UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030) Plans Section, Office of Field Operations (MS 5231)

Public Information copy of Exploration Plan Control # - N-09504 Type - Initial Exploration Plan Lease(s) - OCS-G31521 Block - 705 Mississippi Canyon Area Operator - LLOG Exploration Offshore, L.L.C. Drill and complete well A

SEMISUBMERSIBLE

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.

James Webb Plan Coordinator Description - Rig Type - Subject: From: October 11, 2011

# LLOG EXPLORATION OFFSHORE, L.L.C. 1001 Ochsner Boulevard, Suite 200 Covington, Louisiana 70433



# INITIAL EXPLORATION PLAN (MODIFIED) N-9504
OCS-G-31521

MISSISSIPPI CANYON BLOCK 705

PREPARED BY:
Kathy Gowland Regulatory Specialist 985-801-4300 (Main) 985-801-4317 (Direct)

kathygo@llog.com

September, 2011Mississippi Canyon Block 705 (OCS-G 31521 Modified Exploration Plan (N-9504) 

## APPENDIX A PLAN CONTENTS (30 CFR Part 250.211 and 250.241)

A. Plan information In accordance with Notice to Lessees and Operators (NTL) No. 2010-N06, LLOG Exploration Offshore, LLC wishes to modify our previously submitted Initial Exploration Plan (N-9504), Mississippi Canyon Block 705, OCS-G-31521 Lease, which was submitted on February 25, 2010 and is pending approval.

Included as Attachment A is Form MMS 137 “OCS Plan Information Form”, which provides for the drilling, completion, and testing of Well Location #A.


## B. Location Included are the following attachments: Attachment B: Well Location Plat and Attachment C: Bathymetry Map detailing the proposed surface location disturbance area with the proposed anchor radius of the drilling rig. 

## C. Safety & Pollution Prevention Features Safety features on the semi-submersible will include well control, pollution prevention, welding procedure, and blowout prevention equipment as described in Title 30 CFR Part 250, Subparts C, D, E, G & O; and as further clarified by Notices to Lessees, U.S. Environmental Protection Agency and the U. S. Coast Guard. The appropriate life rafts, life jackets, ring buoys, etc., as prescribed by the U. S. Coast Guard will be maintained on the facility at all time.

D. 

## Storage Tanks and Vessels The following table details the storage tanks and/or production vessels that will store oil (capacity greater than 25 bbls. or more) and be used to support the proposed activities (MODU, barges, platforms, etc.): Type of Storage Tank Type of Facility Tank Capacity

(bbls) Number of tanks Total Capacity

(bbls) Fluid Gravity (API)

Fuel Oil (Marine Diesel) SemiSubmersible 95.24 2 190.5 No. 2 Diesel

2917.8 4 11,671.2 Total 11,861.7



## E. Additional Measures LLOG does not propose any additional safety, pollution prevention, or early spill detection measures beyond those required by 30 CFR Part 250.

### U.S. Department of the Interior OMB Control Number: 1010-0151 Minerals Management Service OMB Approval Expires: 12/31/2011 

### OCS PLAN INFORMATION FORM General Information Type of OCS Plan: Exploration Plan (EP) Development Operations Coordination Document (DOCD) Company Name: MMS Operator Number:
Address: Contact Person:
Phone Number:
E-Mail Address: Lease(s): Area: Block(s): Project Name (If Applicable): Objective(s): Oil Gas Sulphur Salt Onshore Base: Distance to Closest Land (Miles): 

### Description of Proposed Activities (Mark all that apply) Exploration drilling Development drilling Well completion Installation of production platform Well test flaring (for more than 48 hours) Installation of production facilities Installation of caisson or platform as well protection structure Installation of satellite structure Installation of subsea wellheads and/or manifolds Commence production Installation of lease term pipelines Other (Specify and describe) Have you submitted or do you plan to submit a Conservation Information Document to accompany this plan? Yes No Do you propose to use new or unusual technology to conduct your activities? Yes No Do you propose any facility that will serve as a host facility for deepwater subsea development? Yes No Do you propose any activities that may disturb an MMS-designated high-probability archaeological area? Yes No Have all of the surface locations of your proposed activities been previously reviewed and approved by MMS? Yes No 

### Tentative Schedule of Proposed Activities Proposed Activity Start Date End Date No. of Days



### Description of Drilling Rig Description of Production Platform Jackup Drillship Caisson Tension leg platform Gorilla Jackup Platform rig Well protector Compliant tower Semisubmersible Submersible Fixed platform Guyed tower DP Semisubmersible Other (Attach Description) Subsea manifold Floating production system Drilling Rig Name (If Known): Spar Other (Attach Description) 

### Description of Lease Term Pipelines From (Facility/Area/Block) To (Facility/Area/Block) Diameter (Inches) Length (Feet)



### M M S FORM MMS-137 (December 2008

- Supersedes all previous editions of form MMS-137 which may not be used.) Page 1 of 2 X LLOG Exploration Offshore, L.L.C. 02058 1001 Ochsner Boulevard, Suite 200 Covington, Louisiana 70433 Kathy Gowland 985-801-4300 kathygo@llog.com
OCS-G-31521 MC 705 Biddy Ball X Fourchon, LA 53

X
X

X

X X X X X

DRILL AND COMPLETE WELL LOCATION A 11/01/2011 12/30/2011 60

X

### 2

OCS PLAN INFORMATION FORM ( CONTINUED ) Include one copy of this page for each proposed well/structure 

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

Anchor Radius (if applicable) in feet: Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS OCS

Area Name

Block No.

Blockline Departures (in feet) N/S Departure: F____ L N/S Departure: F____ L

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

Lambert X-Y coordinates X: X:

Y: Y:

Latitude/ Longitude Latitude Latitude
Longitude Longitude TVD (Feet): MD (Feet): Water Depth (Feet): 

### Anchor Locations for Drilling Rig or Construction Barge ( If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor
X = Y =
X = Y =
X = Y =
X = Y =
X = Y =
X = Y =
X = Y =
X = Y = Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35) requires us to inform you that MMS collects this in formation as part of an applicant’s Expl oration Plan or Development Operations Coordination Document submitted for MMS approval. We us e the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 250.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an accompanying EP (1,000 hours in AKOCSR), or 690 (1,700 in AKOCSR) with an accompanying DPP or DOCD, including the time for reviewing instructions, gathering and mainta ining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other as pect of this form to the Information Collection Clearance Officer, Mail Stop 5438, Minerals Management Se rvice, 1849 C Street, NW., Washington, DC 20240.



