UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of DOCD

Control # - S-07708

Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS-G25098 Block - 546 Mississippi Canyon Area

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

Drill Well G-3

DP Semisubmersible, 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.

Tonya Jez

Plan Coordinator

WELL/G-3 G25098/MC/546 6277 FNL, 7378 FWL G25098/MC/546

Site Type/Name Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk

Description -

Rig Type -

Subject:

From:

December 4, 2014
LLOG Exploration Offshore, L.L.C.

1001 Ochsner Blvd. Suite 200

Covington, Louisiana 70433

38%/,&,1)250$7,21

SUPPLEMENTAL 

DEVELOPMENT OPERATIONS COORDINATION 

DOCUMENT

LEASE OCS-G-25098

MISSISSIPPI CANYON BLOCK 546

PREPARED BY:

Nelda Runyon

Regulatory Specialist

LLOG Exploration Offshore, L.L.C. 

(985) 801-4300 Main 

 (985) 801-4389 Direct 

neldar@llog.com

Dated: September 1, 2014 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

LLOG EXPLORATION OFFSHORE, L.L.C.

SUPPLEMENTAL DEVELOPMENT OPERATIONS COORDINATION 

DOCUMENT

OCS-G-25098 LEASE

MISSISSIPPI CANYON BLOCK 546 

APPENDIX A Plan Contents 

APPENDIX B General Information 

APPENDIX C Geological, Geophysical Information 

 

APPENDIX D H2S Information 

APPENDIX E Mineral Resource Conservation Information 

APPENDIX F Biological, Physical and Socioeconomic Information 

APPENDIX G Waste and Discharge Information 

APPENDIX H Air Emissions Information

APPENDIX I Oil Spill Information. 

. 

APPENDIX J Environmental Monitoring Information 

APPENDIX K Lease Stipulation Information 

APPENDIX L Environmental Mitigation Measures Information 

APPENDIX M Related Facilities and Operations Information 

APPENDIX N Support Vessels and Aircraft Information 

APPENDIX O Onshore Support Facilities Information 

APPENDIX P Environmental Impact Analysis 

APPENDIX Q Administrative Information
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX A

PLAN CONTENTS

(30 CFR PART 550.211 AND 550.241)

A. Plan Contents

OCS-G-25098 Lease, Mississippi Canyon Block 546 was acquired by Nexen 

Petroleum Offshore U.S.A. Inc. in lease sale 185 effective July 1, 2003.

Effective August 6, 2007, Nexen Petroleum Offshore U.S.A. Inc. designated 

Eni US Operating Co. Inc., as Operator of all of Block 546, Mississippi 

Canyon from 0’ to 13,000’TVD. 

Eni US Operating Co. Inc. Unit Contract No. 754310006 was approved 

effective 07/09/2010. The unit consists of OCS-G-24084 Lease, Mississippi 

Canyon 502 and OCS-G-25098 Lease, Mississippi Canyon Block 546. 

Effective May 15, 2012, Nexen Petroleum Offshore U.S.A. Inc. (02079) 

designated LLOG Offshore Exploration L.L.C. the Operator of the E 1/2 of 

Block 546, OCS-G-25098 Lease, Mississippi Canyon Block from 13,000’SS 

TVD down 18,500’ SS TVD. 

LLOG filed a Supplemental Development Operations Coordination Document 

(S-7563) which was approved May 25, 2012 to drill, complete and produce 

the OCS-G-25098 Lease, Mississippi Canyon Block 546 Well No. 3. The 

Mississippi Canyon Block 546 Well No.003 (surface location in MC 503) was 

spud on June 1, 2012 and placed on production August 5, 2013. 

LLOG filed a Supplemental Development Operations Coordination Document 

(S-7659) which was approved on July 3, 2014 to drill, complete and produce 

the OCS-G-25098 Lease, Mississippi Canyon Block 546 Well Nos. 004 (G-1) 

and 005 (G-2). 

Effective September 11, 2014, Nexen Petroleum Offshore U.S.A. Inc. 

(02079) designated LLOG Offshore Exploration L.L.C the Operator of all of 

Block 546, Mississippi Canyon, OCS-G-25098 Lease, from 13,000’ SS TVD 

down to 99,999’ SSTVD. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

This Supplemental Development Operations Coordination Document is 

requested to cover the drilling, completion, installation of jumper/umbilical to 

produce the OCS-G-25098 Lease, Mississippi Canyon Block 546 Well No. 

006 (G-3).

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

which provides for the drilling, completion installation of jumper/umbilcal to 

produce the MC 546 subsea well No. 006 (G-3) and then connect to the “A” 

Platform in Mississippi Canyon Block 547, OCS-G-27277 Lease via two (2) 

6.625” lease term pipelines and to commence production of Mississippi Canyon 

Block 546 Well No. 006 (G3). 

B. Location

Included are the following attachments:

 Attachment A-1: Form MMS 137 – OCS Plan Information Form

 Attachment A-2: Well Location Plats 

 Attachment A-3: Bathymetry Map - (Proposed surface disturbance 

 area with the anchor radius) 

 Attachment A-4: Pay.gov Receipt $4,238.00 

 

 

C. Safety and Pollution Prevention Features

LLOG will utilize a semi-submersible drilling rig or a DP semisubmersible rig for the

proposed operations. A description of the drilling units are included on t he OCS Plans 

Information Form. R ig specifications will be made part of the Application for 

Permit to Drill.

Safety of personnel and protection of the environment during the proposed 

operations is of primary concern with LLOG, and mandates regulatory 

compliance with the contractors and vendors associated with the proposed 

operations as follows: 

Bureau of Safety and Environmental Enforcement mandates that the operations in 

this Plan comply with well control, pollution prevention, construction and 

welding procedures as described in Title 30 CFR Part 550, Subparts C, D, E, G 

and O; and as further clarified by Notices to Lessees.
Bureau of Safety and Environmental Enforcement conducts periodic announced and 

unannounced onsite inspections of offshore facilities to confirm operators are complying 

with lease stipulations, operating regulations, approved plans, and other conditions; as 

well as to assure safety and pollution prevention requirements are being met. 

The National Potential Incident of Noncompliance (PINC) List serves as the baseline for 

these inspections supplemental with a civil penalties program.

U.S. Coast Guard regulations contained in Title 33 CFR mandate the appropriate life 

rafts, life jackets, ring buoys, etc. be maintained on the facility at all times.

 

U.S. Environmental Protection Agency regulations contained in the 

NPDES General Permit GMG290000 mandate that supervisory and certain designated 

personnel on-board the facility be familiar with the effluent limitations and guidelines for 

overboard discharge into the receiving waters. 

D. Storage Tanks and Production Vessels

Semisubmersible

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 

11,861.7

DP Semisubmersible

Type of Storage 

Tank

Type of Facility Tank Capacity Number of 

Tanks 

Total 

Capacity 

(bbls)

Fluid Gravity

(API)

Fuel Oil 

Marine Diesel

DP 

Semisubmersible

164 1 164 30 

Fuel Oil Day 367 2 734 30 

Emergency 

Generator

 31 1 31 30 

Forward Hull Fuel 

Oil

4634 2 9268 30

Lower Aft Hull Fuel 

Oil

3462 2 6924 30 

Lube Oil Services 117/10.5/4.6 3 132 45

Dirty Lube Oil 38/28 2 66 45 

Dirty Bilge 190 4 760 10

 
E. Pollution Prevention Measures

Not applicable. The State of Florida is not an affected State by the proposed activities in 

this plan. 

F. Additional Measures

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

measures, beyond those required in 30 CFR 550. 

G. Cost Recovery Payment

Included as Attachment A-4 is the Pay.gov receipt in the amount of $4,238.00 for cost 

recovery fee associated with this plan.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

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) Jumper Installation

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
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

LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

WELL LOCATION PLAT

Attachment A-2 

(Proprietary Information)
LLOG EXPLORATION OFFSHORE, INC.

OCS-G 25098

MC 546 

SURFACE LOCATION 

X: 973,618.72 Y: 10,321,402.52

G3: Public

Lat: 28 deg, 25 min, 33.499 sec

Long: 89 deg, 04 min, 30.025 sec

6,277.48’ FNL 7,378.72’ FWL

(NAD27) Mississippi Canyon Block 546 

Gulf of Mexico

Location Map 

 7/14 

0’ 1000’ 2000’ Geo: John D

Surface

Loc G3 

Y= 10,327,680

Y= 10,311,840

X= 966,240

X= 982,080

7,378.72’ 

6,277.48’ 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

BATHYMETRY MAP

Attachment A-3 

(Public Information) 


LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

COST RECOVERY PAYMENT

Attachment A-4 

(Public Information)

LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX B

GENERAL INFORMATION

(30 CFR PART 550.213 AND 550.243) 

A. Application and Permits

No additional Federal/State applications will be submitted for the activities 

provided for in this Plan exclusive of the BOEM/BSEE permit applications and 

general permits issued by the EPA and COE . 

B. Drilling Fluids

 Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

used per well

Water Based (seawater, freshwater, barite) See Table 1 of Appendix G

Oil-based (diesel, mineral oil) N/A

Synthetic-based (internal, olefin, ester) See Table 1 of Appendix G

 

C. Production

LLOG estimates the life of reserves for the proposed development activity to be 

as follows: 

 

Well Sand

Average Production 

Rate 

MCFD/BOPD

Peak Production Rate 

MCFD/BOPD

Life of 

Reservoir 

(Yrs)

MC 546 SS006 (G-3)
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

D. Oil Characteristics

The following table details the chemical and physical characteristics of the oils

that will be potentially produced, handled, transported, or stored on/by the facility

from which the proposed development and production activities will be 

conducted: 

Characteristics Results Analytical Methodologies 

Should be Compatible With:

 

 

 







E. New or Unusual Technology

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

operations proposed in this plan. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

F. Bonding Statement

The bond requirements for the activities and facilities proposed in this 

Supplemental DOCD 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 556.43(d) 

and National NTL No. 2008-N07 “Supplemental Bonding Procedures.” 

G. Oil Spill Financial Responsibility (OSFR)

LLOG Exploration Offshore, Inc. (BOEMRE Company No. 02058) has 

demonstrated oil spill financial responsibility for the facilities proposed in this 

Supplemental DOCD according to 30 CFR Part 253, and NTL 2008-N05, 

“Guidelines for Oil Spill Financial Responsibility for Covered Facilities.”

H. Deepwater Well Control Statement

LLOG Exploration Offshore L.L.C. (BOEMRE Company No. 02058) has the 

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

operations. 

