UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - S-07666

Type - Supplemental Exploration Plan

Lease(s) - OCS-G24062 Block - 253 Mississippi Canyon Area

OCS-G32303 Block - 208 Mississippi Canyon Area

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

Wells A-E and wells H & I

Not Found

Attached is a copy of the subject plan for public comments on issues that 

should be addressed in an Environmental Assessment.

It has been deemed submitted as of this date and is under review for approval.

Michelle Griffitt

Plan Coordinator

Description -

Rig Type -

Subject:

From:

June 10, 2014
 

LLOG EXPLORATION OFFSHORE, L.L.C.

1001 Ochsner Boulevard, Suite 200

Covington, Louisiana 70433

SUPPLEMENTAL EXPLORATION PLAN

OCS-G-32303 & OCS-G-24062 

MISSISSIPPI CANYON BLOCKS 208/253

PREPARED BY:

Nelda Runyon 

Regulatory Specialist 

985-801-4300 – Main

985-801-4389 – Direct

neldar@llog.com 

March 19, 2014
LLOG EXPLORATION OFFSHORE, L.L.C.

REVISED EXPLORATION PLAN 

OCS-G-32303 & 24062 Leases 

Mississippi Canyon Blocks 208 & 253 

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 Support Vessels and Aircraft Information 

APPENDIX M Onshore Support Facilities Information 

APPENDIX N Coastal Zone Management Act (CZMA) Information 

APPENDIX O Environmental Impact Analysis 

APPENDIX P Administrative Information 
 

APPENDIX A

PLAN CONTENTS

(30 CFR Part 250.211 and 250.241)

A. Plan Information

LLOG proposes to supplement our currently approved Initial Exploration Plan 

(N-09406) and Revised Plans (R-05208 and R5635) to include a DP 

Semisubmersible rig and a drillship rig. The approved Revised Exploration Plan 

(R-5208) was approved for the use of a moored semisubmersible rig. The 

proposed wells A – E will be drilled and/or completed with a DP semisubmersible 

or a drillship rig at Mississippi Canyon Blocks 208/253, OCS-G-32303 and OCSG-24062 Leases.

Location “B” was drilled and temporarily abandoned as Mississippi Canyon 

Block 253, Well No. 001, OCS-G 24062, on February 22, 2012. This well will be 

completed at a later date.

This Supplemental Exploration Plan is requesting to add two (2) additional 

locations, Locations “H” and “I” with surface locations located in Mississippi 

Canyon Block 253 (OCS-G 24062) and bottom hole locations located in

Mississippi Canyon Block 208 (OCS-G 32303). 

Proposed well locations “H” and “I” will traverse LLOG’s OCS-G 35491 Lease, 

Mississippi Canyon Block 252. 

B. Location

Included are the following attachments:

Attachment A: Form BOEMRE 137 – OCS Plan Information Form 

 Proposed Schedule and Pay.gov receipt for $7346.00 

Attachment B: Well Location Plats

Attachment C: Bathymetry Map 
 

C. Safety & Pollution Features

LLOG will utilize a drillship similar to Seadrill West Neptune, a DP 

semisubmersible drilling rig similar to the Seadrill Sevan Brazil and/or 

semisubmersible rig for the proposed operations. A description of the drilling 

units is included on the OCS Plans Information Form. Rig specifications and fuel 

history for the Seadrill West Auriga (drillship) and the Seadrill Sevan Brazil (DP 

semi) are attached. The rig descriptions will be made part of the Application for 

Permit to Drill.

Safety features on the drillship and the DP semisubmersible will include well 

control, pollution prevention, welding procedure, and blowout prevention 

equipment as described in Title 30 CFR Part 250, Subparts C, D, E, G & O; and 

as further clarified by Notices to Lessees, U.S. Environmental Protection Agency 

and the U.S. Coast Guard. The appropriate life rafts, life jackets, ring buoys, etc., 

as prescribed by the U.S. Coast Guard 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. 

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

A. Pollution Prevention Measures

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

regards to the proposed operations. 

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.
OCS PLAN INFORMATION FORM

Attachment A

(Public 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 4
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): 

Previously reviewed under an approved EP or 

DOCD? 

Yes No 

Is this an existing well 

or structure? 

Yes No If this is an existing well or structure, list the 

Complex ID or API No. 

Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes No 

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day): 

For structures, volume of all storage and 

pipelines (Bbls): 

API Gravity of 

fluid 

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

enter separate lines) 

Lease No. OCS OCS OCS 

OCS 

Area Name 

Block No. 

Blockline 

Departures 

(in feet)

N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L 

N/S Departure: F____ L 

N/S Departure: F____ L 

E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L 

E/W Departure: F____ L 

E/W Departure: F____ L 

Lambert XY 

coordinates 

X: X: X: 

X: 

X: 

Y: Y: Y: 

Y: 

Y: 

Latitude/ 

Longitude

Latitude Latitude Latitude 

Latitude 

Latitude 

Longitude Longitude Longitude 

Longitude 

Longitude 

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

Anchor Radius (if applicable) in feet: 

MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

Anchor Name 

 or No. 

Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

 

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

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

Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): 

Previously reviewed under an approved EP or 

DOCD? 

Yes No 

Is this an existing well 

or structure? 

Yes No If this is an existing well or structure, list the 

Complex ID or API No. 

Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes No 

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day): 

For structures, volume of all storage and 

pipelines (Bbls):

API Gravity of 

fluid

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

enter separate lines) 

Lease No. OCS OCS OCS

OCS

Area Name 

Block No. 

Blockline

Departures 

(in feet)

N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L

N/S Departure: F____ L 

N/S Departure: F____ L 

E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L 

E/W Departure: F____ L 

E/W Departure: F____ L 

Lambert XY

coordinates 

X: X: X: 

X:

X:

Y: Y: Y:

Y:

Y:

Latitude/

Longitude

Latitude Latitude Latitude 

Latitude

Latitude

Longitude Longitude Longitude 

Longitude

Longitude

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

Anchor Radius (if applicable) in feet: 

MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

Anchor Name 

 or No. 

Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

Form BOEM- 0137 (December 2011- Supersedes all previous editions of this form which may not be used.) Page 2 of 9

x R-5208 & R-5635

X N/A

X

38.2°

SEE ATTACHED

190,525







ATTACHMENT TO FORM MMS-137

OCS-G-32303 & OCS-G-24062 Leases

Mississippi Canyon Blocks 208/253

Supplemental Exploration Plan

TENTATIVE SCHEDULE OF PROPOSED ACTIVITIES

Proposed Activity Start Date End Date No. of 

Days

Location “H” – Drill 07/01/2014 08/30/2014 60

Location “H” – Complete 08/31/2014 10/05/2014 35

Location “B” – Complete ** 01/01/2015 02/14/2015 45

Location “C - Drill 01/01/2016 03/02/2016 60

Location “C” - Complete 03/02/2016 04/05/2016 35

Location “E” - Drill 01/01/2017 03/01/2017 60

Location “E” - Complete 03/02/2017 04/05/2017 35

Location “A” - Drill 01/01/2018 03/02/2018 60

Location “A” - Complete 03/02/2018 04/05/2018 35

Location “D” - Drill 01/01/2019 03/02/2019 60

Location “D” - Complete 03/02/2019 04/05/2019 35

Location “I” - Drill 01/01/2020 03/02/2020 60

Location “I” - Complete 03/02/2020 04/05/2020 35

*MC 253 #001 Well, Location “B”, was drilled and temporarily abandoned on 

02/22/2013 under LLOG’s Revised Exploration Plans, R05208 and R05635. 

WELL LOCATION PLAT

Attachment B

(Public Information)
"PUBLIC INFORMATION"

 LOCATION PLAT

OCS-G-32303

 BLOCK 253, MISSISSIPPI CANYON AREA

JOB No: REVISED: DATE:

FILENAME:

140052 Feb. 4, 2014

LLOG

BP

LLOG

CONPHIL/LLOG

MC252 MC253

MC208 MC209

OCS-G-32306

Well #1

OCS-G-24062

Well #1

LOC. "I"

OCS-G-32303

PROPOSED SURFACE LOCATIONS

BLOCK CALLS X COORDINATE Y COORDINATE LATITUDE LONGITUDE

MC253 "H" 3,680' FNL 596' FWL 1,204,436.00' 10,434,880.00' 
1 
:

NAD27

ZONE 16 NORTH

UTM GRID NORTH

LOC. "H"

OCS-G-32303

MC253 "I" 3,580' FNL 596' FWL 1,204,436.00' 10,434,980.00' 
1 
:

2000 0 2000

SCALE IN US SURVEY FEET
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88°21'0"W88°20'0"W88°19'0"W

28°45'0"N

28°44'0"N

28°43'0"N

1,205,0001,210,0001,215,000

10,425,000

10,430,000

10,435,000

10,440,000

0 1,000 2,000 500 Feet

0 250 500 125 Meters

Chart scale 1" = 2,000'