### M M S FORM MMS-137 (December 2008

- Supersedes all previous editions of form MMS-137 which may not be used.) Page 2 of 2 WELL LOCATION A
8,000' X



### G-31521 MISSISSIPPI CANYON 705



### 1926' FNL
3013' FWL

699,973 10,262,394
28° 14' 53.483"



### 89° 55' 16.843"
850'

## APPENDIX B GENERAL INFORMATION (30 CFR Part 250.213 and 250.243)

A. Applications and Permits
There are no Federal/State applications to be submitted for the activities provided for in this Plan (exclusive to BOEMRE permit applications and general permits issued by the EPA and COE)
Application/Permit Issuing Agency Status N/A



## B. Drilling Fluids
Type of Drilling Fluid Estimated Volume of Drilling Fluid to be used per Well Water Based (seawater, freshwater, barite) 18,263 bbls/well Oil –based (diesel, mineral oil) N/A Synthetic-based (internal olefin, ester) 6,750 bbls/well 

## C. New Or Unusual Technology
LLOG does not propose using any new and/or unusual technology for the operations proposed this Revised Plan. 

## D. Bonding Statement
The bond requirements for the activities and facilities proposed in this Revised EP are satisfied by an area wide bond, furnished and maintained according to 30 CFR Part 256; subpart I; NTL No. 2006-G16, “Guidelines for General Lease Surety Bonds,” and additional security under 30 CFR 256.43(d) and National NTL No. 2003-N06 “Supplemental Bonding Procedures.” 

## E. Oil Spill Responsibility (OSFR)
LLOG Exploration Offshore, L.L.C (MMS Co. No. 02058) will demonstrate oil spill financial responsibility for the facilities proposed in this Revised EP according to 30 CFR Part 253, and NTL 99-N01, “Guidelines for Oil Spill Financial Responsibility for Covered Facilities.”

## F. Deepwater Well Control Statement
LLOG Exploration Offshore, L.L.C. (MMS Co. No. 02058) has the financial capability to drill a relief well and conduct other emergency well control operations.


## G. Blowout Scenario
See the following Blowout Scenario including Site Specific Proposed Relief Well and Intervention Planning and Relief Well Response Time Estimate.BLOWOUT SCENARIO MC 705 OCS-G-31521 Created by: S.L. Stegeman Last Revised: 8/9/2011 Page 1 of 6 Confidential

1 BLOWOUT SCENARIO Pursuant with 30 CFR 250.213(g), 250.219, 250,250 and NTL 2010-N06 the following attachment provides a blowout scenario descripti on, information regarding any oil spill, WCD results and assumptions of potential spill and additional measures taken to firstly enhance the ability to prevent a blowout and secondly to manage a blowout scenario if it occurred.
INFORMATION REQUIREMENTS

PROPOSED PROSPECT INFORMATION

Well Surface Location WD X (NAD 27) Y (NAD 27) Latitude Longitude MC 705 OCS-G-31521 864 699,973’ 10,262,394’ 28 q 14’ 53.483” 89 q 55’ 16.843”
INFORMATION REQUIREMENTS A) Blowout scenario The MC 705 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 / Completion Ops Facility Location (area / block) MC 705 Facility Designation MODU Distance to Nearest Shoreline (miles) ~53 Uncontrolled Blowout (Volume per day) 123,200 bbls Type of Fluid Gas and Condensate
C) Total volume and maximum duration of the potential blowout

Duration of Flow (days) 99 days total (see Relief Well Response Estimate below) Total Volume of Spill (bbls) 12.2 MMBO based on 99 days of uncontrolled flow
D) Assumptions and calculations used in determining the worst case discharge Omitted from Public Information Copies E) Potential for the well to bridge over Mechanical failure/collapse of the borehole in a blowout scenario is influenced by several factors including in-situ stress, rock strength and fluid velocities at the sand face. Given the substantial fluid 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 aBLOWOUT SCENARIO MC 705 OCS-G-31521 Created by: S.L. Stegeman Last Revised: 8/9/2011 Page 2 of 6 Confidential

2 span of a few days, significantly reducing the outflow of the rates. For this blowout scenario, no bridging is considered. F) Likelihood for intervention to stop blowout The likelihood of surface intervention to stop a blowout is based on some of the following equipment specific to potential MODU’s to be contracted for this well. It is reasonable to assume that the sooner you are able to respond to the initial blowout, the better likelihood there is to control and contain the event due to reduced pressures at the wellhead, less exposure of well fluids to erode and compromise the well control equipment, and less exposure of hydrocarbons to the surface to safeguard personnel and equipment in an emergency situation. This equipment includes:

x Secondary Acoustic BOP Control System – typically fitted on DP MODU’s presently operating in the GOM. This system has the ability to communicate and function specific BOP controls from the surface in the event of a failure of the primary umbilical control system. This system typically can establish BOP controls from the su rface acoustic system package on the rig or by deploying a second acoustic package from a separate vessel of opportunity. This system may not be included on all MODU’s such as 4 th generation moored rigs. This system is typically configured to function the following:

- Blind/shear ram close - Pipe ram close - LMRP disconnect

x 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

x Deadman / Autoshear function – typically fitted on DP MODU’s and but to be on all MODU’s operating in the GOM according to new requirements, this equipment allows for an automated pre-programmed sequence of functions to close the casing shear rams and the blind/shear rams in the event of an inadvertent or emergency disconnect of the LMRP or loss of both hydraulic and electrical supply from the surface control system. In the event that the intervention systems for the subsea BOP’s fail, LLOG will initiate call out of a secondary containment / surface intervention system supported by the Helix Well Containment Group (HWCG) of which LLOG is a member. This system incorporates a capping stack capable of being deployed from the back of a vessel of opportunity equipped with an ROV or from the Helix Q4000 DP MODU. Based on the potential integrity concerns of the well, a “cap and flow” system can be deployed which may include the Helix Producer 1 capable of handling up to 55,000 BOPD flowback. The vertical intervention work is contingent upon the condition of the blowing out well and what equipment is intact to access the wellbore for kill or containment operations. The available intervention equipment may also require modifications based on actual wellbore conditions. Standard 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.BLOWOUT SCENARIO MC 705 OCS-G-31521 Created by: S.L. Stegeman Last Revised: 8/9/2011 Page 3 of 6 Confidential

