UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - R-06085

Type - Revised Exploration Plan

Lease(s) - OCS-G25103 Block - 707 Mississippi Canyon Area

Operator - LLOG Exploration Offshore, L.L.C.

Wells B and C

4VCNFSTJCMF
%14FNJTVCNFSTJCMFBOE%SJMMTIJQ

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.

Chiquita Hill

Plan Coordinator

Description -

Rig Type -

Subject:

From:

July 7, 2014
UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - R-06085

Type - Revised Exploration Plan

Lease(s) - OCS-G25103 Block - 707 Mississippi Canyon Area

Operator - LLOG Exploration Offshore, L.L.C.

Wells B and C

4VCNFSTJCMF
%14FNJTVCNFSTJCMFBOE%SJMMTIJQ

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.

Chiquita Hill

Plan Coordinator

Description -

Rig Type -

Subject:

From:

July 7, 2014
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

LLOG EXPLORATION OFFSHORE, L.L.C.

1001 Ochsner Boulevard, Suite 200

Covington, Louisiana 70433

PUBLIC INFORMATION COPY

REVISED

EXPLORATION PLAN

OCS-G-25103 LEASE

MISSISSIPPI CANYON BLOCK 707

PREPARED BY:

Nelda Runyon/Kathy Gowland

Regulatory Specialist

985-801-4300 (Main)

985-801-4389 (Direct)

neldar@llog.com

kathygo@llog.com

Dated: February 25, 2014

Amended: June 12, 2014
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

LLOG EXPLORATION OFFSHORE, L.L.C.

REVISED EXPLORATION PLAN

OCS-G-25103 

MISSISSIPPI CANYON BLOCK 707 

APPENDIX A Plan Contents 

APPENDIX B General Information 

APPENDIX C Geological, Geophysical Information 

 

APPENDIX D H2S Information 

APPENDIX E Biological, Physical and Socioeconomic Information 

APPENDIX F Waste and Discharge Information 

APPENDIX G Air Emissions Information

 

APPENDIX H Oil Spill Information

APPENDIX I Environmental Monitoring Information 

APPENDIX J Lease Stipulation Information 

APPENDIX K Environmental Mitigation Measures Information 

APPENDIX L Related Facilities and Operations Information 

APPENDIX M Support Vessels and Aircraft Information 

APPENDIX N Onshore Support Facilities Information 

APPENDIX O Coastal Zone Management Act (CZMA) Information 

APPENDIX P Environmental Impact Analysis 

APPENDIX Q Administrative Information
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX A

PLAN CONTENTS

(30 CFR Part 250.211 and 250.241)

(A) Plan information: In accordance with 30 CFR 250.211 and 250.241(a), NTL 

No. 2008-G04 and NTL 2010-N06, LLOG Exploration Offshore, LLC (LLOG) 

proposes to revise the previously approved Initial Exploration Plan (Control No. 

N-07922) filed by Westport for the drilling, completion and testing and 

installation of subsea wellhead and/or manifold for proposed locations “B” and 

“C”. LLOG is revising both the “B” and “C” locations and adding a DP 

Semisubmersible Rig and Drillship to possibly drill and complete Locations “B” 

and “C”. The previously approved “A” location has been drilled and completed

as the MC 707 Well No. SS001.

Included as Attachment A is Form MMS 137 “OCS Plan Information Form”, 

which provides for the drilling, completion, and testing of Well Locations B and 

C, Mississippi Canyon Block 707.

(B) Location:

Attachment B – Well Location Plats

Attachment C – Bathymetry Map detailing the proposed surface locations

disturbance area with the proposed anchor radius of the drilling 

rig.

(C) Safety & pollution features:

LLOG will utilize a drillship, semi-submersible moored rig or DP Semisubmersible rig for the proposed operations. A description of the drilling unit is 

included on the OCS Plans Information Form. Rig specifications will be made 

part of the Application for Permit to Drill.

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

and blowout prevention equipment as described in Title 30 CFR Part 250, 

Subparts C, D, E and G; and further clarified by BOEM’s Notices to Lessees, and 

currently policy making invoked by BOEM, EPA and USCG. Appropriate life 

rafts, life jackets, ring buoys, etc., will be maintained on the facility at all times.

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

drains on the drilling deck areas to collect all contaminants and debris.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

(D) Storage Tank and Production Vessels

The following tables detail the storage tanks and/or production vessels that will 

store oil (capacity greater than 25 bbls. or more) and be used to support the 

proposed activities (MODU, barges, platforms, etc.): 

Type of 

Storage Tank

Type of 

Facility

Tank 

Capacity 

(bbls)

Number of 

tanks

Total 

Capacity 

(bbls)

Fluid Gravity 

(API)

Fuel Oil 

Storage Tank

Drillship 16,564 bbls 1 16,564 No. 2 Diesel -

43

Fuel Oil 

Storage Tank

16,685.5 1 16,685.5 No. 2 Diesel -

43

Fuel Oil 

Settleing Tank

836.6 2 1,673.2 No. 2 Diesel -

43

Fuel Oil Day 

Tanks

836.6 2 1,673.2 No. 2 Diesel -

43

Type of 

Storage Tank

Type of 

Facility

Tank Capacity 

(bbls)

Number of 

tanks

Total 

Capacity 

(bbls)

Fluid Gravity 

(API)

Fuel Oil 

(Marine Diesel)

DP SemiSubmersible164 1 164 0.876

Fuel Oil Day 367 2 734 0.876

Emergency 

Generator

31 1 31 0.876

Forward Hull 

Fuel Oil

4634 2 9268 0.876

Lower Aft Hull 

Fuel Oil

3462 2 6924 0.876

Lube Oil 

Services

117/10.5/4.6 3 132 0.8

Dirty Lube Oil 38/28 2 66 0.8

Dirty Bilge 190 4 760 .10

Type of 

Storage Tank

Type of 

Facility

Tank 

Capacity 

(bbls)

Number of 

tanks

Total 

Capacity 

(bbls)

Fluid Gravity 

(API)

Fuel Oil 

(Marine 

Diesel)

SemiSubmersible95.24 2 190.5 No. 2 Diesel –

43

2917.8 4 11,671.2

Total 11,861.7

A. Pollution Prevention Measures

Not applicable to this plan. The State of Florida is not an affected state with 

regards to the proposed operations. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

B. Additional Measures

LLOG does not propose any additional safety, pollution prevention, or early 

detection measure beyond those required in 30 CFR 250 and per December 

13, 2010 G uidance for Deepwater Drilling to Comply with Strengthened 

Safety and Environmental Standards.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

OCS PLAN INFORMATION FORM

Attachment A

(Proprietary Information)

 
U.S. Department of the Interior OMB Control Number: 1010-0151

Bureau of Ocean Energy Management OMB Approval Expires: 12/31/14

 

OCS PLAN INFORMATION FORM 

General Information 

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

Company Name: BOEM Operator Number: 

Address: Contact Person: 

Phone Number: 

E-Mail Address: 

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

Project and Worst Case Discharge (WCD) Information

Lease(s): Area: Block(s): Project Name (If Applicable): 

Objective(s) Oil Gas Sulphur Salt Onshore Support Base(s): 

Platform/Well Name: Total Volume of WCD: API Gravity: 

Distance to Closest Land (Miles): Volume from uncontrolled blowout: 

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

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

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

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

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

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

Proposed Activity Start Date End Date No. of Days 

Exploration drilling 

Development drilling 

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 Drillship Caisson Tension leg platform

Gorilla Jackup Platform rig Fixed platform Compliant tower 

Semisubmersible Submersible Spar Guyed tower

DP Semisubmersible Other (Attach Description) 

Drilling Rig Name (If Known): 

Floating production 

system 

Other (Attach Description) 

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 
Schedule of Activities

WELL / 

EVENT 

SPUD TD COMPL 

START

COMPL 

FINISH

DESCRIPTION NO OF DAYS

MC 707 "C" 10/15/2014 12/17/2014 DRILL 63

MC 707 "C" 12/17/2014 01/21/2015 Complete 35

MC 707 “B” 12/01/2015 01/23/2016 DRILL 53

MC 707 “B” 01/23/2016 03/03/2016 Complete 40
Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name): Subsea Completion 

Anchor Radius (if applicable) in feet: Yes No 

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS OCS 

Area Name    

Block No.

Blockline 

Departures 

(in feet)

N/S Departure: F L N/S Departure: F L 

E/W Departure: F L E/W Departure: F L 

Lambert X-Y

coordinates

X: X: 

Y: Y: 

Latitude/ 

Longitude

Latitude Latitude 

Longitude Longitude 

TVD (Feet): MD (Feet): Water Depth (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 = 

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35) requires us 

to inform you that BOEM collects this information as part of an applicant’s Exploration Plan or Development Operations 

Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for 

OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An 

agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays 

a currently valid Office of Management and Budget Control Number. The use of this form is voluntary. The public 

reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations 

Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an accompanying EP 

(1,000 hours in AKOCSR), or 690 (1,700 in AKOCSR) with an accompanying DPP or DOCD, including the time for 

reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. 

Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance 

Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170. 

2

OCS PLAN INFORMATION FORM (CONTINUED) 

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

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

OCS PLAN INFORMATION FORM (CONTINUED) 

Provide the following information for the well with the highest Worst Case Discharge volume: 

Worst Case Discharge (WCD) Well Information

WCD Well 

Name

Surface Lease Surface 

Area/Block

Bottom Lease Bottom 

Area/Block

Product Type MD TVD

C G25103 MC707 G25103 MC707 Oil 18398 17200

Geologic Data for WCD

Open Hole Interval for WCD

Top (TVD in feet) Base (TVD in feet)

9678 14610

Sand 1 Sand 2 Sand 3 Sand 4 Sand 5

Formation Data

Sand Name

Estimated Top TVD 9920 10420 11820 13690 14070

Estimated Base TVD 9980 10520 11945 13820 14130

Estimated Net Sand Height MD

(Net Pay if hydrocarbon)_ 40 75 40 55

Estimated Net Sand Height 

TVT (Net Pay if hydrocarbon)_ 40 75 40 55

Fluid Type Oil Oil Oil Oil Water

Used in WCD? (Yes/No) Yes Yes Yes Yes No

Seismic Survey Used

TGS Freedom WAZ PSDM

Engineering Data for WCD

WCD Engineering Items

WCD (STB/Day) 140953

WCD Calculated at Mudline? (Yes/No) Yes Atmosphere? (Yes/No) No

Flow Correlation Beggs and Brill

Outlet Pressure (Psia) 683

Gas Turbulence Factor 0

Software Model Used Gemini (Merlin and Avalon)

Sand 1 Sand 2 Sand 3 Sand 4 Sand 5

Formation Data

Sand Name 10000 10500 BN1 BN2 BN3

Permeability (mD) 333 234 179 218 135

Initial Pressure (PSIA) 6933 7353 8874 9773 9872

BOEMRE FORM MMS-0137 (Mo/Year - Supersedes all previous editions of this form which may not be used.) Page 3 of 4 

Analog Well(s)

Area/Block OCS Lease Well No. API No.

MC707 G25103 SS001ST00BP00 60-817-41039-00

MC707 G25103 SS001ST01BP00 60-817-41039-01

MC707 G25103 SS001ST02BP00 60-817-41039-02
OCS PLAN INFORMATION FORM (CONTINUED) 

Reservoir Temperature (F) 135 142 164 186 189

Porosity (0.00) 0.3 0.28 0.3 0.27 0.253

Water Saturation (0.00) 0.19 0.27 0.25 0.33 0.37

Rock Compressibility 

(microsips)

40 40 40 40 40

Water Salinity (ppm) 104000 104000 104000 104000 104000

Drive Mechanism Small, Aquifer/HC 

ratio= 14

Small, Aquifer/HC 

ratio= 19

Small, 

Aquifer/HC 

ratio= 17

Depletion Large, Aquifer/HC 

ratio= 50010

Drainage Area (acres) 88 239 459 175 0

Oil Reservoir Data

Bubble Point Pressure (PSIA) 6732 6776 6901 7011 7030

Initial Bo (RB/STB) 1.49 1.49 1.48 1.48 1.48

Bo (RB/STB) @ Bubble Point 1.49 1.49 1.51 1.52 1.52

Rsi (SCF/STB) 1223 1223 1223 1223 1223

Initial Oil Viscosity (Cp) 0.84 0.84 0.86 0.86 0.9

Oil Viscosity (CP) @ Bubble 

Point

0.82 0.8 0.75 0.71 0.74

Oil Compressibility (μsip) 10 10 10 10 10

Oil API Gravity (API) 26.9 26.9 26.9 26.9 26.9

Specific Gas Gravity (0.00) 0.61 0.61 0.61 0.61 0.61

Gas Reservoir Data

Condensate API Gravity (API)

Specific Gas Gravity (0.00)

Yield (STB/MMCF)

Source of Permeability Used

Permeability from MDT

Permeability from Core Analysis Percussion core Rotary sidewall core Conventional core

Pressure Transient Analysis

Permeability from CMR or NMR log analysis

Permeability from other source OCS-G25103 SS001ST01BP00 and OCS-G25103 SS001ST02BP00 log analysis using Tixier

formula for GOM

Provide Model Input Values for Relative Permeability:

Residual Oil to Gas fraction (=1-Slc-Swc) 0.2

Residual Oil to Water fraction (=Soc) 0.2

Critical Gas fraction (Sgc, Gas/Oil-Water Systems) 0.05

Residual Gas to Water fraction (Sgc, Gas/Gas-Water Systems)

Kro Oil Curve Endpoint (fraction of absolute permeability) 1

Krg Gas Curve Endpoint (fraction of absolute permeability) 1

Krw Water Curve Endpoint (fraction of absolute permeability) 0.15

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEMRE collects this information as part of an applicant’s Exploration Plan or Development Operations 

Coordination Document submitted for BOEMRE approval. We use the information to facilitate our review and data entry for OCS 

plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 250.197. An agency may not 

conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid Office 

of Management and Budget Control Number. Responses are mandatory. The public reporting burden for this form is included in 

the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to 

average 600 hours per response, or 640 with an accompanying EP (1,000 hours in AKOCSR), or 690 (1,700 in AKOCSR) with an 

accompanying DPP or DOCD, including the time for reviewing instructions, gathering and maintaining data, and completing and 

reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to 

the Information Collection Clearance Officer, Mail Stop 5438, Bureau of Ocean Energy Management, Regulation and Enforcement, 

1849 C Street, NW, Washington, DC 20240.

BOEMRE FORM MMS-0137 (Mo/Year - Supersedes all previous editions of this form which may not be used.) Page 4 of 4
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

WELL LOCATION PLAT

Attachment B

(Proprietary Information)

Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

BATHYMETRY MAP

Attachment C

(Public Information)


C Gardline Report #

ANCHORING ASSESSMENT – Proposed MC707-B Well Surface Location

Proposed MC707-B Location (Surface)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid NAD 27 Datum - Clarke 1866 Ellipsoid

Latitude 28° 13' 14.35” North Easting 741,861 US ft E

Longitude 89° 47’ 26.05” West Northing 10,251,385 US ft N

FEL of MC 707 2,619ft US ft Inline 3551

FSL of MC 707 2,905ft US ft Crossline 5222

Water Depth: -1,567 ft Slope: 2.7° ENE

Nearest Shoreline 51 Miles @ 24°

Port of Operation Fourchon 65 Miles @ 336o

Nearest Manned Platform Gomez MC711 11 Miles @ 091o

Anchor Pattern:

LLOG Exploration Offshore LLC has not as yet issued a specific anchor pattern to retain the 

drilling rig. The anchor radius illustrated on Plats and Charts for the proposed Block MC707-

B well surface location is the maximum predicted radius of 7,000ft. An anchor-spread pattern 

can be designed as an addendum to this report after the drilling rig has been identified. The 

anchor pattern will be designed to avoid any infrastructure and potentially sensitive seabed 

habitats. 

Bathymetry

Water depth at the proposed MC707-B well surface location is -1,567ft below sea-surface. 

The seafloor deepens evenly to the ENE at 2.7°.

Seabed Morphology, Faults and Sensitive Sessile Benthic Communities

The seabed within the radius of the proposed anchor pattern deepens evenly to the ENE. 

The proposed well is located in an area of smooth seabed within a slight bathymetrical high 

area. 

Areas considered to be potential sites for hosting sensitive sessile benthic communities are 

located to the southwest of the proposed well location beyond the 2,000ft radius. Two 

potential larger sites were identified, one to the WSW at 2,159ft from the propose location, 

and the second to the SSW at 2,551ft. These must be avoided by at least 250ft by all 

anchoring activities.

Two mud mounds are identified, one to the northeast and the other to the southwest of the 

proposed well. These mud volcanoes must be avoided by all anchor activity.
LLOG Exploration Offshore LLC Gardline Report 9946.01

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-B Well Location

Seabed faults occur to the southwest and the northwest of the 7,000ft radius. Avoidance of 

the seabed fault scarps is recommended.

