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 1 9, 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 S upport Vessels and Aircraft Information

APPENDIX M O nshore 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 Plan s (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 s emi s ubmersible rig. The proposed wells A

– E will be drilled and/or completed with a D P semisubmersible

or a drillship r ig at Mississippi Canyon Block s 208/253, OCS -G- 32303 and OCS

G- 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 w ill 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 att ached. The rig descriptions will be made part of the Application for

Permit to Drill.

Safety features on the drillship and the D P semisubmersible will include well control, pollution prevention, welding procedure, and blowout pr evention 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.,

a s 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. Storag e 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

Sto rage 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 1 6,685.5 No. 2 Diesel

- 43

Fuel Oil

Settle ing Tank 836.6 2 1,673.2 No. 2 Diesel

- 43 Fuel Oil Day

Tanks 836.6 2 1,673.2 No. 2 Diesel

- 43Type of Storage Tank Type of Facility Tank Capacity (bbls) Number of

tanks Total Capacity

(bbls) Fluid Gravity (API)

Fuel Oil (Marine Diesel) DP Semi

Submersible 164 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

No t applicable to this plan. The State of Florida is not an affected s t ate 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 (P ublic 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) Devel opment 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 deepwate r 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 Ot her (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) Diamet er (Inches) Length (Feet)



### Form BOEM- 0137 (December 2011 - Supersedes all previous editi ons of this form which may not be used.) Page 1 of 4OCS PLAN INFORMATION FORM ( CONTINUED ) Include one copy of this page for each proposed well/structure


### Proposed Well/Structure Location

Well or Structure Name/N umber (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 we ll or structure, list the Complex ID or API No.
Do you plan to use a subsea BOP or a surface BOP on a floa ting 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 mult iple 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 4OCS PLAN INFORMATION FORM ( CONTINUED ) Include one copy of this page for each proposed well/structure


### Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name): 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 /01/201 4 0 8 / 30 /201 4 60

Location “ H ”

– Complete 08/31/2014 10/05/2014 35

Location “B”

– Complete ** 01/01/2015 02/14/2015 4 5

Location “C

- Drill 01/01/201 6 03/02/201 6 60

Location “C”

- Complete 03/02/201 6 04/ 05 /201 6 35

Location “E”

- Drill 01/01/20 1 7 03/0 1 /2 01 7 60

Location “E”

- Complete 03/02/201 7 04/05 /201 7 35

Location “A”

- Drill 01/01/201 8 03/02/201 8 60

Location “A”

- Complete 03/02/201 8 04/05 /201 8 35

Location “D”

- Drill 01/01/201 9 03/0 2 /201 9 60

Location “D”

- Complete 03/0 2 / 201 9 04/05 /201 9 35

Loca tion “I”

- Drill 01/01/2 020 03/0 2 /20 20 60

Location “I”

- Complete 03/02/20 20 04/05 /20 20 3 5

*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 (P ublic Informat ion)

## "PUBLIC INFORMATION" LOCATION PLAT OCS-G-32303 BLOCK 253, MISSISSIPPI CANYON AREA

DATE: REVISED: JOB No:

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 
:

0 2000 2000

SCALE IN US SURVEY FEET 

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  88°19'0"W88°20'0"W88°21'0"W

28°45'0"N

28°44'0"N

28°43'0"N1,205,0001,210,0001,215,000 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 ,

0 0 0 f t R

a d i u s MISSISSIPPI CANYON BLOCK 253

OCS-G24062 MISSISSIPPI CANYON BLOCK 209

OCS-G24055

MISSISSIPPI CANYON BLOCK 297

OCS-G34434 3URSRVHG0&+ (DVWLQJIW( 1RUWKLQJIW1

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-4750

-4760 -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 Well1,190,0001,195,0001,200,0001,205,0001,210,0001,215,0001,220,000 10,420,000 10,425,000 10,430,000 10,435,000 10,440,000 10,445,000 10,450,00088°19'0"W88°20'0"W88°21'0"W88°22'0"W88°23'0"W88°24'0"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

Keathley Canyon Alaminos 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 2,000 4,000 6,000 1,000 Feet



### 0 500 1,000 1,500 250 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 2

0

00

M R a d i u

s Proposed MC208-H Well Location

with surface location in MC253 (1,204,436ft E, 10,434,880ft N) ®33 3

3

Proposed MC208-I Well Location

with surface location in MC253 (1,204,436ft E, 10,434,980ft N) ®33 3

3

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1 MARCH 19, 2014 FINAL REV 1 JR VC ARH

