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-09865

Type - Initial Exploration Plan

Lease(s) - OCS-G27247 Block - 960 Viosca Knoll Area

OCS-G34874 Block - 959 Viosca Knoll Area

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

Drilling, completion, testing and installation of subsea wellheads and/or manifolds for Wells A, B, C, and D

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: March 19, 2015

# LLOG EXPLORATION OFFSHORE,

L.L.C.

1001 Ochsner Boulevard, Suite 200 Covington, Louisiana 70433



# PUBLIC INFORMATION COPY

JOINT INITIAL EXPLORATION PLAN

OCS

- G 34874 & OCS

- G 27247

VIOSCA KNOLL BLOCKS 959 & 960

PREPARED BY:

Kathy Gowland

Re gulatory Specialist

985

- 801

- 4300 (Main)

kathygo@llog.com

January 13, 2015

Final Copy: March 10, 2015

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

JOINT INITIAL EXPLORATION PLAN

OCS -G 34874 & OCS-G 27247

VIOSCA KNOLL BLOCKS 959 & 960

APPENDIX A Plan Contents

APPENDIX B General Information

APPENDIX C Geological, Geophysical Information

APPENDIX D H2S Informa tion

APPENDIX E Biological, Physical and Socioeconomic Information

APPENDIX F Waste and Discharge Information

APPENDIX G Air Emissions Information

APPENDIX H Oil Spill Information

APPENDIX I Environmental Monitoring Information

APPENDIX J Le ase 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

APPE NDIX O Coastal Zone Management Act (CZMA) Information

APPENDIX P Environmental Impact Analysis

APPENDIX Q Administrative InformationV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint 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 5 50.241(a), NTL No. 2008

- G04 and NTL

2010- N06, LLOG Exploration Offshore, LLC (LLOG) proposes the drilling, completion

, testing and installation of subsea wellhead and/or manifold for four (4) proposed surface locations on Lease OCS -G-34874, Viosca Knoll Block 959 and two (2) bottom hole locations on Lease OCS-G 27247, Viosca Knoll Block 960.

Included as Attachment A -1 is Form BOEM 1 37 “O CS Plan Information Form”, which provides for the drilling, sub- sea completion and testing 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. Sa fety & Pollution F eatures

LLOG will utilize a Drillship

, or a DP semi

- submersible drilling rig or a moored semi

submersible drilling rig for the proposed operations. A description of the drilling unit s 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.):V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 2 Type of Storage

Tank Type of Facility Tank Capacity (bbls) Number of

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

Tank Dril lship 16,564 bbls 1 16,564 No. 2 Diesel

- 43 Fuel Oil Storage

Tank 16,685.5 1 1 6,685.5 No. 2 Diesel

- 43

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

- 43 Fuel Oil Day

Tanks 836.6 2 1,673.2 No. 2 Diesel

- 43

Type of Storage

Tank Type of Fac ility 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

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



## E. Pollution P revention M easures : Not applicable. The State of Florida is not an affected State by the proposed activities in this plan.



## F. A dditional 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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 3 

# OCS Plan Information Form

Attachment A -1 (Proprietary Information)

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



### OCS PLAN INFORMATION FORM

General Information

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

Company Name: BOEM Operator Number:

Address: Contact Person:

Phone Number:

E-Mail Address:

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



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

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

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

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

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

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

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

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

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

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



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

Proposed Activity Start Date End Date No. of Days

Exploration drilling

Development drilling

Well completion

Well test flaring (for more than 48 hours)

Installation or modification of structure

Installation of production facilities

Installation of subsea wellheads and/or manifolds

Installation of lease term pipelines

Commence production

Other (Specify and attach description)



### Description of Drilling Rig Description of Structure

Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform rig Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed tower

DP Semisubmersible Ot her (Attach Description)

Drilling Rig Name (If Known): Floating production

system Other (Attach Description)



### Description of Lease Term Pipelines

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



### Form BOEM- 0137 (December 2011 - Supersedes all previous editi ons of this form which may not be used.) Page 1 of 4

### WELL / EVENT SPUD TD COMPL

START COMPL

FINISH DESCRIPTION AND

NUMBER OF DAYS
VK 959/960 "A" 15-May-15 3-Jul-15 3-Jul-15 12-Aug-15 D&C - 49 & 40 DAYS

VK 959 "B" 1-Jan-16 14-Feb-16 14-Feb-16 25-Mar-16 D&C - 44 & 40 DAYS

VK 959/960 "C 25-Mar-1 7 11-May-1 7 11-May-1 7 20-Jun-1 7 D&C - 47 & 40 DAYS

VK 959 "D" 20-Jun-1 8 4-Aug-1 8 4-Aug-1 8 13-Sep-1 8 D&C - 45 & 40 DAYS 

# SCHEDULE OF ACTIVITIESOCS 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 4V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 4 

# Well Location Plats

Attachment A -2572’ Surface

Loc C & D

Surface

Loc A & B 

### LLOG EXPLORATION OFFSHORE, INC.

OCS

- G 34874 Y= 10,549,440

Y= 10,533,600X=1,346,400



# Public SURFACE LOCATION A:

X: 1,344,949.130 Y: 10,537,450.00

Lat : 29 deg , 01 min

, 58.889 sec Long: 87 deg , 55 min,29.577 sec

1451’ FEL 3850’ FSL (NAD27) 

## VIOSCA KNOLL Block 959/960

Gulf of Mexico



# Location Map

12/14

Geo: Eric Z 0’ 1000’ 2000’ 

# VK 959 VK 960 ENI PETROLEUM US

OCS

- G 272476180’

SURFACE LOCATION C:

X: 1,345,828.00 Y: 10,539,779.00

Lat : 29 deg , 02 min

, 22.021 sec Long: 87 deg , 55 min,19.879 sec

573’ FEL 6180’ FSL (NAD27)3913’ 1451’

SURFACE LOCATION B:

X: 1,344,904.00 Y: 10,537,513.00

Lat : 29 deg , 01 min

, 59.510 sec Long: 87 deg , 55 min, 30.090 sec

1496’ FEL 3913’ FSL (NAD27)

SURFACE LOCATION D : X: 1,345,904.52 Y: 10,539,685.22

Lat : 29 deg , 02 min

, 21.100 sec Long: 87 deg , 55 min,19.010 sec

495.48’ FEL 6085.22’ FSL (NAD27) 1496’3850’6085’V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 5 

# Bathymetry Map

Attachment A-3 (Public Information)

# ! ( ! ( ! (

! ( ! ( ! ( ! (

S 17657 FREEPORT MCMORAN OIL & GAS LLC 06 S 13384 FREEPORT MCMORAN OIL & GAS LLC 08 S 13386 FREEPORT MCMORAN OIL & GAS LLC 08

S 13234 MARUBENI OIL & GAS USA INC 12 S 13847 TOTAL E & P USA INC 12 S 13233 MARUBENI OIL & GAS USA INC 12 

### S 17663 FREEPORT MCMORAN OIL

& GAS LLC 04 S

1 7

6

6

2

F

R

E

E

P

O

R

T M

C

MO R

A

N O

I L

& G

A

S

L

L

C

0

4 S

1 6 1 5 2

F

R

E

E

P

O

R

T

M

C

M

O

R

A

N O

I L

&

G

A

S

L

L

C

1 2

S 16085 FREEPORT MCMORAN OIL & GAS LLC 06 S 13385 FREEPORT MCMORAN OIL & GAS LLC 12 S 13387 FREEPORT MCMORAN OIL & GAS LLC 12 S 13235 MARUBENI OIL & GAS USA INC 02 S 13236 MARUBENI OIL & GAS USA INC 06



### S 17895 W & T OFFSHORE INC 04-05 S 17896 W & T OFFSHORE INC 02 S 13388 FREEPORT MCMORAN OIL & GAS LLC 04 S 13884 FREEPORT MCMORAN OIL & GAS LLC 02 

### S 17852 FREEPORT MCMORAN OIL & GAS LLC 02 S 17364 BP E & P INC 02

Crossline 1150 Crossline 1200 Crossline 1250 Inline 9500 Inline 10000

Inline 9000 Inline 10500

Crossline 1100 Inline 8500 Inline 11000

Crossline 1300

Crossline 1050 Inline 8000 Inline 11500

Crossline 1350

Crossline 1000 Crossline 1400

Crossline 950 Inline 12000



### G06894 # SS006

G06894 # SS005 G06894 # SS003



# VK960

G27247

Eni Petroleum



# VK1003

Not Leased 

# VK1004

G27249

Eni Petroleum 

# VK959

G34874 LLOG Bluewater Holdings 

# VK958

Not Leased 

# VK915

G06894

PXP Offshore 

# VK916

G27980

W and T Offshore



# VK1002

G33702 W and T Offshore, Inc. 

# VK914

Not Leased

VK 959-A

VK 959-B VK 959-C

VK 959-D

4,750 3,750

4,000 

### 4,000



### 4,500

4,500 

### 4,500 4,250



### 4,250 

### 4,250



### Geodetic Datum: NAD27 Projection: UTM

Zone: 16N

Grid Units: Feet Interpretation By: Stephen Haney Cartography: Zachary I. Metz Project No.: 14-11-10

Date: January 2015

Map Prepared by: Berger Geosciences, LLC. © Berger Geosciences, LLC. 2015 

# Block 959

Viosca Knoll Area

Gulf of Mexico

Map 1 Bathymetry 

# 3

Î Lat/Long Grid Points

0 1,000 2,000 3,000 4,000 500

U.S. Survey Feet



# Viosca Knoll Study Area UTM Northing & Easting Grid Lines

**IMPORTANT NOTICE** This map is not intended for navigation purposes. Public information obtained from BOEM database (December 2014).

