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, 2014
Record 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. 20 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 REPRESENTATIVE:

Jean Martin

J. Connor Consulting, Inc.

16225 Park Ten Place, Suite 700

Houston, Texas 77084

(281) 698-8544

jean.martin@jccteam.com
TOC Pg 1 of 3 

TABLE OF CONTENTS

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

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

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

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

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

1.5 POLLUTION PREVENTION MEASURES ............................................................. 2

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

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

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

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

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

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

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

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

2.6 DEEPWATER WELL CONTROL STATEMENT .................................................... 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 AIR 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 GARDEN 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

SECTION 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 Sale 81. The Viosca Knoll Block 915 Unit (Unit Agreement No. 754396011) was 

approved on May 31, 1996. The unit is currently held by production. 

An Initial Exploration Plan for BP America Production Company (Control No. N-2908) 

was approved on March 4, 1998. A Revised Exploration Plan for Freeport-McMoRan Oil 

& Gas LLC (FM O&G), Control No. R-6011, provided for the revision of Well Locations 

A and B, the rig type from a semisubmersible to a drillship 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 well 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 bottomhole locations of the 

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

included as Attachment 1-B. 

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

proposed well 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 to Drill. 

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

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

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 35o

1.5 POLLUTION PREVENTION MEASURES 

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

state.

1.6 ADDITIONAL MEASURES

FM O&G does not propose any additional safety, pollution prevention, or early spill 

detection measures beyond those required by 30 CFR 250.

1.7 COST RECOVERY FEE 

Documentation of the $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: 35.4o

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

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

Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): 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): 107,958 bbls/day

For structures, volume of all storage and 

pipelines (Bbls): NA API Gravity of fluid 35.4o

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 29o 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): 

Anchor Radius (if applicable) in feet: NA TVD (Feet):

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

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

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

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

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

Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): 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 35.4o

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): 

Anchor Radius (if applicable) in feet: NA TVD (Feet):

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

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

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

X: Y:

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

HH

H

H

H

"H

!.!.

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 915

OCS-G-06894

Freeport-McMoRan Oil & Gas LLC

A-Marlin TLP

FM #A001-003, 

A006 (G06894)

FM #SS1(G06894)

FM #SS2

(G06894)

FM #SS3(G06894)

FM #SS4(G06894)

FM #SS5

(G06894)

FM #A004-005 (G08469)

FM (SN-13763)

10" BLKG (ABN)

FREEPORT (SN-16085)

6" UBEH (ACT)

FM (SN-13148)

3" UMB (ACT)

FREEPORT (SN-17663)

4" UMB (ACT)

FM (SN-13146) 6" BLKG (ACT)

FM (SN-13145) 6" BLKG (ACT)

FM (SN-13762)

4" UMB (ABN)

FREEPORT (SN-17662) 4" UMB (ACT)

FREEPORT (SN-17661) 

6" UMB (ACT)

FREEPORT (SN-13388)

4" UBEH (ACT)

FM (SN-11766) 14" GAS (ACT)

FREEPORT (SN-13884)

2" UBEH (ACT)

FREEPORT (SN-13386) 8" BLKO (ACT)

AND (SN-13387) 12" CSNG (ACT)

FREEPORT (SN-13384) 8" BLKO (ACT)

AND (SN-13385) 12" METH (ACT)

FREEPORT (SN-17852) 2" SERV (ACT)

FREEPORT (SN-12759) 4" UMB (OUT

F

)

REEPORT (SN-12758) 10" CSNG (OUT)

FREEPORT (SN-12757) 6" BLKG (OUT)

FREEPORT (SN-16152) 12" CSNG (ACT)

FREEPORT (SN-16151) 8" BLKO (ACT)

Well F

Well G

87°58'0"W

87°57'0"W

87°56'0"W

29°6'0"N29°5'0"N

29°4'0"N

1,335,000

1,340,000

1,345,000

10,550,00010,555,00010,560,00010,565,000

Proposed Locations- VK 915

Location Call E/W Call N/S X Coordinate Y Coordinate Latitude Longitude WD

F SL 3,000.00 FWL 6,635.00 FSL 1,333,560.00 10,556,075.00 29° 05' 02.4304" N 87° 57' 39.6140" W 3,561'

G SL 2,900.00 FWL 6,635.00 FSL 1,333,460.00 10,556,075.00 29° 05' 02.4223" N 87° 57' 40.7413" W 3,562'
H!.

FM #SS4 (G06894)

FREEPORT (SN-16151) 8" BLKO 

(ACT)

FREEPORT (SN-16152) 12" CSNG

(ACT)

F

RE

E

P

O

RT (S

N

-1

33

88) 4" U

B

E

H (ACT) F

R

EEP

ORT

(S

N

-13884) 2" U

B

EH

(ACT)

FREEPORT (SN-17662) 4" UMB (ACT)

FREEPORT (SN-17658) 

6" BLKO (ACT)

VK 915

OCS-G-06894

Freeport-McMoRan Oil & Gas LLC

VK 914

Open

INLINE 12050

CROSSLINE 1238

-3400

-3300

-3600

-3700

-3400

-3

-3600 500

Well F

87°58'0"W87°57'30"W87°57'0"W

29°5'30"N

29°5'0"N

29°4'30"N

1,330,0001,332,5001,335,000

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

SCALE1:12,000 OR 1 " = 1,000 '
H !.

FM #SS4 (G06894)

FREEPORT (SN-16151) 8" BLKO 

(ACT)

FREEPORT (SN-16152) 12" CSNG

(ACT)

F

RE

E

P

O

RT (S

N

-1

33

88) 4" U

B

E

H (ACT) F

R

EEP

ORT

(S

N

-13884) 2" U

B

EH

(ACT)

FREEPORT (SN-17662) 4" UMB (ACT)

FREEPORT (SN-17658) 

6" BLKO (ACT)

VK 915

OCS-G-06894

Freeport-McMoRan Oil & Gas LLC

VK 914

Open

INLINE 12060

CROSSLINE 1237

-3400

-3300

-3600

-3700

-3400

-3

-3600 500

Well G

87°58'0"W87°57'30"W87°57'0"W

29°5'30"N

29°5'0"N

29°4'30"N

1,330,0001,332,5001,335,000

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

SCALE1:12,000 OR 1 " = 1,000 '
1

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

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

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

 Application Name: BOEM Exploration Plan - BF 

 Pay.gov Tracking ID: 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

The table below provides all additional applications to be filed covering operations 

proposed in this EP. 

Application/Permit Issuing Agency Status

Application for Permit to Drill BSEE To be submitted

2.2 DRILLING FLUIDS 

The table below provides the types and estimated volumes of the drilling fluids FM O&G 

plans to use to drill the proposed wells. 

Type of Drilling Fluid Estimated Volume of Drilling Fluid 

to be 

Used per Well (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 bond, furnished and maintained according to 30 CFR 556, Subpart I; 

NTL No. 2000-G16, "Guidelines for General Lease Surety Bonds;" and a current 

BOEM-approved deferment from providing additional security under 30 CFR 556.53(d) 

and National NTL No. 2008-N07, “Supplemental Bond Procedures.” If at any point 

Freeport-McMoRan Oil & Gas LLC no longer qualifies for a supplemental bonding 

deferment, Freeport-McMoRan Oil & Gas LLC will either provide the required additional 

security or a third party guarantee within 60 days after such disqualification.