Several seabed drainage pathways traverse the anchor radius area. These should not affect 

anchor positioning.

Several pipelines and an existing well are located within the 7,000ft radius. The following are 

the coordinates:

Well Installation:

Operator Block Well No. API No. Depth (ft) TVD Easting Northing Status

LLOG 

Exploration

MC707 001 60 817 41039-02 -1,538 13,920 741,345 10,250,692 COM

Several pipelines occur within the 2,000ft radius. The following is the pipeline information:

Pipeline Installations: 

Operator Area Block - Origin/Termination Outside Diameter (in) Product Status

LLOG Exp Offshore 

LLC

MC707 / MC705 6 5/8 in BLKO (Gas) ACT

LLOG Exp Offshore 

LLC

MC751 / MC707 6 5/8in BLKO (Oil) ACT

LLOG Exp Offshore 

LLC

GI 115 / MC707 3 1/2in UMB ACT

LLOG Exp Offshore 

LLC

MC707 / MC751 2 1⁄2 and 2 7/8in UMBH ACT

No other features which may impact anchor emplacement are observed within the 7,000ft 

anchor radius. 

All anchors will be positioned using a precise DGPS system.

Charts 1, 2, and 3 illustrate an anchor radius of 7,000ft for the proposed Block MC707-B 

location at 1”=1,000ft. Proposed Block MC707-B Location Anchor Plat (overleaf) illustrates 

the anchor radius at 1”=4,000ft.
0 4,000 8,000 16,000 Feet

0 1,000 2,000 4,000 Meters

Chart scale 1" = 4,000'

Anchor Plat (MC707-B)

Depth in feet below sea surface to

seabed, contoured at 25ft intervals

-1525

Proposed MC707-B Well

LLOG 6 5/8" Gas (17457)

LLOG 6 5/8" Gas (17458)

ATP 10 3/4" Gas (16115)

ATP 11" Gas Abandoned (15052)

LLO

G 6 5/8" Oil (18603)

LLO

G 2 1/2" Umbilical (18605)

-1500

-1475

-1750

-1725

-1700

-1675

-1650

-1625

-1600

-1575

-1525 -1550

-1775

-1450

-1425

-1800

-1825

-1850

-1400

-1875

-1900

-1375

-1350 -1325

-1300

-1925

-1950

-1275

-1975

-1250

-2000

-1225

-2025

-2050

-1200

-1550

-1525

-1575

-1500

-1400

-1450

-1300

-1400

-1500

-1275

LLOG 3 1/2" Umbilical (17505)

89°46'0"W89°48'0"W89°50'0"W

28°14'0"N

28°12'0"N

730,000740,000750,000

10,240,000

10,250,000

10,260,000

Seabed fault intersection, tick denotes

downthrown block

7,000ft Max Anchor Radius 1,000 ft Buffer Zone

Seabed hardgrounds, favorable sites for

development of Sensitive Sessile

Benthic Communities

Block boundaries

3® 3

3

3

6 Existing MC707-001 Well

(741,345ft E, 10,250,692ft N)

Pipelines

Proposed MC707-B Surface Location

(741,861ft E, 10,251,385ft N)

2,000ft Rad ui s

±

MISSISSIPPI CANYON BLOCK 707 (OCS-G25103)

MISSISSIPPI CANYON BLOCK 751 (OCS-G33175)

MISSISSIPPI CANYON

BLOCK 708

MISSISSIPPI CANYON

BLOCK 752 (OCS-G34457)

MISSISSIP

PI C

A

N

Y

O

N

B

L

O

C

K 750 MISSISSIP

PI C

A

N

Y

O

N

B

L

O

C

K 706
C Gardline Report #

ANCHORING ASSESSMENT – Proposed MC707-C Well Surface Location

Proposed MC707-C Location (Surface)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid NAD 27 Datum - Clarke 1866 Ellipsoid

Latitude 28° 13' 14.70” North Easting 741,790 US ft E

Longitude 89° 47’ 27.09” West Northing 10,251,314 US ft N

FEL of MC 707 2,690ft US ft Inline 3549

FSL of MC 707 2,834ft US ft Crossline 5222

Water Depth: -1,563 ft Slope: 1.9° ENE

Nearest Shoreline 51 Miles @ 24°

Port of Operation Fourchon 65 Miles @ 336o

Nearest Manned Platform Gomez MC711 11 Miles @ 091o

Anchor Pattern:

LLOG Exploration Offshore LLC has not as yet issued a specific anchor pattern to retain the 

drilling rig. The anchor radius illustrated on Plats and Charts for the proposed Block MC707-

C well surface location is the maximum predicted radius of 7,000ft. An anchor-spread pattern 

can be designed as an addendum to this report after the drilling rig has been identified. The 

anchor pattern will be designed to avoid any infrastructure and potentially sensitive seabed 

habitats. 

Bathymetry

Water depth at the proposed MC707-C well surface location is -1,563ft below sea-surface. 

The seafloor deepens evenly to the ENE at 1.9°.

Seabed Morphology, Faults and Sensitive Sessile Benthic Communities

The seabed within the radius of the proposed anchor pattern deepens evenly to the ENE. 

The proposed well is located in an area of smooth seabed within a slight bathymetrical high 

area. 

Areas considered to be potential sites for hosting sensitive sessile benthic communities are 

located to the southwest of the proposed well location beyond the 2,000ft radius. Two 

potential sites were identified, one to the WSW at 2,022ft from the proposed location, and the 

second to the SSW at 2,450ft. These must be avoided by at least 250ft by all anchoring

activities.

Two mud mounds are identified, one to the northeast and the other to the southwest of the 

proposed well. These mud volcanoes must be avoided by all anchor activity.
LLOG Exploration Offshore LLC Gardline Report TBA

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-C Well Location

Seabed faults occur to the southwest and the northwest of the 7,000ft radius. Avoidance of 

the seabed fault scarps is recommended.

Several seabed drainage pathways traverse the anchor radius area. These should not affect 

anchor positioning.

Several pipelines and an existing well are located within the 7,000ft radius. The following are 

the coordinates:

Well Installation:

Operator Block Well No. API No. Depth (ft) TVD Easting Northing Status

LLOG 

Exploration

MC707 001 60 817 41039-02 -1,538 13,920 741,345 10,250,692 COM

Several pipelines occur within the 2,000ft radius. The following is the pipeline information:

Pipeline Installations: 

Operator Area Block - Origin/Termination Outside Diameter (in) Product Status

LLOG Exp Offshore 

LLC

MC707 / MC705 6 5/8 in BLKO (Gas) ACT

LLOG Exp Offshore 

LLC

MC751 / MC707 6 5/8in BLKO (Oil) ACT

LLOG Exp Offshore 

LLC

GI 115 / MC707 3 1/2in UMB ACT

LLOG Exp Offshore 

LLC

MC707 / MC751 2 1⁄2 and 2 7/8in UMBH ACT

No other features which may impact anchor emplacement are observed within the 7,000ft 

anchor radius. 

All anchors will be positioned using a precise DGPS system.

Charts 1, 2, and 3 illustrate an anchor radius of 7,000ft for the proposed Block MC707-C 

location at 1”=1,000ft. Proposed Block MC707-C Location Anchor Plat (overleaf) illustrates 

the anchor radius at 1”=4,000ft.
0 4,000 8,000 16,000 Feet

0 1,000 2,000 4,000 Meters

Chart scale 1" = 4,000'

Anchor Plat (MC707-C)

Depth in feet below sea surface to

seabed, contoured at 25ft intervals

-1525

Proposed MC707-C Well

LLOG 6 5/8" Gas (17457) LLOG 6 5/8" Gas (17458)

ATP 10 3/4" Gas (16115)

LLO

G 6 5/8" Oil (18603)

LLOG 3 1/2" Umbilical (17505)

LLO

G 2 1/2" Umbilical (18605)

-1500

-1475

-1750

-1725

-1700

-1675

-1650

-1625

-1600

-1575

-1525 -1550

-1775

-1450

-1425

-1800

-1825

-1850

-1400

-1875

-1900

-1375

-1350 -1325

-1300

-1925

-1950

-1275

-1975

-1250

-2000

-1225

-2025 -2050

-1200

-1550

-1525

-1575

-1500

-1400

-1450

-1300

-1400

-1500

-1275

ATP 11" Gas Abandoned (15052)

Existing MC707-001 Well

89°46'0"W89°48'0"W89°50'0"W

28°14'0"N

28°12'0"N

730,000740,000750,000

10,240,000

10,250,000

10,260,000

Seabed fault intersection, tick denotes

downthrown block

7,000 ft Max Anchor

1,000 ft Buffer Zone

Site for potential Sensitive Sessile

Benthic Communities

Block boundaries

Proposed MC707-C Location

(741,790ft E / 10,251,314ft N) 3® 3

3

3

6 Existing Well

Pipelines

2,000ft Radius

Anchor buffer zone

±

MISSISSIPPI CANYON BLOCK 707 (OCS-G25103)

MISSISSIPPI CANYON BLOCK 751 (OCS-G33175)

MISSISSIPPI CANYON

BLOCK 708

MISSISSIPPI CANYON

BLOCK 752 (OCS-G34457)

Seabed hardground
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX B

GENERAL INFORMATION 

(30 CFR Part 250.213 and 250.243)

A. Applications and Permits

There are no Federal/State applications to be submitted for the activities provided 

for in this Plan (exclusive to BOEMRE permit applications and general permits 

issued by the EPA and COE) 

Application/Permit Issuing Agency Status

N/A N/A N/A

B. Drilling Fluids

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

used per Well

Water Based (seawater, freshwater, barite) See Appendix F, Table 1 of this Plan

Oil–based (diesel, mineral oil) N/A

Synthetic-based (internal olefin, ester) See Appendix F, Table 2 of this Plan

C. New Or Unusual Technology

LLOG does not propose using any new and/or unusual technology for the 

operations proposed in this Revised Plan.

D. Bonding Statement

The bond requirements for the activities and facilities proposed in this Revised

Exploration Plan are satisfied by an area wide bond, furnished and maintained 

according to 30 C FR Part 256; subpart I; NTL No. 2000-G16, “Guidelines for 

General Lease Surety Bonds,” and additional security under 30 C FR 256.53(d) 

and NTL No. 2008-N07 “Supplemental Bond Procedures.” 

E. Oil Spill Responsibility (OSFR)

LLOG Exploration Offshore, L.L.C (MMS Co. No. 02058) will demonstrate oil 

spill financial responsibility for the facilities proposed in this Revised EP 

according to 30 CFR Part 253, and NTL No. 2008-N05 “Guidelines for Oil Spill 

Financial Responsibility (OSFR) for Covered Facilities.”
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

F. Deepwater Well Control Statement

LLOG Exploration Offshore, L.L.C. (MMS Co. No. 02058) has the financial 

capability to drill a relief well and conduct other emergency well control 

operations. 

G. Blowout Scenario

The Worst Case Discharge Calculations (Proprietary) is included in this plan as 

Attachment D, and Blowout Scenario, including Site Specific Proposed Relief 

Well and Intervention Planning and Relief Well Response Time Estimate (Public 

Information) is included in this plan as Attachment D-1. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

NTL 2010-N06 Data 

WORST CASE DISCHARGE CALCULATIONS

Attachment D

(Proprietary Information)
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

BLOWOUT SCENARIO

Attachment D-1 

(Public Information)
BLOWOUT SCENARIO

 MC 707

OCS-G-25103

Created by: S.L. Stegeman

Last Revised: 5/27/2014

Page 1 of 6 

Confidential

1 

BLOWOUT SCENARIO 

Pursuant with 30 CFR 250.213(g), 250.219, 250,250 and NTL 2010-N06 the following attachment 

provides a blowout scenario description, information regarding any oil spill, WCD results and assumptions 

of potential spill and additional measures taken to firstly enhance the ability to prevent a blowout and 

secondly to manage a blowout scenario if it occurred. 

INFORMATION REQUIREMENTS

PROPOSED PROSPECT INFORMATION

Well Surface Location WD X (NAD 27) Y (NAD 27) Latitude Longitude

MC 707 “B” OCS-G-25103 1570 741,861’ 10,251,385’ 28° 13’ 13.349”N 89° 47’ 26.045”W

MC 707 “C” OCS-G-25103 1570 741,790’ 10,251,314’ 28° 13’ 13.63”N 89° 47’ 26.82”W

INFORMATION REQUIREMENTS

A) Blowout scenario

The MC 707 prospect to be drilled to potential outlined in the Geological and Geophysical Information 

Section of this plan utilizing a typical subsea wellhead system, conductor, surface and intermediate 

casing strings from a pre-existing wellbore and a MODU rig with marine riser and a subsea BOP 

system. A hydrocarbon influx and a well control event occurring from the objective sand is modeled

with no drill pipe or obstructions in the wellbore followed by a failure of the subsea BOP’s and loss of 

well control at the seabed. The simulated flow and worst case discharge (WCD) results for all wells 

are calculated and the highest WCD is used for this unrestricted blowout scenario.

B) Estimated flow rate of the potential blowout

Category EP

Type of Activity Drilling

Facility Location (area / block) MC 707

Facility Designation MODU

Distance to Nearest Shoreline (miles) ~53

Uncontrolled Blowout (Volume per day) 140,953 bbls (max)

Type of Fluid Crude

C) Total volume and maximum duration of the potential blowout

Duration of Flow (days) 71 days total (see Relief Well Response Estimate below)

Total Volume of Spill (bbls) 6.92 MMBO based on 71 days of uncontrolled flow (based on 

Merlin/Avalon simulator model shown in the Worst Case 

Discharge info)

D) Assumptions and calculations used in determining the worst case discharge

Omitted from Public Information Copies

E) Potential for the well to bridge over

Mechanical failure/collapse of the borehole in a blowout scenario is influenced by several factors 

including in-situ stress, rock strength and fluid velocities at the sand face. Given the substantial fluid 
BLOWOUT SCENARIO

 MC 707

OCS-G-25103

Created by: S.L. Stegeman

Last Revised: 5/27/2014

Page 2 of 6 

Confidential

2 

velocities inherent in the WCD, and the scenario as defined where the formation is not supported by a 

cased and cemented wellbore, it is possible that the borehole may fall/collapse/bridge over within a 

span of a few days, significantly reducing the outflow of the rates. For this blowout scenario, no 

bridging is considered. 

F) Likelihood for intervention to stop blowout

The likelihood of surface intervention to stop a blowout is based on some of the following equipment 

specific to potential MODU’s to be contracted for this well. It is reasonable to assume that the sooner 

you are able to respond to the initial blowout, the better likelihood there is to control and contain the 

event due to reduced pressures at the wellhead, less exposure of well fluids to erode and 

compromise the well control equipment, and less exposure of hydrocarbons to the surface to 

safeguard personnel and equipment in an emergency situation. This equipment includes:

• Secondary Acoustic BOP Control System – typically fitted on DP MODU’s presently operating 

in the GOM. This system has the ability to communicate and function specific BOP controls 

from the surface in the event of a failure of the primary umbilical control system. This system 

typically can establish BOP controls from the surface acoustic system package on the rig or 

by deploying a second acoustic package from a separate vessel of opportunity. This system 

may not be included on all MODU’s such as 4th generation moored rigs. This system is 

typically configured to function the following:

- Blind / shear ram close

- Pipe ram close

- LMRP disconnect

• ROV Intervention BOP Control System – includes one or more ROV intervention panels 

mounted on the subsea BOP’s located on the seabed allows a ROV utilizing standard ROV 

stabs to access and function the specific BOP controls. These functions will be tested at the 

surface as part of the required BOP stump test and selectively at the seafloor to ensure 

proper functionality. These function include the following (at a minimum):

- Blind/shear ram close

- Pipe ram close

- LMRP disconnect

- WH disconnect

 

• Deadman / Autoshear function – typically fitted on DP MODU’s and but to be on all MODU’s 

operating in the GOM according to new requirements, this equipment allows for an 

automated pre-programmed sequence of functions to close the casing shear rams and the 

blind/shear rams in the event of an inadvertent or emergency disconnect of the LMRP or loss 

of both hydraulic and electrical supply from the surface control system.

In the event that the intervention systems for the subsea BOP’s fail, LLOG will initiate call out of a 

secondary containment / surface intervention system supported by the Helix Well Containment Group 

(HWCG) of which LLOG is a member. This system incorporates a capping stack capable of being 

deployed from the back of a vessel of opportunity equipped with an ROV or from the Helix Q4000 DP 

MODU. Based on the potential integrity concerns of the well, a “cap and flow” system can be 

deployed which may include the Helix Producer 1 capable of handling up to 55,000 BOPD flowback. 