1:12,000 Scale = 

# Depth

(Below Sea Level)



### 4,791 ft 3.527 ft 10,550,000 N

10,530,000 N 10,540,000 N2,200,000 E1,350,000 E1,340,000 E1,330,000 E



# Legend

44" X 28" 

## 3-D Seismic Inlines & Crosslines

Seafloor Assessment Area



# ! ( Existing Wells



## Gas Pipeline, Out of Service

Oil Pipeline, Active

Abandoned Pipeline



## Umbilical, Active

Umbilical, Out of Service



# ! ( Proposed Wells

2,000-ft Radius Circle (as per NTL 2009-G40)



## 10,000 ft Maximum Anchor Radius

1,000-ft Buffer from Maximum Anchor Radius

250-ft Contours

50-ft Contours

Grid Information

Data Source: 3-D Seismic Method: Kriging

Search Radius: 200 ft Spacing: 30 ft

Contour Interval: 50 ft87°58'0"W 

### 29°0'0"N87°58'0"W



### 29°4'0"N87°54'0"W 

### 29°0'0"N87°54'0"W



### 29°4'0"NV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint 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 for the activities provided for in this Plan (exclusive to BOEMRE permit applications and general permits issued by the EPA and COE)

Application/Permit Issuing Agency Status

N/A



## B. Drilling Fluids

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

Water Based (seawa ter, 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 does not propose using any new and/or unusual technology for the operations proposed in this Initial Plan.



## D. Bonding Statement

The bond requirements for the activities and facilities proposed in this Initial Exploration Plan are satisfied by an area wide bond, furnished and maintained according to 3 0 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 Responsibility (OSFR)

LLOG Exploration Offshore, L.L.C (MMS Co. No. 02058) will demonstrate oil spill financial responsibility for the facilities proposed in this Initial EP according to 30 CFR

Part 553, and NTL No. 2008- N05 “Guidelines for Oil Spill Financial Responsibility (OSFR) for Covered Facilities.”V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 7 

## F. Deepwater Well Control Statement

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



## G. Blowout Scenario

See the following Worst Case Discharge Calcu lations (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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 8 

# NTL 20 10- N06 Data

Worst Case Discharge Calculations

Attachment B-1

(Proprietary Information)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 9 

# NTL 2010

- N06 Data

Blowout Scenario

Attachment B-2 (Public Information)BLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 1 of 8
Confidential

1 BLOWOUT SCENA R IO

Pursuant with 30 CFR 250.213(g), 250.219, 250,250 and NTL 2010

- N06 the following attachment provides a blowout scenario description, information regarding any oil spill, WCD results and assumptions of potential spill and additional measures taken to firstly enhance the ability to prevent a blowout and secondly to manage a blowout scenario if it occurred.

INFORMATION REQUIREMENTS

PROPOSED PROSPECT INFORMATION

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

VK 959 “A ” OCS

- G

- 34874 436 2 1, 344

, 949 ’ 10, 537

, 45 0 ’ 2 9 ° 01 ’ 58.89 ” N 8 7 ° 55 ’ 2 9

. 58 ” W

VK 959 “ B ” OCS

- G

- 34874 4362 1,344,9 04 ’ 10,537, 513 ’ 29 ° 01’ 59.51”N 87 ° 55’ 30.09”W

VK 959 “ C ” OCS

- G

- 34874 4258 1,34 5

, 828 ’ 10,53 9

, 779 ’ 29 ° 02’ 22.02”N 87 ° 55’ 19.88”W

VK 959 “ D ” OC S

- G

- 34874 4258 1,3 45 ,9 05 ’ 10,53 9

, 685 ’ 29 ° 02’ 21.01”N 87 ° 55’ 19.01”W

INFORMATION REQUIREMENTS

A) Blowout scenario

The VK 959

- 960 well (s) to be drilled to potential objectives are outlined in the Geological and Geophysical Information Section of this plan utilizing a typical subsea wellhead system, conductor, surface and intermediate casing strings from a pre

- existing wellbore and a MODU rig with marine riser and a subsea BOP system. A hydrocarbon influx and a well control event occurr ing from the objecti ve sand is modeled with no drill pipe or obstructions in the wellbore followed by a failure of the subsea BOP’s and loss of well control at the seabed. The simulated flow and worst case discharge (WCD) results for all wells are calculated and the highest WCD is used for this unrestricted blowout

scenario.

B) Estimated flow rate of the potential blowout

Category Revised EP Type of Activity Drilling Facility Location (area / block) VK 959 (surface location) Facility Designation MODU

Distance to Nearest Sh oreline (miles)

~ 66 Uncontrolled Blowout (Volume per day) 82

, 176 bbls (max estimated) Type of Fluid Crude

C) Total volume and maximum duration of the potential blowout

Duration of Flow (days) 71 days total (see Relief Well Response Estimate below )

Tota l Volume of Spill (bbls) ~3

. 58 MMBO based on 71 days of uncontrolled flow based

on simulat or models

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

Attachment B

- 1 of the Proprietary Copy of this Exploratory Plan
- Omitted from Public Information Copy.BLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 2 of 8
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. This equipment includes:

• Secondary Acoustic BOP Control System
– typically fitted on DP MODU’s presently operating in the GOM. This system has the ability to communicate and function specific BOP controls from the surface in the event of a failure of the primary umbilical control system. This system typically can establish BOP controls from the surface acoustic system package on the rig or by deploying a second acoustic package from a separate vessel of opportunity. This system may not be included on all MODU’s such as 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 R OV stabs to access and function the specific BOP controls. These functions will be tested at the surface as part of the required BOP stump test and selectively at the seafloor to ensure proper functionality. These function include the following (at a min imum):

- 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

automate d 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 beBLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 3 of 8
Confidential

3 deployed which may include the Helix Producer 1 capable of handling up to 55,000 BOPD flowback. The vertical intervention work is contingent upon the condition of the blowing out well and what equipment is intact to access the wellbore for kill or containment operations. The available

interv ention 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 wel l.

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

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

, Sevan Louisian
– DP semi, Ensco 8503
– DP semi and Seadrill West Neptune
– DP drills hip ). In the event of a blowout scenario that does not involve loss or damage to the rig such as an inadvertent disconnect of the BOP’s, then the existing contracted rig may be available for drilling the relief well

and vertical intervention work . If the blowout scenario involves damage to the rig or loss of the BOP ’s and riser, a replacement rig or rigs will be required. LLOG is also a member of the Helix Well Containment Group which has the Helix Q4000 under contract for emergency intervention work suc h as an “Emergency Capping Stack” installation which for this well could include a quick response operation and installation of a capping stack which could be shut

- in to control the well.

With the current activity level in the GOM, 30 to 35 deepwater MODU ’S are potentially available to support the relief well drilling operations. Rig 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) M ODU’s would be the preferred option due to the logistical advantage versus a moored MODU which may add complications due to the mooring spread.

VESSELS OF OPPORTUNITY

Based on the water depth restrictions for the proposed locations the following “Vesse ls of Opportunity” are presently available for utilization for intervention and containment and relief well operations. These may include service vessels and drilling rigs capable of working in the potential water depths and may include moored vessels and dynamically positioned vessels. The specific conditions of the intervention or relief well operations will dictate the “best fit” vessel to efficiently perform the desired results based on the blowout scenario. The list included below illustrates specif ic 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 Ri gs • Diamond Ocean Victory (Moored Semi)

• Ensco 850 3 (DP Semi)

• Transocean Enterprise (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 ManagementBLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 4 of 8
Confidential

4 H) Measures taken to enhance ability to prevent blowout

Pursuant to BOEM

- 2010

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

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

- 2010

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

.

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

best wa y prevent a blowout incident. Contractor ’s personnel and service personnel training requirements are verified per regulatory requi r emen ts 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 operat ions. Pre

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

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

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

- Pressure

- While

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

events.

Mud loggers continuously monitor return drilling fluids, drill gas levels and cuttings as well as surface

mud volumes and flow rates , rate of penetration and lithology/paleo to aid in understanding trends and geology being drilled. Remote monitoring of real time drilling parameters and evaluation of geologic markers and pore pressure indicators is used to identify potential well condition changes.

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

and the environment.BLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 5 of 8
Confidential

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

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

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

SITE SPECIFIC PROPOSED RELIEF WELL AND INTERVENTION PLANNING

No platform was considered for drilling relief wells for this location due to location, water depth and

lack of appropriate platform within the area. For this reason a moored or DP MODU will be preferred / required.

Nearest production pipeline tie

- ins are located ~3 miles from ENI MC 296 subsea manifold located on

MC 252 block. Other subsea manifold tie

- in includes ~8 miles from ExxonMobil MC 211 and ~9 miles from ENI MC 299. Potential to utilize these lines in the event of a “cap and flow” scenario are possible.

