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-09870

Type - Initial Exploration Plan

Lease(s) - OCS-G34909 Block - 794 Mississippi Canyon Area

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

Drilling, completing, testing and installing of subsea
wellhead and/or manifold for Wells A and B on Lease OCS-G

34909

Not Found

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

should be addressed in an Environmental Assessment.

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

Tommy Hoke

Plan Coordinator Description -

Rig Type - Subject: From: April 17, 2015

# LLOG EXPLORATION OFFSHORE, L.L.C

. 1001 Ochsner Boulevard, Suite 200 Covington, Louisiana 70433



# PUBLIC INFORMATION COPY

INITIAL EXPLORATION PLAN

OCS -G-34909

MISSISSIPPI CANYON BLOCK 794

PREPARED BY:

Kathy Gowland Regulatory Specialist 985-801-4300 (Main)

985-801-4317 (Direct)

kathygo@llog.com

April 8, 2015

Final Copy

### OCS

- G

- 34909 Lease , Mississippi Canyon Block 794

Plan Control No. N

- 9870



## RECORD OF CHANGES

Date of

Submittal Page Amended Brief Synopsis

02/25/2015 Appendix A

Attachment A

- 1

Pages 2 and 3 Corrected OCS Lease Number on Forms 0137 Included pages 4 and 5 Form 0137 for WCD Information

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

INITIAL EXPLORATION PLAN

OCS -G-34909

MISSISSIPPI CANYON BLOCK 794

APPENDIX A Plan Contents

APPENDIX B General Information

APPENDIX C Geological, Geophysical Information

APPENDIX D H2S Information

APPENDIX E Bio logical, Physical and Socioeconomic Information

APPENDIX F Waste and Discharge Information

APPENDIX G Air Emissions Information

APPENDIX H Oil Spill Information

APPENDIX I Environmental Monitoring Information

APPENDIX J Lease Stipulation Information

APPENDIX K Environmental Mitigation Measures Information

APPENDIX L Related Facilities and Operations Information

APPENDIX M Support Vessels and Aircraft Information

APPENDIX N Onshore Support Facilities Information

APPENDIX O Coastal Zone Management Act (CZMA) Information

APPENDIX P Environmental Impact Analysis

APPENDIX Q Administrative InformationMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 1 

## APPENDIX A

PLAN CONTENTS (30 CFR Part 5 50.211 and 5 50.241)

A. Plan information

In accordance with 30 CFR 550.211 and 550.241(a),and NTL No. 2008

- G04 and NTL

2015- N0 1 , LLOG Exploration Offshore, LLC proposes the drilling, completion

, testing

and installation of subsea wellhead and/or manifold for two (2 ) proposed locations on Lease OCS -G-34909, Mississippi Canyon Block 794.

Included as Attachment A -1 is Form BOEM 1 37 “OC S Plan Information Form”, which provides for the drilling, sub-sea completion and te sting of all well locations.

. 

## B. L ocation

Attachment A-2

– Well Location Plat

Attachment A-3

– Bathymetry Map – Seafloor disturbance area (with anchor radius)



## C. Safety & Pollution F eatures

LLOG will utilize a semi

- submersible moored drilling ri g or a DP semi

- submersible rig for the proposed operations. A description of the drilling unit is included on the OCS Plans Information Form. Rig specifications will be made part of the Application for

Permit to Drill.

Safety features on the drilling unit will include well control, pollution prevention, and blowout prevention equipment as described in Title 30 CFR Part 250, Subparts C, D, E and G; and further clarified by BOEM’s Notices to Lessees, and currently policy making invoked by BOEM, EPA and USCG. Appropriate life rafts, life jackets, ring buoys, etc., will be maintained on the facility at all times.

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

.

D. 

## Storage Tanks and Vessels

The following table details the storage tanks and/or production vessels that will store oil (capacity greater than 25 bbls. or more) and be used to support the proposed activities (MODU, barges, platforms, etc.):Mississippi Canyon Block 794

– OCS

- G 3 4909

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 (Marine Diesel) Semi

Submersible 95.24 2 190.5 No. 2 Diesel

- 43

2917.8 4 11,671.2

Total 11,861.7

Type of Storag e
Tank Type of Facility Tank Capacity (bbls) Number of

tanks Total Capacity (bbls) Fluid Gravity (API) Fuel Oil (Marine Diesel) DP Semi

Submersible 164 1 164 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 P revention M easures : Not applicable. The State of Florida is not an affected State by the pr oposed activities in this plan.



## F. Additional measures : LLOG does not propose any additional safety, pollution prevention, or early detection measures, beyond those required in 30 CFR 250 and per December 13, 2010

– Guidance for Deepwater Drillers to Comply with Strengthened Safety and Environmental Standards.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 3 

# O CS Plan Information Form

Attachment A -1 (PUBLIC Information)

### U.S. Department of the Interior OMB Control Number: 1010-0151 Bureau of Ocean Energy Management OMB Approval Expires: 12/31/14



### OCS PLAN INFORMATION FORM

General Information

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

Company Name: BOEM Operator Number:

Address: Contact Person:

Phone Number:

E-Mail Address:

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



### Project and Worst Case Discharge (WCD) Information

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

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

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

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

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

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

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

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

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



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

Proposed Activity Start Date End Date No. of Days

Exploration drilling

Development drilling

Well completion

Well test flaring (for more than 48 hours)

Installation or modification of structure

Installation of production facilities

Installation of subsea wellheads and/or manifolds

Installation of lease term pipelines

Commence production

Other (Specify and attach description)



### Description of Drilling Rig Description of Structure

Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform rig Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed tower

DP Semisubmersible Ot her (Attach Description)

Drilling Rig Name (If Known): Floating production

system Other (Attach Description)



### Description of Lease Term Pipelines

From (Facility/Area/Block) To (Facility/Area/Block) Diamet er (Inches) Length (Feet)



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


### Proposed Well/Structure Location

Well or Structure Name/N umber (If renaming well or structure, reference previous name): Previously reviewed under an approved EP or

DOCD? Yes No

Is this an existing well

or structure? Yes No If this is an existing we ll or structure, list the Complex ID or API No.
Do you plan to use a subsea BOP or a surface BOP on a floa ting facility to conduct your proposed activities? Yes No

WCD info For wells, volume of uncontrolled blowout (Bbls/day): For structures, volume of all storage and pipelines (Bbls): API Gravity of

fluid

Surface Location Bottom-Hole Location (For Wells) Completion (For mult iple completions, enter separate lines)

Lease No. OCS OCS OCS

OCS

Area Name

Block No.

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

Lambert XY

coordinates X: X: X:

X:

X:

Y: Y: Y:

Y:

Y:

Latitude/
Longitude Latitude Latitude Latitude

Latitude

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

Anchor Radius (if applicable) in feet: MD (Feet):
MD (Feet):
MD (Feet): TVD (Feet):
TVD (Feet):
TVD (Feet):



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

Anchor Name

or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =



### Form BOEM- 0137 (December 2011 - Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS PLAN INFORMATION FORM ( CONTINUED ) Include one copy of this page for each proposed well/structure


### Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name): Previously reviewed under an approved EP or

DOCD? Yes No

Is this an existing well

or structure? Yes No If this is an existing well or structure, list the Complex ID or API No.
Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes No

WCD info For wells, volume of uncontrolled blowout (Bbls/day): For structures, volume of all storage and pipelines (Bbls): API Gravity of

fluid

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

Lease No. OCS OCS OCS

OCS

Area Name

Block No.

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

Lambert XY

coordinates X: X: X:

X:

X:

Y: Y: Y:

Y:

Y:

Latitude/
Longitude Latitude Latitude Latitude

Latitude

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

Anchor Radius (if applicable) in feet: MD (Feet):
MD (Feet):
MD (Feet): TVD (Feet):
TVD (Feet):
TVD (Feet):



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

Anchor Name

or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =



### Form BOEM- 0137 (December 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4 B 

# X

X

X



## 23.7°

G 34909



### MISSISSIPPI CANYON

794

N 

# 4,885.00'

E 

# 1,625.00'



# 727,015.00

10,227,755.00

28° 09' 17.154"N

89° 50' 05.688"W

1,467


## 4,400' 87,946WELL / EVENT SPUD TD COMPL

START COMPL

FINISH DESCRIPTION

MC 794 "A" 15-Aug-15 4-Nov-15 82 days

MC 794 "A" 1-Mar-16 20-Apr-16 50 days

MC 794 "B" 1-Jan-17 23-Mar-17 82 days

MC 794 "B" 1-Mar-18 20-Apr-18 50 days 

# PROPOSED ACTIVITIES & TENTATIVE SCHEDULEMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 4 

# Well Location Plats

Attachment A -2 (P UBLIC Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 5 

# Bathymetry Map

Attachment A-3 (Public Information)!( I n l i n e 4 2 5 8 3

I n l i n e 4 2 3 9 1 I n l i n e 4 2 5 3 5

I n l i n e 4 2 1 5 1 I n l i n e 4 2 4 8 7

I n l i n e 4 2 4 3 9

I n l i n e 4 2 1 9 9 I n l i n e 4 2 3 4 3

I n l i n e 4 2 2 9 5

I n l i n e 4 2 2 4 7

C r o s s l i n e 8 1 5 0 I n l i n e 4 2 6 3 1

C r o s s l i n e 8 2 0 0

C r o s s l i n e 8 2 5 0

C r o s s l i n e 8 3 0 0

C r o s s l i n e 8 3 5 0

C r o s s l i n e 8 4 0 0

C r o s s l i n e 8 4 5 0

C r o s s l i n e 8 5 0 0

C r o s s l i n e 8 5 5 0MC 794G34909LLOG Bluewater HoldingsMC 838G33180Noble EnergyMC 750Not LeasedMC 795G34459Statoil Gulf of MexicoMC 793G33177Walter Oil and Gas Corp.MC 839Not LeasedMC 837G33179Noble EnergyMC 749G33174Statoil Gulf of MexicoMC 751G33175LLOG Bluewater HoldingsMC 794-A

1 , 5 0 0 1 , 5 0 0

1 , 2 5 0 1 , 7 5 0

1 , 2 5 0X = 726,564.00 ft Y = 10,227,516.40 ft28° 09' 14.689" N 89° 50' 10.660" W5,124 ft FNL 2,076 ft FELGeodetic Datum: NAD27Projection: UTMZone: 16NGrid Units: FeetInterpretation By: Brandon BurkeCartography: Sandra R. MilsonProject No.: 14-11-18Date: February 2015Map Prepared by:Berger Geosciences, LLC.© Berger Geosciences, LLC. 2015Block 794Mississippi Canyon AreaGulf of MexicoMap 1BathymetryProposed Well MC 794-ALease No. G349093LegendÎLat/Long Grid Points0 1,000 2,000 3,000 4,000500U.S. Survey FeetMississippi CanyonStudy AreaUTM Northing & Easting Grid Lines**IMPORTANT NOTICE**This map is not intended for navigation purposes.Public information obtained from BOEM database (February 2015).Grid Information:Data Source: 3-D SeismicMethod: KrigingContour Interval: 50 ftSpacing: 30 ftSearch Radius: 250 ft1:12,000Scale =