Bathymetry Plat Figure 10

2,000ft Radius

MISSISSIPPI CANYON BLOCK 253

OCS-G24062

MISSISSIPPI CANYON BLOCK 209

OCS-G24055

MISSISSIPPI CANYON BLOCK 297

OCS-G34434

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-4750

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-4770

-4780

-4910

-4790

-4900

-4800

-4810

-4820

-4830

-4840

-4850

-4890

-4860

-4870

-4880

-4920

-4930

-4940

-4950

-4960

-4970

-4980

-4990

-5000

-5010

-5020

-5030

-5040

-5050

-5060

-5070

-5080

-5090

-5110

-5100

-4690

-4680

-4670

-5120

-4660

-4650

-4640

-4630

-4620

-5130

-4610

-4600

-4590

-4580

-4570

-4560

-4550

-4540

-4530

-4520

-4510

-4500

-4490

-4480

-4470

-4460

-5140

-4450

-4440

-4430

-4420

-4410

-5150

-4400

-4390

-4380

-5160

-4370

-5170

-5180

-5190

-4360

-4350

-5200

-4340

-4330

-5210

-5220

-4320

-5230

-4310

-4300

-4290

-4280

-4270

-4260

-4250

-4240

-5240

-4230

-4220

-5250

-4210

-4200

-5260

-4190

-4180

-4170

-5270

-4160

-4150

-5280

-4140

-4130

-5290

-4120

-5300

-4110

-5310

-4100

-4090

-4840

-4270

-4920

-4920

-4890

-4920

-5130

-4830

-4950

-4910

-4820

-4810

-4100

-4360

-4900

-4910

-4880

-4820

-4850

-4880

-4870

-4280

-4830

-4850 -4290

-4890

-4790

-4930

-4840

-4840

-4860

-4810

-4800

-4890

-4810

-5120

-4820

-4910

-4840

-4900

-4860

-4940

-4830

-4830

-4870

-4830

-4850

-4920

-4800

-4930

-4300

Proposed MC208-H Well

Existing MC253-1 Well

Proposed MC208-I Well

1,190,0001,195,0001,200,0001,205,0001,210,0001,215,0001,220,000

10,420,000

10,425,000

10,430,000

10,435,000

10,440,000

10,445,000

10,450,000

88°24'0"W88°23'0"W88°22'0"W88°21'0"W88°20'0"W88°19'0"W

28°47'0"N

28°46'0"N

28°45'0"N

28°44'0"N

28°43'0"N

Lund

East Breaks Green Canyon Atwater Valley Garden Banks

Walker Ridge

Mississippi Canyon

Alaminos Canyon Keathley Canyon

Study Area

LEGEND

Chart scale 1"=1,000'

3D GEOHAZARD ASSESSMENT

GULF OF MEXICO

MISSISSIPPI CANYON

BLOCK 253

GEODETIC INFORMATION

BIOLOGICAL, PHYSICAL AND SOCIO-ECONOMIC CHART

0 1,000 2,000 4,000 6,000 Feet

0 250 500 1,000 1,500 Meters

Depth in feet below sea surface to 

seabed, contoured at 10ft intervals

REV DATE REMARKS AUTHOR DRAWN CHECKED

SURVEY DATE N/A REPORT REF 10004/10005 REFF NO 9988/9989.01

0 FEBRUARY 21, 2014 DRAFT JR VC ARH

Not to scale

Prepared by: Gardline Surveys, Inc. 1500 Bingle Road, Houston, Texas, 77055. Telephone: 713.481.4630

Notes

-4930

±

Coordinate System: NAD 1927 UTM Zone 16N

Projection: Transverse Mercator

Datum: North American 1927 

Units: Foot US

False Easting: 1,640,416.6667

False Northing: 0.0000

Central Meridian: -87.0000

Scale Factor: 0.9996

Latitude Of Origin: 0.0000

Service Layer Credits: Sources: Esri, GEBCO, NOAA, National Geographic, DeLorme, HERE, Geonames.org, and other contributors

Existing MC253-1 Well Location 

(1,204,437ft E, 10,434,799ft N)

6

MISSISSIPPI CANYON BLOCK 252

OCS-G32306

MISSISSIPPI CANYON BLOCK 253

OCS-G24062

MISSISSIPPI CANYON BLOCK 208

OCS-G32303

MISSISSIPPI CANYON BLOCK 209

OCS-G24055

Fluid expulsion sites favorable

for sensitive sessile benthic 

communities 

Mississippi Canyon Block 296 

OCS-G21164

Mississippi Canyon Block 297

NOT LEASED 

2000M Radius

Proposed MC208-H Well Location 

with surface location in MC253

(1,204,436ft E, 10,434,880ft N)

3® 3

3

3

Proposed MC208-I Well Location 

with surface location in MC253

(1,204,436ft E, 10,434,980ft N)

3® 3

3

3

10,000ft Radius

1,000ft Buffer Zone

10,000ft Radius

1,000ft Buffer Zone

1 MARCH 19, 2014 FINAL REV 1 JR VC ARH
 

APPENDIX B 

General Information

(30 CFR Part 250.213 and 250.243)

A. Applications and Permits

The following Federal/State applications will be submitted for the activities 

provided for in this Plan (exclusive to BOEM permit applications and general 

permits issued by the EPA and COE) 

Application/Permit Issuing Agency Status

CZM Consistency Determination AL & LA CZM Pending

Rig Move Reports USCG, MWA and NGA Pending

B. Drilling Fluids

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be

used per well

Water Based (seawater, freshwater, barite) See Tables 1 & 2 of Appendix F

Oil-based (diesel, mineral oil) N/A

Synthetic-based (internal, olefin, ester) See Tables 1 & 2 of Appendix F

C. Oil Characteristics

LLOG does not propose production, handling, transported or stored to conduct 

the proposed activities. 

D. New or Unusual Technology

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

operations proposed in this Plan. 

E. Bonding Statement

The bond requirements for the activities and facilities proposed in this EP are 

satisfied by an area wide bond, furnished and maintained according to 30 CFR 

Part 256; subpart I; NTL No. 2000-G16, “Guidelines for General Lease Surety 

Bonds,” and additional security under 30 C FR 256.43(d) and National NTL 

No. 2008-N07 “Supplemental Bonding Procedures.” 
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BLOWOUT SCENARIO 

 MC 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 1 of 8 

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 253 “A” OCS-G-24062 5042 1,204,584’ 10,431,637’ 28° 44’ 17.68” 88° 21’ 37.34” 

MC 253 “B” OCS-G-24062 4922 1,204,436’ 10,434,800’ 28° 44’ 48.98” 88° 21’ 39.41” 

MC 208 “C” OCS-G-32303 4750 1,202,630’ 10,439,071’ 28° 45’ 31.07” 88° 22’ 00.25” 

MC 208 “D” OCS-G-32303 4707 1,200,850’ 10,439,116’ 28° 45’ 31.31” 88° 22’ 20.26” 

MC 208 “E” OCS-G-32303 4645 1,203,299’ 10,446,834’ 28° 46’ 48.01” 88° 21’ 53.74” 

INFORMATION REQUIREMENTS

A) Blowout scenario 

The MC 253 well 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 Revised EP 

Type of Activity Drilling 

Facility Location (area / block) MC 253 

Facility Designation MODU 

Distance to Nearest Shoreline (miles) ~54 

Uncontrolled Blowout (Volume per day) 190,525 bbls 

Type of Fluid Crude 

C) Total volume and maximum duration of the potential blowout 

Duration of Flow (days) 114 days total (see Relief Well Response Estimate below) 

Total Volume of Spill (bbls) 21.7 MMBO based on 114 days of uncontrolled flow 

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

 

 Sbmitted under separate cover with the Proprietary Copy of this Plan. Omitted from Public 

 Information Copies. 

E) Potential for the well to bridge over 
BLOWOUT SCENARIO 

 MC 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 2 of 8 

Confidential

2 

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 

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 
BLOWOUT SCENARIO 

 MC 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 3 of 8 

Confidential

3 

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

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 (Moored Semi) 

• Ensco 8502 (DP Semi) 

• Transocean Enterprise (DP Drillship) 

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 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 4 of 8 

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 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 5 of 8 

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. 

Nearest production pipeline tie-ins are located ~3 miles from ENI MC 296 subsea manifold located on 

MC 252 block. Other subsea manifold tie-in includes ~8 miles from ExxonMobil MC 211 and ~9 miles 

from ENI MC 299. Potential to utilize these lines in the event of a “cap and flow” scenario are 

possible. 

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

targets for the proposed wells. A total of 8 relief well surface locations are proposed for the 2 drill 

sites in the Proposed Exploration Plan wells. These 2 drill sites are the most probable well sites for a 

development scenario. The additional EP locations can be drilled from the 2 selected drillsites if 

needed. 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 208 “D” OCS-G-32303 MC 208 NW Relief Well 1,197,995’ 10,441,996’ 

MC 208 NE Relief Well 1,203,377’ 10,440,148’ 

MC 208 SSE Relief Well 1,201,434’ 10,435,866’ 

MC 208SW Relief Well 1,198,871’ 10,436,666’ 

MC 253 “B” OCS-G-24062 MC 253 NW Relief Well 1,202,159’ 10,437,925’ 

MC 253 NE Relief Well 1,206,312’ 10,437,206’ 

MC 253 SE Relief Well 1,207,658’ 10,432,984’ 

MC 253 SW Relief Well5 1,201,626’ 10,432,984’ 

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 
BLOWOUT SCENARIO 

 MC 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 6 of 8 

Confidential

6 

• 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) 

 75 

PERFORM HYDRAULIC KILL OPERATIONS / SECURE BLOWNOUT WELL 

• continue intervention and containment measures

• continue spill control measures

• perform hydraulic kill operations, monitor well, secure well

 

 20 

 ESTIMATED TOTAL DAYS OF UNCONTROLLED FLOW 114 

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

 TOTAL DAYS 144 
BLOWOUT SCENARIO 

 MC 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 7 of 8 

Confidential

7 
BLOWOUT SCENARIO 

 MC 208-253 

Created by: S.L. Stegeman 

Last Revised: 7/13/2011 

Page 8 of 8 

Confidential

8 
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LLOG Exploration Company Gardline Report 9988

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252-253 – Proposed MC208-H Well Location 

Public Shallow Hazards Statement – MC208-H (With Surface Location in MC253)

February 21, 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 253 

OCS-(G 24062) 

Ladies/Gentlemen:

LLOG Exploration Company contracted Gardline Surveys, Inc. to prepare a Well Clearance Letter for 

the proposed MC208-H well with surface location in Block 253, Mississippi Canyon Area (OCS-G 

24062). This letter addresses seafloor and shallow geologic conditions that may impact exploratory 

drilling operations within 2,000ft of the proposed well site. The depth limit of this geohazard assessment 

is 3.2 seconds TWT at -8,758ft below sea surface (3,839ft below seabed).