Relief well sites have been initially identified to address blowout scenarios for the potenti al geologic targets for the proposed wells. A total of 6 relief well surface locations in MC 208 (2 sites) and MC 253 (4 sites) are proposed for the 2 drill sites located on the adjacent MC 253 block drill center in the Proposed Exploration Plan wells. T he 2 drill site are the most probable well sites for a development scenario and are common to an already existing LLOG MC 253

- 1 well with potential future pipeline and subsea manifold option for tie

- in of the potential discharge

. 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 potential shallow hazards.

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

VK 959

- 96 0 “ A ” and/ or “B” VK 959 SSW Relief Well 1 1,343,181’ 10, 534

, 553 ’

VK 959 N Relief Well 2 1,344,424’ 10,5 40 ,5 47 ’

VK 959 WSW Relief Well 3 1,342, 767 ’ 10,53 6

, 075 ’

VK 959

- 960 “C” and/or “D” VK 959 S Relief Well 1 1,34 5

, 861 ’ 10,53 6

, 611 ’

VK 959 W SW Relief Well 2 1,343, 680 ’ 10,5 40

, 862 ’

VK 959 NNW Relief Well 3 1,34 4

, 441 ’ 10,5 52

, 809 ’

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 issuesBLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 6 of 8
Confidential

6 • mobilize people and equipment (He lix DW Containment System)

• implement short term intervention and containment (if possible)

• develop Intervention Plan

• initiate relief well planning

• continue spill control measures 4

INTERVENTION AND CONTAIMENT OPERATIONS

• 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) OPE RATIONS

• continue intervention and containment measures

• continue spill control measures

• drill relief well (s) 32

PERFORM HYDRAULIC KILL OPERATIONS / SECURE BLOWNOUT WELL

• continue intervention and containment measures

• continue spill control m easures

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

ESTIMATED TOTAL DAYS OF UNCONTROLLED FLOW 71 SECURE RELIELF WELL(S) / PERFORM P&A / TA OPERATIONS / DEMOBE 30

TOTAL DAYS 1 0 9BLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 7 of 8
Confidential

7BLOWOUT SCENARIO

VK 959 - 960 Created by: S.L. Stegeman

Last Revised: 1/13/2015 Page 8 of 8
Confidential

8 VK 959 / 960 Worse Case Discharge (Per Reservoir Engineer)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint 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

Included as Attachment C-2 are current structu re 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 geological cross section.



## C. Interpreted Seism ic 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 Hazards Report

A Geohazard Assessment Study was conducted over Viosca Knoll 959 by Fugro Geoservices, Inc. on July 3, 2002 for Murphy Exploration & Production Company, USA, and filed with BOEM (MMS) on July 24, 2004. An Archaeological Assessment Report for Blocks 959 and 960, Viosca Knoll Area, prepared by C & C Technologies for Dominion Exploration & Production Company in March, 2006 and submitted to BOEM (MMS) on July 5, 2006. An Archaeological Assessment for Viosca Knoll Blocks 959 and 960, OCS

- G 34874 and G 27247, was prepared by C & C Technologies Survey Services, for LLOG in January 2015, submitted to BOEM under separate cover.

A Shallow Hazards Assessment and Benthic Communities Evaluation for Viosca Knoll Block 959, OCS

- G 34874, was prepared by Berger Geosciences, LLC, for LLOG, dated January 9 , 2015 and submitted to BOEM under separate cover.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 11 

## 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

man made features and conditions, and is included as Attachment C-5.



## G. High Resolution Seismic Lines

LLOG provided exploration 3

- D seismic data for the evaluation of the proposed surface disturbance operations.



## H. Stratigraphic Column

A g eneralized biostratigraphic/lithostratigraphic column from the seafloor to the total depth of the proposed wells is included as Attachment C-6.



## 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 locations are not required.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 12 

# Geological Description

Attachment C-1 (Proprietary Information)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 13 

# Structure Maps

Attachment C-2 (Proprietary Information)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 14 

# Deep Seismic Lines

Attachment C-3 (Proprietary Information)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 15 

# Cross Section Maps

Attachment C-4 (Proprietary Inf ormation)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 16 

# Shallow Hazards Assessment

Attachment C-5 (Public Information)Shallow Hazards Assessment Crown and Anchor Prospect

Viosca Knoll Area

Block 959

Project No.: 14-11-10 © Berger Geosciences, LLC. 2015



### ES

- 1 

## Executive Summary

This report provides an assessment of the seafloor and subsurface conditions in Viosca Knoll (VK )

Block 959 that could impact exploration activities. The assessment is bas ed on interpretation of 3

- D seismic data. The limit of the investigation is constrained to the sediments between the seafloor and 2.075 s (~7,000 ft) below the mudline (bml).

The following points summarize the seafloor and shallow geologic conditions in VK Block 959.

Section 1 – Shallow Hazards Assessment

 Water depths in the seafloor assessment area range from 3,527 ft to 4,791 ft below sea level.

 There are three existing well s, G06894 #SS003, G06894 #SS005

, G06894 #SS006 reported in

the seafloor assessment area

. Several pipelines and umbilicals are present throughout the

seafloor assessment area

.

 There are no seafloor faults present in the seafloor assessment area.

 There are no seafloor mounds or indications of fluid migration to the seafloor in the s eafloor

assessment area

.

 Slopes in the seafloor assessment area range from 0.0° to 15 °. The steepest slopes are associated with the seafloor expression of subsurface channels.

 Bottom

- simulating reflectors were not identified in the subsurface study area. The overall potential for gas hydrates in the subsurface study area ranges from negligible to low.

 Buried extensional faults offset Horizon 20 and deeper sediments in the northwest portion of the subsurface study area. There is no indication of fluid migration along the faults within the subsurface study area.

 Ten horizons were mapped within the subsurface study area. There are no know n regional sand

prone sequences within the subsurface study area. Several mass transport packages with chaotic sands present a potential for shallow water flow.

 The overall potential for shallow water flow within the subsurface study area ranges from negligible (clay

- dominated sediments) to moderate (sand- bearing sediments) based on the stratigraphic conditions.

 Subsurfac e amplitude anomalies representing possibl e shallow gas are present in several

sequences below Horizon 20 resulting in an overall negligible to moderate potential for encountering shallow gas in the subsurface study area.

 A detailed hazards assessment and tophole prognosis for each proposed well is included in the

Wellsite Discussion of this report.

Section 2 – Benthic Communities Evaluation

 Benthic communities have not been reported in the seafloor assessment area. The nearest reported b enthic communities occur outside the seafloor assessment area i n VK 826. VK 826 is

7.63 miles from the northwestern corner of the seafloor assessment area.

 No water bottom anomalies have been reported by the BOEM within the seafloor assessment area. The nearest reported water bottom anomaly occurs in VK 1002 and is 4,043 ft from the

southwest corner of the seafloor assessment area.Shallow Hazards Assessment Crown and Anchor Prospect

Viosca Knoll Area

Block 959

Project No.: 14-11-10 © Berger Geosciences, LLC. 2015



### ES

- 2  There are no s eafloor faults within the seafloor assessment area.

 A detailed benthic communities evalua tion for each proposed well in the seafloor assessment

area is included in the Wellsite Discussion of this report.Wellsite Discussion Crown and Anchor Prospect

Viosca Knoll Area Proposed Wells VK 959 A&B

Project No.: 14-11-10 © Berger Geosciences, LLC. 2015



### 3 

## Proposed Well **VK 959 -A**  **&B**

The seafloor assessment considers surface conditions within the anchor radius of 10,000 ft from the proposed locations. The following is a discussion of these conditions for Proposed Well VK 959

- A and twinned location Proposed Well VK 959- B. Proposed Well VK 959

- B is a twin well 78 ft northwest of Proposed Well VK 959 -A wi th the same well path , and is intended to be used as an alternate drilling

location . Seafloor and subsurface conditions at these twinned wells are approximately equivalent.

The water depth at Proposed W ell VK 959

- A is 4,362 ft below sea level (bsl; Map W-1 ). The proposed well is within an area of undulating seafloor that slopes to the southeast at 2.2°. The proposed location provided by LLOG is as follows:

Table W- 1. Location, block calls, and seismic lines for Proposed Well VK 959 -A

NAD27 UTM Zone 16 North, US Survey ft Geographic Coordinates

X Y Latitude Longitude

1,344,949.125 10,537,450.000 29° 01' 58.889 " N 87° 55 ' 29.577 " W



### Block Calls 3- D Seismic Line Reference

Line Trace

3,850 ’ F SL 1,451 ‘ F E L 9440 1184



### Twinned Location.



### Proposed Well VK 959-B is less than 130 ft from the 3- D seismic lines depicted in Fig ures W-2 and

W-3 ; therefore, no separate illustrations of the subsurface conditions were prepared. The proposed alternate drilling location is as follows:

Table W -2. Location, block calls, and seismic lines for Proposed Well VK 959 -B

NAD27 UTM Zone 16 North, US Survey ft Geographic Coordinates

X Y Latitude Lon gitude

1,344,904.003 10,537,513.296 29° 01' 59.513 " N 87° 55' 30.091 " W



### Block Calls

3,913’ FSL 1,496’ FELWellsite Discussion Crown and Anchor Prospect

Viosca Knoll Area Proposed Wells VK 959 A&B

Project No.: 14-11-10 © Berger Geosciences, LLC. 2015



### 4 **Power Spectrum Analysis**

The power spectrum for the proposed well was derived through the use of IHS Kingdom Suite’s Trace Calculator tools. The frequency content within the upper one second below the seafloor is of sufficient quality for shallow hazards analysis.

