis, covering an approximate 23 square-mile "Survey Area" that includes**  **all or portions of Federal lease Blocks VK 871, 914, 915, and 959 (Figure G-1). These data were used to create surface renderings and detailed sub-seafloor mapping.** 
**2. A**  **C & C Technologies, Inc., (C & C) geohazard assessment using high-resolution,**  **AUV (Autonomous**
**Un d**  **erwater Vehicle) data covered all or portions of blocks 914, 915, 916, 959, and 960 of the** 
**Vio sca Knoll Area, (C & C, Project No.: 3042/3077, 2002)** 

**. The report was submitted to BP**  **Exp loration & Production Inc. in August, 2002.**  **3. A C & C archaeological report based on high-resolution AUV geophysical data collected by C & C was also provided for this assessment of wellsites. The survey covered VK 915. These data**  **included 1.5-4.5 kHz subbottom profiler, 230-kHz side-scan sonar, and 3-meter bin multibeam bathymetry data. The assessment was originally submitted to BP Exploration in 2007 (C & C**  **Project 072217, 2007). 4. The most recent data provided for this wellsite assessment were from the C & C “Deepwater** **Benthic Community Investigation Block 915 (OCS-G-06894)”. This study was based on high resolution geophysical data and camera imagery. The data and report were submitted to FMI in**  **June, 2014 (C & C, Project 130909, 2014).**

Figure G-1. **Seafloor Rendering of the Viosca Knoll Survey Area.**



### Attachments

**Wellsite maps are centered on the Proposed Exploration Wellsite VK 915-G location and are displayed at**
**a 1 inch = 1,000 ft scale (1:12,000). The maps included in this letter are as follows:** 

**Map No. VK 915-G-1: Bathymetry Map Map No. VK 915-G-2: Seafloor Features Map**  **Map No. VK 915-G-3: Amplitude-Enhanced Seafloor Rendering Proposed Wellsite VK 915-G Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 3
FO RUM ENERGY TECHNOLOGIES, INC. **Map N o. VK 915-G-4: Geologic Features Map** 

**The illustrations accompanying this letter were extracted from the available datasets and are listed below:**

**Illustration VK 915-G-1: Portions of Inline 12060 and Crossline 1237 Showing Conditions Beneath Proposed Wellsite VK 915-G**  **Illustration VK 915-G-2: Tophole Prognosis Chart, Proposed Wellsite VK 915-G, Viosca Knoll,**
**Block 915**



### NTL Requirements

**The following report complies with the Bureau of Ocean Energy Management (BOEM) Notice to Lessees (N**  **T L’s) 2009-G40, 2008-G04, and 2008-G05 (MMS, 2010 and 2008a, b). BOEM’S NTL 2014-G03**  **(BOEM, 2014a) extends the expiration of NTL 2008-G04 and 2008-G05. The Federal lease Block VK 915 is considered archaeologically significant (NTL 2011-JOINT-G01, BOEM, 2011); therefore, requirements set**  **forth in NTL 2005-G07 (MMS, 2005) are applicable in terms of high-probability for historic resources. C & C prepared an archaeological assessment to comply with the Archaeological Resource Surveys and**  **Reports requirements and submitted the report to BP in April 2007 (C & C, 2007).**

**As specified in NTL 2008-G05 (MMS, 2008b), GEMS extracted the power spectrum diagram from the 3-D seismic data cube at the proposed wellsite (Figure G-2). The extraction was generated within a 1,000-ft**  **radius of the intersection of the inline and crossline at the proposed wellsite. The extraction time interval consisted of the seafloor to a depth of 1.0 seconds, two-way travel time below the mudline (bml). We**  **converted the amplitude vs. frequency spectrum, generated by the SMT software, to power vs. frequency by squaring the amplitude values as described by J. A. Coffeen, 1978.** 

Figure G-2. **Power Spectrum Curve, Proposed Wellsite VK 915-G**



### Man-Made Features

**The Proposed Wellsite VK 915-G is located in the Marlin development area (Figure G-1). Several wells**
**ha v**  **e previously been drilled in VK 915 and the surrounding area. The Marlin production platform is located approximately 10,255 ft to the northeast. Table 2 provides a summary of existing wells drilled**  **within about 7,500 feet of the proposed VK 915-G well: Proposed Wellsite VK 915-G Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 4
FO RUM ENERGY TECHNOLOGIES, INC.

Tab le 2. Existing Well Locations Near the Proposed Wellsite

Surface Area / Block Well

Name Operator Well Status Distance / Direction from Proposed Surface Location

**MC 915 #SS 004**  **Freeport McMoRan Oil & Gas LLC**  **Development 215 ft/Northeast** 

**MC 915 #SS 003**  **Freeport McMoRan Oil & Gas LLC**  **Development 7,520 ft /Southeast** 

**Note: Latest infrastructure update from the BOEM database on May, 2014 (BOEM, 2014b).**

**Numerous pipelines and umbilicals exist within VK 915. Table 3 lists the lines within 2,000 ft of the**

**pro posed wellsite. The structures appear on Maps 1 through 4.** 

Table 3. Existing Pipelines/Umbilicals Near the Proposed Wellsite

Structure Segment No. Operator Distance / Direction from Proposed Surface Location

**4” Umbilical SN17662**  **BP 260 ft/Northeast** 
**8” BLKO 12” CSNG**  **SN 16151 SN 16152**  **BP 155 ft /Northeast** 

**Note: Latest infrastructure update from the BOEM database on May, 2014 (BOEM, 2014b).**

Archaeological Assessment

**Based on the information provided in the C & C Archaeological Assessment Report (C & C, 2007), no**
**kno wn shipwrecks and no archaeological avoidances exist within 2,000 ft of the proposed wellsite. The**  **2007 archaeological assessment noted 25 unidentified sonar contacts within the area. The most recent 2014 survey noted one target about 1,220 ft southwest of the proposed site (Sonar Contact #1, Map**  **VK 915-G-2). The object is not archaeologically significant and no avoidance has been placed on this**
**contact**

**The sonar targets within C & C’s AUV surveys are interpreted as a debris zone, broken pipe sections, unknown modern debris, a possible shipwreck site, and a known shipwreck with associated debris fields**  **(C & C, 2002, 2007, 2014).**

**Sonar Contact No. 4, from the 2007 report, is a possible shipwreck site located in the central portion of VK 915 about 2,460 ft northeast of the proposed wellsite. The sonar target is identified as having an oval**  **shape and acoustic signatures similar to known shipwreck sites (C & C, 2007). The BOEM examined the target with an ROV; however the investigation was inconclusive. The BOEM has designated a 1,000 ft**  **avoidance zone surrounding Sonar Contact No. 4.**

**Sonar Contact No. 8, from the 2002 survey, is a known shipwreck identified as the historic steam yacht**
Anona **(C & C, 2002, 2007). This wreck lies in the northwestern corner of VK 960 about 3.1 miles east southeast of the proposed wellsite. A 1,300 ft archaeological avoidance is assigned to this shipwreck.** 



### Wellsite Conditions

**A well (#SS004), pipeline, and umbilical occur within a few hundred feet of the proposed VK 915-G site.**
**Th e**  **se structures will need to be avoided by the new well emplacement. Geologically, the proposed location is clear of any constraining seafloor conditions as defined by the AUV and 3-D seismic datasets.**  **The proposed wellbore will likely penetrate interbedded sand layers within a faulted unit below 1,034 ft bml. The PXP #A001 well in VK 915 experienced a “moderate” shallow water flow that was believed to**  **originate from sands at 768 ft bml. This well was drilled in 1993. However, the existing nearby Freeport McMoRan #SS004 well, with four side-tracks completions, achieved depths of 7,905 to 10,954 ft (TVD).**  **These wells were drilled in 2002. No gas accumulations or shallow water flows were reported from these**
**wells. Proposed Wellsite VK 915-G Clearance Letter** 

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 5
FO RUM ENERGY TECHNOLOGIES, INC. Water Depth and Seafloor Conditions

**T he water depth at the proposed surface location is –3,562 ft (Map VK 915-G-1). The seafloor slopes to** 
**the s outh at 2.4°.** 

**The Proposed Wellsite, VK 915-G is situated within the Fuji Channel, a shallow buried channel-levee complex (Illustration G-1). The edge of the Fuji Channel lies about 1,700 ft southwest of the proposed**  **location (Illustration G-1). The seafloor at the proposed site is slightly irregular along the southwestern flank of the channel (Map G-2). AUV subbottom profiler data in the area indicate a surficial drape of soft,**  **high-water content silty clays covering the seafloor surrounding the proposed wellsite.**

Deepwater Benthic Communities

**T he Amplitude-Enhanced Seafloor Rendering (Map G-3) shows three areas of high-amplitude returns** 

**sou th, southwest, and west of the proposed location. These anomalous areas range from 950 ft to**  **2,020 ft from VK 915-G. The AUV subbottom profiler data identified near-surface zones of gas charged sediment in the vicinity of the amplitude events identified by the 3-D data set (C & C, 2002, 2007). The**  **zones of gas-charged sediments were buried by 5 ft to 30 ft of sediment. One small zone of gas-charged sediments identified on the subbottom profiler data appeared to extend up to the seabed. This small gas**  **charged zone roughly corresponds to the area of highest seafloor amplitude returns on the 3-D rendering (Map G-3). However, sonar and MBE backscatter showed minor variations in seafloor reflectivity within** 
**these areas.**

**The GEMS (2013) report placed a high-potential for high-density benthic communities in the areas of high-amplitude returns (Map G-3). These anomalies are within the 2,000 ft radius of the proposed**  **wellsite. Therefore, FMI commissioned C & C to conduct a Benthic Community Investigation (C & C, 2014). A survey using C & C’s C-Surveyor VI was conducted over the area of anomalous amplitudes**  **(Map G-3). The survey grid consisted of 87 northwest-southeast survey lines with 12-ft spacing. The AUV instruments included a high-resolution digital camera along with the standard multibeam (Kongsberg**  **EM2040), side-scan sonar (Edge Tech DF4500), and subbottom profiler (EdgeTech Chirp DW106).**