This hazards summary letter is issued as a supplement to Gardline Reports No. 8025 entitled 3D 

Geohazard Assessment, Gulf of Mexico, Mississippi Canyon, Blocks MC208 and 253, Volume 1, May 

2009, Volume 2, MC208-C, D, and E Well Clearance Letters, July 2011, and Volume 3, MC253-A & B 

Well Clearance Letters, July 2011. 

Proposed MC208-H Location (With Surface Location in MC253)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid UTM Zone 16N

Latitude 28° 44' 49.77” North Easting 1,204,436 US Feet East

Longitude 88° 21’ 39.42” West Northing 10,434,880 US Feet North

FWL of Mississippi Canyon 253 596 US Feet Inline 17335

FNL of Mississippi Canyon 253 3,680 US Feet Crossline 14177

Water Depth: -4,919 Feet Slope: 2.9° Southeast

Nearest Shoreline: 54 Miles @ 300° 

Port of Operation: Fourchon 116 Miles @ 283° 

Nearest Manned Platform: MC474 “A(NA KIKA FPDS)” 16 Miles @ 164° 
LLOG Exploration Company Gardline Report 9988

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252-253 – Proposed MC208-H Well Location 

Seabed Hazards. The seabed presents a sloping seabed exhibiting areas of slight diapirically induced 

uplift and faulting associated with it. These features do not affect the proposed MC208-H well location.

There are no indications of seabed fluid seeps within 2,000ft of the well location.

No existing seabed infrastructure is located in the area. No seabed obstructions are observed within 

the resolution capabilities of the 3D seismic data.

Sub-Seabed Hazards. A Moderate Risk of Gas is present at depth in the proposed well bore but full 

well control will be established. A Slight Shallow Water Flow Risk is interpreted in several intervals. A 

fault exists within the lower Unit E.

Conclusions and Recommendations. A Slight Shallow Water Flow Risk is interpreted at multiple 

levels. Appropriate drilling methodology to contain minor, non-persistent shallow water flow events 

should be utilized when passing through these intervals. A normal fault is present within Unit E which 

may cause drilling fluid circulation problems if pressures over hydrostatic are exerted by the drilling fluid 

column. Casings should be planned to avoid this fault intersection. A Moderate Risk of Gas is 

assigned to a possible sand interbed within Unit E; full well control should be established before 

contacting this anomaly.

Sincerely,

LLOG Exploration Company

Jaime Mata

Regulatory Specialist

PUBLIC INFORMATION
LLOG Exploration Company Gardline Report 9989

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252-253 – Proposed MC208-I Well Location 

Public Shallow Hazards Statement – MC208-I (With Surface Location in MC253)

February 21, 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 253 

OCS-(G 24062) 

Ladies/Gentlemen:

LLOG Exploration Company contracted Gardline Surveys, Inc. to prepare a Well Clearance Letter for 

the proposed MC208-I well with surface location in Block 253, Mississippi Canyon Area (OCS-G 

24062). This letter addresses seafloor and shallow geologic conditions that may impact exploratory 

drilling operations within 2,000ft of the proposed well site. The depth limit of this geohazard assessment 

is 3.2 seconds Two Way Time at -8,762ft below sea surface (3,850ft below seabed).

This hazards summary letter is issued as a supplement to Gardline Reports No. 8025 entitled 3D 

Geohazard Assessment, Gulf of Mexico, Mississippi Canyon, Blocks MC208 and 253, Volume 1, May 

2009, Volume 2, MC208-C, D, and E Well Clearance Letters, July 2011, and Volume 3, MC253-A & B 

Well Clearance Letters, July 2011. 

Proposed MC208-I Location (Surface)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid UTM Zone 16N

Latitude 28° 44' 50.76” North Easting 1,204,436 US Feet East

Longitude 88° 21’ 39.44” West Northing 10,434,980 US Feet North

FWL of Mississippi Canyon 253 596 US ft Inline 17336

FNL of Mississippi Canyon 253 3,580 US ft Crossline 14179

Water Depth: -4,912 Feet Slope: 3.3° Southeast

Nearest Shoreline: 54 Miles @ 300° 

Port of Operation: Fourchon 116 Miles @ 283° 

Nearest Manned Platform: MC474 “A(NA KIKA FPDS)” 16 Miles @ 164° 

Seabed Hazards. The seabed presents a sloping seabed exhibiting regions of slight diapirically 

induced uplift and faulting associated with it. These features do not affect the proposed MC208-I well 

location.
LLOG Exploration Company Gardline Report 9989

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252-253 – Proposed MC208-I Well Location 

There are no indications of seabed fluid seeps within 2,000ft of the well location.

No existing seabed infrastructure is located in the area.

Sub-Seabed Hazards. A sand interbed interpreted as a High Risk of Gas is present within Unit E. 

Several zones considered a Slight Shallow Water Flow Risk are interpreted.

The well will traverse a normal fault within Unit E.

Conclusions and Recommendations. A Slight Shallow Water Flow Risk is interpreted within 

several intervals. Appropriate drilling methodology to contain minor, non-persistent shallow water flow 

events should be utilized when passing through these intervals. A normal fault is present within Unit E 

which may cause drilling fluid circulation problems if pressures over hydrostatic are exerted by the

drilling fluid column. A High Risk of Gas is assigned to a possible sand interbed within Unit E; full well 

control should be established before contacting this anomaly.

Sincerely,

LLOG Exploration Company

Jaime Mata

Regulatory Specialist

PUBLIC INFORMATION
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E. Live Bottoms (Low Relief) Map

Mississippi Canyon Blocks 253 and 208 are not located within the vicinity 

of a proposed live bottom (Low Relief) area. 

F. Potentially Sensitive Biological Features Map

Mississippi Canyon Blocks 253 and 208 are not located within the vicinity 

of a proposed sensitive biological feature area.

G. Remotely Operated Vehicle (ROV) Monitoring Survey Plan

Mississippi Canyon Blocks 253 and 208 are not located within an area

where ROV surveys are required.

H. Threatened or Endangered Species, Critical Habitat, and 

Marine Mammal Information. 

Proposed activities in MC 253 and 208 are 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

 C & C Technologies Survey Services conducted an Archaeological and 

Hazard Study for LLOG Exploration Offshore, Inc. in May, 2009 

including Mississippi Canyon Blocks 253 and 208. This survey was 

submitted to Minerals Management Service under separate cover.

No change – Refer to Initial EP for MC 253, OCS-G-24062 Lease and 

MC 208, OCS-G-32303, Control No. N-09406 approved on October 

22, 2009.

J. Air and Water Quality Information

 Not applicable to proposed operations. 

K. Socioeconomic Information

 Not applicable to proposed operations. 
LLOG Exploration Company Gardline Report 9988

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252-253 – Proposed MC208-H Well Location 

Sensitive Sessile Benthic Community Statement – MC208-H 

LLOG Exploration Company

February 21, 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 253

OCS-(G 24062) 

Ladies/Gentlemen:

Gardline Surveys Inc was contracted by LLOG Exploration Company to prepare a Well Clearance 

Letter for the proposed MC208-H well with surface location in Mississippi Canyon, Block 253 (OCS-G 

24062). This letter addresses location proximity to potential sensitive sessile benthic community sites. 

LLOG Exploration Company indicates that this well will be drilled this well from a dynamically positioned 

drilling module; therefore, no anchors will impact seabed.

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

No. 8025 entitled 3D Geohazard Assessment, Gulf of Mexico, Mississippi Canyon, Blocks MC208 and 

253, Volume 1, May 2009, Volume 2, MC208-C, D, and E Well Clearance Letters, July 2011, and 

Volume 3, MC253-A & B Well Clearance Letters, July 2011. A Biological, Physical and SocioEconomic Map and Plat are included at the end of this appendix illustrating the areas of potential 

seabed impact. 

Proposed MC208-H Location (With Surface Location in MC253)

Location Coordinates

NAD 27 Datum - Clarke 1866 Ellipsoid UTM Zone 16N

Latitude 28° 44' 49.77” North Easting 1,204,436 US Feet East

Longitude 88° 21’ 39.42” West Northing 10,434,880 US Feet North

FWL of Mississippi Canyon 253 596 US Feet Inline 17335

FNL of Mississippi Canyon 253 3,680 US Feet Crossline 14177

Water Depth: -4,919 Feet Slope: 2.9° Southeast

Nearest Shoreline: 54 Miles @ 300° 

Port of Operation: Fourchon 116 Miles @ 283° 24’ 00’’

Nearest Manned Platform: MC474 “A(NA KIKA FPDS)” 16.14 Miles @ 164° 17’ 24”
LLOG Exploration Company Gardline Report 9988

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252-253 – Proposed MC208-H Well Location 

Potential Sensitive Sessile Benthic Communities. 