The vertical intervention work is contingent upon the condition of the blowing out well and what 

equipment is intact to access the wellbore for kill or containment operations. The available 

intervention equipment may also require modifications based on actual wellbore conditions. Standard 
BLOWOUT SCENARIO

 MC 707

OCS-G-25103

Created by: S.L. Stegeman

Last Revised: 5/27/2014

Page 3 of 6 

Confidential

3 

equipment is available through the Helix Deepwater Containment System to fit the wellhead and BOP 

stack profiles used for the drilling of the above mentioned well. 

G) Availability of rig to drill relief well, rig constraints and timing of rigs

LLOG currently has one deepwater MODU under contract (Noble Amos Runner moored semi). In the 

event of a blowout scenario that does not involve loss or damage to the rig such as an inadvertent 

disconnect of the BOP’s, then the existing contracted rig may be available for drilling the relief well

and vertical intervention work. If the blowout scenario involves damage to the rig or loss of the BOP’s

and riser, a replacement rig or rigs will be required. 

With the current activity level in the GOM, 25 to 35 deepwater MODU’S are potentially available to 

support the relief well drilling operations. Rig share and resource sharing agreements are in place

between members of the Helix Well Containment Group. The ability to negotiate and contract an 

appropriate rig or rigs to drill relief wells is highly probable in a short period of time. If the rig or rigs 

are operating, the time to properly secure the well and mobe the rig to the relief well site location is 

estimated to be about 14 to 21 days. Dynamically positioned (DP) MODU’s would be the preferred 

option due to the logistical advantage versus a moored MODU which may add complications due to 

the mooring spread. 

VESSELS OF OPPORTUNITY

Based on the water depth restrictions for the proposed locations the following “Vessels of 

Opportunity” are presently available for utilization for intervention and containment and relief well 

operations. These may include service vessels and drilling rigs capable of working in the potential 

water depths and may include moored vessels and dynamically positioned vessels. The specific 

conditions of the intervention or relief well operations will dictate the “best fit” vessel to efficiently 

perform the desired results based on the blowout scenario. The list included below illustrates specific 

option that may vary according to the actual timing / availability at the time the vessels are needed.

OPERATION SPECIFIC VESSEL OF OPPORTUNITY

Intervention and Containment • Helix Q4000 (DP Semi) 

• Helix Producer 1 (DP FPU)

Relief Well Drilling Rigs • Diamond Ocean Victory / Ocean Onyx (Moored Semi)

• Ensco 8502 or Ensco 8500 type rigs (DP Semi) 

• Transocean Discover Enterprise (DP Drillship)

• Transoecean Development Driller (DP Semi w/ anchors)

ROV / Multi-Purpose Service Vessels • Oceaneering (numerous DP ROV vessels)

• HOS Achiever, Iron Horse 1 and 2 (DP MPSV)

• Helix Pipe Lay Vessel (equipped w/ 6” PL – 75,000’)

• Other ROV Vessels – (Chouest, HOS, Fugro, Subsea 7)

Shuttle Tanker / Barge Support • OSG Ship Management 

H) Measures taken to enhance ability to prevent blowout

Pursuant to BOEM-2010-034 Final Interim Rules, measures to enhance the ability to prevent or 

reduce the likelihood of a blowout are largely based on proper planning and communication, 

identification of potential hazards, training and experience of personnel, use of good oil field practices 

and proper equipment that is properly maintained and inspected for executing drilling operations of 

the proposed well or wells to be drilled.
BLOWOUT SCENARIO

 MC 707

OCS-G-25103

Created by: S.L. Stegeman

Last Revised: 5/27/2014

Page 4 of 6 

Confidential

4 

When planning and designing the well, ample time is spent analyzing offset data, performing any 

needed earth modeling and identifying any potential drilling hazards or well specific conditions to 

safeguard the safety of the crews when well construction operations are underway. Once the design 

criteria and well design is established, the well design is modeled for the lifecycle of the wellbore to 

ensure potential failure modes are eliminated. Pursuant to BOEM-2010-0034 Interim Final Rules 

implemented additional considerations of a minimum of 2 independent barriers for both internal and 

external flow paths in addition to proper positive and negative testing of the barriers. 

The proper training of crew members and awareness to identify and handle well control event is the 

best way prevent a blowout incident. Contractor’s personnel and service personnel training 

requirements are verified per regulatory requirements per guidelines issued in BOEM-2010-034 

Interim Final Rules. Drills are performed frequently to verify crew training and improve reaction times. 

Good communication between rig personnel, office support personnel is critical to the success of the 

operations. Pre-spud meetings are conducted with rig crews and service providers to discuss, inform 

and as needed improve operations and well plans for safety and efficiency considerations. Daily 

meetings are conducted to discuss planning and potential hazards to ensure state of preparedness 

and behavior is enforced to create an informed and safe culture for the operations. Any changes in 

the planning and initial wellbore design is incorporated and communicated in a Management of 

Change (MOC) process to ensure continuity for all personnel. 

Use of established good oil field practices that safeguard crews and equipment are integrated to 

incorporate LLOG’s, the contractor and service provider policies. 

Additional personnel and equipment will be used as needed to elevate awareness and provide real 

time monitoring of well conditions while drilling such as MWD/LWD/PWD tools used in the bottom 

hole assemblies. The tool configuration for each open hole section varies to optimize information 

gathered including the use of Formation-Pressure-While-Drilling (FPWD) tools to establish real time 

formation pressures and to be used to calibrates pore pressure models while drilling. Log information 

and pressure data is used by the drilling engineers, geologist and pore pressure engineers to 

maintain well control and reduced potential events such as well control events and loss circulation 

events. 

Mud loggers continuously monitor return drilling fluids, drill gas levels and cuttings as well as surface 

mud volumes and flow rates, rate of penetration and lithology/paleo to aid in understanding trends 

and geology being drilled. Remote monitoring of real time drilling parameters and evaluation of 

geologic markers and pore pressure indicators is used to identify potential well condition changes.

Proper equipment maintenance and inspection program for same to before the equipment is required. 

Programmed equipment inspections and maintenance will be performed to ensure the equipment 

operability and condition. Operations will cease as needed in order to ensure equipment and well 

conditions are maintained and controlled for the safety of personnel, rig and subsurface equipment 

and the environment.

I) Measures to conduct effective and early intervention in the event of a blowout

In conjunction with the LLOG Exploration’s “Well Control Emergency Response Plan” and as required 

by NTL 2010-N06, the following is provided to demonstrate the potential time needed for performing 

secondary intervention and drilling of a relief well to handle potential worst case discharge for the 

proposed prospect. Specific plans are integrated into the Helix Well Containment Groups procures to 

be approved and submitted with the Application for Permit to Drill. Equipment availability, backup 

equipment and adaptability to the potential scenarios will need to be addressed based on the initial 
BLOWOUT SCENARIO

 MC 707

OCS-G-25103

Created by: S.L. Stegeman

Last Revised: 5/27/2014

Page 5 of 6 

Confidential

5 

site assessment of the seafloor conditions for intervention operations. Relief well equipment such as 

backup wellhead equipment and tubulars will be available in LLOG’s inventory for immediate 

deployment as needed to address frilling the relief well(s).

SITE SPECIFIC PROPOSED RELIEF WELL AND INTERVENTION PLANNING

No platform was considered for drilling relief wells for this location due to location, water depth and 

lack of appropriate platform within the area. For this reason a moored or DP MODU will be preferred 

/ required. If accessible and needed, there is presently located at the drill center for the MC 707 

locations infrastructure to be used to tie-in and access production flowlines to a shelf production 

facility in GI 115 presently operated by LLOG. This may be a source for a “cap and flow” scenario.

Relief well sites have been initially identified to address blowout scenarios for the potential geologic 

targets for the proposed wells. Two relief well surface locations are proposed for the clustered 3

proposed Exploration Plan wells in water depths around 2100’. Actual relief well sites are common to 

different proposed Exploration Plan wells. Based on actual seafloor state unforeseen at this time, the 

final location(s) may need to be revised. The locations have been selected based on proximity to the 

targets sands and potential shallow hazards. 

Proposed EP Well Proposed Relief Well X (NAD 27) Y (NAD 27)

MC 707- B&C OCS-G-25103 MC 707 RW1* 742,973’ 10,249,482’

MC 707 RW2* 742,415’ 10,252,636’

“*” indicates common relief well site to more than 1 exploration plan well

RELIEF WELL RESPONSE TIME ESTIMATE

OPERATION TIME ESTIMATE 

 (DAYS)

IMMEDIATE RESPONSE 

• safeguard personnel, render first-aid

• make initial notifications

• implement short term intervention (if possible)

• implement spill control

• develop Initial Action Plan

 

 1 

INTERIM REPSONSE

• establish Onsite Command Center and Emergency Management Team

• assess well control issues

• mobilize people and equipment (Helix DW Containment System)

• implement short term intervention and containment (if possible)

• develop Intervention Plan

• initiate relief well planning

• continue spill control measures

 

 4 

INTERVENTION AND CONTAIMENT OPERATIONS 

• mobilize equipment and initiate intervention and containment operations

• perform TA operations and mobilize relief wells rig(s)

• finalize relief well plans, mobilize spud equipment, receive approvals

• continue spill control measures

 14

RELIEF WELL(S) OPERATIONS

• continue intervention and containment measures

• continue spill control measures

• drill relief well (s) 

 36
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX C

GEOLOGICAL AND GEOPHYSICAL INFORMATION

(30 CFR Part 250.214 and 250.244)

A. Geological Description

Included as Attachment E are the geological targets and a narrative of trapping 

features proposed in this plan.

B. Structure Contour Maps

Included as Attachment F are current structure maps (depth base and expressed in 

feet subsea) depicting the entire lease coverage area; drawn on top of the 

prospective hydrocarbon sands. The maps depict the proposed bottom hole 

location and applicable geological cross section.

C. Interpreted Seismic Lines

Included as Attachment G is a copy of the migrated and annotated (shot points, 

time lines, well paths) deep seismic line within 500 feet of the surface location 

being proposed in this Plan.

D. Geological Structure Cross-Sections.

An Interpreted geological cross section depicting the proposed well location and 

depth of the proposed well is included as Attachment H. Such cross section 

corresponds to each seismic line being submitted.

E. Shallow Hazards Report

Tesla Offshore, L.L.C conducted an Archaeological Deep Tow Assessment for 

MC 707 and portions of surrounding blocks in December, 2007, on behalf of 

LLOG Exploration Offshore, L.L.C., submitted to BOEM on January 25, 2008. 

Gardline Surveys Inc. prepared a 3D Geohazard Assessment for proposed 

locations B and C with Well Clearance Letters, on behalf of LLOG which is being 

submitted under separate cover. Gardline Surveys, Inc. prepared a 3D Geohazard 

Assessment for Proposed Revised Locations B and C with Well Clearance 

Letters, on behalf of LLOG Exploration Offshore, Inc., dated June, 2014, 

submitted to BOEM on June 12, 2014.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

F. Shallow Hazards Assessment

A shallow hazards assessment has been prepared for the proposed surface 

location, evaluating the seafloor and subsurface geologic and manmade features 

and conditions, and is included as Attachment I.

G. High Resolution Seismic Lines

Included as Attachment J is a copy of the annotated high resolution survey data 

lines for the surface location disturbance proposed in this Plan.

H. Stratigraphic Column

A generalized biostratigraphic/lithostratigraphic column from the seafloor to the 

total depth of the proposed well is included as Attachment K.

I. Time vs Depth Tables

LLOG has determined that there is existing sufficient well control data for the

target areas proposed in this Plan; therefore, tables providing seismic time versus 

depth for the proposed well locations are not required. 
BLOWOUT SCENARIO

 MC 707

OCS-G-25103

Created by: S.L. Stegeman

Last Revised: 5/27/2014

Page 6 of 6 

Confidential

6 

PERFORM HYDRAULIC KILL OPERATIONS / SECURE BLOWNOUT WELL

• continue intervention and containment measures

• continue spill control measures

• perform hydraulic kill operations, monitor well, secure well

 

 16

 ESTIMATED TOTAL DAYS OF UNCONTROLLED FLOW 71

SECURE RELIELF WELL(S) / PERFORM P&A / TA OPERATIONS / DEMOBE 30

TOTAL DAYS 109
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

GEOLOGICAL DESCRIPTION

Attachment E 

(Proprietary Information)
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

STRUCTURE MAPS

Attachment F 

(Proprietary Information)
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

DEEP SEISMIC LINES

Attachment G 

(Proprietary Information)
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

CROSS SECTION MAPS

Attachment H 

(Proprietary Information) 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

SHALLOW HAZARDS ASSESSMENT

Attachment I 

(Public Information)
 36499 Perkins Road 

 Prairieville, Louisiana 70769 

Telephone: 225.673.2163 

Fax: 225.744.3116 

www.teslaoffshore.com 

May 23, 2014 Job No. 13-257-31 

Bureau of Ocean Energy Management (MS 5230) 

Gulf of Mexico OCS Region 

1201 Elmwood Park Blvd. 

New Orleans, LA 70123-2394

RE: LLOG Exploration Offshore, L.L.C. 

 Proposed OCS-G 25103 ‘B’ Well 

Block 707, Mississippi Canyon Area 

Archaeological Assessment 

LLOG Exploration Offshore, L.L.C. (LLOG) proposes to drill the OCS-G 25103 ‘B’ Well 

from the following surface location: 

Datum: 

NAD 27

 Spheroid: 

Clarke 1866

 Projection: 

UTM

 Zone:

 16 N

Central Meridian:

 87° 00’ West

 Latitude: 28° 13’ 14.349” N Longitude: 89° 47’ 26.045” W

 X: 741,861.00 Y: 10,251,385.00

 FEL: 2,619’ FSL: 2,905’

LLOG selected Tesla Offshore LLC to provide this archaeological assessment of the 

proposed well and associated anchor radius based on high-resolution deep tow 

geophysical site survey centered in Block 707 (OCS-G 25103) with survey coverage 

extending into the adjacent survey blocks (MC 708, 751, and 752). The geophysical 

survey was conducted by Tesla Offshore between September 22nd and 27th, 2007, 

aboard the M/V Terry Bordelon. A dedicated chase vessel was employed for acoustic 

tracking. An archaeological assessment based on the data set was prepared by Tesla 

Offshore and submitted to LLOG (reference number 07-263-13). Complete sonar survey 

coverage was obtained for the entire designated 7,000 foot radius surrounding the 

proposed well site. LLOG operates lease OCS-G 25103 and contracted Tesla Offshore, 

LLC to provide this archaeological analysis (NTL No. 2005-G07) in accordance with 

the Bureau of Ocean Energy Management, Gulf of Mexico OCS Region. 

This archaeological assessment is intended to complement the geo-hazards 

assessment prepared under separate cover, which addresses hazard concerns in 

compliance with NTL 2008-G05 and Deepwater Benthic Communities requirements 

stipulated in NTL 2009-G40. 

Water depth is approximately 1,570 feet surrounding the proposed drill site. Water 

depths across the survey grid increased to the east by an approximate rate of 210 

feet per mile. 

Seafloor sediments are reportedly silty clay (USDI, MMS Visual No. 3, 1983). 
TESLA OFFSHORE 

LLOG Exploration Offshore, L.L.C. 

Proposed OCS-G 25103 ‘B’ Well 

Block 707, Mississippi Canyon Area 

Archaeological Assessment 

Page 2 

Seafloor installations within 2,000 ft of the proposed surface location include Well 

No. SS1 in Block 707, located approximately 860’ to the SW, and its associated 

pipelines. The LLOG 3” pipeline (Segment 17505), LLOG 6” pipeline (Segment 

17458), and LLOG 6” pipeline (Segment 17457) are parallel to one another and 

extend from Well No. SS1 to the WNW, while the LLOG 6” pipeline (Segment 18603) 

and the LLOG 2” pipeline (Segment 18605) are parallel to one another and extend 

from Well No. SS1 to the SSE. The LLOG 2” pipeline (Segment 18605) is located 

closest to the proposed surface location, approximately 710’ to the SW. All of these 

pipelines were installed following survey data acquisition, therefore their reported 

positions should be assumed correct; care should always be exercised near the 

reported position of any pipeline. The only other infrastructure within the survey grid 

is P&A Well No. 1 in Block 751, located approximately 8,430’ to the SW.

Magnetic data is not required for survey in these water depths per NTL 2005-

G07and NTL 2008-G05 (extended by NTL 2013-G02).

Side scan sonar verified that the seafloor immediately surrounding the proposed 

well site was clear of protruding obstructions. Three sonar targets were identified 

within the survey grid, and include targets 2, 3, and 4. Sonar target 1 was identified 

in Block 705 from supplemental survey data shot as part of an associated pipeline 

route survey. None of the reported targets are located within 2,000’ of the proposed 

surface location. Target No. 2 is a semi-circular object measuring approximately 41’ 

by 11’ with 6.5’ of measured relief above the surrounding seafloor, and is located 

approximately 9,490’ WNW of the proposed well site. Target No. 3 is amorphous 

and measures approximately 70' by 40' with no measured relief above the 

surrounding seafloor, and is located approximately 5,790’ NW of the proposed well 

site. Target no. 4 consists of three parallel linear features measuring approximately 

26’ by 8’ with no measured relief above the surrounding seafloor. It is located 

approximately 6,620’ NNE of the proposed well site. The targets do not appear to be 

culturally significant, and likely represent man-made debris or discrete areas of 

seafloor texture changes related to the numerous faults present in the survey area. 