**The main area of high-amplitude south-southwest of the proposed location, corresponded to a zone of irregular seafloor with a lightened seafloor reflectivity and buried shallow gas zones on the subbottom**  **profiler. Camera images showed small pockmarks and undulations of less than 1 foot but no benthic communities were observed (C & C, 2014).** 

**Overall the 2014 survey showed a seafloor with low- to moderate-reflectivity indicative of fine grained sediments. A well-splay from the #SS 004 well was identified as a zone of contrasting sediment type with**  **distinct backscatter properties relative to the ambient sediment type. The splay had an east-west trend across the survey. No benthic communities were identified within the 2014 survey area.** 

**One sonar target (#1) was identified by the 2014 survey. The target was an object 2.1 ft long. 0.9 ft wide, and 0.2 ft high. Digital photographs showed this object was not archaeologically significant and may in**  **fact be a natural feature (C & C, 2014).**

Stratigraphy

**S tratigraphic conditions are shown on Illustrations G-1 and G-2. The surficial interval from the seafloor to** 
**220 ft bml, will likely consist of very soft silty clays overlying stratified, normally consolidated hemipelagic**  **and turbidite clays and silty clays (Illustration G-1). These shallow sediments should provide adequate foundation for bottom-founded structures.** 

**The seismic character of the interval between 220 ft and 424 ft bml indicates mud-rich turbidite deposits. These sediments were the last phase in the Fuji Channel deposition prior to burial by hemipelagic and**  **pelagic sediments.**

**The interval between 424 ft to 546 ft bml consists of chaotic channel fill sediments. The sediments will be a mixture of clay and silt with scattered layers and pockets of sand and silty sand.** **Proposed Wellsite VK 915-G Clearance Letter**

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 6
FO RUM ENERGY TECHNOLOGIES, INC. **The base of Unit 2 (546 ft to 1,034 ft bml) consists of continuous, moderate-amplitude reflectors overlying**  **semi-continuous to continuous, low-amplitude reflectors. The overall sequence likely represents stratified turbidites interlayered intercalated with thin mud-rich mass-transport deposits. Well logs from the**  **Freeport McMoRan #SS5 Well in VK 915 indicate a generally clay-rich unit with thin sand seams interspersed throughout the interval. An increase in sand thickness occurs near the base of the unit.** 

**Unit 3 (1034 ft to 2,065 ft bml) consists of low- to moderate-amplitude reflectors of varying continuity interlayered with units of low-amplitude, continuous, discontinuous, and chaotic reflections (Illustration G**  **2). This unit corresponds to a sand-prone, slope-fan sequence. Low-amplitude stratified reflectors within the unit likely represent hemipelagic clays and silts interlayered with clay-rich turbidite and mass-transport**  **deposits. The moderate-amplitude reflectors within this interval likely represent slope-fan and turbidite deposits. The well logs indicate thin sand seams interspersed throughout the slope-fan sequence with an**  **increase in sand layers in the lower portion of the unit.**

**Unit 4 (2,065 ft to 3,931 ft bml) consists of low-amplitude, continuous to semi-continuous reflectors interbedded with low-amplitude, chaotic reflectors. This sequence likely represents stratified turbidites**  **interlayered with thin mass-transport deposits. The MWD logs show a relatively clay-rich interval with intermittent thin sand seams throughout the unit.** 

Faults

**A seafloor fault will be penetrated by the proposed wellsite (Illustrations VK 915-G-1 through VK 915-G 2)** 

**. The fault intersection will be near the center of Unit 3 at about 1,344 ft bml. The fault intersects the**  **seafloor about 1,600 ft to the southwest of the proposed location (Map G-2). In addition, a vertical wellbore at the proposed location will intersect a buried fault at a depth of approximately 3,080 ft bml**  **(-6,642 ft bsl), Illustration VK 915-G-1. Engineers should be aware of the potential for lost circulation across fault planes.** 

**The base of the Fuji Channel will be intersected about 546 ft bml (Illustrations VK 915-G-1, VK 915-G-2). The interface is not a fault; however, there will be a significant change in sediment type and geotechnical**  **properties across this boundary.**

Shallow Gas

**The well path will not penetrate any interpreted high-amplitude events from the seafloor to the limit of**
**in v**  **estigation (3,931 ft bml), Map No. G-4 and Illustrations VK 915-G-1, VK 915-G-2.**

**A negligible potential for encountering shallow gas exists within the clay-prone units between the seafloor and Horizon 10 (220 ft bml).** 

**In general, there is a low potential for encountering shallow gas within the units below Horizon 10 (220 ft bml) to the limit of investigation (3,931 ft bml). A zone of slightly elevated amplitude returns occur** **in Unit 2 at about 750 ft bml (Illustrations VK 915-G-1, VK 915-G-2). This zone is about 250 ft, north northeast of the proposed VK 915-G wellsite. The nearby #SS4 well was drilled within 115 ft of the**  **elevated amplitude zone and did not report any problems with shallow gas at that level. Therefore, the proposed wellsite should have a lower potential for gas than the existing well at the 750 ft bml level.** 

Shallow Water Flow

**Based on the seismic character, the potential for sand-rich sediments is considered likely within the**
**cha nnel fill interval within Unit 2 (424-546 ft bml) (Illustrations VK 915-G-1, VK 915-G-2). Because of the**  **presence of sand, we assign a moderate potential for overpressures. Overall, the well conditions at the Proposed Wellsite VK 915-G appear to be similar to the nearby #SS4 Well. If sand was encountered, the**  **drilling practices employed for #SS4 well mitigated any overpressure. Therefore, we recommend examining the drilling methods employed at #SS4 and determine if they are applicable to the proposed**  **VK 915-G well.**

**There is a moderate potential for encountering shallow water flow within Unit 3 (1,034 ft to 2,065 ft bml), Illustrations VK 915-G-1, VK 915-G-2. Potentially thick and continuous sand deposits may exist within the** **Proposed Wellsite VK 915-G Clearance Letter**

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 7
FO RUM ENERGY TECHNOLOGIES, INC. **turb idite and slope-fan deposits within these units. The sands within this interval are the source for water**  **flow in wells within the Viosca Knoll Area; however, no wells within the Survey Area have reported shallow water flow conditions within this unit (BOEM, 2013b).** 

**A low potential for water flow exists within Unit 4 from Horizon 40 to the limit of investigation (2,065 ft to 3,931 ft bml), Illustrations VK 915-G-1, VK 915-G-2. Any sands encountered within the turbidite and**  **mass-transport deposits within these intervals are expected to be thin seams and not likely to produce sustained flows. There is a negligible potential for encountering shallow water flow within Unit 1 from the**  **seafloor to Horizon 10 (0 ft to 220 ft bml).**



### Results

**Based on the data and reports from the C & C geohazard, archaeological, and benthic community**

**as s**  **essments, and the GEMS geohazard assessment we conclude that no high-density deepwater benthic communities occur within 2,000 ft of the proposed VK 915-G wellsite. In addition, no potential submerged**  **cultural resources are within 2,000 ft of the Proposed Wellsite G in VK 915.**

**An existing production well, an active pipeline, and one umbilical exist within 250 ft of the Proposed Wellsite VK 915-G. Therefore, extreme care will need to be taken when installing bottom-founded**  **equipment.**

**The subsurface interpretation concluded a moderate potential for shallow water flow within the channel fill interval in the upper portion of Unit 2 (424 ft to 546 ft bml) and within the slope-fan sequence in Unit 3**  **(1,034 ft to 2,065 ft bml). The drilling practices executed in the nearby #SS4 Well successfully mitigated these sand-prone sections.** 



### Closing

**We appreciate the opportunity to be of service to Freeport-McMoRan Oil & Gas and look forward to**

**wor king with FMI on future projects.** 

**Sincerely,**

GEOSCIENCE EARTH & MARINE SERVICES

**Thomas W. Neurauter, Ph.D. Daniel Lanier**  **Senior Marine Geologist Director** 

**Attachments (4 Maps and 2 Figures)**

**Distribution: Mr. Kaare Egedahl, Freeport-McMoRan Oil & Gas, (6 copies)** 

REFERENCES

**BOEM (Bureau of Ocean Energy Management), 2011, Notice to lessees and operators (NTL) of federal oil and gas leases**

**an d**  **pipeline right-of-way (ROW) holders on the outer continental shelf (OCS), Revisions to the list of OCS lease blocks requiring archaeological resource surveys and reports: U. S. Department of the Interior, Bureau of Ocean Energy**  **Management, Bureau of Safety and Environmental Enforcement Gulf of Mexico Region (GOMR), NTL 2011-JOINT-G01. Effective Date December 29, 2011.** 

**Bureau of Ocean Energy Management, 2014a, Notice to lessees and operators of federal oil, gas, and sulphur leases in the outer continental shelf, Gulf of Mexico OCS region: Extension of prior notice to lessees, NTL 2014-G03.** 

**Bureau of Ocean Energy Management, 2014b, ASCII Data Files, published on the BOEM Gulf of Mexico Region Homepage, <http://www.gomr.boem.gov/homepg/pubinfo/freeasci/freedesc.html>, accessed May, 2014.** **Proposed Wellsite VK 915-G Clearance Letter**

**Freeport-McMoRan Oil & Gas //**  **July 16, 2014**

**Geoscience Earth & Marine Services** // 8
FO RUM ENERGY TECHNOLOGIES, INC. **Bureau of Ocean Energy Management, 2014c, Seismic Water Bottom Anomalies Map Gallery, published on the BOEM Gulf of**  **Mexico Region Homepage, <http://www.boem.gov/Oil-and-Gas-Energy-Program/Mapping-and-Data/Map Gallery/Seismic-Water-Bottom-Anomalies-Map-Gallery.aspx>, accessed May, 2014.** 