3 G) Availability of rig to drill relief well, rig constraints and timing of rigs LLOG currently has one deepwater MODU under contract (Noble Amos Runner moored semi). In the event of a blowout scenario that does not involve loss or damage to the rig such as an inadvertent disconnect of the BOP’s, then the existing contracted rig may be available for drilling the relief well and vertical intervention work. If the blowout scena rio involves damage to the rig or loss of the BOP’s and riser, a replacement rig or rigs will be required. With the current activity level in the GOM, 25 to 35 deepwater MODU’S are potentially available to support the relief well drilling operations. Rig share and resource sharing agreements are in place between members of the Helix Well Containment Group. The ability to negotiate and contract an appropriate rig or rigs to drill relief wells is highly probable in a short period of time. If the rig or rigs are operating, the time to properly secure the well and mobe the rig to the relief well site location is estimated to be about 14 to 21 days. Dynamically positioned (DP) MODU’s would be the preferred option due to the logistical advantage versus a moored MODU which may add complications due to the mooring spread.

VESSELS OF OPPORTUNITY Based on the water depth restrictions for the proposed locations the following “Vessels of Opportunity” are presently available for utilization for intervention and containment and relief well operations. These may include service vessels and drilling rigs capable of working in the potential water depths and may include moored vessels and dynamically positioned vessels. The specific conditions of the intervention or relief well operations will dictate the “best fit” vessel to efficiently perform the desired results based on the blowout scenario. The list included below illustrates specific option that may vary according to the actual timing / availability at the time the vessels are needed.

OPERATION SPECIFIC VESSEL OF OPPORTUNITY Intervention and Containment x Helix Q4000 (DP Semi)

x Helix Producer 1 (DP FPU) Relief Well Drilling Rigs x Diamond Ocean Victory (Moored Semi)

x Ensco 8502 (DP Semi)

x Transocean Enterprise (DP Drillship) ROV / Multi-Purpose Service Vessels x Oceaneering (numerous DP ROV vessels)

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

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

x Other ROV Vessels – (Chouest, HOS, Fugro, Subsea 7) Shuttle Tanker / Barge Support x OSG Ship Management

H) Measures taken to enhance ability to prevent blowout / reduce likelihood of blowout Pursuant to BOEM-2010-034 Final Interim Rules, measures to enhance the ability to prevent or reduce the likelihood of a blowout are largely based on proper planning and communication, identification of potential hazards, training and experience of personnel, use of good oil field practices and proper equipment that is properly maintained and inspected for executing drilling operations of the proposed well or wells to be drilled. When planning and designing the well, ample time is spent analyzing offset data, performing any needed earth modeling and identifying any potential drilling hazards or well specific conditions to safeguard the safety of the crews when well construc tion operations are underw ay. Once the designBLOWOUT SCENARIO MC 705 OCS-G-31521 Created by: S.L. Stegeman Last Revised: 8/9/2011 Page 4 of 6 Confidential

4 criteria and well design is established, the well design is modeled for the lifecycle of the wellbore to ensure potential failure modes are eliminated. Pursuant to BOEM-2010-0034 Interim Final Rules implemented additional considerations of a minimum of 2 independent barriers for both internal and external flow paths in addition to proper positive and negative testing of the barriers. The proper training of crew members and awareness to identify and handle well control event is the best way prevent a blowout incident. Contractor’s personnel and service personnel training requirements are verified per regulatory requirements per guidelines issued in BOEM-2010-034 Interim Final Rules. Drills are performed frequently to verify crew training and improve reaction times. Good communication between rig personnel, office support personnel is critical to the success of the operations. Pre-spud meetings are conducted with rig crews and service providers to discuss, inform and as needed improve operations and well plans for safety and efficiency considerations. Daily meetings are conducted to discuss planning and potential hazards to ensure state of preparedness and behavior is enforced to create an informed and safe culture for the operations. Any changes in the planning and initial wellbore design is incorporated and communicated in a Management of Change (MOC) process to ensure continuity for all personnel. Use of established good oil field practices that safeguard crews and equipment are integrated to incorporate LLOG’s, the contractor and service provider policies.
Additional personnel and equipment will be used as needed to elevate awareness and provide real time monitoring of well conditions while drilling such as MWD/LWD/PWD tools used in the bottom hole assemblies. The tool configuration for each open hole section varies to optimize information gathered including the use of Formation-Pressure-While-Drilling (FPWD) tools to establish real time formation pressures and to be used to calibrates pore pressure models while drilling. Log information and pressure data is used by the drilling engineers, geologist and pore pressure engineers to maintain well control and reduced potential events such as well control events and loss circulation events. Mud loggers continuously monitor return drilling fluids, drill gas levels and cuttings as well as surface mud volumes and flow rates, rate of penetration and lithology/paleo to aid in understanding trends and geology being drilled. Remote monitoring of real time drilling parameters and evaluation of geologic markers and pore pressure indicators is used to identify potential well condition changes. Proper equipment maintenance and inspection program for same to before the equipment is required. Programmed equipment inspections and maintenance will be performed to ensure the equipment operability and condition. Operations will cease as needed in order to ensure equipment and well conditions are maintained and controlled for the safety of personnel, rig and subsurface equipment and the environment. I) Measures to conduct effective and early intervention in the event of a blowout In conjunction with the LLOG Exploration’s “Well Control Emergency Response Plan” and as required by NTL 2010-N06, the following is provided to demonstrate the potential time needed for performing secondary intervention and drilling of a relief well to handle potential worst case discharge for the proposed prospect. Specific plans are integrated into the Helix Well Containment Groups procures to be approved and submitted with the Application for Permit to Drill. Equipment availability, backup equipment and adaptability to the potential scenarios will need to be addressed based on the initial 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).BLOWOUT SCENARIO MC 705 OCS-G-31521 Created by: S.L. Stegeman Last Revised: 8/9/2011 Page 5 of 6 Confidential