### 710,000 E 720,000 E 730,000 E10,230,000 N10,220,000 N3-D Seismic Inlines & CrosslinesSeafloor Assessment AreaShipping Fairways!(Proposed WellDepth(Below Sea Level)1,921 ft1,230 ft36" X 28" 

### 89°52'0"W28°8'0"N



### 89°52'0"W28°10'0"N 

### 89°50'0"W28°8'0"N



### 89°50'0"W28°10'0"N4,400-ft Maximum Anchor Radius1,000-ft Buffer from Maximum Anchor Radius2,000-ft Radius Circle(as per NTL 2009-G40)250-ft Contours50-ft Contours!( I n l i n e 4 2 5 8 3

I n l i n e 4 2 3 9 1 I n l i n e 4 2 5 3 5

I n l i n e 4 2 1 5 1 I n l i n e 4 2 4 8 7

I n l i n e 4 2 4 3 9

I n l i n e 4 2 1 9 9 I n l i n e 4 2 3 4 3

I n l i n e 4 2 2 9 5

I n l i n e 4 2 2 4 7

C r o s s l i n e 8 1 5 0 I n l i n e 4 2 6 3 1

C r o s s l i n e 8 2 0 0

C r o s s l i n e 8 2 5 0

C r o s s l i n e 8 3 0 0

C r o s s l i n e 8 3 5 0

C r o s s l i n e 8 4 0 0

C r o s s l i n e 8 4 5 0

C r o s s l i n e 8 5 0 0

C r o s s l i n e 8 5 5 0MC 794G34909LLOG Bluewater HoldingsMC 838G33180Noble EnergyMC 750Not LeasedMC 795G34459Statoil Gulf of MexicoMC 793G33177Walter Oil and Gas Corp.MC 839Not LeasedMC 837G33179Noble EnergyMC 749G33174Statoil Gulf of MexicoMC 751G33175LLOG Bluewater HoldingsMC 794-B

1 , 5 0 0 1 , 5 0 0

1 , 2 5 0 1 , 7 5 0

1 , 2 5 0X = 727,015.00 ft Y = 10,227,755.00 ft28° 09' 17.154" N 89° 50' 05.688" W4,885 ft FNL 1,625 ft FELGeodetic Datum: NAD27Projection: UTMZone: 16NGrid Units: FeetInterpretation By: Brandon BurkeCartography: Sandra R. MilsonProject No.: 14-11-18Date: February 2015Map Prepared by:Berger Geosciences, LLC.© Berger Geosciences, LLC. 2015Block 794Mississippi Canyon AreaGulf of MexicoMap 1BathymetryProposed Well MC 794-BLease No. G349093LegendÎLat/Long Grid Points0 1,000 2,000 3,000 4,000500U.S. Survey FeetMississippi CanyonStudy AreaUTM Northing & Easting Grid Lines**IMPORTANT NOTICE**This map is not intended for navigation purposes.Public information obtained from BOEM database (January 2015).Grid Information:Data Source: 3-D SeismicMethod: KrigingContour Interval: 50 ftSpacing: 30 ftSearch Radius: 250 ft1:12,000Scale =



### 710,000 E 720,000 E 730,000 E10,230,000 N10,220,000 N3-D Seismic Inlines & CrosslinesSeafloor Assessment AreaShipping Fairways!(Proposed WellDepth(Below Sea Level)1,921 ft1,230 ft36" X 28" 

### 89°52'0"W28°8'0"N



### 89°52'0"W28°10'0"N 

### 89°50'0"W28°8'0"N



### 89°50'0"W28°10'0"N4,400-ft Maximum Anchor Radius1,000-ft Buffer from Maximum Anchor Radius2,000-ft Radius Circle(as per NTL 2009-G40)250-ft Contours50-ft ContoursMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 6 

## APPENDIX B

GENERAL INFORMATION (30 CFR Part 550.213 and 5 50.243)

A. Applications and Permits

The re are no Federal/State applications to be submitted fo r the activities provided for in this Plan (exclusive to BOEM permit applications and general permits issued by the EPA and COE)

Application/Permit Issuing Agency Status

N/A



## B. Drilling Fluids

Type of Drilling Fluid Estimated Volume of Drilling Flu id to be used per Well

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

Oil

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

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



## C. New Or Unusual Technology

LLOG do es 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 facilities proposed in this Initial Exploration Plan are satisfied by an area wide bon d, furnished and maintained according to 30 CFR Part 256; subpart I; NTL No. 200 0- G16, “Guidelines for General Lease Surety Bonds,” and additional security under 30 CFR 256.5 3(d) and NTL No.

2008- N0 7 “Supplemental Bond Procedures.”



## E. Oil Spill Responsibilit y (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 Respons ibility (OSFR) for Covered Facilities.”Mississippi Canyon Block 794

– OCS

- G 3 4909

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

S ee the following Worst Case Discharge Calculations (Proprietary)

– Attachment B-1

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

- Attachment

B-2.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 8 

# NTL 2010

- N06 Data

Worst Case Discharge Calculations

Attachment B-1

(Proprietary Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 9 

# NTL 2010

- N06 Data

Blowout Scenario

Attachment B-2 (Public Information)BLOWOUT SCENARIO

MC 794 Created by: John White

Last Revised: 2/19/2015 Page 1 of 7
Confidential

1 BLOWOUT SCENA R IO

Pursuant with 30 CFR 250.213(g), 250.219, 250,250 and NTL 201 5- N0 1 the following attachment provides a blowout scenario description, information regarding any oil spill, WCD results and assumptions of potential spill and additional measures taken to firstly enhance the ability to prevent a blowout and secondly to manage a blowout scenario if it occurred.

INFORMATION REQUIREMENTS

PROPOSED PROSPECT INFORMATION

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

MC 794 “A ” OCS

- G

- 34909 14 60 726,56 4.0 ’ 10, 227,516.40 ’ 28 ° 0 9 ’ 14.689 ” 8 9 ° 50 ’ 10.660 ”

MC 794 “ B ” OCS

- G

- 3 4909 14 67 727,015.0 ’ 10, 227,755.0 ’ 28 ° 09 ’ 17.154 ” 8 9 ° 50 ’ 05.688 ”

INFORMATION REQUIREMENTS

A) Blowout scenario

The MC 794 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 int ermediate casing strings and a MODU rig with marine riser and a subsea BOP system. A hydrocarbon influx

and a well control event occurr ing 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 Initial EP Type of Activity Drilling Facility Location (area / block) MC 794 (surface location)

Faci lity Designation MODU Distance to Nearest Shoreline (miles) ~5 9 Uncontrolled Blowout (Volume per day) 87,946 bbls (max estimated) Type of Fluid Crude

C) Total volume and maximum duration of the potential blowout

Duration of Flow (days) 1 29 days total ( see Relief Well Response Estimate below ) Total Volume of Spill (bbls)

~ 8.55 MMBO based on 1 29 days of uncontrolled flow based

on simulat or models (steady

- state model)

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

Submitted as Attachment B

- 1 in the Proprietary Copy of this Plan - Omitted from Public Information CopiesBLOWOUT SCENARIO

MC 794 Created by: John White

Last Revised: 2/19/2015 Page 2 of 7
Confidential

2 E) Potential for the well to bridge over

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

- situ stress, rock strength and fluid velocities at the sand face. Given the substantial fluid velocities inherent in the WCD, and the scenario as defined where the formation is not supported by a cased and cemented wellbore, it is possible that the borehole may fall/collapse/bridge over within a span of a few days, significantly reducing the outflow of the rates. For this blowout scenario, no bridging is considered.

F) Likelihood for intervention to stop blowout

The likelihood of surface intervention to stop a blowout is based on some of the following equipment specific to potential MODU’s to be contracted for this well. It is reasonable to assume that the sooner you are able to respond to the initial blowout, the better likelihood there is to control and contain the event due to reduced pressures at the wellhead

, less exposure of well fluids to erode and compromise the well control equipment, and less exposure of hydrocarbons to the surface to safeguard personnel and equipment in an emergency situ ation. Thi s equipment includes:

• Secondary Acoustic BOP Control System – typically fitted on DP MODU’s presently operating in the GOM. This system has the ability to communicate and function specific BOP controls from the surface in the event of a failure of the primary umbilical control system. This system typically can establish BOP controls from the surface acoustic system package on the rig or by deploying a second acoustic package from a separate vessel of opportunity. This system may not be included on all M ODU’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 ensu re proper functionality. These function include the following (at a minimum):

- Blind/shear ram close

- Pipe ram close

- LMRP disconnect

- WH disconnect

• Deadman / Autoshear function – typically fitted on DP MODU’s and but to be on all MODU’s operating in the GOM according to new requirements, this equipment allows for an automated pre

- programmed sequence of functions to close the casing shear rams and the blind/shear rams in the event of an inadvertent or emergency disconnect of the LMRP or loss of both hydraulic and electrical supply from the surface control system.

In the event that the intervention systems for the subsea BOP’s fail, LLOG will initiate call out of a secondary containment / surface intervention system supported by the Helix Well Containment Group (HWCG) of which LLOG is a member. This system incorporates a capping stack capable of being deployed from the back of a vessel of opportunity equipped with an ROV or from the Helix Q4000 DP MODU. Based on the potential integrity concerns of the well, a “cap and flow” system can be deployed which may include the Helix Producer 1 capable of handling up to 55,000 BOPD flowback.BLOWOUT SCENARIO

MC 794 Created by: John White

Last Revised: 2/19/2015 Page 3 of 7
Confidential

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 modifications based on actual wellbore conditions. Standard equipment is available through the Helix Deepwater Containment System to fit the wellhead and BOP stack profiles used for the drilling of the above mentioned well.

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

LLOG currently has three deepwater MODU ’s under contract (Noble Amos Runner moored semi

, Sevan Louisiana DP semi, and Seadrill West Neptune DP drillship). In the event of a blowout scenario that does not involve loss or damage to the rig such as an inadvertent disconnect of the BOP’s, then the existing contracted rig may be available for drilling the re lief 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 potential ly available to support the relief well drilling operations. Rig share and resource sharing agreements are in place between members of the Helix Well Containment Group. The ability to negotiate and contract an appropriate rig or rigs to drill relief wells is highly probable in a short period of time. If the rig or rigs are operating, the time to properly secure the well and mobe the rig to the relief well site location is

estimated to be about 14 to 21 days. Dynamically positioned (DP) MODU’s would be t he preferred option due to the logistical advantage versus a moored MODU which may add complications due to the mooring spread.