2.5 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR)

Freeport-McMoRan Oil & Gas LLC, Operator No. 03280, has demonstrated oil spill 

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

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

Facilities" prior to conducting operations covered in this EP.
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 an 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 Control 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 over: 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 conditions at the site. FM O&G has Master Service 

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

Boots and Coots (a Halliburton company). Additionally an ROV capable of manipulating 

the rig’s BOP hot‐stab functions would be mobilized to location and, if appropriate, an 

attempt would be made to shut in the well by closing the blind shear rams if not done 

previously. These actions would take place within 24 ‐ 48 hours of the incident. Initial 

assessment activities are projected to take 3 – 5 days. During this period, the well 

control team would analyze the blowout situation, devise an intervention 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 915 

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)

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

Activity Duration (days)

Assess the situation and obtain the optimum MODU 5

Secure the well at current location of MODU 14

Mobilization time to relief well location 3

Drill relief well 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 mobilizing 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 blowout: 

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

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

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

testing and operation of the diverter system and diverter outlets. 

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

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

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

being utilized.

• Connections will be simulated as needed while drilling into pressure transition 

areas in order to properly assess the current wellbore conditions.

Measures to reduce the likelihood of a blowout: 

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

additional barrier for well safety.
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 concentrated pills 

will be used to prevent uncontrolled mud losses.

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

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

excess hydrostatics pressures on known zones previously encountered.

• Mudloggers may be utilized during critical drilling operations to monitor gas 

content of mud returns, formation characteristics and abnormalities of cuttings 

and to estimate paleo aging of cuttings.

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

evaluate formations, formation pressures and fluid content in the critical sections 

of the well.

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

departments.

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

of a blowout: FM O&G is a member of the Helix Well Containment Group (HWCG) and 

has full access to a subsea capping stack and a complete suite of oil recovery 

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

well location with 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 INTERPRETED SEISMIC LINES 

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, “Extension of Prior Notices to Lessees”), a shallow hazards assessment 

has been prepared for each proposed surface location evaluating seafloor and 

subsurface geological and manmade features and conditions that may adversely affect 

drilling operations. The shallow hazards assessment is included as Attachment 3-D. 

3.7 HIGH-RESOLUTION SEISMIC LINES

Proprietary 

3.8 STRATIGRAPHIC COLUMN

Proprietary 

3.9 TIME VERSUS DEPTH TABLES

Proprietary 
10344 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 

Proposed 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. Geohazard 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 

FORUM 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 

(Autonomous 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 highresolution 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 

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Geoscience Earth & Marine Services // 3 

FORUM ENERGY TECHNOLOGIES, INC. 

Map No. 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 

(NTL’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 

have 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 

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FORUM ENERGY TECHNOLOGIES, INC. 

Table 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 

proposed 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 

known 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 eastsoutheast 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. 

These 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 

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Water Depth and Seafloor Conditions 

The water depth at the proposed surface location is –3,561 ft (Map VK 915-F-1). The seafloor slopes to 

the southeast 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 

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

south, 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 gascharged 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 

Stratigraphic 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 

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FORUM ENERGY TECHNOLOGIES, INC. 

The base of Unit 2 (631 ft to 987 ft) consists of continuous, moderate-amplitude reflectors overlying semicontinuous 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 F2). 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). 

The 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 

investigation (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 

channel 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 

FORUM ENERGY TECHNOLOGIES, INC. 

turbidite 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 

assessments, 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 

working 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 

and 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

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FORUM 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/MapGallery/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. 
10344 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 

Proposed 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. Geohazard 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 
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FORUM 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 

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 highresolution 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 
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Map No. 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 

(NTL’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 

have 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: 
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Table 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 

proposed 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 

known 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 eastsoutheast 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. 

These 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. 
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Water Depth and Seafloor Conditions 

The water depth at the proposed surface location is –3,562 ft (Map VK 915-G-1). The seafloor slopes to 

the south 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 

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

south, 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 gascharged 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 

Stratigraphic 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. 
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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 G2). 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-G2). 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 

investigation (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, northnortheast 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 

channel 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 

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FORUM ENERGY TECHNOLOGIES, INC. 

turbidite 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 

assessments, 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 

working 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 

and 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 

FORUM 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/MapGallery/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 anticipates encountering 0 ppm H2S during the proposed operations.

4.2 CLASSIFICATION

In accordance with Title 30 CFR 250.490(c), FM O&G requests that the area of 

proposed operations be classified by the BOEM as H2S absent. 
Freeport-McMoRan Oil & Gas LLC Section 5 – Pg. 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 highdensity deepwater benthic communities by 2,000 feet from each proposed mud and 

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

disturbances. 

C & C Technologies was contracted to conduct a deepwater Autonomous Underwater 

Vehicle (AUV) benthic community investigation within Vioscal Knoll Block 915. The 

purpose of this investigation was to locate any potential deepwater benthic 

communities. There is no 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.

As 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 

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

Sensitive Underwater Features and Areas.”

5.3 TOPOGRAPHIC FEATURES STATEMENT (SHUNTING)

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

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

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

5.4 LIVE BOTTOMS (PINNACLE TREND FEATURES)

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 BOTTOMS (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. 2008-G06, “Remotely Operated Vehicle Surveys in Deepwater” 

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

Lessees and Operators Pending Review and Reissuance”).

5.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND 

MARINE MAMMAL INFORMATION

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

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

threatened (T).

Species Scientific Name Status Potential 

Presence

Critical 

Habitat 

Designated in 

the Gulf of 

Mexico

Lease 

Area

Coastal

Sea Turtles

Loggerhead Caretta 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 Scientific Name Status Potential 

Presence

Critical 

Habitat 

Designated in 

the Gulf of 

Mexico

Lease 

Area

Coastal

Marine Mammals

Sperm 

Whale

Physeter 

macrocephalus

E x -- None

West Indian 

Manatee

Trichechus manatus 

latirostris

E -- x Florida

Blue Whale Balaenoptera 

masculus

E x -- None

Fin Whale Balaenoptera 

physalus

E x -- None

Humpback 

Whale

Megaptera 

novaeangliae

E x -- None

NorthAtlantic 

Right Whale

Eubalaena glacialis E x -- None

Sei Whale Balaenopiera borealis E x -- None

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

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

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

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

Gulf of Mexico (see table below). 
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 Sturgeon 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. R4782, 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,” an Archaeological 

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 Plans and Development Operations 

Coordination Documents” (Extended by NTL No. BOEM 2014-G05, “Extension of Prior 

Notices to Lessees”).
H!.

