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-09844

Type - Initial Exploration Plan

Lease(s) - OCS-G33764 Block - 895 Mississippi Canyon Area

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

Wells A, B, C, and G

%14FNJTVCNFSTJCMFBOE%SJMMTIJQ

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

should be addressed in an Environmental Assessment.

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

Chiquita Hill

Plan Coordinator Description -

Rig Type - Subject: From: February 5, 2015

# LLOG EXPLORATION OFFSHORE, L.L.C.

1001 Ochsner Boulevard, Suite 200 Covington, Louisiana 70433



# INITIAL EXPLORATION PLAN

OCS-G-33764

Mississippi Canyon 895

PREPARED BY:

Kathy Gowland/Kim DeSopo Regulatory Specialist 985-801-4300 (Main)

kathygo@llog.com kim.desopo@llog.com

November 12, 2014

### LLOG EXPLORATION OFFSHORE, L.L.C.

INITIAL EXPLORATION PLAN

OCS-G 33764

MISSISSIPPI CANYON 895

APPENDIX A Plan Contents

APPENDIX B General Information

APPENDIX C Geological, Geophysical Information

APPENDIX D H2S Information

APPENDIX E Biological, Physical and Socioeconomic Information

APPENDIX F Waste and Discharge Information

APPENDIX G Air Emissions Information

APPENDIX H Oil Spill Information

APPENDIX I Environmental Monitoring Information

APPENDIX J Lease Stipulation Information

APPENDIX K Environmental Mitigation Measures Information

APPENDIX L Related Facilities and Op erations Information

APPENDIX M Support Vessels and Aircraft Information

APPENDIX N Onshore Support Facilities Information

APPENDIX O Coastal Zone Management Act (CZMA) Information

APPENDIX P Environmental Impact Analysis

APPENDIX Q Administrative InformationMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 1 

## APPENDIX A

PLAN CONTENTS (30 CFR Part 550.211 and 550.241)

A. Plan information

In accordance with 30 CFR 550.211 and 550.241(a),and NTL No. 2008-G04 and NTL 2010-N06, LLOG Exploration Offshore, LLC pr oposes the drilling, completion, testing

and installation of subsea wellhead and/or ma nifold for four (4) proposed locations on Lease OCS-G-33764, Mississippi Canyon Block 895.

Included as Attachment A-1 is Form BOEM 137 “OCS Plan Information Form”, which provides for the drilling, sub-sea comple tion and testing of all well locations.

. 

## B. Location

Attachment A-2

– Well Location Plat

Attachment A-3 – Bathymetry Map – Seafloor disturbance area



## C. Safety & Pollution Features

LLOG will utilize either a Drillship or DP semi-submersible drilling rig for the proposed operations. A description of the drilling unit is included on the OCS Plans Information Form. Rig specifications will be made part of the Application for Permit to

Drill.

Safety features on the drilling unit will in clude well control, pollution prevention, and blowout prevention equipment as described in Title 30 CFR Part 250, Subparts C, D, E and G; and further clarified by BOEM’s No tices to Lessees, and currently policy making invoked by BOEM, EPA and USCG. Appr opriate life rafts, life jackets, ring buoys, etc., will be maintained on the facility at all times.

Pollution prevention measures include instal lation of curbs, gutters, drip pans, and drains on the drilling deck areas to collect all contaminants and debris

.

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 th e proposed activities (MODU, barges, platforms, etc.):Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 2 Type of Storage

Tank Type of Facility Tank Capacity (bbls) Number of

tanks Total Capacity (bbls) Fluid Gravity (API) Fuel Oil Storage

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

43 Fuel Oil Storage

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

43

Fuel Oil Settleing Tank 836.6 2 1,673.2 No. 2 Diesel -

43 Fuel Oil Day

Tanks 836.6 2 1,673.2 No. 2 Diesel -

43

Type of Storage

Tank Type of Facility Tank Capacity (bbls) Number of

tanks Total Capacity (bbls) Fluid Gravity (API) Fuel Oil (Marine Diesel) DP SemiSubmersible 164 1 164 30

Fuel Oil Day 367 2 734 30 Emergency

Generator 31 1 31 30

Forward Hull

Fuel Oil 4634 2 9268 30

Lower Aft Hull

Fuel Oil 3462 2 6924 30

Lube Oil

Services 117/10.5/4.6 3 132 45

Dirty Lube Oil 38/28 2 66 45

Dirty Bilge 190 4 760 10



## E. Pollution Prevention Measures: Not applicable. The State of Florida is not an affected State by the proposed activities in this plan.



## F. Additional measures : LLOG does not propose any additional safety, pollution prevention, or early detection measures, bey ond those required in 30 CFR 250 and per December 13, 2010 – Guidance for Deepwater Dr illers to Comply with Strengthened Safety and Environmental Standards.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 3 

# OCS Plan Information Form

Attachment A-1 (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 4 

### $11,019 74706211963

## Schedule	of	Activities

WELL /

EVENT SPUD TD COMPL
START COMPL
FINISH DESCRIPTION NO OF DAYS

MC 895 “G” 05/15/2015 07/26/2015 Drill/TA 72

MC 895 “A” 01/15/2016 03/21/2016 03/21/ 2016 05/05/2016 Drill/Complete 67/46

MC 895 “G” 05/05/2016 06/24/2016 Complete 50

MC 895 “B” 01/15/2017 03/24/2017 03/24/ 2017 05/08/2017 Drill/Complete 68/45

MC 895 “C” 05/08/2017 07/13/2017 07/13/ 2017 08/27/2017 Drill/Complete 66/45Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 4 

# Well Location Plats

Attachment A-2 (Public Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 5 

# Bathymetry Map

Attachment A-3 (Public Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 6 

## APPENDIX B

GENERAL INFORMATION (30 CFR Part 550.213 and 550.243)

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 app lications and general pe rmits 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, freshw ater, barite) See Appendix F, Table 1 of this Plan Oil–based (diesel, mineral oil) N/A Synthetic-based (internal olefin, ester) See Appendix F, Table 2 of this Plan



## C. New Or Unusual Technology

LLOG does not propose using any new and/ or unusual technology for the operations proposed in this Initial Plan.



## D. Bonding Statement

The bond requirements for the activities and fac ilities proposed in this Initial Exploration Plan 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 s ecurity under 30 CFR 256.53(d) and NTL No. 2008-N07 “Supplemental Bond Procedures.”



## E. Oil Spill Responsibility (OSFR)

LLOG Exploration Offshore, L.L.C (MMS Co. No. 02058) will demonstrate oil spill financial responsibility for the facilities proposed in this Initial EP according to 30 CFR Part 553, and NTL No. 2008-N05 “Guidelines for Oil Spill Financial Responsibility (OSFR) for Covered Facilities.”Mississippi Canyon Block 895

– OCS

- G 33764

Initial Exploration Plan 7 

## 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 Worst Case Discharge Calculations (Proprietary)

– Attachment B-1*

and Blowout Scenario, including Site Specific Proposed Relief Well and Inter vention Planning and Relief Well Response Time Estimate (Public Information)

- Attachment

B-2.



## *LLOG accepted BOEM WCD rate of 290,697 BPD on January 14,

2015.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 8 

# NTL 2010-N06 Data

Worst Case Discharge Calculations

Attachment B-1

(Proprietary Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 9 

# NTL 2010-N06 Data

Blowout Scenario

Attachment B-2 (Public Information)BLOWOUT SCENARIO
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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 895 “A” OCS-G-33764 3750 926,266’ 10,196,586’ 28  04’ 49.69” 89  12’ 54.57”

MC 895 “B” OCS-G-33764 3750 926,266’ 10,196,586’ 28  04’ 49.69” 89  12’ 54.57”

MC 895 “C” OCS-G-33764 3825 926,908’ 10,192,596’ 28  04’ 10.31” 89  12’ 46.655”

MC 895 “G” OCS-G-33764 3688 928,199’ 10,195,843’ 28  04’ 42.687” 89  12’ 32.885”

INFORMATION REQUIREMENTS

A) Blowout scenario

The MC 895 well(s) 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 895 (surface location) Facility Designation MODU Distance to Nearest Shoreline (miles) ~59 Uncontrolled Blowout (Volume per day) 290,697 bbls (max estimated) Type of Fluid Crude

C) Total volume and maximum duration of the potential blowout

Duration of Flow (days) 119 days total (see Relief Well Response Estimate below) Total Volume of Spill (bbls) ~34.6 MMBO based on 119 days of uncontrolled flow based on simulator models (steady-state model)

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

Omitted from Public Information CopiesBLOWOUT SCENARIO
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2 E) Potential for the well to bridge over

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.BLOWOUT SCENARIO
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3 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 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, 30 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 8500 Series Rigs (DP Semi)

 Transocean Enterpri se (DP Drillship)

 Seadrill West Neptune (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,BLOWOUT SCENARIO
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4 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 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 theBLOWOUT SCENARIO
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5 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 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 drilling 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 ~6 miles from ATP 8” and 10” pipelines running from the Mirage wells subsea manifold located on MC 941 block. An ATP 8” and an ATP 10” pipeline runs within 8550’ to 12,150’ to the N-NE of the propos ed locations. Other subsea manifold tie-in include ~6 miles from MC 806 Mars surface / subsea development. Potential to utilize these lines in the event of a “cap and flow” scenario are limited but available.

Relief well sites have been initially identified to address blowout scenarios for the potential geologic targets for the proposed wells. A total of 7 relief well surface locations in MC 895 are proposed for the 4 proposed drill sites. The 3 drill sites are the most probable well sites for a development
scenario. 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 895 “A” or “B” OCS-G-3376 4 MC 895 WSW Relief Well #1 923,999’ 10,195,124’

MC 895 S Relief Well #2 * 926,417’ 10,194,005’

MC 895 NNE Relief Well #3 * 927,479’ 10,199,068’

MC 895 “C” OCS-G-33764 MC 895 ESE Relief Well #1 929,480’ 10,191,499’

MC 895 ENE Relief Well #2 * 929,567’ 10,193,268’

MC 895 W Relief Well #3 923,720’ 10,192,526’

MC 895 “G” OCS-G-33764 MC 895 SSE Relief Well #1 * 929,567’ 10,193,268’

MC 895 WSW Relief Well #2 * 926,417’ 10,194,005’

MC 895 W Relief Well #3 924,967’ 10,196,382’

MC 895 NW Relief Well #4 * 927,479’ 10,199,068’
“*” Indicates relief well locatio ns common for proposed wells

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 (Helix DW Containment System) 4BLOWOUT SCENARIO
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6  implement short term intervention and containment (if possible)

 develop Intervention Plan

 initiate relief well planning

 continue spill control measures

INTERVENTION AND CONTAIMENT OPERATIONS

 mobilize equipment and initiate intervention and containment operations

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

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

 continue spill control measures 14

RELIEF WELL(S) OPERATIONS

 continue intervention and containment measures

 continue spill control measures

 drill relief well (s) 80

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

TOTAL DAYS 149BLOWOUT SCENARIO
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7BLOWOUT SCENARIO
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8BLOWOUT SCENARIO
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9Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 10 

## APPENDIX C

GEOLOGICAL AND GEOPHYSICAL INFORMATION (30 CFR Part 550.214 and 550.244)

A. Geological Description

Included as Attachment C-1 are the geological targets a nd a narrative of trapping features proposed in this Plan



## B. Structure Contour Maps

Included as Attachment C-2 are current structure maps (depth base and expressed in feet subsea) depicting the entire lease cove rage area; drawn on top of the prospective hydrocarbon sands. The maps depict each proposed bottom hole location and applicable geological cross section.



## C. Interpreted Seismic Lines

Included as Attachment C-3 is a copy of the migrated a nd annotated (shot points, time lines, well paths) deep seismic line with in 500 feet of the surface location being proposed in this Plan.



## D. Geological Structure Cross-Sections

An interpreted geological cross section depi cting the proposed well locations and depth of the proposed wells is included as Attachment C-4 . Such cross section corresponds to each seismic line being submitted.



## E. Shallow Hazards Report

An Archaeological Deep Tow Survey, Bl ock 895, Mississippi Canyon Area, OCS-G 33764 was prepared by Tesla Offshore, LLC in June, 2010 for Houston Energy, L.P. and submitted to BOEM by LLOG Exploration Offshore, L.L.C. on June 4, 2013. Berger Geosciences, LLC conducted a Shallow Hazards Assessment, Benthic Communities Evaluation, and Archaeological Resource Survey for Mississippi Canyon Block 895, OCS-G 33764 on behalf of LLOG Exploration Offshore, Inc. submitted to BOEM on August 18, 2014.



## F. Shallow Hazards Assessment

Utilizing the 3D deep seismic exploration data a shallow hazards analysis was prepared for the proposed surface locations, evaluati ng seafloor and subsurface geologic and manmade features and conditions, and is included as Attachment C-5.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 11 

## G. High Resolution Seismic Lines

LLOG provided exploration 3-D seismic data for the evaluation of the proposed surface disturbance operations. See Attachment C-6



## H. Stratigraphic Column

A generalized biostratigraphic/ lithostratigraphic column from the seafloor to the total depth of the proposed wells is included as Attachment C-7.



## I. Time vs Depth Tables

LLOG has determined that there is existing sufficient well control data for the target areas proposed in this Plan; therefore, tables providing seismic time versus depth for the proposed well locations are not required.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 12 

# Geological Description

Attachment C-1 (Proprietary Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 13 

# Structure Maps

Attachment C-2 (Proprietary Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 14 

# Deep Seismic Lines

Attachment C-3 (Proprietary Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 15 

# Cross Section Maps

Attachment C-4 (Proprietary Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 16 

# Shallow Hazards Assessment

Attachment C-5 (Public Information)36499 Perkins Road Prairieville, Louisiana 70769 Telephone: 225.673.2163

Fax: 225.744.3116
www.teslaoffshore.com

April 10, 2014 Job #13- 014

- 31

Bureau of Ocean Energy Management (MS 5230) Gulf of Mexico OCS Region

1201 Elmwood Park Blvd. New Orleans, LA 70123- 2394

RE: LLOG Exploration Offshore, L.L.C. Proposed OCS-G 33 764 Wells ‘A ’ & ‘B’

Bl ock 8 95

, Mississippi Canyon Area Archaeological Assessment

Dear Staff:

LLOG Exploration Offshore, L.L.C. (LLOG) proposes to drill the OCS

- G 33 764 Well s ‘ A ’
and ‘B’ from the followi ng common surface location in Block 8 95

, Mississippi Canyon

Area:

Da tum:
NAD 27 Spheroid:

Clarke 1866 Projection:

UTM Zone:

16

. Central Meridian:

87° 00 ’ West

Latitude: 28° 04’ 49

. 690 ” N Longitude: 8 9 ° 12 ’ 54

. 571 ” W

X: 926, 269

. 27 Y: 10, 196

, 586

. 26

F N L: 4, 3 73

. 74 ’ F W L: 7, 549

. 27 ’

This assessment addresses a radius of 2,000-feet around the proposed common surface location. LLOG proposes to drill the wells with a dynamically positioned rig, therefore no anchors will be deployed, and surface impacts will be restricted to the seafloor in the immediate vicinity of the borehole. Tesla Offshore, LLC surveyed all of

Block 8 95, with extended survey coverage in to Blocks 8 50, 851, 852, 894, 896, 938,
and 939, Mississippi Canyon Area. The survey was conducted in April and May of 2010 along a 300

- meter grid. The resulting archaeological assessment report was submitted

to Houston Energy L.P. under Tesla Job# 10

- 078

- 12

. LLOG contracted Tesla Offshore, LLC to provide this archaeological analysis ( NTL No. 2005

- G0 7

) in accordance with the Bureau of Ocean Energy Management (BOEM) Gulf of Mexico OCS Region.

Water depth is approximately 3,7 5 0 feet surrounding the proposed drill site. Water depths increase from north ea st to south we st at the proposed well site at an approximate rate of 162 feet/mile

.

