## 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

G25098/MC/546 6277 FNL, 7378 FWL G25098/MC/546 WELL/G-3 Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk Site Type/Name 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 Spec ialist LLOG Exploration Offshore, L.L.C

. (985) 801-4300 Main (985) 801-4389 Direct neldar@llog.com

Dated: September 1  , 2014

### L LOG 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

D OCUMENT
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

APPE NDIX 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

### L LOG 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 5 50.211 AND 5 50.241)

A. Plan Contents

OCS -G-25098 Lease, Mississippi Canyon Block 546 was acquired by Nexen
Petroleu m Offshore U.S.A. Inc. in le ase 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 N o. 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 Offsh ore 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.

### L LOG 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 unit s 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 contr ol, 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 mandat e 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

St orage Tank Type of Facility Tank Capacity (bbls) Number of

Tanks Total Capacity (bbls) Fluid Gravity (API)

Fuel Oil (Marine Diesel) Semi

Submersible 95.24 2 190.5 No. 2 Diesel

43

2917.8 4 11,671.2
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.

### L LOG 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) Devel opment Operations Coordination Document (DOCD)

Company Name: BOEM Operator Number:

Address: Contact Person:

Phone Number:

E-Mail Address:

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



## Project and Worst Case Discharge (WCD) Information

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

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

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

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

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

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

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

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

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



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

Proposed Activity Start Date End Date No. of Days

Exploration drilling

Development drilling

Well completion

Well test flaring (for more than 48 hours)

Installation or modification of structure

Installation of production facilities

Installation of subsea wellheads and/or manifolds

Installation of lease term pipelines

Commence production

Other (Specify and attach description) 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 Ot her (Attach Description)

Drilling Rig Name (If Known): Floating production
system Other (Attach Description)



## Description of Lease Term Pipelines

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



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

## Page 1 of 4

## OCS PLAN INFORMATION FORM ( CONTINUED 

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

## Proposed Well/Structure Location

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

DOCD? Yes No

Is this an existing well

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

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

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

Lease No. OCS OCS OCS

OCS

Area Name

Block No.

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

Lambert XY
coordinates X: X: X:

X:

X:

Y: Y: Y:

Y:

Y:

Latitude/ Longitude Latitude Latitude Latitude

Latitude

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

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



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

Anchor Name

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

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =



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

## Page 2 of 4

### L LOG 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



# Public SURFACE LOCATION G3:
X: 973,618.72 Y: 10,321,402.52
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

Geo: John D 0’ 1000’ 2000’ Surface

Loc G3 

## Y= 10,327,680

Y= 10,311,840X=966,240X=982,080 

### 7,378.72’6,277.48’

### L LOG 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)

### L LOG 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)

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# A PPENDIX B
GENERAL INFORMATION (30 CFR PART 5 50.21 3 AND 5 50.24 3)

A. App lication and Permits

No additional Federal/State applications will be submitted for the activities provided for in this Plan exclusive of the B OEM/BSEE permit applications and general permits issued by the EPA and COE

.



# B. Drilling Fluids

Type of D rilling 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. Pro duction

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

Well Sand Average Pro d

uction

Rate MCFD/BOPD Peak P r odu c

ti

o

n Rate MCFD/BOPD Life of
Reservoir

(Yrs)


# MC 546 SS006 ( G

- 3 )

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# D. Oil Characteristics

The following table de tails the ch em ical and p hysic al charact e ri s tics of the o ils
th a t will be potentia lly pro d uced, handled, transp o rt e d, or sto r ed on/by the fa cility
f rom which the proposed develop m ent and production activit ies wi ll 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.

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# F. Bonding Stateme nt

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 finan cial 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 Of fshore 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 Supp lemental 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 Attach ment 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 SCENA R IO

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

- N06 the following attachment provides a blowout scenario description, information regarding any oil spill, WCD results and assumptions of potential spill and additional measures taken to firstly enhance the ability to prevent a 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 We ll No. 6 (G -3 ) 2 565’ 9 73,618.79 1 0,321,402.52 ’ 89° 25 ’ 33 .499 8 9 ° 04’ 30.025 ”



## INFORMATION REQUIREMENTS

A) Blowout scenario

The MC 546 Well Nos. 6 to be drilled to potent ial outlined in the Geological and Geophysical
Information S ection 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 occurr ing from the objective sand is modeled with no drill pipe or obstructions in the wellbore followed by a failure of the subsea BOP’s and loss of well control at the seabed. 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 9 9 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 p robable 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 situ ation. 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 en sure 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 contain ment / 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 (S e van 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

appr opriate 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. Dynam ically 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 include d 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 / Mult i

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

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

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

• Other ROV Vessels

– (Chouest, HOS, Fugro , Subsea 7 ) Shuttle Tanker / Barge Support • OSG Ship Management

H) Measures taken to enhance ability to prevent 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 f or executing drilling operations of the proposed well or wells to be drilled.