FM #SS4 (G06894)

FREEPORT (SN-16151) 8" BLKO 

(ACT)

FREEPORT (SN-16152) 12" CSNG

(ACT)

F

RE

E

P

O

RT (S

N

-1

33

88) 4" U

B

E

H (ACT) F

R

EEP

ORT

(S

N

-13884) 2" U

B

EH

(ACT)

FREEPORT (SN-17662) 4" UMB (ACT)

FREEPORT (SN-17658) 

6" BLKO (ACT)

VK 915

OCS-G-06894

Freeport-McMoRan Oil & Gas LLC

VK 914

Open

INLINE 12050

CROSSLINE 1238

-3400

-3300

-3600

-3700

-3400

-3

-3600 500

Well F

87°58'0"W87°57'30"W87°57'0"W

29°5'30"N

29°5'0"N

29°4'30"N

1,330,0001,332,5001,335,000

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

SCALE1:12,000 OR 1 " = 1,000 '
H !.

FM #SS4 (G06894)

FREEPORT (SN-16151) 8" BLKO 

(ACT)

FREEPORT (SN-16152) 12" CSNG

(ACT)

F

RE

E

P

O

RT (S

N

-1

33

88) 4" U

B

E

H (ACT) F

R

EEP

ORT

(S

N

-13884) 2" U

B

EH

(ACT)

FREEPORT (SN-17662) 4" UMB (ACT)

FREEPORT (SN-17658) 

6" BLKO (ACT)

VK 915

OCS-G-06894

Freeport-McMoRan Oil & Gas LLC

VK 914

Open

INLINE 12060

CROSSLINE 1237

-3400

-3300

-3600

-3700

-3400

-3

-3600 500

Well G

87°58'0"W87°57'30"W87°57'0"W

29°5'30"N

29°5'0"N

29°4'30"N

1,330,0001,332,5001,335,000

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

SCALE1:12,000 OR 1 " = 1,000 '
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 

Modeling 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

Projected generated waste Projected ocean discharges Downhole Disposal

Type of Waste Composition Projected Amount Discharge Rate Discharge Method

Cuttings wetted with water-based fluid Cuttings coated while drilling with WBM 2,197 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, CaBr2, CaCl2

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, CaBr2, CaCl2

Brines, NaCl, KCl, CaBr2, CaCl2

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 testedat 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 = 3400D2/3 for CO, and CT = 

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

X

Do your emission calculations include any emission reduction measures 

or modified emission factors?

X

Are your proposed exploration activities located east of 87.5° W 

longitude?

X

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

per million (ppm)?

X

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

hours from any proposed well? X 

Do you propose to burn produced hydrocarbon liquids? X

7.2 SUMMARY INFORMATION

Included as Attachment 7-A are Air Emission Worksheets which show the emissions 

calculations for the Plan Emissions and if different, a set of worksheets showing the 

emissions calculations for the Complex Total emissions.

This information was calculated by: Jean Martin

 (281) 698-8544

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

AIR QUALITY SCREENING CHECKLIST

OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2011

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

COMPANY Freeport-McMoRan Oil & Gas LLC

AREA 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 % weight
EMISSIONS CALCULATIONS 1ST YEAR

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

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Freeport-McMoRan Oil & 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

65.8
SUMMARY

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

COMPANY AREA BLOCK LEASE PLATFORM WELL

Freeport-McMoR 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 55415.28
Day 1 2 3 4 5 6

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

31 13,499 gal 15,507 gal 13,763 gal

Average 13,596 gal 12,734 gal 11,290 gal 13,691 gal 12,677 gal 14,179 gal

Transit Days

Daily Fuel Usage for a 6 month period

Month
Freeport-McMoRan Oil & Gas LLC Section 8 – Pg. 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 FreeportMcMoRan Oil & Gas LLC (FM O&G) Oil Spill Response Plan (OSRP) filed by FreeportMcMoRan Oil & Gas LLC (Operator No. 03280) dated January 10, 2014, revised on 

January 31, 2014, and approved on February 4, 2014 (OSRP Control No. 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 providers 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 Miles Drilling > 10 Miles 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 25o 35.4o

The WCD calculations and assumptions for the Regional OSRP WCD, GC 393 Well 

Location 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 No. 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 Discussion is included as Attachment 8-A.
SPILL RESPONSE DISCUSSION 

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

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

estimated to be 182,478 barrels of crude oil with an API 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 and 

Western Gulf of Mexico available on the BSEE website. The results are shown in Figure 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, shell 

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 practicable. 

A description of the response equipment under contract to contain and recover the Worst Case 

Discharge is shown in Figure 2.

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

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

Less 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 Response Plan includes alternative response technologies such as dispersants and

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

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

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

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

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

soon as possible. Offshore response strategies may include attempting to skim utilizing the 

HOSS Barge, nine Fast Response 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 barges 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 barges may be mobilized 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 Unified

Command would be consulted to ensure that environmental and special economic resources 

would be correctly identified and prioritized to ensure optimal protection. Shoreline protection 

strategies depict the protection response modes applicable for oil spill clean-up operations. The 

State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection 

strategies for this area, and it describes necessary action to keep the oil spill from entering 

Louisiana’s coastal wetlands, based on the assumption that removal of the released oil will be 

much easier and less damaging to fragile coastal ecosystems if done in the open waters of the 

Gulf of Mexico. Supervisory personnel have the option to modify the deployment and operation 

of equipment allowing a more effective response to site-specific circumstances. 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 Recovery Capacity (EDRC)).
Initial Response Considerations 

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

are not limited to:

• Weather

• Equipment and materials availability

• Ocean currents and tides

• Location of the spill 

• Product spilled 

• Amount spilled

• Environmental risk assessments 

• Trajectory and product analysis 

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

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

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

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

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

precedence over all other considerations during these operations. 

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

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

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

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

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

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

the Source Control Section Chief. 

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

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

slick movement in real time.

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

• Information will be confirmed

• An assessment will be made and initial objectives set

• OSROs and appropriate agencies will be notified 

• ICS 201, Initial Report Form will be completed 

• Initial Safety plan will be written and published

• Unified Command will be established

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

objectives

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

site

o On-site command and control established 
Decanting Strategy

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

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

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

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

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

recovery.

Offshore Response Actions

Equipment Deployment

Surveillance 

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

notification, or at first light

• Provide trained observer to provide on site status reports 

• Provide command and control platform at the site if needed 

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

and visual confirmation 

• Continual monitoring of vessel assets using vessel monitoring systems 

Dispersant application assets 

• Put Airborne Support Inc. (ASI) on standby 

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

appropriateness of dispersant application 

• Gain FOSC approval for use of dispersants on the surface 

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

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

• Confirm dispersant availability for current and long range operations 

• Start ordering dispersant stocks required for expected operations 

Containment boom 

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

• Ensure boom handling and mooring equipment is deployed with boom 

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

their most effective containment 

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

Dedicated off-shore skimming systems

General

• Deployed to the highest concentration of oil 

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

• Use in areas with heaviest oil concentrations

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

CGA FRUs

• To the area of the thickest oil

• Use as far off-shore as allowed

• VOOs 140’ – 180’ in length 

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

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

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’ in length

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

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

Storage Vessels 

• Establish availability of CGA contracted assets

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

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

systems

• Position as closely as possible to skimming assets to minimize offloading time
Vessels of Opportunity (VOO)

• Use 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) 

• Determine availability of fire boom and selected ignition systems

• Start ordering fire boom stocks required for expected operations 

• Contact boom manufacturer to provide training if required 

• Determine assets to perform on water operation

• Build operations into safety plan

• Conduct operations in accordance with an approved plan 

Adverse Weather Operations: 