I. Suspensions of Production

LLOG Exploration Offshore, L.L.C. has not filed and does not anticipate filing 

any requests for Suspension of Production to hold the lease(s) or unit addressed in 

this Supplemental Development Operations Coordination Document. 

J. Blowout Scenario

See the following NTL 2010 N06 Data consisting of a Blowout Scenario 

including Site Specific Proposed Relief Well and Intervention Planning and Relief 

Well Response Time Estimate. See Attachment B-1

 
LLOG Exploraiton Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

ATTACHMENT B-1 

BLOWOUT SCENARIO AND RELIEF WELL INFORMATION
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 b lowout 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 546 Well No. 6 (G-3) 2565’ 973,618.79 10,321,402.52’ 89° 25’ 33.499 89° 04’ 30.025”

INFORMATION REQUIREMENTS

A) Blowout scenario

The MC 546 Well Nos. 6 to be drilled to potential outlined in the Geological and Geophysical 

Information Section of this plan utilizing a t ypical subsea wellhead system, conductor, surface and 

intermediate casing strings 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. T he 

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

Supplemental DOCD

Type of Activity Drilling / Completion Ops

Facility Location (area / block) MC 546

Facility Designation MODU

Distance to Nearest Shoreline (miles) ~41

Uncontrolled Blowout (Volume per day) 109,127 bbls 

Type of Fluid 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) 10,803,573 bbls 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 b lowout 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 probable that the borehole may fall/collapse/bridge over within a 

span of a f ew days, significantly reducing the outflow of the rates. F or this blowout scenario, no 

bridging is considered. 
2 

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:

• 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 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. This system is slated 

to be installed on the Amos Runner in the near future.

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. 

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) and 

one DP MODU (Sevan Louisiana). 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. I f 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. T he 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. 
3 

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 r elief 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. T he 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 8502 (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 

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 

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. D aily 

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 eq uipment are integrated to 

incorporate LLOG’s, the contractor and service provider policies. 
4 

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 hol e 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 l oss circulation 

events. 

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

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

and geology being drilled. R emote monitoring of real time drilling parameters and ev aluation 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. E quipment 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. In the event the well can be contained, produced fluid can be plumbed into the production 

manifold within 200’ of the planned surface location. 

Relief well sites have been initially identified to address blowout scenarios for the potential geologic 

targets for the proposed wells. Two relief well surface locations are proposed for the proposed well. 

The proposed relief well locations are 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 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)

 #6 (G-3) Relief Well #1 MC 546 * 974,835.60 10,318,720.20

Relief Well #2 MC 546 * 971,337.00 10,320.195.70

Relief Well #3 MC 546 * 974,365.00 10,324.165.80

“*” indicates common relief well site to more than 1 exploration plan well
5 

RELIEF WELL RESPONSE TIME ESTIMATE

OPERATION TIME ESTIMATE 

 (DAYS)

IMMEDIATE RESPONSE 

• safeguard personnel, render first-aid

• make initial notifications

• implement short term intervention (if possible)

• implement spill control

• develop Initial Action Plan

 

 1 

INTERIM REPSONSE

• establish Onsite Command Center and Emergency Management Team

• assess well control issues

• mobilize people and equipment (Helix DW Containment System)

• implement short term intervention and containment (if possible)

• develop Intervention Plan

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

• 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)

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

• 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), ranging operations to intersect wellbore

 60

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 99

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

TOTAL DAYS 129
!(

!(!

!

!

!

MC546

G25098

Nexen Petroleum Offshore

Operator LLOG

Relief Well 3

Relief Well 2

Relief Well 1

MC 546-G2

MC 546-G1

MC 546-G3

Map Prepared by:

Berger Geosciences, LLC.

© Berger Geosciences, LLC. 2014

Block 546

Mississippi Canyon Area

Gulf of Mexico

Proposed Relief Wells for Proposed

Wells MC 546 G1, G2 and G3

Lease No. G25098

Legend

Block Boundary

!( Proposed Wells

! Relief Wells

3

Î Lat/Long Grid Points

980,000 E

UTM Northing and Easting Grid Lines

PROPOSED RELIEF WELL LOCATIONS

10,325,000 N

Geodetic Datum: NAD27

Projection: UTM

Zone: 16N

Grid Units: Feet

Interpretation By: Carmen Atkins

Cartography: Sandra R. Milson

Project No.: 13-03-22

Date: September 2014

0 1,000 2,000 3,000

Feet

**IMPORTANT NOTICE**

This map is not intended for 

navigation purposes. 

Public information obtained from 

BOEM database (September 2014).

970,000 E

Scale =1:24,000

10,315,000 N

Y = 10,327,680.00

Y = 10,311,840.00

X = 966,240.00

X = 982,080.00

89°5'0"W

28°25'0"N

89°5'0"W

28°26'0"N

89°4'0"W

28°25'0"N

89°4'0"W

28°26'0"N

PROPOSED WELL LOCATIONS

WellName Block X (ft) Y (ft) Block Call (N-S) Block Call (E-W) Latitude Longitude

MC 546-G1 MC 546 973716.56 10321382.25 6,297.25 ft FNL 7,476.56 ft FWL 28° 25' 33.315" N 89° 4' 28.926" W

MC 546-G2 MC 546 973717.06 10321540.00 6,140.00 ft FNL 7,477.06 ft FWL 28° 25' 34.876" N 89° 4' 28.951" W

MC 546-G3 MC 546 973618.79 10321402.52 6,277.48 ft FNL 7,378.79 ft FWL 28° 25' 33.499" N 89° 4' 30.025" W

WellName Block Block Call (N- Block Call (E-W) X (ft) Y (ft) Latitude Longitude WD (ft)

Relief Well 1 MC 546 6,880 ft FSL 7,244 ft FEL 974,835.60 10,318,720.20 28° 25' 07.155" N 89° 4' 15.884" W 2,636

Relief Well 2 MC 546 7,484 ft FNL 5,097 ft FWL 971,337.00 10,320,195.70 28° 25' 21.163" N 89° 4' 55.340" W 2,577

Relief Well 3 MC 546 3,514 ft FNL 7,715 ft FEL 974,365.00 10,324,165.80 28° 26' 00.979" N 89° 4' 22.203" W 2,520
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX C

GEOLOGICAL AND GEOPHYSICAL INFORMATION

(30 CFR PART 550.214 AND 550.244)

A. Geological Description

Included as Attachment C-1 is the discussion of the geological objectives, 

including a brief description of the hydrocarbon trapping elements. 

B. Structure Contour Maps

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

in feet subsea) depicting the entire coverage area; drawn on top of the prospective 

hydrocarbon sands. 

C. Interpreted Seismic Lines

Included as Attachment C-3 are seismic lines with depth scale within 500’ of the 

surface locations for the proposed wells. 

D. Geological Structure Cross-Sections

Included as Attachment C-4 are interpreted geological structure cross-sections 

showing the location and depth of the proposed MC 546 Well No. 004 and No. 

005 and expected productive formations. 

E. Shallow Hazards Report

A shallow hazards Assessment was prepared by Berger Geoscience and submitted 

by Nexen in December 2011. Berger Geoscience prepared a Supplement to the 

report dated August 15, 2014 for LLOG Exploration for Proposed Well No. 6 (G3). Copies of this report are being filed with BOEM under separate cover and 

included with this plan. 

F Shallow Hazards Assessment

Included as Attachment C-5 is the shallow hazards assessment for the proposed 

Well No. 6 (G3) location.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

 

G. High Resolution Seismic Lines

 Submitted under separate cover with Geophysical Survey for MC 546. 

H. Stratigraphic Column

 

 A generalized biostratigraphic/lithostratigraphic column dispicting the

 well from the seafloor to total depth, with each objective horizon labeled, 

 is inlcuded as Attachment C-6 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

GEOLOGICAL DESCRIPTION

Attachment C-1 

(Proprietary Information)
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

STRUCTURE MAP

Attachment C-2 

(Proprietary Information)
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

INTERPRETED

SEISMIC LINE

Attachment C-3 

(Proprietary Information) 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

STRUCTURAL CROSS SECTION

Attachment C-4 

(Proprietary Information) 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

SHALLOW HAZARD ASSESSMENT

Attachment C-5 

(Proprietary Information) 
Wellsite Clearance Letter

Mississippi Canyon, Block 546 

Proposed Well G3

Project No.: 13-03-22 i

© Berger Geosciences, LLC. 2014

Executive Summary

The following points summarize the seafloor and subsurface conditions in the assessment area for the 

proposed well MC 546-G3. 

• Water depths within a maximum anchor radius of 8,000 ft range from 2,312 ft to 2,929 ft below 

sea level (bsl). The water depth at the proposed well location is 2,569 ft bsl. 

• The seafloor near the proposed well is gently sloping southeast at 1.9°. 

• There is no proposed or existing infrastructure within 1,000 ft of the proposed well MC 546-G3 

location. 

• There are 7 existing wells and numerous proposed infrastructure within the maximum anchor 

radius. 

• An archaeological resource survey performed by Tesla Offshore, LLC. (2013) did not identify 

any sonar contacts within 1,000 ft of the proposed well location. No archaeological avoidances 

are assigned to the sonar contacts within the maximum anchor radius. 

• Seafloor faults are not present within the maximum anchor radius nor near the proposed well 

MC 546-G3.

• Data striping parallel to the acquisition direction is evident in the seafloor amplitude response. 

High amplitude responses are found within these data stripes. These linear groups of anomalies 

are not geologic in origin, and are unlikely to support chemosynthetic or other high-density 

benthic communities.

• Pockmarks within the maximum anchor radius have associated high-amplitude seafloor 

responses and likely represent fluid migration to the seafloor. Chemosynthetic or other highdensity benthic communities may be found in association with these pockmarks. However, 

features that could support high-density chemosynthetic or benthic communities are not expected 

within 2,000 ft of the proposed well. 

• Gas hydrates may be present at or near the seafloor in association with the pockmarks within the 

maximum anchor radius; however, gas hydrates are not expected within 2,000 ft of the proposed 

wells. 

• There is an overall negligible to moderate potential for shallow gas at the proposed well. 

• The assessment area lies within the northern portion the regional sand-bearing Blue unit and the 

inferred limits of the Green unit. The potential for shallow water flow at the proposed well 

ranges from negligible to high. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

Biostratigraphic/Lithostratigraphic Column 

Attachment C-6 

(Proprietary Information) 

 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX D

HYDROGEN SULFIDE (H2S) INFORMATION

(30 CFR PART 550.215 AND 550.245) 

A. Concentration

LLOG does not anticipate encountering H2S while conducting the proposed 

development operations provided under this plan. 