5 SITE SPECIFIC PROPOSED RELIEF WELL AND INTERVENTION PLANNING No platform was considered for drilling relief wells for this location due to location, water depth and lack of appropriate platform within the area. For this reason a moored or DP MODU will be preferred / required. In the event the well can be contained, produced fluid can be plumbed into the production manifold within 200’ of the planned surface location. A LLOG pipeline is an abandoned 10” POGO Production pipeline that runs in close proximity and is presently planned to be used for the initial completion tie-in. A relief well site has been initially identified to address blowout scenarios for the potential geologic targets for the proposed wells. One relief well surface locations is proposed for the proposed exploration plan well. Due to shipping fairway restrictions, the proposed relief well location(s) is dependent on governmental agency approvals. A 1000’ bathometry limit is planned to accommodate the use of DP MODUs which typically need 1000’ water depths to operate in a very tight watch circle. Based on actual seafloor state unforeseen at this time, the final location(s) may need to be revised. The location has 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 705 OCS-G-31521 MC 705 R1 699,973’ 10,256,748’

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

RELIEF WELL RESPONSE TIME ESTIMATE

OPERATION TIME ESTIMATE (DAYS) IMMEDIATE RESPONSE

x safeguard personnel, render first-aid

x make initial notifications

x implement short term intervention (if possible)

x implement spill control

x develop Initial Action Plan 1

INTERIM REPSONSE

x establish Onsite Command Center and Emergency Management Team

x assess well control issues

x mobilize people and equipment (Helix DW Containment System)

x implement short term intervention and containment (if possible)

x develop Intervention Plan

x initiate relief well planning, negotiate, acquire rig(s) – 4 days

x continue spill control measures 4

INTERVENTION AND CONTAIMENT OPERATIONS

x mobilize equipment and initiate intervention and containment operations

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

x secure rig operations (10 days) , prep and mobe to location (4 days)

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

x continue spill control measures 14

RELIEF WELL(S) OPERATIONS

x continue intervention and containment measures

x continue spill control measures 60BLOWOUT SCENARIO MC 705 OCS-G-31521 Created by: S.L. Stegeman Last Revised: 8/9/2011 Page 6 of 6 Confidential

6 x drill relief well(s), ranging operations to intersect wellbore

PERFORM HYDRAULIC KILL OPERATIONS / SECURE BLOWNOUT WELL

x continue intervention and containment measures

x continue spill control measures

x perform hydraulic kill operations, monitor well, secure well 20

ESTIMATED TOTAL DAYS OF UNCONTROLLED FLOW 99 SECURE RELIELF WELL(S) / PERFORM P&A / TA OPERATIONS / DEMOBE 30 TOTAL DAYS 129

.

## APPENDIX F WASTE AND DISCHARGE INFORMATION (30 CFR PART 250.217 AND 250.248)

A. Projected Generated Wastes
See the following tables:
TABLE 1. Wastes you will generate, treat and downhole dispose or discharge to the GOM
TABLE 2. Wastes you will transport and /or dispose of onshore



## B. Modeling
Not applicable. Proposed activities will be covered by U.S. EPA NPDES General Permit.please specify if the amount reported is a total or per well amount


## MC Block 705

Type of Waste Composition Projected Amount T
o Discharge rate Discharge Method Answer yes or no Will drilling occur ? If yes, you should list muds and cuttings
EXAMPLE: Cuttings wetted with synthetic based fluid Cuttings generated while using synthetic based drilling fluid. X bbl/well X bbl/day/well discharge overboard No

Water-based drilling fluid Water based mud additives, barite and gel used for WBM 18,263 bbls/well 7,309 bbls/day/well Discharge overboard No

Cuttings wetted with water-based fluid Cuttings generated while using water based drilling fluid. 1,003 bbls/well 401 bbls/day/well Discharge overboard No
Cuttings wetted with synthetic-based fluid Cuttings generated while using synthetic based drilling fluid. 1,732 bbls/well 50 bbls/day/well Discharge overboard No Will humans be there? If yes, expect conventional waste
EXAMPLE: Sanitary waste water Sanitary waste from living quarters X bbl/well X bbl/hr/well discharge overboard No

Domestic waste Kitchen water and unprocessed water not

used for sanitation 3,846 bbls/well 2.7 bbls/hr/well Discharge overboard (no free oil) No

Sanitary waste Processed sanitary waste from living quarters 2,564 bbls/well 1.8 bbls/hr/well Chlorinate and discharge overboard No Is there a deck? If yes, there will be Deck Drainage

Deck Drainage Accumulated drainage due to rainfall 0 to 47,261 bbls/well 0 to 167 bbls/hr/well Test for oil and grease and discharge overboard No Will you conduct well treatment, completion, or workover?

Well treatment fluids NPDES approved treatment fluid used for well operations 100 bbls/well 20 bbls/hr/well Test for oil and grease and discharge overboard. No

Well completion fluids Clear brines used for completion operations 500 bbls/well 100 bbls/hr/well Test for oil and grease and discharge overboard. This excludes clear brines containing Zinc No Workover fluids N/ A N/ A N A N A No Miscellaneous discharges. If yes, only fill in those associated with your activity. Desalinization unit discharge N/A N/A N/A N/A No
Blowout prevent fluid N/A N/A N/A N/A No

Ballast water Uncontaminated seawater used for

ballast control 0 to 100,000 bbls/well 16,350 bbls/hr/well Discharge overboard No Bilge water N/A N/A N/A N/A No

Excess cement at seafloor Excess cement slurry and mixwater used for cementing operation -