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

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

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

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

Timing

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

actual situation, actual trajectories and oil budgets

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

• Outfitting of VOOs for specific missions

• Deployment of assets based on actual movement of oil 

Considerations 

• Water depth, vessel draft

• Shoreline gradient 

• State of the oil 

• Use of VOOs

• Distance of surf zone from shoreline 

Equipment Deployment 

Surveillance 

• Provide trained observer to direct skimming operations 

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

and visual confirmation 

• Continual monitoring of vessel assets 

Dispersant Use

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

water depth 

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

Vessel Deployment

Dedicated Near Shore skimming systems 

• Fast Response Vessels (FRV)

• Egmopol and Marco Shallow Water Skimmer (SWS)

• Operate with aerial spotter directing systems to observed oil slicks

VOO

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

• Time to acquire personnel and equipment and their availability 

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

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

Water Horizon, dated 2 May 2010 

Actions 

Placement of boom 

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

appropriate ACP 

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

impact. Consider: 

o Trajectories

o Weather forecast

o Oil Impact forecast

o Verified spill movement

o Boom, manpower and vessel (shallow draft) availability 

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

Beach Preparation 

Considerations and Actions 

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

• Shoreline Cleanup and Assessment Team Reports and recommendations 

• Determination of Archeological sites and gaining authority to enter 

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

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

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

possible to maximize on-site work time

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

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

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

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

and/or sweep obtained 

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

inland areas 
Decanting Strategy

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

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

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

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

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

recovery.

CGA Equipment Limitations

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

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

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

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

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

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

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

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

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

Boom 3 foot seas, 20 knot winds

Dispersants Winds more than 25 knots

Visibility less than 3 nautical miles

Ceiling less than 1,000 feet.

FRU 8 foot seas

HOSS Barge/OSRB 8 foot seas

Koseq Arms 8 foot seas

OSRV 4 foot seas
Environmental Conditions in the GOM

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

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

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

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

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

flooding is prominent. 

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

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

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

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

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

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

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

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

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

month. 
FIGURE 1 

TRAJECTORY BY LAND SEGMENT

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

utilizing PXP’s WCD and information in the BSEE Oil Spill Risk Analysis Model 

(OSRAM) for the Central 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 

Franklin, 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 

Deploy

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 Tug50 Crew

4 (Barge)

2 (Per Crew) Leeville 4 0 6 20 1.5 31.5

T&T Marine (available through contract with CGA)

Koseq Skimming 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 19000 1 Tug 6 Tampa 4 2 0 42.5 1 49.5
Recovered 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

Staging 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 Utility 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 20.3
Nearshore Response

Nearshore 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 

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 Req. 

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 5 
Shoreline Protection

Staging Area: Venice

Shoreline Protection 

Boom VOO Persons Req. 

Storage/Warehouse

Location

Hrs to 

Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Deployment Site

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

Total 

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 INCIDENTAL TAKES

There is no reason to believe that any of the endangered species or marine mammals 

as listed in the ESA will be “taken” as a result of the operations proposed under this 

plan. 

It has been documented that the use of explosives and or seismic devices can affect 

marine life. Operations proposed in this plan will not be utilizing either of these devices. 

FM O&G will adhere to the requirements as set forth in the following documents, as 

applicable, to avoid or minimize impacts to any of the species listed in the Endangered 

Species Act (ESA) as a result of the operations conducted herein:

• NTL No. 2012-BSEE-G01, “Marine Trash and Debris Awareness and 

Elimination”

• NTL No. 2012-JOINT-G01, “Vessel Strike Avoidance and Injured/Dead Protected 

Species Reporting”

• NTL No. 2012-JOINT-G02, “Implementation of Seismic Survey Mitigation 

Measures and Protected Species Observer Program”

9.3 FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY

Viosca Knoll Block 915 is not located in the Flower Garden Banks National Marine 

Sanctuary; therefore, relevant information is not required in this EP. 
Freeport-McMoRan Oil & Gas LLC Section 10 – Pg. 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 and aircraft during the proposed 

operations.

10.2 MARINE PROTECTED SPECIES

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

Protection Act, FM O&G will: 

(a) collect and remove flotsam resulting from activities related to exploration, 

development, and production of this lease; 

(b) post signs in prominent places on all vessels and platforms used as a result of 

activities related to exploration, development, and production of this lease detailing the 

reasons (legal and ecological) why release of debris must be eliminated; 

(c) observe for marine mammals and sea turtles while on vessels, reduce vessel speed 

to 10 knots or less when assemblages of cetaceans are observed, and maintain a 

distance of 90 meters or greater from whales, and a distance of 45 meters or greater 

from small cetaceans and sea turtles; 

(d) employ mitigation measures prescribed by BOEM/BSEE or the National Marine 

Fisheries Service (NMFS) for all seismic surveys, including the use of an “exclusion 

zone” based upon the appropriate water depth, ramp-up and shutdown procedures, 

visual monitoring, and reporting; 

(e) identify important habitats, including designated critical habitat, used by listed 

species (e.g., sea turtle nesting beaches, piping plover critical habitat), in oil spill 

contingency planning and require the strategic placement of spill cleanup equipment to 

be used only by personnel trained in less-intrusive cleanup techniques on beaches and 

bay shores; and 
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 subcontractors, 

while undertaking activities authorized under this lease, must implement and comply 

with the specific mitigation measures outlined in NTL No. 2012-JOINT-G01, “Vessel 

Strike Avoidance and Injured/Dead Protected Species Reporting;” NTL No. 2012-

JOINT-G02, “Implementation of Seismic Survey Mitigation Measures and Protected 

Species Observer Program;” and NTL No. 2012-BSEE-G01, “Marine Trash and Debris 

Awareness and Elimination.” At the lessee’s option, the lessee, its operators, 

personnel, and contractors may comply with the most current measures to protect 

species in place at the time an activity is undertaken under this lease, including but not 

limited to new or updated versions of the NTLs identified in this paragraph. The lessee 

and its operators, personnel, and subcontractors will be required to comply with the 

mitigation measures, identified in the above referenced NTLs, and additional measures 

in the conditions of approvals for their plans or permits.

10.3 CULTURAL RESOURCES

Viosca Knoll Block 915 has 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 February 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 11 – 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 located within Florida; therefore, mitigation information is 

not required for the activities proposed in this plan. 

11.2 INCIDENTAL TAKES

FM O&G will adhere to the requirements as set forth in the following documents, as 

applicable, to avoid or minimize impacts to any of the species listed in the Endangered 

Species Act (ESA) as a result of the operations conducted herein:

• NTL No. 2012-BSEE-G01, “Marine Trash and Debris Awareness and 

Elimination”

• NTL No. 2012-JOINT-G01, “Vessel Strike Avoidance and Injured/Dead Protected 

Species Reporting”

• NTL No. 2012-JOINT-G02, “Implementation of Seismic Survey Mitigation 

Measures and Protected Species Observer Program”
Freeport-McMoRan Oil & Gas LLC Section 12 – Pg. 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 Capacity 

Maximum Number 

in Area at Any 

Time

Trip Frequency or 

Duration

Crew Boat 1,800 bbls 1 3/week

Supply Boat 9,000 bbls 1 3/week

Supply Boat 5,800 bbls 1 3/week

Helicopter 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 between the 

onshore support facilities and the wells is 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 wastes
Lund

Henderson

Lloyd Ridge

Walker Ridge

Destin Dome

Atwater Valley Green Canyon

De Soto Canyon

Mississippi Canyon

Florida Plain

Port Fourchon

Approx. 170.4 miles to aircraft shorebase

Approx. 137.7 miles

to Shore Base

A

p

p

ro

x

.