B. Classification

Effective January 8, 2013, the Bureau of Ocean Energy Management classified 

Mississippi Canyon Block 546, in accordance with 30 CFR 250.490©, as H2S 

absent.

C. H2S Contingency Plan

H2S Contingency Plan not required as Mississippi Canyon Block 546 has been 

classified in accordance with 30 CRFR 550.490 (c) as “H2S absent”. (Plan S7563). 

D. Modeling Report

Modeling Report not required as Mississippi Canyon Block 546 has been 

classified in accordance with 30 CRFR 550.490 (c) as “H2S absent”.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX E

MINERAL RESOURCE CONSERVATION INFORMATION

(30 CFR PART 550.246)

A. Technology and Reservoir Engineering Practices and Procedures

B. Technology and Recovery Practices and Procedures

 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX F

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC 

INFORMATION

(30 CFR PART 550.216 AND 550.247)

A. High-Density Deepwater Benthic Communities Information:

See Attachment F-1 

B. Topographic Features Map

Minerals Management Service and the National Marine Fisheries (NMFS) have 

entered into a programmatic consultation agreement for Essential Fish Habitat 

that requires that no bottom disturbing activities (including rig placement, and rig 

or construction base use of anchors, chains, cables, and wire ropes) within 152 

meters (500 feet) of a “No-Activity Zone” of a topographic feature.

C. Topographic Features Statement (Shunting)

The activities proposed in this Plan are not affected by a topographic feature; 

D Live Bottoms (Pinnacle Trend) Map

Mississippi Canyon Blocks 546 is not located within the vicinity of a proposed 

live bottom (low relief) area.

E. Live Bottom (Low Relief) Map

 Mississippi Canyon Block 546 is not located within the vicinity of a proposed live 

bottom (low relief) area.

 

F. Potentially Sensitive Biological Features

Mississippi Canyon Blocks 546 is not located within the vicinity of a proposed 

sensitive biological feature area. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

G. Remotely Operated Vehicle (ROV) Monitoring Survey Plan 

 Pursuant to NTL No. 2008-G06, operators may be required to conduct remote 

operated vehicle (ROV) surveys during pre-spudding and post-drilling operations 

for the purpose of biological and physical observations. Mississippi Canyon 

Blocks 546 is located within an area where ROV Surveys are required; however 

BOEM has sufficient data for Grid 12 and is not longer required. 

H. Threatened and Endangered Species Information

Effective May 14, 2007, Minerals Management Service revised Title 30 CFR Part 

250, Subpart B to require lessees/operators to address the federally listed species 

with designated critical habitat as well as marine mammals which may be 

impacted by the proposed activities addressed under this Plan.

Attachment F-1 outlines the listed species under the jurisdiction of NOAA 

fisheries that are known to occur in the Gulf of Mexico which may be affected by 

the proposed action. 

 

LLOG does not anticipate that the proposed activities will occur in the presence 

of federally listed threatened or endangered species and critical habitat designated 

under the ESA and marine mammals protected under the MMPA based on the 

information in the referenced attachment. 

Proposed activities in Mississippi Canyon Block 546 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 M C 546, LLOG will 

mitigate impact through compliance with NTL 2012-G01, G02 and NTL 2012 

BSEE-G01. See Attachment F-2 for a list of the NOAA Species known in the 

Gulf of Mexico. 

I. Archaeological Report

An Archaeological Assessment was prepared by Tesla Offshore, L.L.C dated 

August 14, 2014 for Proposed OCS-G-25098 Lease, Well G3. A copy of this 

report is attached.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

J. Air and Water Quality Information

Not applicable. The State of Florida is not an affected State,

K. Socioeconomic Information

Not applicable. The State of Florida is not an affected State,
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

ATTACHMENT F-1 

ANCHORING ASSESSMENT

AND 

ARCHAEOLOGICAL ASSESSMENT
 36499 Perkins Road 

 Prairieville, Louisiana 70769 

Telephone: 225.673.2163 

Fax: 225.744.3116 

www.teslaoffshore.com 

 

August 14, 2014 Job No. 13-122-31

Bureau of Ocean Energy Management (MS 5230) 

Gulf of Mexico OCS Region 

1201 Elmwood Park Blvd. 

New Orleans, LA 70123-2394

RE: LLOG Exploration Offshore, L.L.C. 

 Proposed OCS-G 25098 Wells ‘G3’

Block 546, Mississippi Canyon Area 

Archaeological Assessment 

Dear Staff: 

LLOG Exploration Offshore, L.L.C. (LLOG) proposes to drill the OCS-G 25098 Well ‘G3’ 

from the following surface location in Block 546, Mississippi Canyon Area:

Datum: 

NAD 27

 Spheroid: 

Clarke 1866

 Projection: 

UTM

 Zone:

 16.

Central Meridian:

87° 00’ West

 Latitude: 28° 25’ 33.499” N Longitude: 89° 04’ 30.025” W

 X: 973,618.79 Y: 10,321,402.52

 FNL: 6,277.48’ FWL: 7,378.79’

This assessment addresses an anchor radius of 8,000-feet as indicated on the enclosed 

map. The surface location in Block 546 and surrounding area were surveyed by Tesla 

Offshore, LLC in January, 2005 (Reference Job No. 04-443-11); survey coverage 

extended into Blocks 501, 502, 503, 545, and 547. The data set for 04-443-11 was 

utilized to prepare a report for LLOG which was submitted to the then MMS in 2006 

which included revisions to the sonar target list (Reference Job No. 06-685-11). The 

remaining portions of the anchor radius were surveyed by Tesla Offshore, LLC in 

January, 2005, as part of a survey that included coverage in Blocks 501, 545, 589, and 

590 (Reference Job No. 05-190-11), and by C&C Technologies in May, 2013 as part of 

an AUV survey that covered the southeastern portion of the anchor radius in Block 546 

(Reference Job No. 130304). Data coverage in the extreme southeastern portion of the 

anchor radius was surveyed in July, 2010 (Reference Job No. 10-245-11). LLOG 

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

2005-G07) of the proposed well location utilizing these combined data sets in 

accordance with the Bureau of Ocean Energy Management (BOEM) Gulf of Mexico 

OCS Region. 

Water depth is approximately 2,565 feet surrounding the proposed drill site. Water 

depths increase from northwest to southeast at the proposed well site.
TESLA OFFSHORE 

LLOG Exploration Offshore, L.L.C. 

Proposed OCS-G 25098 Well ‘G3’

Block 546, Mississippi Canyon Area 

Archaeological Assessment

Page 2 

Seafloor soils are reported to be silty clay and marine deposits (MMS 1983 Visual 

No. 3; MMS 1986 Visual No. 5). 

Man-made features located within the proposed anchor radius are located north of 

the proposed surface location. P&A Well No. 2 (OCS-G06965) is located 

approximately 4,470’ NW of the proposed surface location. Well SS001 is located 

approximately 4,560’ NNW of the proposed well site; the ENI 6” pipelines (Segments

No. 17491 and 17486) extend from Well SS001 away from the proposed well site, 

across the proposed anchor radius to the northwest. P&A Well No. 1 is located 

approximately 4,600’ N of the proposed surface location and Well SS002 is located 

approximately 7,460’ NNE of the proposed well site. P&A Well no. 2 (OCS-G25098) 

and Well SS003 are located approximately 4,290 and 4,280’ NE of the proposed well 

site; the ENI 6” and 5” pipelines (Segments No. 17841 and 17843) extend from the 

wells, away from the proposed surface location across the proposed anchor radius to 

the northwest. P&A Wells no. 1, 2 (OCS-G 06965), and 2 (OCS-G 25098) were 

installed at the time the original survey data were acquired, however none were 

resolved by side scan sonar data. The remaining installations post-date survey data 

acquisition, therefore the reported positions should be assumed to be correct, and 

care should be exercised in the vicinity of reported infrastructure. The proposed 

surface location is located approximately 2,670 feet E of the eastern margin of a 

designated Explosives Dumping Area, Disused (NOAA 1115A-11360, Cape St. 

George to Mississippi Passes). It is highly likely that dumped materials extend 

beyond the published margins of the Area, and previous ROV surveys near the 

Explosives Dumping Area have verified the presence of WWII-era munitions and 

unexploded ordnance.

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

Sonar data indicated that there are no sonar targets recorded within 2,000’ of the 

proposed surface location. Targets recorded within the proposed anchor radius 

include target no. 8 recorded from the January 2005 survey data (04-443-11; 

reported in 06-685-11), and target no. 24 from the January, 2005 survey data (05-

190-11). The 2013 AUV survey recorded multiple targets within the southeastern 

portion of the proposed anchor radius, including targets 2 – 11, 14 – 17, A1 - A5, and 

A7 - A15 (Job No. 130304), as well as larger areas of debris. All of the observed 

targets are interpreted as possible geologic features or relatively small unidentified 

modern materials that may be related to the Explosives Dumping Ground or nearby 

drilling activities and have not been assigned avoidances as potential archaeological 

resources. 

No evidence of intact shipwreck sites was observed within the proposed anchor radius 

or buffer area. No targets of potential archaeological significance were identified within 

the anchor radius surrounding the proposed well site. The only features of potential 

anthropogenic origin (other than the existing pipelines, wells, and P&A wells) were 
TESLA OFFSHORE 

LLOG Exploration Offshore, L.L.C. 

Proposed OCS-G 25098 Well ‘G3’

Block 546, Mississippi Canyon Area 

Archaeological Assessment 

Page 3 

relatively small targets identified as modern in origin, which may be associated with the 

nearby Explosives Dumping Ground or drilling activities. These features are not 

recommended for avoidance as potential cultural resourcHV

. 

LLOG Exploration Offshore, L.L.C. and subcontractors will apply the safest and best 

available technologies during drilling operations and installation of future platforms 

and/or facilities. In compliance with 30 CFR 550.194(c), 30 CFR 550.1010(c), and NTL 

2005-G07, if materials are observed during operations that could indicate the presence 

of a shipwreck, shipwreck site, or other potentially significant archaeological resource, 

operations will cease and the Regional Supervisor, Leasing and Environment with the 

BOEM/BSEE will be notified within 48 hours of discovery. 

 

Sincerely, 

Amanda Evans, PhD, RPA 

Marine Archaeologist 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

 ATTACHMENT F-2 

NOAA Species known in the Gulf of Mexico


LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX G

WASTE AND DISCHARGE INFORMATION

 (30 CFR PART 550.217 AND 550.248)

A. Projected Generated Waste

● See Attached Waste Tables

 

B. Projected Ocean Discharges 

● See Attached Discharge Tables 

 

C Modeling Report

Not applicable. Discharges will be performed under EPA NPDES General 

Permit GMG 290000. 

