UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - N-09504

Type - Initial Exploration Plan

Lease(s) - OCS-G31521 Block - 705 Mississippi Canyon Area

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

Drill and complete well A

SEMISUBMERSIBLE

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

should be addressed in an Environmental Assessment.

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

James Webb

Plan Coordinator

Description -

Rig Type -

Subject:

From:

October 11, 2011
LLOG EXPLORATION OFFSHORE, L.L.C. 

1001 Ochsner Boulevard, Suite 200 

Covington, Louisiana 70433 

INITIAL EXPLORATION PLAN (MODIFIED) 

N-9504

OCS-G-31521

MISSISSIPPI CANYON BLOCK 705 

PREPARED BY: 

Kathy Gowland 

Regulatory Specialist 

985-801-4300 (Main) 

985-801-4317 (Direct) 

kathygo@llog.com

September, 2011 



Mississippi Canyon Block 705 (OCS-G 31521 

Modified Exploration Plan (N-9504) 

APPENDIX A 

PLAN CONTENTS

(30 CFR Part 250.211 and 250.241) 

A. Plan information

In accordance with Notice to Lessees and Operators (NTL) No. 2010-N06, 

LLOG Exploration Offshore, LLC wishes to modify our previously submitted 

Initial Exploration Plan (N-9504), Mississippi Canyon Block 705, OCS-G-31521 

Lease, which was submitted on February 25, 2010 and is pending approval. 

Included as Attachment A is Form MMS 137 “OCS Plan Information Form”, 

which provides for the drilling, completion, and testing of Well Location #A. 

B. Location

Included are the following attachments: Attachment B: Well Location Plat 

and Attachment C: Bathymetry Map detailing the proposed surface location 

disturbance area with the proposed anchor radius of the drilling rig. 

C. Safety & Pollution Prevention Features

Safety features on the semi-submersible will include well control, pollution 

prevention, welding procedure, and blowout prevention equipment as described in 

Title 30 CFR Part 250, Subparts C, D, E, G & O; and as further clarified by 

Notices to Lessees, U.S. Environmental Protection Agency and the U. S. Coast 

Guard. The appropriate life rafts, life jackets, ring buoys, etc., as prescribed by 

the U. S. Coast Guard will be maintained on the facility at all time. 

D. Storage Tanks and Vessels

The following table details the storage tanks and/or production vessels that will 

store oil (capacity greater than 25 bbls. or more) and be used to support the 

proposed activities (MODU, barges, platforms, etc.): 

Type of 

Storage Tank 

Type of 

Facility 

Tank

Capacity 

(bbls)

Number of 

tanks 

Total 

Capacity 

(bbls)

Fluid Gravity 

(API) 

Fuel Oil 

(Marine 

Diesel)

SemiSubmersible 95.24 2 190.5 No. 2 Diesel 

 2917.8 4 11,671.2 

Total 11,861.7 

E. Additional Measures

LLOG does not propose any additional safety, pollution prevention, or early spill 

detection measures beyond those required by 30 CFR Part 250. 

U.S. Department of the Interior OMB Control Number: 1010-0151

Minerals Management Service OMB Approval Expires: 12/31/2011

OCS PLAN INFORMATION FORM 

General Information 

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

Company Name: MMS Operator Number: 

Address: Contact Person: 

 Phone Number: 

 E-Mail Address: 

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

Objective(s): Oil Gas Sulphur Salt Onshore Base: Distance to Closest Land (Miles): 

Description of Proposed Activities (Mark all that apply)

Exploration drilling Development drilling 

Well completion Installation of production platform 

Well test flaring (for more than 48 hours) Installation of production facilities 

Installation of caisson or platform as well protection structure Installation of satellite structure 

Installation of subsea wellheads and/or manifolds Commence production 

Installation of lease term pipelines Other (Specify and describe) 

Have you submitted or do you plan to submit a Conservation Information Document to accompany this plan? Yes No 

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

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

Do you propose any activities that may disturb an MMS-designated high-probability archaeological area? Yes No 

Have all of the surface locations of your proposed activities been previously reviewed and approved by MMS? Yes No 

Tentative Schedule of Proposed Activities 

Proposed Activity Start Date End Date No. of Days 

 

 

Description of Drilling Rig Description of Production Platform 

 Jackup Drillship Caisson Tension leg platform

 Gorilla Jackup Platform rig Well protector Compliant tower 

 Semisubmersible Submersible Fixed platform Guyed tower

 DP Semisubmersible Other (Attach Description) Subsea manifold Floating production system 

Drilling Rig Name (If Known): Spar Other (Attach Description) 

Description of Lease Term Pipelines 

From (Facility/Area/Block) To (Facility/Area/Block) Diameter (Inches) Length (Feet) 

 

MMS FORM MMS-137 (December 2008 - Supersedes all previous editions of form MMS-137 which may not be used.) Page 1 of 2

X

LLOG Exploration Offshore, L.L.C. 02058

1001 Ochsner Boulevard, Suite 200

Covington, Louisiana 70433

Kathy Gowland

985-801-4300

kathygo@llog.com

OCS-G-31521 MC 705 Biddy Ball

X Fourchon, LA 53

X

X

X

X

X

X

X

X

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

X
2

OCS PLAN INFORMATION FORM (CONTINUED)

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

Proposed Well/Structure Location

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

Anchor Radius (if applicable) in feet: Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. OCS OCS 

Area Name 

Block No. 

Blockline

Departures 

(in feet)

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

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

Lambert X-Y 

coordinates 

X: X: 

 Y: Y: 

Latitude/

Longitude

Latitude Latitude 

Longitude Longitude 

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

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

Anchor Name 

 or No. 

Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35) requires us 

to inform you that MMS collects this information as part of an applicant’s Exploration Plan or Development Operations 

Coordination Document submitted for MMS approval. We use the information to facilitate our review and data entry for 

OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 250.197. An 

agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays 

a currently valid Office of Management and Budget Control Number. The use of this form is voluntary. The public 

reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations 

Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an accompanying EP 

(1,000 hours in AKOCSR), or 690 (1,700 in AKOCSR) with an accompanying DPP or DOCD, including the time for 

reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. 

Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance 

Officer, Mail Stop 5438, Minerals Management Service, 1849 C Street, NW., Washington, DC 20240.

MMS FORM MMS-137 (December 2008 - Supersedes all previous editions of form MMS-137 which may not be used.) Page 2 of 2

WELL LOCATION A

8,000' X

G-31521

MISSISSIPPI CANYON

705

1926' FNL

3013' FWL

699,973

10,262,394

28° 14' 53.483"

89° 55' 16.843"

850'





APPENDIX B 

GENERAL INFORMATION

(30 CFR Part 250.213 and 250.243) 

A. Applications and Permits

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

for in this Plan (exclusive to BOEMRE permit applications and general permits 

issued by the EPA and COE) 

Application/Permit Issuing Agency Status 

N/A 

 

B. Drilling Fluids

Type of Drilling Fluid Estimated Volume of Drilling Fluid 

to be used per Well 

Water Based (seawater, freshwater, barite) 18,263 bbls/well 

Oil –based (diesel, mineral oil) N/A 

Synthetic-based (internal olefin, ester) 6,750 bbls/well 

C. New Or Unusual Technology

LLOG does not propose using any new and/or unusual technology for the 

operations proposed this Revised Plan. 

D. Bonding Statement

The bond requirements for the activities and facilities proposed in this Revised EP 

are satisfied by an area wide bond, furnished and maintained according to 30 CFR 

Part 256; subpart I; NTL No. 2006-G16, “Guidelines for General Lease Surety 

Bonds,” and additional security under 30 CFR 256.43(d) and National NTL No. 

2003-N06 “Supplemental Bonding Procedures.” 

E. Oil Spill Responsibility (OSFR)

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

spill financial responsibility for the facilities proposed in this Revised EP 

according to 30 CFR Part 253, and NTL 99-N01, “Guidelines for Oil Spill 

Financial Responsibility for Covered Facilities.” 
F. Deepwater Well Control Statement

LLOG Exploration Offshore, L.L.C. (MMS Co. No. 02058) has the financial 

capability to drill a relief well and conduct other emergency well control 

operations.

G. Blowout Scenario

See the following Blowout Scenario including Site Specific Proposed Relief Well 

and Intervention Planning and Relief Well Response Time Estimate. 
BLOWOUT SCENARIO 

 MC 705 

OCS-G-31521 

Created by: S.L. Stegeman 

Last Revised: 8/9/2011 

Page 1 of 6 

Confidential

 1 

BLOWOUT SCENARIO

Pursuant with 30 CFR 250.213(g), 250.219, 250,250 and NTL 2010-N06 the following attachment 

provides a blowout scenario description, information regarding any oil spill, WCD results and assumptions 

of potential spill and additional measures taken to firstly enhance the ability to prevent a blowout and 

secondly to manage a blowout scenario if it occurred. 

INFORMATION REQUIREMENTS

PROPOSED PROSPECT INFORMATION

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

MC 705 OCS-G-31521 864 699,973’ 10,262,394’ 28q 14’ 53.483” 89q 55’ 16.843” 

INFORMATION REQUIREMENTS

A) Blowout scenario 

The MC 705 to be drilled to potential outlined in the Geological and Geophysical Information Section 

of this plan utilizing a typical subsea wellhead system, conductor, surface and intermediate casing 

strings from a pre-existing wellbore and a MODU rig with marine riser and a subsea BOP system. A 

hydrocarbon influx and a well control event occurring from the objective sand is modeled with no drill 

pipe or obstructions in the wellbore followed by a failure of the subsea BOP’s and loss of well control 

at the seabed. The simulated flow and worst case discharge (WCD) results for all wells are 

calculated and the highest WCD is used for this unrestricted blowout scenario. 

B) Estimated flow rate of the potential blowout 

Category Revised EP 

Type of Activity Drilling / Completion Ops 

Facility Location (area / block) MC 705 

Facility Designation MODU 

Distance to Nearest Shoreline (miles) ~53 

Uncontrolled Blowout (Volume per day) 123,200 bbls 

Type of Fluid Gas and Condensate 

C) Total volume and maximum duration of the potential blowout 

Duration of Flow (days) 99 days total (see Relief Well Response Estimate below) 

Total Volume of Spill (bbls) 12.2 MMBO based on 99 days of uncontrolled flow 

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

Omitted from Public Information Copies 

E) Potential for the well to bridge over 

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

including in-situ stress, rock strength and fluid velocities at the sand face. Given the substantial fluid 

velocities inherent in the WCD, and the scenario as defined where the formation is not supported by a 

cased and cemented wellbore, it is possible that the borehole may fall/collapse/bridge over within a 
BLOWOUT SCENARIO 

 MC 705 

OCS-G-31521 

Created by: S.L. Stegeman 

Last Revised: 8/9/2011 

Page 2 of 6 

Confidential

 2 

span of a few days, significantly reducing the outflow of the rates. For this blowout scenario, no 

bridging is considered. 