When planning and designing the well, ample time is spent analyzing offset data, performing any
needed earth modeling and identifying any potential drilling hazards or well specific conditions to safeguard the safety of the crews when well construction operations are underway. Once the design criteria and well design is established, the well design is modeled for the lifecycle of the wellbore to ensure potential failure modes are eliminated. Pursuant to BOEM

- 2010

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

.

The proper training of crew members and awareness to identify and handle well control event is the
best wa y prevent a blowout incident. Contractor ’s personnel and service personnel tra ining requirements are verified per regulatory requi r ements per guidelines issued in BOEM

- 2010

- 034
Interim Final Rules

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

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

- spud meetings are conducted with rig crews and service providers to discuss, inform and as needed improve operations and well plans for safety and efficiency considerations. D aily meeting s 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

sec ondary 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 w ellhead 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 r elief we lls 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 productio n manifold within 200’ of the planned surface location.

R elief well site s ha ve 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 p rop osed well.
T he 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 o n actual seafloor state unforeseen at this time, the final location(s) may need to be revised. The location s ha ve 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 * 9 74,835.60 1 0,318,720.20
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 Ac tion 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

• continu e intervention and containment measures

• continue spill control measures

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

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

TOTAL DAYS 1 2 9

## ! ( ! ( !

! ! !



# 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

Missi s sippi 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 Points980,000 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



### 1:24,000 Scale = 10,315,000 N Y = 10,327,680.00

Y = 10,311,840.00X = 966,240.00X = 982,080.0089°5'0"W 

### 28°25'0"N89°5'0"W 

### 28°26'0"N89°4'0"W 

### 28°25'0"N89°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

### L LOG 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 5 50.214 AND 5 50.244)

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. Geo logical Structure Cross

- Sections

Included as Attachment C -4 are interpreted geological str ucture 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 thereport 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.

### L LOG 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

### L LOG Exploration Offshore, L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# GEOLOGICAL DESCRIPTION

Attachment C -1 (Propr ietary Information)

### L LOG 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)

### L LOG 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 )

### L LOG Exploration Offshore, L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# STRUCTURAL CROSS SECTION

Attachme nt C -4 (Proprietary Information )

### L LOG 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

M ississippi Canyon, Block 546 Proposed W ell G3

Project No.: 13-03-22 

# i © Berger Ge osciences, 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 b elow sea level (bsl). The water depth at the proposed well location is 2,569 ft bs l.

• 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 identif y

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 with in 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 hig h-density
benthic communities.

• Pockmarks within the maximum anchor radi us have associated high

- amplitu de seafloor responses and likely represent fluid migration to the seafloor. Chemosynthetic or other high

density benthic communities may be found in association with these pockmarks. However

, features that could support high- density chemosynthetic or ben thic 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 radi us ; however, gas hydrates are not expected within 2,000 ft of the pr oposed
wells.

• The re 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 f or shallow water flow at the proposed well ranges from negligible to high.

### L LOG 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 )

### L LOG 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 5 50.215 AND 5 50.245 )

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 5 46, 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 b een classified in accordance with 30 CRFR 550.490 (c) as “H2S absent”. (Plan S

7563).



# D. Modeling Report

Modeling Report not requir ed as Mississippi Canyon Block 546 has been
classified in accordance with 30 CRFR 550.490 (c) as “H2S absent”.

### L LOG 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 5 50.246)

A. Technology and Reservoir Engineering Practices and Procedures

B. Techn ology and Recovery Practices and Procedures

### L LOG 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 5 50.216 AND 5 50.247)

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 ar e not affected by a topographic feature;



# D Live Bottoms (Pinnacle Trend) Map

Mississippi Canyon Blocks 5 46 is not located within the vicinity of a proposed live bottom (low relief) area.



# E. Live Bottom (Low Relief) Map

Mississippi Canyon Block 5 46 is not located within the vicinity of a proposed live bottom (low relief) area.



# F. Potentially Sensitive Biological Features

Mississippi Canyon Block s 546 is not located within the vicinity of a proposed sensitive biological feature area.

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# G. Rem otel y Operated Vehicle (ROV) Monitoring Survey Pla n

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 Mana gement 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 Pl an.

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
BS EE

- 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.