D. NPDES Permits

Not applicable. Discharges will be performed under EPA NPDES General Permit 

GMG290000. 

E. Cooling Water Intakes

The information at 550.217(e) and 550.248(e) regarding cooling water intakes is 

not required to accompany DOCD’s submitted in the BOEM. 
please specify if the amount reported is a total or per well amount

MC 546 G-

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, 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 3,272 bbls/well 1,786 bbls/day/well Discharge overboard No

Cuttings wetted with water-based fluid

Cuttings generated while using 

water based drilling fluid. 393 bbls/well 199 bbls/day/well Discharge overboard No

Cuttings wetted with synthetic-based fluid 

Cuttings generated while using 

synthetic based drilling fluid. 3,586 bbls/well 120 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

Kitchen water, unprocessed 

water not used for sanitation 

purposes 6,429 bbls/well 2.7 bbls/hr/well

Discharge overboard 

(no free oil) No

Sanitary waste

Processed sanitary waste from 

living quarters 4,286 bbls/well 1.8 bbls/hr/well

Chlorinate and 

discharge overboard No

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

Deck Drainage

Accumulated drainage due to 

rainfall 0 to 47,261 bbls/well 0 to 167 bbls/hr/well

Test for oil and grease 

and discharge 

overboard No

Will you conduct well treatment, completion, or workover? 

Well treatment fluids

NPDES approved treatment 

fluid used for well operations 100 bbls/well 20 bbls/hr/well

Test for oil and grease 

and discharge 

overboard. No

Well completion fluids

Clear brines used for 

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

Test for oil and grease 

and discharge 

overboard. This 

excludes clear brines 

containing Zinc No 

Workover fluids NA NA NA NA No

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

Desalinization unit discharge NA NA NA NA No 

Blowout prevent fluid NA NA NA NA No

Ballast water

Uncontaminated seawater used 

for ballast control 0 to 100,000 bbls/well 16,350 bbls/hr/well Discharge overboard No

Bilge water NA NA NA NA 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 NA NA NA NA 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 ? General NPDES Permit

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 

Disposal
please specify whether the amount reported is a total or per well

Projected generated 

waste

Solid and Liquid 

Wastes transportation 

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

Disposal 

Method

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 NA NA NA

Synthetic-based drilling fluid or mud 

Internal olifin, ester nbased 

mud

Barged in 25 bbls cutting boxes 

and / or liquid mud tanks for supply 

vessels

Newpark Transfer Station, 

Fourchon, LA

6750 bbls / 

well Recycled

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

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

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

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

Produced sand NA NA NA NA NA

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

Trash and debris Plastic, paper, aluminum Barged in a storage bin

Blanchard Landfill, Golden 

Meadows, LA 4000 lbs / well Recycled

Used oil Spent oil from machinery

Barged in USCG approved transfer 

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

Wash water

Wash water w/ SBM residue 

and surfactants

Barged in 25 bbls cutting boxes 

and / or liquid mud tanks for supply 

vessels

Newpark Transfer Station, 

Fourchon, LA

2000 bbls / 

well

Approved 

disposal well 

injection or land 

farm

Chemical product wastes

Spent treatment and / or 

damaged chemicals used in 

operations

Barged in 25 bbls cutting boxes 

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

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

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

Waste Disposal

Will you have additional wastes that are not permitted for discharge? If 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX H

AIR EMISSIONS INFORMATION

(30 CFR PART 550.218 AND 550.249)

The primary air pollutants associated with OCS development activities are:

 ● Carbon Monoxide 

● Particulate Matter

 ● Sulphur Oxides 

 ● Nitrogen Oxides 

 ● Volatile Organic Compounds 

These offshore air emissions result mainly from the drilling rig operations, helicopters, 

and support vessels. These emissions occur mainly from combustion or burning of fuels 

and natural gas and from venting or evaporation of hydrocarbons. The combustion of 

fuels occurs primarily on diesel powered generators, pumps or motors and from lighter 

fuel motors. Other air emissions can result from catastrophic events such as oil spills and 

blowouts. 

A. Emission Worksheets and Screening Questions

The Projected Air Quality Emissions Report (Form MMS-139) addresses the 

related support vessels and construction barge information. 

B. Emissions Reduction Measures

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

emission reduction measures are being proposed. 

C. Verification of Non-default Emissions Factors

LLOG has elected to use the default emission factors as provided in 

Attachment H-1 for various vessels however will utilize historical fuel data 

for the proposed rig Noble Amos Runner and vessel Joshua Chouest.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

D. Non-Exempt Activities

The proposed activities are within the exemption amount. 

E. Modeling Report

Not applicable. The State of Florida is not an affected State for the proposed 

activities in this plan.. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

Air Quality Emissions Report

Attachment H-1 

(Public Information)
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

Attachment H-1 

Air Emissions Information (§§ 550.218 and 550.249)

Screening Questions for DOCD’s Yes No

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

proposed development and production activities more than 90% of the amounts 

calculated using the following formulas: CT = 3400D2/3 for CO, and CT = 33.3D for 

the other air pollutants (where D = distance to shore in miles)?

 X 

Do your emission calculations include any emission reduction measures or modified 

emission factors? X

Does or will the facility complex associated with your proposed development and 

production activities process production from eight or more wells? 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 in excess of the criteria set forth under 

30 CFR 250.1105(a)(2) and (3)? X

Do you propose to burn produced hydrocarbon liquids? X

Are your proposed development and production activities located within 25 miles (40 

kilometers) from shore? X

Are your proposed development and production activities located within 124 miles 

(200 kilometers) of the Breton Wilderness Area? X 
DOCD AIR QUALITY SCREENING CHECKLIST OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2011

MMS FORM MMS-139 (December 2008- Supersedes all previous versions of form MMS-139 which may not be used). Page 1 of 8

COMPANY LLOG Exploration Offshore, L.L.C.

AREA Mississippi Canyon 

BLOCK 546

LEASE OCS-G-25098

PLATFORM G Manifold

WELL #6 (G3)

COMPANY CONTACT Nelda Runyon

TELEPHONE NO. 985-801-4389

REMARKS Drill/Complete & jumper installation6HPLVXEPHUVLEOH5LJ

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

2015 N/A N/A

2016

2017

2018

2019

2020

2021

2022

2023

2024

2025
AIR EMISSIONS CUMPUTATION FACTORS

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 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
AIR EMISSIONS CALCULATIONS - FIRST YEAR

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 3 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offsho Mississippi Canyon 546 G-25098 G Manifold #6 (G-3) Nelda Runyon 985-801-4389 #REF!

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 12500 603.75 14490.00 24 105 8.81 40.42 302.86 9.09 66.08 11.10 50.93 381.61 11.45 83.26

See Attached Fuel PRIME MOVER>600hp diesel 0 0 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

for Noble Amos Runner 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) 7000 338.1 8114.40 12 45 4.93 22.63 169.60 5.09 37.00 1.33 6.11 45.79 1.37 9.99

VESSELS>600hp diesel(supply) 4400 212.52 5100.48 12 90 3.10 14.23 106.61 3.20 23.26 1.67 7.68 57.57 1.73 12.56

See Attached Fuel VESSELS>600hp diesel(supply) 15200 734.16 17619.84 12 90 10.71 49.15 368.28 11.05 80.35 5.79 26.54 198.87 5.97 43.39

Usage-Joshua Chouest VESSELS>600hp diesel(tugs) 13500 652.05 15649.20 24 4 9.52 43.65 327.09 9.81 71.37 0.46 2.10 15.70 0.47 3.43

PIPELINE PIPELINE LAY BARGE diesel 16876 815.1108 19562.66 24 7 11.89 54.57 408.89 12.27 89.21 1.00 4.58 34.35 1.03 7.49

INSTALLATION SUPPORT VESSEL diesel 8805 425.2815 10206.76 24 7 6.21 28.47 213.34 6.40 46.55 0.52 2.39 17.92 0.54 3.91

(Jumper) PIPELINE BURY 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

SUPPORT VESSEL 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

FACILITY DERRICK BARGE diesel 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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 55.18 253.12 1896.68 56.90 413.82 21.87 100.33 751.81 22.55 164.03

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1265.40 1265.40 1265.40 1265.40 38429.79

38.0
AIR EMISSIONS CALCULATIONS - SECOND YEAR

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 4 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 G Manifold #6 (G3) Nelda Runyon 985-801-4389 #REF!

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 0.00 0.00 0.00 0.00 0.00

0.0
AIR EMISSIONS CALCULATIONS - THIRD YEAR

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 5 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 G Manifold #6 (G3) Nelda Runyon 985-801-4389 #REF!

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 0.00 0.00 0.00 0.00 0.00

0.0
AIR EMISSIONS CALCULATIONS - FOURTH YEAR

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 6 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 G Manifold #6 (G3) Nelda Runyon 985-801-4389 #REF!

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 0.00 0.00 0.00 0.00 0.00

0.0
AIR EMISSIONS CALCULATIONS - FIFTH YEAR

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 7 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 G Manifold #6 (G3) Nelda Runyon 985-801-4389 #REF!

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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

2019 YEAR TOTAL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 0.00 0.00 0.00 0.00 0.00

0.0
AIR EMISSIONS CALCULATIONS

MMS FORM MMS-139 (December 20008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 8 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL

LLOG Exploratio Mississippi Canyon 546 OCS-G-25098 G Manifold #6 (G3)

Emitted Substance

Year

PM SOx NOx VOC CO

2015 21.87 100.33 751.81 22.55 164.03

2016 0.00 0.00 0.00 0.00 0.00

2017 0.00 0.00 0.00 0.00 0.00

2018 0.00 0.00 0.00 0.00 0.00

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 1265.40 1265.40 1265.40 1265.40 38429.79


M/V JOSHUA CHOUEST

288’ ANCHOR HANDLING TUG SUPPLY VESSEL

EDISON CHOUEST OFFSHORE
M/V JOSHUA CHOUEST M/V JOSHUA CHOUEST Specifications

REGISTRATION: Hull #234 Vessel Type: Anchor Handling Tug Supply Vessel Year Built: 2007, North American Shipbuilding

03/11

U.S. MEASUREMENTS

DIMENSIONS 288’ X 66’ X 29.5’

Draft (Loadline): 23’

Draft (Lightship): 16’

Clear Deck: 136’ x 54’

Clear Deck Area: 7,344 sq. ft.

Deck Cargo Capacity: 1,650 LT

Deadweight Tonnage: 4,236 LT

CAPACITIES

Fuel Oil: 491,613.5 gals.