Sonar data also recorded numerous fault scarps and outcrops; the nearest fault 

scarp is located approximately 1,800’ WSW of the proposed well site. The nearest 

outcrop, which was an isolated feature, is located approximately 1,710’ SE of the 

proposed surface location. Two possible expulsion features were observed on the 

sonar data, located approximately 3,620 NE and 3,520’ SW of the proposed surface 

location. 

Supplemental subbottom data showed penetration up to approximately 120 feet, 

consisting of well stratified, parallel layered, moderately reflecting sediments directly 

underneath the proposed well site. Numerous discrete faults were recorded 

throughout the survey area, most of which could not be connected across survey 

lines. Faults were recorded on the survey line closest to the proposed well site at 

depths of 15’ to 20’ BML approximately 280’ and 370’ to the SW. There is no 
TESLA OFFSHORE 

LLOG Exploration Offshore, L.L.C. 

Proposed OCS-G 25103 ‘B’ Well 

Block 707, Mississippi Canyon Area 

Archaeological Assessment 

Page 3 

potential for prehistoric sites in this portion of Mississippi Canyon Area, and no evidence 

of wrecks or other cultural debris were observed on the subbottom data. 

No evidence of potential cultural resources was observed at the proposed well location. 

The proposed well site will be marked with DGPS during rig moves and drilling to comply 

with the BOEM On-Site Requirements specified in NTL No. 2008-G05 (extended by 

NTL 2013-G02), Section VI, Item B-2(a). Pursuant to 30 CFR 550.194 (c), 30 CFR 

550.101 (c), and NTL No. 2005-G07, if any archaeological or potentially historically 

significant materials are observed during lease development, operations will immediately 

cease in that area and appropriate BOEM/BSEE personnel will be notified within 48 

hours of discovery. 

LLOG Exploration Offshore, L.L.C. and subcontractors will apply the safest and best 

available technologies during rig moves and drilling operations. 

Sincerely, 

Erin Voisin, MA Amanda Evans, PhD, RPA 

Archaeologist Marine Archaeologist
 36499 Perkins Road 

 Prairieville, Louisiana 70769 

Telephone: 225.673.2163 

Fax: 225.744.3116 

www.teslaoffshore.com 

May 23, 2014 Job No. 13-257-31 

Bureau of Ocean Energy Management (MS 5230) 

Gulf of Mexico OCS Region 

1201 Elmwood Park Blvd. 

New Orleans, LA 70123-2394

RE: LLOG Exploration Offshore, L.L.C. 

 Proposed OCS-G 25103 ‘C’ Well 

Block 707, Mississippi Canyon Area 

Archaeological Assessment 

LLOG Exploration Offshore, L.L.C. (LLOG) proposes to drill the OCS-G 25103 ‘C’ Well 

from the following surface location: 

Datum: 

NAD 27

 Spheroid: 

Clarke 1866

 Projection: 

UTM

 Zone:

 16 N

Central Meridian:

 87° 00’ West

 Latitude: 28° 13’ 13.630” N Longitude: 89° 47’ 26.820” W

 X: 741,790.00 Y: 10,251,314.00

 FEL: 2,690’ FSL: 2,834’

LLOG selected Tesla Offshore LLC to provide this archaeological assessment of the 

proposed well and associated anchor radius based on high-resolution deep tow 

geophysical site survey centered in Block 707 (OCS-G 25103) with survey coverage 

extending into the adjacent survey blocks (MC 708, 751, and 752). The geophysical 

survey was conducted by Tesla Offshore between September 22nd and 27th, 2007, 

aboard the M/V Terry Bordelon. A dedicated chase vessel was employed for acoustic 

tracking. An archaeological assessment based on the data set was prepared by Tesla 

Offshore and submitted to LLOG (reference number 07-263-13). Complete sonar survey 

coverage was obtained for the entire designated 7,000 foot radius surrounding the 

proposed well site. LLOG operates lease OCS-G 25103 and contracted Tesla Offshore, 

LLC to provide this archaeological analysis (NTL No. 2005-G07) in accordance with 

the Bureau of Ocean Energy Management, Gulf of Mexico OCS Region. 

This archaeological assessment is intended to complement the geo-hazards 

assessment prepared under separate cover, which addresses hazard concerns in 

compliance with NTL 2008-G05 and Deepwater Benthic Communities requirements 

stipulated in NTL 2009-G40. 

Water depth is approximately 1,570 feet surrounding the proposed drill site. Water 

depths across the survey grid increased to the east by an approximate rate of 210

feet per mile. 

Seafloor sediments are reportedly silty clay (USDI, MMS Visual No. 3, 1983). 
TESLA OFFSHORE 

LLOG Exploration Offshore, L.L.C. 

Proposed OCS-G 25103 ‘C’ Well 

Block 707, Mississippi Canyon Area 

Archaeological Assessment 

Page 2 

Seafloor installations within 2,000 ft of the proposed surface location include Well 

No. SS1 in Block 707, located approximately 760’ to the SW, and its associated 

pipelines. The LLOG 3” pipeline (Segment 17505), LLOG 6” pipeline (Segment 

17458), and LLOG 6” pipeline (Segment 17457) are parallel to one another and 

extend from Well No. SS1 to the WNW, while the LLOG 6” pipeline (Segment 18603) 

and the LLOG 2” pipeline (Segment 18605) are parallel to one another and extend 

from Well No. SS1 to the SSE. The LLOG 2” pipeline (Segment 18605) is located 

closest to the proposed surface location, approximately 610’ to the SW. All of these 

pipelines were installed following survey data acquisition, therefore their reported 

positions should be assumed correct; care should always be exercised near the 

reported position of any pipeline. The only other infrastructure within the survey grid 

is P&A Well No. 1 in Block 751, located approximately 8,330’ to the SW.

Magnetic data is not required for survey in these water depths per NTL 2005-

G07and NTL 2008-G05 (extended by NTL 2013-G02).

Side scan sonar verified that the seafloor immediately surrounding the proposed 

well site was clear of protruding obstructions. Three sonar targets were identified 

within the survey grid, and include targets 2, 3, and 4. Sonar target 1 was identified 

in Block 705 from supplemental survey data shot as part of an associated pipeline 

route survey. None of the reported targets are located within 2,000’ of the proposed 

surface location. Target No. 2 is a semi-circular object measuring approximately 41’ 

by 11’ with 6.5’ of measured relief above the surrounding seafloor, and is located 

approximately 9,450’ WNW of the proposed well site. Target No. 3 is amorphous 

and measures approximately 70' by 40' with no measured relief above the 

surrounding seafloor, and is located approximately 5,820’ NW of the proposed well 

site. Target no. 4 consists of three parallel linear features measuring approximately 

26’ by 8’ with no measured relief above the surrounding seafloor. It is located 

approximately 6,720’ NE of the proposed well site. The targets do not appear to be 

culturally significant, and likely represent man-made debris or discrete areas of 

seafloor texture changes related to the numerous faults present in the survey area. 

Sonar data also recorded numerous fault scarps and outcrops; the nearest fault 

scarp is located approximately 1,660’ WSW of the proposed well site. The nearest 

outcrop, which was an isolated feature, is located approximately 1,680’ SE of the 

proposed surface location. Two possible expulsion features were observed on the 

sonar data, located approximately 3,720 NE and 3,430’ SW of the proposed surface 

location. 

Supplemental subbottom data showed penetration up to approximately 120 feet, 

consisting of well stratified, parallel layered, moderately reflecting sediments directly 

underneath the proposed well site. Numerous discrete faults were recorded 

throughout the survey area, most of which could not be connected across survey 

lines. Faults were recorded on the survey line closest to the proposed well site at 

depths of 15’ to 20’ BML approximately 170’ and 280’ to the SW. There is no 
TESLA OFFSHORE 

LLOG Exploration Offshore, L.L.C. 

Proposed OCS-G 25103 ‘C’ Well 

Block 707, Mississippi Canyon Area 

Archaeological Assessment 

Page 3 

potential for prehistoric sites in this portion of Mississippi Canyon Area, and no evidence 

of wrecks or other cultural debris were observed on the subbottom data. 

No evidence of potential cultural resources was observed at the proposed well location. 

The proposed well site will be marked with DGPS during rig moves and drilling to comply 

with the BOEM On-Site Requirements specified in NTL No. 2008-G05 (extended by 

NTL 2013-G02), Section VI, Item B-2(a). Pursuant to 30 CFR 550.194 (c), 30 CFR 

550.101 (c), and NTL No. 2005-G07, if any archaeological or potentially historically 

significant materials are observed during lease development, operations will immediately 

cease in that area and appropriate BOEM/BSEE personnel will be notified within 48 

hours of discovery. 

LLOG Exploration Offshore, L.L.C. and subcontractors will apply the safest and best 

available technologies during rig moves and drilling operations. 

Sincerely, 

Erin Voisin, MA Amanda Evans, PhD, RPA 

Archaeologist Marine Archaeologist
LLOG Exploration Offshore LLC Gardline Report 9946.01

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-B Well Location

Public Shallow Hazards Statement – MC707-B 

May 28, 2014

US Department of the Interior

Bureau of Ocean Energy Management

1201 Elmwood Park Blvd.

New Orleans, LA 70213-2394

Attention: 

Reference: Shallow Hazards Analysis

Mississippi Canyon Block 707

OCS-(G 25103) 

Ladies/Gentlemen:

LLOG Exploration Offshore LLG contracted Gardline Surveys, Inc. to prepare a Well Clearance Letter 

for the proposed MC707-B well in Block 707, Mississippi Canyon Area (OCS-G 25103). This letter 

addresses seafloor and shallow geologic conditions that may impact exploratory drilling operations 

within 2,000ft of the proposed well location. The depth limit of this geohazard assessment is 2.4 

seconds TWT.

This hazards summary letter is issued as a supplement to Gardline Report No. 9946 entitled: 3D 

Geohazard Assessment, Gulf of Mexico, Mississippi Canyon Block 707, dated January 2014. 

Seabed Hazards. The seabed at the proposed well is smooth. One minor small area of moderate 

reflectivity interpreted as a minor hard ground was identified approximately 1,616ft to the southeast; 

this does not present any indication underlying fluid migration to seabed. No areas with the potential 

to harbor sensitive sessile benthic communities occur within 2,000ft of the proposed well.

Several pipelines and an existing well are located within 2,000ft of the proposed well. 

Sub-Seabed Hazards. Three intervals with the possibility for a Slight Shallow Water Flow Risk are 

predicted at the proposed well in both Unit A and Unit B. 

A Slight Risk of Gas anomaly is observed within Unit A. Drilling Caution is advised. 
LLOG Exploration Offshore LLC Gardline Report 9946.01

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-B Well Location

Proposed MC707-B Location (Surface)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid NAD 27 Datum - Clarke 1866 Ellipsoid

Latitude 28° 13' 14.35” North Easting 741,861 US ft E

Longitude 89° 47’ 26.05” West Northing 10,251,385 US ft N

FEL of MC 707 2,619ft US ft Inline 3551

FSL of MC 707 2,905ft US ft Crossline 5222

Water Depth: -1,567 ft Slope: 2.7° ENE

Nearest Shoreline 51 Miles @ 24°

Port of Operation Fourchon 65 Miles @ 336°

Nearest Manned Platform Gomez MC711 11 Miles @ 091°

Conclusions and Recommendations. Appropriate drilling methodology should be utilized to deal 

with a possible, non-persistent shallow water flow event within three intervals in both Units A and B. 

A Slight Risk of Gas anomaly is observed within Unit A. Drilling Caution is advised. 

Drilling conditions appear similar to those experienced at the existing MC707-001 well location where 

no significant drilling problems were reported.

Sincerely,

LLOG Exploration Offshore LLC

Jaime Mata

Regulatory Specialist

PUBLIC INFORMATION
LLOG Exploration Offshore LLC Gardline Report TBA

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-C Well Location

Public Shallow Hazards Statement – MC707-C

June 5, 2014

US Department of the Interior

Bureau of Ocean Energy Management

1201 Elmwood Park Blvd.

New Orleans, LA 70213-2394

Attention: 

Reference: Shallow Hazards Analysis

Mississippi Canyon Block 707

OCS-(G 25103)

Ladies/Gentlemen:

LLOG Exploration Offshore LLG contracted Gardline Surveys, Inc. to prepare a Well Clearance Letter 

for the proposed MC707-C well in Block 707, Mississippi Canyon Area (OCS-G 25103). This letter 

addresses seafloor and shallow geologic conditions that may impact exploratory drilling operations 

within 2,000ft of the proposed well location. The depth limit of this geohazard assessment 2.4 

seconds TWT.

This hazards summary letter is issued as a supplement to Gardline Report No. 9946 entitled: 3D 

Geohazard Assessment, Gulf of Mexico, Mississippi Canyon Block 707, dated January 2014.

Seabed Hazards. The seabed at the proposed well is smooth. One minor small area of moderate 

reflectivity interpreted as a minor hard ground was identified approximately 1,785ft to the southeast;

this does not present any indication underlying fluid migration to seabed. No areas with the potential 

to harbor sensitive sessile benthic communities occur within 2,000ft of the proposed well.

Several pipelines and an existing well are located within 2,000ft of the proposed well. 

Sub-Seabed Hazards. Three intervals with the possibility for a Slight Shallow Water Flow Risk are 

predicted at the proposed well in both Unit A and Unit B. 

A Slight Risk of Gas anomaly is observed within Unit A. Drilling Caution is advised. 
LLOG Exploration Offshore LLC Gardline Report TBA

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-C Well Location

Proposed MC707-C Location (Surface)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid NAD 27 Datum - Clarke 1866 Ellipsoid

Latitude 28° 13' 14.70” North Easting 741,790 US ft E

Longitude 89° 47’ 27.09” West Northing 10,251,314 US ft N

FEL of MC 707 2,690ft US ft Inline 3549

FSL of MC 707 2,834ft US ft Crossline 5222

Water Depth: -1,563 ft Slope: 1.9° ENE

Nearest Shoreline 51 Miles @ 24°

Port of Operation Fourchon 65 Miles @ 336°

Nearest Manned Platform Gomez MC711 11 Miles @ 091°

Conclusions and Recommendations. Appropriate drilling methodology should be utilized to deal 

with a possible, non-persistent shallow water flow event within three intervals in both Units A and B. 

A Slight Risk of Gas anomaly is observed within Unit A. Drilling Caution is advised. 

Drilling conditions appear similar to those experienced at the existing MC-707-001 well location where 

no significant drilling problems were reported.

Sincerely,

LLOG Exploration Offshore LLC

Jaime Mata

Regulatory Specialist

PUBLIC INFORMATION
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

HIGH RESOLUTION SEISMIC LINES

Attachment J

(Proprietary)
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

STRATIGRAPHIC COLUMN

Attachment K

(Proprietary Information)
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX D

HYDROGEN SULFIDE (H2S) INFORMATION

(30 CFR Part 250.215 and 250.245) 

A. Concentration

LLOG does not anticipate encountering H2S while conducting the proposed 

exploratory operations provided for under this plan. 

B. Classification

In accordance with 30 CFR 250.490© a nd NTL No. 2009-G31 “Hydrogen 

Sulfide”, BOEM classified this area as “H2S Absent” for the Initial Exploration 

Plan (N-7922), approved November 7, 2003. 

C. H2S Contingency Plan

Not applicable for the proposed operations. 

D. Modeling Report

Not applicable to the proposed operations. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX E

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC 

INFORMATION

(30 CFR Part 250.216 and 250.247)

A. High-Density Deepwater Benthic Communities Information

The proposed seafloor disturbing activities are in a water depth of 1538 feet.

Features or areas that could support high density sensitive sessile benthic 

communities are not located within 2,000’ of the proposed well location. The 

closest occurrence of sensitive biology is located 2,159’ to the WSW. Any 

seabed anchors will be at least 250’ from any area with the potential to host 

sensitive sessile benthic communities. See following Sensitive Sessile Benthic 

Community Statements for Locations “B” and “C”.

B. Topographic Features Map

The activities proposed in this Revised Plan are not affected by topographic 

features.

C. Topographic Features Statement (Shunting)

The activities proposed in this Plan are not affected by a topographic feature; 

therefore, LLOG is not required to shunt drill cuttings and drill fluids.

D. Live Bottoms (Pinnacle Trend) Map

Mississippi Canyon Block 707 is not located within the vicinity of a proposed live 

bottom (Pinnacle trend) area.