# APPENDIX B

G eneral Information
(30 CFR Part 250.213 and 250.243)

A. A pplications 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 b y 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 Table s 1 & 2 of Appendix F

Oil

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

- based (internal, olefin, ester) See Table s 1 & 2 of Appendix F



## C. Oil Character istics

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 act ivities 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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3XEOLF,QIRUPDWLRQBLOWOUT 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, informatio n 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 (s ee 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 overBLOWOUT 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 bl owout scenario is influenced by several factors including in-situ stress, rock strength and fluid veloci ties 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 blow out is based on some of the following equipment specific to potential MODU’s to be co ntracted 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 emer gency situation. This equipment includes:

• Secondary Acoustic BOP Control System – ty pically fitted on DP MODU’s presently operating in the GOM. This system has the ability to co mmunicate and function specific BOP controls

from the surface in the event of a failure of th e 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 pa ckage from a separate vessel of opportunity. This system may not be included on all MODU’s such as 4 th 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 requi rements, this equipment allows for an automated pre-programmed sequence of function s 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 supp ly 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 availableBLOWOUT 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 modificati ons 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 we ll, rig constraints and timing of rigs

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

event of a blowout scenario that does not involve lo ss or damage to the rig such as an inadvertent disconnect of the BOP’s, then the existing contract ed 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 shar e 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 pr obable 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 mo ored 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 utilizati on 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 re lief 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 timi ng / availability at the time the vessels are needed.

OPERATION SPECIF IC 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 Enterpri se (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 largel y 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 dr illing hazards or well specific conditions to safeguard the safety of the crews when well constr uction operations are underway. Once the design criteria and well design is established, the well desi gn 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 minimu m of 2 independent barriers for both internal and external flow paths in addition to proper pos itive and negative testing of the barriers.

The proper training of crew members and awarenes s 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 requirem ents 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 ri g 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 pot ential 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 to ols 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 engi neers, geologist and pore pressure engineers to maintain well control and reduced potential event s such as well control events and loss circulation

events.

Mud loggers continuously monitor return drilling flui ds, 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 sa fety 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 dem onstrate 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 Pe rmit to Drill. Equipment availability, backup equipment and adaptability to the potential scenarios will need to be addressed based on the initialBLOWOUT 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 moor ed 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 incl udes ~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 ESTIMAT E (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 c ontrol issues

• mobilize people and equipment (H elix 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 OPERATIONSBLOWOUT 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 operati ons, 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 144BLOWOUT SCENARIO

MC 208-253 Created by: S.L. Stegeman

Last Revised: 7/13/2011 Page 7 of 8

Confidential

7BLOWOUT SCENARIO

MC 208-253 Created by: S.L. Stegeman

Last Revised: 7/13/2011 Page 8 of 8

Confidential

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$WWDFKPHQW, 3XEOLF,QIRUPDWLRQLLOG Exploration Company Gardline Report 9988

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252

- 253 – P roposed 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 25 3

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 explorator y drilling operations within 2,0 00ft of the proposed well site

. The depth limit of this geohazard assessment

is 3.2 seconds TWT at -8 ,7 58 ft below sea surface ( 3, 839 ft below seabed).

This hazards summary letter is issued as a supplement to Gardline Report s No. 8025 entitled 3D
Geohazard Assessment, Gulf of Mexico, Mississippi Canyon, Blocks MC2 08 and 253, Volume 1

, May

2009, Volume 2, MC2 08

- 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

- C larke 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 – P roposed MC208

- H Well Location



### Seabed Hazards. The seabed pres ents 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 locat ion.

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 f ull

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 . Ap propriate drilling methodology to contain minor, non

- persistent shallow water flow event s

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 INFORMATIONLLOG Exp loration 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 25 3

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 explor ator y drilling operations within 2,0 00ft of the proposed well site

. The depth limit of this geohazard assessment

is 3.2 seconds Two Way Time at -8 ,7 62 ft below sea surface ( 3, 850 ft below seabed).