### L LOG 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,

### L LOG 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
Pr airieville, 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 ‘G 3 ’
Bl ock 546

, Mississippi Canyon Area Archaeological Assessment

Dear Staff:

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

- G 25098 Well ‘ G 3 ’
from the followi ng surface location in Block 546

, Mississippi Canyon Area:

Datum:
NAD 27 Sph eroid:

Clarke 1866 Projection:

UTM Zone:

16

. Central Meridian:

87° 00 ’ West
Latitude: 28° 25’ 3 3

. 499 ” N Longitude: 8 9 ° 04 ’ 30

. 025 ” W

X: 973, 618

. 79 Y: 10,321, 402

. 52

F N L: 6

, 277

. 48 ’ F W L: 7

, 378

. 79 ’

This assessment addresses an anchor radius of 8,000- feet a s 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. 0 4

- 443

- 11 ) ; survey cov erage extended into Blo cks 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. 0 5

- 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 T esla 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 appro ximately 2,565 feet surrounding the proposed drill site. Water depths increase from north we st to south ea st 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 A ssessment 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 loca tion. P&A Well No. 2 (OCS

- G0696 5) 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” pipeline s (Segment s No. 17491 and 17486 ) extend from Well SS001 away from the pro posed 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

- G2509 8) 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 no rthwest. P&A Wells no. 1, 2 (OCS

- G 06965), and 2 (OCS

- G 25098) were installed at the time the original survey data w ere 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 WWI I

- era munitions and unexploded ordnance.

Magnetic data

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

Sonar data indicated that the re are no sonar targets recorded within 2,000’ of the proposed surface location. Targets recorded with in 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 so utheastern 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 u nidentified 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

ne arby 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 5 50.1010(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

### L LOG 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

### L LOG 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 5 50.217 AND 5 50.248)

A. Projected Generated Waste



# ● See Attached Waste Tables

B. P rojected 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 NP DES General Permit
GMG290000.



# E. Cooling Water Intakes

The information at 550.217(e) and 5 50.248(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

### L LOG 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 5 50.218 AN D 5 50.249)

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 c atastrophic 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 Mea sures

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.

### L LOG 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.

.

### L LOG 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)

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# Attachment H -1

Air Emissions Information (§§ 5 50.218 and 5 50.249)

Screening Ques tions 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 de velopment 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 cri teria 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 p roposed 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 installation 6HPLVXEPHUVLEOH5LJ

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 % weightAIR 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
38.0AIR 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

0.0AIR 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

0.0AIR 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

0.0AIR 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 38429.79M/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 m 2 

## 1,676 MT 4,303.97 MT

1,860.96 m 3 

## 1,725.58 m 3


## 295.66 m 3



## 307.28 m 3 

## @ 5.5 bars 1,259.72 m 3



## 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 Water Ballast/Fresh Water Fuel Oil Liquid Mud Auxiliary Dry Bulk Dirty Oil Anti-Roll Potable Water Sewage Void/Cofferdam Wash Water Liquid Mud Cleaning Methanol Fuel Oil Overflow

# M/V JOSHUA CHOUEST M/V JOSHUA CHOUEST

Schematics

DOWN

UPDOWNUP

PANTRY GALLEYCOOLERFREEZER MESS AREA

LOUNGECHANGE ROOM HEAD CASING VENTILATIONHEAD

CASING

VENTILATION

CO
2 LOCKER DECK
STORES HPU ROOM WORKSHOPSTERN ROLLERSTERN ROLLER

DECK
STORES 

# MAIN DECK

UP

STORAGE LKRUP BALLAST FUEL OILVOID POTABLE WATERVOID

BALLAST VOID

VOID HEADLOW VOLTAGECONTROL PANEL FUEL OIL

FUEL OIL LIQUID MUD

DRY BULK

DRY BULK DRY BULKDOWN A/C A/CVOID POTABLE WATERVOID FUEL OIL BALLAST DOWNBALLASTLIQUID MUDCLEANINGSPARE #6SPARE #5GEAR OIL CAT
OIL

DOWNSPARE #1TUNNEL THRUSTERHPU OILMAIN ENGCAT OIL HATCH BALLAST

BALLASTANTI ROLLBALLASTBALLASTBALLASTANTI 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 RECESSVOIDVOID

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

BALLASTSEWAGE BALLASTWASHWATER FUEL OIL FUEL OIL

UP

FUEL OIL FUEL OILVOIDVOIDVOID 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