**C & C Technologies Survey Services, 2002, Geohazard assessment, block study, blocks 914, 915, 916, 959, and 960, Viosca Knoll Area, Project No.: 3042/3077. Report submitted to BP Exploration & Production Inc. in August, 2002.** 

**C & C Technologies Survey Services, 2007, Archaeological assessment report block 915 (OCS-G-06894) and vicinity, Viosca Knoll Area, Job No.: 072217. Report submitted to BP Exploration Inc., in April 2007.** 

**C & C Technologies, Inc., (C & C), 2014, Deepwater Benthic Community Investigation, Block 915 (OCS G-06894) Viosca Knoll Area, report No., 130909.** 

**Coffeen, J. A., 1978, Seismic Exploration Fundamentals: Tulsa, the Petroleum Publishing Co., p. 125.**

**Geoscience Earth & Marine Services, 2013, Geologic and Stratigraphic Assessment Block 915 (OCS G-06894) Viosca Knoll Area, Gulf of Mexico: report submitted to Plains Exploration & Production Company, August 5, 2013. GEMS Job No. 0413-**  **2236.**

**Minerals Management Service, 2005, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, Archaeological resource surveys and reports:**  **U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2005-G07.**

**Minerals Management Service, 2008a, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, information requirements for exploration plans**  **and development operations coordination documents: U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G04.** 

**Minerals Management Service, 2008b, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, shallow hazards requirements: U. S.**  **Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G05.**

**Minerals Management Service, 2010, Notice to lessees and operators of federal oil and gas leases in the outer continental shelf, Gulf of Mexico OCS region, deepwater benthic communities: U. S. Department of the Interior, Minerals Management**  **Service, Gulf of Mexico, NTL 2009-G40. Effective Date January 27, 2010.**

### Freeport

- McMoRan Oil & Gas LLC Section 4 – Pg. 9 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 4
HYDROGEN SULFIDE INFORMATION

4.1 CONCENTRATION
FM O&G ant icipates encountering 0 ppm H 2 

### S during the proposed operations.

4.2 CLASSIFICATION
In accordance with Title 30 CFR 250.490(c)

, FM O&G requests that the area of proposed operations be classified by the BOEM as H 2 

### S absent

.

### Freeport

- McMoRan Oil & Gas LLC Section 5 – Pg. 10 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 5 BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

5.1 DEEPWATER BENTHIC COMMUNITIES The seafloor disturbing activities proposed in this plan are in water depths greater than 300 meters (984’).

Geoscience Earth & Marine Services, Inc. was contracted to provide an assessment of the shallow conditions at the proposed surface locations. The purpose of this assessment was to address seafloor conditions that may impact exploratory drilling operations within 2,000 feet of the proposed well sites. FM O&G will avoid all high

density deepwater benthic communities by 2,000 feet from each proposed mu d and cuttings discharge location and 250 feet from the location of all other seafloor

disturbances.

C & C Technologies was contracted to conduct a deepwater Autonomous Underwater Vehicle (AUV) benthic community investigation within Vioscal Knoll Block 91 5. The purpose of this investigation was to locate any potential deepwater benthic

communities. There is n o evidence of high

- density deepwater benthic communities within the survey area. The C & C Technologies AUV benthic community investigation report is provided with this plan.

A s per NTL No. 2009

- G40, “Deepwater Benthic Communities,” a map showing the 2,000 foot radius around each 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

“N o Activity Z one ;” 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 BOTTOM S (PINNACLE TREND FEATURES)

Viosca Knoll Block 915 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.”

### Freeport

- McMoRan Oil & Gas LLC Section 5 – Pg. 11 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 5.5 LIVE BOTTOM S (LOW RELIEF)

Viosca Knoll Block 915 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 Viosca Knoll Block 915 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 Number 16 ; therefore, FM O&G will not be conducting any ROV surveys either pre

- spud or post

- drill operations per NTL No. 200 8- 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”).

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND
MARINE MAMMAL INFORMATION There are five (5) species of sea turtles that may be found in the Gulf of Mexico (see table below). NOAA fisheries currently list all five of these turtles as endangered (E) or threatened (T).

Species Scientific Name Statu s Potential Presence Critical Habitat Designated in

the Gulf of Mexico Lease
Area Coastal

Sea Turtles Loggerhead Carett a caretta T x x Texas, Louisiana, Mississippi,

Alabama,

Florida Green Chelonia mydas T,E x x None
Leatherback Dermochelys coriacea E x x None
Hawksbill Eretmochelys imbricata E x x None

Kemp’s Ridley Lepidochelys kempli E x x None

### Freeport

- McMoRan Oil & Gas LLC Section 5 – Pg. 12 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) In addition, there are 28 species of marine mammals that may be found in the Gulf of Mexico. The table provided below identifies the seven (7) species of marine mammals that are listed as endangered or threatened. Currently, there are no designated critical habitats for the listed species in the Gulf of Mexico Outer Continental Shelf; however, it is possible that one or more of these species could be seen in the area during operations.

Species S cientific Name Status Potential Presence Critical Habitat Designated in

the Gulf of Mexico Lease
Area C oastal

Marine Mammals Sperm Whale Physeter macrocephalus E x

-- None

Wes t Indian Manatee Trichechus manatus latirostris E

-- x Florida

Blue Whale Balaenoptera masculus E x

-- None

Fin Whale Balaenoptera physalus E x

-- None

Humpback Whale Megaptera novaeangliae E x

-- None

NorthAtlantic Right Whale Eubalaena glacialis E x

-- None

Sei Whale Balaenopiera borealis E x

-- None

There is one (1) species of fish that NOAA fisheries currently list as threatened (T) that may be found in the Gulf of Mexico. The Gulf sturgeon, also known as the Gulf of Mexico sturgeon, is an anadromous (breeding in freshwater after migrating up rivers from marine and estuarine environments) fish overwintering in estuaries, bays, and the Gulf of Mexico (see table below).

### Freeport

- McMoRan Oil & Gas LLC Section 5 – Pg. 13 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894)

Species Scientific Name Status Potential

Presence Critical

Habitat Designated

in the Gulf of

Mexico Lease

Area Coastal

Fish

Gulf S turgeon Acipenser oxyrinchus (=oxyrhynchus)

desotoi T X X None

5.9 ARCHAEOLOGICAL REPORT Based on the information provided in the C & C Technologies Archaeological Assessment Report (C & C Technologies, 2007), submitted with Plan Control No. R

4782, approved on February 1, 2008, no known shipwrecks and no archaeological avoidances exist within 2,000 feet of the locations proposed in this EP.

Viosca Knoll Block 915 has been determined to be located in an area where historic shipwrecks may exist. 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 n Archaeol ogical Survey Report was provided with Exploration Plan R

- 6011, approved March 21, 2014.

5.10 AIR AND WATER QUALITY INFORMATION Air and water quality information is not required to be included in this plan per NTL No.
2008

- G04, “Information requirements for Exploration Plans and Development Operations Coordination Documents” (Extended by NTL No. BOEM 2014

- G05

, “Extension of Prior Notices to Lessees” ).

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

- G04, “Information Requirements for Exploration P lans and Development Operations
Coordination Documents ” (Extended by NTL No. BOEM 2014

- G05, “Extension of Prior Notices to Lessees”).

## H ! . FM #SS4 (G06894)

FR

E E P OR

T ( S N

- 1 6 1 5 1 )

8

" B L K O

( A C T) F R E E P O

R T ( S N

- 1 6 1 5 2 )

1 2

" C S N G

( A C T ) F R E E P O R T ( S N -1 3 3 8 8 ) 4 " U B E H ( A C T )

F R EEP OR T (S N -1 3 8 8 4 ) 2 " U B EH (AC T ) F R

E

E

P

O

R

T

( S

N-

17

66

2)

4"

U

M

B (

A

C

T ) FREEPORT (SN-17658) 6" BLKO (ACT) 

### VK 915

OCS-G-06894 Freeport-McMoRan Oil & Gas LLC



### VK 914

Open

I N

L I N

E

1 2 0 5 0 C

R O

SS

L I N E

1 2 3 8



### - 3

4

0

0 - 3 3 0 0

- 3

60 0 - 3

7

0

0 - 3 4 0 0



### -3 6 0 0
- 3

5

0

0 Well F87°57'0"W87°57'30"W87°58'0"W 29°5'30"N

29°5'0"N

29°4'30"N1,330,0001,332,5001,335,000

10,552,500 10,555,000 10,557,500 10,560,000

3D SURVEY LINE.

EXISTING PIPELINE LOCATION, AS REPORTED BY BOEM. 

## H EXISTING WELL LOCATION, AS REPORTED BY BOEM. 

## ! . PROPOSED WELL LOCATION.

CIRCLE REPRESENTS 2000 FT RADIUS AROUND PROPOSED WELLSITE.

WATER DEPTH CONTOUR IN FEET. PROJECT NO.: 0614-2414 FILE NAME: 2414_WELL_F_1.MXD



### FREEPORT-MCMORAN OIL & GAS LLC

BATHYMETRY MAP

BLOCK 915 VIOSCA KNOLL AREA GULF OF MEXICO

MAP F-1 0 500 1000 1500 2000

1:12,000 SCALE 1 " = 1,000 ' OR

## H ! . FM #SS4 (G06894)

FR

E E P OR

T ( S N

- 1 6 1 5 1 )

8

" B L K O

( A C T) F R E E P O

R T ( S N

- 1 6 1 5 2 )

1 2

" C S N G

( A C T ) F R E E P O R T ( S N -1 3 3 8 8 ) 4 " U B E H ( A C T )

F R EEP OR T (S N -1 3 8 8 4 ) 2 " U B EH (AC T ) F R

E

E

P

O

R

T

( S

N-

17

66

2)

4"

U

M

B (

A

C

T ) FREEPORT (SN-17658) 6" BLKO (ACT) 

### VK 915

OCS-G-06894 Freeport-McMoRan Oil & Gas LLC



### VK 914

Open

I N

L I N

E

1 2 0 6 0 C

R O

SS

L I N E

1 2 3 7



### - 3

4

0

0 - 3 3 0 0

- 3

60 0 -3 7

0

0 - 3 4 0 0



### -3 6 0 0
- 3

5

0

0 Well G87°57'0"W87°57'30"W87°58'0"W 29°5'30"N

29°5'0"N

29°4'30"N1,330,0001,332,5001,335,000

10,552,500 10,555,000 10,557,500 10,560,000

3D SURVEY LINE.