This hazards summary letter is issued as a supplement to Gardline Report s No. 8025 entitled 3D
Geohazard Assessment, Gulf of Mexico, Mississippi Canyon, Blocks MC208 and 253, Volume 1

, May

2009, Volume 2, MC2 08

- 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 Mississ ippi 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 Exp loration Company Gardline Report 9989

Well Clearance Letters – Mississippi Canyon Blocks 208 & 252

- 253 – Proposed MC208

- I Well Location



### Th ere 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 dr illing methodology to contain minor, non

- persistent shallow water flow

event s 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 S pecialist



# PUBLI C 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 Feature s 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 critica l 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 – P roposed MC208

- H Well Location



### Sensitive S ess ile B enthic Community Statement – MC208 -H



## LLOG Exploration Company

Fe bruary 21, 2014

US Department of the Interior
Bureau of Ocean Energy Management

1201 Elmwood Park Blvd.

New Orleans, LA 70213

Reference: Sensitive Sessile B enthic Community Summary
Mississippi Canyon, Block 253

OCS

- (G 24062 )

Ladies/Gentlemen:

Gardlin e 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 Socio

E conomic 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 C oordinates

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 Mis sissippi 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 – P roposed MC208

- H Well Location



### Potential **Sensitive Sessile B enthic**  **Communities.**

Features or areas that could support high

- density sensitive sessile benthic communities are **not** l ocated
within 2,000 feet of any proposed mud and cuttings discharge location.

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

expulsion site approximately 11,000 ft 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

T yp e of Waste Com p osition Pro j ected Amount Dischar g e rate Dischar g e Method Answer y es or no
Will drillin g occur ? If y es, fill in the muds and cuttin g s.

EXAMPLE: Cuttin g s wetted with s y nthetic based fluid Cuttings generated while using

s y nthetic based drillin g fluid. X bbl/well X bbl/da y /well dischar g e overboard No

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Is there a deck? If y es, there will be Deck Draina g e

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Will y ou conduct well treatment, com p letion, or workover?

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

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 -13 8) 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

I s 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 (w here 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 en counter 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 includi ng 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 emis sion 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 tha n 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 exempti on 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