F) Likelihood for intervention to stop blowout 

The likelihood of surface intervention to stop a blowout is based on some of the following equipment 

specific to potential MODU’s to be contracted for this well. It is reasonable to assume that the sooner 

you are able to respond to the initial blowout, the better likelihood there is to control and contain the 

event due to reduced pressures at the wellhead, less exposure of well fluids to erode and 

compromise the well control equipment, and less exposure of hydrocarbons to the surface to 

safeguard personnel and equipment in an emergency situation. This equipment includes: 

x Secondary Acoustic BOP Control System – typically fitted on DP MODU’s presently operating 

in the GOM. This system has the ability to communicate and function specific BOP controls 

from the surface in the event of a failure of the primary umbilical control system. This system 

typically can establish BOP controls from the 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 

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

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

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

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

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

- Blind/shear ram close 

- Pipe ram close 

- LMRP disconnect 

- WH disconnect 

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

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

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

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

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

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

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

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

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

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

deployed which may include the Helix Producer 1 capable of handling up to 55,000 BOPD flowback. 

The vertical intervention work is contingent upon the condition of the blowing out well and what 

equipment is intact to access the wellbore for kill or containment operations. The available 

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

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

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

 MC 705 

OCS-G-31521 

Created by: S.L. Stegeman 

Last Revised: 8/9/2011 

Page 3 of 6 

Confidential

 3 

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

LLOG currently has one deepwater MODU under contract (Noble Amos Runner moored semi). In the 

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

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

and vertical intervention work. If the blowout scenario involves damage to the rig or loss of the BOP’s 

and riser, a replacement rig or rigs will be required. 

With the current activity level in the GOM, 25 to 35 deepwater MODU’S are potentially available to 

support the relief well drilling operations. Rig share and resource sharing agreements are in place 

between members of the Helix Well Containment Group. The ability to negotiate and contract an 

appropriate rig or rigs to drill relief wells is highly probable in a short period of time. If the rig or rigs 

are operating, the time to properly secure the well and mobe the rig to the relief well site location is 

estimated to be about 14 to 21 days. Dynamically positioned (DP) MODU’s would be the preferred 

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

the mooring spread. 

VESSELS OF OPPORTUNITY

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

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

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

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

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

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

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

OPERATION SPECIFIC VESSEL OF OPPORTUNITY 

Intervention and Containment x Helix Q4000 (DP Semi) 

x Helix Producer 1 (DP FPU) 

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

x Ensco 8502 (DP Semi) 

x Transocean Enterprise (DP Drillship) 

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

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

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

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

Shuttle Tanker / Barge Support x OSG Ship Management 

H) Measures taken to enhance ability to prevent blowout / reduce likelihood of blowout 

Pursuant to BOEM-2010-034 Final Interim Rules, measures to enhance the ability to prevent or 

reduce the likelihood of a blowout are largely based on proper planning and communication, 

identification of potential hazards, training and experience of personnel, use of good oil field practices 

and proper equipment that is properly maintained and inspected for executing drilling operations of 

the proposed well or wells to be drilled. 

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

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

safeguard the safety of the crews when well construction operations are underway. Once the design 
BLOWOUT SCENARIO 

 MC 705 

OCS-G-31521 

Created by: S.L. Stegeman 

Last Revised: 8/9/2011 

Page 4 of 6 

Confidential

 4 

criteria and well design is established, the well design is modeled for the lifecycle of the wellbore to 

ensure potential failure modes are eliminated. Pursuant to BOEM-2010-0034 Interim Final Rules 

implemented additional considerations of a minimum of 2 independent barriers for both internal and 

external flow paths in addition to proper positive and negative testing of the barriers. 

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

best way prevent a blowout incident. Contractor’s personnel and service personnel training 

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

events.

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

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

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

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

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

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

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

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

and the environment. 

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

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

by NTL 2010-N06, the following is provided to demonstrate the potential time needed for performing 

secondary intervention and drilling of a relief well to handle potential worst case discharge for the 

proposed prospect. Specific plans are integrated into the Helix Well Containment Groups procures to 

be approved and submitted with the Application for Permit to Drill. Equipment availability, backup 

equipment and adaptability to the potential scenarios will need to be addressed based on the initial 

site assessment of the seafloor conditions for intervention operations. Relief well equipment such as 

backup wellhead equipment and tubulars will be available in LLOG’s inventory for immediate 

deployment as needed to address frilling the relief well(s). 
BLOWOUT SCENARIO 

 MC 705 

OCS-G-31521 

Created by: S.L. Stegeman 

Last Revised: 8/9/2011 

Page 5 of 6 

Confidential

 5 

SITE SPECIFIC PROPOSED RELIEF WELL AND INTERVENTION PLANNING

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

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

/ required. In the event the well can be contained, produced fluid can be plumbed into the production 

manifold within 200’ of the planned surface location. A LLOG pipeline is an abandoned 10” POGO 

Production pipeline that runs in close proximity and is presently planned to be used for the initial 

completion tie-in. 

A relief well site has been initially identified to address blowout scenarios for the potential geologic 

targets for the proposed wells. One relief well surface locations is proposed for the proposed 

exploration plan well. Due to shipping fairway restrictions, the proposed relief well location(s) is 

dependent on governmental agency approvals. A 1000’ bathometry limit is planned to accommodate 

the use of DP MODUs which typically need 1000’ water depths to operate in a very tight watch circle. 

Based on actual seafloor state unforeseen at this time, the final location(s) may need to be revised. 

The location has been selected based on proximity to the targets sands and potential shallow 

hazards. 