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

Fire water Uncontaminated seawater used for fire control system 0 to 10,000 bbls/well 16,350 bbls/hr/well Discharge overboard No Cooling water N/A N/A N/A N/A No
Will you produce hydrocarbons? If yes fill in for produced water. Produced water NA NA NA NA No
Will you be covered by an individual or general NPDES permit ? NOTE: If you will not have a type of waste, enter NA in the row. General NPDES Permit #GMG290000 Projected Downhole Disposal Projected ocean discharges Projected generated waste TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE IN THE GOMplease specify whether the amount reported is a total or per wellMC Block 705Projected generatedwasteSolid and LiquidWastes transportationType of Waste Composition Transport Method Name/Location of Facility AmountDisposalMethodWill drilling occur ? If yes, fill in the muds and cuttings.EXAMPLE: Synthetic-based drilling fluid ormud internal olefin, esterBelow deck storage tanks onoffshore support vesselsNewport EnvironmentalServices Inc., Ingleside, TX X bbl/well RecycledOil-based drilling fluid or mudN/ANAN/ANA NASynthetic-based drilling fluid or mudInternal olifin, ester nbased mudBarged in 25 bbls cutting boxes and/ or liquid mud tanks for supplyvesselsNewpark Transfer Station,Fourchon, LA6750 bbls /well RecycledCuttings wetted with Water-based fluidN/ANAN/ANA NACuttings wetted with Synthetic-based fluidN/ANAN/ANA NACuttings wetted with oil-based fluidsN/ANAN/ANA NAWill you produce hydrocarbons? If yes fill in for produced sand.Produced sandN/A N/A N/A N/A N/AEXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage bin ARC, New Iberia, LA X lb/well RecycledTrash and debrisPlastic, paper, aluminum Barged in a storage binBlanchard Landfill, GoldenMeadows, LA 4000 lbs / wellRecycled andland fillUsed oilSpent oil from machineryBarged in USCG approved transfertote tanks. L&L Services, Fourchon, LA 200 bbls / well RecycledWash waterWash water w/ SBM residueand surfactantsBarged in 25 bbls cutting boxes and/ or liquid mud tanks for supplyvesselsNewpark Transfer Station,Fourchon, LA2000 bbls /wellApproveddisposal wellinjection or landfarmChemical product wastesSpent treatment and / ordamaged chemicals used inoperationsBarged in 25 bbls cutting boxes and/ or cutting boxes L&L Services, Fourchon, LA 10 bbls / well RecycledNOTE: If you will not have a type of waste, enter NA in the rowTABLE 2. WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHOREWaste DisposalWill you have additional wastes that are not permitted for discharge? IfEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2011COMPANYLLOG Exploration Offshore, L.L.C.AREAMississippi CanyonBLOCK705LEASEOCS-G 31521PLATFORMWELLACOMPANY CONTACTKathy GowlandTELEPHONE NO.985-801-4300REMARKSDrill and CompleteMMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 1 of 8EMISSIONS FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6La. DEQ 1991Gas Venting lbs/scf 0.0034Sulphur Content Source Value UnitsFuel Gas 3.33 ppmDiesel Fuel 0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightMMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 2 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSLLOG Exploration Offsho Mississippi Canyon 705 OCS-G 31521 A Kathy Gowland 985-801-4300OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 26400 1275.12 30602.88 24 60 18.61 85.36 639.65 19.19 139.56 13.40 61.46 460.55 13.82 100.48PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2100 101.43 2434.32 8 9 1.48 6.79 50.88 1.53 11.10 0.05 0.24 1.83 0.05 0.40VESSELS>600hp diesel(supply) 2100 101.43 2434.32 10 26 1.48 6.79 50.88 1.53 11.10 0.19 0.88 6.61 0.20 1.44VESSELS>600hp diesel(tugs) 4200 202.86 4868.64 12 4 2.96 13.58 101.76 3.05 22.20 0.07 0.33 2.44 0.07 0.53FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00DRILLING OIL BURN 250 24 2 4.38 71.15 20.83 0.10 2.19 0.11 1.71 0.50 0.00 0.05WELL TEST GAS FLARE 208333.33 24 2 0.12 14.87 12.56 80.94 0.00 0.36 0.30 1.942011 YEAR TOTAL28.90 183.79 878.88 37.96 267.09 13.82 64.63 472.29 14.45 104.85EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1764.90 1764.90 1764.90 1764.90 47972.9253.0MMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 3 of 8SUMMARYCOMPANY AREA BLOCK LEASE PLATFORM WELLLLOG ExploratioMississippi Canyon 705 OCS-G 31521 AEmitted SubstanceYearPM SOx NOx VOC CO2011 13.82 64.63 472.29 14.45 104.85Allowable1764.90 1764.90 1764.90 1764.90 47972.92MMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 8 of 8

## APPENDIX H OIL SPILL INFORMATION (30 CFR PART 250.219 AND 250.250)

A. 

## Oil Spill Response Planning
All the proposed activities in this Revised Exploration Plan will be covered by the Oil Spill Response Plan filed by LLOG (MMS Operator No. 02058) in accordance with 30 CFR 254 and approved on June 3, 2009, last modification May 31, 2011 (not currently approved). LLOG submitted the Biennial Oil Spill Response Plan on 06/30/2010 (currently pending approval). OSRP Certification submitted by letter dated June 1, 2011 for modification dated May 31, 2011. The WCD proposed in this Plan does not exceed the WCD submitted in the modification dated 05/31/2011. The last OSRP Certification was accepted by BOEMRE on 03/25/2011.

B. 

## Spill Response Sites
The following locations will be used in the event an oil spill occurs as a result of the proposed activities.
Primary Response Equipment Location Pre-Planned Staging Location(s)
Houma, LA Fort Jackson, LA

C. 

## OSRO Information
The O’Brien Group (TOG) will provide trained personnel capable of providing supervisory management of the oil spill response in addition to contacting and deploying cleanup personnel and equipment
LLOG utilizes Clean Gulf Associates (CGA) as it’s primary provider for equipment, which is an industry cooperative owning an inventory of oil spill clean-up equipment. CGA is supported by the Marine Spill Response Corporation’s (MSRC), which is responsible for storing, inspecting, maintaining and dispatching CGA’s equipment. The MSRC STARS network provides for the closest available personnel, as well as an MSRC supervisor to operate the equipment.

