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

Regulatory 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 Information

APPENDIX E Biological, Physical and Socioeconomic Information 

APPENDIX F Waste and Discharge Information 

APPENDIX G Air Emissions Information

 

APPENDIX H Oil Spill Information

APPENDIX I Environmental Monitoring Information 

APPENDIX J Lease Stipulation Information 

APPENDIX K Environmental Mitigation Measures Information 

APPENDIX L Related Facilities and Operations Information 

APPENDIX M Support Vessels and Aircraft Information 

APPENDIX N Onshore Support Facilities Information 

APPENDIX O Coastal Zone Management Act (CZMA) Information 

APPENDIX P Environmental Impact Analysis 

APPENDIX Q Administrative Information
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 1

APPENDIX A

PLAN CONTENTS

(30 CFR Part 550.211 and 550.241)

A. Plan information 

In accordance with 30 CFR 550.211 and 550.241(a), 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 137 “OCS Plan Information Form”, which 

provides for the drilling, sub-sea completion and testing of all well locations.

. 

B. Location 

 Attachment A-2 – Well Location Plat 

 Attachment A-3 – Bathymetry Map – Seafloor disturbance area with anchor radius 

C. Safety & Pollution Features 

LLOG will utilize a Drillship, or a DP semi-submersible drilling rig or a moored semisubmersible drilling rig for the proposed operations. A description of the drilling units 

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.): 
Viosca Knoll Blocks 959 & 960

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

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

43

Fuel Oil Storage 

Tank

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

43

Fuel Oil 

Settleing Tank

836.6 2 1,673.2 No. 2 Diesel -

43

Fuel Oil Day 

Tanks

836.6 2 1,673.2 No. 2 Diesel -

43

Type of Storage 

Tank

Type of Facility Tank Capacity 

(bbls)

Number of 

tanks

Total Capacity 

(bbls)

Fluid Gravity 

(API)

Fuel Oil (Marine 

Diesel)

DP SemiSubmersible164 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)

SemiSubmersible95.24 2 190.5 No. 2 Diesel -

43

2917.8 4 11,671.2

Total 11,861.7

E. Pollution Prevention Measures: Not applicable. The State of Florida is not an 

affected State by the proposed activities in this plan.

F. Additional measures: LLOG does not propose any additional safety, pollution 

prevention, or early detection measures, beyond those required in 30 CFR 250 and per 

December 13, 2010 – Guidance for Deepwater Drillers to Comply with Strengthened 

Safety and Environmental Standards. 
Viosca Knoll Blocks 959 & 960

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) Development 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 deepwater 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 Other (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) Diameter (Inches) Length (Feet) 

Form BOEM- 0137 (December 2011- Supersedes all previous editions 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-17 11-May-17 11-May-17 20-Jun-17 D&C - 47 & 40 DAYS

VK 959 "D" 20-Jun-18 4-Aug-18 4-Aug-18 13-Sep-18 D&C - 45 & 40 DAYS

SCHEDULE OF ACTIVITIES
OCS PLAN INFORMATION FORM (CONTINUED) 

Include one copy of this page for each proposed well/structure 

Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): 

Previously reviewed under an approved EP or 

DOCD? 

Yes No 

Is this an existing well 

or structure? 

Yes No If this is an existing well or structure, list the 

Complex ID or API No. 

Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes No 

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day): 

For structures, volume of all storage and 

pipelines (Bbls): 

API Gravity of 

fluid 

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

enter separate lines) 

Lease No. OCS OCS OCS 

OCS 

Area Name 

Block No. 

Blockline 

Departures 

(in feet)

N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L 

N/S Departure: F____ L 

N/S Departure: F____ L 

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

E/W Departure: F____ L 

E/W Departure: F____ L 

Lambert XY 

coordinates 

X: X: X: 

X: 

X: 

Y: Y: Y: 

Y: 

Y: 

Latitude/ 

Longitude

Latitude Latitude Latitude 

Latitude 

Latitude 

Longitude Longitude Longitude 

Longitude 

Longitude 

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

Anchor Radius (if applicable) in feet: 

MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

Anchor Name 

 or No. 

Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

X = Y = 

 

Form BOEM- 0137 (December 2011- Supersedes all previous editions of this form which may not be used.) Page 2 of 4



Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 4

Well Location Plats

Attachment A-2 
572’ 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 

0’ 1000’ 2000’ Geo: Eric Z

VK 959 VK 960 

ENI PETROLEUM US

OCS-G 27247

6180’

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’
Viosca Knoll Blocks 959 & 960

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 17662 FREEPORT MCMORAN 

OIL & GAS LLC 04

S 16152 FREEPORT MCMORAN 

OIL & GAS LLC 12

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).

Scale = 1:12,000

Depth

 (Below Sea Level) 

4,791 ft

3.527 ft

10,550,000 N

10,530,000 N

10,540,000 N

1,330,000 E

1,340,000 E1,350,000 E

2,200,000 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 ft

87°58'0"W

29°0'0"N 87°58'0"W

29°4'0"N

87°54'0"W

29°0'0"N 87°54'0"W

29°4'0"N
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 6

APPENDIX B

GENERAL INFORMATION

(30 CFR Part 550.213 and 550.243)

A. Applications and Permits

There are no Federal/State applications to be submitted for the activities provided for in 

this Plan (exclusive to BOEMRE permit applications and general permits issued by the 

EPA and COE)

Application/Permit Issuing Agency Status

N/A

B. Drilling Fluids

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

used per Well

Water Based (seawater, freshwater, barite) 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 30 CFR Part 256; subpart I; NTL No. 2000-G16, “Guidelines for General 

Lease Surety Bonds,” and additional security under 30 CFR 256.53(d) and NTL No. 

2008-N07 “Supplemental Bond Procedures.” 