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

MC 705 OCS-G-31521 MC 705 R1 699,973’ 10,256,748’ 

 

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

RELIEF WELL RESPONSE TIME ESTIMATE

OPERATION TIME ESTIMATE 

 (DAYS)

IMMEDIATE RESPONSE

x safeguard personnel, render first-aid 

x make initial notifications 

x implement short term intervention (if possible) 

x implement spill control 

x develop Initial Action Plan 

 

 1 

INTERIM REPSONSE 

x establish Onsite Command Center and Emergency Management Team 

x assess well control issues 

x mobilize people and equipment (Helix DW Containment System) 

x implement short term intervention and containment (if possible) 

x develop Intervention Plan 

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

x continue spill control measures 

 

 4 

INTERVENTION AND CONTAIMENT OPERATIONS 

x mobilize equipment and initiate intervention and containment operations

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

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

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

x continue spill control measures 

 14 

RELIEF WELL(S) OPERATIONS 

x continue intervention and containment measures

x continue spill control measures 60 
BLOWOUT SCENARIO 

 MC 705 

OCS-G-31521 

Created by: S.L. Stegeman 

Last Revised: 8/9/2011 

Page 6 of 6 

Confidential

 6 

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

PERFORM HYDRAULIC KILL OPERATIONS / SECURE BLOWNOUT WELL 

x continue intervention and containment measures

x continue spill control measures

x perform hydraulic kill operations, monitor well, secure well

 

 20 

 ESTIMATED TOTAL DAYS OF UNCONTROLLED FLOW 99

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

TOTAL DAYS 129 

.



















APPENDIX F 

WASTE AND DISCHARGE INFORMATION

(30 CFR PART 250.217 AND 250.248) 

A. Projected Generated Wastes

See the following tables:

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

discharge to the GOM 

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

B. Modeling

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

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

MC Block 705

Type of Waste Composition Projected Amount 

T

o Discharge rate

Discharge

Method Answer yes or no

Will drilling occur ? If yes, you should list muds and cuttings

EXAMPLE: Cuttings wetted with 

synthetic based fluid 

Cuttings generated 

while using synthetic 

based drilling fluid. X bbl/well X bbl/day/well

discharge

overboard No

Water-based drilling fluid

Water based mud 

additives, barite and 

gel used for WBM 18,263 bbls/well 7,309 bbls/day/well

Discharge

overboard No

Cuttings wetted with water-based fluid

Cuttings generated 

while using water 

based drilling fluid. 1,003 bbls/well 401 bbls/day/well

Discharge

overboard No

Cuttings wetted with synthetic-based 

fluid

Cuttings generated 

while using synthetic 

based drilling fluid. 1,732 bbls/well 50 bbls/day/well

Discharge

overboard No

Will humans be there? If yes, expect conventional waste

EXAMPLE: Sanitary waste water

Sanitary waste from 

living quarters X bbl/well X bbl/hr/well

discharge

overboard No

Domestic waste

Kitchen water and 

unprocessed water not 

used for sanitation 3,846 bbls/well 2.7 bbls/hr/well

Discharge

overboard (no 

free oil) No

Sanitary waste

Processed sanitary 

waste from living 

quarters 2,564 bbls/well 1.8 bbls/hr/well

Chlorinate and 

discharge

overboard No

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

Deck Drainage

Accumulated drainage 

due to rainfall

0 to 47,261 

bbls/well 0 to 167 bbls/hr/well

Test for oil and 

grease and 

discharge

overboard No

Will you conduct well treatment, completion, or workover? 

Well treatment fluids

NPDES approved 

treatment fluid used for 

well operations 100 bbls/well 20 bbls/hr/well

Test for oil and 

grease and 

discharge

overboard. No

Well completion fluids

Clear brines used for 

completion operations 500 bbls/well 100 bbls/hr/well

Test for oil and 

grease and 

discharge

overboard. This 

excludes clear 

brines containing 

Zinc No

Workover fluids N/A N/A NA NA No

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

Desalinization unit discharge N/A N/A N/A N/A No

Blowout prevent fluid N/A N/A N/A N/A No

Ballast water

Uncontaminated

seawater used for 

ballast control

0 to 100,000 

bbls/well 16,350 bbls/hr/well

Discharge

overboard No

Bilge water N/A N/A N/A N/A No

Excess cement at seafloor

Excess cement slurry 

and mixwater used for 

cementing operation - 

NPDES allowed 300 bbls/well 360 bbls/hr/well

Discharge at 

mudline No

Fire water

Uncontaminated

seawater used for fire 

control system

0 to 10,000 

bbls/well 16,350 bbls/hr/well

Discharge

overboard No

Cooling water N/A N/A N/A N/A No

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

Produced water NA NA NA NA No

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

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

General NPDES Permit #GMG290000

Projected

Downhole

Projected generated waste Projected ocean discharges Disposal

TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE IN THE GOM 
please specify whether the amount reported is a total or per well

MC Block 705

Projected generated 

waste

Solid and Liquid 

Wastes transportation 

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

DisposalMethod

Will drilling occur ? If yes, fill in the muds and cuttings.

EXAMPLE: Synthetic-based drilling fluid or mud internal olefin, ester

Below deck storage tanks on offshore support vessels

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

Oil-based drilling fluid or mud N/A NA N/A NA NA

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

Barged in 25 bbls cutting boxes and

/ or liquid mud tanks for supply vessels

Newpark Transfer Station, Fourchon, LA

6750 bbls / well Recycled

Cuttings wetted with Water-based fluid N/A NA N/A NA NA

Cuttings wetted with Synthetic-based fluid N/A NA N/A NA NACuttings wetted with oil-based fluids N/A NA N/A NA NA

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

Produced sand N/A N/A N/A N/A N/A

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

Blanchard Landfill, GoldenMeadows, LA 4000 lbs / well

Recycled and land fill

Used oil Spent oil from machinery

Barged in USCG approved transfer

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

Wash water

Wash water w/ SBM residue and surfactants

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

Newpark Transfer Station, Fourchon, LA

2000 bbls / well

Approved

disposal well injection or land farm

Chemical product wastes

Spent treatment and / or

damaged chemicals used in operations

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

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

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

Waste Disposal

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


EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2011

COMPANY LLOG Exploration Offshore, L.L.C.