Seafloor soils

are reported to be silty clay and marine deposits (MMS 1983 Visual No. 3; MMS 1986 Visual No. 5).TESLA OFFSHORE

LLOG Exploration Offshore, L.L.C. Proposed OCS-G 33764 Wells ‘A’ & ‘B’

Block 8 95 , Mississippi Canyon Area Archaeological Assessment Page 2

Man-made features are not present within 2,000ft of the proposed surface location. There are only two installations in the entire survey grid. T he ATP 8”

- 10”” pipeline (Segment No. 16115) and the ATP 10”

- 12” pi peline (Segment 16127) are located approximately 8,550’ and 8,725’ feet N E of the proposed surface location, respectively

. Both pipelines were verified as

- built on the sonar data.

Magnetic data

is not required for survey in these water depths per NTL 20 05 -G07.

Sonar data recorded no targets of significance within the survey area. Sonar data recorded numerous fault scarps and several areas of increased backscatter reflectivity within the survey grid. The closest area of observed increased seafloor
refl ectivity is located approximately 2,775’ NE of the proposed surface location, while the nearest fault scarp is located approximately 3,175’ NE of the proposed well site. Sonar data also recorded several isolated point source or linear reflectors within th e survey grid . These were primarily located in clusters associated with fault scarps or

near the existing pipelines. The closest point source/linear reflector is located approximately 5,175’ NW of the proposed surface location. Point source reflectors

s een on low frequency sonar are usually associated with small features near the threshold of sonar resolution. These features may represent small quantities of man

made debris, or isolated natural features associated with changes in seafloor morphology. T hese are not interpreted as cultural resources and have not been
recommended for avoidance as such.

Supplemental Subbottom Data showed penetration in excess of 175 feet

, consisting of primarily parallel bedded, moderately reflecting sediments at the

pro posed well site. A fault zone was recorded within the survey area, located approximately 1,92 5’ NE of the proposed surface area. No faults were observed on the subbottom data nearest to the proposed surface location. There is no potential for prehistori c sites in this portion of Mississippi Canyon Area, and no evidence of

wrecks or other cultural debris were observed on the subbottom data. The shallow hazards analysis for the site and surrounding anchor radius will be performed by Berger Geosciences, LL C based on processed 3

- D data and submitted separately by
LLOG

.

No evidence of intact shipwreck sites was observed within the survey grid. No targets of potential archaeological significance were identified within the survey grid or within 2,000ft of the proposed surface location. No sonar targets were recorded within the survey grid, however several small point source/linear reflectors were recorded on sonar data, none of which are recommended for avoidance as potential cultural resources.TESLA OFFSHORE

LLOG Exploration Offshore, L.L.C. Proposed OCS-G 33764 Wells ‘A’ & ‘B’

Block 8 95 , Mississippi Canyon Area Archaeological Assessment Page 3

Geophysical data cannot detect all instances of archaeological or cultural resources. LLOG Exploration Offshore, L.L.C. and subcontractors will apply the safest and best available technologies during drilling operations and installation of future platforms. In compliance with 30 CFR 250.194(c), 30 CFR 250.1010(c), and NTL 2005-G07, if materials are observed during operations that could indicate the presence of a shipwreck, shipwreck site, or other potentially significant archaeological resource, operations will cease and the Regional Supervisor, Leasing and Environment with the BOEM/BSEE will be notified within 48 hours of discovery.

Sincerely,

Amanda Evans, RPA Marine Archaeologist36499 Perkins Road Prairieville, Louisiana 70769 Telephone: 225.673.2163

Fax: 225.744.3116
www.teslaoffshore.com

April 10, 2014 Job #13- 014

- 31

Bureau of Ocean Energy Management (MS 5230) Gulf of Mexico OCS Region

1201 Elmwood Park Blvd. New Orleans, LA 70123- 2394

RE: LLOG Exploration Offshore, L.L.C. Proposed OCS-G 33 764 Wells ‘ C ’ & ‘ D ’

Bl ock 8 95

, Mississippi Canyon Area Archaeological Assessment

Dear Staff:

LLOG Exploration Offshore, L.L.C. (LLOG) proposes to drill the OCS

- G 33 764 Well s ‘ C ’
and ‘ D ’ from the followi ng common surface location in Block 8 95

, Mississippi Canyon

Area:

Da tum:
NAD 27 Spheroid:

Clarke 1866 Projection:

UTM Zone:

16

. Central Meridian:

87° 00 ’ West

Latitude: 28° 04’ 10

. 310 ” N Longitude: 8 9 ° 12 ’ 46

. 655 ” W

X: 926, 906

. 11 Y: 10, 19 2

, 596

. 19

F S L: 7

, 4 76

. 19 ’ F E L: 7, 653

. 89 ’

This assessment addresses a radius of 2,000-feet around the proposed common surface location. LLOG proposes to drill the wells with a dynamically positioned rig, therefore no anchors will be deployed, and surface impacts will be restricted to the seafloor in the immediate vicinity of the borehole. Tesla Offshore, LLC surveyed all of

Block 8 95, with extended survey coverage in to Blocks 8 50, 851, 852, 894, 896, 938,
and 939, Mississippi Canyon Area. The survey was conducted in April and May of 2010 along a 300

- meter grid. The resulting archaeological assessment report was submitted

to Houston Energy L.P. under Tesla Job# 10

- 078

- 12

. LLOG contracted Tesla Offshore, LLC to provide this archaeological analysis ( NTL No. 2005

- G0 7

) in accordance with the Bureau of Ocean Energy Management (BOEM) Gulf of Mexico OCS Region.

Water depth is approximately 3, 825 feet surrounding the proposed drill site. Water depths increase from north ea st to south we st at the proposed well site at an approximate rate of 162 feet/mile

.

Seafloor soils

are reported to be silty clay and marine deposits (MMS 1983 Visual No. 3; MMS 1986 Visual No. 5).TESLA OFFSHORE

LLOG Exploration Offshore, L.L.C. Proposed OCS-G 33764 Wells ‘ C ’ & ‘ D ’

Block 8 95 , Mississippi Canyon Area Archaeological Assessment Page 2

Man-made features are not present within 2,000ft of the proposed surface location. There are only two installations in the entire survey grid. T he ATP 8”

- 10”” pipeline (Segment No. 16115) and the ATP 10”

- 12” pi peline (Segment 16127) are located approximately 12

, 000 ’ and 12

, 150 ’ feet N E of the proposed surface location, respectively

. Both pipelines were verified as

- built on the sonar data.

Magnetic data

is not required for survey in these water depths per NTL 2005-G07.

Sonar data recorded no targets of significance within the survey area. Sonar data recorded numerous fault scarps and several areas of increased backscatter reflectivity within the survey grid. The closest area of observed increased seafloor

re flectivity is located approximately 6

, 1 25 ’ N NE of the proposed surface location, while the nearest fault scarp is located approximately 3

, 375 ’ W of the proposed well

site. Sonar data also recorded several isolated point source or linear reflectors

within the survey grid . These were primarily located in clusters associated with fault

scarps or near the existing pipelines. The closest point source/linear reflector s are located approximately 7

, 575 ’ N E of the proposed surface location. Point source
reflecto rs seen on low frequency sonar are usually associated with small features near the threshold of sonar resolution. These features may represent small quantities of man

- made debris, or isolated natural features associated with changes in seafloor morphology . These are not interpreted as cultural resources and have
not been recommended for avoidance as such.

Supplemental Subbottom Data showed penetration in excess of 1 50 feet

, consisting of primarily parallel bedded, moderately reflecting sediments at the proposed well site. A fault zone was recorded within the survey area, located approximately 3

, 6 00 ’ WNW of the proposed surface area. A single, discrete fault

w as observed on the subbottom data approximately 1,525’ SE of the proposed
surface location at a depth of 40’ BML; observed displacement was 4’

. There is no potential for prehistoric sites in this portion of Mississippi Canyon Area, and no

evidence of wrecks or other cultural debris were observed on the subbottom data. The shallow hazards analysis for the site and surrounding anchor radius will be performed by Berger Geosciences, LLC based on processed 3

- D data and submitted separately by LLOG

.

No evidence of intact shipwreck sites was observed within the survey grid. No targets of potential archaeological significance were identified within the survey grid or within 2,000ft of the proposed surface location. No sonar targets were recorded within the survey grid, however several small point source/linear reflectors were recorded on sonar data, none of which are recommended for avoidance as potential cultural resources.TESLA OFFSHORE

LLOG Exploration Offshore, L.L.C. Proposed OCS-G 33764 Wells ‘ C ’ & ‘ D ’

Block 8 95 , Mississippi Canyon Area Archaeological Assessment Page 3

Geophysical data cannot detect all instances of archaeological or cultural resources. LLOG Exploration Offshore, L.L.C. and subcontractors will apply the safest and best available technologies during drilling operations and installation of future platforms. In compliance with 30 CFR 250.194(c), 30 CFR 250.1010(c), and NTL 2005-G07, if materials are observed during operations that could indicate the presence of a shipwreck, shipwreck site, or other potentially significant archaeological resource, operations will cease and the Regional Supervisor, Leasing and Environment with the BOEM/BSEE will be notified within 48 hours of discovery.

Sincerely,

Amanda Evans, RPA Marine Archaeologist36499 Perkins Road Prairieville, Louisiana 70769 Telephone: 225.673.2163

Fax: 225.744.3116
www.teslaoffshore.com

June 18, 2014 Job #13- 014

- 31

Bureau of Ocean Energy Management (MS 5230) Gulf of Mexico OCS Region

1201 Elmwood Park Blvd. New Orleans, LA 70123- 2394

RE: LLOG Exploration Offshore, L.L.C. Proposed OCS-G 33 764 Well ‘ G ’

Bl ock 8 95

, Mississippi Canyon Area Archaeological Assessment

Dear Staff:

LLOG Exploration Offshore, L.L.C. (LLOG) proposes to drill the OCS

- G 33 764 Well ‘ G ’

from the followi ng surface location in Block 8 95

, Mississippi Canyon Area:

Datum:

NAD 27 Spheroi d:

Clarke 1866 Projection:

UTM Zone:

16

. Central Meridian:

87° 00 ’ West

Latitude: 28° 04’ 42.68 0 ” N Longitude: 8 9 ° 12 ’ 32.885 ” W

X: 928

, 199

. 00 Y: 10, 19 5

, 843

. 00

F N L: 5,117.00 ’ F E L: 6,3 61.00 ’

This assessment addresses a radius of 2,000 feet around the proposed surface location. LLOG proposes to drill the well wi th a dynamically positioned rig; therefore, no anchors will be deployed, and surface impacts will be restricted to the seafloor in the immediate vicinity of the borehole. Tesla Offshore, LLC surveyed all of Block 8 95, with

extended survey coverage in to Blocks 8 50, 851, 852, 894, 896, 938, and 939, Mississippi Canyon Area. The survey was conducted in April and May of 2010 alon g a 300

- meter grid. The resulting archaeological assessment report was submitted to Houston Energy L.P. under Tesla Job# 10

- 078

- 12. LLOG contracted Tesla Offshore, LLC to provide this archaeological analysis ( NTL No. 2005

- G07

) in accordance with

the Bure au of Ocean Energy Management (BOEM) Gulf of Mexico OCS Region.

Water depth is approximately 3, 71 0 feet surrounding the proposed drill site. Water depths increase from north ea st to south we st at the proposed well site at an approximate rate of 1 80 feet/ mile

.

Seafloor soils

are reported to be marine deposits (USDI MMS Visual No. 5, 1986 ).TESLA OFFSHORE

LLOG Exploration Offshore, L.L.C. Proposed OCS- G 33764 Well ‘ G ’ Block 895, Mississippi Canyon Area Archaeological Assessment Page 2

Man-made features are not present within 2,000 feet of the proposed surface location. There are only two installations in the entire survey grid. T he ATP 8”

- 10” pipeline (Segment No. 16115) and the ATP 10”

- 12” pipeline (Segment 16127) are located approximately 8,490 ’ and 8,66 0 ’ feet N E of the proposed surface location at their closest points

, respectively

. Both pipelines were verified as

- built on the sonar

data.

Magnetic data

is not required for survey in these water depths per NTL 2005-G07.

Sonar data recorded no targets of significance within the survey area. Sonar data recorded numerous fault scarps and several areas of increased backscatter reflectivity within the survey grid. The closest area of observed increased seafloor reflectivity is located approximately 2

, 76 0 ’ north of the proposed surface location, while the nearest fault scarp is located approximately 2,520 ’ NE of the proposed well

site ; the fault scarp exhibits approximately 20 ’ of displacement towards the

south west based on measurements from subbottom data

. Sonar data also recorded several isolated point source or linear reflectors within the survey grid . These were primarily located in clusters associated with fault scarps or near the existing pipelines. The closest point source/linear reflector is locat ed approximately 4,580 ’

N N E of the proposed surface location. Point source reflectors seen on low frequency sonar are usually associated with small features near the threshold of sonar resolution. These features may represent small quantities of man

- made debris, or isolated natural features associated with changes in seafloor morphology. These are not interpreted as cultural resources and have not been recommended for

avoidance as such.

Supplemental Subbottom Data showed penetration in excess of 1 50 f eet

, consisting of primarily parallel bedded, moderately reflecting sediments at the proposed well site. An int erpreted fault zone was mapped throughout the survey area which lies approximately 1,780 feet NNE of the proposed surface location at its

closes t point

. No surface faults were observed within 2,000 feet of the proposed surface location. The closest is located approximately 2,540 feet to the NNE and exhibits approximately 20 feet of displacement to the SW. Possible instances of

near

- surface gas were recorded within the fault zone, the closest occurrence of

which is located approximately 4,63 0 feet WNW of the proposed well site at a depth
of 5 feet BML

. There is no potential for prehistoric sites in this portion of Mississippi Canyon Area, and no evidence of wrecks or other cultural debris were observed on

the subbottom data. The shallow hazards analysis for the site and surrounding anchor radius will be performed by Berger Geosciences, LLC based on processed 3

- D data and submitted separately by LLOG

.

No evidence of intact shipwreck sites was observed within the survey grid. No targets of potential archaeological significance were identified within the survey grid or withinTESLA OFFSHORE

LLOG Exploration Offshore, L.L.C. Proposed OCS- G 33764 Well ‘ G ’ Block 895, Mississippi Canyon Area Archaeological Assessment Page 3

2,000 feet of the proposed surface location. No sonar targets were recorded within the survey grid; however, several small point source/linear reflectors were recorded on sonar data, none of which are recommended for avoidance as potential cultural

resources.

Geophysical data cannot detect all instances of archaeological or cultural resources. LLOG Exploration Offshore, L.L.C. and subcontractors will apply the safest and best available technologies during drilling operations and installation of future platforms. In compliance with 30 CFR 550.194(c), 30 CFR 550.1010(c), and NTL 2005-G07, if materials are observed during operations that could indicate the presence of a shipwreck, shipwreck site, or other potentially significant archaeological resource, operations will cease and the Regional Supervisor, Leasing and Environment with the BOEM/BSEE will be notified within 48 hours of discovery.

Sincerely,

Erin Voisin, MA ArchaeologistMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 17 

# High Resolution Seismic Lines

Attachment C-6 (Proprietary Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 18 

# Stratigraphic Column

Attachment C-7 (Proprietary Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 19 

## APPENDIX D

HYDROGEN SULFIDE (H2S) INFORMATION (30 CFR Part 250.215 and 250.245)

A. Concentration

LLOG does not anticipate encountering H2S while conducting the proposed exploratory operations provided for under this plan.



## B. Classification

In accordance with 30 CFR 250.490 (c) and NTL No. 2009-G31 “Hydrogen Sulfide”, LLOG requests that the proposed locations be classified H2S absent.



## C. H2S Contingency Plan

Not applicable for the proposed operations.



## D. Modeling Report

Not applicable to the proposed operations.