### D. 

## Worst-Case Scenario Information

Category Regional OSRP Revised EP Type of Activity Exploratory MODU Exploratory MODU Facility Surface Location Mississippi Canyon Bl ock 547 Mississippi Canyon Blocks 705 Facility Description Well Location Well No. SS002 (Location B) Location A

Distance to Nearest Shoreline (Miles) 38.4 miles 53 miles Volume: Storage Tanks (total) Facility Piping (total) Lease Term Pipeline Uncontrolled Blowout (day) Barging Potential 24 Hour Volume (bbls) Total Volume 225,144 bbls 22,289,256 123,200 bbls 21,196800 Type of Liquid Hydrocarbon Crude Oil Condensate API Gravity 28o 43o 

### 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 approved on June 3, 2009, last modified May 31, 2011 (not currently approved), and since the worst-case scenario determined for this EP does not replace the worst-case scenario in our modified Regional OSRP (May 31, 2011), I hereby certify that LLOG has the capability to respond, to the maximum extent practicable, to a worst-case discharge, or a substantial threat of such a discharge, resulting from the activities proposed in this EP.
LLOG submitted the Biennial Oil Spill Response Plan on 06/30/2010 (currently pending approval). OSRP Certification submitted by letter dated June 1, 2011 for modification dated May 31, 2011. The WCD proposed in this Plan does not exceed the WCD submitted in the modification dated 05/31/2011. The last OSRP Certification was accepted by BOEMRE on 03/25/2011.
LLOG Exploration Offshore, L.L.C., Company No. 02058, previously submitted the Regional OSRP Exploration WCD volume to be reviewed in Plan R-5139, Revised Exploration Plan submitted on March 2, 2011.
The required proprietary data outlined in NTL 2010-N06 was submitted to BOEMRE. LLOG accepts the BOEMRE’s worst case discharge value of 123,200 bbls potential 24 hour volume with a 43o 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 Management Act analysis, the largest spill volume originating from the proposed activity would be a well blowout during drilling operations, estimated to be 123,200 barrels of condensate with an API gravity of 43.9°.
Land Segment and Resource Identification
Trajectories of a spill and the probability of it impacting a land segment have been projected utilizing information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BOEM website. The results are shown in Figure 1. The BOEM OSRAM identifies a 4% probability of impact to the shorelines of Plaquemines Parish, LA within 10 days. Plaquemines Parish includes Barataria Bay, the Mississippi River Delta, Breton Sound and the affiliated islands and bays. This region is an extremely sensitive habitat, and serves as a migratory, breeding, feeding and nursery habitat for numerous species of wildlife. Beaches in this area vary in grain particle size, and can be classified as fine sand, shell or perched shell beaches. Sandy and muddy tidal flats are also abundant.
Response
LLOG Exploration Offshore, L.L.C. will make every effort to respond to the Worst Case Discharge as effectively as practicable. A description of the response equipment available to contain and recover the Worst Case Discharge is shown in Figure 2.
Using the estimated chemical and physical characteristics of condensate, an ADIOS weathering model was run on a similar product from the ADIOS oil database. The results indicate 27% or approximately 33,264 barrels of condensate would be evaporated/dispersed within 24 hours, with approximately 89,936 barrels remaining.

Spill Response MC 705 Barrels of Oil
WCD Volume 123,200

Less 27% natural evaporation/dispersion 33,264 Remaining volume 89,936 Oil addressed by in-situ burning 4,496


### Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary storage equipment available to respond to a spill of 123,200 barrels. The list estimates individual times needed for procurement, load out, travel time to the site and deployment. Figure 2 also indicates how operations will be supported.
LLOG Exploration Offshore, L.L.C.’s Oil Spill Response Plan includes alternative response technologies such as in-situ burn. Strategies will be decided by Unified Command based on size

### of the spill, weather and potential impacts. If the conditions are favorable for in-situ burning, the proper approvals have been obtained and the proper planning is in place, in-situ burning of oil may be attempted. Using estimates based on the Deepwater Horizon spill of 2010, up to 5% or approximately 4,496 barrels of the total daily Worst Case Discharge volume could be burned. Slick containment boom along with sorbent boom would be immediately called out and on-scene as soon as possible. Offshore response strategies may include collection of condensate with sorbent boom (inside hard boom), attempting to skim utilizing the HOSS Barge, nine Fast Response Units, two Aqua Guard Triton RBS skimmers, and eleven sets of Koseq skimming arms, with a total derated skimming capacity of 318,609 barrels. Temporary storage associated with skimming 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 mobilized and centrally located to provide temporary storage allowing the skimmers to stay in the area of operations as much as possible. Safety is first priority. Air monitoring will be accomplished and operations deemed safe prior to any containment/skimming attempts.
If the spill went unabated, shoreline impact in Plaquemines Parish, Louisiana would depend upon existing environmental conditions. Shoreline protection would include the use of CGA’s near shore and shallow water skimmers with a totaled derated skimming capacity of 54,753 barrels. Temporary storage associated with skimming equipment equals 1,861 barrels. If additional storage is needed, an 86,948 barrel storage barge may be mobilized and centrally located to provide temporary storage allowing the skimmers to stay in the area of operations as much as possible. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. MSAs with AMPOL and Oil Mop will ensure the availability of 147,000 feet of 18” shoreline boom. Figure 2 (below) outlines individual times needed for procurement, load out, travel time to the site and deployment. Strategies would be based upon surveillance and real time trajectories that depict areas of potential impact given actual sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan for Plaquemines Parish and Unified Command would be consulted to ensure that environmental and special economic resources would be correctly identified and prioritized to ensure optimal protection. Shoreline protection strategies depict the protection response modes applicable for oil spill clean-up operations. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection strategies for this area, and it describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands, based on the assumption that removal of the released oil will be much easier and less damaging to fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. Supervisory personnel have the option to modify the deployment and operation of equipment allowing a more effective response to site-specific circumstances. LLOG Exploration Offshore, L.L.C.’s contract Spill Management Team holds a copy of the State of Louisiana Initial Oil Spill Response Plan.