7

8

.

2

m

i

l

e

s

t

o

A

l

a

b

a

m

a

S

h

ore

Approx. 65.8 miles 

to Shore

Louisiana

Mississippi Alabama

Houma

0 25 50 75 100 12.5 Miles

VK 915
Freeport-McMoRan Oil & Gas LLC Section 13 – 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 support 

for the proposed activities is provided in the table below.

Name Location Existing/New/Modified

Freeport-McMoRan Oil & 

Gas LLC Shorebase

Fourchon, Louisiana Existing

MI-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 14 – 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 equipment, 

guidelines for the prevention of adverse environmental effects, effective environmental 

protection, emergency plans and contingency plans. Alabama policies have been 

addressed below or are cross referenced to the appropriate sections of the plan: 

Topic Cross 

Reference

Comments

Coastal 

Resource Use 

Policies

Coastal 

Development

Dock and port facilities in Louisiana will be used. There 

will be no new construction, dredging, or filling in 

Alabama state waters. There will be no new commercial 

development or capital improvements in Alabama’s 

coastal zone, nor will there be any employment effects.

Mineral 

Resource 

Exploration 

and Extraction

Proposed exploration operations will take place 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 14 – 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 was previously submitted and approved on March 

21, 2014 (Plan Control No. 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 

such 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 15 – 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 FACTORS 

ENVIRONMENTAL IMPACT ANALYSIS WORKSHEET

Environment

Resources

Impact Producing Factors (IPFs)

Categories and Examples

Refer to recent GOM OCS Lease Sale EIS for a more complete list of IPFs

Emissions 

(air, noise, 

light, etc.)

Effluents 

(muds, 

cutting, other 

discharges to 

the water 

column or 

seafloor)

Physical 

disturbances to the 

seafloor (rig or 

anchor 

emplacements, 

etc.)

Wastes sent 

to shore for 

treatment 

or disposal

Accidents 

(e.g., oil 

spills, 

chemical 

spills, H2S 

releases)

Discarded

Trash &

Debris

Site-specific at Offshore 

Location

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

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

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

Benthic communities (4)

Water quality X X

Fisheries X X

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

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

Air quality X(9)

Shipwreck sites (known or 

potential)

(7)

Prehistoric archaeological sites X(7)

Vicinity of Offshore Location

Essential fish habitat X X(6)

Marine and pelagic birds X X

Public health and safety (5)

Coastal and Onshore

Beaches X(6) X

Wetlands X(6)

Shore birds and coastal nesting 

birds

X6)

Coastal wildlife refuges

Wilderness areas
Footnotes for Environmental Impact Analysis Matrix

1) Activities that may affect a marine sanctuary or topographic feature. Specifically, if the well or platform site or 

any anchors will be on the seafloor within the:

o 4-mile zone of the Flower Garden Banks, or the 3-mile zone of Stetson Bank;

o 1000-m, 1-mile or 3-mile zone of any topographic feature (submarine bank) protected by the Topographic 

Features Stipulation attached to an OCS lease;

o Essential Fish Habitat (EFH) criteria of 500 ft. from any no-activity zone; or

o Proximity of any submarine bank (500 ft. buffer zone) with relief greater than 2 meters that is not protected 

by the Topographic Features Stipulation attached to an OCS lease.

2) Activities with any bottom disturbance within an OCS lease block protected through the Live Bottom (Pinnacle 

Trend) Stipulation attached to an OCS lease.

3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (LowRelief) Stipulation attached to an OCS lease.

4) Activities on blocks designated by the BOEM as being in water depths 300 meters or greater.

5) Exploration or production activities where H2S concentrations greater than 500 ppm might be encountered.

6) All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that you 

determine would impact these environmental resources. If the proposed action is located a sufficient distance 

from a resource that no impact would occur, the EIA can note that in a sentence or two.

7) All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block designated 

by the BOEM as having high-probability for the occurrence of shipwrecks or prehistoric sites, including such 

blocks that will be affected that are adjacent to the lease block in which your planned activity will occur. If the 

proposed activities are located a sufficient distance from a shipwreck or a prehistoric site that no impact would 

occur, the EIA can note that in a sentence or two.

8) All activities that you determine might have an adverse effect on endangered or threatened marine mammals or 

sea turtles or their critical habitats.

9) Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges.
(B) Analysis

Site-Specific at 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 Features

Potential IPFs on topographic features include effluents, and accidents. 

Effluents: Viosca Knoll Block 915 is 101 miles from the closest designated Topographic 

Features Stipulation Block (Sackett Bank); therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to 

benthic organisms only if the oil contacts the organisms. Oil from a surface spill can be driven 

into the water column; measurable amounts have been documented down to a 10 m depth. At 

this depth, the oil is found only at concentrations several orders of magnitude lower than the 

amount shown to have an effect on corals. Because the crests of topographic features in the 

Northern Gulf of Mexico are found below 10 m, no oil from a surface spill could reach their 

sessile biota. Oil from a subsurface spill is not applicable due to the distance of these blocks from 

a topographic area. The activities proposed in this plan will be covered by FM O&G’s Regional 

OSRP (refer to information submitted in Section 8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities, which could impact topographic features. 

2. Pinnacle Trend Area Live Bottoms

Potential IPFs on pinnacle trend area live bottoms include effluents and accidents. 

Effluents: Viosca Knoll Block 915 is 70 miles from the closest live bottom (pinnacle trend) 

area; therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills have the potential to 

foul benthic communities and cause lethal and sublethal effects on live bottom organisms. Oil 

from a surface spill can be driven into the water column; measurable amounts have been 

documented down to a 10 m depth. At this depth, the oil is found only at concentrations several 

orders of magnitude lower than the amount shown to have an effect on marine organisms. Oil 

from a subsurface spill is not applicable due to the distance of these blocks from a live bottom 
(pinnacle trend) area. The activities proposed in this plan will be covered by FM O&G’s

Regional OSRP (refer to information submitted in Section 8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities which could impact a live bottom 

(pinnacle trend) area. 

3. Eastern Gulf Live Bottoms

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

Effluents: 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 Quality). Oil spills cause damage to live 

bottom organisms only if the oil contacts the organisms. Oil from a surface spill can be driven 

into the water column; measurable amounts have been documented down to a 10 m depth. At 

this depth, the oil is found only at concentrations several orders of magnitude lower than the 

amount shown to have an effect on marine invertebrates. Oil from a subsurface spill is not 

applicable due to the distance of these blocks from a live bottom area. The activities proposed in 

this plan will be covered by FM O&G’s Regional OSRP (refer to information submitted in 

Section 8). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for disposal) from the proposed activities which could impact an Eastern Gulf live 

bottom area. 