E. Oil Spill Responsibility (OSFR)

LLOG Exploration Offshore, L.L.C (MMS Co. No. 02058) will demonstrate oil spill 

financial responsibility for the facilities proposed in this Initial EP according to 30 CFR 

Part 553, and NTL No. 2008-N05 “Guidelines for Oil Spill Financial Responsibility

(OSFR) for Covered Facilities.” 
Viosca Knoll Blocks 959 & 960

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 Calculations (Proprietary) – Attachment B-1

and Blowout Scenario, including Site Specific Proposed Relief Well and Intervention 

Planning and Relief Well Response Time Estimate (Public Information) - Attachment 

B-2. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 8

NTL 2010-N06 Data 

Worst Case Discharge Calculations

Attachment B-1 

(Proprietary Information) 
Viosca Knoll Blocks 959 & 960

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 SCENARIO 

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 4362 1,344,949’ 10,537,450’ 29° 01’ 58.89”N 87° 55’ 29.58”W

VK 959 “B” OCS-G-34874 4362 1,344,904’ 10,537,513’ 29° 01’ 59.51”N 87° 55’ 30.09”W

VK 959 “C” OCS-G-34874 4258 1,345,828’ 10,539,779’ 29° 02’ 22.02”N 87° 55’ 19.88”W

VK 959 “D” OCS-G-34874 4258 1,345,905’ 10,539,685’ 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 occurring from the 

objective sand is modeled with no drill pipe or obstructions in the wellbore followed by a failure of the 

subsea BOP’s and loss of well control at the seabed. The simulated flow and worst case discharge 

(WCD) results for all wells are calculated and the highest WCD is used for this unrestricted blowout 

scenario.

B) Estimated flow rate of the potential blowout

Category Revised EP

Type of Activity Drilling

Facility Location (area / block) VK 959 (surface location)

Facility Designation MODU

Distance to Nearest Shoreline (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)

Total Volume of Spill (bbls) ~3.58 MMBO based on 71 days of uncontrolled flow based 

on simulator 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 situation. 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 4th generation moored rigs. This system is 

typically configured to function the following:

- Blind/;shear ram close

- Pipe ram close

- LMRP disconnect

• ROV Intervention BOP Control System – includes one or more ROV intervention panels 

mounted on the subsea BOP’s located on the seabed allows a ROV utilizing standard ROV 

stabs to access and function the specific BOP controls. These functions will be tested at the 

surface as part of the required BOP stump test and selectively at the seafloor to ensure 

proper functionality. These function include the following (at a minimum):

- Blind/shear ram close

- Pipe ram close

- LMRP disconnect

- WH disconnect

 

• Deadman / Autoshear function – typically fitted on DP MODU’s and but to be on all MODU’s 

operating in the GOM according to new requirements, this equipment allows for an 

automated pre-programmed sequence of functions to close the casing shear rams and the 

blind/shear rams in the event of an inadvertent or emergency disconnect of the LMRP or loss 

of both hydraulic and electrical supply from the surface control system.

In the event that the intervention systems for the subsea BOP’s fail, LLOG will initiate call out of a 

secondary containment / surface intervention system supported by the Helix Well Containment Group 

(HWCG) of which LLOG is a member. This system incorporates a capping stack capable of being 

deployed from the back of a vessel of opportunity equipped with an ROV or from the Helix Q4000 DP 

MODU. Based on the potential integrity concerns of the well, a “cap and flow” system can be 
BLOWOUT 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 

intervention equipment may also require modifications based on actual wellbore conditions. Standard 

equipment is available through the Helix Deepwater Containment System to fit the wellhead and BOP 

stack profiles used for the drilling of the above mentioned well. 

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

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

Sevan Louisian – DP semi, Ensco 8503 – DP semi and Seadrill West Neptune – DP drillship). In the 

event of a blowout scenario that does not involve loss or damage to the rig such as an inadvertent 

disconnect of the BOP’s, then the existing contracted rig may be available for drilling the 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 such 

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) MODU’s would be the preferred 

option due to the logistical advantage versus a moored MODU which may add complications due to 

the mooring spread. 

VESSELS OF OPPORTUNITY

Based on the water depth restrictions for the proposed locations the following “Vessels of 

Opportunity” are presently available for utilization for intervention and containment and relief well 

operations. These may include service vessels and drilling rigs capable of working in the potential 

water depths and may include moored vessels and dynamically positioned vessels. The specific 

conditions of the intervention or relief well operations will dictate the “best fit” vessel to efficiently 

perform the desired results based on the blowout scenario. The list included below illustrates specific 

option that may vary according to the actual timing / availability at the time the vessels are needed.

OPERATION SPECIFIC VESSEL OF OPPORTUNITY

Intervention and Containment • Helix Q4000 (DP Semi) 

• Helix Producer 1 (DP FPU)

Relief Well Drilling Rigs • Diamond Ocean Victory (Moored Semi)

• Ensco 8503 (DP Semi)

• Transocean Enterprise (DP Drillship)

ROV / Multi-Purpose Service Vessels • Oceaneering (numerous DP ROV vessels)

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

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

• Other ROV Vessels – (Chouest, HOS, Fugro, Subsea 7)

Shuttle Tanker / Barge Support • OSG Ship Management 
BLOWOUT 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 for executing drilling operations of 

the proposed well or wells to be drilled.

When planning and designing the well, ample time is spent analyzing offset data, performing any 

needed earth modeling and identifying any potential drilling hazards or well specific conditions to 

safeguard the safety of the crews when well 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 way prevent a blowout incident. Contractor’s personnel and service personnel training 

requirements are verified per regulatory requirements per guidelines issued in BOEM-2010-034 

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

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

operations. Pre-spud meetings are conducted with rig crews and service providers to discuss, inform 

and as needed improve operations and well plans for safety and efficiency considerations. Daily 

meetings are conducted to discuss planning and potential hazards to ensure state of preparedness 

and behavior is enforced to create an informed and safe culture for the operations. Any changes in 

the planning and initial wellbore design is incorporated and communicated in a Management of 

Change (MOC) process to ensure continuity for all personnel. 

Use of established good oil field practices that safeguard crews and equipment are integrated to 

incorporate LLOG’s, the contractor and service provider policies. 

Additional personnel and equipment will be used as needed to elevate awareness and provide real 

time monitoring of well conditions while drilling such as MWD/LWD/PWD tools used in the bottom 

hole assemblies. The tool configuration for each open hole section varies to optimize information 

gathered including the use of Formation-Pressure-While-Drilling (FPWD) tools to establish real time 

formation pressures and to be used to calibrates pore pressure models while drilling. Log information 

and pressure data is used by the drilling engineers, geologist and pore pressure engineers to 

maintain well control and reduced potential events such as well control events and loss circulation 

events. 

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

mud volumes and flow rates, rate of penetration and lithology/paleo to aid in understanding trends 

and geology being drilled. Remote monitoring of real time drilling parameters and evaluation of 

geologic markers and pore pressure indicators is used to identify potential well condition changes.

Proper equipment maintenance and inspection program for same to before the equipment is required. 