EXISTING PIPELINE LOCATION, AS REPORTED BY BOEM. 

## H EXISTING WELL LOCATION, AS REPORTED BY BOEM. 

## ! . PROPOSED WELL LOCATION.

CIRCLE REPRESENTS 2000 FT RADIUS AROUND PROPOSED WELLSITE.

WATER DEPTH CONTOUR IN FEET. PROJECT NO.: 0614-2414 FILE NAME: 2414_WELL_G_1.MXD



### FREEPORT-MCMORAN OIL & GAS LLC

BATHYMETRY MAP

BLOCK 915 VIOSCA KNOLL AREA GULF OF MEXICO

MAP G-1 0 500 1000 1500 2000

1:12,000 SCALE 1 " = 1,000 ' OR

### Freeport

- McMoRan Oil & Gas LLC Section 6 – Pg. 14 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## 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

Mod eling reports are not required for the activities proposed in this plan.475 BBLS/WELL 5 BBLS/DAY/WELL TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM
Projected Downhole Disposal Projected generated waste Projected ocean discharges

Type of Waste Composition Projected Amount Discharge Rate Discharge Method

Cuttings wetted with water-based fluid Cuttings coated while drilling with WBM 2,197 BBLS/WELL 366 BBLS/DAY/WELL Discharged to mudline prior to riser installation. Based on 6 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 BBLS/WELL 5,833 BBLS/DAY/WELL Discharge at the mudline prior to the riser installation. Nominal amount of unused fluid may be discharged at the surface. Based on 8 days of drilling with WBM. No

333

833 Will humans be there? If yes, expect conventional waste

15,010 BBLS/WELL 158 BBLS/DAY/WELL USCG approved MSD with chlorination Cuttings wetted with synthetic-based fluid Cuttings coated with synthetic drilling fluids, including drilled out cement 2,841 BBLS/WELL 130 BBLS/DAY/WELL Discharged to surface. Treated cutting will be discharged overboard during drilling of the SBM intervals. Discharge rate is based upon 22 days of drilling. Cuttings will be processed through a cuttings dryer, substantially reducing the ROC percentage. No

Domestic waste

Sanitary Gray water from living quarters 32,870 BBLS/ WELL 346 BBLS/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

57,550 BBLS/WELL 11,510 BBLS/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, CaBr 2 , CaCl 2

N/A
Will you be covered by an individual or general NPDES permit? General NPDES Permit No. GMC290534 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 56,273,200 BBLS/WELL 592,349 BBLS/DAY/WELL Hull discharge overboard No No

No

No

Rejected water from the watermaker. 143,450 BBLS/WELL 1,510 BBLS/DAY/WELL Hull discharge overboard No

Hull discharge overboard. Based upon 5 major ballast operations, with rig at operating draft minimal ballast change is required No 833 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

Overboard upon samples passing the Static Sheen Test per Region 6 GOM GMG 290000 regulations Brines, NaCl, KCl, CaBr 2 , CaCl 2

Brines, NaCl, KCl, CaBr 2 , CaCl 2 2,000

5,000

5,000

Sea Water with no additional chemicals 3,040 BBLS/WELL 32 BBLS/DAY/WELL Hull discharge overboard No Cement Slurry 695 BBLS/WELL 347.5 BBLS/DAY/WELL Discharge at seafloor during riserless operations. Dicharge rate based upon 2 days (28" & 22" cement returns) No N/A N/A N/A N/A No Potable Water with 4% Stack-Magic ECO-Fv2 95 BBLS/WELL 1 BBLS/DAY/WELL Discharge at the seafloor or with deck drainage when tested

at surface No

Uncontaminated seawater used to maintainproper draft

### Freeport

- McMoRan Oil & Gas LLC Section 7 – Pg. 15 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## 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 = 3400D 2/3 

### 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 H 2 

### S at concentrations greater than 20 parts per million (ppm)? X

Do you propose to flare or vent natural gas for more than 48 continuous hours from any proposed well? X

Do you propose to burn produced hydrocarbon liquids? X

7.2 SUMMARY INFORMATION

Included as Attachment 7 -A are Air Emission Worksheets which show the emissions calculations for the Plan Emissions and if different, a set of worksheets showing the emissions calculations for the Complex Total emissions.

This information was calculated by: Jean Martin (281) 698

- 8544 jean.martin @jccteam.comEXPLORATION 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 Viosca Knoll
BLOCK 915
LEASE OCS-G 06894
PLATFORM NA
WELL Loc. F & G

COMPANY CONTACT Jean Martin
TELEPHONE NO. 281-698-8544

REMARKS FM O&G will use a drillship similar to the Transocean Deepwater Champion (DWC). Total horsepower is calculated at 82% of actual horsepower of DWC (Total horsepower = 60,348 hp). Actual fuel usage calculated using highest monthly average in 6 month fuel usage data for DWC.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 % weightEMISSIONS 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 & Viosca Knoll 915 OCS-G 06894 NA Loc. F & G 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 49486 2390.1738 14186.00 24 200 34.88 160.01 1199.00 35.97 261.60 20.70 94.97 711.62 21.35 155.26 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) 7240 349.692 8392.61 12 86 5.10 23.41 175.42 5.26 38.27 2.62 12.04 90.22 2.71 19.68 VESSELS>600hp diesel(supply) 9245 446.5335 10716.80 24 86 6.52 29.89 224.00 6.72 48.87 6.70 30.75 230.40 6.91 50.27 VESSELS>600hp diesel(supply) 9245 446.5335 10716.80 24 86 6.52 29.89 224.00 6.72 48.87 6.70 30.75 230.40 6.91 50.27 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

2016 YEAR TOTAL 53.02 243.33 1837.29 67.23 478.56 36.73 168.51 1262.99 38.18 277.43

EXEMPTION
CALCULATION DISTANCE FROM LAND IN
MILES 2191.14 2191.14 2191.14 2191.14 55415.28
65.8SUMMARY



### 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 Viosca Knoll 915 OCS-G 06894 NA Loc. F & G
Emitted Substance

Year

PM SOx NOx VOC CO

2016 36.73 168.51 1262.99 38.18 277.43
Allowable 2191.14 2191.14 2191.14 2191.14 55415.28Day 1 2 3 4 5 6

1 11,174 gal 16,299 gal 11,042 gal 17,594 gal 13,605 gal 17,383 gal

2 14,133 gal 8,321 gal 11,095 gal 20,843 gal 12,786 gal 20,658 gal

3 17,409 gal 13,816 gal 11,941 gal 15,296 gal 8,612 gal 14,318 gal

4 5,733 gal 12,073 gal 14,529 gal 14,292 gal 12,231 gal 22,032 gal

5 34,818 gal 13,658 gal 11,359 gal 23,353 gal 12,231 gal 12,443 gal

6 16,775 gal 11,386 gal 9,510 gal 31,886 gal 12,469 gal 20,658 gal

7 14,662 gal 12,865 gal 10,223 gal 10,725 gal 13,103 gal 11,016 gal

8 16,167 gal 17,726 gal 11,016 gal 12,495 gal 11,174 gal 15,824 gal

9 14,133 gal 18,043 gal 10,567 gal 14,741 gal 14,556 gal 10,699 gal

10 12,046 gal 13,209 gal 10,514 gal 12,627 gal 18,017 gal 6,789 gal

11 12,733 gal 14,952 gal 13,182 gal 12,760 gal 17,752 gal 11,280 gal

12 12,812 gal 9,880 gal 10,567 gal 12,390 gal 13,895 gal 12,944 gal

13 15,190 gal 23,141 gal 10,752 gal 10,857 gal 12,046 gal 9,722 gal

14 14,001 gal 9,801 gal 11,359 gal 9,695 gal 11,412 gal 13,763 gal

15 10,223 gal 7,819 gal 10,910 gal 8,638 gal 12,073 gal 16,114 gal

16 7,661 gal 5,072 gal 11,069 gal 12,575 gal 10,039 gal 14,080 gal

17 14,635 gal 10,540 gal 12,786 gal 12,099 gal 14,397 gal 15,613 gal

18 11,650 gal 14,107 gal 10,884 gal 7,661 gal 13,314 gal 15,771 gal

19 15,005 gal 18,334 gal 15,692 gal 9,537 gal 14,080 gal 15,401 gal

20 14,899 gal 14,450 gal 7,899 gal 9,827 gal 11,650 gal 14,160 gal

21 13,473 gal 12,495 gal 10,646 gal 18,386 gal 11,967 gal 10,620 gal

22 12,575 gal 19,364 gal 8,189 gal 11,095 gal 14,979 gal 18,439 gal

23 10,778 gal 16,854 gal 11,174 gal 10,778 gal 13,552 gal 15,375 gal

24 10,857 gal 6,234 gal 9,642 gal 10,250 gal 10,725 gal 18,862 gal

25 12,786 gal 12,944 gal 12,443 gal 16,009 gal 10,250 gal 14,477 gal

26 10,805 gal 8,586 gal 11,069 gal 12,786 gal 12,944 gal 10,963 gal

27 12,469 gal 12,760 gal 14,899 gal 12,284 gal 9,589 gal 11,597 gal

28 11,148 gal 14,556 gal 10,673 gal 12,231 gal 11,016 gal 12,125 gal

29 13,684 gal 9,193 gal 9,827 gal 11,148 gal 11,359 gal

30 13,552 gal 13,869 gal 15,375 gal 14,688 gal 11,307 gal

31 13,499 gal 15,507 gal 13,763 gal
Average 13,596 gal 12,734 gal 11,290 gal 13,691 gal 12,677 gal 14,179 gal

Transit Days 

## Daily Fuel Usage for a 6 month period

Month

### Freeport

- McMoRan Oil & Gas LLC Section 8 – Pg. 16 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## 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 Freeport

McMoRan Oil & Gas LLC (FM O&G) Oil Spill Response Plan (OSRP) filed by Freeport

McMoRan Oil & Gas LLC (Operator N o. 03280 ) dated January 10, 2014, revised on January 31, 2014, and approved on February 4, 2014 (OSRP Control N o. O- 713 ).