Ballast: 455,851 gals.

Potable Water: 78,104 gals.

Dry Bulk: 10,851.4 cu. ft. @ 80 psi

Liquid Mud: 7,923.37 barrels

METRIC EQUIVALENTS

87.78 m X 20.12 m X 8.99 m

7.01 m

4.88 m

41.45 m x 16.46 m

682.28 m2

1,676 MT

4,303.97 MT

1,860.96 m3

1,725.58 m3

295.66 m3

307.28 m3 @ 5.5 bars

1,259.72 m3

MACHINERY

Main Engines: Two (2) 3616 Cat Diesels, 15,200 BHP

Bow Thrusters: One (1) 1,500 HP Tunnel

One (1) 1,200 HP Drop-Down Azimuthing

Stern Thruster: One (1) 1,500 HP Tunnel

Propulsion: Two (2) x 4,000 mm C.P. in nozzles

Speed: 16 knots

Generators: Three (3) x 500 kW, One (1) x 300 kW

Winches: Three (3) Drum Waterfall, 500 MT Line Pull

SPECIAL FEATURES

Shark Jaws: Two (2) x 700 MT

Tow Pins: Two (2) x 300 MT

Stern Rollers: Two (2) x 12’ dia. @ 750 MT

Tuggers: Four (4) x 25 Tons

Cranes: Two (2) x 5-Ton (4.53 MT) capacity

Ship Motion: Two (2) Passive Type Anti-Roll Tanks, 

Bilge Keels

Positioning: DP 2

ROV: C-Innovation Schilling UHD14 Gen. 1 ROV

A-Frame: One (1) x 3 AMC “MK2”

(optional equipment)

ACCOMMODATIONS: 43 

LIFESAVING EQUIPMENT

Six (6) x 25-Man Inflatable Life Rafts

One (1) x Narwhal SV 402 Rescue Boat with davit

Other gear as required by USCG and SOLAS

CLASSIFICATION

ABS Star A1 (Unrestricted Ocean Service)

ABS Star AMS

ABS Star ACC

ABS Loadline

ABS Star DP2

USCG Subchapter I/L

SOLAS 2004

MARPOL 1999

ELECTRONICS

JRC NDZ-127C1 Inmarsat

JRC JSB 196GM SSB Radio Telephone

JRC NCT-196N DSC/NBDP Modem

JRC JFE-585 Echo Sounder

Two (2) JRC NWZ-4570 GPS Navigators

Two (2) C-NAV 1000 and 2050 GPS/DP

JRC NCR-333 Navtex Receiver

Two (2) Furuno FM 8800S VHF Radio Telephones

Two (2) ICOM IC-M422 VHF Radios

Marine Technologies Bridge Mate AIS Unit

Navitron NT951G Autopilot

Two (2) Marine Technologies Bridge Mate Gyro Compasses

Three (3) ICOM IC-GM1600 Handheld Emergency VHF 

ACR Satellite 2406 EPIRB

Three (3) ACR Pathfinder 3 SART

Marine Technologies Dynamic Positioning System 

Wire 

Size

Port/Starboard 

Anchor Drums (2) Tow Drum Port/Starboard Storage Reels (2)

3” 13,000 ft. (3,962 m) 27,140 ft. (8,272 m) 19,879 ft. (6,059 m)

3.25” 11,189 ft. (3,410 m) 23,125 ft. (7,048 m) 16,923 ft. (5,158 m)

3.5” 9,648 ft. (2,940 m) 19,939 ft. (6,077 m) 14,601 ft. (4,450 m)

Rope Size Tow Drum Storage Reels

6.75” 9,000 ft. 

(2,743 m)

10,000 ft. 

(3,048 m)

7.25” 7,500 ft. 

(2,286 m)

8,500 ft. 

(2,590 m)

Chain Size Chain Lockers (4)

3” 5,300 ft. (1,600 m)

3.25” 4,526 ft. (1,380 m)

3.5” 3,900 ft. (1,188 m)

Brine/Drill WaterBallast/Fresh WaterFuel OilLiquid MudDry BulkAnti-RollAuxiliaryDirty Oil

Fuel Oil Overflow

Potable WaterSewageVoid/CofferdamWash WaterLiquid Mud CleaningMethanol
M/V JOSHUA CHOUEST M/V JOSHUA CHOUEST Schematics

DOWN

UP

DOWN

UP

PANTRY

GALLEY COOLER FREEZER

MESS AREA

LOUNGE

CHANGE ROOM

HEAD

CASING

VENTILATION

HEAD

CASING VENTILATION

CO2 LOCKER DECK

STORES

HPU ROOM WORKSHOP

STERN ROLLER STERN ROLLER

DECK

STORES

MAIN DECK

UP

STORAGE

LKR

UP

BALLAST FUEL OIL

VOID

POTABLE WATER

VOID

BALLAST

VOID

VOID

HEAD

LOW VOLTAGECONTROL PANEL

FUEL OIL

FUEL OIL

LIQUID MUD

DRY BULK

DRY BULK

DRY BULK

DOWN

A/C A/C

VOID

POTABLE WATER

VOID

BALLAST FUEL OIL

DOWN

BALLAST

LIQUID MUD

CLEANING

GEAR OIL

SPARE #6SPARE #5

CAT

OIL

DOWN

TUNNEL THRUSTER

SPARE #1

HPU OIL

MAIN ENG

CAT OIL

HATCH

BALLAST

BALLAST

ANTI ROLL

BALLAST BALLAST BALLAST

ANTI ROLL

LIQUID MUD

LIQUID MUD

LIQUID MUD

LIQUID MUD

LIQUID MUD HEAD HEAD

HEAD HEAD

LOWER DECK

BALLAST

FUEL OIL

FUEL OIL

DIRTY OIL

FUEL OIL

OVERFLOW

FUEL OIL

FUEL OIL

FUEL OIL

BALLAST

GEAR RECESS

GEAR RECESS

VOID VOID

BALLAST FUEL OIL POTABLE WATER

COFFERDAM

FUEL OIL FUEL OIL FUEL OIL

FUEL OIL FUEL OIL FUEL OIL

FUEL OIL POTABLE WATER

COFFERDAM

BALLAST

BALLAST

BALLAST

BALLAST

BELOW TANK TOP

BALLAST

BALLAST

SEWAGE WASH WATER

BALLAST

FUEL OIL FUEL OIL

UP

FUEL OIL FUEL OIL

VOIDVOID

VOID

POTABLE WATER

POTABLE WATER FUEL OIL

FUEL OIL

LIQUID MUD

LIQUID MUD

LIQUID MUD LIQUID MUD

LIQUID MUD LIQUID MUD

BALLAST

BALLAST

DRY BULK

DRY BULK

DRY BULK

BALLAST

BALLAST

BALLAST

BALLAST BALLAST

UP

VOID

ABOVE TANK TOP

STORAGE CHAIN

LKR

CHAIN

LKR

LAUNDRY

LKR

HEAD HEAD

CASING VENTILATION

CLIENT

BEDROOM

HEAD

CLIENT

DAY ROOM

HEAD

HEAD HEAD

HEAD

HEAD

CASING VENTILATION

DOWN

LKR HYDRAULIC

PAINT LOCKER ROOM

LOCKER HYDRAULIC

ROOM

UP

DOWN

UP

DECK 01

VENTILATION CASING

ENG

BEDROOM HEAD

HEAD

ENG

DAYROOM

CAPT

DAYROOM

CAPT

BEDROOM

HEAD

HEAD

VENTILATION CASING

HEAD

HOSPITAL

DOWN

UP

DOWN

UP

SCORPION 24

WORK VAN

SCORPION 24

CONTROL VAN

UP

SCORPION 24

LAUNCH AND RECOVERY SYSTEM

DECK 02

ELECTRONICS

AREA

UP

BATTERY

ROOM

UP

DOWN

SHIP’S

OFFICE

CASING

STORAGE

UP

DOWN

HVAC ROOM

FUEL

OIL

EMERGENCY

GENERATOR ROOMSWITCHBOARD

UP

CASING

STORAGE

DECK 03

DOWN

DOWN

DOWN

NAV / CONTROL

CENTER

CASING

DOWN

CASING

HEAD

DECK 06 DECK 05 DECK 04











LLOG EXPLORATION COMPANY, L.L.C.

* DISTRIBUTION: 1 copy to Dispatcher

 Original attached to boat logs

M/V 

Month

Location

Rig

DAY STD BY STD BY LIQUID BULK BULK 

OF DOCK RUN OFFSHORE POB Total DIESEL LUBE DIESEL LUBE TICKET DIESEL TICKET DIESEL LUBE DIESEL LUBE MUD CEMENT BARITE DIESEL LUBE

MONTH LOAD & TIME LOAD & Man OIL OIL NUMBER NUMBER OIL OIL BBLS & OIL

UNLOAD UNLOAD Hrs WT

1 5.5 1.5 21 0 275138 4453 500 0 274638 4453

2 2.5 16.5 5 22 110 274638 4453 5600 63 269038 4390

3 21.25 2.75 23 0 269038 4390 10469 2100 0 277407 4390

4 23.5 0.5 23 0 277407 4390 800 0 276607 4390

5 24 23 0 276607 4390 700 37 275907 4353 -176 16

6 21.5 2.5 23 0 275731 4369 700 0 275031 4369

7 9.25 8.75 6 25 150 275031 4369 3301 3 271730 4366

8 24 25 600 271730 4366 3400 7 268330 4359

9 24 25 600 268330 4359 3501 4 264829 4355

10 5 8 11 25 275 264829 4355 5200 50 259629 4305

11 21 3 23 0 259629 4305 700 0 258929 4305

12 3.75 14.25 6 23 138 258929 4305 5901 37 253028 4268 -111 -9

13 22 2 24 0 252917 4259 1400 0 251517 4259

14 23 1 24 0 251517 4259 1200 0 250317 4259 845 -327

15 0 251162 3932 251162 3932

16 0 251162 3932 251162 3932

17 0 251162 3932 251162 3932

18 0 251162 3932 251162 3932

19 0 251162 3932 251162 3932

20 0 251162 3932 251162 3932

21 0 251162 3932 251162 3932

22 16 2.5 24 0 251162 3932 1700 0 249462 3932

23 21.75 2.25 24 0 249462 3932 14999 1019382 501 0 263960 3932

24 11.75 8 4.25 29 123.25 263960 3932 3800 5 260160 3927

25 6.5 17.5 29 507.5 260160 3927 6100 48 254060 3879

26 3.5 20.5 29 594.5 254060 3879 4600 0 249460 3879

27 13.5 10.5 25 0 249460 3879 19327 53 35050/35053 4600 0 264187 3932 -371

28 23 1 25 0 263816 3932 1300 0 262516 3932

29 22 2 24 0 262516 3932 1500 93 261016 3839

30 22.5 1.5 25 0 261016 3839 1200 6 259816 3833

31 24 26 0 259816 3833 500 0 259316 3833

Total HRS 336.75 98.5 118.25 589 3098.3 44795 53 0 60804 353

Actual Hours

Productive STARTING BALANCE RECEIVED CONSUMED ENDING BALANCE

Joshua Chouest

Jan-14

Amos Runner FUEL RECAP SHEET GAUGED STOCK

ON HAND TRANSFERRED LIQUID MUD & BULK ABOARD
DOCD AIR QUALITY SCREENING CHECKLIST OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2014

FORM BOEM-0139 December 2011- Supersedes all previous versions of form BOEM-0139 which may not be used). Page 1 of 8

COMPANY LLOG Exploration Offshore, L.L.C.