Programmed equipment inspections and maintenance will be performed to ensure the equipment 

operability and condition. Operations will cease as needed in order to ensure equipment and well 

conditions are maintained and controlled for the safety of personnel, rig and subsurface equipment 

and the environment.
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 potential 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. The 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 on actual seafloor state 

unforeseen at this time, the final location(s) may need to be revised. The locations have been 

selected based on proximity to the targets sands and potential shallow hazards. 

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

VK 959-960 “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’ 10,540,547’

VK 959 WSW Relief Well 3 1,342,767’ 10,536,075’

VK 959-960 “C” and/or “D” VK 959 S Relief Well 1 1,345,861’ 10,536,611’

VK 959 WSW Relief Well 2 1,343,680’ 10,540,862’

VK 959 NNW Relief Well 3 1,344,441’ 10,552,809’

 

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 issues 
BLOWOUT SCENARIO

 VK 959 - 960

Created by: S.L. Stegeman

Last Revised: 1/13/2015

Page 6 of 8 

Confidential

6 

• mobilize people and equipment (Helix 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) OPERATIONS

• 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 measures

• 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 109
BLOWOUT SCENARIO

 VK 959 - 960

Created by: S.L. Stegeman

Last Revised: 1/13/2015

Page 7 of 8 

Confidential

7 
BLOWOUT 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) 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 10

APPENDIX C

GEOLOGICAL AND GEOPHYSICAL INFORMATION

(30 CFR Part 550.214 and 550.244) 

A. Geological Description

Included as Attachment C-1 are the geological targets and a narrative of trapping 

features proposed in this Plan

B. Structure Contour Maps

Included as Attachment C-2 are current structure maps (depth base and expressed in 

feet subsea) depicting the entire lease 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 Seismic Lines

Included as Attachment C-3 is a copy of the migrated and annotated (shot points, time 

lines, well paths) deep seismic line within 500 feet of the surface location being 

proposed in this Plan. 

D. Geological Structure Cross-Sections

An interpreted geological cross section depicting the proposed well locations and depth 

of the proposed wells is included as Attachment C-4. Such cross section corresponds to 

each seismic line being submitted. 

E. Shallow 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. 
Viosca Knoll Blocks 959 & 960

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 

manmade 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 generalized 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 Plan; therefore, tables providing seismic time versus depth for the 

proposed well locations are not required. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 12

Geological Description

Attachment C-1 

(Proprietary Information)
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 13

Structure Maps

Attachment C-2 

(Proprietary Information)
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 14

Deep Seismic Lines

Attachment C-3 

(Proprietary Information)
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 15

Cross Section Maps

Attachment C-4 

(Proprietary Information) 
Viosca Knoll Blocks 959 & 960

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 based 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 wells, 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 seafloor 

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 known regional sandprone 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. 

 Subsurface amplitude anomalies representing possible 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 benthic communities occur outside the seafloor assessment area in 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 seafloor faults within the seafloor assessment area. 

 A detailed benthic communities evaluation 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 with the same wellpath, 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 Well 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’ FSL 1,451‘ FEL 9440 1184 

Twinned Location.

Proposed Well VK 959-B is less than 130 ft from the 3-D seismic lines depicted in Figures 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 Longitude

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’ FEL 
Wellsite 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 Wells VK 959-A&B are located in the southeastern portion 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 eastern 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 

water bottom anomalies identified by the BOEM (2013) within the maximum anchor radius. 

Features or areas that could support high-density chemosynthetic communities or other benthic 

communities are not anticipated within the maximum anchor radius for 

Proposed Wells VK 959-A&B. 
Wellsite Discussion

Crown and Anchor Prospect 

Viosca Knoll Area 

Proposed Wells VK 959-C&D

Project No.: 14-11-10 

© Berger Geosciences, LLC. 2015

8

Proposed Well VK 959-C&D

The seafloor assessment considers surface conditions within a 2,000-ft radius from the proposed wells. 

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 121 ft southeast of VK 959-C with

the same wellpath, 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 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 Figures 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 North, 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’ FEL
Wellsite Discussion

Crown and Anchor Prospect 

Viosca Knoll Area 

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 Wells VK 959-C&D are located in the southeastern portion of 

VK 959. Water depths across the maximum anchor radius range from 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 wells (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 

anomalies identified by the BOEM (2013) within the maximum anchor radius. 

Features or areas that could support high-density chemosynthetic communities or other benthic 

communities are not anticipated within the maximum anchor radius for 

Proposed Wells VK 959-C&D. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 17

 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 18

Stratigraphic Column

Attachment C-6 

(Proprietary Information)
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 19

APPENDIX D

HYDROGEN SULFIDE (H2S) INFORMATION

(30 CFR Part 250.215 and 250.245) 

A. Concentration

LLOG does not anticipate encountering H2S while conducting the proposed exploratory 

operations provided for under this plan. 

B. Classification

In accordance with 30 CFR 250.490 (c) and NTL No. 2009-G31 “Hydrogen Sulfide”,

LLOG requests that the proposed locations be classified H2S absent. 

C. H2S Contingency Plan

Not applicable for the proposed operations. 

D. Modeling Report

Not applicable to the proposed operations. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 20

APPENDIX E

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

(30 CFR Part 550.216 and 550.247) 

A. High-Density Deepwater Benthic Communities 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 deepwater 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. Topographic 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 within the vicinity of a proposed live 

bottom (Low Relief) area.

F. Potentially Sensitive Biological Features Map

Viosca Knoll Blocks 959 and 960 are not located within the vicinity of a proposed 

sensitive biological feature area.
Viosca Knoll Blocks 959 & 960

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 

impact through compliance with NTL 2012-G01, G02 and NTL 2012 BSEE-G01. See 

Attachment E-1 for a list of the NOAA Species known in the Gulf of Mexico. 

H. Archaeological Report

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. 

I. Air and Water Quality Information

 Not applicable to proposed operations. 