E. Live Bottoms (Low Relief) Map

Mississippi Canyon Block 707 is not located within the vicinity of a proposed live 

bottom (Low Relief) area.

F. Potentially Sensitive Biological Features Map

Mississippi Canyon Block 707 is not located within the vicinity of a proposed 

sensitive biological feature area.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

G. Remotely Operated Vehicle (ROV) Monitoring Survey Plan

Mississippi Canyon Block 707 is not located within an area where ROV Surveys 

are required.

H. Threatened or Endangered Species, Critical Habitat, and Marine 

Mammal Information.

Proposed activities in Mississippi Canyon Block 707 is not located in the presence 

of federally listed threatened or endangered species and critical habitat designated 

under the ESA and marine mammal protected under the MMPA. 

I. Archaeological Report

Tesla Offshore, L.L.C conducted an Archaeological Deep Tow Assessment for 

MC 707 and portions of surrounding blocks in December, 2007, on behalf of

LLOG Exploration Offshore, L.L.C., submitted to BOEM on January 25, 2008. 

Tesla Offshore, LLC prepared an Archaeological Assessment for Locations B and 

C on behalf of LLOG dated January 17, 2014, which is being submitted under 

separate cover. Gardline Surveys Inc. prepared a 3D Geohazard Assessment for 

proposed locations B and C with Well Clearance Letters, on behalf of LLOG 

which is being submitted under separate cover. Gardline Surveys, Inc. prepared a

3D Geohazard Assessment for proposed revised Locations B and C for LLOG 

Exploration Offshore, Inc., dated June, 2014, submitted to BOEM on June 12, 

2014.

J. Air and Water Quality Information

Not applicable to proposed operations.

K. Socioeconomic Information

Not applicable to proposed operations.
LLOG Exploration Offshore LLC Gardline Report 9946.01

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-B Well Location

Sensitive Sessile Benthic Community Statement – MC707-B 

LLOG Exploration Offshore LLC

May 28, 2014

US Department of the Interior

Bureau of Ocean Energy Management

1201 Elmwood Park Blvd.

New Orleans, LA 70213

Reference: Sensitive Sessile Benthic Community Summary

Mississippi Canyon, Block 707

OCS-(G 25103) 

Ladies/Gentlemen:

Gardline Surveys Inc was contracted by LLOG Exploration Offshore LLC to prepare a Site Clearance 

Letter for the proposed MC707-B well surface location in Mississippi Canyon, Block 707 (OCS-G 

25103). This letter addresses location proximity to potential sensitive sessile benthic community sites. 

LLOG Exploration Offshore LLC plans to drill the proposed exploration well from an anchored drilling 

module; therefore, an anchoring assessment is included in this well clearance letter. 

This sensitive sessile benthic community summary letter is issued as a supplement to Gardline Report 

No. 9946 entitled: 3D Geohazard Assessment, Gulf of Mexico, Mississippi Canyon Block 707, dated 

January 2014. A Biological, Physical and Socioeconomic Map is included at the end of this appendix 

illustrating the areas of potential seabed impact.

Potential Sensitive Sessile Benthic Communities. 

Features or areas that could support high density sensitive sessile benthic communities are not 

located within 2,000ft of the proposed well location. The closest occurrence of sensitive biology is 

located 2,159ft to the WSW. Any seabed anchors will be at least 250ft from any area with the potential 

to host sensitive sessile benthic communities.

The sediment plume from the cuttings pile from the existing well located ~867ft to the southwest 

indicates that the bottom current carried the cuttings to the north. If similar bottom currents exist at the 

proposed location this would also carry the cuttings away from the sensitive biology.
LLOG Exploration Offshore LLC Gardline Report 9946.01

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-B Well Location

Proposed MC707- B Location (Surface)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid UTM Zone 16 - CM 90° West

Latitude 28° 13' 14.35” North Easting 741,861 US ft E

Longitude 89° 47’ 26.05” West Northing 10,251,385 US ft N

FEL of MC 707 2,619ft US ft Inline 3551

FSL of MC 707 2,905ft US ft Crossline 5222

Water Depth: -1,567 ft Slope: 2.7° ENE

Nearest Shoreline 51 Miles @ 24°

Port of Operation Fourchon 65 Miles @ 336o

Nearest Manned Platform Gomez MC711 11 Miles @ 091o

Nearest potential sensitive sessile benthic communities to the proposed location is a fluid 

expulsion site 2,159ft to the WSW of the proposed location. 

Conclusions and Recommendations: The proposed MC707-B well surface location will not impact 

any sites considered favourable for development of sensitive sessile benthic communities within a 

2,000ft radius. 

Sincerely,

LLOG Exploration Offshore LLC

Jaime Mata

Regulatory Specialist
LLOG Exploration Offshore LLC Gardline Report TBA

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-C Well Location

Sensitive Sessile Benthic Community Statement – MC707-C

LLOG Exploration Offshore LLC

June 5, 2014

US Department of the Interior

Bureau of Ocean Energy Management

1201 Elmwood Park Blvd.

New Orleans, LA 70213

Reference: Sensitive Sessile Benthic Community Summary

Mississippi Canyon, Block 707

OCS-(G 25103)

Ladies/Gentlemen:

Gardline Surveys Inc was contracted by LLOG Exploration Offshore LLC to prepare a Site Clearance 

Letter for the proposed MC707-C well surface location in Mississippi Canyon, Block 707 (OCS-G 

25103). This letter addresses location proximity to potential sensitive sessile benthic community sites. 

LLOG Exploration Offshore LLC plans to drill the proposed exploration well from an anchored drilling 

module; therefore, an anchoring assessment is included in this well clearance letter. 

This sensitive sessile benthic community summary letter is issued as a supplement to Gardline Report 

No. 9946 entitled: 3D Geohazard Assessment, Gulf of Mexico, Mississippi Canyon Block 707, dated 

January 2014. A Biological, Physical and Socioeconomic Map is included at the end of this appendix 

illustrating the areas of potential seabed impact.

Potential Sensitive Sessile Benthic Communities. 

Features or areas that could support high density sensitive sessile benthic communities are not 

located within 2,000ft of the proposed well location. The closest occurrence of sensitive biology is 

located 2,022ft to the southwest. Any seabed anchors will be at least 250ft from any area with the 

potential to host sensitive sessile benthic communities.

The cuttings pile from the existing well located ~776ft to the southwest indicates that the bottom 

current carried the cuttings to the north. If similar bottom currents exist at the proposed location this 

would also carry the cuttings away from the sensitive biology.
LLOG Exploration Offshore LLC Gardline Report TBA

Well Clearance Letter – Mississippi Canyon Offshore Gulf of Mexico– Proposed MC707-C Well Location

Proposed MC707-C Location (Surface)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid UTM Zone 16 - CM 90° West

Latitude 28° 13' 14.70” North Easting 741,790 US ft E

Longitude 89° 47’ 27.09” West Northing 10,251,314 US ft N

FEL of MC 707 2,690ft US ft Inline 3549

FSL of MC 707 2,834ft US ft Crossline 5222

Water Depth: -1,563 ft Slope: 1.9° ENE

Nearest Shoreline 51 Miles @ 24°

Port of Operation Fourchon 65 Miles @ 336o

Nearest Manned Platform Gomez MC711 11 Miles @ 091o

Nearest potential sensitive sessile benthic communities to the proposed location is a fluid 

expulsion site 2,022ft to the southwest of the proposed location. 

Conclusions and Recommendations: The proposed MC707-C well surface location will not impact 

any sites considered favourable for development of sensitive sessile benthic communities within a 

2,000ft radius. 

Sincerely,

LLOG Exploration Offshore LLC

Jaime Mata

Regulatory Specialist
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX F

WASTE AND DISCHARGE INFORMATION

(30 CFR PART 250.217 AND 250.248)

A. Projected Generated Wastes

TABLE 1. Wastes you will generate, treat and downhole dispose or 

discharge to the GOM

 

LLOG does not propose any treating, storing or downhole disposal of these 

wastes at the proposed well/MODU

B. Projected Ocean Discharges

TABLE 2. Wastes you will transport and /or dispose of onshore 

C. Modeling Report

Not applicable. Proposed activities will be covered by U.S. EPA NPDES 

General Permit.
please specify if the amount reported is a total or per well amount

MC 707

Projected generated waste Projected ocean discharges 

Type of Waste Composition Projected Amount Discharge rate Discharge Method Answer yes or no

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

EXAMPLE: Cuttings wetted with synthetic based fluid

Cuttings generated while using 

synthetic based drilling fluid. X bbl/well X bbl/day/well discharge overboard No

Water-based drilling fluid

Water based mud additives, 

barite and gel used for WBM 39,445 bbls/well 12,658 bbls/day/well Discharge overboard No

Cuttings wetted with water-based fluid

Cuttings generated while using

water based drilling fluid. 2,333 bbls/well 428 bbls/day/well Discharge overboard No

Cuttings wetted with synthetic-based fluid 

Cuttings generated while using 

synthetic based drilling fluid. 3,586 bbls/well 120 bbls/day/well Discharge overboard No

Will humans be there? If yes, expect conventional waste

EXAMPLE: Sanitary waste water

Sanitary waste from living 

quarters X bbl/well X bbl/hr/well

chlorinate and 

discharge overboard No

Domestic waste

Kitchen water, unprocessed 

water not used for sanitation 

purposes 7,457 bbls/well 2.7 bbls/hr/well

Discharge overboard 

(no free oil) No

Sanitary waste

Processed sanitary waste from 

living quarters 4,972 bbls/well 1.8 bbls/hr/well

Chlorinate and 

discharge overboard No

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

Deck Drainage

Accumulated drainage due to 

rainfall 0 to 47,261 bbls/well 0 to 167 bbls/hr/well

Test for oil and grease 

and discharge 

overboard No

Will you conduct well treatment, completion, or workover? 

Well treatment fluids

NPDES approved treatment 

fluid used for well operations 100 bbls/well 20 bbls/hr/well

Test for oil and grease 

and discharge 

overboard. No

Well completion fluids

Clear brines used for completion

operations 500 bbls/well 100 bbls/hr/well

Test for oil and grease 

and discharge 

overboard. This 

excludes clear brines 

containing Zinc No 

Workover fluids NA NA NA NA NA

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

Desalinization unit discharge NA NA NA NA NA

Blowout prevent fluid NA NA NA NA No

Ballast water

Uncontaminated seawater used 

for ballast control 0 to 100,000 bbls/well 16,350 bbls/hr/well Discharge overboard No

Bilge water NA NA NA NA NA

Excess cement at seafloor

Excess cement slurry and 

mixwater used for cementing 

operation - NPDES allowed 300 bbls/well 360 bbls/hr/well Discharge at mudline No

Fire water

Uncontaminated seawater used 

for fire control system 0 to 10,000 bbls/well 16,350 bbls/hr/well Discharge overboard No

Cooling water NA NA NA NA NA

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

Produced water NA NA NA NA NA

Will you be covered by an individual or general NPDES permit ? GMG 290000

comply with the requirements of the NPDES permit. 

NOTE: If you will not have a type of waste, enter NA in the row. 

TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR 

Projected 

Downhole 

Disposal
please specify whether the amount reported is a total or per well

MC 707

Projected generated 

waste

Solid and Liquid 

Wastes transportation 

Type of Waste Composition Transport Method Name/Location of Facility Am

Will drilling occur ? If yes, fill in the muds and cuttings.

EXAMPLE: Synthetic-based drilling fluid or mud internal olefin, ester

Below deck storage tanks on offshore support vessels

Newport Environmental Services Inc., Ingleside, TX X 

Oil-based drilling fluid or mud NA NA NA NA 

Synthetic-based drilling fluid or mud Internal olifin, ester nbased mud

Barged in 25 bbls cutting boxes and

/ or liquid mud tanks for supply vessels

Newpark Transfer Station, Fourchon, LA

67we

Cuttings wetted with Water-based fluid NA NA NA NA 

Cuttings wetted with Synthetic-based fluid NA NA NA NA Cuttings wetted with oil-based fluids NA NA NA NA 

Will you produce hydrocarbons? If yes fill in for produced sand.

Produced sand NA NA NA NA 

EXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage bin ARC, New Iberia, LA X Trash and debris Plastic, paper, aluminum Barged in a storage bin

Blanchard Landfill, GoldenMeadows, LA 40

Used oil Spent oil from machinery

Barged in USCG approved transfer

tote tanks. L&L Services, Fourchon, LA 20

Wash water

Wash water w/ SBM residue and surfactants

Barged in 25 bbls cutting boxes and / or liquid mud tanks for supply vessels

Newpark Transfer Station, Fourchon, LA

20we

Chemical product wastes

Spent treatment and / or

damaged chemicals used in operations

Barged in 25 bbls cutting boxes and / or cutting boxes L&L Services, Fourchon, LA 10 

NOTE: If you will not have a type of waste, enter NA in the row

TABLE 2. WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHORE 

Waste Dis

Will you have additional wastes that are not permitted for discharge? If 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX G

AIR EMISSIONS INFORMATION

(30 CFR PART 250.218AND 250.249)

A. Emissions Worksheets and Screening Questions

The Projected Quality Emissions Report (Form MMS-138) addresses the 

proposed drilling, completion and potential testing operations utilizing a 

typical semi-submersible, DP semi-submersible drilling unit or a drillship, and 

with related support vessels. 

\ 

Screening Questions for EP’s Yes No

Is any calculated Complete Total (CT) Emission amount (in tons associated with 

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

using the following formulas: CT = 3400D(2/3) for CO, and CT = 33.3D for the 

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

X

Does your emission calculations include any emission reduction measures or 

modified emission factors?

X

Are your proposed exploration activities located east of 87.5 degrees 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

B. Emissions Reduction Measures

The projected air emissions are within the exemption level; therefore, no 

emission reduction measures are being proposed. 

C. Verification of Nondefault Emissions Factors

LLOG has elected to use the default emission factors as provided.

D. Non-Exempt Activities 

The proposed activities are within the exemption amount as provided. 

E. Modeling Report

This section of the Plan is not applicable to the proposed operations.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

AIR QUALITY EMISSIONS REPORT

Attachment L 

(Public Information)
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 LLOG Exploration Offshore, L.L.C.

AREA Mississippi Canyon 

BLOCK 707

LEASE OCS-G-25103

PLATFORM N/A

WELL B & C

COMPANY CONTACT Kathy Gowland/Nelda Runyon

TELEPHONE NO. 985-801-4300

REMARKS Semisubmersible Rig
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

LLOG Exploration Offshore Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300

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 26400 1275.12 30602.88 24 77 18.61 85.36 639.65 19.19 139.56 17.19 78.88 591.03 17.73 128.95

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

3 x per week VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 33 1.46 6.68 50.03 1.50 10.92 0.14 0.66 4.95 0.15 1.08

6 x per week VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 65 1.46 6.68 50.03 1.50 10.92 0.47 2.17 16.26 0.49 3.55

VESSELS>600hp diesel(tugs) 4200 202.86 4868.64 12 2 2.96 13.58 101.76 3.05 22.20 0.04 0.16 1.22 0.04 0.27

3-4 days VESSELS>600hp diesel(work) 3000 144.9 3477.60 12 4 2.11 9.70 72.69 2.18 15.86 0.05 0.23 1.74 0.05 0.38

3-4 days VESSELS>600hp diesel(anchor 16000 772.8 18547.20 12 4 11.28 51.74 387.67 11.63 84.58 0.27 1.24 9.30 0.28 2.03

handler) 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 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2014 YEAR TOTAL 37.87 173.73 1301.83 39.05 284.04 18.17 83.34 624.52 18.74 136.26

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
EMISSIONS CALCULATIONS 2ND YEAR

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 4 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshore, Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300

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 26400 1275.12 30602.88 24 52 18.61 85.36 639.65 19.19 139.56 11.61 53.27 399.14 11.97 87.09

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

3 x per week VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 22 1.46 6.68 50.03 1.50 10.92 0.10 0.44 3.30 0.10 0.72

6 x per week VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 45 1.46 6.68 50.03 1.50 10.92 0.33 1.50 11.26 0.34 2.46

VESSELS>600hp diesel(tugs) 4200 202.86 4868.64 12 2 2.96 13.58 101.76 3.05 22.20 0.04 0.16 1.22 0.04 0.27

3-4 days VESSELS>600hp diesel(work) 3000 144.9 3477.60 12 4 2.11 9.70 72.69 2.18 15.86 0.05 0.23 1.74 0.05 0.38

3-4 days VESSELS>600hp diesel(anchor 16000 772.8 18547.20 12 4 11.28 51.74 387.67 11.63 84.58 0.27 1.24 9.30 0.28 2.03

handler) 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 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2015 YEAR TOTAL 37.87 173.73 1301.83 39.05 284.04 12.39 56.85 425.97 12.78 92.94

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
EMISSIONS CALCULATIONS 3RD YEAR

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 5 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshore, L Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300

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 26400 1275.12 30602.88 24 62 18.61 85.36 639.65 19.19 139.56 13.84 63.51 475.90 14.28 103.83

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

3 x per week VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 27 1.46 6.68 50.03 1.50 10.92 0.12 0.54 4.05 0.12 0.88

6 x per week VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 53 1.46 6.68 50.03 1.50 10.92 0.39 1.77 13.26 0.40 2.89

VESSELS>600hp diesel(tugs) 4200 202.86 4868.64 12 2 2.96 13.58 101.76 3.05 22.20 0.04 0.16 1.22 0.04 0.27

3-4 days VESSELS>600hp diesel(work) 3000 144.9 3477.60 12 4 2.11 9.70 72.69 2.18 15.86 0.05 0.23 1.74 0.05 0.38

3-4 days VESSELS>600hp diesel(anchor 16000 772.8 18547.20 12 4 11.28 51.74 387.67 11.63 84.58 0.27 1.24 9.30 0.28 2.03

handler) 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 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2016 YEAR TOTAL 37.87 173.73 1301.83 39.05 284.04 14.70 67.46 505.48 15.16 110.29

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
SUMMARY

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

COMPANY AREA BLOCK LEASE PLATFORM WELL

LLOG Exploratio Mississippi Canyon 707 OCS-G-25103 N/A B & C

Emitted Substance

Year

PM SOx NOx VOC CO

2014 42.23 193.74 1451.77 43.55 316.75

2015 28.57 131.05 981.98 29.46 214.25

2016 33.49 153.63 1151.19 34.54 251.17

Allowable 1698.30 1698.30 1698.30 1698.30 46758.33
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 LLOG Exploration Offshore, L.L.C.