- Exemp t 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 CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2014FORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYLLOGExplorationOffshore,L.L.C.AREAMississippiCanyonBLOCK253/208LEASEOCS-24062/32303PLATFORMN/AWELLWellLocationsH(Drill/Complete),B(Complete),C,E,A,D&I(Drill/CompleteCOMPANY CONTACTNeldaRunyonTELEPHONE NO.985-801-4300REMARKSDP Semi-Submersible Rig(Seadrill Sevan LA)EMISSIONS FACTORSFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRIFuel Usage Conversion Factors1DWXUDO*DV7XUELQHV 1DWXUDO*DV(QJLQHV 'LHVHO5HFLS(QJLQH 5()'$7(6&)KSKU  6&)KSKU  *$/KSKU $3 	Equipment/Emission FactorsXQLWV 30 62[ 12[ 92& &2 5() '$7(1*7XUELQHV JPVKSKU    $3	 1*F\FOHOHDQJPVKSKU   $3 1*F\FOHOHDQJPVKSKU   $3 1*F\FOHULFKJPVKSKU   $3 'LHVHO5HFLSKS JPVKSKU     $3 'LHVHO5HFLS!KSJPVKSKU     $3 'LHVHO%RLOHUOEVEEO     $3 1*+HDWHUV%RLOHUV%XUQHUV OEVPPVFI     3	1*)ODUHVOEVPPVFI   $3 /LTXLG)ODULQJOEVEEO     $3	 7DQN9DSRUVOEVEEO(	3)RUXP )XJLWLYHVOEVKUFRPS$3,6WXG\ *O\FRO'HK\GUDWRU9HQWOEVPPVFI/D'(4*DV9HQWLQJOEVVFISulphur Content Source Value Units)XHO*DV SSPDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightEMISSIONS CALCULATIONS 1ST YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKR0LVVLVVLSSL&DQ\RQ 2&61$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSO1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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 Semisubmersible35,0(029(5!KSGLHVHO              See Attached Fuel35,0(029(5!KSGLHVHO              records & rig specs%851(5GLHVHO           of comparison rig$8;,/,$5<(48,3KSGLHVHO              Seadrill Sevan Brazil9(66(/6!KSGLHVHOFUHZ              9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV               )$&,/,7< '(55,&.%$5*(GLHVHO               ,167$//$7,21 0$7(5,$/78*GLHVHO              9(66(/6!KSGLHVHOFUHZ             9(66(/6!KSGLHVHOVXSSO\              MISC.BPD SCF/HR COUNT7$1.  '5,//,1* 2,/%851           :(//7(67 *$6)/$5(          2014 YEAR TOTAL51.46 236.06 1768.82 53.06 385.92 16.55 75.94 569.06 17.07 124.16EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 2ND YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ 'ULOO&RPSOHWH/RFDWLRQ&OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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 Semisubmersible35,0(029(5!KSGLHVHO              See Attached Fuel35,0(029(5!KSGLHVHO              records & rig specs%851(5GLHVHO          of comparison rig$8;,/,$5<(48,3KSGLHVHO              Seadrill Sevan Brazil9(66(/6!KSGLHVHOFUHZ               9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV              )$&,/,7< '(55,&.%$5*(GLHVHO            ,167$//$7,21 0$7(5,$/78*GLHVHO           9(66(/6!KSGLHVHOFUHZ              9(66(/6!KSGLHVHOVXSSO\              MISC.BPD SCF/HR COUNT7$1. '5,//,1* 2,/%851          :(//7(67 *$6)/$5(         2015 YEAR TOTAL51.72 237.27 1777.9353.34 387.91 7.85 36.02 269.88 8.10 58.88EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 3RD YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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 Semisubmersible35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             records & rig specs%851(5GLHVHO          of comparison rig$8;,/,$5<(48,3KSGLHVHO             Seadrill Sevan Brazil9(66(/6!KSGLHVHOFUHZ              9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV             )$&,/,7< '(55,&.%$5*(GLHVHO            ,167$//$7,21 0$7(5,$/78*GLHVHO           9(66(/6!KSGLHVHOFUHZ             9(66(/6!KSGLHVHOVXSSO\             MISC.BPD SCF/HR COUNT7$1. '5,//,1* 2,/%851          :(//7(67 *$6)/$5(         2016 YEAR TOTAL51.72 237.27 1777.9353.34 387.91 16.55 75.94 569.06 17.07 124.16EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 4TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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 Semisubmersible35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             records & rig specs%851(5GLHVHO          of comparison rig$8;,/,$5<(48,3KSGLHVHO             Seadrill Sevan Brazil9(66(/6!KSGLHVHOFUHZ              9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV             )$&,/,7< '(55,&.%$5*(GLHVHO            ,167$//$7,21 0$7(5,$/78*GLHVHO           9(66(/6!KSGLHVHOFUHZ             9(66(/6!KSGLHVHOVXSSO\             MISC.BPD SCF/HR COUNT7$1. '5,//,1* 2,/%851          :(//7(67 *$6)/$5(         2017 YEAR TOTAL51.72 237.27 1777.9353.34 387.91 16.55 75.94 569.06 17.07 124.16EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 5TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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 Semisubmersible35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             records & rig specs%851(5GLHVHO          of comparison rig$8;,/,$5<(48,3KSGLHVHO             Seadrill Sevan Brazil9(66(/6!KSGLHVHOFUHZ              9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV             )$&,/,7< '(55,&.%$5*(GLHVHO            ,167$//$7,21 0$7(5,$/78*GLHVHO           9(66(/6!KSGLHVHOFUHZ             9(66(/6!KSGLHVHOVXSSO\             MISC.BPD SCF/HR COUNT7$1. '5,//,1* 2,/%851          :(//7(67 *$6)/$5(         2018 YEAR TOTAL51.72 237.27 1777.9353.34 387.91 16.55 75.94 569.06 17.07 124.16EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 5TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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 Semisubmersible35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             records & rig specs%851(5GLHVHO          of comparison rig$8;,/,$5<(48,3KSGLHVHO             Seadrill Sevan Brazil9(66(/6!KSGLHVHOFUHZ              9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV             )$&,/,7< '(55,&.%$5*(GLHVHO            ,167$//$7,21 0$7(5,$/78*GLHVHO           9(66(/6!KSGLHVHOFUHZ             9(66(/6!KSGLHVHOVXSSO\             MISC.BPD SCF/HR COUNT7$1. '5,//,1* 2,/%851          :(//7(67 *$6)/$5(         2019 YEAR TOTAL51.72 237.27 1777.9353.34 387.91 16.55 75.94 569.06 17.07 124.16EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 5TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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 Semisubmersible35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             records & rig specs%851(5GLHVHO          of comparison rig$8;,/,$5<(48,3KSGLHVHO             Seadrill Sevan Brazil9(66(/6!KSGLHVHOFUHZ              9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV             )$&,/,7< '(55,&.