## APPENDIX E BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION (30 CFR Part 550.216 and 5 50.247 )

A. High

- Density Deepwater Benthic Comm unities Information

Proposed Wells MC 895

- A&B are located in the north central portion of MC 895. T he seafloor in this area slopes to the southwest. Water depths within the muds and cuttings discharge area for the proposed wells range from 3,652 ft to 3,805 ft bsl .

There are no seafloor faults within 2,000 ft of the proposed wells’ location.

There is no evidence of fluid migration to the seafloor within 2,000 ft of Proposed Wells MC

895

- A&B.

Features or areas that could support high

- density chemosynthetic or other benthic communities are not anticipated within the proposed muds and cuttings discharge area.

Proposed Wells MC 895

- C is located in the central portion of MC 895. The seafloor in this area slopes to the southwest. Water depths within the muds and cuttings discharge area for the proposed wells range from 3,747 ft to 3,852 ft bsl .

There are no seafloor faults within 2,000 ft of the proposed wells’ location.

There is no evidence of fluid migration to the seafloor within 2,000 ft of Proposed Wells MC

895

- C.

Features or areas that could support high

- density chemosynthetic or other benthic

comm unities are not anticipated within the proposed muds and cuttings discharge area.

Proposed Well MC 895

- G is located in the north central portion of MC 895 . The seafloor in this area slopes to the southwest. Water depths within the muds and cut tings discharge area for the proposed well range from 3,634 ft to 3,805 ft bsl .

There are no seafloor faults within 2,000 ft of the proposed well location.

There is no evidence of fluid migration to the seafloor within 2,000 ft of Proposed Well MC 895

- G

.

Features or areas that could support high

- density chemosynthetic or other benthic communities are not anticipated within the proposed muds and cuttings discharge area.

## B. Topographic Features Map

The activities proposed in this Plan are not affected b y a topographic feature.



## C. T opographic Features Statement (Shunting)

The activities proposed in this Plan are not affected by a topographic feature; therefore, LLOG is not required to shunt drill cuttings and drill fluids.



## D. Live Bottoms (Pinnacle Trend) Ma p

Mississippi Canyon Block 895 is not located within the vicinity of a proposed live bottom (Pinnacle trend) area.



## E. Live Bottoms (Low Relief) Map

Mississippi Canyon Block 895 is no t located within the vicinity of a proposed live bottom (Low Relief) area.



## F. Potentially Sensitive Biologic al Features Map

Mississippi Canyon Block 895 is not located within the vicinity of a proposed sensitive biological feature area.



## G. Remotely Operated Vehicle (ROV) Monitoring Survey Plan

Mississippi Canyon Block 895 is loc ated in Grid 1 3 an area for which there is adequate coverage and does not require a R OV survey.

H. 

## Threatened or Endangered Species, Critical Habitat, and Marine

Mammal Information

.

Proposed activities in Mississippi Canyon Block 8 95 are not located in a critical habitat designated under ESA and marine mammals protected under the MMPA. In the event federally listed species become present on MC 8 95 , LLOG will mitigate impact through compliance with NTL 2012

- G01, G02 and NTL 2012 BSEE

- G01. See Attachmen t E

- 1

for a list of the NOAA Species k nown in the Gulf of Mexico.

### I

. 

## Archaeological Report

An Archaeological Deep Tow Survey, Block 895, Mississippi Canyon Area, OCS

- G 33764 was prepared by Tesla Offshore, LLC in June, 2010 for Houston Ene rgy, L.P. and submitted to BOEM by LLOG Exploration Offshore, L.L.C. on June 4, 2013. Berger Geosciences, LLC conducted a Shallow Hazards Assessment, Benthic Communities Evaluation, and Archaeological Resource Survey for Mississippi Canyon Block 895,

OCS

- G 33764 on behalf of LLOG Exploration Offshore, Inc. submitted to BOEM on August 18, 2014.



## J. Air and Water Quality Information

Not applicable to proposed operations.



## K. Socioeconomic Information

No t applicable to proposed operations.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 22 

# NOAA Species Known in GOM

Attachment E-1 (Public Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 23 

## APPENDIX F

WASTE AND DISCHARGE INFORMATION (30 CFR PART 550.217 AND 550.248)

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 895

Projected generated waste Projected ocean discharges

Type of Waste Composition Projected Amount Discharge rate Discharge Method Answer yes or no Will drilling occur ? If yes, fill in the muds and cuttings

.

EXAMPLE: Cuttings wetted with synthetic based fluid 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 89,984 bbls/well 10,150 bbls/day/well Discharge overboard No

Cuttings wetted with water-based fluid C utt i ngs generate d w hil e us i ng water based drilling fluid. 4,532 bbls/well 511 bbls/day/well Discharge overboard No

Cuttings wetted with synthetic-based fluid Cuttings generated while using synthetic based drilling fluid. 5,599 bbls/well 326 bbls/day/well Discharge overboard No

Will humans be there? If yes, expect conventional wast e

EXAMPLE: Sanitary waste water Sanitary waste from living quarters X bbl/well X bbl/hr/well chlorinate and discharge

overboard No

Domestic waste Misc waste for living quarters 29,459 bbls/well 2.7 bbls/hr/well Discharge overboard (no free oil) No

Sanitary waste Processed sanitary waste from living quarters 19,639 bbls/well 1.8 bbls/hr/well Chlorinate and discharge

overboard No

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

Deck Drainage Accumulated drainage due to rainfall 0 to 47,261 bbls/well 0 to 167 bbls/hr/well Test for oil and grease and discharge overboard No

Will you conduct well treatment, completion, or workover?

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

Well completion fluids Clear brines used for completion operations 500 bbls/well 100 bbls/hr/well Test for oil and grease and discharge overboard. This

excludes clear brines

containing Zinc No

Workover fluids NA NA NA NA NA

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

Desalinization unit discharge Uncontaminated spent seawater used for potable

water generation unit 0 to 100,000 bbls/well 60 bbls/hr/well Discharge overboard No

Blowout prevent fluid Treated freshwater used control of subsea blowout preventers 0 to 100 bbls/well 5 bbls/hr/well Discharge at seafloor No

Ballast water Uncontaminated seawater used for ballast control 0 to 100,000 bbls/well 16,350 bbls/hr/well Discharge overboard No

Bilge water NA NA NA NA NA

Excess cement at seafloor Excess cement slurry and mixwater used for cementing operation - NPDES allowed 300 bbls/well 360 bbls/hr/well Discharge at mudline No

Fire water Uncontaminated seawater used for fire control system 0 to 10,000 bbls/well 16,350 bbls/hr/well Discharge overboard No

Cooling water Uncontaminated seawater used for heat exchanger operations

used to cool machinery 0 to 400,000 bbls/well 120 bbls/hr/well Discharge overboard No

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

.

Produced water N A N A N A N A N A

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

Comply with the requirements of the NPDES permit. NOTE: If you will not have a type of waste, enter NA in the row.

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

Projected

DownholePlease specify whatever the amount reported is a total or per wellMC 895Projectedgenerated wasteSolidandLiquidWastsesTransportationType of WasteCompositionTransport MethodName/Location of Facility Amount Disposal MethodNewport EnvironmentalServices Inc., Ingleside, TX X bbl/well RecycledOil-based drilling fluid or mudNANANANANASynthetic-based drilling fluid or mudInternal olifin, ester nbasedmudBarged in 25 bbls cutting boxesand / or liquid mud tanks forsupply vesselsNewpark Transfer Station,Fourchon, LA6750 bbls / well RecycledCuttings wetted with Water-based fluidNANANANANACuttings wetted with Synthetic-based fluidNANANANANACuttings wetted with oil-based fluidsNANANANANAWill you produce hydrocarbons? If yes fill in for produced sandProduced sandNANANANANAEXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage binARC, New Iberia, LA X lb/well RecycledTrash and debrisPlastic, paper, aluminum Barged in a storage binBlanchard Landfill, GoldenMeadows, LA4000 lbs / well RecycledUsed oilSpent oil from machineryBarged in USCG approvedtransfer tote tanks.L&L Services, Fourchon, LA 200 bbls / well RecycledWash waterWash water w/ SBM residueand surfactantsBarged in 25 bbls cutting boxesand / or liquid mud tanks forsupply vesselsNewpark Transfer Station,Fourchon, LA2000 bbls / wellApproved disposal wellinjection or land farmChemical product wastesSpent treatment and / ordamaged chemicals used inoperationsBarged in 25 bbls cutting boxesand / or cutting boxesL&L Services, Fourchon, LA 10 bbls / well RecycledNOTE: If you will not have a type of waste, enter NA in the row.TABLE 2. WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHOREWill you have additional wastes that are not permitted for discharge? IfWaste DisposalMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 24 

## APPENDIX G

AIR EMISSIONS INFORMATION (30 CFR PART 550.218AND 550.249)

A. Emissions Worksheets and Screening Questions

The Projected Quality Emissions Report (Form MMS-138) addresses the proposed drilling, completion and potential testi ng operations utilizi ng a typical semisubmersible drilling unit, with related support vesse ls and construction barge

information.

As evidenced by Attachment G-1, the worksheets were completed based on the proposed flaring and burning operations.

Screening Questions for EP’s Yes No
Is any calculated Complete Total (CT) Emis sion amount (in tons associated with your proposed exploration activities more than 90% of the amounts calculated using the following formulas: CT = 3400D(2/3) for CO, and CT = 33.3D for the other air pollutants (where D = distance to shore in miles)? X

Does your emission calculations include any emission reduction measures or modified

emission factors? X

Are your proposed exploration activities loca ted east of 87.5 degrees W longitude? X Do you expect to encounter H2S at concentrations greater than 20 parts per million (ppm)? X

Do you propose to flare or vent natural gas for more than 48 continuous hours from any proposed well? X

Do you propose to burn produced hydrocarbon liquids? X



## B. Emissions Reduction Measures

The projected air emissions are not within th e exemption level; therefore, see the actual fuel usage tables and fuel recap sheets following the spreadsheets.



## C. Verification of Nondefault Emissions Factors

LLOG has elected to use the actu al fuel usage as provided in Attachment G-1.



## D. Non-Exempt Activities

The proposed activities are no t within the exemp tion amount; therefore, see the actual fuel usage tables and fuel recap sheets fo llowing the spreadsheets as provided in

Attachment G-1.



## E. Modeling Report

This section of the Plan is not a pplicable to the proposed operations.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 25 

# Air Quality Emissions Report

Attachment G-1 (Public Information)EXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2014COMPANYLLOG Exploration Offshore, L.L.C.AREAMississippi CanyonBLOCK895LEASEOCS-G 33764PLATFORMWELLA, B, C & GCOMPANY CONTACTKathy GowlandTELEPHONE NO.895-801-4300REMARKSDP Semisubmersible Rig - Actual Fuel AttachedFORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 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 Turbinesgms/hp-hr0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle leangms/hp-hr0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle leangms/hp-hr0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle richgms/hp-hr0.00185 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 Boilerlbs/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 Flareslbs/mmscf0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaringlbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vaporslbs/bbl0.03E&P Forum 1/93Fugitiveslbs/hr/comp.0.0005API Study 12/93Glycol Dehydrator Ventlbs/mmscf6.6La. DEQ1991Gas Ventinglbs/scf0.0034Sulphur Content Source Value UnitsFuel Gas3.33 ppmDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightFORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 2 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSLLOG Exploration OffshorMississippi Canyon895 OCS-G 33764 A, B, C & GKathy Gowland895-801-4300 DP Semisubmersible RigOPERATIONSEQUIPMENTRATING 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 CODRILLING PRIME MOVER>600hp diesel 56322 2720.3526 22158.00 24 73 39.70 182.12 1364.63 40.94 297.74 11.80 54.14 405.71 12.17 88.52DP SemisubmersiblePRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Actual Fuel AttachedPRIME MOVER>600hp diesel00 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 diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.003 x per week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6 31 5.07 23.28 174.45 5.23 38.06 0.47 2.17 16.22 0.49 3.546 x per week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 63 5.07 23.28 174.45 5.23 38.06 1.60 7.33 54.95 1.65 11.99VESSELS>600hp diesel(tugs)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 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 diesel00 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) 00 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) 00 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-00 00.000.00DRILLING OIL BURN00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE00 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL49.85 228.68 1713.53 51.41 373.86 13.87 63.64 476.88 14.31 104.05EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1964.70 1964.70 1964.70 1964.70 51528.4359.0FORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 3 of 8EMISSIONS CALCULATIONS 2ND YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSLLOG Exploration OffshorMississippi Canyon895 OCS-G 33764 A, B, C & GKathy Gowland895-801-4300 DP SemisubmersibleOPERATIONSEQUIPMENTRATING 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 CODRILLING PRIME MOVER>600hp diesel 56322 2720.3526 22158.00 24.00 163.00 39.70 182.12 1364.63 40.94 297.74 26.35 120.90 905.90 27.18 197.65DP SemisubmersiblePRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Actual Fuel AttachedPRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.003 x per week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6.00 70.00 5.07 23.28 174.45 5.23 38.06 1.07 4.89 36.63 1.10 7.996 x per week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10.00 140.00 5.07 23.28 174.45 5.23 38.06 3.55 16.30 122.11 3.66 26.64VESSELS>600hp diesel(tugs)00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK-0000.000.00DRILLING OIL BURN000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE0000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002016 YEAR TOTAL49.85 228.68 1713.53 51.41 373.86 30.97 142.08 1064.64 31.94 232.29EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1964.70 1964.70 1964.70 1964.70 51528.4359.0FORM BOEM-0138December 2011- Supersedes all previous versions of form BOEM-0138 which may not be used).Page 4 of 8EMISSIONS CALCULATIONS 3RD YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSLLOG Exploration OffshorMississippi Canyon895 OCS-G 33764 A, B, C & GKathy Gowland895-801-4300 DP Semisubmersible RigOPERATIONSEQUIPMENTRATING 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 CODRILLING PRIME MOVER>600hp diesel 56322 2720.3526 22158.00 24 224 39.70 182.12 1364.63 40.94 297.74 36.22 166.14 1244.91 37.35 271.62DP SemisubmersiblePRIME MOVER>600hp diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Actual Fuel AttachedPRIME MOVER>600hp diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.003 x per week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 696 5.07 23.28 174.45 5.23 38.06 1.46 6.70 50.24 1.51 10.966 x per week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 192 5.07 23.28 174.45 5.23 38.06 4.87 22.35 167.47 5.02 36.54VESSELS>600hp diesel(tugs)00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK-0000.000.00DRILLING OIL BURN000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE0000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002017 YEAR TOTAL49.85 228.68 1713.53 51.41 373.86 42.55 195.19 1462.62 43.88 319.12EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1964.70 1964.70 1964.70 1964.70 51528.4359.0FORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 5 of 8SUMMARYCOMPANY AREABLOCKLEASEPLATFORM WELLLLOG ExploratioMississippi Canyon 895OCS-G 33764A, B, C & GEmittedSubstanceYearDP Semisubmersible RigPMSOxNOxVOCCO2015 13.8763.64476.8814.31104.052016 30.97142.08 1064.64 31.94232.292017 42.55195.19 1462.62 43.88319.12Allowable1964.70 1964.70 1964.70 1964.70 51528.43FORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 8 of 8