8.2 SPILL RESPONSE SITES Primary Response Equipment Location Preplanned Staging Location

Houma, LA Harvey, LA Venice, LA Houma, LA Harvey, LA Venice, LA

8.3 OSRO INFORMATION
FM O&G’s primary equipment provider s are Clean Gulf Associates (CGA), Marine Spill Response Corporation (MSRC) and National Response Corporation (NRCC). Clean Gulf Associates Services, LCC (DGAS) 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.

### Freeport

- McMoRan Oil & Gas LLC Section 8 – Pg. 17 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 8.4 WORST CASE SCENARIO DETERMINATION

Category Regional OSRP WCD

- Drilling EP WCD

- Drilling

Type of Activity > 10 

### Mile s Drilling > 10 

### Mile s Drilling

Facility Location (Area/Block) GC 393 VK 915

Facility Designation Well Location B Well Location A

Distance to Nearest Shoreline (miles) 96.5 mi 65.8 mi

Volume

• Storage Tanks (Total)

• Uncontrolled blowout Total Volume 400,000 bbls 182,478 bbls Type of Oil(s) (crude, condensate, diesel) Crude Crude

API Gravity 25 o 

### 35.4 o



### The WCD calculations and assumptions for the Regional OSRP WCD, GC 393 W ell

Locati o n B (400,000) were previously accepted under Plan Control No. N

- 9739. The WCD calculations and assumptions for the EP WCD, VK 915 Well Location A (182, 478) were previously accepted under Plan Control No. R

- 6011.

Since FM O&G has the capability to respond to the worst

- case spill scenario included in our Regional OSRP dated January 10, 2014, revised on January 31, 2014, and approved on February 4, 2014 (OSRP Control N o. O- 713) , and since the worst -case scenario determined for our EP does not replace the worst

- case scenario in our Regional OSRP, FM O&G hereby certifies that FM O&G 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 Discus sion is included as Attachment 8- A.

### SPILL RESPONSE DISCUSSION

For the purpose of NEPA and Coastal Zone Management Act analysis, the largest spill volume originating from the proposed activity would be a well blowout during drilling operations

, estimated to be 182,478 barrels of crude oil wi th an A PI gravity of 35.4°.

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 BSEE Oil Spill Risk Analysis Model (OSRAM) for the Central an d
Western Gulf of Mexico available on the BSEE website . Th e results are shown in Fi gure 1. The
BSEE OSRAM identifies a 17 % probability of impact to the shorelines of Plaquemines Parish,
Louisiana within 30 days. Plaquemines Parish includes Barataria Bay, the Mississippi River Delta, Breton Sound and the affiliated islands and bays. This region is an extremely sensitive habitat and serves as a migratory, breeding, feeding and nursery habitat for numerous species of wildlife. Beaches in this area vary in grain particle size and can be classified as fine sand, s hell or perched shell beaches. Sandy and muddy tidal flats are also abundant.

Response

PXP will make every effort to respond to the Worst Case Discharge as effectively as p racticable

. 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 da tabase. The results indicate 17 % or approximately 31,021 barrels of crude oil would be evaporated/dispersed within 24 hours, with approximately 151,457 barrels remaining.

Spill Response VK 915, Well Location A Barrels of Oil

WCD Volume 182,478

Les s 17 % natural evaporation/dispersion 31,021
Remaining volume 151,457



### 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.

PXP ’s Oil Spill Respons e Plan includes alternative response technologies such as dispersants and
in

- situ burn. Strategies will be decided by Unified Command based on the size of the spill, weather and potential impacts. If aerial disper sants are utilized, 8 sorties (9 ,6 00 gallo ns) 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. S lick containment boom would be immediately called out and on

- scene as soon as possible. Offshore response strategies may include attempting to skim utilizing the HOSS Barge, nine Fast Resp onse Units (FRUs), six sets of Koseq skimming arms, and two sets of Aqua Guard Triton RBS skimmers , with a total derated skimming capacity of 353,793 barrels. Temporary storage associated with skimming equipment equals 79,692 barrels. If additional storage is needed, several storage barge s may be mobilized and centrally located to provide a total of 337,833 barrels of temporary storage allowing the skimmers to stay in the area of operations as much as possible

. Safety is first priority. Air monitoring will be accomplished and operations deemed safe prior to any containment/skimming attempts.

If the spill went unabated, shoreline impact in Plaquemines Parish , Louisiana would depend upon existing environmental conditions. Shoreline protection would include the use of CGA’s near shore and shallow water skimmers with a totaled derated skimming capacity of 100,606 barrels. Temporary storage associated with skimming equipment equals 1,314 barrels. If additional storage is needed, several storage barge s may be m obilized and centrally located to provide a total of 116,000 barrels of temporary storage allowing the skimmers to stay in the area of operations as much as possible. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. Master Service Agreements with AMPOL and OMI Environmental will ensure access to 147,000 feet of 18” shoreline protection boom

. Figure 2 outlines individual times needed for procurement, load out,
travel time to the site and deployment. Strategies would be based upon surveillance and real time trajectories that depict areas of potential impact given actual sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan for Plaquemines Parish and Un ified 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. PXP ’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, PXP 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 76 hours (based on the equipment’s Effective Daily Recover y Capacity (EDRC)).

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

are not limited to:

• Weather

• Equipment and materials availability

• Ocean currents and tides

• Location of the spill

• Product spilled

• Amount spilled

• Environmental risk assessments

• Trajectory and product analysis

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

PXP will take action to provide a safe, aggressive response to contain and recover as much of the spill ed 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 possib le. 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 gro up 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 w ill be made and initial objectives set

• OSROs and appropriate agencies will be notified

• ICS 201, Initial Report Form will be completed

• Initial Safety plan will be written and published

• Unified Command will be established

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

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

o On -site command and control established

### Decanting Strategy Recovered oil and water mixtures will typically separate into distinct phases when left in a quiescent state. When separation occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases
the effective on

- sit e oil storage capacity and equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill

recovery.

Offshore Response Actions

Equipment Deployment
Surveillance

• Surveillance Airc raft will be deployed within two hours of Q ualified Individual (QI) notification, or at first light

• Provide trained observer to provide on site status reports

• Provide command and control platform at the site if needed

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

• Continual monitoring of vessel assets using vessel monitoring systems

Dispersant application assets

• Put Airborne Support I nc. (ASI) on standby

• With the Federal On -Scene Coordinator ( FOSC ), conduct analysis to determine appropriateness of dispersant application

• Gain FOSC approval for use of dispersants on the surface

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

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

• Confirm dispersant availability for current and long range operations

• Start ordering dispersant stocks required for expected operations

Containment boom

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

• Ensure boom handling and mooring equipment is deployed with boom

• Provide continuing reports to vessels to expedite their arrival at sites that will provide for
their most effective containment

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

Dedicated off- shore skimming systems
General

• Deployed to the highest concentration of oil

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

### CGA HOSS Barge

• Use in areas with heaviest oil concentrations

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

CGA FRUs

• To the area of the thickest oil

• Use as far off

- shore as allowed

• VOOs 140’ – 180’ in length

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

• VOOs in shallow water sho uld have a draft of <10 feet when fully loaded

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

T&T Koseq Skimming Systems

• To the area of the thickest oil

• Use as far off

- shore as allowed

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

• VOOs at least 200’ i n length

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

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

Storage Vessels

• Establish availability of CGA contracted assets

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

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

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

### Vessels of Opportunity (VO O)

• Use PXP ’s contracted resources as applicable

• Industry vessels are usually best for deployment of Vessel of Opportunity Skimming Systems (VOSS)

• Acquire additional resources as needed

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

• Expect mission specific and safety training to be required

• Plan with the US Coast Guard for vessel inspections

In -situ Burn assets

• Determine appropriateness of in -situ burn operation in coordination with the FOSC and
affected State On -Scene Coordinator (SOSC)

• Det ermine availability of fire boom and selected ignition systems

• Start ordering fire boom stocks required for expected operations

• Contact boom manufacturer to provide training if required

• Determine assets to perform on water operation

• Build operations into s afety plan

• Conduct operations in accordance with an approved plan

Adverse Weather Operations:

In adverse weather, when seas are > 3 feet, the use of larger recovery and storage vessels, oleophilic skimmers, and large offshore boom will be maximized. Safety will be the overriding factor in all operations and will cease at the order of the Unified Command, vessel captain, or in

an emergency, ”stop work” may be directed by any crew member.