VESSELS OF OPPORTUNITY

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

OPERATION SPECIFIC VESSEL OF OPPORTUNITY

Intervention and Containment • Helix Q4000 (DP Semi)

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

• Diamond Ocean Onyx (Moored Semi)

• Ensco 8500 Series Rigs (DP Semi)

• Transocean Enterprise (DP Drillship)

• Seadrill West Neptune (DP Drillship)

ROV / Mult i

- 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 blowoutBLOWOUT SCENARIO

MC 794 Created by: John White

Last Revised: 2/19/2015 Page 4 of 7
Confidential

4 Pursuant to BOEM

- 2010

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

reduce the likelihood of a blowout are largely based on proper planning and communication, identification of potential hazards, training and experience of personnel, use of good oil field practices and proper equipment that is properly maintained and inspected f or 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 an y needed earth modeling and identifying any potential drilling hazards or well specific conditions to safeguard the safety of the crews when well construction operations are underway. Once the design criteria and well design is established, the well design is modeled for the lifecycle of the wellbore to ensure potential failure modes are eliminated. Pursuant to BOEM

- 2010

- 0034 Interim Final Rules implemented additional considerations of a minimum of 2 independent barriers for both internal and external flow paths in addition to proper positive and negative testing of the barriers

.

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

best wa y prevent a blowout incident. Contractor ’s personnel and service personnel training requirements are verified per regulatory requi r ements per guidelines issued in BOEM

- 2010

- 034

Interim Final Rules

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

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

- spud meetings are conducted with rig crews and service providers to discuss, inform and as needed improve operations and well plans for safety and efficiency considerations. Dail y meetings are conducted to discuss planning and potential hazards to ensure state of preparedness and behavior is enforced to create an informed and safe culture for the operations. Any changes in the planning and initial wellbore design is incorporated and communicated in a Management of Change (MOC) process to ensure continuity for all personnel.

Use of established good oil field practices that safeguard crews and equipment are integrated to incorporate LLOG’s, the contractor and service provider pol icies.

Additional personnel and equipment will be used as needed to elevate awareness and provide real time monitoring of well conditions while drilling such as MWD/LWD/PWD tools used in the bottom hole assemblies. The tool configuration for each open hole section varies to optimize information gathered including the use of Formation

- Pressure

- While

- Drilling (FPWD) tools to establish real time formation pressures and to be used to calibrates pore pressure models while drilling. Log information and pressure data is used by the drilling engineers, geologist and pore pressure engineers to maintain well control and reduced potential events such as well control events and loss circulation

events.

Mud loggers continuously monitor return drilling fluids, drill gas levels and cuttings as well as surface mud volumes and flow rates, rate of penetration and lithology/paleo to aid in understanding trends and geology being drilled. Remote monitoring of real time drilling parameters and evaluation of geologic markers and pore pressure indicators is used to identify potential well condition changes.

Proper equipment maintenance and inspection program for same to before the equipment is required. Programmed equipment inspections and maintenance will be performed to ensure the equipment operability and condition. Operations will cease as needed in order to ensure equipment and well conditions are maintained and controlled for the safety of personnel, rig and subsurface equipment

and the environment.BLOWOUT SCENARIO

MC 794 Created by: John White

Last Revised: 2/19/2015 Page 5 of 7
Confidential

5 I) Measures to co nduct effective and early intervention in the event of a blowout

In conjunction with the LLOG Exploration’s “Well Control Emergency Response Plan” and as required by NTL 2010

- N06, the following is provided to demonstrate the potential time needed for perf orming secondary intervention and drilling of a relief well to handle potential worst case discharge for the proposed prospect. Specific plans are integrated into the Helix Well Containment Groups procures to be approved and submitted with the Application for Permit to Drill. Equipment availability, backup equipment and adaptability to the potential scenarios will need to be addressed based on the initial site assessment of the seafloor conditions for intervention operations. Relief well equipment such a s backup wellhead equipment and tubulars will be available in LLOG’s inventory for immediate deployment as needed to address d rilling the relief well(s).

SITE SPECIFIC PROPOSED RELIEF WELL AND INTERVENTION PLANNING

No platform was considered for drilling r elief wells for this location due to location, water depth and lack of appropriate platform within the area. For this reason a moored or DP MODU will be preferred / required.

Nearest production pipeline tie

- in is located ~ 4 miles from LLOG 6

- 5/8” pipeline running from the

LLOG MC 751 well subsea manifold located on MC 751 block. Other subsea manifold tie

- in include

~5 miles from MC 707 LLOG subsea manifold

. Potential to utilize these lines in the event of a “cap

and flow” scenario are limited but a vailable

.

Relief well sites have been initially identified to address blowout scenarios for the potential geologic targets for the proposed wells. A total of 3 relief well surface locations in MC 794 are proposed for

the 2 proposed drill sites

. The 2 dr ill site s are the most probable well sites for a development

scenario

. Based o n 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 poten tial

shallow hazards.

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

MC 794 “A & B ” OCS

- G

- 3 4909 MC 794 N Relief Well #1 * 726,950 ’ 10, 230,096 ’

MC 794 S SW Relief Well #2 * 725,274 ’ 10, 224,331 ’

MC 794 N NW Relief Well #3 * 725,218 ’ 10, 22 9,828 ’
“*” Indicates relief well locations common for proposed wells

RELIEF WELL RESPONSE TIME ESTIMATE

OPERATION TIME ESTIMATE (DAYS)

IMMEDIATE RESPONSE

• safeguard personnel, render first

- aid

• make initial notifications

• implement short term intervention (if possible)

• implement spill control

• develop Initial Action Plan 1

INTERIM REPSONSE

• establish Onsite Command Center and Emergency Management Team

• assess well control issues

• mobilize people and equipment (Helix DW Containment System)

• implement short term intervention and containment (if possible)

• develop Intervention Plan 4BLOWOUT SCENARIO

MC 794 Created by: John White

Last Revised: 2/19/2015 Page 6 of 7
Confidential

6 • 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

• cont inue intervention and containment measures

• continue spill control measures

• drill relief well (s) 90

PERFORM HYDRAULIC KILL OPERATIONS / SECURE BLOWNOUT WELL

• continue intervention and containment measures

• continue spill control measures

• perf orm hydraulic kill operations, monitor well, secure well 20

ESTIMATED TOTAL DAYS OF UNCONTROLLED FLOW 1 2 9 SECURE RELIELF WELL(S) / PERFORM P&A / TA OPERATIONS / DEMOBE 30

TOTAL DAYS 1 5 9!(!(!(!(!(!(!(!(MC837G33179Noble EnergyMC838G33180Noble EnergyMC839Not LeasedMC793G33177Walter Oil and Gas Corp.MC794G34909LLOG Bluewater Holdings M C 7 9 5

G 3 4 4 5 9

S t a t o i l G u l f o f M e x i c o

M C 7 4 9

G 3 3 1 7 4

S t a t o i l G u l f o f M e x i c oMC750Not LeasedMC751G33175LLOG Bluewater HoldingsMC 794-AMC 794-B

R e l i e f W e l l 1

R e l i e f W e l l 2

R e l i e f W e l l 3

R e l i e f W e l l 4

R e l i e f W e l l 5MC 794-C3 730,000 E10,225,000 N10,230,000 NProposed Relief Wells forProposed Wells MC 794-AMC 794-B and MC 794-CLease No. G34909Geodetic Datum: NAD27Projection: UTMZone: 16NGrid Units: FeetInterpretation By: Brandon BurkeCartography: Sandra R. MilsonProject No.: 14-11-18Date: February 20150 1,000 2,000 3,000 4,000U.S. Survey FeetBlock 794Mississippi Canyon AreaGulf of Mexico1:24,000Scale =Map Prepared by:Berger Geosciences, LLC.© Berger Geosciences, LLC. 2015**IMPORTANT NOTICE**This map is not intended for navigation purposes.Public information obtained from BOEM database (January 2015).

720,000 E

X = 712,800.00

710,000 E 89°52'0"W28°8'0"N

89°52'0"W28°10'0"N 89°50'0"W28°8'0"N

89°50'0"W28°10'0"N X = 728,640.00X = 10,216,800.00X = 10,232,640.00Proposed Well LocationsWell NameBlockBlock Call (N-S)Block Call (E-W)LatitudeLongitudeX (ft)Y (ft)Relief Well 1 MC 794 2,543 ft FNL 1,689 ft FEL 28° 09' 40.309" N 89° 50' 07.015" W 726,950.89 10,230,096.93Relief Well 2 MC 794 7,531 ft FSL 3,366 ft FEL 28° 08' 42.877" N 89° 50' 24.227" W 725,274.02 10,224,331.07Relief Well 3 MC 794 2,811 ft FNL 3,421 ft FEL 28° 09' 37.257" N 89° 50' 26.279" W 725,218.83 10,229,828.96Relief Well 4 MC 794 6,836 ft FNL 7,849 ft FWL 28° 08' 56.377" N 89° 51' 16.232" W 720,649.11 10,225,804.15Relief Well 5 MC 794 1,851 ft FNL 7,449 ft FEL 28° 09' 45.821" N 89° 51' 11.488" W 721,191.38 10,230,789.11Proposed Relief Well LocationsLegendÎLat/Long Grid PointsUTM Northing and Easting Grid LinesBlock Boundary!(Proposed Wells!(Relief WellsWell NameBlockBlock Call (N-S)Block Call (E-W)LatitudeLongitudeX (ft)Y (ft)MC 794-A MC 794 5,124 ft FNL 2,076 ft FEL 28° 09' 14.689" N 89° 50' 10.660" W 726,564.00 10,227,516.40MC 794-C MC 794 4,320 ft FNL 5,616 ft FEL 28° 09' 21.815" N 89° 50' 50.381" W 723,024.25 10,228,319.60MC 794-B MC 794 4,885 ft FNL 1,625 ft FEL 28° 09' 17.154" N 89° 50' 05.688" W 727,015.00 10,227,755.00Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 10 

## APPENDIX C

GEOLOGICAL AND GEOPHYSICAL INFORMATION (30 CFR Part 550.214 and 5 50.244 )

A. Geological Description

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



## B. Structure Contour Maps

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



## C. Interpreted Seismic Lines

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



## D. Geological Structure Cross

- Sections

An interpreted geological cross section depicting the proposed well 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 Haza rds Report

AUV Archaeological Survey, OCS

- G 34909 Lease, Mississippi Canyon Block 794. This survey was conducted for LLOG Exploration by Tesla Offshore, L.L.C., dated February , 2015, submitted to BOEM on February 4, 2015. Shallow Hazards

Assessment and Benthic Communities Evaluation, Mississippi Canyon Block 794,

OCS

- G 34909 Lease, Berger Geosciences, L.L.C. prepared for LLOG Exploration, February, 2015, submitted to BOEM on February 11, 2015.