%$5*(GLHVHO            ,167$//$7,21 0$7(5,$/78*GLHVHO           9(66(/6!KSGLHVHOFUHZ             9(66(/6!KSGLHVHOVXSSO\             MISC.BPD SCF/HR COUNT7$1. '5,//,1* 2,/%851          :(//7(67 *$6)/$5(         2020 YEAR TOTAL51.72 237.27 1777.9353.34 387.91 16.55 75.94 569.06 17.07 124.16EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47SUMMARYFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI&203$1< $5($%/2&./($6(3/$7)250 :(////2*([SORUDWLR0LVVLVVLSSL&DQ\RQ 2&6 1$+%&($'	,EmittedSubstanceYearPMSOxNOxVOCCO2014 16.5575.94569.0617.07124.162015 7.8536.02269.888.1058.882016 16.5575.94569.0617.07124.162017 16.5575.94569.0617.07124.162018 16.5575.94569.0617.07124.162019 16.5575.94569.0617.07124.162020 16.5575.94569.0617.07124.162021 0.000.000.000.000.002022 0.000.000.000.000.002023 0.000.000.000.000.00Allowable1798.20 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 galEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2014FORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYLLOGExplorationOffshore,L.L.C.AREAMississippiCanyonBLOCK253/208LEASEOCS-24062/32303PLATFORMN/AWELLWellLocationsH(Drill/Complete),B(Complete),C,E,A,D&I(Drill/CompleteCOMPANY CONTACTNeldaRunyonTELEPHONE NO.985-801-4300REMARKSDrillship6HDGULOO:HVW1HSWXQHEMISSIONS FACTORSFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRIFuel Usage Conversion Factors1DWXUDO*DV7XUELQHV 1DWXUDO*DV(QJLQHV 'LHVHO5HFLS(QJLQH 5()'$7(6&)KSKU  6&)KSKU  *$/KSKU $3 	Equipment/Emission FactorsXQLWV 30 62[ 12[ 92& &2 5() '$7(1*7XUELQHV JPVKSKU    $3	 1*F\FOHOHDQJPVKSKU   $3 1*F\FOHOHDQJPVKSKU   $3 1*F\FOHULFKJPVKSKU   $3 'LHVHO5HFLSKS JPVKSKU     $3 'LHVHO5HFLS!KSJPVKSKU     $3 'LHVHO%RLOHUOEVEEO     $3 1*+HDWHUV%RLOHUV%XUQHUV OEVPPVFI     3	1*)ODUHVOEVPPVFI   $3 /LTXLG)ODULQJOEVEEO     $3	 7DQN9DSRUVOEVEEO(	3)RUXP )XJLWLYHVOEVKUFRPS$3,6WXG\ *O\FRO'HK\GUDWRU9HQWOEVPPVFI/D'(4*DV9HQWLQJOEVVFISulphur Content Source Value Units)XHO*DV SSPDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightEMISSIONS CALCULATIONS 1ST YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKR0LVVLVVLSSL&DQ\RQ 2&61$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSO1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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            *Drillship35,0(029(5!KSGLHVHO              See Attached Fuel35,0(029(5!KSGLHVHO              history for comparison%851(5GLHVHO           rig Seadrill W Auriga$8;,/,$5<(48,3KSGLHVHO              sister rig to Seadrill9(66(/6!KSGLHVHOFUHZ              West Neptune9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV               )$&,/,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)/$5(          2014 YEAR TOTAL49.57 227.38 1703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 2ND YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ 'ULOO&RPSOHWH/RFDWLRQ&OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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              *Drillship35,0(029(5!KSGLHVHO              See Attached Fuel35,0(029(5!KSGLHVHO              history for comparison%851(5GLHVHO          rig Seadrill W Auriga$8;,/,$5<(48,3KSGLHVHO              sister rig to Seadrill9(66(/6!KSGLHVHOFUHZ               West Neptune9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV             )$&,/,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)/$5(         2015 YEAR TOTAL49.57 227.38 1703.8451.12 371.75 8.52 39.08 292.83 8.79 63.89EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 3RD YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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             *Drillship35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             history for comparison%851(5GLHVHO          rig Seadrill W Auriga$8;,/,$5<(48,3KSGLHVHO             sister rig to Seadrill9(66(/6!KSGLHVHOFUHZ              West Neptune9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV            )$&,/,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)/$5(         2016 YEAR TOTAL49.57 227.381703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 4TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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             *Drillship35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             history for comparison%851(5GLHVHO          rig Seadrill W Auriga$8;,/,$5<(48,3KSGLHVHO             sister rig to Seadrill9(66(/6!KSGLHVHOFUHZ              West Neptune9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV            )$&,/,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)/$5(         2017 YEAR TOTAL49.57 227.381703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 5TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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             *Drillship35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             history for comparison%851(5GLHVHO          rig Seadrill W Auriga$8;,/,$5<(48,3KSGLHVHO             sister rig to Seadrill9(66(/6!KSGLHVHOFUHZ              West Neptune9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV            )$&,/,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)/$5(         2018 YEAR TOTAL49.57 227.381703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 5TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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             *Drillship35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             history for comparison%851(5GLHVHO          rig Seadrill W Auriga$8;,/,$5<(48,3KSGLHVHO             sister rig to Seadrill9(66(/6!KSGLHVHOFUHZ              West Neptune9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV            )$&,/,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)/$5(         2019 YEAR TOTAL49.57 227.381703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47EMISSIONS CALCULATIONS 5TH YEARFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRICOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKS//2*([SORUDWLRQ2IIVKRU0LVVLVVLSSL&DQ\RQ 2&6 1$ :HOO/RFDWLRQV+'ULOO&RPSOHWH%&RPSOHWH 1HOGD5XQ\RQ OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/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             *Drillship35,0(029(5!KSGLHVHO             See Attached Fuel35,0(029(5!KSGLHVHO             history for comparison%851(5GLHVHO          rig Seadrill W Auriga$8;,/,$5<(48,3KSGLHVHO             sister rig to Seadrill9(66(/6!KSGLHVHOFUHZ              West Neptune9(66(/6!KSGLHVHOVXSSO\              9(66(/6!KSGLHVHOWXJV            )$&,/,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(         2020 YEAR TOTAL49.57 227.381703.84 51.12 371.75 17.96 82.41 617.53 18.53 134.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1798.20 1798.20 1798.20 1798.20 48574.47SUMMARYFORM BOEM-0138'HFHPEHU6XSHUVHGHVDOOSUHYLRXVYHUVLRQVRIIRUP%2(0ZKLFKPD\QRWEHXVHG3DJHRI&203$1< $5($%/2&./($6(3/$7)250 :(////2*([SORUDWLR0LVVLVVLSSL&DQ\RQ 2&6 1$:HOO/RFDWLRQV+'ULOOEmittedSubstanceYearPMSOxNOxVOCCO2014 17.9682.41617.5318.53134.732015 8.5239.08292.838.7963.892016 17.9682.41617.5318.53134.732017 17.9682.41617.5318.53134.732018 17.9682.41617.5318.53134.732019 17.9682.41617.5318.53134.732020 17.9682.41617.5318.53134.732021 0.000.000.000.000.002022 0.000.000.000.000.002023 0.000.000.000.000.00Allowable1798.20 1798.20 1798.20 1798.20 48574.47