4. Benthic Communities 

There are no IPFs (including emissions, physical disturbances to the seafloor, wastes sent to 

shore for disposal, or accidents) from the proposed activities that could cause impacts to benthic 

communities.

A 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 Quality

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: Oil spills have the potential to alter offshore water quality; however, it is unlikely 

that an accidental surface or subsurface spill would occur from the proposed activities. Between 

1980 and 2000, OCS operations produced 4.7 billion barrels of oil and spilled only 0.001 percent 

of this oil, or 1 bbl for every 81,000 bbl produced. The spill risk related to a diesel spill from 

drilling operations is even less. Between 1976 and 1985, (years for which data were collected), 

there were 80 reported diesel spills greater than one barrel associated with drilling activities. 

Considering that there were 11,944 wells drilled, this is a 0.7 percent probability of an 

occurrence. If a spill were to occur, the water quality of marine waters would be temporarily 

affected by the dissolved components and small oil droplets. Dispersion by currents and 

microbial degradation would remove the oil from the water column and dilute the constituents to 

background levels. Historically, changes in offshore water quality from oil spills have only been 

detected during the life of the spill and up to several months afterwards. Most of the components 

of oil are insoluble in water and therefore float. The activities proposed in this plan will be 

covered by FM O&G’s Regional Oil Spill Response Plan (refer to information submitted in 

Section 8).

There are no other IPFs (including emissions, physical disturbances to the seafloor, and wastes 

sent to shore for disposal) from the proposed activities which could cause impacts to water 

quality. 

6. Fisheries

IPFs that could cause impacts to fisheries as a result of the proposed operations in Viosca Knoll 

Block 915 include effluents and accidents. 

Effluents: Effluents such as drilling fluids and cuttings discharges contain components and 

properties which are detrimental to fishery resources. Moderate petroleum and metal 

contamination of sediments and the water column can occur out to several hundred meters downcurrent from the discharge point. Offshore discharges are expected to disperse and dilute to very 

near background levels in the water column or on the seafloor within 3,000 m of the discharge 

point, and are expected to have negligible effect on fisheries.

Accidents: An accidental oil spill has the potential to cause some detrimental effects on 

fisheries; however, it is unlikely that such an event would occur from the proposed activities 

(refer to Item 5, Water Quality). The effects of oil on mobile adult finfish or shellfish would 

likely be sublethal and the extent of damage would be reduced to the capacity of adult fish and 

shellfish to avoid the spill, to metabolize hydrocarbons, and to excrete both metabolites and 

parent compounds. The activities proposed in this plan will be covered by FM O&G’s Regional 

OSRP (refer to information submitted in Section 8). 
There are no IPFs from emissions, physical disturbances to the seafloor or wastes sent to shore 

for disposal from the proposed activities which could cause impacts to fisheries. 

7. Marine Mammals

GulfCet II studies revealed that cetaceans of the continental shelf and shelf-edge were almost 

exclusively bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and 

pygmy killer whale, Risso’s dolphin, rough-toothed dolphin, and Cuvier’s beaked whale, 

occurred most frequently along the upper slope in areas outside of anticyclones. IPFs that could 

cause impacts to marine mammals as a result of the proposed operations in 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 discharges contain components which may be detrimental 

to marine mammals. Most operational discharges are diluted and dispersed upon release. Any 

potential impact from drilling fluids would be indirect, either as a result of impacts on prey items 

or possibly through ingestion in the food chain (API, 1989). 

Discarded trash and debris: Both entanglement in, and ingestion of debris have caused the 

death or serious injury of marine mammals (Laist, 1997; MMC, 1999). The limited amount of 

marine debris, if any, resulting from the proposed activities is not expected to substantially harm 

marine mammals. Operators are prohibited from deliberately discharging debris as mandated by 

MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations 

imposed by various agencies including the United States Coast Guard (USCG) and the 

Environmental Protection Agency (EPA).

FM O&G will operate in accordance with the regulations and also avoid accidental loss of solid 

waste items by maintaining waste management plans, manifesting trash sent to shore, and using 

special precautions such as covering outside trash bins to prevent accidental loss of solid waste. 

Special caution will be exercised when handling and disposing of small items and packaging 

materials, particularly those made of non-biodegradable, environmentally persistent materials 

such as plastic or glass. 

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 
presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from FM O&G management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

Accidents: Collisions between support vessels and cetaceans would be unusual events, however 

should one occur, death or injury to marine mammals is possible. Contract vessel operators can 

avoid marine mammals and reduce potential deaths by maintaining a vigilant watch for marine 

mammals and maintaining a safe distance when they are sighted. Vessel crews should use a 

reference guide to help identify the twenty-eight species of whales and dolphins, and the single 

species of manatee that may be encountered in the Gulf of Mexico OCS. Vessel crews must 

report sightings of any injured or dead protected marine mammal species immediately, 

regardless of whether the injury or death is caused by their vessel, to the Marine Mammal and 

Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional Office at (727) 

824-5312, or the Marine Mammal Stranding Network at (305) 862-2850. In addition, if the 

injury or death was caused by a collision with a contract vessel, the BOEM must be notified 

within 24 hours of the strike by email to protectedspecies@boemre.gov. If the vessel is the 

responsible party, it is required to remain available to assist the respective salvage and stranding 

network as needed. 

Oil spills have the potential to cause sublethal oil-related injuries and spill-related deaths to 

marine mammals. However, it is unlikely that an accidental oil spill would occur from the 

proposed activities (refer to Item 5, Water Quality). Oil spill response activities may increase 

vessel traffic in the area, which could add to changes in cetacean behavior and/or distribution, 

thereby causing additional stress to the animals. The effect of oil dispersants on cetaceans is not 

known. The acute toxicity of oil dispersant chemicals included in FM O&G’s OSRP is 

considered to be low when compared with the constituents and fractions of crude oils and diesel 

products. The activities proposed in this plan will be covered by FM O&G’s OSRP (refer to 

information submitted in accordance with Section 8).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed 

activities which could impact marine mammals.

8. Sea Turtles

IPFs that could cause impacts to sea turtles as a result of the proposed operations include 

emissions, effluents, discarded trash and debris, and accidents. GulfCet II studies sighted most 

loggerhead, Kemp’s ridley and leatherback sea turtles over shelf waters. Historically these 

species have been sighted up to the shelf’s edge. They appear to be more abundant east of the 

Mississippi River than they are west of the river (Fritts et al., 1983b; Lohoefener et al., 1990).

Deep waters may be used by all species as a transitory habitat.
Emissions: Noise from drilling activities, support vessels, and helicopters may elicit a startle 

reaction from sea turtles, but this is a temporary disturbance.

Effluents: Drilling fluids and cuttings discharges are not known to be lethal to sea turtles. Most

operational discharges are diluted and dispersed upon release. Any potential impact from 

drilling fluids would be indirect, either as a result of impacts on prey items or possibly through 

ingestion in the food chain (API, 1989). 