## F. Shallow Hazards Assessment

Utilizing the 3D deep seismic exploration data a shallow hazards analysis was prepared for the proposed surface locations, evaluating seafloor and subsurface geologic and manmade features and conditions, and is included as Attachment C-5.Mississippi Canyon Block 794

– OCS

- G 3 4909

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 P lan; therefore, tables providing seismic time versus depth for the proposed well l ocations are not required.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 12 

# Geological Description

Attachment C-1 (Proprietary Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 13 

# Structure Maps

Attachment C-2 (Proprietary Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 14 

# Deep Seismic Lines

Attachment C-3 (Proprietary Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 15 

# Cross Section Maps

Attachment C-4 (Proprietary Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 16 

# Shallow Hazards Assessment

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

Fax: 225.744.3116

www.teslaoffshore.com



### February 2, 2015 Job #14-042-41

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 349 09 Well ‘ A ’

Bl o ck 794

, Mississippi Canyon Area Archaeological Assessment

Dear Staff:

LLOG Exploration Offshore, L.L.C

. (LLOG) proposes to drill the OCS

- G 349 09 Well ‘ A ’

from the followi ng surface location in Block 794

, Mississippi Canyon Area:

Datum:

NAD 27 Spher oid:

Clarke 1866 Projection:

UTM Zone:

16 N Central Meridian:

87° 00 ’ West

Latitude: 2 8 ° 09 ' 14

. 689 ” N Longitude: 89 ° 50 ' 10

. 660 ” W

X: 726

, 564 .00 Y: 10, 227

, 516 .4 0

F E L: 2

, 076 .00’ F N L: 5

, 123

. 60 ’

LLOG contracted Tesla Offshore, LLC to conduct a high

- resolution geophysical survey

centered on Block 794 with coverage extending into Blocks 750, 751, and 795

, Mississippi Canyon Area . The survey was performed between December 16 and 17

, 201 4 , using 2 00

- meter primary grid spacing and 900

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

- G07

) in accordance with the Bureau of Ocean Energy Management (BOEM) Gulf of Mexico OCS Region. The drilling platform for this well is currently unknown. Therefore, this assessment has been prepared assuming that the well will be drilled with an anchored drill rig, taking into account a radius of 4

, 500 ’ (plus 1,000’ buffer) surrounding the proposed wel l site.

 Water depth is approximately 1, 460 feet BSL surrounding the proposed drill site. The overall seafloor gradient increases from northwest to southeast at a rate of approximately 89 feet/mile in the northeastern portion of the survey grid, however, the seafloor slopes more rapidly through the southeastern portion of the survey grid at an approximate rate of 150 feet/mile. Bathymetric data did not indicate any significant areas of relief at the seafloor that could indicate a possible shipwreck or

oth er culturally significant material.

 Seafloor soils

are reported to be marine deposits (MMS 1983 Visual No. 3; MMSTESLA OFFSHORE



### LLOG Exploration Offshore, L.L.C. Proposed OCS-G 349 09 Well ‘A’

Block 794

, Mississippi Canyon Area Archaeological Assessment Page 2

1986 Visual No. 5).

 Existing installations are not present within the survey grid. The closest installation, P&A Well No. 1 in Block 839, is located approximately 1 4

, 735 ’ to the S E of the proposed surface location.

 Magnetic data

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

 Sonar data recorded a total of 14 sonar targets throughout the entire survey area

, eight (8) of which are located within the proposed anchor radius

. The majority of these were small, indistinct features , howeve r three of the recorded sonar targets were interpreted as possible cultural resources and include targets no. 7, 9, and 13

. Target no. 7 is a strongly reflective, semi

- circular feature measuring approximately 24’ in length, with an average width of 2’, an d appears to be flush with the seafloor. It is located approximately 2,815’ NW of the proposed surface location and is recommended for avoidance by 500ft. Target no. 9 is an oblong, variably

- reflective,

mound

- like feature, measuring approximately 17’ x 2 5’ with 2.5’ of measured relief above the surrounding seafloor. Due to its proximity to interpreted geologic features, target no. 9 may represent a naturally

- occurring biologic or geologic feature, but is also consistent with acoustic imagery of a disarti culated wooden shipwreck, or preserved shipwreck components and therefore warrants avoidance by 1,000ft pending further investigation. Target no. 9 is located approximately 1,510’ W NW of the proposed surface location. Target no. 13 is a composite target consisting of three discrete objects with an overall length of 79’. The individual features within target no. 13 are oriented north

- south and measure approximately 12’ x 11’ x 2’, 9’ x 7’, and 12’ x 25’. Only the northernmost section has any measurable relief above the surrounding seafloor. Target no. 13 is not correlated with any observed fault scarps, outcrops, or other areas of naturally

- occurring seafloor features. Its size, shape, orientation, and variable reflectivity against an otherwise weakly reflective seafloor suggest that this target could represent a shipwreck. Target no. 13 is located approximately 4,230’ SW of the proposed well site and should be avoided by a distance of 1,000 ’

. The remaining targets are not considered archaeologically significant, but are recommended for avoidance as possible hazard s by 1 0 0 ’

.

Sonar data also recorded possible drag scars, fault scarps, expulsion

- like fe atures

, and associated outcrops within the survey grid

. The closest area with probable expulsion

- li ke features was observed approximately 470’ SSE of the proposed well site; the closest observed outcrops are located approximately 480’ SSE of the proposed well site. An approximately west to east

- southeast trending fault scarp is located approximately 11 0’ SSW of the proposed well site.

 Supplemental Subbottom d ata depict a moderately reflecting seafloor underlain by approximately 135 ’ of parallel to subparallel , well stratified sediments before acoustic

attenuation sets in

. A small isolated gas intrusio n was observed close to theTESLA OFFSHORE



### LLOG Exploration Offshore, L.L.C

. Proposed OCS-G 349 09 Well ‘A’

Block 794

, Mississippi Canyon Area Archaeological Assessment Page 3

proposed well site at a depth of approximately 77’ BML. There is no potential for prehisto ric sites in this portion of Mississippi Canyon Area. The shallow hazards and benthic analyses for the site and surrounding area are based on processed 3

- D data

and ha ve been provided as a separate assessment by Berger Geosciences, LLC

.

Three (3) targets of potential archaeological significance were identified within the proposed anchor radius, none of which is within 300m (1,000’ ) of the proposed surface location. Targets no. 7, 9, and 13 are located between approximately 1,500 and 4,200 ’ from the proposed well site. If an anchored rig is utilized, the operator w ill ensure that anchors and anchor chains avoid any designated targets by the recommended distance.

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 PhD

, RPA John Allen, PG Marine Archaeologist Marine Geologist36499 Perkins Road Prairieville, Louisiana 70769 Telephone: 225.673.2163

Fax: 225.744.3116

www.teslaoffshore.com



### February 2, 2015 Job #14-042-41

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 349 09 Well ‘ B ’

Bl o ck 794

, Mississippi Canyon Area Archaeological Assessment

Dear Staff:

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

- G 349 09 Well ‘ B ’

from the followi ng surface location in Block 794

, Mississippi Canyon Area:

Datum:

NAD 27 Spher oid:

Clarke 1866 Projection:

UTM Zone:

16 N Central Meridian:

87° 00 ’ West

Latitude: 2 8 ° 09 ' 1 7

. 154 ” N Longitude: 89 ° 50 ' 05

. 688 ” W

X: 72 7

, 015 .00 Y: 10, 227

, 755

. 0 0

F E L: 1

, 625 .00’ F N L: 4

, 885

. 0 0 ’

LLOG contracted Tesla Offshore, LLC to conduct a high

- resolution geophysical survey

centered on Block 794 with coverage extending into Blocks 750, 751, and 795

, Mississippi Canyon Area . The survey was performed between December 16 and 17

, 201 4 , using 2 00

- meter primary grid spacing and 900

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

- G07

) in accordance with the Bureau of Ocean Energy Management (BOEM) Gulf of Mexico OCS Region. The drilling platform for this well is currently unknown. Therefore, this assessment has been prepared assuming that the well will be drilled with an anchored drill rig, taking into account a radius of 4

, 500 ’ (plus a 1,000’ buffer) surrounding the proposed w ell site.

 Water depth is approximately 1, 46 7 feet BSL surrounding the proposed drill site.

The o verall seafloor gradient increases from northwest to southeast at a rate of approximately 89 feet/mile in the northeastern portion of the survey grid, however

, the seafloor slopes more rapidly through the southeastern portion of the survey grid at an approximate rate of 150 feet/mile. Bathymetric data did not indicate any significant areas of relief at the seafloor that could indicate a possible shipwreck or

o ther culturally significant material.

 Seafloor soils

are reported to be marine deposits (MMS 1983 Visual No. 3; MMSTESLA OFFSHORE



### LLOG Exploration Offshore, L.L.C. Proposed OCS-G 349 09 Well ‘ B ’

Block 794

, Mississippi Canyon Area Archaeological Assessment Page 2

1986 Visual No. 5).

 E xisting installations are not present within the survey grid. The closest installation, P&A Well No. 1 in Block 839, is located approximately 1 4

, 660 ’ to the S E

of the proposed surface location.

 Magnetic data

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

 Sonar data recorded a total of 14 sonar targets throughout the entire survey area

, six (6) of which are located within the proposed anchor radius

. The majority of these were small, indistinct features , howev er two of the recorded sonar targets were interpreted as possible cultural resources and include targets no. 7 and 9

. Target no. 7 is a strongly reflective, semi

- circular feature measuring approximately 24’ in length, with an average width of 2’, and appe ars to be flush with the seafloor. It is located approximately 2, 9 5 0 ’ NW of the proposed surface location and is recommended for avoidance by 500ft. Target no. 9 is an oblong, variably

- reflective, mound

- like feature, measuring approximately 17’ x 25’ wit h 2.5’ of measured relief above the surrounding seafloor. Due to its proximity to interpreted geologic features, target no. 9 may represent a naturally

- occurring biologic or geologic feature, but is also consistent with acoustic imagery of a disarticulate d wooden shipwreck, or preserved shipwreck components and therefore warrants avoidance by 1,000 ’ pending further investigation. Target no. 9 is located approximately 1, 890 ’ W NW of the proposed

surface location. The remaining targets within the proposed a nchor radius are not considered archaeologically significant, but are recommended for avoidance as possible hazard s by 1 0 0 ’

.

Sonar data also recorded possible drag scars, fault scarps, expulsion

- like fe atures

, and associated outcrops within the survey g rid

. The closest area with probable expulsion

- like features was observed approximately 640’ south of the proposed well site; the closest observed outcrops are located approximately 670’ south of the proposed well site

. An approximately south west to nort h east trending fault scarp is located approximately 410 ’ S SE of the proposed well site.

Supplemental Subbottom d ata depict a moderately reflecting seafloor underlain by approximately 140’ of parallel to subparallel, well stratified sediments before acoust ic

attenuation sets in. The shallow hazards and benthic analyses for the site and surrounding area are based on processed 3

- D data and have been provided as a separate assessment by Berger Geosciences, LLC.