**Seafloor Conditions.**

The following paragraphs summarize the seafloor morphology, benthic potential, and archaeological potential at the proposed well location.

Seafloor Morphology. Proposed Well s VK 959 -A &B are located in the southeastern p ortion of

VK 959 . Water depths across the maximum anchor radius range from 3,958 ft to 4, 661 ft bsl ( Map 1 ).

A subsurface channel feature is evident in the seafloor morphology throughout the eas tern portion of the

maximum anchor radius ( Map 2 ; Figure W -1 ). The seafloor outside the subsurface channel is relatively smooth and gently dipping to southeast. There are no seafloor faults at or near the proposed

well ( Map 4 ).

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

Benthic Communities Assessment. Slight 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 ( Map 3 ). Although anomalous seafloor amplitudes occur within northwestern portion of the survey, there are no seafloor amplitude anomalies within the maximum anchor radius ( Map 3 ). There are no

w ater bottom anomalies identifi ed 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 s VK 959-A&B.Wellsite Discussion Crown and Anchor Prospect

Viosca Knoll Are a Proposed Wells VK 959

- C&D

Project No.: 14-11-10 © Berger Geosciences, LLC. 2015



### 8 

## Propo **sed Well VK 959**  **-C &D** 

The seafloor assessment considers surface conditions within a 2,000

- ft radius from the proposed well s. The following is a discussion of these conditions for Proposed Well VK 959

- C and twinned location Proposed Well VK 959- D. Proposed Well VK 959 -D is a twin well 12 1 ft southeast of VK 959 -C with

the same well path

, and is intended to be used as an alternate drilling location

. Seafloor and subsurface

conditions at these twinned wells are approximately equivalent.

The water depth at p ro posed well VK 959 -C is 4,258 ft below sea level (bsl; Map W-2 ). The proposed well is within an area of undulating seafloor that slopes to the southeast at 3.8 ° . The proposed location provided by LLOG is as follows:

Table W -3 . Location, block calls, and seismic lines for Proposed Well VK 959 -C

NAD27 UTM Zone 16 North, US Survey ft Geographic Coordinates

X Y Latitude Longitude

1,345,828.000 10,539,779.000 29° 02' 22.021 " N 87° 55' 19.879 " W



### Block Calls 3- D Seismic Line Reference

Line Trace

6,179 ’ FSL 572 ‘ FEL 9570 1211



### Twinned Location.



### Proposed Well VK 959- D is less than 130 ft from the 3- D seismic lines depicted in Fig ures W-4 and

W-5 ; therefore, no separate illustrations of the subsurface conditions were prepared. The proposed alternate drilling location is as follows:

Table W -4. Location, block calls, and seismic lines for Proposed Well VK 959 -D

NAD27 UTM Zone 16 N orth, US Survey ft Geographic Coordinates

X Y Latitude Longitude

1,345,904.522 10,539,685.225 29° 02' 21.009 " N 87° 55' 19.008 " W



### Block Calls

6,085 ’ FSL 495 ’ FELWellsite Discussion Crown and Anchor Prospect

Viosca Knoll Are a Proposed Wells VK 959

- C&D

Project No.: 14-11-10 © Berger Geosciences, LLC. 2015



### 9 **Power Spectrum Analysis**

The power spectrum for the proposed well was derived through the use of IHS Kingdom Suite’s Trace Calculator tools. The frequency content within the upper one second below the seafloor is of sufficient quality for shallow hazards analysis.

**Seafloor Conditions.**

The following paragraphs summarize the seafloor morphology, benthic potential, and archaeological potential at the proposed well location.

Seafloor Morphology. Proposed Well s VK 959 -C &D are located in the southeastern portion of

VK 959. Water depths across the maximum anchor radius range fr om 3,923 ft to 4,604 ft bsl ( Map 1 ).

A subsurface channel feature is evident in the seafloor morphology throughout the western portion of the maximum anchor radius ( Map 2 ; Figure W -1 ). The seafloor outside the subsurface channel is relatively smooth and gently dipping to the southeast. There are no seafloor faults at or near the proposed well s ( Map 4 ).

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

Benthic Communities Assessment. Slight 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 northwestern portion of the survey, there are no seafloor amplitude anomalies within the maximum anchor radius ( Map 3 ). There are no water bottom

ano malies 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 s VK 959-C&D.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 17V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 18 

# Stratigraphic Column

Attachment C-6 (Proprietary Information)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 19 

## A PPENDIX D HYDROGEN SULFIDE (H2S) INFORMATION (30 CFR Part 250.215 and 250.245 )

A. Concentration

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



## B. Classification

In accordance with 30 CFR 250.490 (c) and NTL No. 2009- 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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 20 

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

A. High

- Density Deepwater Benthic Comm unities Information

No benthic communities are reported within the seafloor assessment area. All know

communities are found outside the assessment limits within Viosca Knoll Block 826.

No seafloor mounds were identified within the seafloor assessment area. Anomalous seafloor amplitude responses are present in the northwestern portion of the seafloor

assessment area. There are no indicators of fluid migration from depth associated with anomalous seafloor amplitude responses. These anomalous seafloor amplitude response are interpreted to represent more consolidated sediments at the seafloor and are not likely to support deep water benthic or chemosynthetic communities.

Features or areas that could support high

- density chemosynthetic communities or other benthic communities are not anticipated within the maximum anchor radius for the proposed wells.



## B. Topographic 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

Viosca Knoll Blocks 959 and 960 are not located within the vicinity of a proposed live bottom (Pinnacle trend) area.



## E. Live Bottoms (Low Relief) Map

Viosca Knoll Blocks 959 and 960 are not located w ithin the vicinity of a proposed live bottom (Low Relief) area.



## F. Potentially Sensitive Biologic al Features Map

Viosca Knoll Blocks 959 and 960 are not located within the vicinity of a proposed sensitive biological feature area.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 21 

### G

. 

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

Mammal Information

.

Proposed activities in Viosca Knoll Blocks 959 and 960 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 VK 959 and 960 , LLOG will mitigate impa ct 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

A Geohazard Assessment Study was conducted over Viosca Knoll 959 by Fugro

Geoservice s, Inc. on July 3, 2002 for Murphy Exploration & Production Company, USA, and filed with BOEM (MMS) on July 24, 2004. An Archaeological Assessment Report for Blocks 959 and 960, Viosca Knoll Area, prepared by C & C Technologies for Dominion Exploration & Production Company in March, 2006 and submitted to BOEM (MMS) on July 5, 2006. An Archaeological Assessment for Viosca Knoll Blocks 959 and 960, OCS

- G 34874 and G 27247, was prepared by C & C Technologies Survey Services, for LLOG in January 2015, submitted to BOEM under separate cover.

A Shallow Hazards Assessment and Benthic Communities Evaluation for Viosca Knoll Block 959, OCS

- G 34874, was prepared by Berger Geosciences, LLC, for LLOG, dated January 9, 2015 and submitted to BOEM under separate cover.



## I

. Air and Water Quality Information

Not applicable to proposed operations.



## J

. Socioeconomic Information

No t applicable to proposed operations.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 22 

# NOAA Species Known in GOM

Attachment E-1 (Public Information)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 23 

## A PPENDIX F

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

A. Projected Generated Wastes

See the following tables:

TABLE 1. Wastes you will generate, treat and downhole dispose or discharge to the GOM

TABLE 2. Wastes you will transport and /or dispose of onshore



## B. Modeling

Not applicable. Proposed activities will be covered by U.S. EPA NPDES General

Permit.please specify if the amount reported is a total or per well amount

V IOSCA KNOLL 959 & 960

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 205,503 bbls/well 10,709 bbls/day/well Discharge overboard No

Cuttings wetted with water-based fluid C utt i ngs generate d w hil e us i ng water based drilling fluid. 9,272 bbls/well 483 bbls/day/well Discharge overboard No

Cuttings wetted with synthetic-based fluid Cuttings generated while using synthetic based drilling fluid. 3,577 bbls/well 108 bbls/day/well Discharge overboard No

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

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

overboard No

Domestic waste Misc waste for living quarters 22,241 bbls/well 2.7 bbls/hr/well Discharge overboard (no free oil) No

Sanitary waste Processed sanitary waste from living quarters 14,828 bbls/well 1.8 bbls/hr/well Chlorinate and discharge

overboard No

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

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

Will you conduct well treatment, completion, or workover?

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

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

excludes clear brines

containing Zinc No

Workover fluids N/A N/A N/A N/A N/A

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 N/A N/A N/A N/A N/A

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

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

Cooling water Uncontaminated seawater used for heat exchanger operations

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

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

.