Discarded trash and debris: Both entanglement in, and ingestion of, debris have caused the 

death or serious injury of sea turtles (Balazs, 1985). The limited amount of marine debris, if any, 

resulting from the proposed activities is not expected to substantially harm sea turtles. Operators 

are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the 

Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies 

including the United States Coast Guard (USCG) and the Environmental Protection Agency 

(EPA). FM O&G will operate in accordance with the regulations and also avoid accidental loss 

of solid waste items by maintaining waste management plans, manifesting trash sent to shore, 

and using special precautions such as covering outside trash bins to prevent accidental loss of 

solid waste. Special caution will be exercised when handling and disposing of small items and 

packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from FM O&G management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

Accidents: Collisions between support vessels and sea turtles would be unusual events, however 

should one occur, death or injury to sea turtles is possible. Contract vessel operators can avoid 

sea turtles and reduce potential deaths by maintaining a vigilant watch for sea turtles and 

maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to 

help identify the five species of sea turtles that may be encountered in the Gulf of Mexico OCS. 

Vessel crews must report sightings of any injured or dead protected sea turtle species 

immediately, regardless of whether the injury or death is caused by their vessel, to the Marine 

Mammal and Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional 

Office at (727) 824-5312, or the Marine Mammal Stranding Network at (305) 862-2850. In 

addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must 

be notified within 24 hours of the strike by email to protectedspecies@boemre.gov. If the vessel 

is the responsible party, it is required to remain available to assist the respective salvage and 

stranding network as needed. 
All sea turtle species and their life stages are vulnerable to the harmful effects of oil through 

direct contact or by fouling of their food. Exposure to oil can be fatal, particularly to juveniles 

and hatchlings. However, it is unlikely that an accidental oil spill would occur from the proposed 

activities (refer to Item 5, Water Quality). Oil spill response activities may increase vessel traffic 

in the area, which could add to the possibility of collisions with sea turtles. The activities 

proposed in this plan will be covered by FM O&G’s Regional Oil Spill Response Plan (refer to 

information submitted in accordance with Section 8).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed 

activities which could impact sea turtles.

9. Air Quality

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 Viosca 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 designated 

by BOEM as having a high probability for occurrence of shipwrecks, therefore, no adverse 

impacts are expected.

FM O&G will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning 

sonar within a minimum 500’ radius of the proposed well location(s) prior to or upon 

commencement of operations. These locations will be certified by an authorized marine 
archaeologist and by FM O&G to be clear of seafloor archaeological resources, including 

historic shipwrecks. Copies of the certifications and a circle radius plat of the survey area will be 

submitted to the BOEM. Should a resource be encountered, FM O&G will contact the BOEM 

immediately and make every reasonable effort to preserve and protect that cultural resource.

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or 

disposal, or accidents) from the proposed activities that could cause impacts to shipwreck sites. 

11. Prehistoric Archaeological Sites

IPFs that could cause impacts to prehistoric archaeological 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 

utilizing 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 prehistoric 

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 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. .

Accidents: An accidental oil spill has the potential to cause some detrimental effects to 

prehistoric archaeological sites if the release were to occur subsea. However, it is unlikely that 

an accidental oil spill would occur from the proposed activities (refer to Item 5, Water Quality). 

The activities proposed in this plan will be covered by FM O&G’s Regional Oil Spill Response 

Plan (refer to information submitted in accordance with Section 8).

There are no other IPFs (including emissions, effluents or wastes sent to shore for treatment or 

disposal) from the proposed activities which could impact prehistoric archeological sites. 
Vicinity of Offshore Location 

1. Essential Fish Habitat (EFH)

IPFs that could cause impacts to EFH as a result of the proposed operations in 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 

restrictions, and monitoring and toxicity testing are regulated by the EPA NPDES permit, 

thereby eliminating many significant biological or ecological effects. Operational discharges are 

not expected to cause significant adverse impacts to EFH.

Accidents: An accidental oil spill has the potential to cause some detrimental effects on EFH. 

Oil spills that contact coastal bays and estuaries, as well as OCS waters when pelagic eggs and 

larvae are present, have the greatest potential to affect fisheries. However, it is unlikely that an 

oil spill would occur from the proposed activities (refer to Item 5, Water Quality). The activities 

proposed in this plan will be covered by FM O&G’s Regional OSRP (refer to information 

submitted in Section 8).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes 

sent to shore for treatment or disposal) from the proposed activities which could impact essential 

fish habitat.

2. Marine and Pelagic Birds 

IPFs that could impact marine birds as a result of the proposed activities include air emissions, 

accidental oil spills, and discarded trash and debris from vessels and the facilities.

Emissions: Emissions of pollutants into the atmosphere from these activities are far below 

concentrations which could harm coastal and marine birds.

Accidents: An oil spill would cause localized, low-level petroleum hydrocarbon contamination. 

However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, 

Water Quality). Marine and pelagic birds feeding at the spill location may experience chronic, 

nonfatal, physiological stress. It is expected that few, if any, coastal and marine birds would 

actually be affected to that extent. The activities proposed in this plan will be covered by FM 

O&G’s Regional OSRP (refer to information submitted in Section 8).
Discarded trash and debris: Marine and pelagic birds could become entangled and snared in 

discarded trash and debris, or ingest small plastic debris, which can cause permanent injuries and 

death. Operators are prohibited from deliberately discharging debris as mandated by MARPOLAnnex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by 

various agencies including the United States Coast Guard (USCG) and the Environmental 

Protection Agency (EPA). FM O&G will operate in accordance with the regulations and also 

avoid accidental loss of solid waste items by maintaining waste management plans, manifesting 

trash sent to shore, and using special precautions such as covering outside trash bins to prevent 

accidental loss of solid waste. Special caution will be exercised when handling and disposing of 

small items and packaging materials, particularly those made of non-biodegradable, 

environmentally persistent materials such as plastic or glass. Informational placards will be 

posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore 

personnel, including contractors and other support services-related personnel (e.g. helicopter 

pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view 

the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from FM O&G

management or the designated lease operator management that emphasizes their commitment to 

waste management in accordance with NTL No. 2012-G01. Debris, if any, from these proposed 

activities will seldom interact with marine and pelagic birds; therefore, the effects will be 

negligible.

There are no other IPFs (including effluents, physical disturbances to the seafloor, or wastes sent 

to shore for treatment or disposal) from the proposed activities which could impact marine and 

pelagic birds. 

3. Public Health and Safety Due to Accidents.

There are no IPFs (emissions, effluents, physical disturbances to the seafloor, wastes sent to 

shore for treatment or disposal or accidents, including an accidental H2S release) from the 

proposed activities which could cause impacts to public health and safety. In accordance with 

NTL No.’s 2008-G04, 2009-G27, and 2009-G31, sufficient information is included in Section 4

to justify our request that our proposed activities be classified by BSEE as H2S absent. 

Coastal and Onshore 

1. Beaches

IPFs from the proposed activities that could cause impacts to beaches include accidents (oil 

spills) and discarded trash and debris. 

Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches 

and associated resources. Due to the distance from shore (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 Environmental Protection Agency (EPA). FM O&G will operate in 

accordance with the regulations and also avoid accidental loss of solid waste items by 

maintaining waste management plans, manifesting trash sent to shore, and using special 

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as 

plastic or glass. 