Two (2) targets of potential archaeological significance were identified within the proposed anchor radius, neither of which is within 300m (1,000 ’ ) of the proposed surface location. Targets no. 7 and 9 are located between approximately 1,890 and 2,960 ’ fromTESLA OFFSHORE



### LLOG Exploration Offshore, L.L.C. Proposed OCS-G 349 09 Well ‘ B ’

Block 794

, Mississippi Canyon Area Archaeological Assessment Page 3

the proposed well site and are unlikely to be impacted by drilling at the proposed site. If an anchored rig is utilized, the operator will ensure that anchors and anchor chains avoid any designated targets by the recommended distance.

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 PhD, RPA John Allen, PG Marine Archaeologist Marine GeologistMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 17 

# High Resolution Seismic Lines

Attachment C -6 (Proprietary Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 18 

# Stratigraphic Column

Attachment C-7 (Proprietary Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 19 

## A PPENDIX D

HYDR OGEN 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 250.4 90 (c) and NTL No. 2009- G3 1 “Hydrogen Sulfide”, LLOG requests that the proposed location s be classified H2S absent.



## C. H2S Contingency Plan

Not applicable for the proposed operations.



## D. Modeling Report

Not applicable to the proposed operations.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 20 

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

A. High

- Densit y Deepwater Benthic Comm unities Information

Features or areas that could support high

- density benthic communities are estimated to occur in less than one percent of the Gulf of Mexico (MMS, 2009). These communities can be damaged by oil and gas activities that disturb the seafloor in the immediate vicinity of the communities; therefore, high

- density benthic communities are protected.

Locations A and B have a slight north

- south trending linear banding parallel to the acquisition direction is evident on the seafloor amplitude rendering; however, this does not impact the assessment of the survey area. Although anomalous seafloor amplitudes occur within the southwestern portion of the survey where there is an expulsion mound, there are no seafloor amplitude anomalies within the maximum anchor radius. There are no water bottom anomalies identified by the BOEM (2013) within the maximum anchor radius.

Features or areas that could support high

- density chemosynthetic communities or other

benthic communities are not anticipated within the maximum anchor radius for proposed

well Locations A and B.

Features or areas that could support high

- density chemosynthetic or other benthic communities are not anticipated within 2,000’ of proposed well Locations A and B.



## B. Topogra phic Features Map

The activities proposed in this Plan are not affected by 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) Map

Mississippi Canyon Block 794 is not located within the vicinity of a proposed live bottom (Pinnacle trend) area.



## E. Live Bottoms (Low Relief) Map

Mississippi Canyon Block 794 is no t located within the vicinity of a proposed live bottom (Low Relief) area.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 21 

## F. Potentially Sensitive Biologic al Features Map

Mississippi Canyon Block 794 is not located within the vicinity of a proposed sensitive biological feature area.

G. 

## Threatened or En dangered Species, Critical Habitat, and Marine

Mammal Information

.

Proposed activities in Mississippi Canyon Block 794 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 794 , LLOG will mitigate impact through compliance with NTL 2012

- G01, G02 and NTL 2012 BSEE

- G01. See Attachment E

- 1

for a list of the NOAA Species known in the Gulf of Mexico.

H. 

## Archaeological Report

AUV Archaeologic al Survey, OCS

- G 34909 Lease, Mississippi Canyon Block 794. This survey was conducted for LLOG Exploration by Tesla Offshore, L.L.C., dated February , 2015, submitted to BOEM on February 4, 2015. Shallow Hazards Assessment and Benthic Communities Evaluation, Mississippi Canyon Block 794,

OCS

- G 34909 Lease, Berger Geosciences, L.L.C. prepared for LLOG Exploration, February, 2015, submitted to BOEM on February 11, 2015.



## J. Air and Water Quality Information

Not applicable to proposed operations.



## K. Socioeconomi c Information

No t applicable to proposed operations.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 22 

# NOAA Species Known in GOM

Attachment E-1 (Public Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 23 

## A PPENDIX F

WASTE AND DISCHARGE INFORMATION (30 CFR PART 5 50.217 AND 5 50.248)

A. Projected Gene rated 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 794

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 62,438 bbls/well 7,599 bbls/day/well Discharge overboard No

Cuttings wetted with water-based fluid Cuttings generated while using water based drilling fluid. 3,391 bbls/well 413 bbls/day/well Discharge overboard No

Cuttings wetted with synthetic-based fluid Cuttings generated while using synthetic based drilling fluid. 6,865 bbls/well 364 bbls/day/well Discharge overboard No

Will humans be there? If yes, expect conventional waste

EXAMPLE: Sanitary waste water Sanitary waste from living

quarters X bbl/well X bbl/hr/well chlorinate and discharge

overboard No

Domestic waste Misc waste for living quarters 16,951 bbls/well 2.7 bbls/hr/well Discharge overboard (no free oil) No

Sanitary waste Processed sanitary waste from living quarters 11,300 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 NA NA NA NA NA

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 well



## MC 794 Projected generated waste Solid and Liquid

Wastses Transportation

Type of Waste Composition Transport Method Name/Location of Facility Amount Disposal Method

Newport Environmental Services Inc., Ingleside, TX X bbl/well Recycled

Oil-based drilling fluid or mud NA NA NA NA NA

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

mud Barged in 25 bbls cutting boxes and / or liquid mud tanks for supply vessels Newpark Transfer Station,
Fourchon, LA 6750 bbls / well Recycled

Cuttings wetted with Water-based fluid NA NA NA NA NA

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

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

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

Produced sand NA NA NA NA NA

EXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage bin ARC, New Iberia, LA X lb/well Recycled

Trash and debris Plastic, paper, aluminum Barged in a storage bin Blanchard Landfill, Golden
Meadows, LA 4000 lbs / well Recycled

Used oil Spent oil from machinery Barged in USCG approved

transfer tote tanks. L&L Services, Fourchon, LA 200 bbls / well Recycled

Wash water Wash water w/ SBM

residue and surfactants Barged in 25 bbls cutting boxes and / or liquid mud tanks for supply vessels Newpark Transfer Station,
Fourchon, LA 2000 bbls / well Approved disposal well injection or land farm

Chemical product wastes Spent treatment and / or damaged chemicals used in operations Barged in 25 bbls cutting boxes and / or cutting boxes L&L Services, Fourchon, LA 10 bbls / well Recycled

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

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

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

### Waste DisposalMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 24 

## APPENDIX G

AIR EMISSIONS INFORMATION (30 CFR PART 5 50.218AND 5 50.249)

A. Emissions Worksheets and Screening Questions

The Projected Quality Emissions Report (Form MMS

- 138) addresses the proposed drilling, completion and potential testing operations utilizing a typical DP semi

submersible drilling unit, with related support vessels 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) Emission amount (in tons associated with your proposed exploration activities more than 90% of the amounts calculated using the

fol lowing 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 ex ploration activities located east of 87.5 degrees W longitude? 

### X
Do you expect to encounter H2S at concentrations greater than 20 parts per million (ppm)? 

### X

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

### X

Do you propose to burn produced hydrocarbon liquids? 

### X



## B. Emissions Reduction Measures

The projected air emissions are within the exemption level; therefore, no emission reduction measures are being proposed.



## C. Verification of Nondefault Emissions Factors

LLOG has elected to use the default emission factors as provided in Attachment G-1.



## D. Non

- Exempt Activities

The proposed activities are within the exemption amount as provided in Attachment G1.



## E. Modeling Report

This section of the Plan is not applicable to the proposed operations.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 25 

# Air Quality Emissions Report

Attachment G-1 (Public Information)EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST OMB Control No. 1010-0151 OMB Approval Expires: 12/31/2014

FORM BOEM-0138 December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used). Page 1 of 8 COMPANY LLOG Exploration Offshore, L.L.C.

AREA Mississippi Canyon

BLOCK 794

LEASE OCS-G 34909

PLATFORM

WELL A & B

COMPANY CONTACT Kathy Gowland

TELEPHONE NO. 985-801-4300

REMARKS DP Semi submersible rigEMISSIONS FACTORS

FORM BOEM-0138 December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used). Page 2 of 8 Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATE
SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

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

NG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96 NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96 NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96 NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 3.3-1 10/96 Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96

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

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

NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91 Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98 Tank Vapors lbs/bbl 0.03 E&P Forum 1/93 Fugitives lbs/hr/comp. 0.0005 API Study 12/93 Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991 Gas Venting lbs/scf 0.0034

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight
Produced Gas( Flares) 3.33 ppm Produced Oil (Liquid Flaring) 1 % weightEMISSIONS CALCULATIONS 1ST YEAR

FORM BOEM-0138 December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used). Page 3 of 8 COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offsho Mississippi Canyon 794 OCS-G 34909 A & B Kathy Gowland 985-801-4300

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONS Diesel Engines HP GAL/HR GAL/D Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24 82 43.14 197.89 1482.82 44.48 323.52 42.45 194.72 1459.09 43.77 318.35 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6 35 5.07 23.28 174.45 5.23 38.06 0.53 2.44 18.32 0.55 4.00 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 70 5.07 23.28 174.45 5.23 38.06 1.78 8.15 61.06 1.83 13.32 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2015 YEAR TOTAL 53.29 244.45 1831.72 54.95 399.65 44.76 205.32 1538.47 46.15 335.67

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 1964.70 1964.70 1964.70 1964.70 51528.43

59.0EMISSIONS CALCULATIONS 2ND YEAR

FORM BOEM-0138 December 2011- Supersedes all previous versions of form BOEM-0138 which may not be used). Page 4 of 8 COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offsho Mississippi Canyon 794 OCS-G 34909 A & B Kathy Gowland 985-801-4300

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONS Diesel Engines HP GAL/HR GAL/D
Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24 50 43.14 197.89 1482.82 44.48 323.52 25.88 118.73 889.69 26.69 194.11 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6 22 5.07 23.28 174.45 5.23 38.06 0.33 1.54 11.51 0.35 2.51 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 43 5.07 23.28 174.45 5.23 38.06 1.09 5.01 37.51 1.13 8.18 VESSELS>600hp diesel(tugs) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2016 YEAR TOTAL 53.29 244.45 1831.72 54.95 399.65 27.31 125.28 938.71 28.16 204.81

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 1964.70 1964.70 1964.70 1964.70 51528.43

59.0EMISSIONS CALCULATIONS 3RD YEAR

FORM BOEM-0138 December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used). Page 5 of 8 COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offsho Mississippi Canyon 794 OCS-G 34909 A & B Kathy Gowland 985-801-4300

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONS Diesel Engines HP GAL/HR GAL/D
Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24 82 43.14 197.89 1482.82 44.48 323.52 42.45 194.72 1459.09 43.77 318.35 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6 35 5.07 23.28 174.45 5.23 38.06 0.53 2.44 18.32 0.55 4.00 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 70 5.07 23.28 174.45 5.23 38.06 1.78 8.15 61.06 1.83 13.32 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2017 YEAR TOTAL 53.29 244.45 1831.72 54.95 399.65 44.76 205.32 1538.47 46.15 335.67