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

Will you be covered by an individual or general NPDES permit ? General NPDES GMG 290180

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 wellVIOSCA KNOLL 959 & 960Projectedgenerated wasteSolidandLiquidWastsesTransportationType of WasteCompositionTransport MethodName/Location of Facility Amount Disposal MethodNewport EnvironmentalServices Inc., Ingleside, TX X bbl/well RecycledOil-based drilling fluid or mudNANANANANASynthetic-based drilling fluid or mudInternal olifin, ester nbasedmudBarged in 25 bbls cutting boxesand / or liquid mud tanks forsupply vesselsNewpark Transfer Station,Fourchon, LA6750 bbls / well RecycledCuttings wetted with Water-based fluidNANANANANACuttings wetted with Synthetic-based fluidNANANANANACuttings wetted with oil-based fluidsNANANANANAWill you produce hydrocarbons? If yes fill in for produced sand.Produced sandNANANANANAEXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage binARC, New Iberia, LA X lb/well RecycledTrash and debrisPlastic, paper, aluminum Barged in a storage binBlanchard Landfill, GoldenMeadows, LA4000 lbs / well RecycledUsed oilSpent oil from machineryBarged in USCG approvedtransfer tote tanks.L&L Services, Fourchon, LA 200 bbls / well RecycledWash waterWash water w/ SBM residueand surfactantsBarged in 25 bbls cutting boxesand / or liquid mud tanks forsupply vesselsNewpark Transfer Station,Fourchon, LA2000 bbls / wellApproved disposal wellinjection or land farmChemical product wastesSpent treatment and / ordamaged chemicals used inoperationsBarged in 25 bbls cutting boxesand / or cutting boxesL&L Services, Fourchon, LA 10 bbls / well RecycledNOTE: If you will not have a type of waste, enter NA in the row.TABLE 2. WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHOREWill you have additional wastes that are not permitted for discharge? IfWaste DisposalV iosc a Knoll Block s 959 & 960

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 24 

## APPENDIX G

AIR EMISSIONS INFORMATION (30 CFR PART 5 50.2 18 AND 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 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

pro posed exploration activities more than 90% of the amounts calculated using the following formulas: CT = 3400D(2/3) for CO, and CT = 33.3D for the other air pollutants (where D = distance to shore in miles)? 

### X

Does your emission calculations include any emission reduction measures or modified

emission factors? 

### X

Are your proposed exploration activities located east of 87.5 degrees W longitude? 

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

### X

Do you propos e 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 e mission 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 amou nt as provided in Attachment G

1

.



## E. Modeling Report

This section of the Plan is not applicable to the proposed operations.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint 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: 12/31/14

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

AREA Viosca Knoll

BLOCK 959/960

LEASE G

PLATFORM N/A

WELL A, B, C & D

COMPANY CONTACT Kathy Gowland

TELEPHONE NO. 985-801-4300

REMARKS DP Drillship - Worst CaseEMISSIONS FACTORS

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

LLOG Exploration Offsho Viosca Knoll 959/960 G N/A A, B, C & D 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 61800 2984.94 71638.56 24 89 43.56 199.83 1497.36 44.92 326.70 46.52 213.42 1599.18 47.98 348.91 DP Drillship 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 38 5.07 23.28 174.45 5.23 38.06 0.58 2.65 19.89 0.60 4.34 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 76 5.07 23.28 174.45 5.23 38.06 1.93 8.85 66.29 1.99 14.46 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 53.71 246.39 1846.26 55.39 402.82 49.03 224.92 1685.36 50.56 367.71

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 2197.80 2197.80 2197.80 2197.80 55527.51

66.0EMISSIONS CALCULATIONS 2ND YEAR

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

LLOG Exploration Offshor Viosca Knoll 959/960 G N/A A, B, C & D 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 61800 2984.94 71638.56 24.00 84.00 43.56 199.83 1497.36 44.92 326.70 43.91 201.43 1509.34 45.28 329.31
DP Drillship PRIME MOVER>600hp diesel 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 PRIME MOVER>600hp diesel 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 PRIME MOVER>600hp diesel 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

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 0.00 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(crew) 7200 347.76 8346.24 6.00 36.00 5.07 23.28 174.45 5.23 38.06 0.55 2.51 18.84 0.57 4.11 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10.00 72.00 5.07 23.28 174.45 5.23 38.06 1.83 8.38 62.80 1.88 13.70 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 53.71 246.39 1846.26 55.39 402.82 46.28 212.32 1590.98 47.73 347.12

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 2197.80 2197.80 2197.80 2197.80 55527.51

66.0EMISSIONS CALCULATIONS 3RD YEAR

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

LLOG Exploration Offshor Viosca Knoll 959/960 G N/A A, B, C & D 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 61800 2984.94 71638.56 24 87 43.56 199.83 1497.36 44.92 326.70 45.48 208.62 1563.24 46.90 341.07
DP Drillship 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 37 5.07 23.28 174.45 5.23 38.06 0.56 2.58 19.36 0.58 4.22 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 75 5.07 23.28 174.45 5.23 38.06 1.90 8.73 65.42 1.96 14.27 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 53.71 246.39 1846.26 55.39 402.82 47.94 219.94 1648.02 49.44 359.57

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 2197.80 2197.80 2197.80 2197.80 55527.51

66.0EMISSIONS CALCULATIONS 4TH YEAR

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

LLOG Exploration Offshor Viosca Knoll 959/960 G N/A A, B, C & D 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 61800 2984.94 71638.56 24 85 43.56 199.83 1497.36 44.92 326.70 44.43 203.83 1527.30 45.82 333.23
DP Drillship 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 36 5.07 23.28 174.45 5.23 38.06 0.55 2.51 18.84 0.57 4.11 VESSELS>600hp diesel(supply) 7200 347.76 8346.24 10 73 5.07 23.28 174.45 5.23 38.06 1.85 8.50 63.67 1.91 13.89 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 53.71 246.39 1846.26 55.39 402.82 46.83 214.84 1609.82 48.29 351.23

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 2197.80 2197.80 2197.80 2197.80 55527.51

66.0SUMMARY

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

LLOG Exploratio Viosca Knoll 959/960 G N/A A, B, C & D

Emitted Substance

Year

PM SOx NOx VOC CO

2015 49.03 224.92 1685.36 50.56 367.71

2016 46.28 212.32 1590.98 47.73 347.12

2017 47.94 219.94 1648.02 49.44 359.57

2018 46.83 214.84 1609.82 48.29 351.23

2019 0.00 0.00 0.00 0.00 0.00

2020 0.00 0.00 0.00 0.00 0.00

2021 0.00 0.00 0.00 0.00 0.00

2022 0.00 0.00 0.00 0.00 0.00

2023 0.00 0.00 0.00 0.00 0.00

2024 0.00 0.00 0.00 0.00 0.00

Allowable 2197.80 2197.80 2197.80 2197.80 55527.51V iosc a Knoll Block s 959 & 960

OCS

- G 34874 & OCS

- G 27247

Joint 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 proposed activities in this Exploration Plan will be covered by the Oil Spill Response Plan filed by LLOG (MMS Operator No. 02058) in accordance with 30 CFR 254, modified by lette r dated January 27, 2015 to indicate the worst case discharge for drilling operations greater than 10 miles seaward of the coastline. This modification was approved by letter dated February 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 Associate s (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, maintai ning 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.V iosc a Knoll Block s 959 & 960

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 27 

### D. 

## Worst

- Case Scenario Information

Category Regional OSRP Revised EP Type of Activ ity Exploratory MODU Exploratory MODU Facility Surface Location Mississippi Canyon Block 895 Viosca Knoll Blocks 959 & 960 Facility Description Location D Location A

Distance to Nearest Shoreline (Miles) 59 miles 66 miles

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

Potential 24 Hour Volume (bbls) 290,697 bbls 82,176 bbls

Type of Liquid Hydrocarbon Oil Crude

API Gra vity 2 2.4 o 33.3 °



### 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 (MMS Operator No.02058 ) in accordance with 30 CFR 254, modified by letter dated January 27, 2015 to indicate the worst case discharge for drilling operations greater than 10 miles seaward of the coastline. This modification was approved by letter dated February 27, 2015

. S ince the worst case discharge determined in o ur Joint Initial Exploration Plan for VK 959 and 960 does not exceed our worst case discharge outlined in our Regional OSRP, I hereby certify that LLOG Exploration Offshore, L.L.C. has the capability to respond, to the maximum extent practicable, to a wors t

- case discharge, or a substantial threat of such a discharge, resulting 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 Exploratio n Offshore, L.L.C., Company No. 02058, previously submitted the Regional OSRP Exploration WCD volume to be reviewed in Plan N

- 9844

, Initial Exploration Plan , Mississippi Canyon Block 895, submitted on November 13, 2014

.

The required proprietary data out lined in NTL 201 5

- N0 1 is being submitted to BOEM within the Confidential Copy of this Joint Initial Exploration 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 82,176 barrels of crud e oil with an API gravity of 33.3°.

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 a 17% probability of impact to the 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 ADIO S oil database. The results indicate 17% or approximately 13,970 barrels of crude oil would be evaporated/dispersed w ithin 24 hours, with approximately 68,206 barrels remaining.

Spill Response VK 959, Well Location A Barrels of Oil

WCD Volume 82,176

Less 17% natural evaporation/dispersion 13,970

Remaining volume 68,206



### 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 additional storage is needed, two 20,000 barrel storage barges and three 23,000 barrel storage barges may be mobilized and centrally located to provide temporary storage an d minimize off-loading time. Safety is first priority. Air monitoring will be accomplished and operations deemed safe prior to any containment/skimming attempts.