AREA Mississippi Canyon

BLOCK 705

LEASE OCS-G 31521PLATFORMWELL A

COMPANY CONTACT Kathy GowlandTELEPHONE NO. 985-801-4300REMARKS Drill and Complete

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 1 of 8

EMISSIONS FACTORS

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. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 14-2, & 14 7/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03 E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005 API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991Gas 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

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 2 of 8
EMISSIONS CALCULATIONS 1ST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offsho Mississippi Canyon 705 OCS-G 31521 A 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 26400 1275.12 30602.88 24 60 18.61 85.36 639.65 19.19 139.56 13.40 61.46 460.55 13.82 100.48

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 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2100 101.43 2434.32 8 9 1.48 6.79 50.88 1.53 11.10 0.05 0.24 1.83 0.05 0.40VESSELS>600hp diesel(supply) 2100 101.43 2434.32 10 26 1.48 6.79 50.88 1.53 11.10 0.19 0.88 6.61 0.20 1.44VESSELS>600hp diesel(tugs) 4200 202.86 4868.64 12 4 2.96 13.58 101.76 3.05 22.20 0.07 0.33 2.44 0.07 0.53

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 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

DRILLING OIL BURN 250 24 2 4.38 71.15 20.83 0.10 2.19 0.11 1.71 0.50 0.00 0.05WELL TEST GAS FLARE 208333.33 24 2 0.12 14.87 12.56 80.94 0.00 0.36 0.30 1.94

2011 YEAR TOTAL 28.90 183.79 878.88 37.96 267.09 13.82 64.63 472.29 14.45 104.85

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 1764.90 1764.90 1764.90 1764.90 47972.92

53.0

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 3 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELLLLOG ExploratioMississippi Canyon 705 OCS-G 31521 A 

Emitted Substance

Year

 PM SOx NOx VOC CO

2011 13.82 64.63 472.29 14.45 104.85

Allowable 1764.90 1764.90 1764.90 1764.90 47972.92

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 8 of 8
 APPENDIX H 

OIL SPILL INFORMATION

(30 CFR PART 250.219 AND 250.250)

A. Oil Spill Response Planning

All the proposed activities in this Revised Exploration Plan will be covered by the 

Oil Spill Response Plan filed by LLOG (MMS Operator No. 02058) in 

accordance with 30 CFR 254 and approved on June 3, 2009, last modification 

May 31, 2011 (not currently approved). LLOG submitted the Biennial Oil Spill 

Response Plan on 06/30/2010 (currently pending approval). OSRP Certification 

submitted by letter dated June 1, 2011 for modification dated May 31, 2011. The 

WCD proposed in this Plan does not exceed the WCD submitted in the 

modification dated 05/31/2011. The last OSRP Certification was accepted by 

BOEMRE on 03/25/2011. 

B. Spill Response Sites

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

the proposed activities. 

Primary Response Equipment 

Location

Pre-Planned Staging Location(s) 

Houma, LA Fort Jackson, LA 

C. OSRO Information

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

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

deploying cleanup personnel and equipment 

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

equipment, which is an industry cooperative owning an inventory of oil spill 

clean-up equipment. CGA is supported by the Marine Spill Response 

Corporation’s (MSRC), which is responsible for storing, inspecting, maintaining 

and dispatching CGA’s equipment. The MSRC STARS network provides for the 

closest available personnel, as well as an MSRC supervisor to operate the 

equipment. 
D. Worst-Case Scenario Information

Category Regional OSRP Revised EP 

Type of Activity Exploratory MODU Exploratory MODU 

Facility Surface Location Mississippi Canyon Block 547 Mississippi Canyon Blocks 705 

Facility Description Well Location Well No. SS002 

(Location B) 

Location A 

Distance to Nearest Shoreline 

(Miles) 38.4 miles 53 miles 

Volume: 

 Storage Tanks (total) 

 Facility Piping (total) 

 Lease Term Pipeline 

 Uncontrolled Blowout (day) 

 Barging 

Potential 24 Hour Volume 

(bbls)

Total Volume 

225,144 bbls 

22,289,256 

 

123,200 bbls 

21,196800 

Type of Liquid Hydrocarbon Crude Oil Condensate 

API Gravity 28o 43o 

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

to the appropriate worst-case spill scenario included in its regional OSRP 

approved on June 3, 2009, last modified May 31, 2011 (not currently approved), 

and since the worst-case scenario determined for this EP does not replace the 

worst-case scenario in our modified Regional OSRP (May 31, 2011), I hereby 

certify that LLOG has the capability to respond, to the maximum extent 

practicable, to a worst-case discharge, or a substantial threat of such a discharge, 

resulting from the activities proposed in this EP.

LLOG submitted the Biennial Oil Spill Response Plan on 06/30/2010 (currently 

pending approval). OSRP Certification submitted by letter dated June 1, 2011 for 

modification dated May 31, 2011. The WCD proposed in this Plan does not 

exceed the WCD submitted in the modification dated 05/31/2011. The last OSRP 

Certification was accepted by BOEMRE on 03/25/2011. 

LLOG Exploration Offshore, L.L.C., Company No. 02058, previously submitted 

the Regional OSRP Exploration WCD volume to be reviewed in Plan R-5139, 

Revised Exploration Plan submitted on March 2, 2011. 

The required proprietary data outlined in NTL 2010-N06 was submitted to 

BOEMRE. LLOG accepts the BOEMRE’s worst case discharge value of 123,200 

bbls potential 24 hour volume with a 43o API Gravity. 