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 1964.70 1964.70 1964.70 1964.70 51528.43

59.0EMISSIONS CALCULATIONS 4TH YEAR

FORM BOEM-0138 December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used). Page 6 of 8 COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offsho Mississippi Canyon 794 OCS-G 34909 A & B Kathy Gowland 985-801-4300

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONS Diesel Engines HP GAL/HR GAL/D
Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24 50 43.14 197.89 1482.82 44.48 323.52 25.88 118.73 889.69 26.69 194.11 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 7200 347.76 8346.24 6 22 5.07 23.28 174.45 5.23 38.06 0.33 1.54 11.51 0.35 2.51 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 43 5.07 23.28 174.45 5.23 38.06 1.09 5.01 37.51 1.13 8.18 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2018 YEAR TOTAL 53.29 244.45 1831.72 54.95 399.65 27.31 125.28 938.71 28.16 204.81

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 1964.70 1964.70 1964.70 1964.70 51528.43

59.0SUMMARY

FORM BOEM-0138 December 2011 - Supersedes all previous versions of form BOEM-0138 which may not be used). Page 8 of 8 COMPANY AREA BLOCK LEASE PLATFORM WELL

LLOG Explorati Mississippi Canyon 794 OCS-G 34909 A & B

Emitted Substance

Year

PM SOx NOx VOC CO

2015 44.76 205.32 1538.47 46.15 335.67

2016 27.31 125.28 938.71 28.16 204.81

2017 44.76 205.32 1538.47 46.15 335.67

2018 27.31 125.28 938.71 28.16 204.81

Allowable 1964.70 1964.70 1964.70 1964.70 51528.43Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 26 

## APPENDIX H

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

A. 

## Oil Spill Response Planning

All the prop osed activities in this Exploration Plan will be covered by the Oil Spill Response Plan filed by LLOG (MMS Operator No. 02058) in accordance with 30 CFR 254 Biennial update modification submitted June 30, 2014 and approved on August 15, 2014, modified January 27, 2015.

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

B. 

## Spill Response Sites

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

Primary Response Equipment

Location Pre

- Planned Staging Location(s)

Houma, LA Fort Jackson, LA

C. 

## OSRO Information

The O’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 794

– OCS

- G 3 4909

Initial Exploration Plan 27 

### D. 

## Worst

- Case Scenario Information

Category Regional OSRP EP Type of Activity Exploratory MODU Exploratory MODU Facility Surface Location Mississippi Canyon Block 895 Mississippi Canyon Block 794 Facility Description Location G Location A

Distance to Nearest Sho reline (Miles) 59 miles 59 miles

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

Potential 24 Hour Volume (bbls) 290,697 bbls 87,946 bbls

Type of Liquid Hydrocarbon Crude Crude API Gravity 22.4 o 2 3.7 °



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

- case spill scenario included in its regional OSRP Plan filed by LLOG (M MS Operator No.02058) in accordance with 30 CFR 254 Biennial update modification accepted by letter dated August 15, 2014, modified January 27, 2015

. S ince the worst case discharge determined in our Initial Exploration Plan for MC 794

does not exceed ou r worst case discharge outlined in our Regional OSRP, I hereby certify that LLOG Exploration Offshore, L.L.C. has the capability to respond, to the maximum extent practicable, to a worst

- case discharge, or a substantial threat of such a discharge, resultin g from the activities proposed in this Initial Exploration Plan. The WCD for the subject plan does not exceed the worst case discharge previously

submitted for MC 895

.

LLOG Exploration Offshore, L.L.C., Company No. 02058, previously submitted the Regiona l OSRP Exploration WCD volume to be reviewed in Plan N-9844, Initial Exploration Plan submitted on November 13, 2014.

The required proprietary data outlined in NTL 201 5- N0 1 is being submitted to BOEM within the Confidential Copy of this Initial Explorat ion Plan.

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 87,946 barrels of crud e oil with an API gravity of 23.7°.

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 7% or approximately 6,156 barrels of crude oil would be evaporated/dispersed within 24 hours, with approximately 81,790 barrels remaining.

Spill Response MC 794, Well Location A Barrels of Oil

WCD Volume 87,946

Less 7% natural evaporation/dispersion 6,156

Remaining volume 81,790



### 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 105,943 barrels. Temporar y storage associated with skimming equipment equals 6,198 barrels. If add itional storage is needed, a 47,000 barrel storage barge, two 20,000 barrel storage barges, and a 23,000 barrel storag e barge may be mobilized and centrally located to provide temporary storage and 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 147,500 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 37 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 Simultaneous Operations (SIMOPS) unit may be established in the Source Control Section 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 remote sensing systems, aerial photography

and visual confirmation

• Continual monitoring of vessel assets using vessel monitoring systems

Dispersant application assets

• Put ASI on standby

• With the FOSC, conduct analysis to determin e appropriateness of dispersant 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 deployme nt 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 operati ons 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 shoreline if possible

• Outfitting of VOOs for specific missions

• Deployment of assets based on actual movement of oil

Considerations

• Water depth, vessel draft

• Shoreline gradient

• State of the oil

• Use of VOOs

• Distance of surf zone from shoreline

• Sea state, tides, currents

Surveillance

• Provide trained observer to direct skimming operations

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

and visual confirmation

• Continual monitoring of vessel assets

Dispersant Use

• 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 deployment of Vessel of Opportunity Skimming Systems (VOSS)

• Acquire additional resources as needed

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

• Expect mission specific and sa fety training to be required

• Plan with the US Coast Guard for vessel inspections

• 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. Decanting 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 mo st active month and May is the least active

month.

### FIGURE 1

TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it impacting a land segment have been projected utilizing LLOG Exploration Offshore, L.L.C. ’s WCD and information in the BOEM Oil 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 794,

Well Location A

59 miles from shore G34909 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)81,790 bbls of crude oil (Volume considering natural weathering)API Gravity 23.7°FIGURE 2 – Equipment ResponseTime to MC 794, Well Location ADispersants/SurveillanceDispersant/SurveillanceDispersant Capacity(gal)StorageCapacityPersons Req.FromHrs toProcureHrs toLoadoutTravel tositeTotal HrsASIBasler 67T2000NA2Houma2 2 0.64.6DC 31200NA2Houma2 2 0.74.7DC 31200NA2Houma2 2 0.74.7Aero CommanderNANA2Houma2 2 0.64.6Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge43000 4000 3 Tugs 5Harvey 7 057.5 1 20.595’ FRV12342 249 NA 4 Leeville 2 023.5 0 7.595’ FRV12342 249 NA 4Venice 2 023 0 7Boom Barge (CGA-300)42” Auto Boom (25000’)NA NA1 Tug50 Crew4 (Barge)2 (Per Crew)Leeville 4 0610 2 22Recovered Oil Storage NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsEnterprise Marine Services LLC (available through contract with CGA)CTCo 2604NA 20000 1 Tug 6Amelia 4 12416 1 37CTCo 2605NA 20000 1 Tug 6Amelia 4 12416 1 37CTCo 2608NA 23000 1 Tug 6Amelia 4 12416 1 37CTCo 5001NA 47000 1 Tug 6Amelia 4 12416 1 37Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGAFRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6Galveston 2 2 12.75 1 22.7FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6Harvey2 22.15 1 12.1FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 17.75 1 27.7FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 285 1 18FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12Leeville2 24.45 1 14.4FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 24.95 1 14.9FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12Venice2 205 1 10Hydro-Fire BoomNA NA 8 Utility 40Harvey2 42.15 6 19.1Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsCGA46’ FRV5000 65 NA 4Venice2 012.5 0 5.5Trinity SWS21500 249 NA 4Leeville2 06N/A 48 56Trinity SWS21500 249 NA 4Venice2 06N/A 48 56Enterprise Marine Services LLC (available through contract with CGA)CTCo 2603NA 25000 1 Tug 6Amelia4 12415 1 36CTCo 2606NA 20000 1 Tug 6Amelia4 12415 1 36CTCo 2607NA 23000 1 Tug 6Amelia4 12415 1 36Staging Area: VeniceNearshore and Inland Skimmers WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGASWS Egmopol3000 100 NA 3 Galveston 2 2 12.7 20 18.7SWS Egmopol3000 100 NA 3 Morgan City 2 2 4.920 10.9SWS Marco3588 20 NA 3 Lake Charles 2 2 820 14SWS Marco3588 34 NA 3 Leeville 2 2 4.420 10.4SWS Marco3588 34 NA 3 Venice 2 2 020 6Rope Mop772 0 3 Harvey 2 2 2.120 8.1Foilex Skim Package (TDS 150)891 45 NA 3 Lake Charles 2 2 820 14Foilex Skim Package (TDS 150)891 45 NA 3 Galveston 2 2 12.7 20 18.7Foilex Skim Package (TDS 150)891 45 NA 3 Harvey 2 2 2.120 8.14 Drum Skimmer (Magnum 100)686 100 1 Crew 3 Lake Charles 2 2 820 144 Drum Skimmer (Magnum 100)686 100 1 Crew 3 Harvey 2 2 2.120 8.1Shoreline ProtectionStaging Area: VeniceShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeployment SiteHrs toDeployTotal HrsAMPOL (available through MSA)32,500’ 18” Boom 13 Crew 26New Iberia, LA2 2 62122430,000’ 18” Boom 13 Crew 26Harvey, LA2 2 221220OMI Environmental (available through MSA)10,000’ 18” Boom 4 Crew 10New Iberia, LA1 1 6231310,000’ 18” Boom 4 Crew 10Houston, TX1 1 12.12319.110,000’ 18” Boom 4 Crew 10Port Arthur, TX1 1 9.72316.720,000’ 18” Boom 8 Crew 20Belle Chasse, LA1 1 1.92611.910,000’ 18” Boom 4 Crew 10Port Allen, LA1 1 4.52311.510,000’ 18” Boom 4 Crew 10Houma, LA1 1 3.82310.815,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.12412.1Wildlife ResponseEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGAWildlife Support TrailerNA NA NA 2 Harvey 2 2 2.112 9.1Bird Scare Guns (48)NA NA NA 2 Harvey 2 2 2.112 9.1Bird Scare Guns (12)NA NA NA 2 Galveston 2 2 12.7 12 19.7Bird Scare Guns (12)NA NA NA 2 Aransas Pass 2 2 17.7 12 24.7Bird Scare Guns (24)NA NA NA 2 Lake Charles 2 2 812 15Bird Scare Guns (24)NA NA NA 2 Leeville 2 2 4.412 11.4Response AssetTotalOffshore EDRC105,943Offshore Recovered Oil Storage116,198Nearshore / Shallow Water EDRC68,886Nearshore / Shallow Water Recovered Oil Storage 69,188Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 28 

## APPENDIX I

ENVIRONMENTAL MONITORING INFORMATION (30 CFR PART 5 50.221 AND 5 50.25 2)

A. Monitoring S ystems

LLOG subscribes to Impact Weather Service which provi des access to real

- time

weather conditions , and provides periodic updates on impending inclement weather conditions such as tropical depressions, storms and/or hurricanes entering the Gulf of

Mexico.