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# APPENDIX H Oil Spill s 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 LL OG (MMS O perator No. 02 0 58) 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 F ort 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 Cle an 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, ins pecting, 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 E P Type of Activity Exploratory MODU Exploratory MODU Facility Surface Location Mississippi Canyon Block 547 M ississippi Canyon Blocks 253

& 208 Facility Description Well Location Well No. SS002 (Location B) Well No. 001 (Location B )

Distance to Nea rest 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 .2 o



### 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 disch arge, 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 l owout 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, feed ing and nursery habitat for numerous species of

wildlife. Beaches in this area vary in grain pa rticle size, and can be clas sified 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 rac ticable. 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 ADIO S oil database. The results indicate 25% or 47,631 barrels of crude oil would be evaporated/dispersed with in 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 tw o 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 bur ned. 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 mpor ary 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 equipm ent 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 vegetate d 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 protect ion strategies depict the protecti on 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 necessa ry action to keep the oil spill from entering Louisiana’s coastal wetlands, based on the assumption that re moval 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 pers onnel have the option to modify the deployment and operation of equipm ent allowing a m ore eff ective 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 Initia l 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 agen cies 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 situa tion and coordinated objectives

o Areas of responsibility esta blished for Source Control a nd each surface operational

site

o On-site command and control established

Offshore Response Actions

Equipment Deployment

Surveillance

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

• Provide trained observer to pr ovide on site status reports

• Provide command and control platfo rm 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 m onitoring systems

### Dispersant application assets

• Put ASI on standby

• With the FOSC, conduct analysis to determin e 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, ai rcraft, and support equipment and personnel

• Confirm dispersant availability fo r current and long range operations

• Start ordering dispersa nt 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 aer ial 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 boa t 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 ski mmi ng 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 sa fety training to be required

• Plan with the US Coast Guard for vessel inspections

In-situ Burn assets

• Determine appropriateness of in-situ burn ope ration 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 deploym ent 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 Re sponse Team level (Region 6)

Vessel Deployment Dedicated Near Shore skimming systems

• FRVs

• Egmopol and Marco SWS

• Operate with aerial spotter directi ng systems to observed oil slicks

VOO

• Use LLOG Exploration Offshore, L.L.C.’s contracted resources as applicable

• Industry vessel are usually best for depl oyment 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 sa fety 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 eq uipment and their availability