# Sevan Louisiana: Fuel consumption

1/10/2014 36 m3 9510.12 gal

1/11/2014 84 m3 22190.28 gal

1/12/2014 180 m3 47550.6 gal

1/13/2014 127 m3 33549.59 gal

1/14/2014 118 m3 31172.06 gal

1/15/2014 118 m3 31172.06 gal

1/16/2014 126 m3 33285.42 gal

1/17/2014 96 m3 25360.32 gal

1/18/2014 94 m3 24831.98 gal

1/19/2014 109 m3 28794.53 gal

1/20/2014 102 m3 26945.34 gal

1/21/2014 111 m3 29322.87 gal

1/22/2014 98 m3 25888.66 gal

1/23/2014 94 m3 24831.98 gal

1/24/2014 101 m3 26681.17 gal

1/25/2014 70 m3 18491.9 gal

1/26/2014 108 m3 28530.36 gal

1/27/2014 64 m3 16906.88 gal

1/28/2014 93 m3 24567.81 gal

1/29/2014 85 m3 22454.45 gal

1/30/2014 69 m3 18227.73 gal

1/31/2014 62 m3 16378.54 gal

2/1/2014 86 m3 22718.62 gal

2/2/2014 140 m3 36983.8 gal

2/3/2014 131 m3 34606.27 gal

2/4/2014 49 m3 12944.33 gal2/5/2014 10 m3 2641.7 gal

2/6/2014 25 m3 6604.25 gal

2/7/2014 278 m3 73439.26 gal

2/8/2014 166 m3 43852.22 gal

2/9/2014 24 m3 6340.08 gal

2/10/2014 120 m3 31700.4 gal

2/11/2014 28 m3 7396.76 gal

2/12/2014 86 m3 22718.62 gal

2/13/2014 50 m3 13208.5 gal

2/14/2014 53 m3 14001.01 gal

2/15/2014 28 m3 7396.76 gal

2/16/2014 79 m3 20869.43 gal

2/17/2014 102 m3 26945.34 gal

2/18/2014 133 m3 35134.61 gal

2/19/2014 125 m3 33021.25 gal

2/20/2014 147 m3 38832.99 gal

2/21/2014 153 m3 40418.01 gal

2/22/2014 150 m3 39625.5 gal

2/23/2014 133 m3 35134.61 gal

2/24/2014 71 m3 18756.07 gal

2/25/2014 77 m3 20341.09 gal

2/26/2014 105 m3 27737.85 gal

2/27/2014 102 m3 26945.34 gal

2/28/2014 102 m3 26945.34 gal

3/1/2014 153 m3 40418.01 gal

3/2/2014 91 m3 24039.47 gal

3/3/2014 150 m3 39625.5 gal

3/4/2014 138 m3 36455.46 gal

3/5/2014 137 m3 36191.29 gal

3/6/2014 96 m3 25360.32 gal

3/7/2014 104 m3 27473.68 gal

3/8/2014 130 m3 34342.1 gal

3/9/2014 125 m3 33021.25 gal

3/10/2014 81 m3 21397.77 gal

3/11/2014 126 m3 33285.42 gal

3/12/2014 126 m3 33285.42 gal

3/13/2014 99 m3 26152.83 gal3/14/2014 116 m3 30643.72 gal

3/15/2014 103 m3 27209.51 gal
3/16/2014 116 m3 30643.72 gal
3/17/2014 106 m3 28002.02 gal

3/18/2014 73 m3 19284.41 gal 3/19/2014 117 m3 30907.89 gal
3/20/2014 123 m3 32492.91 gal

3/21/2014 91 m3 24039.47 gal

3/22/2014 127 m3 33549.59 gal 3/23/2014 118 m3 31172.06 gal

3/24/2014 22.4 m3 5917.408 gal

3/25/2014 32.6 m3 8611.942 gal

3/26/2014 46 m3 12151.82 gal

3/27/2014 33.3 m3 8796.861 gal

3/28/2014 48 m3 12680.16 gal

3/29/2014 40 m3 10566.8 gal

3/30/2014 43 m3 11359.31 gal

3/31/2014 11 m3 2905.87 gal

4/1/2014 59 m3 15586.03 gal

4/2/2014 60 m3 15850.2 gal

4/3/2014 20 m3 5283.4 gal

4/4/2014 67 m3 17699.39 gal

4/5/2014 71 m3 18756.07 gal

4/6/2014 65 m3 17171.05 gal

4/7/2014 97 m3 25624.49 gal

4/8/2014 105 m3 27737.85 gal

4/9/2014 73 m3 19284.41 gal
4/10/2014 108 m3 28530.36 gal
4/11/2014 101 m3 26681.17 gal
4/12/2014 117 m3 30907.89 gal
4/13/2014 117 m3 30907.89 gal
4/14/2014 52 m3 13736.84 gal
4/15/2014 100 m3 26417 gal
4/16/2014 93 m3 24567.81 gal
4/17/2014 87 m3 22982.79 gal
4/18/2014 32 m3 8453.44 gal
4/19/2014 26 m3 6868.42 gal
4/20/2014 20 m3 5283.4 gal
4/21/2014 63 m3 16642.71 gal
4/22/2014 51 m3 13472.67 gal
4/23/2014 23 m3 6075.91 gal
4/24/2014 41 m3 10830.97 gal
4/25/2014 27 m3 7132.59 gal4/26/2014 45 m3 11887.65 gal
4/27/2014 45 m3 11887.65 gal
4/28/2014 18 m3 4755.06 gal
4/29/2014 18 m3 4755.06 gal
4/30/2014 62 m3 16378.54 gal

5/1/2014 33 m3 8717.61 gal
5/2/2014 48.6 m3 12838.662 gal
5/3/2014 32.4 m3 8559.108 gal
5/4/2014 36 m3 9510.12 gal
5/5/2014 20.8 m3 5494.736 gal
5/6/2014 1341 m3 354251.97 gal
5/7/2014 28 m3 7396.76 gal
5/8/2014 28 m3 7396.76 gal
5/9/2014 28 m3 7396.76 gal
5/10/2014 42 m3 11095.14 gal
5/11/2014 42 m3 11095.14 gal
5/12/2014 29 m3 7660.93 gal
5/13/2014 32 m3 8453.44 gal
5/14/2014 20 m3 5283.4 gal
5/15/2014 36 m3 9510.12 gal
5/16/2014 25 m3 6604.25 gal
5/17/2014 43 m3 11359.31 gal
5/18/2014 37 m3 9774.29 gal
5/19/2014 20 m3 5283.4 gal
5/20/2014 14 m3 3698.38 gal
5/21/2014 40 m3 10566.8 gal
5/22/2014 30 m3 7925.1 gal
5/23/2014 28 m3 7396.76 gal
5/24/2014 27 m3 7132.59 gal
5/25/2014 31 m3 8189.27 gal
5/26/2014 28 m3 7396.76 gal
5/27/2014 37 m3 9774.29 gal
5/28/2014 27 m3 7132.59 gal
5/29/2014 41 m3 10830.97 gal
5/30/2014 42 m3 11095.14 gal
5/31/2014 23 m3 6075.91 gal

6/1/2014 23 m3 6075.91 gal
6/2/2014 32 m3 8453.44 gal
6/3/2014 28 m3 7396.76 gal
6/4/2014 41 m3 10830.97 gal
6/5/2014 24 m3 6340.08 gal
6/6/2014 53 m3 14001.01 gal
6/7/2014 22 m3 5811.74 gal
6/8/2014 42 m3 11095.14 gal
6/9/2014 27 m3 7132.59 gal
6/10/2014 41 m3 10830.97 gal
6/11/2014 46 m3 12151.82 gal6/12/2014 39 m3 10302.63 gal
6/13/2014 27 m3 7132.59 gal
6/14/2014 44 m3 11623.48 gal
6/15/2014 52 m3 13736.84 gal
6/16/2014 32 m3 8453.44 gal
6/17/2014 36 m3 9510.12 gal
6/18/2014 29 m3 7660.93 gal
6/19/2014 48 m3 12680.16 gal
6/20/2014 25 m3 6604.25 gal
6/21/2014 35 m3 9245.95 gal
6/22/2014 48 m3 12680.16 gal
6/23/2014 36 m3 9510.12 gal
6/24/2014 45 m3 11887.65 gal
6/25/2014 31 m3 8189.27 gal
6/26/2014 75 m3 19812.75 gal
6/27/2014 28 m3 7396.76 gal
6/28/2014 53 m3 14001.01 gal
6/29/2014 42 m3 11095.14 gal
6/30/2014 18 m3 4755.06 gal

7/1/2014 40 m3 10566.8 gal
7/2/2014 66 m3 17435.22 gal
7/3/2014 37 m3 9774.29 gal
7/4/2014 32 m3 8453.44 gal
7/5/2014 31 m3 8189.27 gal
7/6/2014 37 m3 9774.29 gal
7/7/2014 52 m3 13736.84 gal
7/8/2014 29 m3 7660.93 gal
7/9/2014 43 m3 11359.31 gal
7/10/2014 33 m3 8717.61 gal
7/11/2014 44 m3 11623.48 gal
7/12/2014 36 m3 9510.12 gal
7/13/2014 33 m3 8717.61 gal
7/14/2014 53 m3 14001.01 gal
7/15/2014 47 m3 12415.99 gal
7/16/2014 55 m3 14529.35 gal
7/17/2014 30 m3 7925.1 gal
7/18/2014 38 m3 10038.46 gal
7/19/2014 37 m3 9774.29 gal
7/20/2014 47 m3 12415.99 gal
7/21/2014 92 m3 24303.64 gal
7/22/2014 30 m3 7925.1 gal
7/23/2014 46 m3 12151.82 gal
7/24/2014 26 m3 6868.42 gal
7/25/2014 52 m3 13736.84 gal
7/26/2014 52 m3 13736.84 gal
7/27/2014 49 m3 12944.33 gal
7/28/2014 52 m3 13736.84 gal7/29/2014 31 m3 8189.27 gal
7/30/2014 40 m3 10566.8 gal
7/31/2014 46 m3 12151.82 gal

8/1/2014 63 m3 16642.71 gal
8/2/2014 32 m3 8453.44 gal
8/3/2014 51 m3 13472.67 gal
8/4/2014 95 m3 25096.15 gal
8/5/2014 32 m3 8453.44 gal
8/6/2014 32 m3 8453.44 gal
8/7/2014 31 m3 8189.27 gal
8/8/2014 54 m3 14265.18 gal
8/9/2014 32 m3 8453.44 gal
8/10/2014 50 m3 13208.5 gal
8/11/2014 33 m3 8717.61 gal
8/12/2014 41.5 m3 10963.055 gal
8/13/2014 30 m3 7925.1 gal
8/14/2014 42 m3 11095.14 gal
8/15/2014 30 m3 7925.1 gal
8/16/2014 16 m3 4226.72 gal
8/17/2014 36 m3 9510.12 gal
8/18/2014 36 m3 9510.12 gal
8/19/2014 43 m3 11359.31 gal
8/20/2014 37 m3 9774.29 gal
8/21/2014 41 m3 10830.97 gal
8/22/2014 38 m3 10038.46 gal
8/23/2014 34 m3 8981.78 gal
8/24/2014 44 m3 11623.48 gal
8/25/2014 35 m3 9245.95 gal
8/26/2014 91 m3 24039.47 gal
8/27/2014 34 m3 8981.78 gal
8/28/2014 43 m3 11359.31 gal
8/29/2014 46 m3 12151.82 gal
8/30/2014 49 m3 12944.33 gal
8/31/2014 33 m3 8717.61 gal

9/1/2014 36 m3 9510.12 gal
9/2/2014 36 m3 9510.12 gal
9/3/2014 37 m3 9774.29 gal
9/4/2014 34 m3 8981.78 gal
9/5/2014 29 m3 7660.93 gal
9/6/2014 34 m3 8981.78 gal
9/7/2014 29 m3 7660.93 gal
9/8/2014 31 m3 8189.27 gal
9/9/2014 29 m3 7660.93 gal
9/10/2014 40 m3 10566.8 gal
9/11/2014 33 m3 8717.61 gal
9/12/2014 28 m3 7396.76 gal
9/13/2014 37 m3 9774.29 gal9/14/2014 35 m3 9245.95 gal
9/15/2014 26 m3 6868.42 gal
9/16/2014 34 m3 8981.78 gal
9/17/2014 35 m3 9245.95 gal
9/18/2014 31 m3 8189.27 gal
9/19/2014 31 m3 8189.27 gal
9/20/2014 40 m3 10566.8 gal
9/21/2014 52 m3 13736.84 gal
9/22/2014 54 m3 14265.18 gal
9/23/2014 35 m3 9245.95 gal
9/24/2014 41 m3 10830.97 gal
9/25/2014 20 m3 5283.4 gal
9/26/2014 42 m3 11095.14 gal
9/27/2014 44 m3 11623.48 gal
9/28/2014 31 m3 8189.27 gal
9/29/2014 37 m3 9774.29 gal
9/30/2014 39 m3 10302.63 gal
10/1/2014 50 m3 13208.5 gal
10/2/2014 41 m3 10830.97 gal
10/3/2014 31 m3 8189.27 gal
10/4/2014 37 m3 9774.29 gal
10/5/2014 33 m3 8717.61 gal
10/6/2014 43 m3 11359.31 gal
10/7/2014 54 m3 14265.18 gal
10/8/2014 29 m3 7660.93 gal
10/9/2014 39 m3 10302.63 gal
10/10/2014 19 m3 5019.23 gal
10/11/2014 43 m3 11359.31 gal
10/12/2014 m3 264.17 gal
10/13/2014 43 m3 11359.31 gal
10/14/2014 37 m3 9774.29 gal
10/15/2014 45 m3 11887.65 gal
10/16/2014 43 m3 11359.31 gal
10/17/2014 21 m3 5547.57 gal
10/18/2014 69 m3 18227.73 gal
10/19/2014 40 m3 10566.8 gal
10/20/2014 48 m3 12680.16 gal
10/21/2014 38 m3 10038.46 gal
10/22/2014 48 m3 12680.16 gal
10/23/2014 36 m3 9510.12 gal
10/24/2014 36 m3 9510.12 gal
10/25/2014 26 m3 6868.42 gal
10/26/2014 26 m3 6868.42 gal
10/27/2014 m3 264.17 galEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2014COMPANYLLOG Exploration Offshore, L.L.C.AREAMississippi CanyonBLOCK895LEASEOCS-G 33764PLATFORMWELLA, B, C & GCOMPANY CONTACTKathy GowlandTELEPHONE NO.895-801-4300REMARKSDrillship - Actual Fuel AttachedFORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 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 Turbinesgms/hp-hr0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle leangms/hp-hr0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle leangms/hp-hr0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle richgms/hp-hr0.00185 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 Boilerlbs/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 Flareslbs/mmscf0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaringlbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vaporslbs/bbl0.03E&P Forum 1/93Fugitiveslbs/hr/comp.0.0005API Study 12/93Glycol Dehydrator Ventlbs/mmscf6.6La. DEQ1991Gas Ventinglbs/scf0.0034Sulphur Content Source Value UnitsFuel Gas3.33 ppmDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightFORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 2 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSLLOG Exploration OffshorMississippi Canyon895 OCS-G 33764 A, B, C & GKathy Gowland895-801-4300 DrillshipOPERATIONSEQUIPMENTRATING 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 CODRILLING PRIME MOVER>600hp diesel 59004 2849.8932 20124.00 24 73 41.59 190.79 1429.61 42.89 311.92 10.72 49.17 368.47 11.05 80.39DrillshipPRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Actual Fuel AttachedPRIME MOVER>600hp diesel00 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 diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.003 x per week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6 31 5.07 23.28 174.45 5.23 38.06 0.47 2.17 16.22 0.49 3.546 x per week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 63 5.07 23.28 174.45 5.23 38.06 1.60 7.33 54.95 1.65 11.99VESSELS>600hp diesel(tugs)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 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 diesel00 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) 00 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) 00 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-00 00.000.00DRILLING OIL BURN00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE00 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL51.74 237.35 1778.51 53.36 388.04 12.79 58.67 439.64 13.19 95.92EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1964.70 1964.70 1964.70 1964.70 51528.4359.0FORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 3 of 8EMISSIONS CALCULATIONS 2ND YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSLLOG Exploration OffshorMississippi Canyon895 OCS-G 33764 A, B, C & GKathy Gowland895-801-4300 DrillshipOPERATIONSEQUIPMENTRATING 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 CODRILLING PRIME MOVER>600hp diesel 59004 2849.8932 20124.00 24.00 163.00 41.59 190.79 1429.61 42.89 311.92 23.93 109.80 822.74 24.68 179.51DrillshipPRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Actual Fuel AttachedPRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.003 x per week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6.00 70.00 5.07 23.28 174.45 5.23 38.06 1.07 4.89 36.63 1.10 7.996 x per week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10.00 140.00 5.07 23.28 174.45 5.23 38.06 3.55 16.30 122.11 3.66 26.64VESSELS>600hp diesel(tugs)00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK-0000.000.00DRILLING OIL BURN000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE0000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002016 YEAR TOTAL51.74 237.35 1778.51 53.36 388.04 28.55 130.98 981.49 29.44 214.14EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1964.70 1964.70 1964.70 1964.70 51528.4359.0FORM BOEM-0138December 2011- Supersedes all previous versions of form BOEM-0138 which may not be used).Page 4 of 8EMISSIONS CALCULATIONS 3RD YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSLLOG Exploration OffshorMississippi Canyon895 OCS-G 33764 A, B, C & GKathy Gowland895-801-4300 DrillshipOPERATIONSEQUIPMENTRATING 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 CODRILLING PRIME MOVER>600hp diesel 59004 2849.8932 20124.00 24 224 41.59 190.79 1429.61 42.89 311.92 32.89 150.89 1130.63 33.92 246.68DrillshipPRIME MOVER>600hp diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Actual Fuel AttachedPRIME MOVER>600hp diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.003 x per week VESSELS>600hp diesel(crew) 7200 347.76 8346.24 696 5.07 23.28 174.45 5.23 38.06 1.46 6.70 50.24 1.51 10.966 x per week VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 192 5.07 23.28 174.45 5.23 38.06 4.87 22.35 167.47 5.02 36.54VESSELS>600hp diesel(tugs)00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK-0000.000.00DRILLING OIL BURN000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE0000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002017 YEAR TOTAL51.74 237.35 1778.51 53.36 388.04 39.22 179.94 1348.35 40.45 294.18EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES1964.70 1964.70 1964.70 1964.70 51528.4359.0FORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 5 of 8SUMMARYCOMPANY AREABLOCKLEASEPLATFORM WELLLLOG ExploratioMississippi Canyon 895OCS-G 33764A, B, C & GEmittedSubstanceYearDrillshipPMSOxNOxVOCCO2015 12.7958.67439.6413.1995.922016 28.55130.98 981.4929.44214.142017 39.22179.94 1348.35 40.45294.18Allowable1964.70 1964.70 1964.70 1964.70 51528.43FORM BOEM-0138December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used).Page 8 of 8