E. Oil Spill Response Discussion

See the following Oil Spill Response Discussion. 
SPILL RESPONSE DISCUSSION 

For the purpose of NEPA and Coastal Zone Management Act analysis, the largest spill volume 

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

estimated to be 123,200 barrels of condensate with an API gravity of 43.9°. 

Land Segment and Resource Identification

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

utilizing information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and 

Western Gulf of Mexico available on the BOEM website. The results are shown in Figure 1. The 

BOEM OSRAM identifies a 4% probability of impact to the shorelines of Plaquemines Parish, 

LA within 10 days. Plaquemines Parish includes Barataria Bay, the Mississippi River Delta, 

Breton Sound and the affiliated islands and bays. This region is an extremely sensitive habitat, 

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

wildlife. Beaches in this area vary in grain particle size, and can be classified as fine sand, shell 

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

Response

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

Discharge as effectively as practicable. A description of the response equipment available to 

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

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

model was run on a similar product from the ADIOS oil database. The results indicate 27% or 

approximately 33,264 barrels of condensate would be evaporated/dispersed within 24 hours, with 

approximately 89,936 barrels remaining. 

Spill Response MC 705 Barrels of Oil 

WCD Volume 123,200 

Less 27% natural evaporation/dispersion 33,264 

Remaining volume 89,936 

Oil addressed by in-situ burning 4,496 

Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary 

storage equipment available to respond to a spill of 123,200 barrels. The list estimates individual 

times needed for procurement, load out, travel time to the site and deployment. Figure 2 also 

indicates how operations will be supported. 

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

technologies such as in-situ burn. Strategies will be decided by Unified Command based on size 
of the spill, weather and potential impacts. If the conditions are favorable for in-situ burning, the 

proper approvals have been obtained and the proper planning is in place, in-situ burning of oil 

may be attempted. Using estimates based on the Deepwater Horizon spill of 2010, up to 5% or 

approximately 4,496 barrels of the total daily Worst Case Discharge volume could be burned. 

Slick containment boom along with sorbent boom would be immediately called out and on-scene 

as soon as possible. Offshore response strategies may include collection of condensate with 

sorbent boom (inside hard boom), attempting to skim utilizing the HOSS Barge, nine Fast 

Response Units, two Aqua Guard Triton RBS skimmers, and eleven sets of Koseq skimming 

arms, with a total derated skimming capacity of 318,609 barrels. Temporary storage associated 

with skimming equipment equals 31,700 barrels. If additional storage is needed, an 80,000 barrel 

storage barge, an 83,937 barrel storage barge, an 86,948 barrel storage barge, and a 107,285 

barrel storage barge may be mobilized and centrally located to provide temporary storage 

allowing the skimmers to stay in the area of operations as much as possible. Safety is first 

priority. Air monitoring will be accomplished and operations deemed safe prior to any 

containment/skimming attempts. 

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

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

near shore and shallow water skimmers with a totaled derated skimming capacity of 54,753 

barrels. Temporary storage associated with skimming equipment equals 1,861 barrels. If 

additional storage is needed, an 86,948 barrel storage barge may be mobilized and centrally 

located to provide temporary storage allowing the skimmers to stay in the area of operations as 

much as possible. Onshore response may include the deployment of shoreline boom on beach 

areas, or protection and sorbent boom on vegetated areas. MSAs with AMPOL and Oil Mop will 

ensure the availability of 147,000 feet of 18” shoreline boom. Figure 2 (below) outlines 

individual times needed for procurement, load out, travel time to the site and deployment. 

Strategies would be based upon surveillance and real time trajectories that depict areas of 

potential impact given actual sea and weather conditions. The State of Louisiana Initial Oil Spill 

Response Plan for Plaquemines Parish and Unified Command would be consulted to ensure that 

environmental and special economic resources would be correctly identified and prioritized to 

ensure optimal protection. Shoreline protection strategies depict the protection response modes 

applicable for oil spill clean-up operations. The State of Louisiana Initial Oil Spill Response Plan 

provides detailed shoreline protection strategies for this area, and it describes necessary action to 

keep the oil spill from entering Louisiana’s coastal wetlands, based on the assumption that 

removal of the released oil will be much easier and less damaging to fragile coastal ecosystems if 

done in the open waters of the Gulf of Mexico. Supervisory personnel have the option to modify 

the deployment and operation of equipment allowing a more effective response to site-specific 

circumstances. LLOG Exploration Offshore, L.L.C.’s contract Spill Management Team holds a 

copy of the State of Louisiana Initial Oil Spill Response Plan. 
Initial Response Considerations 

Actual actions taken during an oil spill response will be based on many factors to include but not 

be limited to: 

x Weather

x Equipment and materials availability 

x Ocean currents and tides 

x Location of the spill 

x Product spilled

x Amount spilled 

x Environmental risk assessments 

x Trajectory and product analysis 

x Well status, i.e., shut in or continual release 

LLOG Exploration Offshore, L.L.C. will take action to provide a safe, aggressive response to 

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

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

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

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

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

x Information will be confirmed 

x An assessment will be made and initial objectives set 

x OSROs and appropriate agencies will be notified

x ICS 201, Initial Report Form completed 

x Initial Safety plan will be written and published 

x Unified Command will be established 

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

objectives

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

site

o On-site command and control established 

Offshore Response Actions 

Equipment Deployment

Surveillance

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

x Provide trained observer to provide on site status reports 

x Provide command and control platform at the site if needed 

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

and visual confirmation 

x Continual monitoring of vessel assets using vessel monitoring systems 
Containment boom & sorbent boom