### Initial Response Considerations Actual actions taken during an oil spill response will be based on many factors to include but not be limited to:

x Weather

x Equipment and materials availability

x Ocean currents and tides

x Location of the spill

x Product spilled

x Amount spilled

x Environmental risk assessments

x Trajectory and product analysis

x Well status, i.e., shut in or continual release
LLOG Exploration Offshore, L.L.C. will take action to provide a safe, aggressive response to contain and recover as much of the spilled oil as quickly as it is safe to do so. In an effort to protect the environment, response actions will be designed to provide an “in-depth” protection strategy meant to recover as much oil as possible as far from environmentally sensitive areas as possible. Safety will take precedence over all other considerations during these operations.
Upon notification of a spill, the following actions will be taken:

x Information will be confirmed

x An assessment will be made and initial objectives set

x OSROs and appropriate agencies will be notified

x ICS 201, Initial Report Form completed

x Initial Safety plan will be written and published

x Unified Command will be established

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

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

o On-site command and control established
Offshore Response Actions
Equipment Deployment Surveillance

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

x Provide trained observer to provide on site status reports

x Provide command and control platform at the site if needed

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

x Continual monitoring of vessel assets using vessel monitoring systems

### Containment boom & sorbent boom

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

x Ensure boom handling and mooring equipment is deployed with boom

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

x Use Vessels of Opportunity (VOO) to deploy and maintain boom
Dedicated off-shore skimming systems General

x Deployed to the highest concentration of oil

x Assets deployed at safe distance from in-situ burn operations
CGA HOSS Barge

x Use in areas with heaviest oil concentrations

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

CGA FRUs

x To the area of the thickest oil

x Use as far off-shore as allowed
T&T Koseq Skimming Systems

x To the area of the thickest oil

x Use as far off-shore as allowed

x VOOs with a minimum of 2,000 bbls storage capacity
Storage Vessels

x Establish availability of CGA contracted assets

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

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

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

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

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

x Acquire additional resources as needed

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

x Expect mission specific and safety training to be required

x Plan with the US Coast Guard for vessel inspections

### In-situ Burn assets

x Determine appropriateness of in-situ burn operation in coordination with the FOSC and affected SOSC

x Determine availability of fire boom and selected ignition systems

x Start ordering fire boom stocks required for expected operations

x Contact boom manufacturer to provide training if required

x Determine assets to perform on water operation

x Build operations into safety plan

x Conduct operations in accordance with an approved plan

### Near Shore Response Actions
Timing

x Put near shore assets on standby and deployment in accordance with planning based on the actual situation, actual trajectories and oil budgets

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

x Outfitting of VOOs for specific missions

x Deployment of assets based on actual movement of oil

Considerations

x Water depth, vessel draft

x Shoreline gradient

x State of the oil

x Use of VOOs

x Distance of surf zone from shoreline
Equipment Deployment Surveillance

x Provide trained observer to direct skimming operations

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

x Continual monitoring of vessel assets
Vessel Deployment Dedicated Near Shore skimming systems

x FRVs

x Egmopol and Marco SWS

x Operate with aerial spotter directing systems to observed oil slicks

VOO

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

x Industry vessel are usually best for deployment of Vessel of Opportunity Skimming Systems (VOSS)

x Acquire additional resources as needed

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

x Expect mission specific and safety training to be required

x Plan with the US Coast Guard for vessel inspections

x Operate with aerial spotter directing systems to oil patches

### Shoreline Protection Operations
Response Planning Considerations

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

x Time to acquire personnel and equipment and their availability

x Previous contingency planning contained in the appropriate Area Contingency Plan, and currently (Feb 2011) for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep Water Horizon, dated 2 May 2010 (La. OSRP)

Actions
Placement of boom

x Position boom in accordance with the ERA based on the actual situation or the appropriate ACP

x 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

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

x Shoreline Cleanup and Assessment Team Reports and recommendations

x Determination of Archeological sites and gaining authority to enter

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

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

x Staging of equipment and housing of response personnel as close to the job site as possible to maximize on-site work time

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

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

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

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

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

### Decanting Strategy Recovered oil and water mixtures will typically se parate into distinct phases when left in a quiescent state. When separation occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill recovery. CGA Equipment Limitations The capability for any spill response equipment, whether a dedicated or portable system, to operate in differing weather conditions will be dir ectly in relation to the capabilities of the vessel the system in placed on. Most importantly, however, the decision to operate will be based on the judgment of the Unified Command and/or the Captain of the vessel, who will ultimately have the final say in terminating operations. Skimming equipment listed below may have operational limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil spill response, vessel skimming operations ceased when seas reached 5-6 feet and vessels were often recalled to port when those conditions were exceeded. Systems below are some of the most up-to-date systems available and were employed during the DWH spill.
Boom 3 foot seas, 20 knot winds FRU 8 foot seas HOSS Barge/OSRB 8 foot seas Koseq Arms 8 foot seas OSRV 4 foot seas

### Environmental Conditions in the GOM Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences westerly winds during the winter and easterly winds in the summer. Average wind speed is generally 14-15 mph along the coast. Wave heights average 4 and 5 feet. However, during hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, flooding is prominent.
Surface water temperature ranges between 70 and 80  ̊ F during the summer months. During the winter, the average temperature will range from 50 and 60  ̊ F.
The Atlantic and Gulf of Mexico hurricane season is officially from 1 June to 30 November. 97% of all tropical activity occurs within this window. The Atlantic basin shows a very peaked season from August through October, with 78% of the tropical storm days, 87% of the minor (Saffir-Simpson Scale categories 1 and 2) hurricane days, and 96% of the major (Saffir-Simpson categories 3, 4 and 5) hurricane days occurring then. Maximum activity is in early to mid September. Once in a few years there may be a hurricane occurring "out of season" - primarily in May or December. Globally, September is the most active month and May is the least active month.

### FIGURE 1 TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it impacting a land segment have been projected utilizing LLOG Exploration Offshore, L.L.C.’s WCD and information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BOEM website using 10 day impact. The results are tabulated below.