# West Auriga: Fuel Consumption

9/11/2013 24.7 m3 6524.999 gal

9/12/2013 22.6 m3 5970.242 gal

9/13/2013 24.4 m3 6445.748 gal

9/14/2013 22.6 m3 5970.242 gal

9/15/2013 25.8 m3 6815.586 gal

9/16/2013 26.5 m3 7000.505 gal

9/17/2013 20.4 m3 5389.068 gal

9/18/2013 34.4 m3 9087.448 gal

9/19/2013 20.2 m3 5336.234 gal

9/20/2013 23.9 m3 6313.663 gal

9/21/2013 21.9 m3 5785.323 gal

9/22/2013 31.1 m3 8215.687 gal

9/23/2013 20.4 m3 5389.068 gal
9/24/2013 25.2 m3 6657.084 gal
9/25/2013 23 m3 6075.91 gal
9/26/2013 36.3 m3 9589.371 gal
9/27/2013 22.8 m3 6023.076 gal
9/28/2013 27.9 m3 7370.343 gal
9/29/2013 32.4 m3 8559.108 gal
9/30/2013 29.6 m3 7819.432 gal
10/1/2013 26.9 m3 7106.173 gal
10/2/2013 38.9 m3 10276.213 gal
10/3/2013 42.2 m3 11147.974 gal
10/4/2013 49.6 m3 13102.832 gal
10/5/2013 72.9 m3 19257.993 gal
10/6/2013 43.6 m3 11517.812 gal
10/7/2013 99.4 m3 26258.498 gal
10/8/2013 36.5 m3 9642.205 gal
10/9/2013 46 m3 12151.82 gal
10/10/2013 26.2 m3 6921.254 gal
10/11/2013 77 m3 20341.09 gal
10/12/2013 68.1 m3 17989.977 gal
10/13/2013 38 m3 10038.46 gal
10/14/2013 37.4 m3 9879.958 gal
10/15/2013 34.3 m3 9061.031 gal
10/16/2013 47.2 m3 12468.824 gal
10/17/2013 35.6 m3 9404.452 gal
10/18/2013 36.7 m3 9695.039 gal
10/19/2013 36.5 m3 9642.205 gal
10/20/2013 35.9 m3 9483.703 gal
10/21/2013 34.6 m3 9140.282 gal
10/22/2013 36.9 m3 9747.873 gal
10/23/2013 76 m3 20076.92 gal
10/24/2013 37.5 m3 9906.375 gal10/25/2013 54 m3 14265.18 gal
10/26/2013 41.8 m3 11042.306 gal
10/27/2013 47.6 m3 12574.492 gal
10/28/2013 60.2 m3 15903.034 gal
10/29/2013 56.6 m3 14952.022 gal
10/30/2013 82.9 m3 21899.693 gal
10/31/2013 137.4 m3 36296.958 gal

11/1/2013 41.5 m3 10963.055 gal
11/2/2013 28.1 m3 7423.177 gal
11/3/2013 0 m3 0 gal
11/4/2013 41 m3 10830.97 gal
11/5/2013 50.3 m3 13287.751 gal
11/6/2013 40 m3 10566.8 gal
11/7/2013 40.9 m3 10804.553 gal
11/8/2013 31.4 m3 8294.938 gal
11/9/2013 43.7 m3 11544.229 gal
11/10/2013 40 m3 10566.8 gal
11/11/2013 37.9 m3 10012.043 gal
11/12/2013 40.1 m3 10593.217 gal
11/13/2013 39 m3 10302.63 gal
11/14/2013 34 m3 8981.78 gal
11/15/2013 40 m3 10566.8 gal
11/16/2013 41 m3 10830.97 gal
11/17/2013 32 m3 8453.44 gal
11/18/2013 34 m3 8981.78 gal
11/19/2013 35 m3 9245.95 gal
11/20/2013 41 m3 10830.97 gal
11/21/2013 37 m3 9774.29 gal
11/22/2013 18 m3 4755.06 gal
11/23/2013 68 m3 17963.56 gal
11/24/2013 28 m3 7396.76 gal
11/25/2013 39 m3 10302.63 gal
11/26/2013 28.1 m3 7423.177 gal
11/27/2013 32.7 m3 8638.359 gal
11/28/2013 28.6 m3 7555.262 gal
11/29/2013 31.3 m3 8268.521 gal
11/30/2013 25.4 m3 6709.918 gal

12/1/2013 45.9 m3 12125.403 gal
12/2/2013 37.8 m3 9985.626 gal
12/3/2013 36.4 m3 9615.788 gal
12/4/2013 39 m3 10302.63 gal
12/5/2013 34.4 m3 9087.448 gal
12/6/2013 28.4 m3 7502.428 gal
12/7/2013 34.7 m3 9166.699 gal
12/8/2013 36 m3 9510.12 gal
12/9/2013 34.9 m3 9219.533 gal
12/10/2013 32.7 m3 8638.359 gal12/11/2013 46.3 m3 12231.071 gal
12/12/2013 22.7 m3 5996.659 gal
12/13/2013 63.5 m3 16774.795 gal
12/14/2013 82 m3 21661.94 gal
12/15/2013 47.9 m3 12653.743 gal
12/16/2013 33.9 m3 8955.363 gal
12/17/2013 41.3 m3 10910.221 gal
12/18/2013 38 m3 10038.46 gal
12/19/2013 39 m3 10302.63 gal
12/20/2013 42 m3 11095.14 gal
12/21/2013 41 m3 10830.97 gal
12/22/2013 28 m3 7396.76 gal
12/23/2013 35 m3 9245.95 gal
12/24/2013 37 m3 9774.29 gal
12/25/2013 41 m3 10830.97 gal
12/26/2013 35 m3 9245.95 gal
12/27/2013 42 m3 11095.14 gal
12/28/2013 38 m3 10038.46 gal
12/29/2013 32 m3 8453.44 gal
12/30/2013 36 m3 9510.12 gal
12/31/2013 38 m3 10038.46 gal
1/1/2014 46 m3 12151.82 gal
1/2/2014 63 m3 16642.71 gal
1/3/2014 53 m3 14001.01 gal
1/4/2014 59 m3 15586.03 gal
1/5/2014 37 m3 9774.29 gal
1/6/2014 0 m3 0 gal
1/7/2014 0 m3 0 gal
1/8/2014 36.2 m3 9562.954 gal
1/9/2014 40.3 m3 10646.051 gal
1/10/2014 79.7 m3 21054.349 gal
1/11/2014 36.8 m3 9721.456 gal
1/12/2014 35.2 m3 9298.784 gal
1/13/2014 39.2 m3 10355.464 gal
1/14/2014 35.8 m3 9457.286 gal
1/15/2014 51.5 m3 13604.755 gal
1/16/2014 36.4 m3 9615.788 gal
1/17/2014 44.8 m3 11834.816 gal
1/18/2014 38.7 m3 10223.379 gal
1/19/2014 56.7 m3 14978.439 gal
1/20/2014 4.4 m3 1162.348 gal
1/21/2014 37.4 m3 9879.958 gal
1/22/2014 39.3 m3 10381.881 gal
1/23/2014 37.4 m3 9879.958 gal
1/24/2014 41.3 m3 10910.221 gal
1/25/2014 39.9 m3 10540.383 gal
1/26/2014 0 m3 0 gal1/27/2014 45.2 m3 11940.484 gal
1/28/2014 47 m3 12415.99 gal
1/29/2014 199 m3 52569.83 gal
1/30/2014 62 m3 16378.54 gal
1/31/2014 54 m3 14265.18 gal

2/1/2014 43 m3 11359.31 gal
2/2/2014 59 m3 15586.03 gal
2/3/2014 43 m3 11359.31 gal
2/4/2014 38 m3 10038.46 gal
2/5/2014 53 m3 14001.01 gal
2/6/2014 36 m3 9510.12 gal
2/7/2014 68 m3 17963.56 gal
2/8/2014 42 m3 11095.14 gal
2/9/2014 44 m3 11623.48 gal
2/10/2014 48 m3 12680.16 gal
2/11/2014 53 m3 14001.01 gal
2/12/2014 49 m3 12944.33 gal
2/13/2014 39 m3 10302.63 gal
2/14/2014 64 m3 16906.88 gal
2/15/2014 37 m3 9774.29 gal
2/16/2014 42 m3 11095.14 gal
2/17/2014 39 m3 10302.63 gal
2/18/2014 43.8 m3 11570.646 gal
2/19/2014 37.2 m3 9827.124 gal
2/20/2014 44.5 m3 11755.565 gal
2/21/2014 41.8 m3 11042.306 gal
2/22/2014 0 m3 0 gal
2/23/2014 39.2 m3 10355.464 gal
2/24/2014 40.8 m3 10778.136 gal
2/25/2014 37.8 m3 9985.626 gal
2/26/2014 36.7 m3 9695.039 gal
2/27/2014 40.9 m3 10804.553 gal
2/28/2014 33.8 m3 8928.946 gal

3/1/2014 0 m3 0 gal
3/2/2014 0 m3 0 gal
3/3/2014 36.5 m3 9642.205 gal
3/4/2014 37.3 m3 9853.541 gal
3/5/2014 43.1 m3 11385.727 gal
3/6/2014 41 m3 10830.97 gal
3/7/2014 38.3 m3 10117.711 gal
3/8/2014 41.7 m3 11015.889 gal
3/9/2014 40 m3 10566.8 gal
3/10/2014 0 m3 0 gal
3/11/2014 38.1 m3 10064.877 gal
3/12/2014 39 m3 10302.63 gal
3/13/2014 39 m3 10302.63 galMississippi Canyon Block 895

– OCS

- G 33764

Initial Exploration Plan 27 

## APPE NDIX H

OIL SPILL INFORMATION (30 CFR PART 5 50.219 AND 5 50.250)

A. 

## Oil Spill Response Planning

All the proposed activities in this Exploration Plan will be covered by the Oil Spill Response Plan filed by LLOG (MMS Operator No. 02058) in accordance with 3 0 CFR 254 Biennial update modification submitted June 30, 2014 and approved on August 15,

2014.

The WCD proposed in this Plan does exceed the WCD outlined in our OSRP. Therefore, LLOG Exploration Offshore, L.L.C. (LLOG) is submitting the new worst

case scenario to BOEM within 15 days of this Plan submittal for inclusion in our regional OSRP in accordance with 30 CFR 254.

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’Brie n 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.Mississippi Canyon Block 895

– OCS

- G 33764

Initial Exploration Plan 28 

### D. 

## Worst

- Case Scenario Information

Category Regional OSRP Revised EP Type of Activity Exploratory MODU Exploratory MODU Facility Surface Location Mississippi Canyon Block 547 Mississippi Canyon Block 895 Facility Description Well Location Well No. SS002 (Location B) Location G

Distance to Nearest Shoreline (Miles) 38 miles 59 miles

Volume: Storage Tanks (total) Facility Piping (total) Lease Term Pipeline Uncontrolled Blowout (day) Barging

Potential 24 Hour Volume (bb ls) 225,144 bbls 290,697 bbls

Type of Liquid Hydrocarbon C ondensate Oil API Gravity 28 o 22.4°



### 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 and approved October 6, 2011. However, the WCD volume for this Exploration Plan does exceed the previously submitted

volume.

Because the WCD for the subject plan does exceed the worst case discharge previously submitted for MC 547, LLOG Exploration Offshore, L.L.C. (LLOG) is submitting the

new worst

- case scenario to BOEM within 15 days of this Plan submittal for inclusion in our regional OSRP in accordance with 30 CFR 254.

The required proprietary data outlined in NTL 2010

- N06 is being submitted to BOEM within the Confidential Copy of this Initial Exploration Plan.

LLOG accepted BOEM WCD rate for this Initial Exploration Plan of 290,697 BPD on January 14, 2014.

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 volume originating from the proposed activity would be a well bl owout during drilling operations, estimated to be 290,697 barrels of crude oil with an API gravity of 22.4°.

Land Segment and Resource Identification

Trajectories of a spill and the probability of it impacting a land segment have been projected utilizing information in the BOEM Oil Spill Risk 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 identifies an 8% probability of impact to th e shorelines of Plaquemines Parish, Louisiana within 30 days. Plaquemines Parish includes Barataria Bay, the Mississippi River Delta, Breton Sound and th e 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 th is area vary in grain particle size and can be classified as fine sand, shell or perched shell beaches. Sa ndy 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 desc ription of the response eq uipment under contract

to contain and recover the Wors t Case Discharge is shown in Figure 2.

Using the estimated chemical and physical charact eristics of crude oil, an ADIOS weathering model was run on a similar product from the ADIOS oil database. The results indicate 9% or approximately 26,163 barrels of crude oil would be evaporated/dispersed w ithin 24 hours, with approximately 264,534 barrels remaining.

Spill Response MC 895 Barrels of Oil

WCD Volume 290,697

Less 9% natural evaporation/dispersion 26,163

Remaining volume 264,534



### Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary storage equipment available to respond to the worst case discharge. The volume accounts for the amount remaining after evaporation/dispersion at 24 hours. The list estimates individual times needed for procurement, load out, tr avel time to the site and deployment. Figure 2 also indicates how operations will be supported.