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

within 2,000 feet of any proposed mud and cuttings discharge location.

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

expulsion site approximately 11,000ft southeast of the proposed well location.

Conclusions and Recommendations: The proposed MC208-H well with surface location in MC253

will not impact any sites favorable for the development of sensitive sessile benthic communities.

Sincerely,

LLOG Exploration Company

Jaime Mata

Regulatory Specialist




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MC 208-253 - H & I

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, fill in the muds and cuttings.

EXAMPLE: Cuttings wetted with synthetic based fluid 

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

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

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Projected 

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APPENDIX G

Air Emissions Information

(30 CFR Part 250.218 and 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 DP 

semi-submersible drilling unit and drillship, and with related support vessels. 

Screening Questions for EP’s – DP Semi-submersible drilling unit 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

** LLOG is including actual fuel records for the Seadrill Sevan Brazil a DP 

Semisubmersible rig as well as the Rig Specifications. LLOG will be utilizing a 

new Seadrill rig Sevan LA DP Semisubmersible for the proposed operations and 

request approval to utilize the values of the comparable rig Sevan Brazil in the 

attached AQR spreadsheets

Screening Questions for EP’s – Drillship 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
 

** LLOG is including actual fuel records for the Seadrill West Auriga drillship as 

well as the Rig Specifications. LLOG will be utilizing a new Seadrill rig West 

Neptune drillship for the proposed operations and request approval to utilize the 

values of the comparable rig West Auriga in the attached AQR spreadsheets.

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 provided fuel records for both Seadrill West Auriga drillship and 

the Seadrill Sevan Brazil for emissions factors.

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.
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2014

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY LLOG Exploration Offshore, L.L.C.AREA Mississippi CanyonBLOCK 253/208LEASE OCS-24062/32303PLATFORM N/AWELL Well Locations H (Drill/Complete), B (Complete), C, E, A, D & I (Drill/CompleteCOMPANY CONTACT Nelda RunyonTELEPHONE NO. 985-801-4300REMARKS DP Semi-Submersible Rig (Seadrill Sevan LA)
EMISSIONS FACTORS

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

Fuel Usage Conversion Factors 1DWXUDO*DV7XUELQHV 1DWXUDO*DV(QJLQHV 'LHVHO5HFLS(QJLQH 5() '$7(

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Equipment/Emission Factors XQLWV 30 62[ 12[ 92& &2 5() '$7(

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1*F\FOHOHDQ JPVKSKU     $3 1*F\FOHOHDQ JPVKSKU     $3 1*F\FOHULFK JPVKSKU     $3 

'LHVHO5HFLSKS JPVKSKU      $3 

'LHVHO5HFLS!KS JPVKSKU      $3 'LHVHO%RLOHU OEVEEO      $3 

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Sulphur Content Source Value Units

)XHO*DV  SSP

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

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

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

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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

'5,//,1* 35,0(029(5!KSGLHVHO                  

35,0(029(5!KSGLHVHO               

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MISC. BPD SCF/HR COUNT7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2014 YEAR TOTAL 51.46 236.06 1768.82 53.06 385.92 16.55 75.94 569.06 17.07 124.16

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 2ND YEAR

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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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*DP Semisubmersible 35,0(029(5!KSGLHVHO               See Attached Fuel 35,0(029(5!KSGLHVHO               records & rig specs %851(5GLHVHO             of comparison rig $8;,/,$5<(48,3KSGLHVHO               Seadrill Sevan Brazil 9(66(/6!KSGLHVHOFUHZ               

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MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

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2015 YEAR TOTAL 51.72 237.27 1777.93 53.34 387.91 7.85 36.02 269.88 8.10 58.88

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 3RD YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ  2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ  

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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*DP Semisubmersible 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               records & rig specs %851(5GLHVHO             of comparison rig $8;,/,$5<(48,3KSGLHVHO               Seadrill Sevan Brazil 9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2016 YEAR TOTAL 51.72 237.27 1777.93 53.34 387.91 16.55 75.94 569.06 17.07 124.16

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 4TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ  2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ  

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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*DP Semisubmersible 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               records & rig specs %851(5GLHVHO             of comparison rig $8;,/,$5<(48,3KSGLHVHO               Seadrill Sevan Brazil 9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2017 YEAR TOTAL 51.72 237.27 1777.93 53.34 387.91 16.55 75.94 569.06 17.07 124.16

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 5TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ  2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ  

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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*DP Semisubmersible 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               records & rig specs %851(5GLHVHO             of comparison rig $8;,/,$5<(48,3KSGLHVHO               Seadrill Sevan Brazil 9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2018 YEAR TOTAL 51.72 237.27 1777.93 53.34 387.91 16.55 75.94 569.06 17.07 124.16

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 5TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ  2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ  

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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*DP Semisubmersible 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               records & rig specs %851(5GLHVHO             of comparison rig $8;,/,$5<(48,3KSGLHVHO               Seadrill Sevan Brazil 9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2019 YEAR TOTAL 51.72 237.27 1777.93 53.34 387.91 16.55 75.94 569.06 17.07 124.16

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 5TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ  2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ  

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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*DP Semisubmersible 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               records & rig specs %851(5GLHVHO             of comparison rig $8;,/,$5<(48,3KSGLHVHO               Seadrill Sevan Brazil 9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2020 YEAR TOTAL 51.72 237.27 1777.93 53.34 387.91 16.55 75.94 569.06 17.07 124.16