LLOG also relies on the National Weather Service to sup port the aforementioned subscribed service. During impending inclement weather conditions, LLOG closely coordinates the activity with our contractors and field personnel to ensure the safety of people for evacuation; measures to prepare the facility for e vacuation to ensure protection of the environment and the facility/equipment.

Mississippi Canyon Block 794 is in water depths greater than 400 meters (1,312’); therefore LLOG will follow the guidelines of the applicable NTL 2009 -G02 “Ocean

Current Monitor ing”, by monitorin g and gathering oce an current data using Acoustic Doppler Current Profile (ADCP) while the MODU is on location.



## B. Incidental T akes

LLOG does not anticipate the incidental taking of any species as a result of the proposed activities based on the implementation of, and adherence to, the BSEE NTL

No. 2012- G01 “Marine Trash and Debris Awareness Training and Elimination” and

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



## C. Flower Garden Banks Nat ional Marine Sanctuary

This section of the plan is not applicable to the proposed operations.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 29 

## APPENDIX J

LEASE STIPULATIONS/SPECIAL CONDITIONS INFORMATION (30 CFR PART 5 50.2 22 A ND 5 50.253)

A. Lease Stipulations

Minerals Management Service (BOEM) in voked Stipulation No. 8 – Protected Species

on Lease OCS -G-33764 , Mississippi Canyon Block 794.

Lease Stipulation No. 8 is to reference measures to minimize or avoid potential adverse impacts to protected species (sea turtles, marine mammals, gulf sturgeo n, and other federally protected species). BOEM has issued Notice to Lessees Joint NTL No. 2012

- G02 “ Implementation of Seismic Survey Mitigation Measures and Protected Species Observer Program ”, Joint NTL No. 2012 -G01 “Vessel Strike Avoidance and Injured/ Dead Protected Species Reporting” and BSEE NTL No. 2012

- G01 “Marine

Trash and Debris Awareness and Elimination”.



## B. Special Conditions

• Subsea Completions

LLOG may potentially complete the proposed wells as subsea completions. Therefore, LLOG will follow the regulations 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 are in water depths greater than 400 meters (1,312’); therefore, LLOG will follow the guidelines of the applicable

NTL 2009 -G02 “Ocean Current Monitoring”, by continuously monitoring and gathering ocean current data using Acoustic Doppler Current Profile (ADCP)

while the MODU is on location.

• Breton Sound Area

Mississippi Canyon Block 794 is located within the 200 km zone of the Breton National Wildlife Refuge, and LLOG will consider the use of best available control technology as required if the projected air emissions are determined to significantly affect the air quality of an onshore area.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 30 

## APPENDIX K

ENVIRONMENTAL MITIGATION MEASURES INFORMATION (30 CFR Part 5 50.23 and 5 50.54)

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

This section does not apply to the operations as proposed herein.



## B. Incidental Takes

LLOG does not anticipate the incidental taking of any species as a result of the proposed activities based on the implementation of, and adherence to, the 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 Inj ured/Dead Protected Species Reporting” and BSEE NTL No.

2012-G01 “Marine Trash and Debris Awareness and Elimination”.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 31 

## APPENDIX L

RELATED FACILITIES AND OPERATIONS INFORMATION (30 CFR PART 5 50.256 )

A. 

## Produced Liquid Hydrocarbon Transportation Vessels

Not applicable to proposed operations.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 32 

## APPENDIX M

SUPPORT VESSELS AND AIRCRAFT INFORMATION (30 CFR PART 5 50.2 24 A ND 5 50.257)

A. 

## General

Personnel involved in the proposed operations will typically u se their own vehicles as transportation to and from the selected onshore base; whereas the selected vendors will transport the equipment by a combination of trucks, boats and/or helicopters to the onshore base. The personnel and equipment will then be transported to the drilling rig via the transportation methods and frequencies shown, taking the most direct route feasible as mandated by weather and traffic conditions:

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



### Semisubmersible Rig:

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

Duration Tug Boats 3000 bbls 1 During rig moves on/off Supply Boats 500 bbls 1 Six times weekly

Crew Boats 500 bbls 1 Three times weekly

Aircraft 1900 lbs 1 As Needed Anchor Handling

Vessel 15,100 bbls 1 3

- 4 days

Work Boat 6,450 bbls 1 3

- 4 days



## B. Diesel Oil Supply Vessels

Size of Fuel Supply

Vessel Capacity of fuel Supply Vessel Frequency of Fuel

Transfers Route Fuel Supply

Vessel Will Take

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

Block 794



## C. Drilling Fluids Transportation

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of this Plan.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 33 

## D. Solid and Liquid Wastes Transportation

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of th is Plan.



## E. Vicinity Map

Vicinity Plat s showing the location of Mississippi Canyon Block 794 relative to the

nearest shoreline and onshore base is included as Attachment M-1.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 34 

# V icinity Map

Attachment M -1 (Public Inform ation)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 35 

## APPENDIX N

ONSHORE SUPPORT FACILITIES INFORMATION (30 CFR PART 5 50.225 AND 5 50.258 )

A. 

## General

The proposed surface disturbances in Mississippi Canyon Block 794 will be located approximately 59 statute miles from th e nearest Louisiana shoreline, and approximately 70 statute miles from the following onshore support base and th e 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, and do es not anticipate the need for any expansion of the selected facilities as a result of the activities proposed in this

Initial Plan.

● Temporary storage for materials and equipment. ● 24 Hour Dispatcher

B. 

## Support Base Construction or Expansion

The proposed operations are temporary in nature and do not require any immediate action to acquire additional land or expand existing base facilit ies.

C. 

## Support Base Construction or Expansion Timetable

This section of the plan is not applicable to the proposed operations.

D. 

## Waste Disposal

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of this Plan.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 36 

## APPENDIX O COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION (30 CFR PART 5 50.226 AND 5 50.260 )

A. Consistency Certification

. A certificate of Coastal Zone Management Consistency for the State of Louisiana is

enclosed as Attachment O-1



## B. Other Information

LLOG has considered all of Louisiana’s enforceable policies and certifies the consistency for the proposed operations.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 37



# Coastal Zone Management Consistency Statement for the

State of Louisiana

Attachment O-1 (Public Information)Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 38 

## APPENDIX P

ENVIRONMENTAL IMPACT ANALYSIS (30 CFR PART 5 50.227 AND 5 50.261 )

A. Impact Producing Factors (IPF’s) From Proposed Activities

The following matrix is utilized to identify the affected environments that could be impacted by these IPF’s. An “x” has been marked for each IPF category that LLOG has determined may impact a particular environment as a result of the proposed activities. For those cells which are footnoted, a statement is provided as to the applicability of the propose d 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

seaflo or) 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 794

– OCS

- G 3 4909

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 zone) with relief greater than 2 meters that is not protected by the Topographic Stipulation attached to an OCS lease.

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

3. Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (Low

Relief) Stipulation attached to an OCS lease.

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

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

6. All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that yo u determine would impact these environmental 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, incl uding anchor emplacements, in any OCS block designated by the BOEM as having high

- probability for the occurrence of shipwrecks or prehistoric sites, including such blocks that will be affected that are adjacent to the lease block in which your planned acti vity 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 transportation of produced fluids to shore using shuttle tankers or barges.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 40 

## B. Impact Analysis

LLOG does not anticipate any unforeseen incidents from the proposed activities which could significantly impact the associated environment. LLOG activities associated with this Exploration Plan (Plan) will be performed with prudent and industry accepted standards, and in compliance with the federal agency regulations and oversight.

The “Oil Spills Information” Section of this Plan details the potential worse case discharge volume which has been calculated based on the new Bureau of Ocean Energy Management (BOEM) Notice to Le ssees (NTL 201 5- N01 ). Response details associated with an unanticipated spill from this site are detailed in our Regional Oil Spill Response Plan (OSRP) which outlines the potential spill scenario, spill volumes, anticipated trajectory of the spill, respo nse equipment available, and actions to be taken to respond to the potential spill incident. Additional measures implemented by LLOG is trajectory analyses to be obtained prior to and during the proposed activities, contractual arrangements with well cont rol specialists and preliminary reviews of potential well intervention scenarios, and to supplement existing contracted response/clean -up equipment with equipment offered by Helix which specializes in subsea deepwater well intervention, containment and pro cessing.



## Site Specific at Offshore Location

• Designated Topographic Features

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

activities that could cause impacts to topographic features.

The proposed surface disturbances within Mississippi Canyon Block 794 are located a significant distance from the closest designated topographic feature (Sackett Bank).

The crests of these designated topographic features in the northern Gulf are typically found below 10 m; therefore, concentrated oil from a surface spill is not likely to reach sessile biota. Subsurface spills could cause adverse impacts to a designated topographic feature; however, due to the offset distance this should not have an impact.

In the event of an unanticipated spill, LLOG would immediately implement its Regional Oil Spill Response Plan and active source control and countermeasures to minimize these potential impacts.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 41 

### • Pinnacle Trend Area Live Bottoms

There are no anticipated emissions, effluents, physical disturbances to the seafloor, wastes sent to shore and/or accidents from the proposed activities that could cause impacts to a pinnacle trend area.

The proposed surface disturbanc es within Mississippi Canyon Block 794 are located a significant distance from the closest pinnacle trend live bottom stipulated block. The crests of these pinnacle trend areas are much deeper than

20 m.

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

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

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

• Eastern Gulf Live Bottoms

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

T he proposed surface disturbance within Mississippi Canyon Block 794 is

located a significant distance from the closest Eastern Gulf live bottom s 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 and would avoid placement of any surface disturbances such as a drilling rig and associated anchors.

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

• Chemosynthetic Communities

Water depths at the surface locations in Mississippi Canyon Block 794 range

from 1,460 to 1,467 feet . As not ed in the shallow hazards assessment (Attachment I) benthic communities have not been reported in the seafloor

assessment area.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 42 

### • Water Quality

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

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

Certain wastes generated from the proposed activities will be manifested and sent to shore for treatment and/or disposal at approved facilities. Other waste which may be considered hazardous will be col lected 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 th e vicinity could potentially 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 constituents to background levels.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement i ts Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

• Fisheries

Accidental oil spill releases from the proposed activities, and cumulative similar discharge activity within the vicinity may potentially cause some detrimental effects on fisheries. It is unlikely a spill would occur; however, such a release in open waters closed to mobile adult finfish or shellfish would likely be sub

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

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Plan andMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 43 

### activate source control and countermeasures to minimize these potential impacts.

• Marine Mammals

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

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

Chronic and sporadic sub

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

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

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

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

NTL No. 2012

- G01 “Marine Trash and Debris Awareness Training and

Elimination” and Joint NTL No. 2012

- G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”. The proposed operations will be conducted in accordance with the regulations via manifesting waste sent to shore and ensuring such wastes are contained to prevent loss. Informational placards

will be maintained on the fac ility, and LLOG and the associated contractors obtain training on at least an annual basis to ensure personnel are aware of the reporting and operational requirements.