LLOG Exploration Offshore, L.L.C.’s Oil Spill Response Plan includes alternative response technologies such as dispersants and in-situ burn. Strategies will be decided by Unified Command based on an operations safety analysis , the size of the spill, weather and potential impacts. If aerial dispersants are utilized, 8 sorties (9,600 gallons) from two of the DC-3 aircrafts

### and 4 sorties (8,000 gallons) from the Basler aircra ft would provide a daily dispersant capability of 7,540 barrels. If the conditions are favorable for in-situ burning, the proper approvals have been obtained and the proper planni ng is in place, in-situ burning of oil may be attempted. Slick containment boom would be immediately called out and on-scene as soon as possible. Offshore response strategies may include attempting to sk im utilizing CGA spill response equipment, with a total derated skimming capac ity of 347,622 barrels. Temporar y storage associated with skimming equipment equals 32,198 barrels. If additional storage is needed, various tank barges with a total of 323,000+ ba rrels of storage capacity may be m obilized and centrally located to provide temporary storage an d minimize off-loading time. 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. Shorelin e protection would include the use of CGA’s

near shore and shallow water skimmers with a totaled derated sk imming capacity of 68,886 barrels. Temporary storage asso ciated with skimming equipm ent equals 1,188 barrels. If additional storage is needed, a 25,000 barrel storage barge, a 23,000 barrel storage barge, and a 20,000 barrel storage barge may be mobilized and cen trally located to provide temporary storage and minimize off-loading time. Onshore respons e may include the depl oyment of shoreline boom on beach areas, or protection and sorben t boom on vegetated areas. Master Service Agreements with AMPOL and OMI Environmen tal will ensure access to 147,000 feet of 18” shoreline protection boom. Figure 2 outlines individual times needed for procurement, load out, travel time to the site and deployment. Stra tegies would be based upon surveillance and real time trajectories that depict areas of potentia l impact given actual sea and weather conditions.

The State of Louisiana Initia l Oil Spill Response Plan, appl icable Area Contingency and Geographical Response Plans and Unified Comm and would be consulted to ensure that environmental and special economic resources woul d be correctly identifie d and prioritized to ensure optimal protection. Shorel ine protection strategies depict the protection response modes applicable for oil spill clean-up operations. The St ate of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection strategies fo r this area, and it describes necessary action to keep the oil spill from entering Louisiana’s co astal 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 allowi ng a more effective res ponse to site-specific circumstances. LLOG Exploration Offshore, L.L.C.’s contract Spill Management Team holds a copy of the State of Louisiana Initial Oil Spill Response Plan.

Based on the anticipated worst case discharge sc enario, LLOG Exploration Offshore, L.L.C. can be onsite with contracted oil spill recovery equi pment with adequate response capacity to contain and recover surface hydrocarbons, and prevent land impact, to the maximum extent practicable, within an estimated 68 hours (based on the equi pment’s Effective Daily Recovery Capacity (EDRC)).

### 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 oil as quickly as it is safe to do so. In an effort to protect the environment, response actions will be designed to provide an “in-depth” protection strategy meant to recover as much oil as possible as far from environmentally sensitive areas as possible. Safety will take precedence over all other considerations during these operations.

Coordination of response assets will normally be supervised by the Operations Section as necessary for close quarter vesse l response activities. A Simu ltaneous Operations (SIMOPS) unit may be established in the Source Control Sec tion to control operations if events require a significant number of large vessels to operate in dependently, but in coordination with each other. This unit would normally monitor the subsurfa ce activities of each vessel (ROV, dispersant application, well control s upport, etc.), as well.

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

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

slick movement in real time.

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

• Information will be confirmed

• An assessment will be made and initial objectives set

• OSROs and appropriate 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 re mote sensing systems, aerial photography

and visual confirmation

• Continual monitoring of vessel assets using vessel monitoring systems

Dispersant application assets

• Put ASI on standby

• With the FOSC, conduct analysis to determin e appropriateness of di spersant application (refer to Section 18)

• 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 situational st atus reports to vessels to e xpedite their arrival at sites that will provide for their most effective containment

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

Oceangoing Boom Barge

• Containment at the source

• Increased/enhanced skimmer encounter rate

• Protection booming

In-situ Burn assets

• Determine appropriateness of in-situ burn 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

### 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 95’ Fast Response Vessels (FRVs)

• Designed to be a first vessel on scene

• Capable of maintaining the initial Command and Control function for on water recovery operations

• 24 hour oil spill detection capability

• Highly mobile and efficient skimming capability

• Use as far off-shore as safely possible

CGA FRUs

• To the area of the thickest oil

• Use as far off-shore as allowed

• VOOs 100’ minimum in length

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

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

T&T Koseq Skimming Systems

• To the area of the thickest oil

• Use as far off-shore as allowed

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

• VOOs at least 200’ in length

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

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

Storage Vessels

• Establish availability of CGA c ontracted assets (See Appendix E)

• 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 mming assets to minimize offloading time

Vessels of Opportunity (VOO)

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

• Industry vessels are ideal for deployment of Vessel of Opportunity Skimming Systems (VOSS)

### • Acquire additional resources as needed

• Consider use of local assets , i.e. fishing and pleasure cr aft for ISB operations or boom tending

• Expect mission specific and sa fety training to be required

• Plan with the US Coast Guard for vessel inspections

• 

### Place VOOs in Division or Groups as needed

• 

### Use organic on-board st orage if appropriate

• 

### Maximize non-organic storage approp riate to vessel limitations

• 

### Decant as appropriate after approv al to do so has been granted

• 

### Assign bulk storage barges to each Division/Group

• 

### Position bulk storage barges as close to skimming units as possible

• 

### Utilize large skimming vessel (e.g. barges) storage for smaller vessel offloading

• 

### Maximize skimming area (swath) to the optimum width given sea conditions and available equipment

• 

### Maximize use of oleophilic skimmers in all operations, but especially offshore

• 

### Nearshore, use shallow water barges a nd shuttle to skimming units to minimize offloading time

• 

### Plan and equip to use all offloading capabilities of the storage vessel to minimize offloading time

Adverse Weather Operations:

In adverse weather, when seas are > 3 feet, the use of larger recovery and storage vessels, oleophilic skimmers, and large offshore boom will be maximized. KOSEQ Arm systems are built for rough conditions, and they should be used until their operational limit (9.8’ seas) is met. Safety will be the overriding factor in all operat ions and will cease at the order of the Unified Command, vessel captain, or in an emergency, ”stop work” may be directed by any crew

member.

Surface Oil Recovery Considerations and Tactics (Offshore and Near-shore Operations)

Maximization of skimmer-oil encounter rate

• Place barges in skimming task forces, groups , etc., to reduce recovered oil offloading

time

• Place barges alongside skimming systems for immediate offloading of recovered oil when practicable

• Use two vessels, each with heavy sea boom, in an open-ended “V” configuration to

funnel surface oil into a tra iling skimming unit’s organic, V-shaped boom and skimmer (see page 7, CGA Equipment Guide Book and Tactic Manual (CGATM)

• Use secondary vessels and heavy sea boom to widen boom swath beyond normal skimming system limits (see page 15, CGATM)

• Consider night-time operations, fi rst considering safety issues

### • Utilize all available advanced technology syst ems ( IR, X-Band Radar, etc.) to determine the location of, and move to, recoverable oil

• Confirm the presence of recoverable oil prior to moving to a new location

Maximize skimmer system efficiency

• Place weir skimming systems in areas of calm seas and thick oil

• Maximize the use of oleophilic sk imming systems in heavier seas

• Place less mobile, high EDRC skimming systems (e.g. HOSS Barge) in the largest pockets of the heaviest oil

• Maximize onboard recovered oil storage for vessels.

• Obtain authorization for decanting of recovered water as soon as possible

• Use smaller, more agile skimming systems to recover streamers of oil normally found farther from the source. Place recovered oil barges nearby

Recovered Oil Storage

• Smaller barges in larger quantities will in crease flexibility for multi-location skimming operations

• Place barges in skimming task forces, groups , etc., to reduce recovered oil offloading

time

• Procure and deploy the maximum number of portable tanks to support Vessel of Opportunity Skimming Systems if o nboard storage is not available

• Maximize use of the organic recovered o il storage capacity of the skimming vessel

Command, Control, and Communications (C 3 

### )

• Publish, implement, and fully test an appropriate communications plan

• Design an operational scheme, maintain ing a manageable span of control

• Designate and mark C 3 

### vessels for easy aerial identification

• Designate and employ C 3 

### aircraft for task forces, groups, etc.

• Use reconnaissance air craft and Rapid Res ponse Teams (RAT) to c onfirm the presence

of recoverable oil

### On Water Recovery Group When the first skimming vessel arrives on scene, a complete si te assessment will be conducted before recovery operations begin. Once it is co nfirmed that the air mon itoring readings for O2, LEL, H2S, CO, VOC, and Benzene are all within the permissible limits, oil recovery operations may begin.

As skimming vessels arrive, they will be organized to work in areas that allow for the most efficient vessel operation and free vessel movement in the recovery of o il. Vessel groups will vary in structure as determined by the Operat ions Section of the Unified Command, but will generally consist, at a minimum, of the following dedicated assets:

• 3 to 5 – Offshore skimming vessels (recovery)

• 1 – Tank barge (temporary storage)

• 1 – Air asset (tactical direction)

• 2 – Support vessels (crew/utility for supply)

• 6 to 10 – Boom vessels (enhanced booming )

Example ( Note: Actual organization of TFs will be de pendent on several factors including, asset availability, weather, spilled o il migration, currents, etc.)

The 95’ FRV Breton Island out of Venice arri ves on scene and conducts an initial site assessment. Air monitoring levels are acceptable a nd no other visual threats have been observed. The area is cleared for safe skimming operati ons. The Breton Island assumes command and control (CoC) of on-water rec overy operations until a dedicate d non-skimming vessel arrives to

relieve it of those duties.

A second 95’ FRV arrives and begins recovery operations alongside the Breton Island. Several more vessels begin to arrive, including a thir d 95’ FRV out of Galveston, the HOSS Barge (High Volume Open Sea Skimming System) out of Harvey, a boom barge (CGA 300) with 25,000’ of 42” auto boom out of Leeville, and 9 Fast Resp onse Units (FRUs) from the load-out location at

C-Port in Port Fourchon.

As these vessels set up and begin skimming, they ar e grouped into task for ces (TFs) as directed by the Operations Section of the Unified Command located at the command post.

Initial set-up a nd potential actions:

• A 1,000 meter safety zone has been establis hed around the incident location for vessels

involved in Source Control

• The HOSS Barge is positioned facing the incident location just outside of this safety zone or at the point where the freshe st oil is reaching the surface

• The HOSS Barge engages its Oil Spill Detection (OSD) system to locate the heaviest oil and maintains that ability for 24-hour operations

### • The HOSS Barge deploys 1,320’ of 67” Sea Se ntry boom on each side, creating a swath

width of 800’

• The Breton Island and H.I. Rich skim near by, utilizing the same OSD systems as the HOSS Barge to locate and recover oil

• Two FRUs join this group and it becomes TF1

• The remaining 7 FRUs are split into a 2 a nd 3 vessel task force numbered TF2 and TF3

• A 95’ FRV is placed in each TF

• The boom barge (CGA 300) is positioned nearby and begins deploying auto boom in sections between two utility vessels (1,000’ to 3,000’ of boom, depending on conditions) with chain-link gates in the middle to funnel oil to the skimmers

• The initial boom support vessels po sition in front of TF2 and TF3

• A 100,000+ barrel offshore tank barge is placed with each task force as necessary to facilitate the immediate offload of skimming vessels

The initial task forces (36 hours in ) may be structured as follows:

TF 1

• 1 – 95’ FRV

• 1 – HOSS Barge with 3 tugs

• 2 – FRUs

• 1 – 100,000+ barrel tank barge and associated tug(s)

• 1 – Dedicated air asset for tactical direction

• 8 – 500’ sections of auto boom with gates

• 8 – Boom-towing vessels

• 2 – Support vessels (crew/utility)

TF 2

• 1 – 95’ FRV

• 4 – FRUs

• 1 – 100,000+ barrel tank barge and associated tug(s)

• 1 – Dedicated air asset for tactical direction

• 10 – 500’ sections of auto boom with gates

• 10 – Boom-towing vessels

• 2 – Support vessels (crew/utility)

TF 3

• 1 – 95’ FRV

• 3 – FRUs

• 1 – 100,000+ barrel tank barge and associated tug(s)

• 1 – Dedicated air asset for tactical direction

• 8 – 500’ sections of auto boom with gates

• 8 – Boom-towing vessels

• 2 – Support vessels (crew/utility)

### Offshore skimming equipment continues to arrive in accordance with the ETA data listed in figure H.3a; this equipment includes 2 AquaGu ard skimmers and 11 sets of Koseq Rigid Skimming Arms. These high volume heavy weat her capable systems will be divided into functional groups and assigned to specific areas by the Operati ons Section of the Unified

Command.

At this point of the response, the additional TFs may assume the following configurations:

TF 4

• 2 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs

• 1 – AquaGuard Skimmer

• 1 – 100,000+ barrel tank barge and associated tug(s)

• 1 – Dedicated air asset for tactical direction

• 2 – Support vessels (crew/utility)

• 6 – 500’ sections of auto boom with gates

• 6 – Boom-towing vessels

TF 5

• 3 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs

• 1 – AquaGuard Skimmer

• 1 – 100,000+ barrel tank barge and associated tug(s)

• 1 – Dedicated air asset for tactical direction

• 2 – Support vessels (crew/utility)

• 8 – 500’ sections of auto boom with gates

• 8 – Boom-towing vessels

TF 6

• 3 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs

• 1 – 100,000+ barrel tank barge and associated tug(s)

• 1 – Dedicated air asset for tactical direction

• 2 – Support vessels (crew/utility)

• 6 – 500’ sections of auto boom with gates

• 6 – Boom-towing vessels

TF 7

• 3 – Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs

• 1 – 100,000+ barrel tank barge and associated tug(s)

• 1 – Dedicated air asset for tactical direction

• 2 – Support vessels (crew/utility)

• 6 – 500’ sections of auto boom with gates

• 6 – Boom-towing vessels

### 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 sh oreline 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

• Sea state

• Tides

• Currents

Surveillance

• Provide trained observer to direct skimming operations

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

and visual confirmation

• Continual monitoring of vessel assets

Dispersant Use

• Dispersants are pre-approved with FOSC a pproval outside of 3 miles and the 10 meter depth curve and requires RRT VI approval inside 3 mile and/or 10 meter curve

• 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)

Dedicated Near Shore skimming systems

• FRVs

• 56’ shallow water skimmers

• Egmopol and Marco SWS (protected waters)

• 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 vessels 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

• Shoreline Cleanup Assessment Team (SCAT) assessments

• Time to acquire personnel and eq uipment and their availability

• Previous contingency planning contained in the appropriate ACP, Geographic Response Plan (GRP), and currently for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep Water Horizon, dated 2 May 2010

Actions

Placement of boom

• Position boom in accordance with the ERA based on the actual situation or the appropriate ACP or GRP.

• 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 tide 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 water mixtures will typically se parate into distinct phases when left in a quiescent state. When separati on occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with minima l, if any, impact. Decan ting therefore increases the effective on-site oil storage capacity a nd equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill

recovery.

CGA Equipment Limitations The capability for any spill response equipment, whether a dedicated or portable system, to operate in differing weather conditions will be directly in rela tion to the capabilities of the vessel the system in placed on. Most importantly, howev er, 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 were exceeded. Systems below are some of the most up-to-date systems available and were employed during the DWH spill.

Boom 3 foot seas, 20 knot winds Dispersants Winds more than 25 knots Visibility less than 3 nautical miles Ceiling less than 1,000 feet.

FRU 8 foot seas HOSS Barge/OSRB 8 foot seas Koseq Arms 8 foot seas

OSRV 4 foot seas

### Environmental Conditions in the GOM Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences westerly winds during the wint er and easterly winds in the summer. Average wind speed is generally 14-15 mph along the coast. Wave 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 November. 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 minor (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. Maximum activity is in early to mid September. Once in a few years there may be a hurri cane 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 th e Central and Western Gulf of Mexico available on the BOEM website using 30 day impact. The results are tabulated below.