AREA Mississippi Canyon 

BLOCK 707

LEASE OCS-G-25103

PLATFORM N/A

WELL B & C

COMPANY CONTACT Kathy Gowland/Nelda Runyon

TELEPHONE NO. 985-801-4300

REMARKS Drillship
EMISSIONS FACTORS

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991

Gas Venting lbs/scf 0.0034

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight
EMISSIONS CALCULATIONS 1ST YEAR

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

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshore Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300 Drillship

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61800 2984.94 71638.56 24 77 43.56 199.83 1497.36 44.92 326.70 40.25 184.64 1383.56 41.51 301.87

Drillship 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

3 x weeks VESSELS>600hp diesel(crew) 7200 347.76 8346.24 4 33 5.07 23.28 174.45 5.23 38.06 0.33 1.54 11.51 0.35 2.51

6 x weeks VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 65 5.07 23.28 174.45 5.23 38.06 1.65 7.57 56.70 1.70 12.37

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 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2014 YEAR TOTAL 53.71 246.39 1846.26 55.39 402.82 42.23 193.74 1451.77 43.55 316.75

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
EMISSIONS CALCULATIONS 2ND YEAR

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 4 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshore, Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300 Drillship

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61800 2984.94 71638.56 24.00 52.00 43.56 199.83 1497.36 44.92 326.70 27.18 124.69 934.35 28.03 203.86

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

3 x week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 4.00 24.00 5.07 23.28 174.45 5.23 38.06 0.24 1.12 8.37 0.25 1.83

6 x week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10.00 45.00 5.07 23.28 174.45 5.23 38.06 1.14 5.24 39.25 1.18 8.56

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

2015 YEAR TOTAL 53.71 246.39 1846.26 55.39 402.82 28.57 131.05 981.98 29.46 214.25

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
EMISSIONS CALCULATIONS 3RD YEAR

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 5 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshore, L Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300 Drillship

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61800 2984.94 71638.56 24 62 43.56 199.83 1497.36 44.92 326.70 32.41 148.67 1114.03 33.42 243.06

Drillship 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

3 x week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 4 27 5.07 23.28 174.45 5.23 38.06 0.27 1.26 9.42 0.28 2.06

6 x week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 6 53 5.07 23.28 174.45 5.23 38.06 0.81 3.70 27.74 0.83 6.05

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 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2016 YEAR TOTAL 53.71 246.39 1846.26 55.39 402.82 33.49 153.63 1151.19 34.54 251.17

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
SUMMARY

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

COMPANY AREA BLOCK LEASE PLATFORM WELL

LLOG Exploratio Mississippi Canyon 707 OCS-G-25103 N/A B & C

Emitted Substance

Year

PM SOx NOx VOC CO

2014 42.23 193.74 1451.77 43.55 316.75

2015 28.57 131.05 981.98 29.46 214.25

2016 33.49 153.63 1151.19 34.54 251.17

Allowable 1698.30 1698.30 1698.30 1698.30 46758.33
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 LLOG Exploration Offshore, L.L.C.

AREA Mississippi Canyon 

BLOCK 707

LEASE OCS-G-25103

PLATFORM N/A

WELL B & C

COMPANY CONTACT Kathy Gowland/Nelda Runyon

TELEPHONE NO. 985-801-4300

REMARKS DP Semisubmersible
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

LLOG Exploration Offshore Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300 DP Semisubmersible

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 61200 2955.96 70943.04 24 77 43.14 197.89 1482.82 44.48 323.52 39.86 182.85 1370.13 41.10 298.94

Drillship 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

3 x weeks VESSELS>600hp diesel(crew) 7200 347.76 8346.24 4 33 5.07 23.28 174.45 5.23 38.06 0.33 1.54 11.51 0.35 2.51

6 x weeks VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 65 5.07 23.28 174.45 5.23 38.06 1.65 7.57 56.70 1.70 12.37

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 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2014 YEAR TOTAL 53.29 244.45 1831.72 54.95 399.65 41.84 191.95 1438.33 43.15 313.82

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
EMISSIONS CALCULATIONS 2ND YEAR

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 4 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshore, Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300 DP Semisubmersible

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 61200 2955.96 70943.04 24.00 52.00 43.14 197.89 1482.82 44.48 323.52 26.92 123.48 925.28 27.76 201.88

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

3 x week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 4.00 24.00 5.07 23.28 174.45 5.23 38.06 0.24 1.12 8.37 0.25 1.83

6 x week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10.00 45.00 5.07 23.28 174.45 5.23 38.06 1.14 5.24 39.25 1.18 8.56

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

2015 YEAR TOTAL 53.29 244.45 1831.72 54.95 399.65 28.30 129.84 972.90 29.19 212.27

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
EMISSIONS CALCULATIONS 3RD YEAR

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 5 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshore, L Mississippi Canyon 707 OCS-G-25103 N/A B & C Kathy Gowland/Nelda Runyon 985-801-4300 DP Semisubmersible

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 61200 2955.96 70943.04 24 62 43.14 197.89 1482.82 44.48 323.52 32.09 147.23 1103.22 33.10 240.70

Drillship 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

3 x week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 4 27 5.07 23.28 174.45 5.23 38.06 0.27 1.26 9.42 0.28 2.06

6 x week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 6 53 5.07 23.28 174.45 5.23 38.06 0.81 3.70 27.74 0.83 6.05

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 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2016 YEAR TOTAL 53.29 244.45 1831.72 54.95 399.65 33.17 152.19 1140.38 34.21 248.81

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1698.30 1698.30 1698.30 1698.30 46758.33

51.0
SUMMARY

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

COMPANY AREA BLOCK LEASE PLATFORM WELL

LLOG Exploratio Mississippi Canyon 707 OCS-G-25103 N/A B & C

Emitted Substance

Year

PM SOx NOx VOC CO

2014 41.84 191.95 1438.33 43.15 313.82

2015 28.30 129.84 972.90 29.19 212.27

2016 33.17 152.19 1140.38 34.21 248.81

Allowable 1698.30 1698.30 1698.30 1698.30 46758.33
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX H

OIL SPILL INFORMATION

(30 CFR PART 250.219 AND 250.250)

A. Oil Spill Response Planning

The proposed activities in this Revised Exploration Plan will be covered by the 

Oil Spill Response Plan filed by LLOG (MMS Operator No. 02058) in 

accordance with 30 C FR 254 Biennial update approved on August 8, 2 012 and 

modifications submitted on January 29, 2013, a pproved February 25, 20 13, and 

April 11, 2013, approved on April 19, 2013. 

The WCD proposed in this Plan does not exceed the WCD outlined in our OSRP. 

B. Spill Response Sites

The following locations will be used in the event an oil spill occurs as a result of 

the proposed activities. 

Primary Response Equipment 

Location

Pre-Planned Staging Location(s)

Houma, LA Fort Jackson, LA

C. OSRO Information

The O’Brien Group (TOG) will provide trained personnel capable of providing 

supervisory management of the oil spill response in addition to contacting and 

deploying cleanup personnel and equipment 

LLOG utilizes Clean Gulf Associates (CGA) as it’s primary provider for 

equipment, which is an industry cooperative owning an inventory of oil spill 

clean-up equipment. CGA is supported by the Marine Spill Response 

Corporation’s (MSRC), which is responsible for storing, inspecting, maintaining 

and dispatching CGA’s equipment. The MSRC STARS network provides for the 

closest available personnel, as well as an MSRC supervisor to operate the 

equipment. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

D. Worst-Case Scenario Information

Category Regional OSRP Modified EP

Type of Activity Exploratory MODU Exploratory MODU

Facility Surface Location Mississippi Canyon 

Block 547

Mississippi Canyon Block 707

Facility Description Well Location 2 Well Location C (#2 Well)

Distance to Nearest Shoreline

(Miles) 38.4 51 

Volume:

 Storage Tanks (total)

 Facility Piping (total)

 Lease Term Pipeline

 Uncontrolled Blowout (day)

 Barging

Potential 24 Hour Volume 

(bbls) 

225,144 bbls

 

 

140,953 bbls

 

Type of Liquid Hydrocarbon Condensate Crude Oil

API Gravity 28o 29.6o

Since LLOG Exploration Offshore, L.L.C. (LLOG) has the capability to respond 

to the appropriate worst-case spill scenario included in its regional OSRP Biennial 

update approved on August 8, 2012, a nd modifications submitted on January 29, 

2013, approved February 25, 2013, and April 11, 2013, approved on A pril 19, 

2013 and since the worst case discharge determined in our Revised Exploration 

Plan for MC 707 does not exceed our worst case discharge outlined in our 

Regional OSRP, I hereby certify that LLOG Exploration Offshore, L.L.C. 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 Revised Exploration Plan. The WCD for the subject plan does 

not exceed the worst case discharge previously submitted for MC 547. 

LLOG Exploration Offshore, L.L.C., Company No. 02058, previously submitted 

the Regional OSRP Exploration WCD volume to be reviewed in Plan R-5139, 

Revised Exploration Plan submitted on March 2, 2011 a nd approved October 6, 

2011. 

 

The required proprietary data outlined in NTL 2010-N06 is included in this plan 

as Attachment D.

E. Oil Spill Response Discussion

See the following Oil Spill Response Discussion. 
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 140,953 barrels of crude oil with an API gravity of 26.9°. 

Land Segment and Resource Identification

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

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

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

The BOEM OSRAM identifies a 4% probability of impact to the shorelines of Plaquemines 

Parish, Louisiana within 10 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

LLOG Exploration Offshore, L.L.C. 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 13% or 

approximately 18,324 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 122,629 barrels remaining. 

Spill Response MC 707, Well No. 2 Barrels of Oil 

WCD Volume 140,953 

Less 13% natural evaporation/dispersion 18,324 

Remaining volume 122,629 

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. 

LLOG Exploration Offshore, L.L.C.’s Oil Spill Response Plan includes alternative response 

technologies such as dispersants and in-situ burn. Strategies will be decided by Unified 

Command based on the size of the spill, weather and potential impacts. If aerial dispersants are 

utilized, 8 sorties (9,600 gallons) from two of the DC-3 aircrafts and 4 sorties (8,000 gallons) 
from the Basler aircraft would provide a daily dispersant capability of 7,540 barrels. If the 

conditions are favorable for in-situ burning, the proper approvals have been obtained and the 

proper planning is in place, in-situ burning of oil may be attempted. Slick containment boom 

would be immediately called out and on-scene as soon as possible. Offshore response strategies 

may include attempting to skim utilizing CGA’s spill response equipment, with a total derated 

skimming capacity of 141,601 barrels. Temporary storage associated with skimming equipment 

equals 10,198 barrels. If additional storage is needed, a 25,000 barrel storage barge, three 20,000 

barrel storage barges, and a 47,000 barrel storage barge may be mobilized and centrally located 

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

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

deemed safe prior to any containment/skimming attempts. 

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

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

near shore and shallow water skimmers with a totaled derated skimming capacity of 22,086 

barrels. Temporary storage associated with skimming equipment equals 825 barrels. If additional 

storage is needed, a 23,000 barrel storage barge may be mobilized and centrally located to 

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

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

protection and sorbent boom on vegetated areas. Master Service Agreements with AMPOL 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. LLOG Exploration Offshore, L.L.C.’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, LLOG Exploration Offshore, L.L.C. 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 57 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 

LLOG Exploration Offshore, L.L.C. 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 

Oceangoing Boom Barge 

• Containment at the source 

• Increased/enhanced skimmer encounter rate 

• Protection booming 
In-situ Burn assets 

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

affected SOSC 

• Determine availability of fire boom and selected ignition systems 

• Start ordering fire boom stocks required for expected operations 

• Contact boom manufacturer to provide training if required 

• Determine assets to perform on water operation 

• Build operations into safety plan 

• Conduct operations in accordance with an approved plan 

Dedicated off-shore skimming systems 

General 

• Deployed to the highest concentration of oil 

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

CGA HOSS Barge 

• Use in areas with heaviest oil concentrations 

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

CGA 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 

Storage Vessels 

• Establish availability of CGA contracted assets (See Appendix E) 

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

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

systems 

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

Vessels of Opportunity (VOO) 

• Use {Company Name}’s contracted resources as applicable 

• Industry vessels are ideal for deployment of Vessel of Opportunity Skimming Systems 

(VOSS) 

• Acquire additional resources as needed 

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

• Expect mission specific and safety training to be required 

• Plan with the US Coast Guard for vessel inspections 

• Place VOOs in Division or Groups as needed 
• Use organic on-board storage if appropriate 

• Maximize non-organic storage appropriate to vessel limitations 

• Decant as appropriate after approval to do so has been granted 

• Assign bulk storage barges to each Division/Group 

• Position bulk storage barges as close to skimming units as possible 

• Utilize large skimming vessel (e.g. barges) storage for smaller vessel offloading 

• Maximize skimming area (swath) to the optimum width given sea conditions and 

available equipment 

• Maximize use of oleophilic skimmers in all operations, but especially offshore 

• Nearshore, use shallow water barges and shuttle to skimming units to minimize 

offloading time 

• Plan and equip to use all offloading capabilities of the storage vessel to minimize 

offloading time 

Adverse Weather Operations: 

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

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

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

an emergency, ”stop work” may be directed by any crew member. 
Surface Oil Recovery Considerations and Tactics 

(Offshore and Near-shore Operations) 

Maximization of skimmer-oil encounter rate

• Place barges in skimming task forces, groups, etc., to reduce recovered oil offloading 

time 

• Place barges alongside skimming systems for immediate offloading of recovered oil 

when practicable 

• Use two vessels, each with heavy sea boom, in an open-ended “V” configuration to 

funnel surface oil into a trailing skimming unit’s organic, V-shaped boom and skimmer 

(see page 7, CGA Equipment Guide Book and Tactic Manual (CGATM) 

• Use secondary vessels and heavy sea boom to widen boom swath beyond normal 

skimming system limits (see page 15, CGATM) 

• Consider night-time operations, first considering safety issues 

• Utilize all available advanced technology systems ( IR, X-Band Radar, etc.) to determine 

the location of, and move to, recoverable oil 

• Confirm the presence of recoverable oil prior to moving to a new location 

Maximize skimmer system efficiency 

• Place weir skimming systems in areas of calm seas and thick oil 

• Maximize the use of oleophilic skimming systems in heavier seas 

• Place less mobile, high EDRC skimming systems (e.g. HOSS Barge) in the largest 

pockets of the heaviest oil 

• Maximize onboard recovered oil storage for vessels. 

• Obtain authorization for decanting of recovered water as soon as possible 

• Use smaller, more agile skimming systems to recover streamers of oil normally found 

farther from the source. Place recovered oil barges nearby 

Recovered Oil Storage 

• Smaller barges in larger quantities will increase flexibility for multi-location skimming 

operations 

• Place barges in skimming task forces, groups, etc., to reduce recovered oil offloading 

time 

• Procure and deploy the maximum number of portable tanks to support Vessel of 

Opportunity Skimming Systems if onboard storage is not available 

• Maximize use of the organic recovered oil storage capacity of the skimming vessel 

Command, Control, and Communications (C3

) 

• Publish, implement, and fully test an appropriate communications plan 

• Design an operational scheme, maintaining a manageable span of control 

• Designate and mark C3

 vessels for easy aerial identification 

• Designate and employ C3

 aircraft for task forces, groups, etc. 