If the spill went unabated, shoreline impact in Plaquemines Parish, Louisiana would depend upon existing environmental conditions. Shorelin e protection would include the use of CGA’s

near shore and shallow water skimmers with a totaled derated sk imming capacity of 23,841 barrels. Temporary storage associated with skim ming equipment equals 320 barrels. If additional storage is needed, a 25,000 barrel storage barge may be mobilized and centrally located to provide temporary storage and minimize off-lo ading time. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. Master Service Agreements with AMPOL and OMI Environmental will ensure access to 147,000 feet of 18” shoreline protection boom. Figure 2 outlines individual times needed for procurement, load out, travel time to the site and deployment. Strategies would be based upon surveillance and real time trajectories that depict areas of potential imp act given actual sea and

weather conditions. The State of Louisiana Initial Oil Spill Re sponse Plan, applicable Area Contingency and Geographical Response Plans a nd Unified Command would be consulted to ensure that environmental and special economic resources would be co rrectly identified and prioritized to ensure optimal protection. Shorel ine protection strategies depict the protection response modes applicable for o il spill clean-up operati ons. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection strategies for this area, and it describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands, based on the assumption that removal of the released oil will be much easier and less damaging to fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. Supervisory personnel have the option to modify the deploym ent and operation of equipment allowing a more effective response to site-speci fic 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 50 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) established 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 deploym ent 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 prioritie s for area protection

• Shoreline Cleanup Assessment Team (SCAT) assessments

• Time to acquire personnel and eq uipment and their availability

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

Actions

Placement of boom

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

• Assess timing of booming operations to ensure it is where it needs to be at time of impact. Consider:

o Trajectories

o Weather forecast

o Oil Impact forecast

o Verified spill movement

o Boom, manpower and vessel (shallow draft) availability

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

Beach Preparation

Considerations and Actions

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

• Shoreline Cleanup and Assessment Team Reports and recommendations

• Determination of Archeological site s and gaining authority to enter

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

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

• Staging of equipment and housing of respons e personnel as close to the job site as possible to maximize on-site work time

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

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

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

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

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

inland areas

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

recovery.

CGA Equipment Limitations The capability for any spill response equipment, whether a dedicated or portable system, to operate in differing weather conditions will be directly in rela tion to the capabilities of the vessel the system in placed on. Most importantly, however, the decision to operate will be based on the judgment of the Unified Command a nd/or the Captain of the vessel, who will ultimately have the final say in terminating operations. Skimming equipment listed below may have operational limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil spill response, vessel skimming opera tions ceased when seas reache d 5-6 feet and vessels were often recalled to port when those conditions were exceeded. Systems below are some of the most up-to-date systems available and were employed during the DWH spill.

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

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

OSRV 4 foot seas

### Environmental Conditions in the GOM Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences westerly winds during the wint er and easterly winds in the summer. Average wind speed is generally 14-15 mph along the coast. Wave he ights average 4 and 5 feet. However, during hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, flooding is prominent.

Surface water temperature ranges between 70 and 80  ̊ F during the summer months. During the winter, the average temperatur e will range from 50 and 60  ̊ F.

The Atlantic and Gulf of Mexico hurricane seas on is officially from 1 June to 30 November. 97% of all tropical activity occurs within this window. The Atlant ic basin shows a very peaked season from August through October, with 78% of the tropical storm days, 87% of the minor (Saffir-Simpson Scale categories 1 and 2) hurricane days, and 96% of the major (Saffir-Simpson categories 3, 4 and 5) hurricane days occurri ng then. Maximum activity is in early to mid September. Once in a few years there may be a hurri cane occurring "out of season" - primarily in May or December. Globally, September is the most active month and May is the least active

month.

### FIGURE 1

TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it impacting a land segment have been projected utilizing LLOG Exploration Offshore, L.L.C. ’s WCD and information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for th e Central and Western Gulf of Mexico available on the BOEM website using 30 day impact. The results are tabulated below.

Area/Block OCS-G Launch

Area Land Segment and/or

Resource Conditional Probability (%) within 30 days

Exploratory Drilling

VK 959,

Well Location A

66 miles from shore G34874 C55 Terrebonne, LA Lafourche, LA Plaquemines, LA

St. Bernard, LA Hancock & Harrison, MS Jackson, MS Mobile, AL Baldwin, AL Escambia, FL Okaloosa, FL

Walton, FL

Bay, FL Gulf, FL Franklin, FL 1

1

17

7

2

2

2

3

2

1

1

2

1

1WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(66 miles from shore)68,206 bbls of crude oil (Volume considering natural weathering)API Gravity 33.3°FIGURE 2 – Equipment ResponseTime to VK 959, Well Location ADispersants/SurveillanceDispersant/SurveillanceDispersantCapacity (gal)StorageCapacityPersons Req.FromHrs toProcureHrs toLoadoutTravel tositeTotal HrsASIBasler 67T2000 NA2Houma2 2 0.94.9DC 31200 NA2Houma2 2 1.25.2DC 31200 NA2Houma2 2 1.25.2Aero CommanderNANA2Houma2 2 0.94.9Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge43000 4000 3 Tugs 5 Harvey 7 05 12.5 1 25.5Boom Barge (CGA-300)42” Auto Boom (25000’)NA NA1 Tug50 Crew4 (Barge)2 (Per Crew)Leeville 4 06 21.5 2 33.595’ FRV12342 249 NA 4 Leeville 2 017.5 0 10.595’ FRV12342 249 NA 4 Venice 2 015 0 8Recovered Oil Storage NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsEnterprise Marine Services LLC (available through contract with CGA)CTCo 2605NA 20000 1 Tug 6 Amelia 4 124 28.75 1 49.75CTCo 2606NA 20000 1 Tug 6 Amelia 4 124 28.75 1 49.75CTCo 2607NA 23000 1 Tug 6 Amelia 4 124 28.75 1 49.75CTCo 2608NA 23000 1 Tug 6 Amelia 4 124 28.75 1 49.75CTCo 2609NA 23000 1 Tug 6 Amelia 4 124 28.75 1 49.75Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGAFRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 2 2 12.7 8.3 1 26FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 2 22.1 8.3 1 15.4FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 17.7 8.3 1 31FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 288.3 1 21.3FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Leeville 2 24.4 8.3 1 17.7FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 24.9 8.3 1 18.2FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 2 208.3 1 13.3Hydro-Fire BoomNA NA 8 Utility40 Harvey 2 42.1 8.3 6 22.4Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsCGA46’ FRV5000 65 NA 4 Morgan City 2 026.5 0 10.546’ FRV5000 65 NA 4 Venice 2 012.5 0 5.5Enterprise Marine Services LLC (available through contract with CGA)CTCo 2603NA 25000 1 Tug 6 Amelia 4 124 16.25 1 37.25Staging Area: VeniceNearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGASWS Egmopol3000 100 NA 3 Morgan City 2 24.92010.9SWS Marco3588 20 NA 3 Lake Charles 2 282014SWS Marco3588 34 NA 3Leeville2 24.42010.4SWS Marco3588 34 NA 3Venice2 20206Rope Mop77 2 0 3Harvey2 22.1208.1Shoreline ProtectionStaging Area: VeniceShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeployment SiteHrs toDeployTotal HrsAMPOL (available through MSA)42,000’ 18” Boom 16 Crew 40New Iberia, LA2 2 62122420,000’ 18” Boom 8 Crew 20New Orleans, LA2 2 2.22614.2OMI 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 2Harvey2 22.1129.1Bird Scare Guns (48)NA NA NA 2Harvey2 22.1129.1Bird Scare Guns (12)NA NA NA 2 Galveston 2 2 12.71219.7Bird Scare Guns (12)NA NA NA 2 Aransas Pass 2 2 17.71224.7Bird Scare Guns (24)NA NA NA 2 Lake Charles 2 281215Bird Scare Guns (24)NA NA NA 2Leeville2 24.41211.4Response AssetTotalOffshore EDRC105,943Offshore Recovered Oil Storage115,198Nearshore / Shallow Water EDRC23,841Nearshore / Shallow Water Recovered Oil Storage 25,320V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 28 

## APPENDIX I

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

A. Monitoring S ystem s

LLOG subscribes to Impact Weather Service which provides 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 support 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 peopl e for evacuation; measures to prepare the facility for evacuation to ensure protection of the environment and the facility/equipment.

Viosca Knoll Blocks 959 and 960 are in water depths greater than 400 meters (1,312’); therefore LLOG will follow the guid elines of the applicable NTL 2009 -G02 “Ocean Current Monitoring”, 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 National Marine Sanctuary

This section of the plan is not applicable to the proposed operations.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint 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) invoked Stipulation No. 3

– Military Areas on

Leases OCS -G- 34874 and OCS -G- 27247, Viosca Knoll Blocks 959 and 960, respectively. These leases are located in Military Warning Area W

- 155B and therefo re as stated in Stipulation No. 3, LLOG will enter into an agreement with Naval Air

Station

.

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

on Lease OCS -G-34874, Viosca Knoll Block 959 and Stipulation No. 6

– Protected Sp ecies on Lease OCS -G-27247.