AREA Mississippi Canyon

BLOCK 546

LEASE OCS-G-25098

PLATFORM "G" Manifold

WELL #6 (G-3)

COMPANY CONTACT Nelda Runyon

TELEPHONE NO. 985-801-4300

REMARKS DP Semisubmersible

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

2015 N/A

2016

2017

2018

2019

2020

2021

2022

2023

2024

2025
AIR EMISSIONS CUMPUTATION FACTORS

FORM BOEM-0139 December 2011 - Supersedes all previous versions of form BOEM-0139 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
AIR EMISSIONS CALCULATIONS - FIRST YEAR

FORM BOEM-0139 December 2011- Supersedes all previous versions of form BOEM-0139 which may not be used). Page 3 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offsho Mississippi Canyon 546 OCS-G-25098 "G" Manifold #6 (G-3) Nelda Runyon 985-801-4300 #REF!

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 59380 2868.054 20124.00 24 105 41.85 192.00 1438.72 43.16 313.90 15.42 70.73 529.98 15.90 115.63

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

See Attached Fuel 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

Usuage for Sevan 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

Rig 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) 7000 338.1 8114.40 12 45 4.93 22.63 169.60 5.09 37.00 1.33 6.11 45.79 1.37 9.99

VESSELS>600hp diesel(supply) 4400 212.52 5100.48 12 90 3.10 14.23 106.61 3.20 23.26 1.67 7.68 57.57 1.73 12.56

VESSELS>600hp diesel(supply) 15200 734.16 17619.84 12 90 10.71 49.15 368.28 11.05 80.35 5.79 26.54 198.87 5.97 43.39

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 60.60 278.01 2083.22 62.50 454.52 24.21 111.06 832.22 24.97 181.57

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1265.40 1265.40 1265.40 1265.40 38429.79

38.0
AIR EMISSIONS CALCULATIONS - SECOND YEAR

FORM BOEM-0139 December 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used). Page 4 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 "G" Manifold #6 (G-3) Nelda Runyon 985-801-4300 DP Rig

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1198.80 1198.80 1198.80 1198.80 37069.26

36.0
AIR EMISSIONS CALCULATIONS - THIRD YEAR

FORM BOEM-0139 December 2011- Supersedes all previous versions of form BOEM-0139 which may not be used). Page 5 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 "G" Manifold #6 (G-3) Nelda Runyon 985-801-4300 #REF!

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1198.80 1198.80 1198.80 1198.80 37069.26

36.0
AIR EMISSIONS CALCULATIONS - FOURTH YEAR

FORM BOEM-0139 December 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used). Page 6 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 "G" Manifold #6 (G-3) Nelda Runyon 985-801-4300 #REF!

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1198.80 1198.80 1198.80 1198.80 37069.26

36.0
AIR EMISSIONS CALCULATIONS - FIFTH YEAR

FORM BOEM-0139 December 2011- Supersedes all previous versions of form BOEM-0139 which may not be used). Page 7 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

LLOG Exploration Offshor Mississippi Canyon 546 OCS-G-25098 "G" Manifold #6 (G-3) Nelda Runyon 985-801-4300 #REF!

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 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

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) 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

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

PIPELINE PIPELINE LAY 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 SUPPORT VESSEL 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

PIPELINE BURY 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

SUPPORT VESSEL 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

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

PRODUCTION RECIP.<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

RECIP.>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

SUPPORT VESSEL 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

TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER nat gas 0 0.00 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

FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0.00 0.00

FUGITIVES- 0.0 0 0.00 0.00

GLYCOL STILL VENT- 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

2019 YEAR TOTAL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 1198.80 1198.80 1198.80 1198.80 37069.26

36.0
AIR EMISSIONS CALCULATIONS

FORM BOEM-0139 December 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used). Page 8 of 8

COMPANY AREA BLOCK LEASE PLATFORM WELL

LLOG Exploratio Mississippi Canyon 546 OCS-G-25098 "G" Manifold #6 (G-3)

Emitted Substance

Year

PM SOx NOx VOC CO

2015 24.21 111.06 832.22 24.97 181.57

2016 0.00 0.00 0.00 0.00 0.00

2017 0.00 0.00 0.00 0.00 0.00

2018 0.00 0.00 0.00 0.00 0.00

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 1265.40 1265.40 1265.40 1265.40 38429.79
          	 
    
    

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Sevan Brasil: Fuel consumption

12/1/2013 41 m3 10830.97 gal

12/2/2013 32 m3 8453.44 gal

12/3/2013 39 m3 10302.63 gal

12/4/2013 36 m3 9510.12 gal

12/5/2013 45 m3 11887.65 gal

12/6/2013 36 m3 9510.12 gal

12/7/2013 34 m3 8981.78 gal

12/8/2013 35 m3 9245.95 gal

12/9/2013 34 m3 8981.78 gal

12/10/2013 23 m3 6075.91 gal

12/11/2013 45 m3 11887.65 gal

12/12/2013 49 m3 12944.33 gal

12/13/2013 44 m3 11623.48 gal

12/14/2013 29 m3 7660.93 gal

12/15/2013 27 m3 7132.59 gal

12/16/2013 44 m3 11623.48 gal

12/17/2013 37 m3 9774.29 gal

12/18/2013 62 m3 16378.54 gal

12/19/2013 116 m3 30643.72 gal

12/20/2013 69 m3 18227.73 gal

12/21/2013 80 m3 21133.6 gal

12/22/2013 40 m3 10566.8 gal

12/23/2013 70 m3 18491.9 gal

12/24/2013 31 m3 8189.27 gal

12/25/2013 32 m3 8453.44 gal

12/26/2013 28 m3 7396.76 gal

12/27/2013 40 m3 10566.8 gal

12/28/2013 50 m3 13208.5 gal

12/29/2013 50 m3 13208.5 gal

12/30/2013 28 m3 7396.76 gal

12/31/2013 67 m3 17699.39 gal

1/1/2014 0 m3 0 gal

1/2/2014 0 m3 0 gal

1/3/2014 0 m3 0 gal

1/4/2014 0 m3 0 gal

1/5/2014 0 m3 0 gal

1/6/2014 0 m3 0 gal

1/7/2014 0 m3 0 gal

1/8/2014 0 m3 0 gal

1/9/2014 0 m3 0 gal

1/10/2014 0 m3 0 gal

1/11/2014 0 m3 0 gal

1/12/2014 0 m3 0 gal

1/13/2014 0 m3 0 gal
1/14/2014

0 m30 gal

1/15/20140 m30 gal

1/16/20140 m30 gal

1/17/20140 m30 gal

1/18/20140 m30 gal

1/19/20140 m30 gal

1/20/20140 m30 gal

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2/25/20140 m30 gal

2/26/20140 m30 gal

2/27/20140 m30 gal

2/28/20140 m30 gal

3/1/20140 m30 gal
3/2/2014

0 m30 gal

3/3/20140 m30 gal

3/4/20140 m30 gal

3/5/20140 m30 gal

3/6/20140 m30 gal

3/7/20140 m30 gal

3/8/20140 m30 gal

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3/25/20140 m30 gal

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3/27/20140 m30 gal

3/28/20140 m30 gal

3/29/20140 m30 gal

3/30/20140 m30 gal

3/31/20140 m30 gal

4/1/20140 m30 gal

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4/13/20140 m30 gal

4/14/20140 m30 gal

4/15/20140 m30 gal

4/16/20140 m30 gal

4/17/20140 m30 gal
4/18/2014

0 m30 gal

4/19/20140 m30 gal

4/20/20140 m30 gal

4/21/20140 m30 gal

4/22/20140 m30 gal

4/23/20140 m30 gal

4/24/20140 m30 gal

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5/25/20140 m30 gal

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5/28/20140 m30 gal

5/29/20140 m30 gal

5/30/20140 m30 gal

5/31/20140 m30 gal

6/1/20140 m30 gal

6/2/20140 m30 gal
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX I

OIL SPILL INFORMATION

(30 CFR PART 550.219 AND 550.250)

A. Oil Spill Response Planning

The proposed activities in this Supplemental Development Operations 

Coordination Document Plan will be covered by the Oil Spill Response Plan filed 

by LLOG (MMS Operator No. 02058) in accordance with 30 CFR 254 Biennial 

update approved on A ugust 8, 2012, m odification submitted January 29, 2013, 

approved on February 25, 2013 and last modified April 13, 2013 a nd approved 

April 19, 2013. 

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

 WCD approved in Plan S-7505. 

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 Venice, LA

C. OSRO Information 

The O’Brian 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. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

D. Worst-Case Scenario Information

Category Regional OSRP Supp DOCD

Type of Activity Development Development

Facility Surface Location Mississippi Canyon 547 Mississippi Canyon 547

Facility Description Platform A Platform A

Distance to Nearest Shore (Miles) 36 Miles 36 Miles

Volume:

Storage Tanks (total)

Facility Piping (total)

Lease Term Pipeline

Uncontrolled Blowout (day)

Potential 24 Hour Volume (bbls)

3,902 bbls

200 bbls

1,908 bbls

29,440 bbls

35,450 bbls

3,902 bbls

200 bbls

1,908 bbls

29,440 bbls

35,450 bbls

Type of Liquid Hydrocarbon Crude Oil Crude Oil

API Gravity 27° 27°

Category Regional OSRP Supp DOCD

Type of Activity Drilling Drilling

Facility Surface Location Mississippi Canyon 503 Mississippi Canyon 546

Facility Description Well No. SS002 Well No.SS006 (G3)

Distance to Nearest Shore (Miles) 36 Miles 38 Miles

Potential 24 Hour Volume (bbls) 225,144 bbls 109,127 bbls

Type of Liquid Hydrocarbon Crude Oil Crude Oil

API Gravity 28° 27°

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 Biennial update approved on 

August 8, 2012, modification submitted January 29, 2013, approved on February 25, 

2013 and last modified April 13, 2013 and approved April 19, 2013, I hereby certify that 

LLOG has the capability to respond, to the maximum extent practicable, to a worst-case 

discharge, or a s ubstantial threat of such a d ischarge, resulting from the activities 

proposed in this Supplemental EP. 