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

x Ensure boom handling and mooring equipment is deployed with boom 

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

their most effective containment 

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

Dedicated off-shore skimming systems 

General

x Deployed to the highest concentration of oil 

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

CGA HOSS Barge 

x Use in areas with heaviest oil concentrations 

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

CGA FRUs 

x To the area of the thickest oil 

x Use as far off-shore as allowed 

T&T Koseq Skimming Systems 

x To the area of the thickest oil 

x Use as far off-shore as allowed 

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

Storage Vessels 

x Establish availability of CGA contracted assets 

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

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

systems 

x Position as closely as possible to skimming assets to minimize offloading time 

Vessels of Opportunity (VOO) 

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

x Industry vessels are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS) 

x Acquire additional resources as needed 

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

x Expect mission specific and safety training to be required 

x Plan with the US Coast Guard for vessel inspections 
In-situ Burn assets 

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

affected SOSC 

x Determine availability of fire boom and selected ignition systems 

x Start ordering fire boom stocks required for expected operations 

x Contact boom manufacturer to provide training if required 

x Determine assets to perform on water operation 

x Build operations into safety plan 

x Conduct operations in accordance with an approved plan 
Near Shore Response Actions 

Timing

x Put near shore assets on standby and deployment in accordance with planning based on 

the actual situation, actual trajectories and oil budgets 

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

x Outfitting of VOOs for specific missions 

x Deployment of assets based on actual movement of oil 

Considerations

x Water depth, vessel draft 

x Shoreline gradient 

x State of the oil

x Use of VOOs 

x Distance of surf zone from shoreline

Equipment Deployment 

Surveillance

x Provide trained observer to direct skimming operations 

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

and visual confirmation 

x Continual monitoring of vessel assets 

Vessel Deployment 

Dedicated Near Shore skimming systems 

x FRVs

x Egmopol and Marco SWS 

x Operate with aerial spotter directing systems to observed oil slicks 

VOO

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

x Industry vessel are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS) 

x Acquire additional resources as needed 

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

x Expect mission specific and safety training to be required 

x Plan with the US Coast Guard for vessel inspections 

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

Response Planning Considerations 

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

x Time to acquire personnel and equipment and their availability 

x Previous contingency planning contained in the appropriate Area Contingency 

Plan, and currently (Feb 2011) for Louisiana, The State of Louisiana Initial Oil Spill 

Response Plan, Deep Water Horizon, dated 2 May 2010 (La. OSRP)

Actions

Placement of boom 

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

appropriate ACP

x Assess timing of booming operations to ensure it is where it needs to be at time of 

impact. Consider: 

o Trajectories 

o Weather forecast 

o Oil Impact forecast 

o Verified spill movement 

o Boom, manpower and vessel (shallow draft) availability 

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

Beach Preparation 

Considerations and Actions 

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

x Shoreline Cleanup and Assessment Team Reports and recommendations 

x Determination of Archeological sites and gaining authority to enter

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

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

x Staging of equipment and housing of response personnel as close to the job site as 

possible to maximize on-site work time 

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

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

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

x Passive clean up of marshes should considered and appropriate stocks of sorbent boom 

and/or sweep obtained 

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

inland areas 
Decanting Strategy 

Recovered oil and water mixtures will typically 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 

FRU 8 foot seas 

HOSS Barge/OSRB 8 foot seas 

Koseq Arms 8 foot seas 

OSRV 4 foot seas 
Environmental Conditions in the GOM

Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences 

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

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

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

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

flooding is prominent. 

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

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

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

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

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

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

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

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

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

month.
FIGURE 1 

TRAJECTORY BY LAND SEGMENT 

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

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

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

available on the BOEM website using 10 day impact. The results are tabulated below. 

Area/Block OCS-G Launch

Area

Land Segment and/or 

Resource

Conditional

Probability (%) 

within 10 days 

Exploratory Drilling 

MC 705 #1 

53 miles from shore 

G31521 C58 Terrebonne Parish, LA 

Lafourche Parish, LA 

Plaquemines Parish, LA 

1

2

4
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (53 miles from shore) 

123,200 bbls of condensate API Gravity 43.9° 

FIGURE 2 – Equipment Response Time to MC 705#1 

Surveillance

Surveillance Dispersant Capacity (gal) Storage Capacity Persons Req. From Hrs to Procure Hrs to Loadout Travel to site Total Hrs 

ASI

Aero Commander NA NA 2 Houma 1 1 0.8 2.8 

Offshore Response 

Offshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM Travel to Spill Site Hrs to Deploy Total Hrs

CGA

HOSS Barge 43000 4000 3 Tugs 8 Harvey 4 0 5 7.5 1 17.5 

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 4 12 1 5 2 24 Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 4 12 1 5 2 24 Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 4 12 1 5 2 24 Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 4 12 1 24.2 2 43.2 

Recovered Oil Storage No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM Travel to Spill Site Hrs to Deploy Total Hrs

K-Sea Operating (available through contract with CGA) 

PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 4 7.5 1 28.5 DBL 76 1212984 NA 83937 1 Tug 6 Venice 4 12 4 7.5 1 28.5 DBL 81 1132231 NA 86948 1 Tug 6 Venice 4 12 4 7.5 1 28.5 DBL 101 1119760 NA 107285 1 Tug 6 Venice 4 12 4 7.5 1 28.5 
Staging Area: Venice 

Offshore Equipment With 

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

CGA

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2 5 1 11 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 8 5 1 17 FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 3 5 1 12 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 11 5 1 20 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 5.5 5 1 14.5 FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6 Venice 1 2 0 5 1 9 Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 8 5 2 17 