Lease Stipulation No s. 6 and 8 reference measures to minimize or avoid potential adverse impacts to protected species (sea turtles, marine mammals, gulf sturgeon, and other federally protected species). BOEM has issued Notice to Lessees Joint NTL No.

2012- G02 “ Implementation of Seismic Survey Mitigation Measures and Protected Species Observer Program ”, Joint NTL No. 2012

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

- G01 “Marine

Trash and Debris Awareness and Elimination”.



## B. Special Conditions

• Subsea Completions

LLOG may potentially complete the proposed wells as subsea completions. 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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 30 

### • Breton Sound Area

Viosca Knoll Blocks 959 and 960 are 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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 31 

## APPENDIX K

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

A. M easures 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 Injured/Dead Protected Speci es Reporting” and BSEE NTL No.

2012-G01 “Marine Trash and Debris Awareness and Elimination”.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 32 

## APPENDIX L

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

A. 

## Produced Liquid Hydrocarbon Transportation Vessels

No t applicable to proposed operations.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 33 

## 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 use their own vehicles as

t ransportation 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 r ig via the transportation methods and frequencies shown, taking the most direct route feasible as mandated by weather and traffic conditions:

Drillship and DP Semisubmersible Rig:

Type Maximum Fuel Tank Storage Capacity Maximum No. in Area at Any Time Tr ip 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 o r 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 Viosca

Knoll Blocks 959 and

960



## C. Drilling Fluids Transpo rtation

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of this Plan.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 34 

## D. Solid and Liquid Wastes Transportation

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



## E. Vicinity Map

Vicinity Plat showing the location of Viosca Knoll Blocks 959 and 960 relative to the

nearest shoreline and onshore base is included as Attachment M-1.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 35 

# V icinity Map

Attachment M -1 (Public Information )Venice

Buras Empire Pointe a La

Hache Chalmette

Belle

Chase Gretna New Orleans

Golden

Meadow

Port

Fourchon



## VICINITY MAP

Block 959

Vios Knoll Area 0 20 20

SCALE IN US STATUTE MILES ~140 Statute Miles to Base ~66 Statute Miles to Shore

PREPARED

BY: 730 E. KALISTE SALOOM RD.
LAFAYETTE, LA 70508 (337) 210-0000 LA Reg. No. 330 

### SHEET 1 of 1 DATE: REV. JOB No:

FILENAME: BY: 141465 CBB Jan. 9, 2015

141465VIC2.DWG 

# 0 BARATARIA

BAY GRAND

BAY BRETON SOUND

TIMBALIER BAY

WEST

BAY GARDEN
ISLAND

BAY EAST

BAY Timbalier Islands BLIND

BAY ~82 Statute Miles to Shore

MISSISSIPPI CANYON AREA CHANDELEUR

SOUND AREA NORTH LAKE

BORGNE AREA MOBILE AREA CHANDELEUR SOUND

ADDITION AREA

CHANDELEUR

AREA VIOSCA KNOLL AREA

DESOTO

CANYON

AREA SHIP

SHOAL

AREA SOUTH

PELTO

AREA SOUTH

TIMBALIER

AREA WEST

DELTA

AREA AREA VIOSCA KNOLL AREA MAIN PASS AREA SOUND

BAY MARCHAND AREA

SOUTH PASS BRETON

AREA

ISLE GRAND LAKE

BOURGE LAKE

PONTCHARTRAIN LAKE

MAUREPASV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 36 

## APPENDIX N

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

A. 

## General

The proposed surface disturbances in Viosca Knoll Blocks 959 and 960 will be located approximately 66 statute miles from the ne arest Louisiana shoreline, and approximately 140 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 selecte d 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 facilities.

C. 

## Support Base Construction or Expansion Timetable

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

D. 

## Waste Disposal

See Table 2

– Wastes you will Transport and/or Dispose of Onshore, located in Appendix F of this Plan.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 37 

## 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 f or the States of Louisiana and

Alabama are enclosed as Attachment O-1



## B. Other Information

Included as Attachment O-2 are the enforceable policies from the State of Alabama that are related to OCS Plan Filings.

LLOG has considered all of Louisiana’s enfor ceable policies and certifies the consistency for the proposed operations.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 38



# Coastal Zone Management Consistency Statement for the

States of Louisiana and Alabama

Attachment O-1 (Public Information)V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 39 

# Coastal Zone Management Enforceable Policies for the

State of Alabama

Attachment O -2 (Public Information)

## ALABAMA COASTAL ZONE MANAGEMENT

CONSISTENCY CERTIFICATION

JOINT EXPLORATION PLAN

VIOSCA KNOLL BLOCKS 959 & 960

OCS -G 34874 & OCS -G 27247

The OCS related oil and gas development activities having potential impact on the Alabama Coastal Zone are based on the location of the proposed facilities, access to those sites, best practical techniques for operations and production equipment, guidelines for the prevention of adverse environmental effects, effective environmental protection, emergency plans and contingency plans. A labama policies have been addressed below or are cross referenced to the appropriate sections of the Plan:

Topic Cross

Reference Comments

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

wil l be no new construction, dredging or filling in

Alabama state waters. There will be no new commercial development or capital improvements in Alabama’s coastal zone, nor will there be any employment effects. Mineral Resource Exploration

and Extraction P roposed development operations will take place 82

statute miles from Alabama’s coastline Commercial Fishing Appendix H Hazard Management Appendix C A Shallow Hazards Report was previously submitted to

BOEM in order to identify and assess the seafloor and shallow geologic conditions in this block

Shoreline Erosion Appendix H Proposed development operations will take place 82

statute miles from Alabama’s coastline

Recreation Appendix H Transportation Appendix B

Natural Resource Protection

Policie s Biological Productivity Appendix H Water Quality Appendix H

Water Resources Appendix H Air Quality Appendix G Wetlands and Submerged

Grassbeds Appendix H

Beach and Dune Protection Appendix H

Wildlife Habitat Protection Appendix H Endange red Species Appendix H

Cultural Resources Protection Appendix D Viosca Knoll Blocks 959 & 960 have been determined to have a high potential for containing archaeological properties. An archaeological report was submitted to

BOEM under separate cover.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 40 

## APPENDIX P

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

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

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

activi ties. For those cells which are footnoted, a statement is provided as to the applicability of the proposed activities, and where there may be an effect, an analysis of the effect is provided.

Environmental Resources Impact Producing Factors (IPF’s)

Emi ssions (air, noise, light, etc) Effluents (muds, cuttings, other discharges

to the water

column or seafloor) Physical

disturbances

to the seafloor (rig, anchor,

structure emplacement, etc.) Wastes sent

to shore for

treatment or disposal Accidents (e.g., o il 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)
Chemosy nthetic communities X (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 X (6)

Wetlands X (6)
Shorebirds and coastal nesting

birds X X (6)

Coastal wildlife refuge X

Wilderness areasV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 41 

### 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 atta ched to an OCS lease; (c) Essential Fish Habitat (EFH) criteria of 500 feet from any no

- activity zone; or (d) Proximity of any submarine bank (500 ft buffer zone) with relief greater than 2 meters that is not protected by the Topographic Stipulation attached to an OCS lease.

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

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

Relief) Stipulation attached to an OCS lease.

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

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

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

7. All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block designated by the BOEMRE as having high

- probability for the occurrence of shipwrecks or prehisto ric sites, including such blocks that will be affected that are adjacent to the lease block in which your planned activity will occur. If the proposed activities are located a sufficient distance from a shipwreck or prehistoric site that no impact

would o ccur, 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 prod uced fluids to shore using shuttle tankers or barges.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 42 

## 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, Regulation and Enforcement (BOEMRE) Notice to Lessees (NTL 2010

- N06). Response details associated with an unanticipated spill from this site are detailed in our Regional Oil Spill Response Plan (OSRP) which outlines the potential spill scenario, spill volumes, anticipated trajectory of the spill, response equipment available, and actions to be taken to respond to the potential spill incident. Additional me asures implemented by LLOG is trajectory analyses to be obtained prior to and during the proposed activities, contractual arrangements with well control specialists and preliminary reviews of potential well intervention scenarios, and to supplement existin g contracted response/clean

- up equipment with equipment offered by Helix which specializes in subsea deepwater well intervention, containment and processing.



## Site Specific at Offshore Location

• Designated Topographic Features

There are no anticipate d 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 Viosca Knoll Blocks 959 an d 960 are located greater than 75 miles away from the closest designated topographic feature (Sackett Bank).

The crests of these designated topographic features in the northern Gulf are typically found below 10 m; therefore, concentrated oil from a surfac e 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 immedi ately implement its Regional Oil Spill Response Plan and active source control and countermeasures to minimize these potential impacts.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 43 

### • Pinnacle Trend Area Live Bottoms

There are no anticipated emissions, effluents, physical disturbances to the

seafl oor, wastes sent to shore and/or accidents from the proposed activities that could cause impacts to a pinnacle trend area.

The proposed surface disturbances within Viosca Knoll Blocks 959 and 960 are located approximately 15 miles southeast of Viosca Knoll Area Block 778, the nearest block where the Live Bottom (Pinnacle Trend) Stipulation applies. After review of impact

- producing factors resulting from activities proposed in this Exploration Plan, there are no potential impacts to pinnacle trend live bot toms.