### Near Shore Response Actions

Timing

• P lace near shore assets on stan dby and deploy in accordance with planning based on the actual situation, actual trajectories and oil budgets

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

• Outfitting of VOOs for specific missions

• Deployment of assets ba sed 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

• Contin ual surveillance of oil movement by remote sensing systems, aerial photography
and visual confirmation

• Continual monitoring of vessel assets

Dispersant Use

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

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

Vessel Deployment Dedicated Near Shore skimming systems

• F ast Response V essel s (FRV)

• Egmopol and Marco S hallow Water Skimmer (SWS)

• Operate with aerial spotter directing systems to observed oil slicks

VOO

• Use PXP ’s contracted resources as applicable

• Industry vessels are usually best for deployment of Vessel of Opportunity Skimming Systems (VOSS)

• Acquire additional resources as needed

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

• Expect mission specific and safety training to be required

• Plan with the US Coast Guard for vessel inspections

• Operate with aerial spotter directing systems to oil patches

### Shoreline Protection Operations

Response Planning Considerations

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

• Time to acquire personnel and equipment and their availability

• Previous contingency planning contained in the appropriate Area Contingency Plan, and currently for Louisiana, The State of Lou isiana 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 wher e 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 ti d e lines to minimize waste

• Staging of equipment and housing of response personnel as close to the job site as possible to maximize on

- site work time

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

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

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

• Passive clean up of marshes should be considered and appropriate stocks of sorbent boom and/or sweep obtained

• Earthen berms and shoreline protection boom may be considered to protect sensitive
inland areas

### Decanting Strategy Recovered oil and water mixtures will typically separate into distinct phases when left in a quiescent state. When separation occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases
the effective on

- site oil storage capacity and equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill

recovery.

CGA Equipment Limitations The capability for any spill response equipment, whet her 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 Co nditions 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 activi ty 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

ca tegories 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 i s 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 PXP ’s WCD and information in the BSEE Oil Spill Risk Analysis Model (OSRAM) for the Cen tral and Western Gulf of Mexico available on the BSEE 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 and
install subsea trees on 2 wells

VK 915,
Well Location A

65.8 miles from shore G06894 C55 Terrebonne, LA Lafourche, LA Plaquemines, LA

St. Bernard, LA Hancock & Harrison, MS Jackson, MS Mobile, AL Baldwin, AL Escambia, FL Okaloosa, FL

Walton, FL

Bay, FL Gulf, FL
Fr anklin, FL 1
1
17
7
2
2
2
3
2
1
1
2
1
1

### WCD Scenario

– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (65.8 miles from shore) 151,457 bbls of crude oil (Volume considering natural weathering)
API Gravity 35.4°
FIGURE 2

– Equipment Response Time to VK 915, Well Location A

Dispersants/Surveillance

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

ASI

Basler 67T 2000 NA 2 Houma 1 1 0.9 2.9

DC 3 1200 NA 2 Houma 1 1 1.1 3.1

DC 3 1200 NA 2 Houma 1 1 1.1 3.1

Aero Commander NA NA 2 Houma 1 1 0.9 2.9

Offshore Response
Offshore Equipment No Staging EDRC Storage Capacity VOO Persons Required From Hrs to
Procure Hrs to
Loadout Hrs to
GOM Travel to Spill Site Hrs to
D eploy Total
Hrs

CGA
HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 11.3 1 24.3 Boom Barge (CGA

- 300) 42” Auto Boom (25000’) NA NA 1 Tug
50 Crew 4 (Barge) 2 (Per Crew) Leeville 4 0 6 20 1.5 31.5

T&T Marine (available through contract with CGA)
Koseq Skimmi ng Arms ( 4 ) 71316 8000 4 Utility 24 Galliano 24 24 2 11.7 2 63.7
Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey 24 24 2 7.5 2 59.5

NRCC OSRV Energy (Marco Class XI AB) 24000 300 NA 6 Morgan City 4 2 0 17.5 1 24.5

OSRV Admiral (Marco Class XI AB ) 24000 300 NA 6 Galveston 4 2 0 34.2 1 41.2

OSRB Defender (Marco Class XI AB) 24000 16500 1 Tug 6 Bayou La
Batre 4 2 0 10 1 17

OSRB Valiant (Marco Class XI AB) 24000 20892 1 Tug 6 Aransas Pass 4 2 0 68.75 1 75.75

OSRB Valor (Marco Class XI AB) 24000 19 000 1 Tug 6 Tampa 4 2 0 42.5 1 49.5Recovered Oil Storage No 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

K- Sea Operating (available through contract with CGA)

PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 2 11.25 1 30.25

DBL 76 1212984 NA 83937 1 Tug 6 Venice 4 12 2 11.25 1 30.25

DBL 81 1132231 NA 86948 1 Tug 6 Venice 4 12 2 11.25 1 30.25

DBL 82 1137538 NA 86948 1 Tug 6 Venice 4 12 2 11.25 1 30.25

Sta ging Area: Venice

Offshore Equipment With 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 contract with CGA)
Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 8 7.5 2 33.5

CGA
FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 8 7.5 1 19.5
FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 1 2 1.75 7.5 1 13.3
FRU (1) + 100 bbl Tank (2) 4251 200 1 Util ity 6 Ingleside 1 2 11 7.5 1 22.5
FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 5.5 7.5 1 17
FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 3.5 7.5 1 15
FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 3. 25 7.5 1 14.8
FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 7.5 1 11.5
Hydro

- Fire Boom NA NA 8 Utility 40 Harvey 1 4 1.75 7.5 6 20.3Nearshore Response Nearshore Equipment No Staging EDRC Storage Capa city VOO Persons Required From Hrs t o Procure Hrs to
Loadout Hrs to
GOM Travel to Spill Site Hrs to Deploy Total
Hrs

CGA

46’ FRV 5000 65 NA 4 Morgan City 1 0 2 4.8 0 7.8

46’ FRV 5000 65 NA 4 Venice 1 0 1 2 0 4

95 ’ FRV 12342 249 NA 4 Venice 1 0 1 2 0 4
Trinity SWS 21500 249 NA 4 Leeville 1 2 2 3 0 8
Trinity SWS 21500 249 NA 4 Morgan City 1 2 2 4.8 0 9.8
Trinity SWS 21500 249 NA 4 Venice 1 2 2 2 0 7 Enterprise Marine Services LLC (available through contract with CGA)

CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 14.38 1 35.38

CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 14.38 1 35.38

CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 14.38 1 35.38

CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 14.38 1 35.38

Staging Area: Venice

Nearshore and Inland Skimmers With Staging EDRC Storage Capacity VOO Persons
Re q. From Hrs to
Procure Hrs to
Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total
Hrs

CGA

SWS Egmopol 3000 100 NA 3 Morgan City 1 2 3.25 2 0 8.25

SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 2 0 10.5

SWS Marco 3588 34 NA 3 Leeville 1 2 3 .5 2 0 8.5

SWS Marco 3588 34 NA 3 Venice 1 2 0 2 0 5Shoreline Protection Staging Area: Venice

Shoreline Protection
Boom VOO Persons Req. Storage/Warehouse
Location Hrs to
Procure Hrs to
Loadout Travel to Staging Travel to Deployment Site Hrs to Deploy Total Hrs

AMPOL (available through MSA)

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 4 2 12 22

20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2 2 6 14
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 7.5 2 3 14.5

10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 6.25 2 3 13.25

20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.75 2 6 11.75

10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 3.5 2 3 10.5

10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.5 2 3 10.5

15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2 2 4 12

Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to
Procure Hrs to
Loadout Travel to Staging Travel to Deployment Hrs to Deploy T otal
Hrs

CGA
Wildlife Support Trailer NA NA NA 2 Houma 1 2 3 1 2 9

Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 1.5 1 2 7.5

Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 1 2 14

Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 1 2 9

Bird Scare Guns ( 12) NA NA NA 2 Ingleside 1 2 11 1 2 17

Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 1 2 11.5

Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 1 2 10

Response Asset Total

Offshore EDRC 353,793

Offshore Recovered Oil Storage 416,525

Nearshore / Shallow Water EDRC 100,606

Nearshore / Shallow Water Recovered Oil Storage 117,314

### Freeport

- McMoRan Oil & Gas LLC Section 9 – Pg. 18 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 9
ENVIRONMENTAL MONITORING INFORMATION

9.1 MONITORING SYSTEMS
FM O&G will monitor loop currents per the requirements as set forth in NTL No. 

### 2009

- G02 , “Ocean Current Monitoring ” (Extended by NTL No. 2014

- G05, “Extension of Prior Notices to Lessees” ).

9.2 INCID ENTAL TAKES There is no reason to believe that any of the endangered species or marine mammal s 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 av oid 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

Viosca Knoll Block 915 is n ot located in the Flower Garden Banks National Marine Sanctuary; therefore, relevant information is not required in this EP.

### Freeport

- McMoRan Oil & Gas LLC Section 1 0 – Pg. 19 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 10
LEASE STIPULATIONS INFORMATION

Exploration activities are subject to the following stipulations attached to Lease OCS

- G

06894

, Viosca Knoll Block 915

.

10.1 MILITARY WARNING AREA (MWA)

Viosca Knoll Block 915 is located within designated MWA -W- 155B

. The NAS in Pensacola, Florida was contacted on May 29, 2014 in order to coordinate and control the electromagnetic emissions and use of vessels an d aircraft during the proposed operations.

10.2 MARINE PROTECTED SPECIES

In accordance with t he Federal Endangered Species Act and the Marine Mammal

Protection Act

, FM O&G will:

(a) collect and remove flotsam resulting from activities related to explorat ion, 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 equipm ent to be used only by personnel trained in less

- intrusive cleanup techniques on beaches and bay shores; and

### Freeport

- McMoRan Oil & Gas LLC Section 10 – Pg. 20 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) (f) immediately report all sightings and locations of injured or dead protected species (e.g., marine mammals and sea turtles) to the appropriate stranding network. If oil and gas industry activity is responsible for the injured or dead animal (e.g., because of a vessel strike), the responsible parties should remain available to assist the stranding network. If the injury or death was caused by a collision with the lessee’s vessel, the lessee must notify BOEM within 24 hours of the strike.

BOEM and BSEE issue Notices to Lessees (NTLs), which more fully describe measures implemented in support of the above

- mentioned implementing statutes and regulations, as well 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 subcontract ors, 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

- G0 2, “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.