Area/Block OCS-G Launch Area Land Segment and/or Resource Conditional Probability (%) within 10 days
Exploratory Drilling

MC 705 #1
53 miles from shore G31521 C58 Terrebonne Parish, LA Lafourche Parish, LA Plaquemines Parish, LA 1 2 4WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(53 miles from shore)123,200 bbls of condensateAPI Gravity 43.9°FIGURE 2 – Equipment Response Time to MC 705#1SurveillanceSurveillanceDispersantCapacity (gal)StorageCapacityPersonsReq.From Hrs to ProcureHrs toLoadoutTravel tositeTotal HrsASIAero Commander NA NA 2 Houma 1 1 0.8 2.8Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge 43000 4000 3 Tugs 8 Harvey 4 0 5 7.5 1 17.5T&T Marine (available through contract with CGA)Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 4 12 1 5 2 24Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 4 12 1 5 2 24Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 4 12 1 5 2 24Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 4 12 1 24.2 2 43.2Recovered Oil Storage NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsK-Sea Operating (available through contract with CGA)PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 4 7.5 1 28.5DBL 76 1212984 NA 83937 1 Tug 6 Venice 4 12 4 7.5 1 28.5DBL 81 1132231 NA 86948 1 Tug 6 Venice 4 12 4 7.5 1 28.5DBL 101 1119760 NA 107285 1 Tug 6 Venice 4 12 4 7.5 1 28.5Staging 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 1 11FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 8 5 1 17FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 3 5 1 12FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 11 5 1 20FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 5.5 5 1 14.5FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6 Venice 1 2 0 5 1 9Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 8 5 2 17Offshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGA42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 5 1 1142” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 5 1 1742” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 2 3 5 1 1242” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 5 1 2042” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 5 1 14.542” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 5 1 131000’ Hydro-Fire Boom(In-Situ Burn)NA NA 8 Utility 40 Harvey 1 4 2 5 6 18Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsK-Sea Operating (available through contract with CGA)DBL 82 1137538 NA 86948 1 Tug 6 Venice 4 12 4 6.25 1 27.25CGA46’ FRV 5000 65 NA 4 Galveston 1 0 0 12.4 0 13.446’ FRV 5000 65 NA 4 Houma 1 0 2 2.8 0 5.846’ FRV 5000 65 NA 4 Lake Charles 1 0 1 9.2 0 11.246’ FRV 5000 65 NA 4 Venice 1 0 1 2 0 4Trinity SWS 21500 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 Egmopol 3000 100 NA 3 Galveston 1 2 8 2 0 13SWS Egmopol 3000 100 NA 3 Houma 1 2 3 2 0 8SWS Marco 3588 34 NA 3 Houma 1 2 3 2 0 8SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 2 0 10.5Rope Mop 77 2 0 3 Belle Chasse 1 2 2 2 0 7RO Storage Barge NA 249 Towed 0 Galveston 1 2 8 2 0 13RO Storage Barge NA 249 Towed 0 Houma 1 2 3 2 0 8RO Storage Barge NA 249 Towed 0 Lake Charles 1 2 5.5 2 0 10.5RO Storage Barge NA 249 Towed 0 Venice 1 2 0 2 0 5Shoreline ProtectionStaging Area: VeniceShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsAMPOL (available through MSA)42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 4 2 12 2220,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2 2 6 14Oil Mop (available through MSA)10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 3 1110,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 7.5 2 3 14.510,000 18” Boom 4 Crew 10 Port Arthur, TX 1 1 6.25 2 3 13.2520,000 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.75 2 6 11.7510,000 18” Boom 4 Crew 10 Port Allen, LA 1 1 3.5 2 3 10.510,000 18” Boom 4 Crew 10 Houma, LA 1 1 3.5 2 3 10.515,000 18” Boom 6 Crew 14 Gretna, LA 2 2 2 2 4 12Beach Boom EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGABeach Boom (2000’) NA NA NA 6 Galveston 1 2 8 1 2 14Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 11 1 2 17Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 1 2 10Wildlife Response EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGAWildlife Support Trailer NA NA NA 2 Houma 1 2 3 1 2 9Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 2 1 2 8Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 1 2 14Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 1 2 9Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 11 1 2 17Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 1 2 11.5Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 1 2 10Response Asset TotalOffshore EDRC 318,609Offshore Recovered Oil Storage 389,870Nearshore / Shallow Water EDRC 54,753Nearshore / Shallow Water Recovered Oil Storage 88,709

## APPENDIX M SUPPORT VESSELS AND AIRCRAFT INFORMATION (30 CFR PART 250.224 AND 250.257)

A. 

## General
Personnel involved in the proposed operations will typically use their own vehicles as transportation to and from the selected onshore base; whereas the selected vendors will transport the equipment by a combination of trucks, boats and/or helicopters to the onshore base. The personnel and equipment will then be transported to the drilling rig via the transportation methods and frequencies shown, taking the most direct route feasible as mandated by weather and traffic conditions:
Type Maximum Fuel Tank Storage Capacity Maximum No. in Area at Any Time Trip Frequency or Duration
Tug Boats 3000 bbls 1 Every two weeks Supply Boats 500 bbls 1 Three times weekly Service Boats 500 bbls 1 Daily

Crew Boats 500 bbls 1 Weekly

Aircraft 1900 lbs 1 As Needed 

## B. Diesel Oil Supply Vessels

Size of Fuel Supply Vessel Capacity of fuel Supply Vessel Frequency of Fuel Transfers Route Fuel Supply Vessel Will Take 180’ 1,500 bbls Weekly From shorebase in Fourchon, LA to MC 705 

## A. Drilling Fluids Transportation
See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of this Plan. 

## B. Solid and Liquid Wastes Transportation
See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of this Plan.



## C. Vicinity Map
A Vicinity Plat showing the location of Mississippi Canyon Block 705 relative to the nearest shoreline and onshore base is included as Attachment M.

## APPENDIX N ONSHORE SUPPORT FACILITIES INFORMATION (30 CFR PART 250.225 AND 250.258)

A. 

## General
The proposed surface disturbances in Mississippi Canyon Block 705 will be located approximately 53 miles from the nearest Louisiana shoreline, and approximately 62 miles from the following onshore support base:
Name Location Existing/New/Modified Martin North Fourchon, LA Existing
LLOG will use an existing onshore base to accomplish the following routine operations:

Ɣ Loading/Offloading point for equipment supporting the offshore operations.

Ɣ Dispatching personnel and equipment, and does not anticipate the need for any expansion of the selected facilities as a result of the activities proposed in this Revised Plan.

Ɣ Temporary storage for materials and equipment.

Ɣ 24 Hour Dispatcher

B. 

## Support Base Construction or Expansion
The proposed operations are temporary in nature and do not require any immediate action to acquire additional land or expand existing base facilities.

C. 

## Support Base Construction or Expansion Timetable
This section of the plan is not applicable to the proposed operations.

D. 

## Waste Disposal
See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of this Plan.