J. Socioeconomic Information

Not applicable to proposed operations. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 22

NOAA Species Known in GOM

Attachment E-1 

(Public Information)


Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 23

APPENDIX F 

WASTE AND DISCHARGE INFORMATION

(30 CFR PART 550.217 AND 550.248)

A. Projected Generated Wastes

See the following tables:

TABLE 1. Wastes you will generate, treat and downhole dispose or 

discharge to the GOM

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

B. Modeling

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

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

VIOSCA 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

Cuttings generated while using 

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 waste

EXAMPLE: Sanitary waste water

Sanitary waste from living 

quarters X bbl/well X bbl/hr/well

chlorinate and discharge 

overboard No

Domestic waste Misc waste for living quarters 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 NA NA NA NA 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 

Downhole 
Please specify whatever the amount reported is a total or per well

VIOSCA KNOLL 959 & 960

Projected 

generated waste

Solid and Liquid

Wastses 

Transportation

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

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

Oil-based drilling fluid or mud NA NA NA NA 

Synthetic-based drilling fluid or mud 

Internal olifin, ester nbased mud

Barged in 25 bbls cutting boxes and / or liquid mud tanks for supply vessels

Newpark Transfer Station, Fourchon, LA 6750 bbls / we

Cuttings wetted with Water-based fluid NA NA NA NA Cuttings wetted with Synthetic-based fluid NA NA NA NA Cuttings wetted with oil-based fluids NA NA NA NA 

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

Produced sand NA NA NA NA 

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

Blanchard Landfill, Golden Meadows, LA 4000 lbs / wel

Used oil Spent oil from machinery

Barged in USCG approved transfer tote tanks. L&L Services, Fourchon, LA 200 bbls / wel

Wash water

Wash water w/ SBM residue and surfactants

Barged in 25 bbls cutting boxes and / or liquid mud tanks for supply vessels

Newpark Transfer Station, Fourchon, LA 2000 bbls / we

Chemical product wastes

Spent treatment and / or damaged chemicals used in operations

Barged in 25 bbls cutting boxes and / or cutting boxes L&L Services, Fourchon, LA 10 bbls / well 

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

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

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

Waste Dispos
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 24

APPENDIX G

AIR EMISSIONS INFORMATION

(30 CFR PART 550.218AND 550.249)

A. Emissions Worksheets and Screening Questions

The Projected Quality Emissions Report (Form MMS-138) addresses the proposed 

drilling, completion and potential testing operations utilizing a typical semisubmersible drilling unit, with related support vessels and construction barge

information.

As evidenced by Attachment G-1, the worksheets were completed based on the 

proposed flaring and burning operations.

Screening Questions for EP’s Yes No

Is any calculated Complete Total (CT) Emission amount (in tons associated with your 

proposed exploration activities more than 90% of the amounts calculated using the 

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 propose to flare or vent natural gas for more than 48 continuous hours from any 

proposed well?

X

Do you propose to burn produced hydrocarbon liquids? X

B. Emissions Reduction Measures

The projected air emissions are within the exemption level; therefore, no emission 

reduction measures are being proposed.

C. Verification of Nondefault Emissions Factors

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

D. Non-Exempt Activities

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

E. Modeling Report 

This section of the Plan is not applicable to the proposed operations.
Viosca Knoll Blocks 959 & 960

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 Case 
EMISSIONS 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 % weight
EMISSIONS 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

66.0
EMISSIONS 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

66.0
EMISSIONS 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

66.0
EMISSIONS 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

66.0
SUMMARY

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 55527.51
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 26

APPENDIX H

OIL SPILL INFORMATION

(30 CFR PART 550.219 AND 550.250)

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 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.

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’Brien Group (TOG) will provide trained personnel capable of providing 

supervisory management of the oil spill response in addition to contacting and 

deploying cleanup personnel and equipment

LLOG utilizes Clean Gulf Associates (CGA) as it’s primary provider for equipment, 

which is an industry cooperative owning an inventory of oil spill clean-up equipment. 

CGA is supported by the Marine Spill Response Corporation’s (MSRC), which is 

responsible for storing, inspecting, maintaining and dispatching CGA’s equipment. The 

MSRC STARS network provides for the closest available personnel, as well as an 

MSRC supervisor to operate the equipment.
Viosca Knoll Blocks 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 Activity 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 Gravity 22.4o 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. Since the worst case discharge determined in our 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 worst-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 Exploration 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 outlined in NTL 2015-N01 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 Management Act analysis, the largest spill volume 

originating from the proposed activity would be a well blowout during drilling operations, 

estimated to be 82,176 barrels of crude 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 BOEM 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 the affiliated islands and bays. This region is an extremely 

sensitive habitat and serves as a migratory, breeding, feeding and nursery habitat for numerous 

species of wildlife. Beaches in this area vary in grain particle size and can be classified as fine 

sand, shell or perched shell beaches. Sandy and muddy tidal flats are also abundant. 

Response

LLOG Exploration Offshore, L.L.C. will make every effort to respond to the Worst Case 

Discharge as effectively as practicable. A description of the response equipment under contract 

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

Using the estimated chemical and physical characteristics of crude oil, an ADIOS weathering 

model was run on a similar product from the ADIOS oil database. The results indicate 17% or 

approximately 13,970 barrels of crude oil would be evaporated/dispersed within 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, travel time to the site and deployment. Figure 2 also indicates 

how operations will be supported. 

LLOG Exploration Offshore, L.L.C.’s Oil Spill Response Plan includes alternative response 

technologies such as 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 aircraft 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 planning 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 skim utilizing CGA spill response equipment, with 

a total derated skimming capacity of 105,943 barrels. Temporary 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 and minimize off-loading time. Safety is first priority. Air 

monitoring will be accomplished and operations deemed safe prior to any 

containment/skimming attempts. 

If the spill went unabated, shoreline impact in Plaquemines Parish, Louisiana would depend 

upon existing environmental conditions. Shoreline protection would include the use of CGA’s 

near shore and shallow water skimmers with a totaled derated skimming capacity of 23,841 

barrels. Temporary storage associated with skimming 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-loading 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 impact given actual sea and 

weather conditions. The State of Louisiana Initial Oil Spill Response Plan, applicable Area 

Contingency and Geographical Response Plans and Unified Command would be consulted to 

ensure that environmental and special economic resources would be correctly identified and 

prioritized to ensure optimal protection. Shoreline protection strategies depict the protection 

response modes applicable for oil spill clean-up operations. The State of Louisiana Initial Oil 

Spill Response Plan provides detailed shoreline protection strategies for this area, and it 

describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands, based 

on the assumption that removal of the released oil will be much easier and less damaging to 

fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. Supervisory 

personnel have the option to modify the deployment and operation of equipment allowing a more 

effective response to site-specific circumstances. LLOG Exploration Offshore, L.L.C.’s contract 

Spill Management Team holds a copy of the State of Louisiana Initial Oil Spill Response Plan. 

Based on the anticipated worst case discharge scenario, LLOG Exploration Offshore, L.L.C. can 

be onsite with contracted oil spill recovery equipment 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 equipment’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 action to provide a safe, aggressive response to 

contain and recover as much of the spilled oil as quickly as it is safe to do so. In an effort to 

protect the environment, response actions will be designed to provide an “in-depth” protection 

strategy meant to recover as much oil as possible as far from environmentally sensitive areas as 

possible. Safety will take precedence over all other considerations during these operations. 