BALLASTBALLASTBALLASTUPVOID 

# ABOVE TANK TOP

STORAGE CHAIN

LKR

CHAIN

LKRLAUNDRY

LKR

HEAD HEAD

CASING

VENTILATION CLIENT
BEDROOM

HEAD CLIENT
DAY ROOMHEAD HEAD HEAD HEAD

HEAD CASING VENTILATION

LKRDOWN HYDRAULIC
ROOM PAINT LOCKER

LOCKER HYDRAULIC
ROOMUP

DOWN

UP



# DECK 01 CASING VENTILATION

ENG
BEDROOM HEAD HEAD

ENG
DAYROOM

CAPT
DAYROOM

CAPT
BEDROOM HEAD HEAD

CASING VENTILATION HEAD

HOSPITAL

DOWN

UPDOWNUPSCORPION 24WORK VANSCORPION 24CONTROL VANUPSCORPION 24LAUNCH AND RECOVERY SYSTEM



# DECK 02 ELECTRONICS
AREA UP BATTERY
ROOM

UP DOWN

SHIP’S
OFFICE CASINGSTORAGEUPDOWN HVAC ROOM FUEL
OIL

EMERGENCY
GENERATOR ROOM

SWITCHBOARD

UP

CASINGSTORAGE



# DECK 03 DOWN

DOWN DOWN NAV / CONTROL
CENTER CASINGDOWN

CASING HEAD



# DECK 04 DECK 05 DECK 06

# 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 CONSUMED ENDING BALANCE STARTING BALANCE RECEIVED Joshua Chouest

Jan-14

Amos Runner 

### FUEL RECAP SHEET

GAUGED STOCK

ON HAND LIQUID MUD & BULK ABOARD TRANSFERRED

## 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 % weightAIR 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

38.0AIR 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

36.0AIR 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

36.0AIR 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

36.0AIR 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 m3 0 gal 1/15/2014 0 m3 0 gal 1/16/2014 0 m3 0 gal 1/17/2014 0 m3 0 gal 1/18/2014 0 m3 0 gal 1/19/2014 0 m3 0 gal 1/20/2014 0 m3 0 gal 1/21/2014 0 m3 0 gal 1/22/2014 0 m3 0 gal 1/23/2014 0 m3 0 gal 1/24/2014 0 m3 0 gal 1/25/2014 0 m3 0 gal 1/26/2014 0 m3 0 gal 1/27/2014 0 m3 0 gal 1/28/2014 0 m3 0 gal 1/29/2014 0 m3 0 gal 1/30/2014 0 m3 0 gal 1/31/2014 0 m3 0 gal

2/1/2014 0 m3 0 gal 2/2/2014 0 m3 0 gal 2/3/2014 0 m3 0 gal 2/4/2014 0 m3 0 gal 2/5/2014 0 m3 0 gal 2/6/2014 0 m3 0 gal 2/7/2014 0 m3 0 gal 2/8/2014 0 m3 0 gal 2/9/2014 0 m3 0 gal 2/10/2014 0 m3 0 gal 2/11/2014 0 m3 0 gal 2/12/2014 0 m3 0 gal 2/13/2014 0 m3 0 gal 2/14/2014 0 m3 0 gal 2/15/2014 0 m3 0 gal 2/16/2014 0 m3 0 gal 2/17/2014 0 m3 0 gal 2/18/2014 0 m3 0 gal 2/19/2014 0 m3 0 gal 2/20/2014 0 m3 0 gal 2/21/2014 0 m3 0 gal 2/22/2014 0 m3 0 gal 2/23/2014 0 m3 0 gal 2/24/2014 0 m3 0 gal 2/25/2014 0 m3 0 gal 2/26/2014 0 m3 0 gal 2/27/2014 0 m3 0 gal 2/28/2014 0 m3 0 gal

3/1/2014 0 m3 0 gal

## 3/2/2014 0 m3 0 gal 3/3/2014 0 m3 0 gal 3/4/2014 0 m3 0 gal 3/5/2014 0 m3 0 gal 3/6/2014 0 m3 0 gal 3/7/2014 0 m3 0 gal 3/8/2014 0 m3 0 gal 3/9/2014 0 m3 0 gal 3/10/2014 0 m3 0 gal 3/11/2014 0 m3 0 gal 3/12/2014 0 m3 0 gal 3/13/2014 0 m3 0 gal 3/14/2014 0 m3 0 gal 3/15/2014 0 m3 0 gal 3/16/2014 0 m3 0 gal 3/17/2014 0 m3 0 gal 3/18/2014 0 m3 0 gal 3/19/2014 0 m3 0 gal 3/20/2014 0 m3 0 gal 3/21/2014 0 m3 0 gal 3/22/2014 0 m3 0 gal 3/23/2014 0 m3 0 gal 3/24/2014 0 m3 0 gal 3/25/2014 0 m3 0 gal 3/26/2014 0 m3 0 gal 3/27/2014 0 m3 0 gal 3/28/2014 0 m3 0 gal 3/29/2014 0 m3 0 gal 3/30/2014 0 m3 0 gal 3/31/2014 0 m3 0 gal