Area/Block OCS-G Launch

Area Land Segment and/or

Resource Conditional Probability (%) within 30 days

Exploratory Drilling

MC 895

59 miles from shore G33764 C58 Galveston, TX Jefferson, TX
Cameron, LA Vermilion, LA Iberia, LA Terrebonne, LA Lafourche, LA Jefferson, LA Plaquemines, LA

St. Bernard, LA

Okaloosa, FL 1

1

3

2

1

3

3

1

8

1

1WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(59 miles from shore)264,534 bbls of crude oil (Volume considering natural weathering)API Gravity 22.4°FIGURE 2 – Equipment Response Time to MC 895Dispersants/SurveillanceDispersant/SurveillanceDispersant Capacity(gal)StorageCapacityPersons Req.FromHrs toProcureHrs toLoadoutTravel tositeTotal HrsASIBasler 67T 2000 NA 2 Houma 2 2 0.7 4.7DC 3 1200 NA 2 Houma 2 2 0.9 4.9DC 3 1200 NA 2 Houma 2 2 0.9 4.9Aero Commander NA NA 2 Houma 2 2 0.7 4.7Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 7.5 1 20.595’ FRV 12342 249 NA 4 Leeville 2 0 2 4.5 8.5 5.495’ FRV 12342 249 NA 4 Venice 2 0 1 3 0 6Boom Barge (CGA-300)42” Auto Boom (25000’)NA NA1 Tug50 Crew4 (Barge)2 (Per Crew)Leeville 4 0 6 13 2 25Recovered Oil Storage NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsKirby (available throughcontract with CGA)RO Barge NA 80000+ 1 Tug 6 Venice 44 0 2 14 0 60RO Barge NA 110000+ 1 Tug 6 Venice 44 0 2 14 0 60Enterprise Marine Services LLC (available through contract with CGA)CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGAFRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 2 2 12.7 5 1 22.7FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 2 2 2.1 5 1 12.1FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 17.7 5 1 27.7FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 2 8 5 1 18FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 2 2 4.4 5 1 14.4FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 2 4.9 5 1 14.9FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 2 2 0 5 1 10Hydro-Fire Boom NA NA 8 Utility 40 Harvey 2 4 2.1 5 6 19.1T&T Marine (available through contract with CGA)Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 12.7 5 1 34.7Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 24 24 12.7 5 2 67.7Koseq Skimming Arms (4) 71316 8000 4 Utility 24 Galliano 24 24 4.7 5 2 59.7Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey 24 24 2.1 5 2 57.1Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsCGA46’ FRV 5000 65 NA 4 Venice 2 0 1 2.5 0 5.5Trinity SWS 21500 249 NA 4 Leeville 2 0 6 N/A 48 56Trinity SWS 21500 249 NA 4 Venice 2 0 6 N/A 48 56Enterprise Marine Services LLC (available through contract with CGA)CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 15 1 36Staging Area: VeniceNearshore and Inland Skimmers WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGASWS Egmopol 3000 100 NA 3 Galveston 2 2 12.7 2 0 18.7SWS Egmopol 3000 100 NA 3 Morgan City 2 2 4.9 2 0 10.9SWS Marco 3588 20 NA 3 Lake Charles 2 2 8 2 0 14SWS Marco 3588 34 NA 3 Leeville 2 2 4.4 2 0 10.4SWS Marco 3588 34 NA 3 Venice 2 2 0 2 0 6Rope Mop 77 2 0 3 Harvey 2 2 2.1 2 0 8.1Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 2 2 8 2 0 14Foilex Skim Package (TDS 150) 891 45 NA 3 Galveston 2 2 12.7 2 0 18.7Foilex Skim Package (TDS 150) 891 45 NA 3 Harvey 2 2 2.1 2 0 8.14 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 2 2 8 2 0 144 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 2 2 2.1 2 0 8.1Shoreline ProtectionStaging Area: VeniceShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeployment SiteHrs toDeployTotal HrsAMPOL (available through MSA)42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 6 2 12 2420,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2.2 2 6 14.2OMI Environmental (available through MSA)10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 6 2 3 1310,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 12.1 2 3 19.110,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 9.7 2 3 16.720,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.9 2 6 11.910,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 4.5 2 3 11.510,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.8 2 3 10.815,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.1 2 4 12.1Wildlife ResponseEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGAWildlife Support Trailer NA NA NA 2 Harvey 2 2 2.1 1 2 9.1Bird Scare Guns (48) NA NA NA 2 Harvey 2 2 2.1 1 2 9.1Bird Scare Guns (12) NA NA NA 2 Galveston 2 2 12.7 1 2 19.7Bird Scare Guns (12) NA NA NA 2 Aransas Pass 2 2 17.7 1 2 24.7Bird Scare Guns (24) NA NA NA 2 Lake Charles 2 2 8 1 2 15Bird Scare Guns (24) NA NA NA 2 Leeville 2 2 4.4 1 2 11.4Response AssetTotalOffshore EDRC 347,622Offshore Recovered Oil Storage 355,198Nearshore / Shallow Water EDRC 68,886Nearshore / Shallow Water Recovered Oil Storage 69,188Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 28 

## APPENDIX I

ENVIRONMENTAL MONITORING INFORMATION (30 CFR PART 550.221 AND 550.252)

A. Monitoring Systems

LLOG subscribes to Impact Weather Serv ice which provides access to real-time weather conditions, and provi des periodic updates on impending inclement weather conditions such as tropical depressions, storms and/or hur ricanes entering the Gulf of

Mexico.

LLOG also relies on the National Weather Service to support the aforementioned subscribed service. During impending inclement weather conditions, LLOG closely coordinates the activity with our contractors and field personne l to ensure the safety of people for evacuation; measures to prepar e the facility for ev acuation to ensure protection of the environment and the facility/equipment.

Mississippi Canyon Block 895 is in water de pths greater than 400 meters (1,312’); therefore LLOG will follow the guidelines of the applicable NTL 2009-G02 “Ocean Current Monitoring”, by monitoring and gath ering ocean current da ta using Acoustic Doppler Current Profile (ADCP) while the MODU is on location.



## B. Incidental Takes

LLOG does not anticipate the incidental taki ng 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 Awa reness Training and Elimination” and

Joint NTL No. 2012-G01 “Vessel Strike Avoida nce and Injured/Dead Protected Species Reporting”.



## C. Flower Garden Banks National Marine Sanctuary

This section of the plan is not a pplicable to the proposed operations.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 29 

## APPENDIX J

LEASE STIPULATIONS/SPECIAL CONDITIONS INFORMATION (30 CFR PART 550.222 AND 550.253)

A. Lease Stipulations

Minerals Management Service (BOEMRE) invoked Stipulation No. 8 – Protected Species on Lease OCS-G-33764, Mississippi Canyon Block 895.

Lease Stipulation No. 8 is to reference meas ures to minimize or avoid potential adverse impacts to protected species (sea turtle s, marine mammals, gulf sturgeon, and other federally protected species). BOEMRE ha s issued Notice to Lessees Joint NTL No. 2012-G02 “Implementation of Seismic Surv ey Mitigation Measures and Protected Species Observer Program”, Joint NTL No. 2012-G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reportin g” and BSEE NTL No. 2012-G01 “Marine

Trash and Debris Awareness and Elimination”.



## B. Special Conditions

 Subsea Completions

LLOG may potentially comple te the proposed wells as subsea completions. Therefore, LLOG will follow the regul ations in Title 30 CFR Parts 550.296 through 550.299, which mandates the submittal and approval of separate regulatory filings entitled a “Conservation Information Document” and Title 30

CFR Parts 250.286 to Title 30 CFR Parts 250.295 entitled “Deepwater Operations Plan”.

 Ocean Current Monitoring

The proposed operations under this Plan ar e in water depths greater than 400 meters (1,312’); therefore, LLOG will fo llow the guidelines of the applicable NTL 2009-G02 “Ocean Current Monitoring”, by continuously monitoring and gathering ocean current data using Ac oustic Doppler Current Profile (ADCP)

while the MODU is on location.

 Breton Sound Area

Mississippi Canyon Block 895 is located within the 200 km zone of the Breton National Wildlife Refuge, and LLOG will consider the use of best available control technology as required if the proj ected air emissions are determined to significantly affect the air quality of an onshore area.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 30 

## APPENDIX K

ENVIRONMENTAL MITIGATION MEASURES INFORMATION (30 CFR Part 550.23 and 550.54)

A. Measures Taken to Avoid, Minimize, and Mitigate Impacts

This section does not apply to th e operations as proposed herein.



## B. Incidental Takes

LLOG does not anticipate the incidental taki ng of any species as a result of the proposed activities based on the implementatio n of, and adherence to, the 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 Protec ted Species Reporting” and BSEE NTL No.

2012-G01 “Marine Trash and Debris Awareness and Elimination”.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 31 

## APPENDIX L

RELATED FACILITIES AND OPERATIONS INFORMATION (30 CFR PART 550.256)

A. 

## Produced Liquid Hydrocar bon Transportation Vessels

Not applicable to proposed operations.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 32 

## APPENDIX M

SUPPORT VESSELS AND AI RCRAFT INFORMATION (30 CFR PART 550.224 AND 550.257)

A. 

## General

Personnel involved in the proposed operations will typically use their own vehicles as transportation to and from the selected ons hore 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 frequenc ies shown, taking the most direct route feasible as mandated by weather and traffic conditions:

Drillship and DP Semisubmersible Rig:

Type Maximum Fuel Tank Storage Capacity Maximum No. in Area at Any Time Trip Frequency or

Duration Supply Boats 500 bbls 1 Six times weekly

Crew Boats 500 bbls 1 Three times weekly

Aircraft 279 gallons 1 As Needed



## B. Diesel Oil Supply Vessels

Size of Fuel Supply

Vessel Capacity of fuel Supply Vessel Frequency of Fuel

Transfers Route Fuel Supply

Vessel Will Take

180’ OSV 1900 bbls 1/weekly Fourchon, LA to Mississippi Canyon

Block 895



## C. Drilling Fluids Transportation

See Table 2 – Wastes you will Transport an d/or Dispose of Onshore, located in Appendix F of this Plan.



## D. Solid and Liquid Wastes Transportation

See Table 2 – Wastes you will Transport an d/or Dispose of Onshore, located in Appendix F of this Plan.



## E. Vicinity Map

Vicinity Plats showing the location of Mississippi Canyon Block 895 relative to the

nearest shoreline and ons hore base is included as Attachment M-1.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 33 

# Vicinity Map

Attachment M-1 (Public Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 34 

## APPENDIX N

ONSHORE SUPPORT FACILITIES INFORMATION (30 CFR PART 550.225 AND 550.258)

A. 

## General

The proposed surface disturbances in Miss issippi Canyon Block 895 will be located approximately 59 statute miles from th e nearest Louisiana shoreline, and approximately 93 statute miles from th e following onshore support base and the proposed surface disturbances:

Name Location Existing/New/Modified LLOG c/o Turn Key

Cleaning Services Fourchon, LA Existing

LLOG will use an existing onshore base to accomplish the following routine operations:

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

● Dispatching personnel and equipment, a nd does not anticipate the need for any expansion of the selected facilities as a result of the activities proposed in this

Initial Plan.

● Temporary storage for materials and equipment.

● 24 Hour Dispatcher

B. 

## Support Base Construction or Expansion

The proposed operations are temporary in nature and do not re quire 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 a pplicable to the proposed operations.

D. 

## Waste Disposal

See Table 2 – Wastes you will Transport an d/or Dispose of Onshore, located in Appendix F of this Plan.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 35 

## APPENDIX O COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION (30 CFR PART 550.226 AND 550.260)

A. Consistency Certification

. A certificate of Coastal Zone Management Co nsistency for the States of Louisiana and Mississippi are enclosed as Attachment O-1



## B. Other Information

Included as Attachment O-2 are the enforceable policies fr om the State of Mississippi that are related to OCS Plan Filings.

LLOG has considered all of Louisiana’s enforceable policies and certifies the consistency for the proposed operations.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 36



# Coastal Zone Management Consistency Statement for the States of Louisiana and Mississippi

Attachment O-1 (Public Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 37 

# Coastal Zone Management Enforceable Policies for the State of Mississippi

Attachment O-2 (Public Information)Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 38 

## APPENDIX P

ENVIRONMENTAL IMPACT ANALYSIS (30 CFR PART 550.227 AND 550.261)

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 be en marked for each IPF category that LLOG has determined may impact a particular environment as a resu lt of the proposed

activities. For those cells which are foot noted, 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) Other IPF’s you Identify

Site Specific at Offshore

Location Designated topographic

features (1) (1) (1)

Pinnacle Trend area live

bottoms (2) (2) (2)

Eastern Gulf live bottoms (3) (3) (3) Chemosynthetic communities (4) Water quality X X

Fisheries X X X

Marine mammals X (8) X X (8)

Sea turtles X (8) X X (8) Air quality (9) Shipwreck sites (known or potential) (7)

Prehistoric archaeological sites (7)

Vicinity of Offshore Location

Essential fish habitat X ( 6 ) Marine and pelagic birds X Public health and safety (5)

Coastal and Onshore

Beaches ( 6 )

Wetlands ( 6 ) Shorebirds and coastal nesting

birds ( 6 )

Coastal wildlife refuge

Wilderness areasMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 39 

### 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 zo ne) with relief greater than 2 meters that is not protected by the Topographic Stipul ation attached to an OCS lease.

2. Activities with any bottom disturbance within an OCS lease block protected through the Live Bottom (Pinnacle Trend) Stipulation attached to an OCS lease.

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

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

5. Exploration or production activities where H2S concentr ations greater than 500 ppm might be encountered.

6. All activities that could result in an accidental spill of produced liquid hydro carbons or diesel fuel that you determine would impact these environmen tal resources. If the proposed action is located a sufficient distance from a resource that no impact would occur, the EIA can note that in a sentence or two.

7. All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block designated by the BOEMRE as having high-probability for the occu rrence of shipwrecks or prehistoric sites, including

such blocks that will be affected th at are adjacent to the lease block in which your planned activity will occur. If the proposed activities are located a sufficient distance from a shipwreck or 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 trans portation of produced fluids to shor e using shuttle tankers or barges.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 40 

## B. Impact Analysis

LLOG does not anticipate any unforeseen inci dents from the proposed activities which could significantly impact the associated envi ronment. LLOG activities associated with this Exploration Plan (Plan) will be perf ormed with prudent and industry accepted standards, and in compliance with the fe deral 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 Enforcemen t (BOEMRE) Notice to Lessees (NTL 2010- N06). Response details associated with an unanticipated spill from this site are detailed in our Regional Oil Spill Response Plan (OSRP) which outlines the potential spill scenario, spill volumes, anticipated trajectory of the sp ill, response equipment available, and actions to be taken to respond to the po tential spill incident. Additional measures implemented by LLOG is trajectory analyses to be obtained prior to and during the proposed activities, contract ual arrangements with we ll control specialists and preliminary reviews of potential well interv ention scenarios, and to supplement existing contracted response/clean-up equipment w ith equipment offered by Helix which specializes in subsea deepwater well in tervention, containm ent and processing.



## Site Specific at Offshore Location

 Designated Topographic Features

There are no anticipated emissions, effl uents, physical disturbances to the seafloor, wastes transported to shore, and/or accidents from the proposed

activities that could cause im pacts to topographic features.

The proposed surface distur bances within Mississippi Canyon Block 895 are located greater than 75 miles away fr om the closest designated topographic feature (Sackett Bank).

The crests of these designated topogra phic features in th e northern Gulf are typically found below 10 m; therefore, concentrated oil from a surface spill is not likely to reach sessile biota. Subs urface spills could ca use adverse impacts to a designated topographic feature; however, due to th e 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.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 41 

###  Pinnacle Trend Area Live Bottoms

There are no anticipated emissions, effl uents, 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 distur bances within Mississippi Canyon Block 895 are located a significant distance (> 100 miles) from the closest pinnacle trend live bottom stipulated block. The crests of these pinnacle trend areas are much deeper than 20 m.