10.3 CULTURAL RESOURCES

Viosca Knoll Block 915 ha s been determined to be located in an area where cultural resources may exist.

Based on the information provided in the C&C Technologies Archaeological Assessment Report (C&C Technologies, 2007) submitted with Plan Control No. R

- 4782, approved on Februar y 1, 2008, no known shipwrecks and no archaeological avoidances exist within 2,000 feet of the locations proposed in this EP.

.If FM O&G discovers any cultural resource while conducting operations on the lease area, the discovery will be immediately reported to the BOEM GOMR Regional Manager. FM O&G will make every reasonable effort to preserve the cultural resource until the Regional Manager has told FM O&G how to protect the resource.

### Freeport

- McMoRan Oil & Gas LLC Section 1 1 – Pg. 21 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 11
ENVIRONMENTAL MITIGATION MEASURES INFORMATION

11.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS

Viosca Knoll Block 915 is not lo cated within Florida; therefore, mitigation information is not required for the activities proposed in this plan

.

11.2 INCIDENTAL TAKES
FM O&G wi ll 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 1 2 – Pg. 22 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 12
SUPPORT VESSELS AND AIRCRAFT INFORMATION

12.1 GENERAL The most practical, direct route from the shore base as permitted by weather and traffic

conditions will be utilized.

Type Maximum Fuel Tank Capacit y Maximum Number in Area at Any Time Trip Frequency or Duration

Crew Boat 1,800 bbls 1 3/week Supply Boat 9,0 00 bbls 1 3/week Supply Boat 5,800 bbls 1 3/week Helicopter 760 gals 1 2/day

12.2 DIESEL OIL SUPPLY VESSELS

Size of Fuel Supply Vessel Capacity of Fuel Supply Vessel Frequency of Fuel Transfers Route Fuel Supply Vessel Will Take 265 ft 9,000 bbls 2/week Shortest route from Shore base to block 312 ft 5,800 bbls 2/week Shortest route from Shore base 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 betwe en the onshore support facilities and t he wells i s included as Attachment 12

- B.

## 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

Synthetic-based drilling fluid

Cuttings wetted with Water-based fluid Recycled

N/A N/A

SBM Cuttings Boxes on Supply Boat Newpark Enviromental Services

145 17th St
Port Fourchon, LA 1,000 BBLS/Well Will drilling occur? If yes, fill in the muds and cuttings. Composition Projected Generated

Wastes

Oil-based drilling fluid or mud N/A N/A N/A N/A Water-based drilling fluid or mud Water-based (seawater, fresh water, barite) 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 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 LBS/WELL Recycled if possible, transported to

landfill otherwise

Used Engine Oil Proper DOT containers on supply boat Univar
Carencro, LA 215 BBLS/WELL Cuttings coated with synthetic drilling

fluids, including drilled out cement

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 Cuttings Boxes on Supply Boat Newpark Enviromental Services

145 17th St
Port Fourchon, LA N/A N/A

2,841 BBLS/Well

N/A N/A

Recycled

N/A

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 wastesFLORIDA MIDDLEGROUNDLundHendersonLloyd RidgeWalker RidgeDestin DomeAtwater ValleyGreen CanyonDe Soto CanyonMississippi CanyonFlorida PlainThe ElbowVernon BasinApalachicolaHowell HookPort Fourchon A p p r o x

. 1 7 0

. 4 m i l e s

to a i r cr a f t sh o r e b a s e

A p p r o x . 1 3 7

. 7 m i l e s

t

o S h o r e B a s e A p p r o x

. 7 8

. 2 m i l e s

t o A l a b a m a S h o reApprox. 65.8 milesto ShoreLouisianaFloridaMississippiAlabamaGeorgiaHoumaVICINITY MAPBLOCK 915OCS-G 06894VIOSCA KNOLL AREAGULF OF MEXICOATTACHMENT A0 25 50 75 10012.5MilesVK 915

### Freeport

- McMoRan Oil & Gas LLC Section 1 3 – Pg. 23 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 13
ONSHORE SUPPORT FACILITIES INFORMATION

13.1 GENERAL

A listing of the onshore facilities that will be used to provide supply and service supp ort 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

- Swaco Mud Plants Fourchon, Louisiana Existing Petroleum Helicopters, Inc. Houma, Louisiana Existing

13.2 SUPPORT BASE CONSTRUCTION OR EXPANSION There will be no new construction of an onshore support base, nor will we expand the existing shore base as a result of the operations proposed in this EP

.

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE

A support base construction or expansion timetable is not required for the activities proposed in this plan

.

13.4 WASTE DISPOSAL The Table, “ Wastes You Will Transport and/or Dispose of Onshore

, “is included as
Attachment 12 -A.

### Freeport

- McMoRan Oil & Gas LLC Section 1 4 – Pg. 24 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 14
COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION

The OCS related oil and gas development activities having potential impact on the Alabama Coastal Zone are based on the location of the proposed facilities, access to those sites, best practical technique for operations and production equipmen t, guidelines for the prevention of adverse environmental effects, effective environmental protection, emergency plans and contingency plans. Alabama policies have been addressed below or are cross referenced to the appropriate sections of the plan:

Topic Cross Reference Comments

**Coastal Resource Use**  **Policies** Coastal Development Dock and port facilities in Louisiana will be used. There will be no new construction, dredging, or filling in Alabama state waters. There will be no new commercial development or capital improvements in Alabama’s coastal zone, nor will there be any employ ment effects.
Mineral Resource Exploration and Extraction Proposed exploration operations will take place 78.2 miles from Alabama’s coastline.

Commercial Fishing Section 8

Hazard Management Section 3 A Shallow Hazards Report has been prepared and submitted to BOEM in order to identify and assess the seafloor and shallow geologic conditions in this block. Shoreline Erosion Section 8 Proposed exploration operations will take place 78.2 miles from Alabama’s coastline.
Recreation Section 8 Transportation Section 12
**Natural Resource**  **Protection Policies**  Biological Productivity Section 8

Water Quality Section 8
Water Section 8

### Freeport

- McMoRan Oil & Gas LLC Section 1 4 – Pg. 25 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894)

Resources Air Quality Section 7
Wetlands and Submerged Grassbeds Section 8

Beach and Dune Protection Section 8

Wildlife Habitat Protection Section 8

Endangered Species Section 8

Cultural Resources Protection Section 5 Viosca Knoll Block 915 is located in an area where historic shipwrecks may exist. An archaeological report was prepared by contractor and it was determined that there are no known historic shipwrecks located in the block. An archaeological report for Viosca Knoll Block 915 wa s previously submitted and approved on March 21, 2014 (Plan Control N o. R

- 6011 ).

The proposed activities described in detail in this Plan comply with Alabama’s approved Coastal Zone Management Programs and will be conducted in a manner consistent with

su ch Programs.

A certificate of Coastal Zone Management Consistency for the state of Alabama is

included as Attachment 14 -A

.

### Freeport

- McMoRan Oil & Gas LLC Section 1 5 – Pg. 26 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## 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

OCS

- G 06894

(A) IMPACT PRODUCING FAC TORS

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, H 2 S releases) Discarded
Trash &
Debris

Site

- specific at Offshore
Location

Designated topographic features (1) (1) (1)

Pinnacle Trend area live bottoms (2) (2) (2)

Eastern Gulf live bottoms (3) (3) (3)

Benthic communities (4)

Water quality X X

Fisheries X X

Marine Mammals X(8) X X(8) X

Sea Turtles X(8) X X(8) X

Air quality X(9)

Shipwreck sites (known or potential) (7)

Prehistoric archaeological sites X (7)

Vicinity of Offshore Location

Essential fish habitat X X(6)

Marine and pelagic birds X X

Public health and safety (5)

Coastal and Onshore

Beaches X(6) X

Wetlands X (6)

Shore birds and coastal nesting
birds X 6)

Coastal wildlife refuges

Wilderness areasFootnotes 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

- mil e 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) Stip ulation attached to an OCS lease. 3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (Low

Relief) 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 emplac ements, 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. I f 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 Viosca Knoll Block 915
Proposed operations consist of the drilling, testing, completion, and flaring of Well Locations F & G, and installation of subsea wellheads. The operations will be conducted with a DP drillship

.

1. Designated Topographic F eatures
Potential IPFs on topographic features include effluents, and accidents.

Effluents: Viosca Knoll Block 915 is 101 mil es from the closest designated T opographic
F eature s Stipulation Block ( Sackett Bank ); therefore

, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed activities (refer to statistics in Item 5 , Water Quality). Oil spills cause damage to benthic organisms only if the oil contacts the organisms. Oil from a surfac e 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 co uld reach their
sessile biota. Oil from a subsurface spill is not applicable due to the distance of these blocks from a topographic area. T he 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 T rend A rea L ive B ottoms
Potential IPFs on pinnacle trend area live bottoms include effluents and accidents.

Effluents: Viosca Knoll Block 915 is 70 miles from the closest live b ottom (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 , Wat er Quality). Oil spills have the potential to
foul benthic communities and cause lethal and sublethal eff ects 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 B ottoms

Potential IPFs on Eastern Gulf live bottoms include effluents and accidents.

Effluents: Viosca Knoll Block 915 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 Q uality). 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 pr oposed 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 acti vities which could impact an Eastern Gulf live
bottom area.

4. Benthic C ommunities 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 ca use impacts to benthic
communities.

A DP 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 DP drillship

, FM O&G’s proposed operations in Viosca Knoll Block 915 would not cause impacts to benthic communities.

5. Water Q uality
IPFs that could result in water quality degradation from the proposed operations in Viosca Knoll
Block 915 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: O il 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 spill s 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 cons tituents to background levels. Historically, changes in offshore water quality from oil spil ls 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 Resp onse 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 Viosca Knoll
Block 915 include effluents and accidents.