4/1/2014 0 m3 0 gal 4/2/2014 0 m3 0 gal 4/3/2014 0 m3 0 gal 4/4/2014 0 m3 0 gal 4/5/2014 0 m3 0 gal 4/6/2014 0 m3 0 gal 4/7/2014 0 m3 0 gal 4/8/2014 0 m3 0 gal 4/9/2014 0 m3 0 gal 4/10/2014 0 m3 0 gal 4/11/2014 0 m3 0 gal 4/12/2014 0 m3 0 gal 4/13/2014 0 m3 0 gal 4/14/2014 0 m3 0 gal 4/15/2014 0 m3 0 gal 4/16/2014 0 m3 0 gal 4/17/2014 0 m3 0 gal

## 4/18/2014 0 m3 0 gal 4/19/2014 0 m3 0 gal 4/20/2014 0 m3 0 gal 4/21/2014 0 m3 0 gal 4/22/2014 0 m3 0 gal 4/23/2014 0 m3 0 gal 4/24/2014 0 m3 0 gal 4/25/2014 0 m3 0 gal 4/26/2014 0 m3 0 gal 4/27/2014 0 m3 0 gal 4/28/2014 0 m3 0 gal 4/29/2014 0 m3 0 gal 4/30/2014 0 m3 0 gal

5/1/2014 0 m3 0 gal 5/2/2014 0 m3 0 gal 5/3/2014 0 m3 0 gal 5/4/2014 0 m3 0 gal 5/5/2014 0 m3 0 gal 5/6/2014 0 m3 0 gal 5/7/2014 0 m3 0 gal 5/8/2014 0 m3 0 gal 5/9/2014 0 m3 0 gal 5/10/2014 0 m3 0 gal 5/11/2014 0 m3 0 gal 5/12/2014 0 m3 0 gal 5/13/2014 0 m3 0 gal 5/14/2014 0 m3 0 gal 5/15/2014 0 m3 0 gal 5/16/2014 0 m3 0 gal 5/17/2014 0 m3 0 gal 5/18/2014 0 m3 0 gal 5/19/2014 0 m3 0 gal 5/20/2014 0 m3 0 gal 5/21/2014 0 m3 0 gal 5/22/2014 0 m3 0 gal 5/23/2014 0 m3 0 gal 5/24/2014 0 m3 0 gal 5/25/2014 0 m3 0 gal 5/26/2014 0 m3 0 gal 5/27/2014 0 m3 0 gal 5/28/2014 0 m3 0 gal 5/29/2014 0 m3 0 gal 5/30/2014 0 m3 0 gal 5/31/2014 0 m3 0 gal

6/1/2014 0 m3 0 gal 6/2/2014 0 m3 0 gal

### L LOG 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 pro posed 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 o il 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.

### L LOG 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 Missi ssippi 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 Ho ur 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 Dr illing Drilling Facility Surface Location Mississippi Canyon 503 Mississippi Canyon 546 Facility Description Well No. SS002 Well No.SS00 6 (G3) Distance to Nearest Shore (Miles) 36 Miles 3 8 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

LL OG 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.

### L LOG 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 Mana gement Act analysis, the largest spill volume originating from the proposed activity would be a well bl owout during drilling operations, estimated to be 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 BO EM website. The results are shown in Figure 1.
The BOEM OSRAM identifies an 8% probability of impact to th e shorelines of Plaquemines Parish, Louisiana within 30 days. Plaquemines Parish includes Barataria Bay, the Mississippi River Delta, Breton Sound and th e affiliated islands and bays. This region is an extremely sensitive habitat, and serves as a migratory, breeding, feeding and nursery habitat for numerous species of wildlife. Beaches in this area vary in grain particle size, and can be classified as fine sand, shell or perched shell beaches. Sa ndy and muddy tidal flats are also abundant.

Response

LLOG Exploration Offshore, L.L.C. will make every effort to respond to the Worst Case Discharge as effectively as practicable. A desc ription of the response eq uipment under contract
to contain and recover the Wors t Case Discharge is shown in Figure 2.