Coordination of response assets will normally be supervised by the Operations Section as 

necessary for close quarter vessel 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 independently, but in coordination with each other. 

This unit would normally monitor the subsurface activities of each vessel (ROV, dispersant 

application, well control support, etc.), as well. 

In addition, these activities will be monitored by the spill management 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 agencies 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 situation and coordinated 

objectives 

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

site 

o On-site command and control established 
Offshore Response Actions 

Equipment Deployment

Surveillance 

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

• Provide trained observer to provide on site status reports 

• Provide command and control platform 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 determine 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, aircraft, and support equipment and personnel 

• Confirm dispersant availability for current and long range operations 

• Start ordering dispersant 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 status reports to vessels to expedite their arrival at sites 

that will provide for their most effective containment 

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

Oceangoing Boom Barge 

• Containment at the source 

• Increased/enhanced skimmer encounter rate 

• Protection booming 

In-situ Burn assets 

• Determine appropriateness of in-situ burn operation 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 aerial 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 draft 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 with a draft of <10 feet when fully loaded 

Storage Vessels 

• Establish availability of CGA contracted assets (See Appendix E) 

• Early call out (to allow for tug boat 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 skimming assets to minimize offloading time 

Vessels of Opportunity (VOO) 

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

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

(VOSS) 
• Acquire additional resources as needed 

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

tending 

• Expect mission specific and safety 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 storage if appropriate 

• Maximize non-organic storage appropriate to vessel limitations 

• Decant as appropriate after approval 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 and 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 operations 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 trailing 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, first considering safety issues 
• Utilize all available advanced technology systems ( 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 skimming 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 increase 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 onboard storage is not available 

• Maximize use of the organic recovered oil storage capacity of the skimming vessel 

Command, Control, and Communications (C3) 

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

• Design an operational scheme, maintaining a manageable span of control 

• Designate and mark C3

 vessels for easy aerial identification 

• Designate and employ C3 aircraft for task forces, groups, etc. 

• Use reconnaissance air craft and Rapid Response Teams (RAT) to confirm the presence 

of recoverable oil 
On Water Recovery Group 

When the first skimming vessel arrives on scene, a complete site assessment will be conducted 

before recovery operations begin. Once it is confirmed that the air monitoring 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 oil. Vessel groups will 

vary in structure as determined by the Operations 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 dependent on several factors including, asset 

availability, weather, spilled oil migration, currents, etc.) 

The 95’ FRV Breton Island out of Venice arrives on scene and conducts an initial site 

assessment. Air monitoring levels are acceptable and no other visual threats have been observed. 

The area is cleared for safe skimming operations. The Breton Island assumes command and 

control (CoC) of on-water recovery operations until a dedicated 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 third 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 Response Units (FRUs) from the load-out location at 

C-Port in Port Fourchon. 

As these vessels set up and begin skimming, they are grouped into task forces (TFs) as directed 

by the Operations Section of the Unified Command located at the command post. 

Initial set-up and potential actions: 

• A 1,000 meter safety zone has been established 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 freshest 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 Sentry boom on each side, creating a swath 

width of 800’ 

• The Breton Island and H.I. Rich skim nearby, 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 and 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 position 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 AquaGuard skimmers and 11 sets of Koseq Rigid 

Skimming Arms. These high volume heavy weather capable systems will be divided into 

functional groups and assigned to specific areas by the Operations 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 deployment 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 approval 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 Response Team level (Region 6) 

Dedicated Near Shore skimming systems 

• FRVs 

• 56’ shallow water skimmers 

• Egmopol and Marco SWS (protected waters) 

• Operate with aerial spotter directing 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 safety training to be required 

• Plan with the US Coast Guard for vessel inspections 

• Operate with aerial spotter directing systems to oil patches 
Shoreline Protection Operations 

Response Planning Considerations 

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

• Shoreline Cleanup Assessment Team (SCAT) assessments 

• Time to acquire personnel and equipment 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 sites 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 response personnel as close to the job site as 

possible to maximize on-site work time 

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

• Constant awareness of weather and oil movement 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 separate into distinct phases when left in a 

quiescent state. When separation occurs, the relatively clean water phase can be siphoned or 

decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases 

the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval 

will be requested prior to decanting operations. This practice is routinely used for oil spill 

recovery. 

CGA Equipment Limitations 

The capability for any spill response equipment, whether a dedicated or portable system, to 

operate in differing weather conditions will be directly in relation to the capabilities of the vessel 

the system in placed on. Most importantly, however, the decision to operate will be based on the 

judgment of the Unified Command and/or the Captain of the vessel, who will ultimately have the 

final say in terminating operations. Skimming equipment listed below may have operational 

limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil 

spill response, vessel skimming operations ceased when seas reached 5-6 feet and vessels were 

often recalled to port when those conditions were exceeded. Systems below are some of the 

most up-to-date systems available and were employed during the DWH spill. 

Boom 3 foot seas, 20 knot winds 

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 winter and easterly winds in the summer. Average wind speed is 

generally 14-15 mph along the coast. Wave heights average 4 and 5 feet. However, during 

hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and 

winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, 

flooding is prominent. 

Surface water temperature ranges between 70 and 80 ̊F during the summer months. During the 

winter, the average temperature will range from 50 and 60 ̊F. 

The Atlantic and Gulf of Mexico hurricane season is officially from 1 June to 30 November. 

97% of all tropical activity occurs within this window. The Atlantic basin shows a very peaked 

season from August through October, with 78% of the tropical storm days, 87% of the minor 

(Saffir-Simpson Scale categories 1 and 2) hurricane days, and 96% of the major (Saffir-Simpson 

categories 3, 4 and 5) hurricane days occurring then. Maximum activity is in early to mid 

September. Once in a few years there may be a hurricane occurring "out of season" - primarily in 

May or December. Globally, September is the most active month and May is the least active 

month. 
FIGURE 1 

TRAJECTORY BY LAND SEGMENT 

Trajectory of a spill and the probability of it impacting a land segment have been projected 

utilizing LLOG Exploration Offshore, L.L.C.’s WCD and information in the BOEM Oil 

Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico 

available on the BOEM website using 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 

1 
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (66 miles from sh

68,206 bbls of crude oil (Volume considering natural weathering) API Gravity 33.3° 