Effluents: Effluents such as drilling fluids and cuttings discharges contain components and propert ies 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 detrimen tal effe cts on fisheries; however, it is unlikely that such an event would occur from the proposed activities (refer to Item 5 , Water Q uality). The effects of oil on mobile adult finfish or shellfish would likely be sublethal and the extent of damage would be redu ced to the c apacity of adult fish and
shell fish 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 submi tted 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 M ammals

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 Viosca Knoll Block 915 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 dischar ges 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 f rom 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 ac cidental 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 mater ials such as plastic or glass.

Inf ormational 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 trai ning 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 b etween 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 marin e mammals and maintaining a safe d istance when they are sighted. Vessel crews should use a reference guide to help identify the twenty

- eight species of whales and dolphins, and the single species of manatee that may be encountered in the Gulf of Mexico OCS. Vessel crews must report sightings of any injured or dead protected marine mammal species immediately, regardless of whether the injury or death is caused by their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline at (888) 404

- 3922, the NMFS Southeast Regional Office at (727)
824- 5312, or the Marine Mammal Stranding Network at (305) 862 -2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@boemre.gov . If the vessel is the responsible party, it is required to remain available to assist the respective salvage and stran ding
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 (ref er to Item 5 , Wate r Q uality). 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
kn own. 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 OS RP (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 T urtles
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 h ave 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., 1 983b; Lohoefener et al., 1990). Deep waters may be used by all species as a transitory habitat.

### Emissi ons: Noise from drilling activities, support vessels, and helicopters may elicit a startle reaction from sea turtles, but th is is a temporary disturbance.

Effluents: Drilling fluids and cuttings discharges are not know n 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 debr is: 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 turtle s. 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

mater ials 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 pi lots, 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 th e 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 inju ry 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 encounte red 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 (7 27) 824

- 5312, or the Marine Mammal Stranding Network at (305) 862 -2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@boemre.gov

. If the vessel is the responsible party, it is required to remain available to assist the respective salvage and stranding network as needed.

### All sea turtle species and their life stages are vulnerable to t he 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 It em 5 , Water Q uality). 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 Pla n (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

Viosca Knoll Block 915 is located 70 miles from the Breton Wilderness Area and 65.8 miles from shore. Applicable emissions data is included in Section 7 of the Plan.

There would be a limited degree of air quality degradation in the immediate vicinity of the proposed activities. Plan Emissions for the proposed activities do not exceed the annual exemption levels as set forth by BOEM . Accidents and blowouts can release hydrocarbons or chemicals, which could cause the emission of air pollutants. However, these releases would not impact onshore air quality because of the prevailing atmospheric conditions, emission height, emission rates, and the distance of Viosca Knoll Block 915 from the coastline. There are no other IPFs (including effluents, physical disturbances to the seafloor, wastes sent to shore for treatment or disposal) from the proposed activities which would impact air quality.

10. Shipwreck Sites (known or potential)
Potential IPFs that could impact known or unknown shipwreck sites as a result of the proposed operations in Viosc a Knoll Block 915 include disturbances to the seafloor.

Physical disturbances to the seafloor: A DP 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 DP drillship

, FM O&G’s proposed operations in Viosca Knoll Block 915 would not cause impacts to shipwreck sites.

Additionally, Viosca Knoll Block 915 is not located in or adjacent to an OCS block designat ed by BOEM as having a high probability for occurrence of shipwrecks, therefore, no adverse impacts are expected.

FM O&G will perform an AUV/ ROV survey imaging 100% of the seafloor with sector scanning sonar within a minimum 500’ radius of the proposed well location(s) prior to or upon commencement of operations. These locations will be certified by an authorized marine

### archaeologist and by FM O&G to be clear of seafloor archaeological resources, including historic shipwrecks. Copies of the certification s and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be encountered, FM O&G will contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural resource.

There are no other IP Fs (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 a rchaeological sites as a result of the proposed operations in Viosca Knoll Block 915 are physical disturbances to the seafloor and accidents (oil spills).

Physical Disturbances to the seafloor: Although the operations proposed will be conducted by
util izing a DP drillship , which would cause only an insignificant amount of seafloor to be disturbed, Viosca Knoll Block 915 is located inside the Archaeological Prehistoric high probability lines. FM O&G will report to BOEM the discovery of any object of preh istoric archaeological significance and make every reasonable effort to preserve and protect that cultural

resource.

FM O&G will perform an AUV/ ROV survey imaging 100% of the seafloor with sector scanning sonar within a minimum 500’ radius of the proposed well location(s) prior to or upon commencement of operations. These locations will be certified by an authorized marine archaeologist and by FM O&G to be clear of seafloor archaeological resources. Copies of the certifications and a circle radius plat o f the survey area will be submitted to the BOEM. Should a resource be encountered, FM O&G will contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural resource. .

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 I tem 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 F ish H abitat (EFH)
IPFs that could cause impacts to EFH as a result of the proposed operations in Viosca Knoll
Block 915 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

res trictions, 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: A n 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 Q uality). 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 seaflo or and wastes sent to shore for treatment or disposal) from the proposed activities which could impact essential
fish habitat.

2. Marine and P elagic B irds
IPFs that could impact marine birds a s a result of the proposed activities include air emissions, accidental oil spills, and discarded trash and debris fr om 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 Q uality). Marine and pelagic birds feeding at the spill locati on 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 inform ation 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 f rom 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

ac cidental 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. Info rmational 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 v iew
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
traini ng 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 wit h 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) fro m the proposed activities which could impact marine and pelagic birds.

3. Public H ealth and S afety D ue to A ccidents.
There are no IPFs (emissions, effluents, physical disturbances to the seafloor, wastes sent to
sho re for treatment or disposal or accident s, including an accidental H 2 

### S 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 H 2 

### S absent.

Coastal and Onshore

1. Beaches
IPFs from the proposed activities that could cause impacts to beaches include accidents (oil spills) and discarded trash and debris.

Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches and associated resources. Due to the distance from shore ( 65.8 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 Environm ental Protection Agency (EPA). FM O&G will operate in accordance with the regulations and also avoid accidental loss of solid waste items by

ma intaining 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), “Thi nk 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 leas e operator management that emphasizes their commitment to waste management in accordance
with NTL No. 2012- G01

.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to shore for treatment or disposal) from the proposed activities which could impact beaches.

2. Wetlands
IPFs from the proposed activities that could cause impacts to wetlands include accidents (oil spills) and discarded trash and debris.

Accidents: It is unlikely that an oil spill would occur from the proposed activities (refer to Item
5 , Water Quality). Due to the distance from shore ( 65.8 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
maintain ing 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 packa ging 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 offsh ore 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 Abo ut 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

oper ator 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 B irds and Coastal N esting B irds

Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Given the distance from shore ( 65.8 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 infor mation 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 i n 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 so lid 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

### indoctrin ated 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. Off shore 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 th e proposed activities could cause impacts to coastal wildlife refuges. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, Water Quality). Due to the distance from shore ( 65.8 miles) and the response capabi lities 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 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 pilo ts, 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- G0 1.

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 ( 70 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 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 pilo ts, 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- G0 1.

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) IMPAC TS ON PROPOSED ACTIV ITIES

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 HAZARD S 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, Viosca Knoll Block 915 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 & completi on

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 M EASURES
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 su ch entities has not been provided.

(H) PREPARER(S)

Evan Connolly J. Connor Consulting, Inc. 16225 Park Ten Place, Suite 700 Houston, TX 77084 (281) 578-3388 Evan.connolly @jccteam.com

### (I ) REFERENCES

Authors:

American Pe troleum Institute (API). 1989. Eff ects 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 ma rine turtles: entanglement an d ingestion. In:
Shomur a, R.S. and H.O. Yoshida, eds. Proceedin gs, Workshop on the Fate and Impact of Marine Debris, 26

- 29 November 1984, Honolulu, HI. U.S. Dept. of C ommerce. NOAA
Tech. Memo. NOAA- TM

- NMFS

- SWFC -54. Pp 387-429.

Bu rke, 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

cut tings in waters of the United States. U.S. Environmental Prote ction 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. BLM

YK

- ES -81-006-1792.

Laist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris including a comprehensive lis t 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

expose d 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 th is 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 1 6 – Pg. 27 of 27 Supplemental EP September, 2014 Viosca Knoll Block 915 (OCS

- G 06894) 

## SECTION 16
ADMINISTRATIVE INFORMATION

16.1 EXEMPTED INFORMATION DESCRIPTION The proposed bottom

- hole location s of the planned well s have been removed from the

Public I nformation 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. Initial Exploration Plan (Control N o. N- 2908).

2. Revised Exploration Plan (Control N o. R- 6011).

3. C&C Technologies Survey Services. Archaeological Assessment Report Block 915 (OCS

- G 06894) and Vicinity Viosca Knoll Area, April 2007, (C & C Job No. 072217).

4. C& C Technologies Survey Services. AUV Survey Operations Report, Deepwater Benthic Communities Investigation, Block 915 (OCS

- G 06894) Viosca Knoll Area, July, 2014 (C&C Project #130909).

5. Geoscience Earth & Marine Services, Inc. Geologic and Stratigraphic

As sessment Block 915 (OCS

- G 06894) Viosca Knoll Area, Gulf of Mexico, August 2013 (Project No. 0413

- 2236).

6. Geoscience Earth & Marine Services, Inc. Site Clearance Letters Proposed Wellsites F and G, Block 915, Viosca Knoll Area, Gulf of Mexico, July 16, 20 14 (Project No. 0614

- 2414 ).

7. Regional Oil Spill Response Plan, Freeport

- McMoRan Oil & Gas LLC (Control
No. O

- 713).

8. Wilson, S.M., Nagoo, A.S. & Sharma, M.M. “Analysis of Potential Bridging Scenarios During Blowout Events,” paper SPE/IADC 163438, presented at the SPE/IADC Drilling Conference and Exhibition, Amsterdam, The Netherlands, 5

- 7 March 2013.