Using the estimated chemical and physical charact eristics of crude oil, an ADIOS weathering model was run on a similar product from the ADIO S oil database. The results indicate 10% or approximately 10,913 barrels of crude oil would be evaporated/dispersed w ithin 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, tr avel time to the site and deployment. Figure 2 also indicates how operations will be supported.

LLOG Exploration Offshore, L.L.C.’s Oil Spill Response Plan includes alternative response technologies such as dispersants and in-situ burn. Strategies will be decided by Unified Command based on 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 dail y 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 st orage associated with skimming equipment equals 5,363 barrels. If additi onal storage is needed, a 25,000 barrel storage barge, a 23,000 barrel storage barge, and three 20,000 barrel stor age barges may be m obilized and centrally located to provide temporary storage allowing the sk immers 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. Shorelin e protection would include the use of CGA’s
near shore and shallow water skimmers with a totaled derated sk imming capacity of 69,764 barrels. Temporary storage associated with skim ming equipment equals 916 barrels. If additional storage is needed, a 47,000 barrel storage barg e and two 23,000 barrel storage barges may be mobilized and centrally located to provide temporary storage allowi ng the skimmers to stay in the area of operations as much as possible. On shore response may include the deployment of shoreline boom on beach areas, or protecti on and sorbent boom on vegetated areas. Master Service Agreements with AMPOL and OMI Envir onmental will ensure acc ess 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 potentia l impact given actual sea and weather conditions. The State of Louisiana Initial Oil Spill Respon se 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 O il Spill Response Plan provides detailed shoreline protection strategies for this area, and it describes necessary action to k eep the oil spill from entering Louisiana’s coastal wetlands, base d 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 sc enario, LLOG Exploration Offshore, L.L.C. can be onsite with contracted oil spill recovery equi pment with adequate response capacity to contain and recover surface hydrocarbons, and prevent land impact, to the maximum extent practicable, within an estimated 40 hours (based on the equi pment’s Effective Daily Recovery Capacity (EDRC)).

# Initial Response Considerations Actual actions taken during an oil spill response will be based on many factors 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 acti on to provide a safe, aggressive response to contain and recover as much of the spilled oil as quickly as it is safe to do so. In an effort to protect the environment, response actions will be designed to provide an “in-depth” protection strategy meant to recover as much oil as possible as far from environmentally sensitive areas as possible. Safety will take precedence over all other considerations during these operations.

Coordination of response assets will be supe rvised by the designation of a SIMOPS group as necessary for close quarter vessel response activitie s. Most often, this gr oup will be used during source control events that require a significant nu mber of large vessels operating independently, but in coordination to complete a common objec tive, in a small area and in close coordination and support of each other. This group must also monitor the subsurface activ ities of each vessel (ROV, dispersant application, well control sup port, etc.). The SIMOPS group leader reports to
the Source Control Section Chief.

In addition, these activities will be monitored by the spill mana gement team (SMT) and Unified
Command via a structured Common Operating Picture (COP) esta blished to track resource and
slick movement in real time.

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

• Information will be confirmed

• An assessment will be made and initial objectives set

• OSROs and appropriate agen cies will be notified

• ICS 201, Initial Report Form 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 situa tion and coordinated objectives

o Areas of responsibility esta blished for Source Control a nd each surface operational
site

o On-site command and control established

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

recovery.

Offshore Response Actions

Equipment Deployment
Surveillance

• Surveillance Aircraft will be deployed within two hours of Qu alified Individual (QI) notification, or at first light

• Provide trained observer to pr ovide on site status reports

• Provide command and control platfo rm at the site if needed

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

• Continual monitoring of vessel assets using vessel monitoring systems

Dispersant application assets

• Put 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, ai rcraft, and support equipment and personnel

• Confirm dispersant availability fo r current and long range operations

• Start ordering dispersa nt stocks required for expected operations

Containment boom

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

• Ensure boom handling and mooring equipment is deployed with boom

• Provide continuing 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 aer ial dispersant and in-situ burn operations

# CGA HOSS Barge

• Use in areas with heaviest oil concentrations

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

CGA 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 dr aft 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 boa t acquisition and deployment speeds)

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

• Position as closely as possible to ski mming assets to minimize offloading time

Vessels of Opportunity (VOO)

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

• Industry vessels are usually best for deployment of Vessel of Opportunity Skimming Systems (VOSS)

• Acquire additional resources as needed

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

• Expect mission specific and sa fety training to be required

• Plan with the US Coast Guard for vessel inspections

# In-situ Burn assets

• Determine appropriateness of in-situ burn ope ration 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 depl oy in accordance with planning based on the actual situation, actual traj ectories 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 Re sponse 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 directi ng systems to observed oil slicks