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

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

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

• Eastern Gulf Live Bottoms

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

T he proposed surface disturbance s within Viosca Knoll Blocks 959 and 960 are located approximately 9 miles west of the nearest block protected by the eastern live bottom stipulation. After review of impact

- producing factors resulting from activities proposed in this Exploration Plan, there are no potential impacts to eastern gulf live bottoms. 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 Viosca Knoll Blocks 959 and 960 range from 4,265 to 4,360 feet . As noted in the shall ow hazards assessmentV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 44 

### (Attachment I) benthic communities have not been reported in the seafloor

assessment area.

• 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 Pe rmit 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 collected and trans ported in sealed containers and transported to approve disposal sites in accordance with the RCRA regulations and guidelines.

An accidental oil spill release from the proposed activities, and cumulative similar discharge activity within the vicinity could potentially cause temporary impacts to water quality. In the event of such a 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 its Regional Oil Spill Response Plan and activate source control and countermeasures to minimize these potential impacts.

• Fisheries

Accidental oil spill releases from the proposed activities, and cumulative similar discharge activity within the vicinity may potentially c ause 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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 45 

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

• Marine Mammals

GulfCet II studies reveal that cetaceans of the continental shelf and shelf edge are comprised of bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and pygmy killer 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 net results of an y 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 activities 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 Speci es Reporting”. The proposed operations will be conducted in accordance with the regulations via manifesting waste sent to shore and ensuring such wastes are contained to prevent loss. Informational placards will be maintained on the facility, 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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 46 

### LLOG will conduct the proposed activities under EPA’s Region VI NPDES General Permit GMG290000 which authorizes the discharge of certain effluents, subject to certain limitations, prohibitions and recordkeeping requirements. As such, it is not anticipated these discharges authorized under the approved EPA NPDES permit will not cause significant adverse imp acts to water quality.

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

activate source control and countermeasures to minimize these potential impacts.

• Sea Turtles

Small numbers of turtles could be killed or injured by chance collision with service vessels or by eating indigestible trash, particularly plastic items accidentally lost from drilling rigs, production facilities and service vessels. Drilling rigs and project vessels produce noise that could disrupt normal behavior patterns and create some stress to sea turtles, making them more susceptible to disease. Accidental oil spi ll releases are potential threats which could have lethal effects on turtles. Contact and/or consumption of this released material could seriously affect individual sea turtles. Most OCS related impacts on sea turtles are expected to be sub

- lethal. Chronic and/or avoidance of affected areas could cause declines in survival or productivity, resulting in gradual population declines.

LLOG will conduct the proposed activities under EPA’s Region VI NPDES General Permit GMG290000 which authorizes the discharge of certain effluents, subject to certain limitations, prohibitions and recordkeeping requirements. As such, it is not anticipated these discharges authorized under the approved EPA NPDES permit will not cause significant adverse impacts to water quality

.

Additionally, LLOG and its contractors will conduct the proposed activities under the additional criteria addressed by 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 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 w ide standards for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Plan andV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 47 

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

• Air Quality

The propos ed activities are located approximately 66 miles to the nearest shoreline. LLOG has addressed the air quality issues associated with the proposed activities in the “Air Emissions Information” section of this Plan as a result of the proposed activities.

• S hip 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 l ocated within the survey area. As such, LLOG does not anticipate any IPF’s as a result of the proposed activities.

• Prehistoric Archaeological Sites

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

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

Vicinity of Offs hore Location

• Essential Fish Habitat

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

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

sub- lethal and the extent o f 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

standard s for using proven equipment and technology for such responses. LLOG would immediately implement its Regional Oil Spill Response Plan andV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 48 

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

• Marine and Pelagic Birds

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

released oil.

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

• Public Health and Safety

There are no anticipated emissions, effluents, wastes sent to shore, and/or accidents from the proposed activities that could cause impacts to the public health safety. LLOG has requested BOEMRE approval to classify the proposed objective area as absent of hydrogen sulfide.

Coastal and Onshore

• Beaches

As a result of the proposed activities, beaches may be adversely impacted by an accidental oil spill. However, due to the distance from shore ( approximately 66

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

BOEMRE 2009-053 indicate there i s 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 imm ediately 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 66V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 49 

### 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 t he publication of OCS EIA/EA

BOEMRE 2009-053 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 66 miles ) and the response capabilities that would be implemented, no significant adverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEMRE 2009-053 indicate there is little risk of contact or impact to the coastline and associated environmental resources.

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

activate source control and countermeasures to minimize these potential impacts.

• Coastal Wildlife Refuges

As a result of the proposed activities, coastal wildlife refuges may be adversely impacted by an accidental oil spill. However, due to the distance from shore (app roximately 66 miles ) and the response capabilities that would be implemented, no significant adverse impacts are expected. Both historical spill data and the combined trajectory/risk calculations referenced in the publication

of OCS EIA/EA BOEMRE 2009-053 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.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 50 

### • Wilderness Area

As a result of the proposed activities, wilderness areas may be adversely impa cted by an accidental oil spill. However, due to the distance from shore (approximately 66 miles ) and the response capabilities that would be implemented, no significant adverse impacts are expected. Both historical spill data and the combined trajectory /risk calculations referenced in the publication

of OCS EIA/EA BOEMRE 2009-053 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 indust ry 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 Ide ntified

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

above.



## C. Impacts of Proposed Activities

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

this reservoir.



## D. Environmental Hazards

The Gulf of Mexico may experience several hurricanes throughout the season wh ich typically runs from June through November. A severe hurricane may impact the activities covered in this Plan. Such impacts may be damage to the drilling rig, the unanticipated release of hydrocarbons depending upon the current status of the well.

Ad ditionally, the surface s located in Viosca Knoll Blocks 959 and 960 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 to the well during impending hurricanes or loop currents, LLOG will take precautionary measures by securing the well, rig and evacuation of personnel; and will comply with the requirements of NTL’s 2008- G09 and 2009 -G10.V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 51 

## 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.comV iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 52 

## I. References

The following documents were utilized in preparing the Environmental Impact

Assessment:

Document Author Dated
Geohazard Assessment Study Archaeological Assessment

Shallow Hazards Assessment , Benthic Communities Evaluation, and Archaeological Resource Survey , VK 959 Archaeological Assessment Fugro Geoservices, Inc. C&C Technologies Berger Geosciences, LLC

C&C Technologies 20 02

20 06

2015

2015 BOEMRE Environmental Impact Statement Report No.

2009

- 053 Bureau of Ocean Energy Manageme nt, Regulation, and Enforcement 200 9

Title 30 CFR Part 250 Subpart B (250.2 16 / 250.2 21 /

250.2 23 / 250.2 27 Bureau of Ocean Energy Management, Regulation, and Enforcement 2006

NTL 2000

- G16 “Guidelines for General Lease Surety

Bonds” Bureau of Ocean Energ y Management, Regulation, and Enforcement 2000

NTL 2005

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

NTL 2006

- N06 “Flaring and Venting Regulations” Bureau of Ocean Energy Management

, Regulation, and Enforcement 2006

NTL 2006

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

JOINT NTL 20 12

- G02 “Implementation of seismic Su rvey Mitigation Measures and Protected Species Observer Program” Bureau of Ocean Energy Management, Regulation, and Enforcement 20 12

BSEE NTL 20 12

- G0 1 “Marine Trash & Debris Awareness

& Elimination” Bureau of Ocean Energy Management, Regulation, and Enfor cement 20 12

JOINT NTL 20 12

- G0 1 “Vessel Strike Avoidance and Injured/Dead Protective Species” Bureau of Ocean Energy Management, Regulation, and Enforcement 20 12

NTL 2008

- G04 “Information Requirements for Exploration Plans and Development Operations Coord ination

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

NTL 2008

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

NT L 2008

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

NTL 2008

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

NTL 2008

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

NTL 2009

- G02 “Ocean Current Monitoring” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009

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

NTL 2009

- G29 “Implementation Plan for Transition from

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

NTL 2009

- G31 “Hydrogen Sul f ide” Bureau of Ocean Energy Management, Regulation, and Enforcement 2009

NTL 2009

- G34 “Ancillary Activities” Bureau of Ocean Ene rgy Management, Regulation, and Enforcement 2009

NTL 2009

- G38 “Drilling Windows, Eastern Gulf of

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

NTL 2009

- G39 “Biologically

- Sensitive Underwater

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

NTL 2009

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

NTL 2009

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

NTL 2010

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

NTL 2010

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

NPDES General Permit GMG290000 EPA

– Region VI 20 12 Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2014V iosc a Knoll Block s 959 & 9 60

OCS

- G 34874 & OCS

- G 27247

Joint Initial Exploration Plan 53 

## APPENDIX Q

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

A. Exempted Information Description (Public Information 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 Ra tes and Life of Reserves

• New and Unusual Technologies

• Geological and Geophysical Attachments



## B. Bibliography

The following documents were utilized in preparing this Plan:

Document Author Dated

Geohazard Assessment Study Archaeological Assessment

Shallow Hazards Assessment, Benthic Communities Evaluation, and Archaeological Resource Survey , VK 959 Archaeological Assessment Fugro Geoservices, Inc. C&C Technologies Berger Geosciences, LLC

C&C Technologies 20 02

20 06

2015

2015 BOEMRE Environmental Impact Statement Report

– No.

2009

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

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