During the surface location disturbance review, LLOG reviews potential surface impacts, and would be able to identify any pinnacles within the vicinity and would avoid placement of any surface dist urbances such as a drilling rig and

associated anchors. These surface location disturbance areas would be avoided and/or mitigated during the review and approval process by the BOEM.

In the event of an unanticipated spill , LLOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

 Eastern Gulf Live Bottoms

There are no anticipated emissions, efflue nts, emissions physical disturbances to the seafloor, wastes sent to shore, and/ or accidents from the proposed activities that could cause impacts to Eastern Gulf live bottoms.

The proposed surface disturbance with in Mississippi Canyon Block 895 is located a significant distance (> 100 mile s) from the closest Eastern Gulf live bottoms stipulated block. During the surface location disturbance review, LLOG previews potential surface impacts, and would be able to identify any live bottom areas within the vicinity a nd would avoid placeme nt of any surface

disturbances such as a drilli ng rig and associated anchors.

In the event of an unanticipated spill , LLOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

 Chemosynthetic Communities

Water depths at the surface locations in Mississippi Canyon Block 895 range from 3,688 to 3,825 feet. As noted in the shallow hazards assessment (Attachment I) benthic communities have not been reported in the seafloor

assessment area.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 42 

###  Water Quality

Bottom disturbances which may result based on placement of drilling rigs during an exploratory pha se could increase water column turbidity and redistribution of any accumulated pollutants in the water column; which could cause temporary impacts on water qualit y conditions in the immediate vicinity.

Associated overboard effluents are re gulated by the EPA Region VI NPDES General Permit GMG290000 which mandates volume discharge rate limitations, certain testing requirements for toxicity and oil and grease limitations. As such, it is not anticipated these discharg es authorized under the approved EPA NPDES permit will cause significant adverse impacts to water quality.

Certain wastes generated from the propos ed activities will be manifested and sent to shore for treatment and/or dispos al 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 vici nity could potentia lly cause temporary impacts to water quality. In the event of such a release, 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 constituen ts to background levels.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Re gional Oil Spill Response Plan and

activate source control and countermeas ures 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 finfis h or shellfish would likely be sub-lethal and the extent of damage would be redu ced to the capability of adult fish and shellfish to avoid a spill, to meta bolize 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 Re gional Oil Spill Response Plan andMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 43 

### activate source control and countermeas ures to minimize these potential impacts.

 Marine Mammals

GulfCet II studies reveal that cetaceans of the continental shelf and shelf edge are comprised of bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and pygmy killer whale, Risso’s dolphin and Cuvier’s beaked whale occur most frequently along th e upper slope in areas outside of anticyclones.

As a result of the proposed activities, marine mammals may be adversely impacted by emissions, effluents, wast e sent to shore a nd/or accidents.

Chronic and sporadic sub-le thal effects would occur that may stress and/or weaken individuals of a local group or population and make them more susceptible to infection from natural or anthropogenic sources. Few lethal effects are expected from an accidental oi l spill, chance collisions with service vessels and ingestion of plastic material.

The net results of any disturbance would depend on the size and percentage of the population affected, ecological im portance of the disturbed area, environmental and biological parameters th at influence an animal’s sensitivity to disturbance and stress, and the accom modation time in response to prolonged disturbance (Geraci and St. Aubin, 1980) . Collisions between cetaceans and ship could cause serious injury or death (Laist et al., 2001).

Sperm whales are one of 11 whale species that are hit commonly by ships (Laist et al., 2001). Collisions between OCS ve ssels and cetaceans w ithin the project area are expected to be unusual events.

LLOG does not anticipate the incidental taking of any marine mammals as the result of the proposed activities. The proposed activities will be conducted by our company and its contractors under the additional criteria addressed in BSEE

NTL No. 2012-G01 “Marine Trash a nd Debris Awareness Training and

Elimination” and Joint NTL No. 2012- G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”. The proposed operations will be conducted in accordance with the regulations via manifesting waste sent to shore and ensuring such wastes are contained to prevent loss. Informational placards will be maintained on the facility, a nd LLOG and the associated contractors obtain training on at least an annual basis to ensure pe rsonnel are aware of the reporting and operational requirements.

LLOG will conduct the proposed activities under EPA’s Region VI NPDES

General Permit GMG290000 which authorizes the discharge of certain effluents, subject to certain limitations, prohibitions and recordkeeping requirements. AsMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 44 

### such, it is not anticipated these discharges authorized under the approved EPA NPDES permit will not cause significan t adverse impacts to water quality.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Re gional Oil Spill Response Plan and

activate source control and countermeas ures to minimize these potential impacts.

 Sea Turtles

Small numbers of turtles could be killed or injured by chance collision with service vessels or by eating indigestib le trash, particularly plastic items accidentally lost from drilling rigs, produc tion facilities a nd service vessels. Drilling rigs and project vessels pr oduce noise that could disrupt normal behavior patterns and create some stre ss to sea turtles, making them more susceptible to disease. A ccidental oil spill releases are potential threats which

could have lethal effects on turtles. Contact and/or consumption of this released material could seriously affect individual sea turtles. Most OCS related impacts on sea turtles are expected to be sub- lethal. Chronic a nd/or avoidance of

affected areas could cause declines in survival or produ ctivity, 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 significan t adverse impacts to water quality.

Additionally, LLOG and its contractors will conduct the proposed activities

under the additional criteria addres sed by BSEE NTL No. 2012-G01 “Marine Trash and Debris Awareness Training and Elimination” and Joint NTL No.

2012-G01 “Vessel Strike Avoidance a nd Injured/Dead Protected Species Reporting”. The proposed ope rations will be conducted in accordance with the regulations via manifesting waste sent to shore and ensuring such wastes are contained to prevent loss. Informationa l placards will be maintained on the facility, and LLOG and the associated c ontractors obtain trai ning on at least an annual basis to ensure personnel are aware of the reporting and operational requirements.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Re gional Oil Spill Response Plan and

activate source control and countermeas ures to minimize these potential impacts.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 45 

###  Air Quality

The proposed activities are located a pproximately 59 miles to the nearest shoreline. LLOG has addressed the air quality issues associated with the proposed activities in the “Air Emissions Information” section of this Plan as a result of the proposed activities.

 Ship Wreck Sites (Known or Potential)

There are no physical disturbances to th e seafloor which could impact known or potential shipwreck sites, as the review of high resolution shallow hazards data indicate there are no known or potentia l shipwreck sites located within the survey area. As such, LLOG does not anticipate any IPF’s as a result of the proposed activities.

 Prehistoric Archaeological Sites

There are no physical disturbances to the seafloor which co uld cause impacts to prehistoric archaeological sites, as the review of high resolution shallow hazards data and supporting studies did not re flect 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, e ssential fish habita t may be adversely impacted by effluents and/or accidents.

An Accidental oil spill that may occur as a result of the proposed activities has potential to cause some detrimental effects on essential fish habitat. It is unlikely that an accidental oil spill release would occur; however, if a spill were to occur in close proximity to finfish or shellfish, the effects would likely be

sub-lethal and the extent of damage would be reduced to the capability of adult fish and shellfish to avoid a spill, to metabolize hydrocarbons and to excrete both metabolites and parent compounds.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Re gional Oil Spill Response Plan and

activate source control and countermeas ures to minimize these potential impacts.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 46 

###  Marine and Pelagic Birds

As a result of the proposed activities, ma rine 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 wi de standards for using proven equipment and technology for such responses. In that event, LLOG will implement the Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

 Public Health and Safety

There are no anticipated emissions, efflue nts, wastes sent to shore, and/or accidents from the proposed activities that could cause impacts to the public health safety. LLOG has requested BOEM RE 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. However, due to the distance from shore (approximately 59 miles), and the response capabilities that would be implemented, no significant adverse impacts are expected. Both hi storical spill data and the combined trajectory/risk calculations referenced in the publication of OCS EIA/EA

BOEMRE 2009-053 indicate there is little ri sk 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 Re gional Oil Spill Response Plan and

activate source control and countermeas ures to minimize these potential impacts.

 Wetlands

As a result of the proposed activities, wetlands may be adversely impacted by an accidental oil spill. However, due to the distance from shore (approximately 59 miles) and the response capabilities that would be implemented, no significant adverse impacts are expected. Both hi storical spill data and the combined trajectory/risk calculations referenced in the publication of OCS EIA/EAMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 47 

### BOEMRE 2009-053 indicate there is little ri sk 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 Re gional Oil Spill Response Plan and

activate source control and countermeas ures 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 59 miles) and the response capabilities that would be implemented, no significant a dverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEMRE 2009-053 indicate th ere is little risk of contact or impact to the coastline and asso ciated 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 Re gional Oil Spill Response Plan and

activate source control and countermeas ures to minimize these potential impacts.

 Coastal Wildlife Refuges

As a result of the propose d activities, coastal wildlife refuges may be adversely impacted by an accidental oil spill. Ho wever, due to the distance from shore (approximately 59 miles) and the re sponse capabilities that would be implemented, no significant a dverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEMRE 2009-053 indicate th ere is little risk of contact or impact to the coastline and asso ciated 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 Re gional Oil Spill Response Plan and

activate source control and countermeas ures to minimize these potential impacts.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 48 

###  Wilderness Area

As a result of the proposed activities , wilderness areas may be adversely impacted by an accidental oil spill. Ho wever, due to the distance from shore (approximately 59 miles) and the re sponse capabilities that would be implemented, no significant a dverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEMRE 2009-053 indicate th ere is little risk of contact or impact to the coastline and asso ciated 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 Re gional Oil Spill Response Plan and

activate source control and countermeas ures to minimize these potential impacts.

Other Resources Identified

LLOG has not identified any other environmen tal resources other than those addressed

above.



## C. Impacts of Proposed Activities

LLOG does not anticipate any impacts on th e offshore site specifi c locations, offshore vicinity, and/or coastal and onshore envir onmental conditions based on the potential impacts identified in the EIA worksheets and hi storical operations in the exploration of

this reservoir.



## D. Environmental Hazards

The Gulf of Mexico may experience se veral hurricanes throughout the season which typically runs from June through November. A severe hurricane may impact the activities covered in this Plan. Such imp acts may be damage to the drilling rig, the unanticipated release of hydrocarbons dependi ng upon the current status of the well. Additionally, the surf aces located in Missi ssippi Canyon Block 895 has the potential to be affected by the “Loop Current” which is a warm ocean current in the Gulf of Mexico

that flows northward between Cuba and the Yucatan Penins ula, moves northward into the Gulf of Mexico, then loops east and s outh before exiting to the east through the Florida Straits. While the loop current is present approximately 95% of the time, it is

most active in the summer and fall seasons.

To mitigate potential impacts to the well during impending hurricanes or loop currents, LLOG will take precautionary measures by securing the well, rig and evacuation of personnel; and will comply with the re quirements of NTL’s 2008-G09 and 2009-G10.Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 49 

## E. Alternatives

LLOG did not consider any alternatives to reduce environmental im pacts as a result of the proposed activities.



## F. Mitigation Measures

LLOG will not implement any mitigation measures to avoid, diminish or eliminate potential environmental resources, other th an those required by regulation and policy.



## G. Consultation

LLOG has not contacted any agencies or pe rsons for consultation regarding potential impacts associated with the pr oposed activities. Therefore, a list of such entities is not being provided.



## H. Preparers

Questions or requests for addi tional information should be made to LLOG’s authorized representative of this Plan:

Kathy Gowland Kim DeSopo Regulatory Specialist Regulatory Specialist 1001 Ochsner Boulevard, Suite 200 1001 Ochsner Boulevard, Suite 200 Covington, Louisiana 70433 Covington, Louisiana 70433 985-801-4300 (Phone) 985-801-4300 (Phone) kathygo@llog.com kim.desopo@llog.comMississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 50 

## I. References

The following documents were utilized in preparing the Environmental Impact

Assessment:

Document Author Dated
Archaeological Deep Tow Survey Shallow Hazards Assessment, Benthic Communities Evaluation, and Archaeological Resource Survey Tesla Berger Geosciences, LLC 2010

2014

BOEMRE Environmental Impact Statement Report No.

2009-053 Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

Title 30 CFR Part 250 Subp art B (250.216 / 250.221 /

250.223 / 250.227 Bureau of Ocean Energy Management, Regulation, and Enforcement 2006

NTL 2000-G16 “Guidelines for General Lease Surety

Bonds” Bureau of Ocean Energy Management, Regulation, and Enforcement 2000

NTL 2005-G07 “Archaeological Resource Surveys and Reports” Bureau of Ocean Energy Management, Regulation, and Enforcement 2005

NTL 2006-N06 “Flaring and Venti ng 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

JOINT NTL 2012-G02 “Implementation of seismic Survey Mitigation Measures and Protected Species Observer Program” Bureau of Ocean Energy Management, Regulation, and Enforcement 2012

BSEE NTL 2012-G01 “Marine Trash & Debris Awareness

& Elimination” Bureau of Ocean Energy Management, Regulation, and Enforcement 2012

JOINT NTL 2012-G01 “Vessel Strike Avoidance and Injured/Dead Protective Species” Bureau of Ocean Energy Management, Regulation, and Enforcement 2012

NTL 2008-G04 “Information Requirements for Exploration Plans and Development Op erations Coordination

Documents” Bureau of Ocean Energy Management, Regulation, and Enforcement 2008

NTL 2008-N05 “Guidelines for Oil Spill Financial Responsibility for Covered Offshore Facilities” Bureau of Ocean Energy Management, Regulation, and Enforcement 2008

NTL 2008-G06 “Remotely Operated Vehicle Surveys in Deepwater” Bureau of Ocean Energy Management, Regulation, and Enforcement 2008

NTL 2008-N07 “Supplemental Bond Procedures Bureau of Ocean Energy Management, Regulation, and Enforcement 2008

NTL 2008-G20 “Revisions to the List of OCS Lease Blocks Requiring Archaeological Resource Surveys and Reports” Bureau of Ocean Energy Management, Regulation, and Enforcement 2008

NTL 2009-G02 “Ocean Current Monitoring” Bu reau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-G27 “Submitting E xploration Plans and Development Operations Coordination Documents” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-G29 “Implementation Plan for Transition from

North American Datum 27 to North American Datum 83” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-G31 “Hydrogen Sulfide” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-G34 “Ancillary Activities” Bur eau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-G38 “Drilling Window s, Eastern Gulf of

Mexico” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-G39 “Biologically-Sensitive Underwater

Features and Areas” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-G40 “Deepwater Benthic Communities” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009-N11 “Air Quality Jurisdiction on the OC S” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2010-N05 “Increased Safety Measures for Energy Development on the OCS” Bureau of Ocean Energy Management, Regulation, and Enforcement 2010

NTL 2010-N06 “Information Requirements for EP’s, DOCD’s, DPP on the OCS” Bureau of Ocean Energy Management, Regulation, and Enforcement 2010

NPDES General Permit GMG 290000 EPA – Region VI 2012 Regional Oil Spill Response Plan LLOG Exploration Offshor e, L.L.C. 2014Mississippi Canyon Block 895 – OCS-G 33764 Initial Exploration Plan 51 

## APPENDIX Q

ADMINISTRATIVE INFORMATION (30 CFR Part 550.228 and 550.262)

A. Exempted Information Description (Public Information Copies only)

Excluded from the Public Informa tion copies are the following:

 Proposed bottom hole location information

 Proposed total well depths (measured and true vertical depth)

 Production Rates and Life of Reserves

 New and Unusual Technologies

 Geological and Geophysical Attachments



## B. Bibliography

The following documents were utilized in preparing this Plan:

Document Author Dated

Archaeological Deep Tow Survey Shallow Hazards Assessment, Benthic Communities Evaluation, and Archaeological Resource Survey Tesla Berger Geosciences, LLC 2010

2014

BOEMRE Environmental Impact Statement Report – No.

2009-053 Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

Regional Oil Spill Response Plan LLOG Exploration Offshor e, L.L.C. 2014