• Previous contingency planning containe d in the appropriate Area Contingency Plan, and currently (Feb 2011) for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep Water Hori zon, 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 site s 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 respons e personnel as close to the job site as possible to maximize on-site work time

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

• Constant awareness of weather and oil moveme nt 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 se parate into d istinct phases when lef t in a quiescent state. W hen separati on occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with m inima l, if any, impact. Decan ting therefore increases the effective on-site oil storage c apacity a nd 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 rela tion 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 a nd/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 he ights 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 temperatur e 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 hurri cane 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 impac ting 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

1WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(54 miles from shore)190,525 bbls of crude oilAPI Gravity 38.2°FIGURE 2 – Equipment Response Time to MC 253 Loc BDispersant/SurveillanceDispersantCapacity (gal)StorageCapacityPersonsReq.From Hrs to ProcureHrs toLoadoutTravel tositeTotal HrsCGABasler 67T2000 NA 2 Houma11 0.82.8ASIDC 31200 NA 2 Houma11 1.03.0DC 31200 NA 2 Houma11 1.03.0Aero CommanderNA NA 2 Houma11 0.82.8Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge43000 4000 3 Tugs 8Harvey4 0 5 8.1 1 18.1T&T Marine (available through contract with CGA)Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 4 12 1 9.2 2 28.2Koseq Skimming Arms (2) 35658 4000 2 Utility 12Venice4 12 1 5.4 2 24.4Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 4 12 1 9.2 2 28.2Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 4 12 1 32.5 2 51.5Recovered Oil Storage NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsK-Sea Operating (available through contract with CGA)PACIFIC 996165NA 80000 1 Tug 6Venice4 12 4 8.13 1 29.13DBL 76 1212984NA 83937 1 Tug 6Venice4 12 4 8.13 1 29.13DBL 81 1132231NA 86948 1 Tug 6Venice4 12 4 8.13 1 29.13DBL 101 1119760NA 107285 1 Tug 6Venice4 12 4 8.13 1 29.13Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGAFRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2 5.4 1 11.4FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 8 5.4 1 17.4FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6Houma1 2 3 5.4 1 12.4FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 11 5.4 1 20.4FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 5.5 5.4 1 14.9FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6Venice1 2 0 5.4 1 9.4Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 8 5.4 2 31.4Offshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGA42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 5.4 1 11.442” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 5.4 1 17.442” Auto Boom (5000’) NA NA 10 Crew 20Houma1 2 3 5.4 1 12.442” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 5.4 1 20.442” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 5.4 1 14.942” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 5.4 1 13.41000’ Hydro-Fire Boom(In-Situ Burn)NA NA 8 Utility 40Harvey1 4 2 5.4 6 18.4Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsK-Sea Operating (available through contract with CGA)DBL 82 1137538NA 86948 1 Tug 6Venice4 12 4 6.25 1 27.25CGA46’ FRV5000 65 NA 4 Galveston 1 0 0 12.4 0 13.446’ FRV5000 65 NA 4Houma1 0 2 2.8 0 5.846’ FRV5000 65 NA 4 Lake Charles 1 0 1 9.2 0 11.246’ FRV5000 65 NA 4Venice1 0 12 0 4Trinity SWS21500 249 NA 4 Morgan City 1 2 2 4.8 1 10.8Staging Area: VeniceNearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGASWS Egmopol3000 100 NA 3 Galveston 1 2820 13SWS Egmopol3000 100 NA 3Houma1 2320 8SWS Marco3588 34 NA 3Houma1 2320 8SWS Marco3588 20 NA 3 Lake Charles 1 2 5.520 10.5Rope Mop77 2 0 3 Belle Chasse 1 2220 7RO Storage BargeNA 249 Towed 0 Galveston 1 2820 13RO Storage BargeNA 249 Towed 0Houma1 2320 8RO Storage BargeNA 249 Towed 0 Lake Charles 1 2 5.520 10.5RO Storage BargeNA 249 Towed 0Venice1 2020 5Shoreline ProtectionStaging Area: VeniceShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsAMPOL (available through MSA)42,000’ 18” Boom 16 Crew 40New Iberia, LA2 242122220,000’ 18” Boom 8 Crew 20New Orleans, LA2 222614Oil Mop (available through MSA)10,000’ 18” Boom 4 Crew 10New Iberia, LA1 14231110,000’ 18” Boom 4 Crew 10Houston, TX1 1 7.52314.510,000 18” Boom 4 Crew 10Port Arthur, TX1 1 6.252313.2520,000 18” Boom 8 Crew 20Belle Chasse, LA1 1 1.752611.7510,000 18” Boom 4 Crew 10Port Allen, LA1 1 3.52310.510,000 18” Boom 4 Crew 10Houma, LA1 1 3.52310.515,000 18” Boom 6 Crew 14Gretna, LA2 222412Beach BoomEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGABeach Boom (2000’)NA NA NA 6 Galveston 1 2812 14Beach Boom (1000’)NA NA NA 4 Ingleside 1 2 1112 17Beach Boom (2000’)NA NA NA 6 Pascagoula 1 2412 10Wildlife Response EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGAWildlife Support Trailer NA NA NA 2Houma1 2312 9Bird Scare Guns (24)NA NA NA 2 Belle Chasse 1 2212 8Bird Scare Guns (12)NA NA NA 2 Galveston 1 2812 14Bird Scare Guns (24)NA NA NA 2Houma1 2312 9Bird Scare Guns (12)NA NA NA 2 Ingleside 1 2 1112 17Bird Scare Guns (24)NA NA NA 2 Lake Charles 1 2 5.512 11.5Bird Scare Guns (24)NA NA NA 2 Pascagoula 1 2412 10Response AssetTotalOffshore EDRC318,609Offshore Recovered Oil Storage389,870Nearshore / Shallow Water EDRC54,753Nearshore / Shallow Water Recovered Oil Storage88,709 