• Use reconnaissance air craft and Rapid Response Teams (RAT) to confirm the presence 

of recoverable oil 
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 LLOG Exploration Offshore, L.L.C.’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 LLOG Exploration Offshore, L.L.C.’s WCD and information in the BOEM Oil 

Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico 

available on the BOEM website using 30 day impact. The results are tabulated below. 

Area/Block OCS-G Launch 

Area 

Land Segment and/or 

Resource 

Conditional 

Probability (%) 

within 30 days 

Exploratory Drilling 

MC 707, Well No. 2 

51 miles from shore 

G25103 C58 Terrebonne, LA 

Lafourche, LA 

Plaquemines, LA 

1 

2

4 
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (51 miles from sh

122,629 bbls of crude oil (Volume considering natural weathering) API Gravity 26.9° 

FIGURE 2 – Equipment Response Time to MC 707, Well No. 2 

Dispersants/Surveillance

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

sit

ASI 

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

Offshore Response

Offshore Equipment No 

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

CGA 

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 46’ FRV 12342 249 NA 4 Leeville 1 0 2 46’ FRV 12342 249 NA 4 Venice 1 0 1 Boom Barge (CGA-300) 42” Auto Boom (25000’) NA NA 1 Tug 50 Crew 4 (Barge) 2 (Per Crew) Leeville 4 0 6 

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 24 24 2 

Recovered Oil Storage No 

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

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 
Staging Area: Venice

Offshore Equipment With 

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

CGA 

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

Nearshore Equipment No 

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

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 

Staging Area: Venice

Nearshore and Inland Skimmers 

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

Deploy

CGA 

SWS Egmopol 3000 100 NA 3 Galveston 1 2 12.7 2 SWS Egmopol 3000 100 NA 3 Morgan City 1 2 4.9 2 SWS Marco 3588 20 NA 3 Lake Charles 1 2 8 2 SWS Marco 3588 34 NA 3 Leeville 1 2 4.4 2 SWS Marco 3588 34 NA 3 Venice 1 2 0 2 Rope Mop 77 2 0 3 Harvey 1 2 2.1 2 Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 1 2 8 2 Foilex Skim Package (TDS 150) 891 45 NA 3 Galveston 1 2 12.7 2 Foilex Skim Package (TDS 150) 891 45 NA 3 Harvey 1 2 2.1 2 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 1 2 8 2 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 1 2 2.1 2 2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Lake Charles 1 2 8 2 2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Harvey 1 2 2.1 2 
Shoreline Protection 

Staging Area: Venice 

Shoreline Protection 

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

AMPOL (available through MSA) 

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 6 2 20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2.2 2 

OMI Environmental (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 6 2 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 12.1 2 10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 9.7 2 20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.9 2 10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 4.5 2 10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.8 2 15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.1 2 

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

Deplo

CGA 

Wildlife Support Trailer NA NA NA 2 Harvey 1 2 2.1 Bird Scare Guns (48) NA NA NA 2 Harvey 1 2 2.1 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 12.7 Bird Scare Guns (12) NA NA NA 2 Aransas Pass 1 2 17.7 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 8 Bird Scare Guns (24) NA NA NA 2 Leeville 1 2 4.4 

Response Asset Total 

Offshore EDRC 141,601 

Offshore Recovered Oil Storage 142,198 

Nearshore / Shallow Water EDRC 22,086 

Nearshore / Shallow Water Recovered Oil Storage 23,840 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX I

ENVIRONMENTAL MONITORING INFORMATION

(30 CFR PART 250.221 AND 250.252) 

A. Monitoring Systems

LLOG subscribes to Impact Weather Service which provides access to real-time 

weather conditions, and provides periodic updates on i mpending inclement 

weather conditions such as tropical depressions, storms and/or hurricanes entering 

the Gulf of Mexico. 

LLOG also relies on the National Weather Service to support the aforementioned 

subscribed service. During impending inclement weather conditions, LLOG 

closely coordinates the activity with our contractors and field personnel to ensure 

the safety of people for evacuation; measures to prepare the facility for evacuation 

to ensure protection of the environment and the facility/equipment. 

Mississippi Canyon Block 707 is in water depths greater than 400 meters (1312 

feet); therefore, LLOG will follow the guidelines of the applicable NTL 2009-

G02 “Ocean Current Monitoring”, by monitoring and gathering ocean current 

data using Acoustic Doppler Current Profile (ADCP) while the MODU is on 

location. 

B. Incidental Takes

LLOG does not anticipate the incidental taking of any species as a result of the 

proposed activities based on the implementation of, and adherence to, the BSEE 

NTL No. 2012-G01 “Marine Trash and Debris Awareness Training and 

Elimination” and Joint NTL No. 2012-G01 “Vessel Strike Avoidance and 

Injured/Dead Protected Species Reporting”.

C. Flower Garden Banks National Marine Sanctuary

This section of the plan is not applicable to the proposed operations. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX J

LEASE STIPULATIONS/SPECIAL CONDITIONS INFORMATION

(30 CFR PART 250.222 AND 250.253)

A. Lease Stipulations

Minerals Management Service (BOEM) invoked Stipulation No. 6 – Marine 

Protected Species, Lease OCS-G-25103, Mississippi Canyon Block 707. 

Lease Stipulation No. 6 is to reference measures to minimize or avoid potential 

adverse impacts to protected species (sea turtles, marine mammals, gulf sturgeon, 

and other federally protected species). BOEM has issued Notice to Lessees Joint 

NTL No. 2012-G02 “Implementation of Seismic Survey Mitigation Measures and 

Protected Species Observer Program”, Joint NTL No. 2012-G01 “Vessel Strike 

Avoidance and Injured/Dead Protected Species Reporting” and BSEE NTL No. 

2012-G01 “Marine Trash and Debris Awareness and Elimination”.

B. Special Conditions

• Subsea Completions

LLOG may potentially complete the proposed well as a subsea 

completion. Therefore, LLOG will follow the regulations in Title 30 CFR 

Parts 550.296 t hrough 550.299, w hich mandates the submittal and 

approval of separate regulatory filings entitled a “Conservation 

Information Document” and Title 30 CFR Parts 250.286 to Title 30 CFR 

Parts 250.295 entitled “Deepwater Operations Plan”. 

 

• Ocean Current Monitoring

The proposed operations under this Plan are in water depths greater than 

300 meters (984’); therefore, LLOG will follow the guidelines of the 

applicable NTL 2009-G02 “Ocean Current Monitoring”, by continuously 

monitoring and gathering ocean current data using Acoustic Doppler 

Current Profile (ADCP) while the MODU is on location. 

• Breton Sound Area

Mississippi Canyon Block 707 is located within the 200 km zone of the 

Breton National Wildlife Refuge, and LLOG will consider the use of best 

available control technology as required if the projected air emissions are 

determined to significantly affect the air quality of an onshore area. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX K

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(30 CFR Part 250.23 and 250.54)

A. Measures Taken to Avoid, Minimize, and Mitigate Impacts

This section does not apply to the operations as proposed herein. 

D. Incidental Takes

LLOG does not anticipate the incidental taking of any species as a result of the 

proposed activities based on the implementation of, and adherence to, the BSEE 

NTL No. 2012-G01 “Marine Trash and Debris Awareness Training and 

Elimination” and Joint NTL No. 2012-G01 “Vessel Strike Avoidance and 

Injured/Dead Protected Species Reporting”.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX L

RELATED FACILITIES AND OPERATIONS INFORMATION

(30 CFR PART 250.256)

A. Produced Liquid Hydrocarbon Transportation Vessels

Not applicable to proposed operations. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX M

SUPPORT VESSELS AND AIRCRAFT INFORMATION

(30 CFR PART 250.224 AND 250.257)

A. General

Personnel involved in the proposed operations will typically use their own 

vehicles as transportation to and from the selected onshore base; whereas the 

selected vendors will transport the equipment by a combination of trucks, boats 

and/or helicopters to the onshore base. The personnel and equipment will then be 

transported to the drilling rig via the transportation methods and frequencies 

shown, taking the most direct route feasible as mandated by weather and traffic 

conditions: 

Drillship or DP Semisubmersible Rig:

Type Maximum Fuel Tank 

Storage Capacity

Maximum No. in Area 

at Any Time

Trip Frequency or 

Duration

Supply Boats 500 bbls 1 Six times weekly

Crew Boats 500 bbls 1 Three times weekly

Aircraft 1900 lbs 1 As Needed

Semisubmersible Rig:

Type Maximum Fuel Tank 

Storage Capacity

Maximum No. in Area 

at Any Time

Trip Frequency or 

Duration

Tug Boats 3000 bbls 1 During rig moves on/off

Supply Boats 500 bbls 1 Six times weekly

Crew Boats 500 bbls 1 Three times weekly

Aircraft 1900 lbs 1 As Needed

Anchor Handler 15,100 bbls 1 3-4 days

Work Boat 6,450 bbls 1 3-4 days

B. Diesel Oil Supply Vessels

Size of Fuel Supply 

Vessel

Capacity of fuel 

Supply Vessel

Frequency of Fuel 

Transfers

Route Fuel Supply 

Vessel Will Take

180’ OSV 1900 bbls 1/weekly Fourchon, LA to 

Mississippi Canyon 

Block 707

C. Drilling Fluids Transportation

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in 

Appendix F of this Plan. 

D. Solid and Liquid Wastes Transportation

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in 

Appendix F of this Plan. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

E. Vicinity Map

Vicinity Plats showing the location of Mississippi Canyon Block 707 relative to 

the nearest shoreline and onshore base are included as Attachment M. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

Vicinity Map

Attachment M

(Public Information)

Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX N

ONSHORE SUPPORT FACILITIES INFORMATION

(30 CFR PART 250.225 AND 250.258) 

 A. General

The proposed surface disturbances in Mississippi Canyon Block 707 will be 

located approximately 51 miles from the nearest Louisiana shoreline, and 

approximately 62 miles from the following onshore support base: 

Name Location Existing/New/Modified

Turn Key Cleaning Fourchon, LA Existing

LLOG will use an existing onshore base to accomplish the following routine 

operations: 

● Loading/Offloading point for equipment supporting the offshore 

operations. 

● Dispatching personnel and equipment, and does not anticipate the need for 

any expansion of the selected facilities as a result of the activities 

proposed in this Initial Plan. 

● Temporary storage for materials and equipment.

● 24 Hour Dispatcher 

B. Support Base Construction or Expansion

The proposed operations are temporary in nature and do not require any 

immediate action to acquire additional land or expand existing base facilities. 

C. Support Base Construction or Expansion Timetable

This section of the plan is not applicable to the proposed operations. 

 

D. Waste Disposal

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in 

Appendix F of this Plan. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX O

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION

(30 CFR PART 250.226 AND 250.260)

A. Consistency Certification

. 

A certificate of Coastal Zone Management Consistency for the State of Louisiana 

is enclosed as Attachment N

B. Other Information

LLOG has considered all of Louisiana’s enforceable policies and certifies the 

consistency for the proposed operations. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

Coastal Zone Management Consistency for the 

State of Louisiana

Attachment N 

(Public Information)

Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

 

APPENDIX P 

ENVIRONMENTAL IMPACT ANALYSIS

(30 CFR PART 250.227 AND 250.261) 

A. Impact Producing Factors (IPF’s) From Proposed Activities

The following matrix is utilized to identify the affected environments that 

could be impacted by these IPF’s. An “x” has been marked for each IPF 

category that LLOG has determined may impact a particular environment as a 

result of the proposed activities. For those cells which are footnoted, a 

statement is provided as to the applicability of the proposed activities, and 

where there may be an effect, an analysis of the effect is provided.

Environmental Resources Impact Producing Factors (IPF’s)

Emissions 

(air, noise, 

light, etc)

Effluents

(muds, cuttings, 

other discharges 

to the water 

column or 

seafloor)

Physical 

disturbances 

to the seafloor 

(rig, anchor, 

structure 

emplacement, 

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)

Chemosynthetic communities

Water quality X X

Fisheries X X

Marine mammals X (8) X (8) X

Sea turtles X (8) X (8) X

Air quality X (9)

Shipwreck sites (known or 

potential)

(7)

Prehistoric archaeological sites (7)

Vicinity of Offshore Location

Essential fish habitat X X (6)

Marine and pelagic birds X (6) X

Public health and safety

Coastal and Onshore

Beaches X (6) X

Wetlands X (6)

Shorebirds and coastal nesting 

birds

X (6)

Coastal wildlife refuge X

Wilderness areas X
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

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:

(a) 4-mile zone of the Flower Gardens Banks, or the 3-mile zone of Stetson Bank;

(b) 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;

(c) Essential Fish Habitat (EFH) criteria of 500 feet from any no-activity zone; or

(d) Proximity of any submarine bank (500 ft buffer zone) with relief greater than 2 meters that 

is not protected by the Topographic 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 (Low-Relief) Stipulation attached to an OCS lease.

4. Activities on blocks designated by the BOEMRE 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. I f 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 BOEMRE as having high-probability for the occurrence of shipwrecks or prehistoric 

sites, including such blocks that will be affected that are adjacent to the lease block in which your 

planned activity will occur. I f the proposed activities are located a sufficient distance from a 

shipwreck or 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.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

B. Impact Analysis

LLOG does not anticipate any unforeseen incidents from the proposed activities 

which could significantly impact the associated environment. LLOG activities 

associated with this Revised Exploration Plan (Plan) will be performed with 

prudent and industry accepted standards, and in compliance with the federal 

agency regulations and oversight. 

The “Oil Spills Information” Section of this Plan details the potential worse case 

discharge volume which has been calculated based on the new Bureau of Ocean 

Energy Management (BOEM) Notice to Lessees (NTL 2010-N06). R esponse 

details associated with an unanticipated spill from this site are detailed in our 

Regional Oil Spill Response Plan (OSRP) which outlines the potential spill 

scenario, spill volumes, anticipated trajectory of the spill, response equipment 

available, and actions to be taken to respond to the potential spill incident. 

Additional measures implemented by LLOG is trajectory analyses to be obtained 

prior to and during the proposed activities, contractual arrangements with well 

control specialists and preliminary reviews of potential well intervention 

scenarios, and to supplement existing contracted response/clean-up equipment 

with equipment offered by Helix which specializes in subsea deepwater well 

intervention, containment and processing. 

 Site Specific at Offshore Location

• Designated Topographic Features 

There are no anticipated emissions, effluents, physical disturbances to the 

seafloor, wastes transported to shore, and/or accidents from the proposed 

activities that could cause impacts to topographic features.

The proposed surface disturbances within Mississippi Canyon Block 707 

is located approximately 58 miles away from the from the closest 

designated topographic feature (Diaphus Bank). 

The crests of these designated topographic features in the northern Gulf 

are typically found below 10 m; therefore, concentrated oil from a surface 

spill is not likely to reach sessile biota. S ubsurface spills could cause 

adverse impacts to a designated topographic feature; however, due to the 

offset distance this should not have an impact. 

In the event of an unanticipated spill, LLOG would immediately 

implement its Regional Oil Spill Response Plan and active source control 

and countermeasures to minimize these potential impacts.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

• Pinnacle Trend Area Live Bottoms

There are no anticipated emissions, effluents, physical disturbances to the 

seafloor, wastes sent to shore and/or accidents from the proposed activities 

that could cause impacts to a pinnacle trend area.

The proposed surface disturbance within Mississippi Canyon Block 707 is

located a significant distance (> 100 miles) from the closest pinnacle trend 

live bottom stipulated block. The crests of these pinnacle trend areas are 

much deeper than 20 m . In the event of an accidental oil spill from the 

proposed activities, the gravity of such oil (high gravity condensate and/or 

diesel fuel) would rise to the surface, quickly dissipate, and/or be swept 

clear by currents moving around the bank; and thus not impacting the 

pinnacles.

During the surface location disturbance review, LLOG reviews potential 

surface impacts, and would be able to identify any pinnacles within the 

vicinity and would avoid placement of any surface disturbances such as a 

drilling rig and associated anchors. T hese surface location disturbance 

areas would be avoided and/or mitigated during the review and approval 

process by the BOEM.

In the event of an unanticipated spill, LLOG would immediately 

implement its Regional Oil Spill Response Plan and activate source 

control and countermeasures to minimize these potential impacts.

• Eastern Gulf Live Bottoms

There are no anticipated emissions, effluents, emissions physical 

disturbances to the seafloor, wastes sent to shore, and/or accidents from 

the proposed activities that could cause impacts to Eastern Gulf live 

bottoms. 