VOO

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

• Industry vessels are usually best for deployment of Vessel of Opportunity Skimming Systems (VOSS)

• Acquire additional resources as needed

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

• Expect mission specific and sa fety training to be required

• Plan with the US Coast Guard for vessel inspections

• Operate with aerial spotter directing systems to oil patches

# Shoreline Protection Operations

Response Planning Considerations

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

• Time to acquire personnel and eq uipment and their availability

• Previous contingency planning contained in the appropriate Area Contingency Plan, and currently for Louisiana, The State of Loui siana 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 site s and gaining authority to enter

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

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

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

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

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

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

• Passive clean up of marshes should be consider ed and appropriate stoc ks of sorbent boom and/or sweep obtained

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

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

recovery.

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

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

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

OSRV 4 foot seas

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

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

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

# FIGURE 1
TRAJECTORY BY LAND SEGMENT

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

Area/Block OCS-G Launch

Area Land Segment and/or

Resource Conditional Probability (%) within 30 days

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

1WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(41 miles from shore)98,214 bbls of crude oil (Volume considering natural weathering)API Gravity 28°FIGURE 2 – Equipment Response Time to MC 546, No. SS004Dispersants/SurveillanceDispersant/SurveillanceDispersantCapacity (gal)StorageCapacityPersons Req.FromHrs toProcureHrs toLoadoutTravel tositeTotal HrsASIBasler 67T2000 NA2Houma1 1 0.62.6DC 31200 NA2Houma1 1 0.82.8DC 31200 NA2Houma1 1 0.82.8Aero CommanderNA NA2Houma1 1 0.62.6Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsHOSS Barge43000 4000 3 Tugs 5Harvey 7 055 1 1895’ FRV12342 249 NA 4Leeville 1 023.4 0 6.495’FRV12342 249 NA 4 Venice 1 0 1 1.6 0 3.646’FRV5000 65 NA 4 Venice 1 0 1 1.6 0 3.6Boom Barge (CGA-300)42” Auto Boom (25000’)NA NA1 Tug50 Crew4 (Barge)2 (Per Crew)Leeville 4 0 6 12.1 1.5 23.6Recovered Oil Storage NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsEnterprise Marine Services LLC (available through contract with CGA)CTCo 2603NA 25000 1 Tug 6Amelia 4 12 4 18.75 1 39.75CTCo 2604NA 20000 1 Tug 6Amelia 4 12 4 18.75 1 39.75CTCo 2605NA 20000 1 Tug 6Amelia 4 12 4 18.75 1 39.75CTCo 2606NA 20000 1 Tug 6Amelia 4 12 4 18.75 1 39.75CTCo 2607NA 23000 1 Tug 6Amelia 4 12 4 18.75 1 39.75Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravel toSiteHrs toDeployTotalHrsFRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 12.7 3.3 1 20FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6Harvey 1 2 2.1 3.3 1 9.4FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 1 2 17.7 3.3 1 25FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 283.3 1 15.3FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 4.4 3.3 1 11.7FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 4.9 3.3 1 12.2FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 203.3 1 7.3Hydro-Fire BoomNA NA 8 Utility40 Harvey 1 4 2.1 3.3 6 16.4Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGA46’ FRV5000 65 NA 4 Morgan City 1 0 22 0 546’ FRV5000 65 NA 4 Lake Charles 1 0 23 0 6Trinity SWS21500 249 NA 4Leeville1 2 22 0 7Trinity SWS21500 249 NA 4Venice1 2 22 0 7Enterprise Marine Services LLC (available through contract with CGA)CTCo 2608NA 23000 1 Tug 6Amelia4 12 415 1 36CTCo 2609NA 23000 1 Tug 6Amelia4 12 415 1 36CTCo 5001NA 47000 1 Tug 6Amelia4 12 415 1 36Staging Area: VeniceNearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGASWS Egmopol3000 100 NA 3 Galveston 1 2 12.72017.7SWS Egmopol3000 100 NA 3 Morgan City 1 24.9209.9SWS Marco3588 20 NA 3 Lake Charles 1 282013SWS Marco3588 34 NA 3Leeville1 24.4209.4SWS Marco3588 34 NA 3Venice1 20205Shoreline ProtectionStaging Area: VeniceShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeployment SiteHrs toDeployTotal HrsAMPOL (available through MSA)42,000’ 18” Boom 16 Crew 40New Iberia, LA2 2 62122420,000’ 18” Boom 8 Crew 20New Orleans, LA2 2 2.22614.2OMI Environmental (available through MSA)10,000’ 18” Boom 4 Crew 10New Iberia, LA1 1 6231310,000’ 18” Boom 4 Crew 10Houston, TX1 1 12.12319.110,000’ 18” Boom 4 Crew 10Port Arthur, TX1 1 9.72316.720,000’ 18” Boom 8 Crew 20Belle Chasse, LA1 1 1.92611.910,000’ 18” Boom 4 Crew 10Port Allen, LA1 1 4.52311.510,000’ 18” Boom 4 Crew 10Houma, LA1 1 3.82310.815,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.12412.1Wildlife ResponseEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGAWildlife Support TrailerNA NA NA 2Harvey1 22.1128.1Bird Scare Guns (48)NA NA NA 2Harvey1 22.1128.1Bird Scare Guns (12)NA NA NA 2 Galveston 1 2 12.71218.7Bird Scare Guns (12)NA NA NA 2 Aransas Pass 1 2 17.71223.7Bird Scare Guns (24)NA NA NA 2 Lake Charles 1 281214Bird Scare Guns (24)NA NA NA 2Leeville1 24.41210.4Response AssetTotalOffshore EDRC110,943Offshore Recovered Oil Storage113,363Nearshore / Shallow Water EDRC69,764Nearshore / Shallow Water Recovered Oil Storage 93,916