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

General Permit GM G290000 which authorizes the discharge of certain effluents, subject to certain limitations, prohibitions and recordkeeping requirements. AsMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 44 

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

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Pl an and activate source control and countermeasures to minimize these potential impacts.

• Sea Turtles

Small numbers of turtles could be killed or injured by chance collision with service vessels or by eating indigestible trash, particularly plastic items

a ccidentally lost from drilling rigs, production facilities and service vessels. Drilling rigs and project vessels produce noise that could disrupt normal behavior patterns and create some stress to sea turtles, making them more susceptible to disease. Ac cidental 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 s ub- lethal. Chronic and/or avoidance of affected areas could cause declines in survival or productivity, resulting in gradual population declines.

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

General Permit GMG290000 which authori zes the discharge of certain effluents, subject to certain limitations, prohibitions and recordkeeping requirements. As such, it is not anticipated these discharges authorized under the approved EPA NPDES permit will not cause significant adverse impacts to water quality.

Additionally, LLOG and its contractors will conduct the proposed activities under the additional criteria addressed by BSEE NTL No. 2012

- G01 “Marine Trash and Debris Awareness Training and Elimination” and Joint NTL No.

2012- G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”. The proposed operations will be conducted in accordance with the regulations via manifesting waste sent to shore and ensuring such wastes are contained to prevent loss. Informational placard s will be maintained on the facility, and LLOG and the associated contractors obtain training on at least an annual basis to ensure personnel are aware of the reporting and operational requirements.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 45 

### • Air Quality

The proposed activities are located approximately 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 propos ed activities.

• Ship Wreck Sites (Known or Potential)

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

• Prehistoric Archaeological Sites

There are no physical disturbances to the seafloor which could cause impacts to prehisto ric archaeological sites, as the review of high resolution shallow hazards data and supporting studies did not reflect the occurrence of prehistoric

archaeolo gical sites. As such LLOG does not anticipate an y IPF’s as a result of the proposed activities.

Vicinity of Offshore Location

• Essential Fish Habitat

As a result of the proposed activities, essential fish habitat may be adversely impacted by effluents and/or accidents.

An Accidental oil spill that may occur as a result of the proposed activities h as 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 indus try wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 46 

### • Marine and Pelagic Birds

As a result of the proposed activities, marine and pelagic birds may be adversely impacted by an accidental oil spill, by the birds coming into contact with the

released oil.

In the event of an unanticipated blowout resulting in an oil spill, it is likely to have an impact based on the industry wide standards for using proven equipment and technology for such responses. In that event, LLOG will implement the Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

• Public Health and Safety

There are no anticipated emissions, effluents, wastes sent to shore, and/or accidents from the proposed activities that could cause impacts to the public health safety. LLOG has requested BOEM 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 ( approx imately 59

miles ), and the response capabilities that would be implemented, no significant adverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication of OCS EIA/EA BOEM

2012-019 ind icate there is little risk of contact or impact to the coastline and

associated environmental resources.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses.

L LOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

• Wetlands

As a result of the proposed activities, wetlands may be adversely impacted by an

accidental oil spill. 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 historical spill data and the combined trajectory/risk calculations re ferenced in the publication of OCS EIA/EA BOEMMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 47 

### 2012-019 indicate there is little risk of contact or impact to the coastline and

associated environmental resources.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

• Shore Birds and Coastal Nesting Birds

As a result of the proposed activities, shore birds and coastal nesting birds may be adversely impacted by an accidental oil spill. However, due to the distance from shore (approximately 59 miles ) and the response capabilities that would be implemented, no s ignificant adverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEM 2012-019 indicate there is little risk of contact or impact to the coastline and associated environmental resources.

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

activat e source control and countermeasures to minimize these potential impacts.

• Coastal Wildlife Refuges

As a result of the proposed activities, coastal wildlife refuges may be adversely impacted by an accidental oil spill. However, due to the distance from s hore (approximately 59 miles ) and the response capabilities that would be implemented, no significant adverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEM 2012-019 indicate there is little risk of contact or impact to the coastline and associated environmental resources.

In the event of an unanticipated blowout, LLOG will implement industry wide standards for using proven equipment and technology for such re sponses. LLOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 48 

### • Wilderness Area

As a result of the proposed activities, wilderness areas may be adve rsely 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 historical spill

data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEM 2012-019 indicate there is little risk of contact or impact to the coastline and associated environmental resources.

In the event of an unanticipated blowout, LLOG will implemen t industry wide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

Other Resources Identified

LLOG has not identified any other environmental resources other than those addressed

above.



## C. Impacts of Proposed Activities

LLOG does not anticipate any impacts on the offshore site specific locations, offshore vicinity, and/or coastal an d onshore environmental conditions based on the potential impacts identified in the EIA worksheets and historical operations in the exploration of

this reservoir.



## D. Environmental Hazards

The Gulf of Mexico may experience several hurricanes throughout the s eason which typically runs from June through November. A severe hurricane may impact the activities covered in this Plan. Such impacts may be damage to the drilling rig, the unanticipated release of hydrocarbons depending upon the current status of the w ell. Additionally, the surface s located in Mississippi Canyon Block 794 has the potential to be affected by the “Loop Current” which is a warm ocean current in the Gulf of Mexico that flows northward between Cuba and the Yucatan Peninsula, moves northward into the Gulf of Mexico, then loops east and south before exiting to the east through the Florida Straits. While the loop current is present approximately 95% of the time, it is

most active in the summer and fall seasons.

To mitigate potential impacts t o the well during impending hurricanes or loop currents, LLOG will take precautionary measures by securing the well, rig and evacuation of personnel; and will comply with the requirements of NTL’s 2008- G09 and 2009 -G10.Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 49 

## E. Alternatives

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



## F. Mitigation Measures

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



## G. Consultation

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



## H. Preparers

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

Kathy Gowland Regulatory Specialist 1001 Ochsner Boulevard, Suite 200 Covington, Louisiana 70433 985-801-4300 (Phone) kathygo@llog.comMississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 50 

## I. References

The following documents were utilized in preparing the Environmental Impact

Assessment:

Document Author Dated
AUV Archaeological Survey

Shallow Hazards Assessment , Benthic Communities Evaluation, and Archaeological Resour ce Survey Tesla Berger Geosciences, LLC 20 15

20 15

BOEM Environmental Impact Statement Report No. 2012

- 019 Bureau of Ocean Energy Management 20 12

Title 30 CFR Part 250 Subpart B (250.216 / 250.221 /

250.223 / 250.227 Bureau of Ocean Energy Management 2006

NTL 2000

- G16 “Guidelines for General Lease Surety

Bonds” Bureau of Ocean Energy Management 2000

NTL 2005

- G07 “Archaeological Resource Surveys and Reports” Bureau of Ocean Energy Management 2005

NTL 2006

- N06 “Flaring and Venting Regulations” Bureau of O cean Energy Management 2006

NTL 2006

- G07 “Revisions to the List of OCS Lease Blocks Requiring Archaeological Surveys and Reports:” Bureau of Ocean Energy Management 2006

JOINT NTL 2012

- G02 “Implementation of seismic Survey Mitigation Measures and Protect ed Species Observer Program” Bureau of Safety and Environmental Enforcement

and Bureau of Ocean Energy Management 2012

BSEE NTL 2012

- G01 “Marine Trash & Debris Awareness

& Elimination” Bureau of Safety and Environmental Enforcement 2012

JOINT NTL 2012

- G0 1 “Vessel Strike Avoidance and Injured/Dead Protective Species” Bureau of Safety and Environmental Enforcement

and Bureau of Ocean Energy Management 2012

NTL 2008

- G04 “Information Requirements for Exploration Plans and Development Operations Coordination

Documents” Bureau of Ocean Energy Management 2008

NTL 2008

- N05 “Guidelines for Oil Spill Financial Responsibility for Covered Offshore Facilities” Bureau of Ocean Energy Management 2008

NTL 2008

- N07 “Supplemental Bond Procedures Bureau of Ocean Energy Ma nagement 2008

NTL 2008

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

NTL 2009

- G02 “Ocean Current Monitoring” Bureau of Ocean Energy Management 2009

NTL 2009

- G 27 “Submitting Exploration Plans and Development Operations Coordination Documents” Bureau of Ocean Energy Management 2009

NTL 2009

- G29 “Implementation Plan for Transition from

North American Datum 27 to North American Datum 83” Bureau of Ocean Energy Man agement 2009

NTL 2009

- G31 “Hydrogen Sul f ide” Bureau of Ocean Energy Management 2009

NTL 2009

- G34 “Ancillary Activities” Bureau of Ocean Energy Management 2009

NTL 2009

- G38 “Drilling Windows, Eastern Gulf of

Mexico” Bureau of Ocean Energy Management 2009

NTL 2009

- G39 “Biologically

- Sensitive Underwater

Features and Areas” Bureau of Ocean Energy Management 2009

NTL 2009

- G40 “Deepwater Benthic Communities” Bureau of Ocean Energy Management 2009

NTL 2009

- N11 “Air Quality Jurisdiction on the OCS” Bureau of Ocean Energy Management 2009

NTL 2010

- N05 “Increased Safety Measures for Energy Development on the OCS” Bureau of Ocean Energy Management 2010

NTL 2015

- N01 “Information Requirements for EP’s, DOCD’s, DPP on the OCS” Bureau of Ocean Energy Management 2015

NPDES General Permit GMG290000 EPA

– Region VI 20 12 Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 201 4Mississippi Canyon Block 794

– OCS

- G 3 4909

Initial Exploration Plan 51 

## APPENDIX Q

ADMINISTRATIVE INFORMATION (30 CFR Part 5 50.228 and 5 50.262)

A. Exempted Information Description (Public Informa tion Copies only )

Excluded from the Public Information copies are the following:

• Proposed bottom hole location information

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

• Production Rates and Life of Reserves

• New and Unusual Technologies

• Ge ological and Geophysical Attachments



## B. Bibliography

The following documents were utilized in preparing this Plan:

Document Author Dated

AUV Archaeological Survey Shallow Hazards Assessment, Benthic Communities Evaluation, and Archaeological Resource Su rvey Tesla Berger Geosciences, LLC 2015

2015

BOEM Environmental Impact Statement Report

– No. 20 12

- 019 Bureau of Ocean Energy Management 20 12

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 201 4