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


SUMMARY

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

&203$1< $5($ %/2&. /($6( 3/$7)250 :(//

//2*([SORUDWLR0LVVLVVLSSL&DQ\RQ  2&6 1$ +%&($'	,

Emitted Substance

Year

PM SOx NOx VOC CO

2014 16.55 75.94 569.06 17.07 124.16

2015 7.85 36.02 269.88 8.10 58.88

2016 16.55 75.94 569.06 17.07 124.16

2017 16.55 75.94 569.06 17.07 124.16

2018 16.55 75.94 569.06 17.07 124.16

2019 16.55 75.94 569.06 17.07 124.16

2020 16.55 75.94 569.06 17.07 124.16

2021 0.00 0.00 0.00 0.00 0.00

2022 0.00 0.00 0.00 0.00 0.00

2023 0.00 0.00 0.00 0.00 0.00

Allowable 1798.20 1798.20 1798.20 1798.20 48574.47






6HYDQ%UDVLO)XHOFRQVXPSWLRQ

9/1/2013 36 m3 9510.12 gal

9/2/2013 38 m3 10038.46 gal

9/3/2013 48 m3 12680.16 gal

9/4/2013 38 m3 10038.46 gal

9/5/2013 27 m3 7132.59 gal

9/6/2013 27 m3 7132.59 gal

9/7/2013 28 m3 7396.76 gal

9/8/2013 28 m3 7396.76 gal

9/9/2013 40 m3 10566.8 gal

9/10/2013 41 m3 10830.97 gal

9/11/2013 37 m3 9774.29 gal

9/12/2013 35 m3 9245.95 gal

9/13/2013 39 m3 10302.63 gal

9/14/2013 29 m3 7660.93 gal

9/15/2013 38 m3 10038.46 gal

9/16/2013 33 m3 8717.61 gal

9/17/2013 36 m3 9510.12 gal

9/18/2013 22 m3 5811.74 gal

9/19/2013 20 m3 5283.4 gal

9/20/2013 34 m3 8981.78 gal

9/21/2013 50 m3 13208.5 gal

9/22/2013 48 m3 12680.16 gal

9/23/2013 44 m3 11623.48 gal

9/24/2013 54 m3 14265.18 gal

9/25/2013 54 m3 14265.18 gal

9/26/2013 40 m3 10566.8 gal
9/27/2013 31 m3 8189.27 gal

9/28/2013 42 m3 11095.14 gal

9/29/2013 30 m3 7925.1 gal

9/30/2013 45 m3 11887.65 gal

10/1/2013 42 m3 11095.14 gal

10/2/2013 51 m3 13472.67 gal

10/3/2013 36 m3 9510.12 gal

10/4/2013 36 m3 9510.12 gal

10/5/2013 30 m3 7925.1 gal

10/6/2013 25 m3 6604.25 gal

10/7/2013 33 m3 8717.61 gal

10/8/2013 36 m3 9510.12 gal

10/9/2013 45 m3 11887.65 gal

10/10/2013 31 m3 8189.27 gal

10/11/2013 54 m3 14265.18 gal

10/12/2013 60 m3 15850.2 gal

10/13/2013 50 m3 13208.5 gal

10/14/2013 57 m3 15057.69 gal

10/15/2013 43 m3 11359.31 gal

10/16/2013 30 m3 7925.1 gal

10/17/2013 41 m3 10830.97 gal

10/18/2013 27 m3 7132.59 gal

10/19/2013 31 m3 8189.27 gal

10/20/2013 26 m3 6868.42 gal

10/21/2013 43 m3 11359.31 gal

10/22/2013 28 m3 7396.76 gal

10/23/2013 29 m3 7660.93 gal

10/24/2013 38 m3 10038.46 gal

10/25/2013 46 m3 12151.82 gal

10/26/2013 31 m3 8189.27 gal

10/27/2013 46 m3 12151.82 gal

10/28/2013 32 m3 8453.44 gal

10/29/2013 39 m3 10302.63 gal

10/30/2013 34 m3 8981.78 gal

10/31/2013 32 m3 8453.44 gal

11/1/2013 32 m3 8453.44 gal

11/2/2013 37 m3 9774.29 gal
11/3/2013 45 m3 11887.65 gal

11/4/2013 37 m3 9774.29 gal

11/5/2013 41 m3 10830.97 gal

11/6/2013 29 m3 7660.93 gal

11/7/2013 35 m3 9245.95 gal

11/8/2013 47 m3 12415.99 gal

11/9/2013 37 m3 9774.29 gal

11/10/2013 28 m3 7396.76 gal

11/11/2013 30 m3 7925.1 gal

11/12/2013 35 m3 9245.95 gal

11/13/2013 32 m3 8453.44 gal

11/14/2013 33 m3 8717.61 gal

11/15/2013 45 m3 11887.65 gal

11/16/2013 45 m3 11887.65 gal

11/17/2013 53 m3 14001.01 gal

11/18/2013 33 m3 8717.61 gal

11/19/2013 31 m3 8189.27 gal

11/20/2013 39 m3 10302.63 gal

11/21/2013 38 m3 10038.46 gal

11/22/2013 38 m3 10038.46 gal

11/23/2013 30 m3 7925.1 gal

11/24/2013 39 m3 10302.63 gal

11/25/2013 42 m3 11095.14 gal

11/26/2013 36 m3 9510.12 gal

11/27/2013 40 m3 10566.8 gal

11/28/2013 47 m3 12415.99 gal

11/29/2013 39 m3 10302.63 gal

11/30/2013 27 m3 7132.59 gal

12/1/2013 41 m3 10830.97 gal

12/2/2013 32 m3 8453.44 gal

12/3/2013 39 m3 10302.63 gal

12/4/2013 36 m3 9510.12 gal

12/5/2013 45 m3 11887.65 gal

12/6/2013 36 m3 9510.12 gal

12/7/2013 34 m3 8981.78 gal

12/8/2013 35 m3 9245.95 gal

12/9/2013 34 m3 8981.78 gal

12/10/2013 23 m3 6075.91 gal

12/11/2013 45 m3 11887.65 gal

12/12/2013 49 m3 12944.33 gal

12/13/2013 44 m3 11623.48 gal

12/14/2013 29 m3 7660.93 gal

12/15/2013 27 m3 7132.59 gal
12/16/2013 44 m3 11623.48 gal

12/17/2013 37 m3 9774.29 gal

12/18/2013 62 m3 16378.54 gal

12/19/2013 116 m3 30643.72 gal

12/20/2013 69 m3 18227.73 gal

12/21/2013 80 m3 21133.6 gal

12/22/2013 40 m3 10566.8 gal

12/23/2013 70 m3 18491.9 gal

12/24/2013 31 m3 8189.27 gal

12/25/2013 32 m3 8453.44 gal

12/26/2013 28 m3 7396.76 gal

12/27/2013 40 m3 10566.8 gal

12/28/2013 50 m3 13208.5 gal

12/29/2013 50 m3 13208.5 gal

12/30/2013 28 m3 7396.76 gal

12/31/2013 67 m3 17699.39 gal

1/1/2014 41 m3 10830.97 gal

1/2/2014 43 m3 11359.31 gal

1/3/2014 46 m3 12151.82 gal

1/4/2014 47 m3 12415.99 gal

1/5/2014 40 m3 10566.8 gal

1/6/2014 43 m3 11359.31 gal

1/7/2014 30 m3 7925.1 gal

1/8/2014 36 m3 9510.12 gal

1/9/2014 29 m3 7660.93 gal

1/10/2014 34 m3 8981.78 gal

1/11/2014 83 m3 21926.11 gal

1/12/2014 64 m3 16906.88 gal

1/13/2014 27 m3 7132.59 gal

1/14/2014 27 m3 7132.59 gal

1/15/2014 34 m3 8981.78 gal

1/16/2014 28 m3 7396.76 gal

1/17/2014 35 m3 9245.95 gal

1/18/2014 29 m3 7660.93 gal

1/19/2014 38 m3 10038.46 gal

1/20/2014 22 m3 5811.74 gal

1/21/2014 29 m3 7660.93 gal

1/22/2014 30 m3 7925.1 gal

1/23/2014 59 m3 15586.03 gal

1/24/2014 26 m3 6868.42 gal

1/25/2014 26 m3 6868.42 gal

1/26/2014 33 m3 8717.61 gal

1/27/2014 33 m3 8717.61 gal

1/28/2014 35 m3 9245.95 gal

1/29/2014 35 m3 9245.95 gal

1/30/2014 29 m3 7660.93 gal

1/31/2014 43 m3 11359.31 gal
2/1/2014 30 m3 7925.1 gal

2/2/2014 44 m3 11623.48 gal

2/3/2014 34 m3 8981.78 gal

2/4/2014 33 m3 8717.61 gal

2/5/2014 40 m3 10566.8 gal

2/6/2014 40 m3 10566.8 gal

2/7/2014 27 m3 7132.59 gal

2/8/2014 42 m3 11095.14 gal

2/9/2014 34 m3 8981.78 gal

2/10/2014 26 m3 6868.42 gal

2/11/2014 30 m3 7925.1 gal

2/12/2014 36 m3 9510.12 gal

2/13/2014 37 m3 9774.29 gal

2/14/2014 34 m3 8981.78 gal

2/15/2014 52 m3 13736.84 gal

2/16/2014 38 m3 10038.46 gal

2/17/2014 27 m3 7132.59 gal

2/18/2014 37 m3 9774.29 gal

2/19/2014 19 m3 5019.23 gal

2/20/2014 44 m3 11623.48 gal

2/21/2014 31 m3 8189.27 gal

2/22/2014 38 m3 10038.46 gal

2/23/2014 46 m3 12151.82 gal

2/24/2014 18 m3 4755.06 gal

2/25/2014 35 m3 9245.95 gal

2/26/2014 38 m3 10038.46 gal

2/27/2014 35 m3 9245.95 gal

2/28/2014 28 m3 7396.76 gal

3/1/2014 30 m3 7925.1 gal

3/2/2014 47 m3 12415.99 gal

3/3/2014 33 m3 8717.61 gal

3/4/2014 27 m3 7132.59 gal

3/5/2014 35 m3 9245.95 gal

3/6/2014 43 m3 11359.31 gal

3/7/2014 29 m3 7660.93 gal

3/8/2014 29 m3 7660.93 gal

3/9/2014 30 m3 7925.1 gal

3/10/2014 0 m3 0 gal

3/11/2014 0 m3 0 gal

3/12/2014 0 m3 0 gal

3/13/2014 0 m3 0 gal

3/14/2014 0 m3 0 gal

3/15/2014 0 m3 0 gal

3/16/2014 0 m3 0 gal

3/17/2014 0 m3 0 gal

3/18/2014 0 m3 0 gal

3/19/2014 0 m3 0 gal
3/20/2014 0 m3 0 gal

3/21/2014 0 m3 0 gal

3/22/2014 0 m3 0 gal

3/23/2014 0 m3 0 gal

3/24/2014 0 m3 0 gal

3/25/2014 0 m3 0 gal

3/26/2014 0 m3 0 gal

3/27/2014 0 m3 0 gal

3/28/2014 0 m3 0 gal

3/29/2014 0 m3 0 gal

3/30/2014 0 m3 0 gal

3/31/2014 0 m3 0 gal

4/1/2014 0 m3 0 gal

4/2/2014 0 m3 0 gal

4/3/2014 0 m3 0 gal

4/4/2014 0 m3 0 gal

4/5/2014 0 m3 0 gal

4/6/2014 0 m3 0 gal

4/7/2014 0 m3 0 gal

4/8/2014 0 m3 0 gal

4/9/2014 0 m3 0 gal

4/10/2014 0 m3 0 gal

4/11/2014 0 m3 0 gal

4/12/2014 0 m3 0 gal

4/13/2014 0 m3 0 gal

4/14/2014 0 m3 0 gal

4/15/2014 0 m3 0 gal

4/16/2014 0 m3 0 gal

4/17/2014 0 m3 0 gal

4/18/2014 0 m3 0 gal

4/19/2014 0 m3 0 gal

4/20/2014 0 m3 0 gal

4/21/2014 0 m3 0 gal

4/22/2014 0 m3 0 gal

4/23/2014 0 m3 0 gal

4/24/2014 0 m3 0 gal

4/25/2014 0 m3 0 gal

4/26/2014 0 m3 0 gal

4/27/2014 0 m3 0 gal

4/28/2014 0 m3 0 gal

4/29/2014 0 m3 0 gal

4/30/2014 0 m3 0 gal

5/1/2014 0 m3 0 gal

5/2/2014 0 m3 0 gal

5/3/2014 0 m3 0 gal

5/4/2014 0 m3 0 gal

5/5/2014 0 m3 0 gal
5/6/2014 0 m3 0 gal

5/7/2014 0 m3 0 gal

5/8/2014 0 m3 0 gal

5/9/2014 0 m3 0 gal

5/10/2014 0 m3 0 gal

5/11/2014 0 m3 0 gal

5/12/2014 0 m3 0 gal

5/13/2014 0 m3 0 gal

5/14/2014 0 m3 0 gal

5/15/2014 0 m3 0 gal

5/16/2014 0 m3 0 gal

5/17/2014 0 m3 0 gal

5/18/2014 0 m3 0 gal

5/19/2014 0 m3 0 gal

5/20/2014 0 m3 0 gal

5/21/2014 0 m3 0 gal

5/22/2014 0 m3 0 gal

5/23/2014 0 m3 0 gal

5/24/2014 0 m3 0 gal

5/25/2014 0 m3 0 gal

5/26/2014 0 m3 0 gal

5/27/2014 0 m3 0 gal

5/28/2014 0 m3 0 gal

5/29/2014 0 m3 0 gal

5/30/2014 0 m3 0 gal

5/31/2014 0 m3 0 gal

6/1/2014 0 m3 0 gal

6/2/2014 0 m3 0 gal
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2014

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY LLOG Exploration Offshore, L.L.C.AREA Mississippi CanyonBLOCK 253/208LEASE OCS-24062/32303PLATFORM N/AWELL Well Locations H (Drill/Complete), B (Complete), C, E, A, D & I (Drill/CompleteCOMPANY CONTACT Nelda RunyonTELEPHONE NO. 985-801-4300REMARKS Drillship6HDGULOO:HVW1HSWXQH
EMISSIONS FACTORS