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# APPENDIX J

LEASE STIPULATIONS/SPECIAL CONDITIONS

INFORMATION

(30 CFR PART 250.222 A ND 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,

marin e 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 heref ore, 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 e missions 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

a

pplicable NTL 2009

- G02 by continuously monitoring and gathering ocean current data using Acoustic Doppler Current Profile (ADCP) while

the MODU is on location.

# A PPENDIX K

ENVIRONMENTAL MITIGATION MEASURES

INFORMATION
(30 CFR Part 250.23 and 250.54)

A. Me asures 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, “Impleme ntation of Seismic Survey Mitigation Measures and Protected Species Observer Program

.

# APPENDIX L

S upport 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 Ri g: 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

Siz e 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 locatio ns 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 pr oposed facilities, access to those sites, best practical techniques for operati ons 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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5HIHUHQFH &RPPHQWV

&RDVWDO5HVRXUFH8VH3ROLFLHV 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

1DWXUDO5HVRXUFH3URWHFWLRQ

3ROLFLHV 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 dete rmined 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 l ive

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 (kno wn 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

Bea ches (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 E astern 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 activi ties 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 h aving 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 si gnificantly 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). Respons e 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

a ctions 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 preliminar y 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 a t 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 f eatures.

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

T here 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, LL OG 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 av oided 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 pote ntial 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

bot toms.

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 imm ediately 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

coul d 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 requirement s 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 w ill 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 bl owout, 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 emiss ions, 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 s ources. 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, ecologi cal 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 betwee n 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.

### L LOG 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 additio nal criteria addressed by BSEE in Notice to Lessees Joint (NTLs) 2012

- G01 “Vessel Strike Avoidance and Injured/Dead Protective Species” and 20 12- G01

“Marine Trash & Debris Awareness & Elimination”. T he proposed operations will be conducted in accordance with the regulations via

ma nifesting 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

recordk eeping 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 s tandards 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 o f 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 pr oduce 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

consump tion of this released material could seriously affect individual sea turtles. Most OCS related impacts on sea turtles are expected to be sub

lethal. 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 c riteria addressed by BOEMRE in Notice to

Lessees Joint (NTL ) 20 12- 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 per sonnel 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 a ssociated 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.

• Pr ehistoric 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

adverse ly 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 S pill 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 tha t 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

ac cidents 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

im plemented, 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 coastlin e 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

referen ced 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 ar e 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.

I n 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 counte rmeasures 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 respon se 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 c ontact 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

operat ions 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 Pla n. 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 wel l, 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

L LOG 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

p otential 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 “Archaeologica l 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 Managemen t, 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 Repor ts” 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 Coor dination 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 Enforcemen t 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 G ulf 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 Com munities” 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

Develo pment 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 GMG290 000 EPA

– Region VI 2007 Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 201 2

3D Geoh a zard Assessment Gardline Surveys, Inc. 2014

## APPENDIX P

ADMINISTRATIVE INFORMATION (30 CFR Part 250.228 and 250.262)

A. Exempted Information Descr iption (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 Unu sual 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

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