FIGURE 2 – Equipment Response Time to VK 959, Well Location A 

Dispersants/Surveillance

Dispersant/Surveillance Dispersant Capacity (gal) Storage Capacity Persons Req. From Hrs to Procure Hrs to Loadout Trav

si

ASI 

Basler 67T 2000 NA 2 Houma 2 2 0DC 3 1200 NA 2 Houma 2 2 1DC 3 1200 NA 2 Houma 2 2 1Aero Commander NA NA 2 Houma 2 2 0

Offshore Response

Offshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

CGA 

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 Boom Barge (CGA-300) 42” Auto Boom (25000’) NA NA 1 Tug 50 Crew 4 (Barge) 2 (Per Crew) Leeville 4 0 6 95’ FRV 12342 249 NA 4 Leeville 2 0 1 95’ FRV 12342 249 NA 4 Venice 2 0 1 

Recovered Oil Storage No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 
Staging Area: Venice

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging 

CGA 

FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 2 2 12.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 2 2 2.1 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 17.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 2 8 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Leeville 2 2 4.4 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 2 4.9 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 2 2 0 Hydro-Fire Boom NA NA 8 Utility 40 Harvey 2 4 2.1 
Nearshore Response

Nearshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

CGA 

46’ FRV 5000 65 NA 4 Morgan City 2 0 2 46’ FRV 5000 65 NA 4 Venice 2 0 1 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 

Staging Area: Venice

Nearshore and Inland 

Skimmers With Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Trav

Deplo

CGA 

SWS Egmopol 3000 100 NA 3 Morgan City 2 2 4.9 SWS Marco 3588 20 NA 3 Lake Charles 2 2 8 SWS Marco 3588 34 NA 3 Leeville 2 2 4.4 SWS Marco 3588 34 NA 3 Venice 2 2 0 Rope Mop 77 2 0 3 Harvey 2 2 2.1 
Shoreline Protection 

Staging Area: Venice 

Shoreline Protection 

Boom VOO Persons Req. Storage/Warehouse Location Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Site 

AMPOL (available through MSA) 

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 6 2 20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2.2 2 

OMI Environmental (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 6 2 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 12.1 2 10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 9.7 2 20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.9 2 10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 4.5 2 10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.8 2 15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.1 2 

Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Trav

Deplo

CGA 

Wildlife Support Trailer NA NA NA 2 Harvey 2 2 2.1 Bird Scare Guns (48) NA NA NA 2 Harvey 2 2 2.1 Bird Scare Guns (12) NA NA NA 2 Galveston 2 2 12.7 Bird Scare Guns (12) NA NA NA 2 Aransas Pass 2 2 17.7 Bird Scare Guns (24) NA NA NA 2 Lake Charles 2 2 8 Bird Scare Guns (24) NA NA NA 2 Leeville 2 2 4.4 

Response Asset Total 

Offshore EDRC 105,943 

Offshore Recovered Oil Storage 115,198 

Nearshore / Shallow Water EDRC 23,841 

Nearshore / Shallow Water Recovered Oil Storage 25,320 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 28

APPENDIX I

ENVIRONMENTAL MONITORING INFORMATION

(30 CFR PART 550.221 AND 550.252) 

A. Monitoring Systems 

LLOG subscribes to Impact Weather 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 

people 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 guidelines of the applicable NTL 2009-G02 “Ocean 

Current Monitoring”, by monitoring and gathering ocean current data using Acoustic 

Doppler Current Profile (ADCP) while the MODU is on location. 

B. Incidental Takes

LLOG does not anticipate the incidental taking of any species as a result of the 

proposed activities based on the implementation of, and adherence to, the BSEE NTL 

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

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

Reporting”. 

C. Flower Garden Banks National Marine Sanctuary

This section of the plan is not applicable to the proposed operations. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 29

APPENDIX J

LEASE STIPULATIONS/SPECIAL CONDITIONS INFORMATION

(30 CFR PART 550.222 AND 550.253) 

A. Lease Stipulations

Minerals Management Service (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 therefore 

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 

Species on Lease OCS-G-27247. 

Lease Stipulation Nos. 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. 
Viosca Knoll Blocks 959 & 960

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. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 31

APPENDIX K

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(30 CFR Part 550.23 and 550.54)

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

This section does not apply to 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 Species Reporting” and BSEE NTL No. 

2012-G01 “Marine Trash and Debris Awareness and Elimination”. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 32

APPENDIX L

RELATED FACILITIES AND OPERATIONS INFORMATION

(30 CFR PART 550.256) 

A. Produced Liquid Hydrocarbon Transportation Vessels

Not applicable to proposed operations. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 33

APPENDIX M

SUPPORT VESSELS AND AIRCRAFT INFORMATION

(30 CFR PART 550.224 AND 550.257)

A. General

Personnel involved in the proposed operations will typically use their own vehicles as 

transportation to and from the selected onshore base; whereas the selected vendors will 

transport the equipment by a combination of trucks, boats and/or helicopters to the 

onshore base. The personnel and equipment will then be transported to the drilling rig 

via the transportation methods and frequencies shown, taking the most direct route 

feasible as mandated by weather and traffic conditions:

Drillship and DP Semisubmersible Rig:

Type Maximum Fuel Tank 

Storage Capacity

Maximum No. in Area 

at Any Time

Trip Frequency or 

Duration

Supply Boats 500 bbls 1 Six times weekly

Crew Boats 500 bbls 1 Three times weekly

Aircraft 279 gallons 1 As Needed

Semisubmersible Rig:

Type Maximum Fuel Tank 

Storage Capacity

Maximum No. in Area 

at Any Time

Trip Frequency or 

Duration

Tug Boats 3000 bbls 1 During rig moves on/off

Supply Boats 500 bbls 1 Six times weekly

Crew Boats 500 bbls 1 Three times weekly

Aircraft 1900 lbs 1 As Needed

Anchor Handling 

Vessel

15,100 bbls 1 3-4 days

Work Boat 6,450 bbls 1 3-4 days

B. Diesel Oil Supply Vessels

Size of Fuel Supply 

Vessel

Capacity of fuel 

Supply Vessel

Frequency of Fuel 

Transfers

Route Fuel Supply 

Vessel Will Take

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

Knoll Blocks 959 and 

960

C. Drilling Fluids Transportation

See Table 2 – Wastes you will Transport and/or Dispose of Onshore, located in 

Appendix F of this Plan. 
Viosca Knoll Blocks 959 & 960

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. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 35

Vicinity 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

20 0 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

JOB No: DATE: REV. 