The proposed surface disturbance within Mississippi Canyon Block 707 is 

located a significant distance (> 100 miles) from the closest Eastern Gulf 

live bottoms stipulated block. D uring the surface location disturbance 

review, LLOG previews potential surface impacts, and would be able to 

identify any live bottom areas within the vicinity and would avoid 

placement of any surface disturbances such as a drilling rig and associated 

anchors. In the event of an accidental oil spill from the proposed 

activities, the gravity of such oil (high gravity condensate and/or diesel 

fuel) would rise to the surface, quickly dissipate, and/or be swept clear by 

currents moving around the bank; and thus not impacting the Eastern Gulf 

live bottoms because of the depth of the features and dilutions of spills. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

In the event of an unanticipated spill, LLOG would immediately 

implement its Regional Oil Spill Response Plan and activate source 

control and countermeasures to minimize these potential impacts.

• Chemosynthetic Communities

Water depths in Mississippi Canyon Block 707 range from 1525’ to 1575’

including anchor radius. The proposed activities are not located within the 

vicinity of any known chemosynthetic communities, which typically occur 

in water depths greater than 300 meters. Based on the water depth, there 

are no anticipated emissions, effluents, emissions physical disturbances to 

seafloor, wastes sent to shore, and/or accidents from the proposed 

activities that could impact these types of communities. 

• Water Quality 

Bottom disturbances which may result based on placement of drilling rigs 

during an exploratory phase could increase water column turbidity and 

redistribution of any accumulated pollutants in the water column; which 

could cause temporary impacts on w ater quality conditions in the 

immediate vicinity.

Associated overboard effluents are regulated by the EPA Region VI 

NPDES General Permit GMG290000 which mandates volume discharge 

rate limitations, certain testing requirements for toxicity and oil and grease 

limitations. A s such, it is not anticipated these discharges authorized 

under the approved EPA NPDES permit will cause significant adverse 

impacts to water quality.

Certain wastes generated from the proposed activities will be manifested 

and sent to shore for treatment and/or disposal at approved facilities. 

Other waste which may be considered hazardous will be collected and 

transported in sealed containers and transported to approve disposal sites 

in accordance with the RCRA regulations and guidelines. 

An accidental oil spill release from the proposed activities, and cumulative 

similar discharge activity within the vicinity could potentially cause 

temporary impacts to water quality. In the event of such a r elease, the 

water quality would be temporarily affected by the dissolved components 

and small droplets. Currents and microbial degradation would remove the 

oil from the water column or dilute the constituents to background levels. 

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Fisheries

Accidental oil spill releases from the proposed activities, and cumulative 

similar discharge activity within the vicinity may potentially cause some 

detrimental effects on fisheries. It is unlikely a spill would occur; 

however, such a release in open waters closed to mobile adult finfish or 

shellfish would likely be sub-lethal and the extent of damage would be 

reduced to the capability of adult fish and shellfish to avoid a spill, to 

metabolize hydrocarbons, and to excrete both metabolites and parent 

compounds. 

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Marine Mammals

GulfCet II studies reveal that cetaceans of the continental shelf and shelf 

edge are comprised of bottlenose dolphin and Atlantic spotted dolphin. 

Squid eaters, including dwarf and pygmy killer whale, Risso’s dolphin and 

Cuvier’s beaked whale occur most frequently along the upper slope in 

areas outside of anticyclones.

As a result of the proposed activities, marine mammals may be adversely 

impacted by emissions, effluents, waste sent to shore and/or accidents. 

Chronic and sporadic sub-lethal effects would occur that may stress and/or 

weaken individuals of a local group or population and make them more 

susceptible to infection from natural or anthropogenic sources. Few lethal 

effects are expected from an accidental oil spill, chance collisions with 

service vessels and ingestion of plastic material.

The net results of any disturbance would depend on t he size and 

percentage of the population affected, ecological importance of the 

disturbed area, environmental and biological parameters that influence an 

animal’s sensitivity to disturbance and stress, and the accommodation time 

in response to prolonged disturbance (Geraci and St. Aubin, 1980). 

Collisions between cetaceans and ship could cause serious injury or death 

(Laist et al., 2001). 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

Sperm whales are one of 11 whale species that are hit commonly by ships 

(Laist et al., 2001). Collisions between OCS vessels and cetaceans within 

the project area are expected to be unusual events. 

LLOG does not anticipate the incidental taking of any marine mammals as 

the result of the proposed activities. T he proposed activities will be 

conducted by our company and its contractors under the additional criteria 

addressed in BSEE NTL No. 2012-G01 “Marine Trash and Debris 

Awareness Training and Elimination” and Joint NTL No. 2012-G01 

“Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”. 

The proposed operations will be conducted in accordance with the 

regulations via manifesting waste sent to shore and ensuring such wastes 

are contained to prevent loss. Informational placards will be maintained 

on the facility, and LLOG and the associated contractors obtain training on 

at least an annual basis to ensure personnel are aware of the reporting and 

operational requirements. 

LLOG will conduct the proposed activities under EPA’s Region VI 

NPDES General Permit GMG290000 which authorizes the discharge of 

certain effluents, subject to certain limitations, prohibitions and 

recordkeeping requirements. A s such, it is not anticipated these 

discharges authorized under the approved EPA NPDES permit will not 

cause significant adverse impacts to water quality.

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Sea Turtles

Small numbers of turtles could be killed or injured by chance collision 

with service vessels or by eating indigestible trash, particularly plastic 

items accidentally lost from drilling rigs, production facilities and service 

vessels. Drilling rigs and project vessels produce noise that could disrupt 

normal behavior patterns and create some stress to sea turtles, making 

them more susceptible to disease. A ccidental oil spill releases are 

potential threats which could have lethal effects on turtles. Contact and/or 

consumption of this released material could seriously affect individual sea 

turtles. Most OCS related impacts on sea turtles are expected to be sublethal. Chronic and/or avoidance of affected areas could cause declines in 

survival or productivity, resulting in gradual population declines. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

LLOG will conduct the proposed activities under EPA’s Region VI 

NPDES General Permit GMG290000 which authorizes the discharge of 

certain effluents, subject to certain limitations, prohibitions and 

recordkeeping requirements. A s such, it is not anticipated these 

discharges authorized under the approved EPA NPDES permit will not 

cause significant adverse impacts to water quality.

Additionally, LLOG and its contractors will conduct the proposed 

activities under the additional criteria addressed by BSEE NTL No. 2012-

G01 “Marine Trash and Debris Awareness Training and Elimination” and 

Joint NTL No. 2012-G01 “Vessel Strike Avoidance and Injured/Dead 

Protected Species Reporting”. The proposed operations will be conducted 

in accordance with the regulations via manifesting waste sent to shore and 

ensuring such wastes are contained to prevent loss. Informational placards 

will be maintained on the facility, and LLOG and the associated 

contractors obtain training on at least an annual basis to ensure personnel 

are aware of the reporting and operational requirements.

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Air Quality

The proposed activities are located approximately 51 miles to the nearest 

shoreline. LLOG has addressed the air quality issues associated with the 

proposed activities in the “Air Emissions Information” section of this Plan 

as a result of the proposed activities. 

• Ship Wreck Sites (Known or Potential)

There are no physical disturbances to the seafloor which could impact 

known or potential shipwreck sites, as the review of high resolution 

shallow hazards data indicate there are no known or potential shipwreck 

sites located within the survey area. As such, LLOG does not anticipate 

any IPF’s as a result of the proposed activities. 

• Prehistoric Archaeological Sites

There are no physical disturbances to the seafloor which could cause 

impacts to prehistoric archaeological sites, as the review of high resolution 

shallow hazards data and supporting studies did not reflect the occurrence 

of prehistoric archaeological sites. As such LLOG does not anticipate any 

IPF’s as a result of the proposed activities. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

Vicinity of Offshore Location 

• Essential Fish Habitat

As a result of the proposed activities, essential fish habitat may be 

adversely impacted by effluents and/or accidents.

An Accidental oil spill that may occur as a result of the proposed activities 

has potential to cause some detrimental effects on essential fish habitat. It 

is unlikely that an accidental oil spill release would occur; however, if a 

spill were to occur in close proximity to finfish or shellfish, the effects 

would likely be sub-lethal and the extent of damage would be reduced to 

the capability of adult fish and shellfish to avoid a spill, to metabolize 

hydrocarbons and to excrete both metabolites and parent compounds. 

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Marine and Pelagic Birds

As a result of the proposed activities, marine and pelagic birds may be 

adversely impacted by an accidental oil spill, by the birds coming into 

contact with the released oil.

In the event of an unanticipated blowout resulting in an oil spill, it is likely 

to have an impact based on the industry wide standards for using proven 

equipment and technology for such responses. In that event, LLOG will 

implement the Regional Oil Spill Response Plan and activate source 

control and countermeasures to minimize these potential impacts.

• Public Health and Safety

There are no anticipated emissions, effluents, wastes sent to shore, and/or 

accidents from the proposed activities that could cause impacts to the 

public health safety. BOEM classified the proposed objective area as 

absent of hydrogen sulfide. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

Coastal and Onshore 

• Beaches

As a result of the proposed activities, beaches may be adversely impacted 

by an accidental oil spill. H owever, due to the distance from shore 

(approximately 51 miles), and the response capabilities that would be 

implemented, no significant adverse impacts are expected. Both historical 

spill data and the combined trajectory/risk calculations referenced in the 

publication of OCS EIA/EA BOEMRE 2002-052 indicate there is little 

risk of contact or impact to the coastline and associated environmental 

resources.

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Wetlands 

As a result of the proposed activities, wetlands may be adversely impacted 

by an accidental oil spill. H owever, due to the distance from shore 

(approximately 51 miles) and the response capabilities that would be 

implemented, no significant adverse impacts are expected. Both historical 

spill data and the combined trajectory/risk calculations referenced in the 

publication of OCS EIA/EA BOEMRE 2002-052 indicate there is little 

risk of contact or impact to the coastline and associated environmental 

resources.

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Shore Birds and Coastal Nesting Birds

As a result of the proposed activities, shore birds and coastal nesting birds 

may be adversely impacted by an accidental oil spill. However, due to the 

distance from shore (approximately 51 miles) and the response capabilities 

that would be implemented, no significant adverse impacts are expected. 

Both historical spill data and the combined trajectory/risk calculations 

referenced in the publication of OCS EIA/EA BOEMRE 2002-052 

indicate there is little risk of contact or impact to the coastline and 

associated environmental resources.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Coastal Wildlife Refuges 

As a result of the proposed activities, coastal wildlife refuges may be 

adversely impacted by an accidental oil spill. H owever, due to the 

distance from shore (approximately 51 miles) and the response capabilities 

that would be implemented, no significant adverse impacts are expected. 

Both historical spill data and the combined trajectory/risk calculations 

referenced in the publication of OCS EIA/EA BOEMRE 2002-052 

indicate there is little risk of contact or impact to the coastline and 

associated environmental resources.

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

• Wilderness Area

As a result of the proposed activities, wilderness areas may be adversely 

impacted by an accidental oil spill. H owever, due to the distance from 

shore (approximately 51 miles) and the response capabilities that would be 

implemented, no significant adverse impacts are expected. Both historical 

spill data and the combined trajectory/risk calculations referenced in the 

publication of OCS EIA/EA BOEMRE 2002-052 indicate there is little 

risk of contact or impact to the coastline and associated environmental 

resources.

In the event of an unanticipated blowout, LLOG will implement industry 

wide standards for using proven equipment and technology for such 

responses. LLOG would immediately implement its Regional Oil Spill 

Response Plan and activate source control and countermeasures to 

minimize these potential impacts.

Other Resources Identified

LLOG has not identified any other environmental resources other than those 

addressed above.
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

C. Impacts of Proposed Activities

LLOG does not anticipate any impacts on the offshore site specific locations, 

offshore vicinity, and/or coastal and onshore environmental conditions based on 

the potential impacts identified in the EIA worksheets and historical operations in

the exploration of this reservoir. 

D. Environmental Hazards

Mississippi Canyon Block 707 is not located within a geographic area impacted 

by strong environmental phenomena, other than potential hurricanes in the Gulf of 

Mexico. The Gulf of Mexico may experience several hurricanes throughout the 

season which typically runs from June through November. A severe hurricane 

may impact the activities covered in this Plan. Such impacts may be damage to 

the drilling rig, the unanticipated release of hydrocarbons depending upon the 

current status of the well. Additionally, this block has the potential to be affected 

by the “Loop Current” which is a warm ocean current in the Gulf of Mexico that 

flows northward between Cuba and the Yucatan Peninsula, moves northward into 

the Gulf of Mexico, then loops east and south before exiting to the east through 

the Florida Straits. While the loop current is present approximately 95% of the 

time, it is most active in the summer and fall seasons.

To mitigate potential impacts to the well during impending hurricanes or loop 

currents, LLOG will take precautionary measures by securing the well, rig and 

evacuation of personnel; and will comply with the requirements of NTL’s 2008-

G09 and 2009-G10. 

E. Alternatives

LLOG did not consider any alternatives to reduce environmental impacts as a 

result of the proposed activities. 

F. Mitigation Measures

LLOG will not implement any mitigation measures to avoid, diminish or 

eliminate potential environmental resources, other than those required by 

regulation and policy. 

G. Consultation

LLOG has not contacted any agencies or persons for consultation regarding 

potential impacts associated with the proposed activities. Therefore, a list of such 

entities is not being provided. 
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

H. Preparers

Questions or requests for additional information should be made to LLOG’s 

authorized representative of this Plan: 

Nelda Runyon 

Regulatory Specialist 

1001 Ochsner Boulevard, Suite 200 

Covington, Louisiana 70433 

985-801-4300 (Phone) 

neldar@llog.com 

I. References

The following documents were utilized in preparing the Environmental Impact 

Assessment:

Document Author Dated

Archaeological Deep Tow Assessment Tesla 2007

3D Geohazard Assessment, Locations B & C Gardline 2014

Archaeological Assessment Tesla 2014

Initial Exploration Plan (N-7922)

MC 707 

Westport Resources Corporation 2003

 

BOEMRE Environmental Impact Statement Report No. 

2007-003

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2007

Title 30 CFR Part 250 Subpart B (250.216 / 250.221 / 

250.223 / 250.227

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2006

NTL 2000-G16 “Guidelines for General Lease Surety 

Bonds”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2000

NTL 2005-G07 “Archaeological Resource Surveys and 

Reports”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2005

NTL 2006-N06 “Flaring and Venting Regulations” Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2006

NTL 2006-G07 “Revisions to the List of OCS Lease Blocks 

Requiring Archaeological Surveys and Reports:”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2006

NTL 2008-G04 “Information Requirements for Exploration 

Plans and Development Operations Coordination 

Documents”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement 

2008

NTL 2008-N05 “Guidelines for Oil Spill Financial 

Responsibility for Covered Offshore Facilities”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

NTL 2008-G06 “Remotely Operated Vehicle Surveys in 

Deepwater”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

NTL 2008-N07 “Supplemental Bond Procedures Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

NTL 2008-G20 “Revisions to the List of OCS Lease Blocks 

Requiring Archaeological Resource Surveys and Reports”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

NTL 2009-G02 “Ocean Current Monitoring” Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-G27 “Submitting Exploration Plans and 

Development Operations Coordination Documents”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-G29 “Implementation Plan for Transition from 

North American Datum 27 to North American Datum 83”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-G31 “Hydrogen Sulphide” Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

NTL 2009-G34 “Ancillary Activities” Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-G38 “Drilling Windows, Eastern Gulf of 

Mexico”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-G39 “Biologically-Sensitive Underwater 

Features and Areas”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-G40 “Deepwater Benthic Communities” Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-N11 “Air Quality Jurisdiction on the OCS” Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2010-N05 “Increased Safety Measures for Energy 

Development on the OCS”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2010

NTL 2010-N06 “Information Requirements for EP’s, 

DOCD’s, DPP on the OCS”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2010

NPDES General Permit GMG290000 EPA – Region VI 2012

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2013

Joint NTL 2012-G02

Implementation of Seismic Survey Mitigation Measures 

and Protected Species Observer Program

Bureau of Ocean Energy Management 2012

BSEE NTL 2012-G02

“Marine Trash & Debris Awareness & Eliminiation”

Bureau of Ocean Energy Management 2012

JOINT NTL 2012-G01 “Vessel Strike Avoidance and 

Injured/Dead Protective Species”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2012
Revised Exploration Plan

Mississippi Canyon Block 707 – OCS-G-25103

APPENDIX Q

ADMINISTRATIVE INFORMATION

(30 CFR Part 250.228 and 250.262)

A. Exempted Information Description (Public Information Copies 

only)

Excluded from the Public Information copies are the following: 

• Proposed bottom hole location information 

• Proposed total well depths (measured and true vertical depth) 

• Production Rates and Life of Reserves

• New and Unusual Technologies 

• Geological and Geophysical Attachments

B. Bibliography

The following documents were utilized in preparing this Plan: 

Document Author Dated

Archaeological Deep Tow Assessment Tesla 2007

3D Geohazard Assessment, Locations B & C Gardline 2014

Archaeological Assessment Tesla 2014

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2012