### L LOG 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 5 50.221 AND 5 50.252)

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 hurrican es 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 personn el 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 s pecies as a result of the proposed activities based on the implementation of, and adherence to, the Joint

NTL 20 12- G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”.



# C. Flower Garden Banks National Marine Sanctuary

The activitie s proposed in this plan are not within the Protective Zones of the
Flower Garden Banks and Stetson Banks.

### L LOG 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 5 50.22 2 AND 5 50.25 3)

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 impact s 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 20 12- G02 “Implementation of Seismic Mitigation Measures and Protected Species Observer Program”,

● Joint NTL 20 12 – G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting” and,

● Joint NTL 20 12 – G0 1 – “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, w hich 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.

### L LOG 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 5 50.22 3 AND 5 50.25 4)

A. Mitigation of Impacts

Not applic able. 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 Awarene ss 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’

.

### L LOG 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 5 50.256 )

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)

.

Instal l 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

v essels will be utilized.

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# A PPENDIX N
SUPPORT VESSELS AND AIRCRAFT INFORMATION (30 CFR PART 5 50.22 4 AND 5 50.25 7)

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 5 46



# 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.

### L LOG 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)

### L LOG 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 5 50.22 5 AND 5 50.25 8)

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

### L LOG 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 5 50.227 and 5 50.261)

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

The following matrix is utilized to identify the affected environments that could be impacted by these IPF’s. An “x” has been marked for each IPF
categ ory 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, anc hor,

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

### L LOG 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 th at 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 zo ne 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 b lock 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 act ivities 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.

### L LOG 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 pr oposed 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 traject ory 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 arra ngements 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 propose d 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 cr ests 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 topogra phic 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.

### L LOG 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 t han 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 anticipat ed 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 r e 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. B ased 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.

### L LOG 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
temp orary 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 an d 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 ce rtain 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.

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# 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 o r 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 unanticip ated 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 an d 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 par ameters 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.

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

OCS -G- 25098 Lease, Mississippi Canyon Block 546 

# 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 Prote cted Species Observer Program.

The proposed operations will be conducted in accordanc e 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 limitati ons, 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 w ill 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. Drillin g 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 sub

lethal. 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 an d 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

act ivities 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 plac ards 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 i mplement 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 activit ies 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 archaeologi cal 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 a nd 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 industr y 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 B irds

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 appro val 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 (appr oximately 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 accid ental 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 calculatio ns 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 standard s 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.

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

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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
dista nce from shore (approximately 38 miles) and the response capabilities that would be implemente d, 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

as sociated 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 an d 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
distan ce 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 dista nce 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.

### L LOG Exploration Offshore , L.L.C. Supplemental Development Operations Coordination Document

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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.

O ther 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 throu ghout 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 stat us 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 di d 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 tho se 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 G ardline 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, Regulatio n, 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 Ocea n 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 “Guidel ines 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, a nd 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 Oc ean 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 Documen ts” 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” B ureau 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 Specie s 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

(3 0 CFR PART 5 50. 228 and 5 50.262)



# A. Exempted Information Description (Public Information Copies Only)

Excluded from the Public Information copies are the following:

• Proposed 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 Au thor 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 201 1 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