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

Fuel Usage Conversion Factors 1DWXUDO*DV7XUELQHV 1DWXUDO*DV(QJLQHV 'LHVHO5HFLS(QJLQH 5() '$7(

6&)KSKU  6&)KSKU  *$/KSKU  $3 	

Equipment/Emission Factors XQLWV 30 62[ 12[ 92& &2 5() '$7(

1*7XUELQHV JPVKSKU     $3	 

1*F\FOHOHDQ JPVKSKU     $3 1*F\FOHOHDQ JPVKSKU     $3 1*F\FOHULFK JPVKSKU     $3 

'LHVHO5HFLSKS JPVKSKU      $3 

'LHVHO5HFLS!KS JPVKSKU      $3 'LHVHO%RLOHU OEVEEO      $3 

1*+HDWHUV%RLOHUV%XUQHUV OEVPPVFI      3	 1*)ODUHV OEVPPVFI     $3 /LTXLG)ODULQJ OEVEEO      $3	 7DQN9DSRUV OEVEEO  (	3)RUXP )XJLWLYHV OEVKUFRPS  $3,6WXG\ *O\FRO'HK\GUDWRU9HQW OEVPPVFI  /D'(4 *DV9HQWLQJ OEVVFI 

Sulphur Content Source Value Units

)XHO*DV  SSP

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

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

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

//2*([SORUDWLRQ2IIVKR 0LVVLVVLSSL&DQ\RQ  2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSO 1HOGD5XQ\RQ  

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

'5,//,1* 35,0(029(5!KSGLHVHO                  

35,0(029(5!KSGLHVHO               

*Drillship 35,0(029(5!KSGLHVHO               See Attached Fuel 35,0(029(5!KSGLHVHO               history for comparison %851(5GLHVHO             rig Seadrill W Auriga $8;,/,$5<(48,3KSGLHVHO               sister rig to Seadrill 9(66(/6!KSGLHVHOFUHZ               West Neptune 9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               ,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2014 YEAR TOTAL 49.57 227.38 1703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 2ND YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ  2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ  'ULOO&RPSOHWH/RFDWLRQ&

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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*Drillship 35,0(029(5!KSGLHVHO               See Attached Fuel 35,0(029(5!KSGLHVHO               history for comparison %851(5GLHVHO             rig Seadrill W Auriga $8;,/,$5<(48,3KSGLHVHO               sister rig to Seadrill 9(66(/6!KSGLHVHOFUHZ               West Neptune 9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2015 YEAR TOTAL 49.57 227.38 1703.84 51.12 371.75 8.52 39.08 292.83 8.79 63.89

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 3RD YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

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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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*Drillship 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               history for comparison %851(5GLHVHO             rig Seadrill W Auriga $8;,/,$5<(48,3KSGLHVHO               sister rig to Seadrill 9(66(/6!KSGLHVHOFUHZ               West Neptune 9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2016 YEAR TOTAL 49.57 227.38 1703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 4TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

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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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*Drillship 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               history for comparison %851(5GLHVHO             rig Seadrill W Auriga $8;,/,$5<(48,3KSGLHVHO               sister rig to Seadrill 9(66(/6!KSGLHVHOFUHZ               West Neptune 9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2017 YEAR TOTAL 49.57 227.38 1703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 5TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

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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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*Drillship 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               history for comparison %851(5GLHVHO             rig Seadrill W Auriga $8;,/,$5<(48,3KSGLHVHO               sister rig to Seadrill 9(66(/6!KSGLHVHOFUHZ               West Neptune 9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2018 YEAR TOTAL 49.57 227.38 1703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 5TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

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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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*Drillship 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               history for comparison %851(5GLHVHO             rig Seadrill W Auriga $8;,/,$5<(48,3KSGLHVHO               sister rig to Seadrill 9(66(/6!KSGLHVHOFUHZ               West Neptune 9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2019 YEAR TOTAL 49.57 227.38 1703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


EMISSIONS CALCULATIONS 5TH YEAR

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

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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

'5,//,1* 35,0(029(5!KSGLHVHO               

35,0(029(5!KSGLHVHO               

*Drillship 35,0(029(5!KSGLHVHO               

See Attached Fuel 35,0(029(5!KSGLHVHO               history for comparison %851(5GLHVHO             rig Seadrill W Auriga $8;,/,$5<(48,3KSGLHVHO               sister rig to Seadrill 9(66(/6!KSGLHVHOFUHZ               West Neptune 9(66(/6!KSGLHVHOVXSSO\               

9(66(/6!KSGLHVHOWXJV               

)$&,/,7< '(55,&.%$5*(GLHVHO               

,167$//$7,21 0$7(5,$/78*GLHVHO               

9(66(/6!KSGLHVHOFUHZ               

9(66(/6!KSGLHVHOVXSSO\               

MISC. BPD SCF/HR COUNT

7$1.      

'5,//,1* 2,/%851             

:(//7(67 *$6)/$5(             

2020 YEAR TOTAL 49.57 227.38 1703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1798.20 1798.20 1798.20 1798.20 48574.47


SUMMARY

FORM BOEM-0138 'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI

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Emitted Substance

Year

PM SOx NOx VOC CO

2014 17.96 82.41 617.53 18.53 134.73

2015 8.52 39.08 292.83 8.79 63.89

2016 17.96 82.41 617.53 18.53 134.73

2017 17.96 82.41 617.53 18.53 134.73

2018 17.96 82.41 617.53 18.53 134.73

2019 17.96 82.41 617.53 18.53 134.73

2020 17.96 82.41 617.53 18.53 134.73

2021 0.00 0.00 0.00 0.00 0.00

2022 0.00 0.00 0.00 0.00 0.00

2023 0.00 0.00 0.00 0.00 0.00

Allowable 1798.20 1798.20 1798.20 1798.20 48574.47




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APPENDIX H

Oil Spills Information 

(30 CFR Part 250.219 and 250.250)

A. Oil Spill Response Planning

The proposed activities in this Supplemental 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 its 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. 
 

 

D. Worst-Case Scenario Information

Category Regional OSRP Revised EP

Type of Activity Exploratory MODU Exploratory MODU

Facility Surface Location Mississippi Canyon Block 547 Mississippi Canyon Blocks 253 

& 208

Facility Description Well Location Well No. SS002 

(Location B)

Well No. 001 (Location B)

Distance to Nearest Shoreline

(Miles) 38.4 miles 54 miles

Volume:

 Storage Tanks (total)

 Facility Piping (total)

 Lease Term Pipeline

 Uncontrolled Blowout (day)

 Barging

Potential 24 Hour Volume 

(bbls) 225,144 bbls

 

190,525 bbls

Type of Liquid Hydrocarbon Crude Oil Crude Oil

API Gravity 28o 38.2o

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 Supplemental 

Exploration Plan for MC 253/208 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 Supplemental Exploration Plan. The 

WCD for the subject plan does not exceed the worst case discharge previously 

submitted for MC 547. 

The required proprietary data outlined in NTL 2010-N06 was submitted to BOEM 

with our Initial Exploration Plan (N-09560) approved on August 18, 2011. LLOG 

accepted the BOEM’s worst case discharge value of 190,525 bbls potential 24 

hour volume with a 38.2o API Gravity.

E. Oil Spill Response Discussion

See the following Oil Spill Response Discussion. 
SPILL RESPONSE DISCUSSION 

For the purpose of NEPA and Coastal Zone Mana gement Act analysis, the largest spill volum e 

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

estimated to be 190,525 barrels of crude oil with an API gravity of 38.2°. 

Land Segment and Resource Identification

Trajectories of a spill a nd the prob ability of it im pacting a land segm ent have bee n projected 

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

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

The BOEM OSRAM identif ies a 2 1% probability of impact to the sho relines of Plaquemines 

Parish, LA within 30 days. Plaquem ines Parish includes Barata ria Bay, the Mis sissippi 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 pa rticle 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 m ake every effort to resp ond to th e Worst Case 

Discharge as effectively as p racticable. A description of the re sponse equipment available to 

contain and recover the Worst Case Discharge is shown in Figure 2. 

Using the estim ated chemical and physical charact eristics of crude oil, an ADIOS weathering 

model was run on a similar product from the ADIOS oil database. The results indicate 25% or 

47,631 barrels of crude oil would be evaporated/dispersed within 24 hours, with 142,894 barrels 

remaining. 