Offshore Equipment With 

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

CGA

42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 5 1 11 42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 5 1 17 42” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 2 3 5 1 12 42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 5 1 20 42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 5 1 14.5 42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 5 1 13 1000’ Hydro-Fire Boom (In-Situ Burn) NA NA 8 Utility 40 Harvey 1 4 2 5 6 18 
Nearshore Response 

Nearshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM Travel to Spill Site Hrs to Deploy Total Hrs

K-Sea Operating (available through contract with CGA) 

DBL 82 1137538 NA 86948 1 Tug 6 Venice 4 12 4 6.25 1 27.25 

CGA

46’ FRV 5000 65 NA 4 Galveston 1 0 0 12.4 0 13.4 46’ FRV 5000 65 NA 4 Houma 1 0 2 2.8 0 5.8 46’ FRV 5000 65 NA 4 Lake Charles 1 0 1 9.2 0 11.2 46’ FRV 5000 65 NA 4 Venice 1 0 1 2 0 4 Trinity SWS 21500 249 NA 4 Morgan City 1 2 2 4.8 1 10.8 

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 Travel to Deployment Hrs to Deploy Total Hrs

CGA

SWS Egmopol 3000 100 NA 3 Galveston 1 2 8 2 0 13 SWS Egmopol 3000 100 NA 3 Houma 1 2 3 2 0 8 SWS Marco 3588 34 NA 3 Houma 1 2 3 2 0 8 SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 2 0 10.5 Rope Mop 77 2 0 3 Belle Chasse 1 2 2 2 0 7 RO Storage Barge NA 249 Towed 0 Galveston 1 2 8 2 0 13 RO Storage Barge NA 249 Towed 0 Houma 1 2 3 2 0 8 RO Storage Barge NA 249 Towed 0 Lake Charles 1 2 5.5 2 0 10.5 RO Storage Barge NA 249 Towed 0 Venice 1 2 0 2 0 5 
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 Hrs to Deploy Total Hrs 

AMPOL (available through MSA) 

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 4 2 12 22 20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2 2 6 14 

Oil Mop (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 3 11 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 7.5 2 3 14.5 

10,000 18” Boom 4 Crew 10 Port Arthur, TX 1 1 6.25 2 3 13.25 20,000 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.75 2 6 11.75 10,000 18” Boom 4 Crew 10 Port Allen, LA 1 1 3.5 2 3 10.5 10,000 18” Boom 4 Crew 10 Houma, LA 1 1 3.5 2 3 10.5 15,000 18” Boom 6 Crew 14 Gretna, LA 2 2 2 2 4 12 

Beach Boom EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total Hrs

CGA

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 8 1 2 14 Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 11 1 2 17 Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 1 2 10 
Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total Hrs

CGA

Wildlife Support Trailer NA NA NA 2 Houma 1 2 3 1 2 9 Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 2 1 2 8 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 1 2 14 Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 1 2 9 Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 11 1 2 17 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 1 2 11.5 Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 1 2 10 

Response Asset Total 

Offshore EDRC 318,609 Offshore Recovered Oil Storage 389,870 Nearshore / Shallow Water EDRC 54,753 Nearshore / Shallow Water Recovered Oil Storage 88,709 





APPENDIX M 

SUPPORT VESSELS AND AIRCRAFT INFORMATION

(30 CFR PART 250.224 AND 250.257) 

A. General

Personnel involved in the proposed operations will typically use their own 

vehicles as transportation to and from the selected onshore base; whereas the 

selected vendors will transport the equipment by a combination of trucks, boats 

and/or helicopters to the onshore base. The personnel and equipment will then be 

transported to the drilling rig via the transportation methods and frequencies 

shown, taking the most direct route feasible as mandated by weather and traffic 

conditions:

Type Maximum Fuel 

Tank Storage 

Capacity

Maximum No. in 

Area at Any Time 

Trip Frequency or 

Duration

Tug Boats 3000 bbls 1 Every two weeks 

Supply Boats 500 bbls 1 Three times weekly 

Service Boats 500 bbls 1 Daily 

Crew Boats 500 bbls 1 Weekly 

Aircraft 1900 lbs 1 As Needed 

B. Diesel Oil Supply Vessels

Size of Fuel Supply 

Vessel

Capacity of fuel 

Supply Vessel 

Frequency of Fuel 

Transfers

Route Fuel Supply 

Vessel Will Take 

180’ 1,500 bbls Weekly From shorebase in 

Fourchon, LA to MC 

705 

A. Drilling Fluids Transportation

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

Appendix F of this Plan. 

B. Solid and Liquid Wastes Transportation

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

Appendix F of this Plan. 

C. Vicinity Map

A Vicinity Plat showing the location of Mississippi Canyon Block 705 relative to 

the nearest shoreline and onshore base is included as Attachment M.


APPENDIX N

ONSHORE SUPPORT FACILITIES INFORMATION

(30 CFR PART 250.225 AND 250.258) 

 A. General

The proposed surface disturbances in Mississippi Canyon Block 705 will be 

located approximately 53 miles from the nearest Louisiana shoreline, and 

approximately 62 miles from the following onshore support base: 

Name Location Existing/New/Modified

Martin North Fourchon, LA Existing 

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

operations: 

Ɣ Loading/Offloading point for equipment supporting the offshore 

operations. 

Ɣ Dispatching personnel and equipment, and does not anticipate the need for 

any expansion of the selected facilities as a result of the activities 

proposed in this Revised Plan. 

Ɣ Temporary storage for materials and equipment. 

Ɣ 24 Hour Dispatcher 

B. Support Base Construction or Expansion

The proposed operations are temporary in nature and do not require any 

immediate action to acquire additional land or expand existing base facilities. 

C. Support Base Construction or Expansion Timetable

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

D. Waste Disposal

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

Appendix F of this Plan.