The WCD for the subject plan does not exceed the worst case discharge previously 

submitted for MC 547. (Plan S-7505) 

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

Supplemental Development Operations Coordination Document (S-7659) for Mississippi 

Canyon Block 546 (OCS-G-25098) approved by BOEM on July 3, 2014.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

E. Oil Spill Response Discussion – See Attached.

F. Modeling Report 

Not applicable. Florida is not an affected state. 

 

 
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 109,127 barrels of crude oil with an API gravity of 28°. 

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 an 8% 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 10% or 

approximately 10,913 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 98,214 barrels remaining. 

Spill Response MC 546, No. SS004 Barrels of Oil 

WCD Volume 109,127 

Less 10% natural evaporation/dispersion 10,913 

Remaining volume 98,214 

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 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’s spill response equipment, with a total derated 

skimming capacity of 110,943 barrels. Temporary storage associated with skimming equipment 

equals 5,363 barrels. If additional storage is needed, a 25,000 barrel storage barge, a 23,000 

barrel storage barge, and three 20,000 barrel storage barges 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 69,764 

barrels. Temporary storage associated with skimming equipment equals 916 barrels. If additional 

storage is needed, a 47,000 barrel storage barge and two 23,000 barrel storage barges 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. 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 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. 

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 40 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 which include but 

are not 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 be supervised by the designation of a SIMOPS group as 

necessary for close quarter vessel response activities. Most often, this group will be used during 

source control events that require a significant number of large vessels operating independently, 

but in coordination to complete a common objective, in a small area and in close coordination 

and support of each other. This group must also monitor the subsurface activities of each vessel 

(ROV, dispersant application, well control support, etc.). The SIMOPS group leader reports to 

the Source Control Section Chief. 

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 will be 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 
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. 

Offshore Response Actions 

Equipment Deployment

Surveillance 

• Surveillance Aircraft will be deployed within two hours of Qualified Individual (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 Airborne Support Inc. (ASI) on standby 

• With the Federal On-Scene Coordinator (FOSC), conduct analysis to determine 

appropriateness of dispersant application 

• 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 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 

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 FRUs 

• To the area of the thickest oil 

• Use as far off-shore as allowed 

• VOOs 140’ – 180’ 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 

MSRC Oil Spill Response Vessels (OSRV) 

• Use in areas with heaviest oil concentrations 

• Use as far off-shore as allowed 

MSRC Responders 

• Use in areas with heaviest oil concentrations 

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

Storage Vessels 

• Establish availability of CGA contracted assets 

• 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 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 
In-situ Burn assets 

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

affected State On-Scene Coordinator (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 

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. 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. 
Near Shore Response Actions 

Timing 

• Place near shore assets on standby and deploy 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 

Equipment Deployment 

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 

• 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) 

Vessel Deployment 

Dedicated Near Shore skimming systems 

• Fast Response Vessels (FRV) 

• Egmopol and Marco Shallow Water Skimmer (SWS) 

• 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 

• Time to acquire personnel and equipment and their availability 

• Previous contingency planning contained in the appropriate Area Contingency Plan, 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 

• 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 be 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 

MC 546, No. SS004 

G1

41 miles from shore 

G-25098 C58 Galveston, TX 

Jefferson, TX 

Cameron, LA 

Vermilion, LA 

Iberia, LA 

Terrebonne, LA 

Lafourche, LA 

Jefferson, LA 

Plaquemines, LA 

St. Bernard, LA 

Okaloosa, FL 

1 

1 

3 

2 

1 

3 

3 

1 

8 

1 

1 
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (41 miles from sh

98,214 bbls of crude oil (Volume considering natural weathering) API Gravity 28° 

FIGURE 2 – Equipment Response Time to MC 546, No. SS004 

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 1 1 0DC 3 1200 NA 2 Houma 1 1 0DC 3 1200 NA 2 Houma 1 1 0Aero Commander NA NA 2 Houma 1 1 0

Offshore Response

Offshore Equipment No 

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

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 95’ FRV 12342 249 NA 4 Leeville 1 0 2 95’ FRV 12342 249 NA 4 Venice 1 0 1 46’ FRV 5000 65 NA 4 Venice 1 0 1 Boom Barge (CGA-300) 42” Auto Boom (25000’) NA NA 1 Tug 50 Crew 4 (Barge) 2 (Per Crew) Leeville 4 0 6 

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 2603 NA 25000 1 Tug 6 Amelia 4 12 4 CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 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 
Staging Area: Venice

Offshore Equipment With 

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

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 12.7 FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 1 2 2.1 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 1 2 17.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 8 FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 4.4 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 4.9 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 Hydro-Fire Boom NA NA 8 Utility 40 Harvey 1 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 1 0 2 46’ FRV 5000 65 NA 4 Lake Charles 1 0 2 Trinity SWS 21500 249 NA 4 Leeville 1 2 2 Trinity SWS 21500 249 NA 4 Venice 1 2 2 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 5001 NA 47000 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 Galveston 1 2 12.7 SWS Egmopol 3000 100 NA 3 Morgan City 1 2 4.9 SWS Marco 3588 20 NA 3 Lake Charles 1 2 8 SWS Marco 3588 34 NA 3 Leeville 1 2 4.4 SWS Marco 3588 34 NA 3 Venice 1 2 0 
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 1 2 2.1 Bird Scare Guns (48) NA NA NA 2 Harvey 1 2 2.1 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 12.7 Bird Scare Guns (12) NA NA NA 2 Aransas Pass 1 2 17.7 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 8 Bird Scare Guns (24) NA NA NA 2 Leeville 1 2 4.4 

Response Asset Total 

Offshore EDRC 110,943 

Offshore Recovered Oil Storage 113,363 

Nearshore / Shallow Water EDRC 69,764 

Nearshore / Shallow Water Recovered Oil Storage 93,916 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX J

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 to ensure protection of the environment and 

the facility/equipment.

B. Incidental Takes

Effective Mary 14, 2007, Minerals Management Service revised regulations in 

Title 30 CFR 550, Subpart B to require lessees/operators to provide for 

monitoring systems if the activities provided for in this Plan have the potential to 

result in an incidental take of any federally listed species and/or marine animals.

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 Joint 

NTL 2012-G01 “Vessel Strike Avoidance and Injured/Dead Protected Species 

Reporting”. 

C. Flower Garden Banks National Marine Sanctuary

The activities proposed in this plan are not within the Protective Zones of the 

Flower Garden Banks and Stetson Banks. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX K

LEASE STIPULATION INFORMATION

(30 CFR PART 550.222 AND 550.253) 

Leases OCS-G-25098 Mississippi Canyon Blocks 546 is subject to the following lease 

stipulations and special conditions: 

 

Marine Protected Species

This lease stipulation was implemented to reduce the potential taking of federally 

protected species and referenced measures to minimize or avoid the potential adverse 

impacts to these protected species (sea turtles, marine mammals, gulf sturgeon, and other 

federally protected species). These measures are addressed in the BOEM/BSEE Notice 

to Lessees (NTL):

● Joint NTL 2012- G02 “Implementation of Seismic Mitigation Measures 

and Protected Species Observer Program”,

● Joint NTL 2012 – G01 “Vessel Strike Avoidance and Injured/Dead 

Protected Species Reporting” and,

● Joint NTL 2012 – G01 – “Marine Trash and Debris Awareness and 

Elimination”

A. Special Conditions

● Subsea Completions

LLOG will complete the subject well as subsea completions under this 

Supplemental DOCD. Therefore, LLOG will follow the regulations in 

Title 30 CFR Parts 550.286 through 550.299, which mandates the 

submittal and approval of separate regulatory filings entitles as a 

“Deepwater Operations Plan” and a Conservation Information Document” 

respectively. Both documents have been submitted and will be modified 

accordingly.

● Ocean Current Monitoring 

The proposed operations under this Plan are in water depths greater than 

300 meters (984); therefore, LLOG will follow the guidelines of the 

applicable regulations and NTl 2009-G02 by monitoring and gathering 

ocean data using Acoustic Doppler Current Profile (ADCP) while the 

platform is on location as outlined in the Initial approved DOCD (N-9551) 

for MC 503/547. 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX L

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(30 CFR PART 550.223 AND 550.254) 

A. Mitigation of Impacts

Not applicable. Florida is not an affected State.

B. Incidental Takes

LLOG does not anticipate the incidental taking of any protected species or marine 

mammal as a result of the proposed in this Plan based on the implementation of, 

and adherence to Joint NTL No. 2012-G01 “Marine Trash and Debris Awareness 

Training and Elimination”, “Vessel Strike Avoidance and Injured/Dead Protected 

Species Reporting” and No. 2012-G02 “Implementation of Seismic Survey 

Mitigation Measure and Protected Species Observer Program’. 

 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX M

RELATED FACILITIES AND OPERATIONS INFORMATION

(30 CFR PART 550.256) 

A. Related OCS Facilities and Operations –

The subject subsea well will be equipped with a wellhead and manifold 

connected via existing dual lease term pipelines with associated 

umbilicals/jumpers to the “A” Platform in Mississippi Canyon 547. This is 

an existing manned platform and will process produced hydrocarbons from 

the incoming subsea well for Mississippi Canyon Block 546 Well SS006 

(G-3). 

Install an approximate 70’ long x 6.625 O.D. well jumper at Mississippi 

Canyon 546 Well SS006 (G-3). 

The anticipated combined flow rates and shut in times for the flowlines are as 

follows: 

 

Origination Point Flow Rates Shut In Time

Area/Block Well No. 

MC 546 SS006 (G3)

5000 BOPD 

8.5 MMCFD 

< 20 Minutes 

A. Transportation System

 

LLOG does not anticipate installation of any new/or modified onshore 

facilities to accommodate the production of Mississippi Canyon Block 546. 

 

B. Produced Liquid Hydrocarbon Transportation Vessels 

 Not applicable. All production will flow through pipelines. No transportation 

 vessels will be utilized.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX N

SUPPORT VESSELS AND AIRCRAFT INFORMATION

(30 CFR PART 550.224 AND 550.257) 

A. General

 

The most practical, direct route from the shorebase as permitted by 

weather and traffic conditions will be utilized.