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from FM O&G management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities which could impact beaches. 

2. Wetlands 

IPFs from the proposed activities that could cause impacts to wetlands include accidents (oil 

spills) and discarded trash and debris. 

Accidents: It is unlikely that an oil spill would occur from the proposed activities (refer to Item 

5, Water Quality). Due to the distance from shore (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 

maintaining waste management plans, manifesting trash sent to shore, and using special 

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as 

plastic or glass. 

Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from FM O&G management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities which could impact 

wetlands.

3. Shore Birds and Coastal Nesting Birds

Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. However, it is 

unlikely that an oil spill would occur from the proposed activities (refer to Item 5, Water 

Quality). Given the distance from shore (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: Coastal and marine birds are highly susceptible to entanglement 

in floating, submerged, and beached marine debris: specifically plastics. Operators are prohibited 

from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic 

Pollution Research and Control Act, and regulations imposed by various agencies including the 

United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). FM O&G

will operate in accordance with the regulations and also avoid accidental loss of solid waste 

items by maintaining waste management plans, manifesting trash sent to shore, and using special 

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as 

plastic or glass.

 

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 
indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from FM O&G management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities that could cause impacts to 

shore birds and coastal nesting birds. 

4. Coastal Wildlife Refuges 

Accidents: An accidental oil spill from the proposed activities could cause impacts to coastal 

wildlife refuges. However, it is unlikely that an oil spill would occur from the proposed activities 

(refer to Item 5, Water Quality). Due to the distance from shore (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: Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and 

the Environmental Protection Agency (EPA). FM O&G will operate in accordance with the 

regulations and also avoid accidental loss of solid waste items by maintaining waste management 

plans, manifesting trash sent to shore, and using special precautions such as covering outside 

trash bins to prevent accidental loss of solid waste. Special caution will be exercised when 

handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass.

 

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from FM O&G management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities that could cause impacts to 

coastal wildlife refuges.
5. Wilderness Areas

Accidents: An accidental oil spill from the proposed activities could cause impacts to wilderness 

areas. However, it is unlikely that an oil spill would occur from the proposed activities (refer to 

Item 5, Water Quality). Due to the distance from the nearest designated Wilderness Area (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 nonbiodegradable, environmentally persistent materials such as plastic or glass.

 

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from FM O&G management or the designated lease 

operator management that emphasizes their commitment to waste management in accordance 

with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

sent to shore for treatment or disposal) from the proposed activities that could cause impacts to 

wilderness areas.

6. Other Environmental Resources Identified

There are no other environmental resources identified for this impact assessment. 

(C) IMPACTS ON PROPOSED ACTIVITIES

The site–specific environmental conditions have been taken into account for the proposed 

activities. No impacts are expected on the proposed activities from site-specific environmental 

conditions. 

(D) ENVIRONMENTAL HAZARDS 

During the hurricane season, June through November, the Gulf of Mexico is impacted by an 

average of ten tropical storms (39-73 mph winds), of which six become hurricanes ( > 74 mph 
winds). Due to its location in the gulf, 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 & completion 

a. Secure well

b. Secure rig / platform

c. Evacuate personnel

Drilling activities will be conducted in accordance with NTL No.’s 2008-G09, 2009-G10, and 

2010-N10. 

2. Structure Installation

 Operator will not conduct structure installation operations during Tropical Storm or 

Hurricane threat.

(E) ALTERNATIVES

No alternatives to the proposed activities were considered to reduce environmental impacts.

(F) MITIGATION MEASURES

No mitigation measures other than those required by regulation will be employed to avoid, 

diminish, or eliminate potential impacts on environmental resources. 

(G) CONSULTATION

No agencies or persons were consulted regarding potential impacts associated with the proposed 

activities. Therefore, a list of such entities has not been provided. 

(H) PREPARER(S)

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 Petroleum Institute (API). 1989. Effects of offshore petroleum operations on cold 

water marine mammals: a literature review. Washington, DC: American Petroleum 

Institute. 385 pp. 

Balazs, G.H. 1985. Impact of ocean debris on marine turtles: entanglement and ingestion. In: 

Shomura, R.S. and H.O. Yoshida, eds. Proceedings, Workshop on the Fate and Impact of

Marine Debris, 26-29 November 1984, Honolulu, HI. U.S. Dept. of Commerce. NOAA 

Tech. Memo. NOAA-TM-NMFS-SWFC-54. Pp 387-429. 

Burke, C.J. and J.A. Veil. 1995. Potential benefits from regulatory consideration of synthetic 

drilling muds. Environmental Assessment Division, Argonne National Laboratory, 

ANL/EAD/TM-43. 

Daly, J.M. 1997. Controlling the discharge of synthetic-based drilling fluid contaminated 

cuttings in waters of the United States. U.S. Environmental Protection Agency, Office of 

Water. Work Plan, June 24, 1997. 

Hansen, D.J. 198l. The relative sensitivity of seabird populations in Alaska to oil pollution. U.S.

Dept. of the Interior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLMYK-ES-81-006-1792. 

Laist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris 

including a comprehensive list of species with entanglement and ingestion records. In: Coe, 

J.M. and D.B. Rogers, eds. Marine debris: sources, impacts, and solutions. New York, NY: 

Springer-Verlag. Pp. 99-139. 

Majors, A.P. and A.C. Myrick, Jr. 1990. Effects of noise on animals: implications for dolphins 

exposed to seal bombs in the eastern tropical Pacific purse-seine fishery–an annotated 

bibliography. NOAA Administrative Report LJ-90-06. 

Marine Mammal Commission. 1999. Annual report to Congress – 1998. 

Piatt, J.F., C.J. Lensink, W. Butler, M. Kendziorek, and D.R. Nysewander. 1990. Immediate 

impact of the Exxon Valdez oil spill on marine birds. The Auk. 107 (2): 387-397 

Vauk , G., E. Hartwig, B. Reineking, and E. Vauk-Hentzelt. 1989. Losses of seabirds by oil 

pollution at the German North Sea coast. Topics in Marine Biology. Ros, J.D, ed. Scient. 

Mar. 53 (2-3): 749-754. 

Vermeer, K. and R. Vermeer, 1975 Oil threat to birds on the Canadian west coast. The Canadian 

Field-Naturalist. 89:278-298. 
Although not cited, the following were utilized in preparing this EIA:

• Hazard Surveys 

• BOEM EIS’s:

o GOM Deepwater Operations and Activities. Environmental Assessment. BOEM 2000-

001 

o GOM Central and Western Planning Areas Sales 166 and 168 Final Environmental 

Impact Statement. BOEM 96-0058. 
Freeport-McMoRan Oil & Gas LLC Section 16 – Pg. 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 locations of the planned wells have been removed from the 

Public Information copy of this EP as well as any discussions of the target objectives, 

geologic or geophysical data, and any interpreted geology.

16.2 BIBLIOGRAPHY

1. Initial Exploration Plan (Control No. N-2908).

2. Revised Exploration Plan (Control No. 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 

Assessment 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, 2014

(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.