Spill Response MC 253 Barrels of Oil 

WCD Volume 190,525 

Less 25% natural evaporation/dispersion 47,631 

Remaining volume 142,894 

Oil addressed by aerial dispersants 7,540 

Oil addressed by in-situ burning 7,144 

Figure 2 outlines equipment, personnel, materials and su pport vessels as well as tem porary 

storage equipment available to respond to a spill of 190,525 barrels. The list estimates individual 

times needed for procurem ent, load out, trav el time to the site and d eployment. Figure 2 also 

indicates how operations will be supported. 
If aerial dispersants are utilized , 8 sorties (9,600 gallons) from two of the DC-3 aircrafts and 4 

sorties (8,000 gallons) f rom the Bas ler aircraft should disperse approxim ately 7,540 barrels of 

product. 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 attem pted. Using 

estimates based on the Deepwater Horizon spill of 2010, up to 5% or 5,439 barrels of the W orst 

Case Discharge volume (remaining after natural weathering) could be burned. Slick containment 

boom would be i mmediately called out and on-s cene as soon as possible. Offshore response 

strategies may include a ttempting to skim utilizing the HOSS Barge, nine Fast Resp onse Units, 

two Aqua Guard Triton RBS ski mmers, and eleven sets of Koseq skimming arms, with a to tal 

derated skimming capacity of 318,609 barrels. Te mporary storage associated with skimm ing 

equipment equals 31,700 barrels. If additional storage is needed, an 80,000 barrel storage barge, 

an 83,937 barrel storage barge, an 86,948 barrel storage barge, and a 107,285 barrel storage 

barge may be m obilized and centr ally located to provide temporary storage a llowing 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 im pact in Plaquemines Parish, L ouisiana would depend 

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

near shore and shallow water skimm ers with a totaled derated sk imming capacity of 54,753 

barrels. Temporary storage asso ciated with skimm ing equipment equals 1,861 barrels. If 

additional storage is n eeded, an 86,948 barrel storage barge may be mobilized and centrall y 

located to provide tem porary storage allowing the sk immers to stay in the area of operations as 

much as possible. Onshore response m ay include the deployment of shoreline boom on beach 

areas, or protection and sorbent boom on vegetated areas. MSAs with AMPOL and Oil Mop will 

ensure the availability of 147,000 feet of 18” shoreline boom. Figure 2 outlines individual times 

needed for procurement, load out, travel tim e to the site and deploym ent. Strategies would be 

based upon surveillance and real tim e 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 prior itized to en sure 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 dam aging to fragile coastal ecosystem s if done in the open 

waters of the Gulf of M exico. Supervisory personnel have the option to modify the deployment 

and operation of equipm ent allowing a m ore effective response to site-specific circumstances. 

LLOG Exploration Offshore, L.L. C.’s contract Spill Man agement Team holds a copy of the 

State of Louisiana Initial Oil Spill Response Plan. 
Initial Response Considerations 

Actual actions taken during an oil spill response will be based on many factors to include but not 

be limited to: 

• Weather 

• Equipment and materials availability 

• Ocean currents and tides 

• Location of the spill 

• Product spilled 

• Amount spilled 

• Environmental risk assessments 

• Trajectory and product analysis 

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

LLOG Exploration Offshore, L.L.C. will take acti on to provide a safe, aggressive response to 

contain and recover as much of the spilled o il as quickly a s it is saf e to do so. In an ef fort 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. 

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

• Information will be confirmed 

• An assessment will be made and initial objectives set 

• OSROs and appropriate agencies will be notified 

• ICS 201, Initial Report Form completed 

• Initial Safety plan will be written and published 

• Unified Command will be established 

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

objectives 

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

site 

o On-site command and control established 

Offshore Response Actions 

Equipment Deployment

Surveillance 

• Surveillance Aircraft: within two hours of QI notification, or at first light

• Provide trained observer to provide on site status reports 

• Provide command and control platform at the site if needed 

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

and visual confirmation 

• Continual monitoring of vessel assets using vessel monitoring systems 
Dispersant application assets 

• Put ASI on standby 

• With the FOSC, conduct analysis to determine appropriateness of dispersant application 

• Gain FOSC approval for use of dispersants on the surface 

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

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

• Confirm dispersant availability for current and long range operations 

• Start ordering dispersant stocks required for expected operations 

Containment boom 

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

• Ensure boom handling and mooring equipment is deployed with boom 

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

their most effective containment 

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

Dedicated off-shore skimming systems 

General 

• Deployed to the highest concentration of oil 

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

CGA HOSS Barge 

• Use in areas with heaviest oil concentrations 

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

CGA FRUs 

• To the area of the thickest oil 

• Use as far off-shore as allowed 

T&T Koseq Skimming Systems 

• To the area of the thickest oil 

• Use as far off-shore as allowed 

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

Storage Vessels 

• Establish availability of CGA contracted assets 

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

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

systems 

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

• Use 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 

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 
Near Shore Response Actions 

Timing 

• Put near shore assets on standby and deployment in accordance with planning based on 

the actual situation, actual trajectories and oil budgets 

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

• Outfitting of VOOs for specific missions 

• Deployment of assets based on actual movement of oil 

Considerations 

• Water depth, vessel draft 

• Shoreline gradient 

• State of the oil 

• Use of VOOs 

• Distance of surf zone from shoreline 

Equipment Deployment 

Surveillance 

• Provide trained observer to direct skimming operations 

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

and visual confirmation 

• Continual monitoring of vessel assets 

Dispersant Use 

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

water depth 

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

Vessel Deployment 

Dedicated Near Shore skimming systems 

• FRVs 

• Egmopol and Marco 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 vessel are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS) 

• Acquire additional resources as needed 

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

• Expect mission specific and safety training to be required 

• Plan with the US Coast Guard for vessel inspections 

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

Response Planning Considerations 

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

• Time to acquire personnel and equipment and their availability 

• Previous contingency planning contained in the appropriate Area Contingency 

Plan, and currently (Feb 2011) for Louisiana, The State of Louisiana Initial Oil Spill 

Response Plan, Deep Water Horizon, dated 2 May 2010 (La. OSRP)

Actions 

Placement of boom 

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

appropriate ACP 

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

impact. Consider: 

o Trajectories 

o Weather forecast 

o Oil Impact forecast 

o Verified spill movement 

o Boom, manpower and vessel (shallow draft) availability 

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

Beach Preparation 

Considerations and Actions 

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

• Shoreline Cleanup and Assessment Team Reports and recommendations 

• Determination of Archeological sites and gaining authority to enter 

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

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

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

possible to maximize on-site work time 

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

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

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

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

and/or sweep obtained 

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

inland areas 
Decanting Strategy 

Recovered oil and wa ter mixtures will typic ally separate into d istinct phases when lef t in a 

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

decanted back to the recovery point with m inimal, if any, impact. Decan ting therefore increases 

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

will be req uested prior to decan ting operations. This practice is rou tinely used f or oil spill 

recovery. 

CGA Equipment Limitations 

The capability f or any spill respon se equipment, whether a dedica ted or portab le 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 opera tions ceased when seas reache d 5-6 feet and vessels were 

often recalled to port when those conditions w ere exceeded. Syste ms below are som e 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 wint er and easterly winds in th e summer. Average wind speed is 

generally 14-15 m ph along the coast. W ave 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 seas on is officially from 1 June to 30 Nove mber. 

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

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

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

categories 3, 4 and 5) hurricane days occurri ng then. Maxim um activity is in early to m id 

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

May or Decem ber. Globally, September is the mo st 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 Sp ill 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 

Mississippi Canyon 253 

Loc B 

54 miles from shore 

G24062 C57 Cameron Parish, LA 

Vermilion Parish, LA 

Terrebonne Parish, LA 

Lafourche Parish, LA 

Plaquemines Parish, LA 

St. Bernard Parish, LA 

Hancock & Harrison County, MS 

Jackson County, MS 

Mobile County, AL 

Baldwin County, AL 

Escambia County, FL 

Okaloosa County, FL 

Walton County, FL 

Bay County, FL 

1 

1 

2 

2 

21 

3 

1 

1 

1 

1 

1 

1 

1 

1 
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (54 miles from sh

190,525 bbls of crude oil API Gravity 38.2° 

FIGURE 2 – Equipment Response Time to MC 253 Loc B 

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

CGA 

Basler 67T 2000 NA 2 Houma 1 1 0.8 

ASI 

DC 3 1200 NA 2 Houma 1 1 1.0 DC 3 1200 NA 2 Houma 1 1 1.0 Aero Commander NA NA 2 Houma 1 1 0.8 

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 8 Harvey 4 0 5 

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 4 12 1 Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 4 12 1 Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 4 12 1 Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 4 12 1 

Recovered Oil Storage No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

K-Sea Operating (available through contract with CGA) 

PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 4 DBL 76 1212984 NA 83937 1 Tug 6 Venice 4 12 4 DBL 81 1132231 NA 86948 1 Tug 6 Venice 4 12 4 DBL 101 1119760 NA 107285 1 Tug 6 Venice 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 (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 8 FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 3 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 11 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 5.5 FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6 Venice 1 2 0 Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 8 

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging 

CGA 

42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 42” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 2 3 42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 1000’ Hydro-Fire Boom (In-Situ Burn) NA NA 8 Utility 40 Harvey 1 4 2 
Nearshore Response 

Nearshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

K-Sea Operating (available through contract with CGA) 

DBL 82 1137538 NA 86948 1 Tug 6 Venice 4 12 4 

CGA 

46’ FRV 5000 65 NA 4 Galveston 1 0 0 46’ FRV 5000 65 NA 4 Houma 1 0 2 46’ FRV 5000 65 NA 4 Lake Charles 1 0 1 46’ FRV 5000 65 NA 4 Venice 1 0 1 Trinity SWS 21500 249 NA 4 Morgan City 1 2 2 

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 T

De

CGA 

SWS Egmopol 3000 100 NA 3 Galveston 1 2 8 SWS Egmopol 3000 100 NA 3 Houma 1 2 3 SWS Marco 3588 34 NA 3 Houma 1 2 3 SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 Rope Mop 77 2 0 3 Belle Chasse 1 2 2 RO Storage Barge NA 249 Towed 0 Galveston 1 2 8 RO Storage Barge NA 249 Towed 0 Houma 1 2 3 RO Storage Barge NA 249 Towed 0 Lake Charles 1 2 5.5 RO Storage Barge NA 249 Towed 0 Venice 1 2 0 
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 

AMPOL (available through MSA) 

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 4 2 20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2 2 

Oil Mop (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 7.5 2 

10,000 18” Boom 4 Crew 10 Port Arthur, TX 1 1 6.25 2 20,000 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.75 2 10,000 18” Boom 4 Crew 10 Port Allen, LA 1 1 3.5 2 10,000 18” Boom 4 Crew 10 Houma, LA 1 1 3.5 2 15,000 18” Boom 6 Crew 14 Gretna, LA 2 2 2 2 

Beach Boom EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging T

De

CGA 

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 8 Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 11 Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 
Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging T

De

CGA 

Wildlife Support Trailer NA NA NA 2 Houma 1 2 3 Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 2 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 11 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 

Response Asset Total 

Offshore EDRC 318,609 Offshore Recovered Oil Storage 389,870 Nearshore / Shallow Water EDRC 54,753 Nearshore / Shallow Water Recovered Oil Storage 88,709 
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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 on Lease OCS-G-24062, Mississippi Canyon Block 253 a nd 

Stipulation No. 8 – Protected Species on Lease OCS-G-32303, Mississippi 

Canyon Block 208. Lease Stipulation Nos. 6 and 8 are 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 wells as subsea 

completions. T herefore, LLOG will follow the regulations in Title 30 

CFR Parts 250.288 t hrough 250.290, which mandates the submittal and 

approval of separate regulatory filings entitled a “Conservation 

Information Document” and a “Deepwater Operations Plan”, respectively.

 

• Breton Sound Area

Mississippi Canyon Blocks 208 and 253 are located within the 200 k m 

zone of the Breton National Wildlife Refuge, and will consider the use of 

best available control technology as required as Notice to Lessees 98-10 if 

the projected air emissions are determined to significantly affect the air 

quality of an onshore area. 

• Ocean Current Monitoring

The proposed operations under this Plan are in water depths greater than 

400 meters (1,312’); therefore, LLOG will follow the guidelines of the 

applicable NTL 2009-G02 by continuously monitoring and gathering 

ocean current data using Acoustic Doppler Current Profile (ADCP) while 

the MODU is on location. 


 

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. 

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” and Joint NTL No. 2012-G02, 

“Implementation of Seismic Survey Mitigation Measures and Protected Species 

Observer Program. 
 

APPENDIX L

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

 

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 1/Week Fourchon shorebase to 

MC253

 

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. 

E Vicinity Map

A Vicinity Plat showing the locations of Mississippi Canyon Block 208 and 253 

relative to the shoreline and onshore base is included as Attachment L. 

 
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The OCS related oil and gas development activities having potential impact on the Alabama 

Coastal Zone are based on the location of the proposed facilities, access to those sites, best 

practical techniques for operations and production equipment, guidelines for the prevention 

of adverse environmental effects, e ffective environmental protection, emer gency plans and 

contingency plans. Alab ama policies have be en addressed below or are cross referenced to 

the appropriate sections of the Plan: 

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Coastal Development Dock and port facilities in Louisiana will be used. There 

will be no new construction, dredging or filling in 

Alabama state waters. There will be no new commercial 

development or capital improvements in Alabama’s 

coastal zone, nor will there be any employment effects.

Mineral Resource Exploration 

and Extraction

Proposed exploration operations will take place 92

miles from Alabama’s coastline

Commercial Fishing Appendix H

Hazard Management Appendix C A Shallow Hazards Report was previously submitted to 

BOEM in order to identify and assess the seafloor and 

shallow geologic conditions in this block

Shoreline Erosion Appendix H Proposed exploration operations will take place 92

miles from Alabama’s coastline

Recreation Appendix H

Transportation Appendix B

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Biological Productivity Appendix H

Water Quality Appendix H

Water Resources Appendix H

Air Quality Appendix G

Wetlands and Submerged 

Grassbeds

Appendix H

Beach and Dune Protection Appendix H

Wildlife Habitat Protection Appendix H

Endangered Species Appendix H

Cultural Resources Protection Appendix D Archaeological survey was performed on Mississippi 

Canyon Blocks 253/208 and submitted to the BOEM 

under separate cover.
 

APPENDIX O

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 Tana 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 (4)

Water quality X X

Fisheries X X X

Marine mammals X (8) X X (8)

Sea turtles X (8) X X (8)

Air quality (9)

Shipwreck sites (known or 

potential)

(7)

Prehistoric archaeological sites (7)

Vicinity of Offshore Location

Essential fish habitat X (6)

Marine and pelagic birds X

Public health and safety (5)

Coastal and Onshore

Beaches (6)

Wetlands (6)

Shorebirds and coastal nesting 

birds

(6)

Coastal wildlife refuge

Wilderness areas
 

Footnotes for Environmental Impact Analysis Matrix: 

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

platform site or any anchors will be on the seafloor within the:

(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.
 

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 Supplemental 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, Regulation and Enforcement (BOEMRE) Notice 

to Lessees (NTL 2010-N06). Response 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. A dditional 

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 Blocks 208 

& 253 are located approximately 72 miles away from the closest 

designated topographic feature (Sackett 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.
 

• 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 disturbances within Mississippi Canyon Blocks 208 

& 253 are located a s ignificant 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.

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 disturbances within Mississippi Canyon Blocks 208 

& 253 are located a s ignificant 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 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 at the surface locations in Mississippi Canyon Blocks 208 & 

253 range from 4,100 feet to 5,200 feet. As noted in the shallow hazard assessment

it is unlikely that the identified anomalies represent the presence of 

high-density chemosynthetic or other benthic 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 

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 wale, 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). 

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 by BSEE in Notice to Lessees Joint (NTLs) 2012-G01 “Vessel 

Strike Avoidance and Injured/Dead Protective Species” and 2012-G01

“Marine Trash & Debris Awareness & Elimination”. T he 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 t he facility, 

and LLOG and the associated contractors obtain training on a t 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. 

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. As 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 BOEMRE in Notice to 

Lessees Joint (NTL) 2012-G01 “Vessel Strike Avoidance and 

Injured/Dead Protective Species” and “Marine Trash & Debris Awareness 

& Elimination”. 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 54 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. 
 

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. LLOG has requested BOEMRE approval to classify 

the proposed objective area as absent of hydrogen sulfide. 
 

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 48 m iles), 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 54 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 54 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.

• Coastal Wildlife Refuges 

As a r esult 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 54 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 54 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.
 

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

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. A dditionally, the surface located in Mississippi 

Canyon Blocks 208 & 253 ha s 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. 
 

H. Preparers

Questions or requests for additional information should be made to LLOG’s 

authorized representative of this Plan: 

Carol Eaton Nelda Runyon 

Regulatory Administrator Regulatory Specialist 

1001 Ochsner Boulevard, Suite 2000 1001 Ochsner Boulevard, Ste 2000 

Covington, Louisiana 70433 Covington, Louisiana 70433 

985-801-4300 (Phone) 985-801-4300 (Phone) 

Carole@llog.com Neldar@llog.com

 
 

I. References

The following documents were utilized in preparing the Environmental 

Impact Assessment:

Document Author Dated

Shallow Hazards Survey

3-D GeoHazard Assessment

C&C Technologies

Gardline Surveys, Inc.

2009

2009

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 2007-G02 “Implementation of seismic Survey 

Mitigation Measures and Protected Species Observer 

Program”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2007

NTL 2007-G03 “Marine Trash & Debris Awareness & 

Elimination”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2007

NTL 2007-G04 “Vessel Strike Avoidance and Injured/Dead 

Protective Species”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2007

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

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 2007

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2012

3D Geohazard Assessment Gardline Surveys, Inc. 2014
 

APPENDIX P

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 bottomhole 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

Shallow Hazards Survey

3-D GeoHazard Assessment

C&C Technologies

Gardline Surveys, Inc.

2009

2009

BOEMRE Environmental Impact Statement Report – No. 

2007-003

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2007

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2012

Initial Exploration Plan (N-9406) MC 253/208 LLOG Exploration Offshore, L.L.C. 2009

Revised Exploration Plan (R-5208) MC 253/208 LLOG Exploration Offshore, L.L.C. 2011

Revised Exploration Plan (R-5635) MC 253/208 LLOG Exploration Offshore, L.L.C. 2012

3D Geohazard Assessment Gardline Surveys, Inc. 2014