Type Maximum Fuel Tank

Storage Capacity

Maximum No. in Area 

at Any Time

Trip Frequency or 

Duration

Tug Boats 3,000 bbls 1 Rig Moves only

Supply Boats 500 bbls 1 Three Times Weekly

Supply Boats 500 bbls 1 Three Times Weekly

Crew Boats 500 bbls 1 Daily

Aircraft 1,900 gallons 1 As needed

B. Diesel Oil Supply Vessels

Size of Fuel Supply 

Vessel

Capacity of fuel

Supply Vessel

Frequency of Fuel

Transfers

Route Fuel Supply 

Vessel Will Take

180’ OSV 1900 bbls 1/weekly Fourchon Shorebase to

MC 546

 C. Drilling Fluids Transportation

 See Table 2 - Wastes you will transport and/or dispose of onshore

 in Appendix F

D. Solide and Liquid Wastes Transportation

 See Table 2 - Wastes you will transport and/or dispose of onshore

 in Appendix F 

E. Vicinity Map

See Attachment N-1.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

VICINITY MAP

Attachment N-1 

(Public Information)

LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

APPENDIX O

ONSHORE SUPPORT FACILITIES INFORMATION

(30 CFR PART 550.225 AND 550.258) 

A. General

The proposed operations in Mississippi Canyon Block 546 will be located 

approximately 38 miles from the nearest shoreline and 84 miles from the onshore 

support base. 

Name Location Existing/New/Modified

LLOG c/o Turn Key 

Cleaning Service

Fourchon Existing

B. Support Base Construction or Expansion

Not applicable. All bases are existing and will not be modified due to proposed 

operations. 

C. Support Base Construction or Expansion Timetable.

Not applicable. LLOG will utilize and existing shore base and has no plans to 

modify due to proposed operations. 

D. Waste disposal. 

 

 The attached Tables 2 in Appendix G provides information for the onshore facilities that

 will be used to store and dispose of any solid and liquid waste generated by the proposed

 activities 

 
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

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)

Discarded 

Trash & 

Debris

Site Specific at Offshore 

Location

Designated topographic 

features

(1) (1) (1)

Pinnacle Trend area live 

bottoms

(2) (2) (2)

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

Chemosynthetic communities (4)

Water quality X X X

Fisheries X X X

Marine mammals X (8) X X (8) X

Sea turtles X (8) X X (8) X

Air quality X (9)

Shipwreck sites (known or 

potential)

(7)

Prehistoric archaeological sites (7)

Vicinity of Offshore Location

Essential fish habitat X X X (6)

Marine and pelagic birds X X X

Public health and safety (5)

Coastal and Onshore

Beaches X (6) X

Wetlands X (6)

Shorebirds and coastal nesting 

birds

X (6) X

Coastal wildlife refuge

Wilderness areas
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

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 (Low-Relief) Stipulation attached to an OCS lease.

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

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

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. I f 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. I f 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.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

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 Supplemental Development Operations 

Coordination Document 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. A dditional 

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 not 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.

MC 546 is located approximately 105 m iles away from the closest 

designated topographic feature (Sackett Bank); therefore, no a dverse 

impacts are expected during the planned operations. 

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. S ubsurface 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.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

• 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. 

There are no pr oposed surface disturbances within Mississippi Canyon 

Block 546 which is located a significant distance (<100 miles) from the 

closest pinnacle trend live bottom stipulated block. T he crests of these 

pinnacle trend areas are much deeper than 20 m. 

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 operations in Mississippi Canyon Block 546 a re located 

approximately (<100 miles) from the closest Eastern Gulf live bottom 

stipulated block. There are no proposed surface disturbance for operations 

proposed in this plan.. 

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 across the anchor assessment area in Mississippi Canyon 

Block 546 for the proposed wells range from 2312’ to 2929’ below sea 

level. Based on t he water depth, there are no anticipated emissions, 

effluents, emissions physical disturbances to the seafloor, waste sent to 

shore, and/or accidents from the proposed activities that could impact 

these types of communities.
LLOG Exploration Offshore, L.L.C.

Supplemental Development Operations Coordination Document

OCS-G-25098 Lease, Mississippi Canyon Block 546

 

 

• Water Quality 

There are no pr oposed bottom disturbances which may result from the 

proposed operations outlined in this plan. 

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. A s such, it is not anticipated these discharges authorized 

under the approved EPA NPDES permit will cause significant adverse 

impacts to water quality.

Certain waste 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 approved disposal sites 

in accordance with the RERA 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 r elease, 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

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. A s such, it is not anticipated these 

discharges authorized under the approved EPA NPDES permit will cause 

significant adverse impacts to water quality.
LLOG Exploration Offshore, L.L.C.

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Accidental oil spill releases from the proposed activities, and cumulative 

similar discharge activity within the vicinity may potentially cause some 

detrimental effects on fisheries. It is unlikely a spill would occur; however, 

such a release in open waters closed to mobile adult finfish or shellfish would 

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

capability of adult fish and shellfish to avoid a spill, to metabolize 

hydrocarbons, and to excrete both metabolites and parent compounds. 

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

standards for using proven equipment and technology for such responses. 

LLOG would immediately implement its Regional Oil Spill Response Plan 

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 wale, Risso’s dolphin and 

Cuvier’s beaked whale occur most frequently along the upper slop in areas 

outside of anticyclones. 

As a result of the proposed activities, marine mammals should not be 

adversely impacted by the proposed operations outlined in this plan.. 

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

the result of the proposed activities. T he proposed activities will be 

conducted by our company and its contractors under the additional criteria 

addressed by BOEM/BSEE Joint Notice to Lessees (NTL) 2012-G01 

“Vessel Strike Avoidance and Injured/Dead Protective Species” and 

“Marine Trash & Debris Awareness & Elimination” and 2012-G02 

“Implementation of Seismic Survey Mitigation Measures and Protected 

Species Observer Program.

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. 

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. A s 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. A ccidental oil spill releases are 

potential threats which could have lethal effects on turtles. Contact and/or 

consumption of this released material could seriously affect individual sea 

turtles. Most OCS related impacts on sea turtles are expected to be sublethal. Chronic and/or avoidance of affected areas could cause declines in 

survival or productivity, resulting in gradual population declines. 
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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. A s 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 BOEM/BSEE in Joint 

Notice to Lessees (NTL) 2012-G01 “Vessel Strike Avoidance and 

Injured/Dead Protective Species” and “Marine Trash & Debris Awareness 

& Elimination” and 2012-G01 Implementation of Seismic Survey 

Mitigation Measures and Protected Species Observer Program. T he 

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 activate source control and countermeasures to 

minimize these potential impacts.

• Air Quality

The proposed activities are located approximately 38 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. 

• 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 shall 

hazards data indicate there are no know n or potential shipwreck sites 

located within the surveyed area. As such, LLOG does not anticipate any 

IPF’s as a result of the proposed activities in this plan.

 

 
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• 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. A s such, LLOG does not anticipate 

any IPF’s as a result of the proposed activities in this plan. 

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 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.
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• Public Health and Safety

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

accidents from the proposed activities that could cause impacts to the 

public health safety. LLOG has requested BOEM approval to classify the 

proposed objective area as absent of hydrogen sulphide. 

Coastal and Onshore 

• Beaches

As a result of the proposed activities, beaches may be adversely impacted 

by an accidental oil spill. H owever, due to the distance from shore 

(approximately 38 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 2002-052 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. H owever, due to the distance from shore 

(approximately 38 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 2002-052 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.
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• 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 38 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 2002-052 

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. H owever, due to the 

distance from shore (approximately 38 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 2002-052 

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.

• Wilderness Area

As a result of the proposed activities, wilderness areas may be adversely 

impacted by an accidental oil spill. H owever, due to the distance from 

shore (approximately 38 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 2002-052 indicate there is little 

risk of contact or impact to the coastline and associated environmental 

resources.
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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 development 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. A dditionally, the surface located in Mississippi 

Canyon Block 503 ha s 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 NTLs 

2008-G09 and 2009-G10.
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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/preparer of this Plan: 

Nelda Runyon 

LLOG Exploration Offshore, L.L.C. 

1001 Ochsner Blvd., Suite 200 

Covington, Louisiana 70433 

(985) 801-4300 

(985) 801-4389 

neldar@llog.com
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I. References

The following documents were utilized in preparing the Environmental Impact 

Assessment:

Document Author Dated

Shallow Hazards Survey Tesla 2005

3D Geophysi8cal Survey Gardline 2005

BOEMRE Environmental Impact Statement Report No. 2007-

003

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2007

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

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 Sulphide” 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 2007

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2013

Benthic Communities Evaluation, and Archaeological 

Resources Survey

Tesla 2011

Joint NTL 2012-G02 “Implementation of seismic Survey 

Mitigation Measures and Protected Species Observer Program”

BOEM/BSEE 2012

Joint NTL 2012-G01“Marine Trash & Debris Awareness & 

Elimination”

BOEM/BSEE 2012

Joint NTL 2012-G01 “Vessel Strike Avoidance and 

Injured/Dead Protective Species”

BOEM/BSEE 2012
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APPENDIX R

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 bottomhole location information 

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

• New and Unusual Technology 

• Production Rates and Life of Reserves

• Geological and Geophysical Attachments

B. Bibliography

The following documents were utilized in preparing this Plan: 

Document Author Dated

Shallow Hazards Survey Tesla/Gardline 2005

BOEMRE Environmental Impact Statement Report – No. 

2007-003

Bureau of Ocean Energy Management, 

Regulation, and Enforcement

2007

Regional Oil Spill Response Plan LLOG Exploration Offshore, L.L.C. 2013

Benthic Communities Evaluation, and Archaeological 

Resources Survey Tesla 2011

Initial Development Operations Coordination Document

(N-9551) 

LLOG Exploration Offshore, L.L.C. 2010

Revised Exploration Plan (R-5139) LLOG Exploration Offshore, L.L.C 2011

Supplemental DOCD (S-7545) LLOG Exploration Offshore, L.L.C. 2012

Benthic Communities Evaluation, and Archaeological 

Resources Survey Tesla 2012

Shallow Hazards Assessment & Benthic Communities 

Evaluation 

Berger Geosciences 2013

Supplemental DOCD (S-7659) LLOG Exploration Offshore, L.L.C. 2014

Well Assessment MC 546 Tesla 2014

Wellsite Clearance Berger Geosciences 2014