FILENAME:

141465 BY: CBB Jan. 9, 2015

141465VIC2.DWG 0

BARATARIA

BAY GRAND

BAY

BRETON

SOUND

TIMBALIER BAY

WEST BAY GARDEN

ISLAND

BAY

EAST Timbalier Islands BAY

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 MAUREPAS
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 36

APPENDIX N

ONSHORE SUPPORT FACILITIES INFORMATION

(30 CFR PART 550.225 AND 550.258) 

 A. General

The proposed surface disturbances in Viosca Knoll Blocks 959 and 960 will be 

located approximately 66 statute miles from the nearest Louisiana shoreline, and 

approximately 140 statute miles from the following onshore support base and the 

proposed surface disturbances: 

Name Location Existing/New/Modified

LLOG c/o Turn Key 

Cleaning Services

Fourchon, LA Existing

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

operations: 

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

● Dispatching personnel and equipment, and does not anticipate the need for any 

expansion of the selected facilities as a result of the activities proposed in this 

Initial Plan.

● Temporary storage for materials and equipment.

● 24 Hour Dispatcher 

B. Support Base Construction or Expansion

The proposed operations are temporary in nature and do not 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. 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 37

APPENDIX O

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION

(30 CFR PART 550.226 AND 550.260) 

A. Consistency Certification

. 

A certificate of Coastal Zone Management Consistency for 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 enforceable policies and certifies the 

consistency for the proposed operations. 
Viosca Knoll Blocks 959 & 960

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)

 


Viosca Knoll Blocks 959 & 960

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. Alabama 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 

will be no new construction, dredging or filling in 

Alabama state waters. There will be no new commercial 

development or capital improvements in Alabama’s 

coastal zone, nor will there be any employment effects.

Mineral Resource Exploration 

and Extraction

Proposed 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 

Policies

Biological Productivity Appendix H

Water Quality Appendix H

Water Resources Appendix H

Air Quality Appendix G

Wetlands and Submerged 

Grassbeds

Appendix H

Beach and Dune Protection Appendix H

Wildlife Habitat Protection Appendix H

Endangered Species Appendix H

Cultural Resources Protection Appendix D 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.
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 40

APPENDIX P 

ENVIRONMENTAL IMPACT ANALYSIS

(30 CFR PART 550.227 AND 550.261) 

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

The following matrix is utilized to identify the affected environments that could be 

impacted by these IPF’s. An “x” has been marked for each IPF category that LLOG 

has determined may impact a particular environment as a result of the proposed 

activities. For those cells which are footnoted, a statement is provided as to the 

applicability of the proposed activities, and where there may be an effect, an 

analysis of the effect is provided.

Environmental Resources Impact Producing Factors (IPF’s)

Emissions 

(air, noise, 

light, etc)

Effluents

(muds, cuttings, 

other discharges 

to the water 

column or 

seafloor)

Physical 

disturbances 

to the seafloor 

(rig, anchor, 

structure 

emplacement, 

etc.)

Wastes sent 

to shore for 

treatment 

or disposal

Accidents 

(e.g., oil 

spills, 

chemical 

spills, H2S 

releases)

Other IPF’s 

you Identify

Site Specific at Offshore 

Location

Designated topographic 

features

(1) (1) (1)

Pinnacle Trend area live 

bottoms

(2) (2) (2)

Eastern Gulf live bottoms (3) (3) (3)

Chemosynthetic communities 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 areas
Viosca Knoll Blocks 959 & 960

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 attached to an OCS lease;

(c) Essential Fish Habitat (EFH) criteria of 500 feet from any no-activity zone; or

(d) Proximity of any submarine bank (500 ft buffer zone) with relief greater than 2 meters that is not 

protected by the Topographic Stipulation attached to an OCS lease.

2. Activities with any bottom disturbance within an OCS lease block protected through the Live Bottom 

(Pinnacle Trend) Stipulation attached to an OCS lease.

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

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

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

6. All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that you 

determine would impact these environmental resources. 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 prehistoric 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 occur, the EIA can note that in a sentence or two.

8. All activities that you determine might have an adverse effect on endangered or threatened marine mammals 

or sea turtles or their critical habitats.

9. Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges.
Viosca Knoll Blocks 959 & 960

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 measures 

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 existing 

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 anticipated emissions, effluents, physical disturbances to the 

seafloor, wastes transported to shore, and/or accidents from the proposed 

activities that could cause impacts to topographic features.

The proposed surface disturbances within Viosca Knoll Blocks 959 and 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 surface spill is 

not likely to reach sessile biota. Subsurface spills could cause adverse impacts 

to a designated topographic feature; however, due to the offset distance this 

should not have an impact. 

In the event of an unanticipated spill, LLOG would immediately implement its 

Regional Oil Spill Response Plan and active source control and countermeasures 

to minimize these potential impacts.
Viosca Knoll Blocks 959 & 960

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 

seafloor, wastes sent to shore and/or accidents from the proposed activities that 

could cause impacts to a pinnacle trend area.

The proposed surface disturbances within 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 bottoms.

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 anchors. These surface location disturbance areas would be avoided 

and/or mitigated during the review and approval process by the BOEM. 

In the event of an unanticipated spill, LLOG would immediately implement its 

Regional Oil Spill Response Plan and activate source control and 

countermeasures to minimize these potential impacts.

• Eastern Gulf Live Bottoms

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

the seafloor, wastes sent to shore, and/or accidents from the proposed activities 

that could cause impacts to Eastern Gulf live bottoms.

The proposed surface disturbances 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 shallow hazards assessment 
Viosca Knoll Blocks 959 & 960

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 Permit GMG290000 which mandates volume discharge rate limitations, 

certain testing requirements for toxicity and oil and grease limitations. As such, 

it is not anticipated these discharges authorized under the approved EPA 

NPDES permit will cause significant adverse impacts to water quality.

Certain wastes generated from the proposed activities will be manifested and 

sent to shore for treatment and/or disposal at approved facilities. Other waste 

which may be considered hazardous will be collected and transported in sealed 

containers and transported to approve disposal sites in accordance with the 

RCRA regulations and guidelines. 

An accidental oil spill release from the proposed activities, and cumulative 

similar discharge activity within the vicinity could potentially cause temporary 

impacts to water quality. In the event of such a 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 cause some detrimental 

effects on fisheries. It is unlikely a spill would occur; however, such a release in 

open waters closed to mobile adult finfish or shellfish would likely be sub-lethal 

and the extent of damage would be reduced to the capability of adult fish and 

shellfish to avoid a spill, to metabolize hydrocarbons, and to excrete both 

metabolites and parent compounds. 
Viosca Knoll Blocks 959 & 960

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 whale, 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 any disturbance would depend on the size and percentage of 

the population affected, ecological importance of the disturbed area, 

environmental and biological parameters that influence an animal’s sensitivity to 

disturbance and stress, and the accommodation time in response to prolonged 

disturbance (Geraci and St. Aubin, 1980). Collisions between cetaceans and 

ship could cause serious injury or death (Laist et al., 2001). 

Sperm whales are one of 11 whale species that are hit commonly by ships (Laist 

et al., 2001). Collisions between OCS vessels and cetaceans within the project 

area are expected to be unusual events.

LLOG does not anticipate the incidental taking of any marine mammals as the 

result of the proposed activities. The proposed 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 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. 
Viosca Knoll Blocks 959 & 960

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 impacts to water quality.

In the event of an unanticipated blowout, LLOG will implement industry wide 

standards for using proven equipment and technology for such responses. 

LLOG would immediately implement its Regional Oil Spill Response 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 spill releases are potential threats which 

could have lethal effects on turtles. Contact and/or consumption of this released 

material could seriously affect individual sea turtles. Most OCS related impacts 

on sea turtles are expected to be sub-lethal. Chronic 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 wide 

standards for using proven equipment and technology for such responses. 

LLOG would immediately implement its Regional Oil Spill Response Plan and 
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 47

activate source control and countermeasures to minimize these potential 

impacts.

• Air Quality

The proposed 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. 

• Ship Wreck Sites (Known or Potential)

There are no physical disturbances to the seafloor which could impact known or 

potential shipwreck sites, as the review of high resolution shallow hazards data 

indicate there are no known or potential shipwreck sites located within the 

survey area. As such, LLOG does not anticipate any IPF’s as a result of the 

proposed activities. 

• Prehistoric Archaeological Sites

There are no physical disturbances to the seafloor which could cause impacts to 

prehistoric archaeological sites, as the review of high resolution shallow hazards 

data and supporting studies did not reflect the occurrence of prehistoric 

archaeological sites. As such LLOG does not anticipate any IPF’s as a result of 

the proposed activities. 

Vicinity of Offshore Location 

• Essential Fish Habitat

As a result of the proposed activities, essential fish habitat may be adversely 

impacted by effluents and/or accidents.

An Accidental oil spill that may occur as a result of the proposed activities has 

potential to cause some detrimental effects on essential fish habitat. It is 

unlikely that an accidental oil spill release would occur; however, if a spill were 

to occur in close proximity to finfish or shellfish, the effects would likely be 

sub-lethal and the extent of damage would be reduced to the capability of adult 

fish and shellfish to avoid a spill, to metabolize hydrocarbons and to excrete 

both metabolites and parent compounds. 

In the event of an unanticipated blowout, LLOG will implement industry wide 

standards for using proven equipment and technology for such responses. 

LLOG would immediately implement its Regional Oil Spill Response Plan and 
Viosca Knoll Blocks 959 & 960

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 result of the proposed activities, marine and pelagic birds may be adversely 

impacted by an accidental oil spill, by the birds coming into contact with the 

released oil.

In the event of an unanticipated blowout resulting in an oil spill, it is likely to 

have an impact based on the industry wide standards for using proven equipment 

and technology for such responses. In that event, LLOG will implement the 

Regional Oil Spill Response Plan and activate source control and 

countermeasures to minimize these potential impacts.

• Public Health and Safety

There are no anticipated emissions, effluents, wastes sent to shore, and/or 

accidents from the proposed activities that could cause impacts to the public 

health safety. LLOG has requested 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 

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.

• 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 66 
Viosca Knoll Blocks 959 & 960

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 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.

• 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 

(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.
Viosca Knoll Blocks 959 & 960

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 

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.

Other Resources Identified

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

above. 

C. Impacts of Proposed Activities

LLOG does not anticipate any impacts on the offshore site specific locations, offshore 

vicinity, and/or coastal and onshore environmental conditions based on the potential 

impacts identified in the EIA worksheets and historical operations in the exploration of 

this reservoir.

D. Environmental Hazards

The Gulf of Mexico may experience several hurricanes throughout the season which 

typically runs from June through November. A severe hurricane may impact the 

activities covered in this Plan. Such impacts may be damage to the drilling rig, the 

unanticipated release of hydrocarbons depending upon the current status of the well. 

Additionally, the surfaces 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. 
Viosca Knoll Blocks 959 & 960

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.com 
Viosca Knoll Blocks 959 & 960

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

2002

2006

2015

2015

BOEMRE Environmental Impact Statement Report No. 

2009-053

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

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

250.223 / 250.227

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2006

NTL 2000-G16 “Guidelines for General Lease Surety 

Bonds”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2000

NTL 2005-G07 “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 2012-G02 “Implementation of seismic Survey 

Mitigation Measures and Protected Species Observer 

Program”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2012

BSEE NTL 2012-G01 “Marine Trash & Debris Awareness 

& Elimination”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2012

JOINT NTL 2012-G01 “Vessel Strike Avoidance and 

Injured/Dead Protective Species”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2012

NTL 2008-G04 “Information Requirements for Exploration 

Plans and Development Operations Coordination 

Documents”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

NTL 2008-N05 “Guidelines for Oil Spill Financial 

Responsibility for Covered Offshore Facilities”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

NTL 2008-G06 “Remotely Operated Vehicle Surveys in 

Deepwater”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

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

Regulation, and Enforcement

2008

NTL 2008-G20 “Revisions to the List of OCS Lease Blocks 

Requiring Archaeological Resource Surveys and Reports”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2008

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

Regulation, and Enforcement

2009

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

Regulation, and Enforcement

2009

NTL 2009-G38 “Drilling Windows, Eastern Gulf of 

Mexico”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

NTL 2009-G39 “Biologically-Sensitive Underwater 

Features and Areas”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2009

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

Regulation, and Enforcement

2009

NTL 2009-N11 “Air Quality Jurisdiction on the 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”

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2010

NPDES General Permit GMG290000 EPA – Region VI 2012

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2014
Viosca Knoll Blocks 959 & 960

OCS-G 34874 & OCS-G 27247

Joint Initial Exploration Plan 53

APPENDIX Q

ADMINISTRATIVE INFORMATION

(30 CFR Part 550.228 and 550.262)

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 Rates and Life of Reserves

• New and Unusual Technologies 

• Geological and Geophysical Attachments

B. Bibliography

The following documents were utilized in preparing this Plan: 

Document Author Dated

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

2002

2006

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. 2014