UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of DOCD

Control # - S-07672

Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS-G16764 Block - 609 Green Canyon Area

OCS-G16765 Block - 610 Green Canyon Area

OCS-G20084 Block - 653 Green Canyon Area

Operator - BHP Billiton Petroleum (GOM) Inc.

Drill, Complete H-A, H-FGt, H-H, H-B, C-A

%SJMMTIJQ

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

G20084/GC/653

G20084/GC/653

G16765/GC/610

G16765/GC/610

G16765/GC/610

G20084/GC/653

G20084/GC/653

G20084/GC/653

G16764/GC/609

4849 FNL, 251 FWL

4808 FNL, 251 FWL

1173 FSL, 518 FWL

1144 FNL, 655 FWL

1144 FSL, 655 FWL

1173 FSL, 518 FWL

1180 FSL, 478 FWL

1181 FSL, 478 FWL

1173 FSL, 518 FWL

G20084/GC/653

G20084/GC/653

G16765/GC/610

G16765/GC/610

G16765/GC/610

G16765/GC/610

G16765/GC/610

G16765/GC/610

G16765/GC/610

WELL/C-A

WELL/C-ALT

WELL/H-A

WELL/H-B

WELL/H-B

WELL/H-FG

WELL/H-FGT

WELL/H-FGT

WELL/H-H

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

Description -

Rig Type -

Subject:

From:

October 3, 2014

bhpbilliton 

BHP Billiton Petroleum (GOM) Inc. 

1360 Post Oak Boulevard Suite 150 

Houston Texas 77056-3020 USA 

Tel 713 961 8500 Fax 713 499 5994 

www.bhpbilliton.com 

Aprils, 2014 

Ms. Ann Glazner 

Deputy Regional Supervisor for Leasing and Plans 

U.S. Department of the Interior 

Bureau of Ocean Energy Management 

1201 Elmw/ood Park Boulevard 

New Orleans, LA 70123-2394 

ATTN: Plans Unit 

RE: Supplemental Unit Development Operations Coordination Document (DOCD) 

Green Canyon 654 Unit (Agreement No. 754307012) 

Lease OCS-G 16764,16765 and 20084 

Green Canyon Area, Blocks 609, 610, 652 and 653 

OCS Federal Waters, Gulf of Mexico, Offshore, Louisiana 

Gentlemen: 

In accordance with the provisions of Title 30 CFR, Parts 250 and 550, Subpart B and further defined in 

Notice to Lessees (NTL) 2009-G27 and 2008-G04 (extended by NTL 2014-G03), clarifying the 

information requirements for Exploration Plans and Development Operations Coordination Documents on 

the OCS, BHP Billiton Petroleum (GOM) Inc. (herein referred to as 'BHPB') hereby submits for your 

review and approval a Supplemental DOCD for the above referenced Unit. 

Enclosed are two (2) hard copies (One for Public Information and One for Proprietary Data) with one (1) 

CD for each. The State of Louisiana CZM does not require a review at this time. 

Under this Supplemental DOCD BHPB proposes to supplement the Initial DOCD Plan No, N-9001 by 

drilling five (5) additional wells, installing associated jumpers and commencing production in the above 

referenced Unit. 

BHPB anticipates commencing drilling operations on July 1, 2015. 

Should additional information be required, please contact the undersigned at 713.599.6349. Please 

forward all approval documents to susan.wilson@bhpbilliton.com. 

Sincerely, 

Susan Wilson 

Senior Regulatory Specialist 

SW:KC 

Enclosures 

PUBLIC INFORMATION COPY
TABLE OF CONTENTS

SECTION 1:

CONTENTS OF PLAN ................................................................................................................................1

Plan Information Form ................................................................................................................................ 3

Bathymetry Map and Location Plat............................................................................................................. 3

Safety and Pollution Prevention Features................................................................................................... 3

Storage Tanks and Production Vessels........................................................................................................ 4

Service Fees  ................................................................................................................................................ 4

Pollution Prevention Measures to Prevent Discharge of Oils and Greases during Rainfall and Routine

Operations................................................................................................................................................... 5

Safety, Pollution Prevention and Early Spill Detection Measures............................................................... 5

SECTION 2:

GENERAL INFORMATION.........................................................................................................................6

Applications and Permits............................................................................................................................. 6

Drilling Fluids............................................................................................................................................... 6

Peak Production Rates / Life of Reserves.................................................................................................... 6

Oil Characteristics........................................................................................................................................ 7

New or Unusual Technology ....................................................................................................................... 8

Bonding Information ................................................................................................................................... 8

Oil Spill Financial Responsibility (OSFR)....................................................................................................... 8

Deepwater Well Control Statement  ........................................................................................................... 8

Suspensions of Production .......................................................................................................................... 9

Blowout Scenario  ........................................................................................................................................ 9

Chemical Products  .................................................................................................................................... 12

SECTION 3:

GEOLOGICAL AND GEOPHYSICAL INFORMATION................................................................................... 13

Geological Description  .............................................................................................................................. 13

Structure Contour Maps  ........................................................................................................................... 14

Interpreted 2‐D or 3‐D Seismic Lines  ........................................................................................................ 14

Geological Structure Cross‐Sections  ......................................................................................................... 14

Shallow Hazards Report  ............................................................................................................................ 14

Site Specific Shallow Hazards Assessment  ............................................................................................... 15

High Resolution Seismic Lines  .................................................................................................................. 15

PUBLIC INFORMATION COPY
Stratigraphic Column  ................................................................................................................................15

Time Versus Depth Table  .......................................................................................................................... 15

Geochemical Information  ......................................................................................................................... 15

Future G&G Activities  ............................................................................................................................... 15

SECTION 4:

HYDROGEN SULFIDE INFORMATION  ..................................................................................................... 16

Concentration  ........................................................................................................................................... 16

Classification Request  ............................................................................................................................... 16

Contingency Plan  ...................................................................................................................................... 16

Modeling Report  ....................................................................................................................................... 16

SECTION 5:

MINERAL AND RESOURCE CONVERSATION INFORMATION  ................................................................... 17

Technology and Reservoir Engineering Practices and Procedures  .......................................................... 17

Technology and Recovery Practices and Procedures  ............................................................................... 17

Reservoir Development  ............................................................................................................................ 17

SECTION 6:

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION  ............................................................. 18

Chemosynthetic Communities Report  ..................................................................................................... 18

Topographic Features Map ....................................................................................................................... 18

Topographic Features Statement   ............................................................................................................ 18

Live Bottom (Pinnacle Trend) Map  ........................................................................................................... 18

Live Bottom (Low Relief) Map  .................................................................................................................. 18

Potentially Sensitive Biological Features  .................................................................................................. 18

ROV Monitoring Survey Plan  .................................................................................................................... 18

Threatened and Endangered Species Information  ................................................................................... 19

Archaeological Report  .............................................................................................................................. 20

Air and Water Quality Information   .......................................................................................................... 20

Socioeconomic Information  ..................................................................................................................... 20

SECTION 7:

WASTE AND DISCHARGE INFORMATION  ............................................................................................... 21

Projected Generated Wastes  ................................................................................................................... 21

Projected Ocean Discharges  ..................................................................................................................... 21

Modeling Report  ....................................................................................................................................... 21

NPDES Permits   ......................................................................................................................................... 21

PUBLIC INFORMATION COPY
Cooling Water Intakes  .............................................................................................................................. 21

SECTION 8:

AIR EMISSIONS INFORMATION  ............................................................................................................. 22

Screening Checklist  ................................................................................................................................... 22

Summary Table(s) of Plan Emissions......................................................................................................... 22

SECTION 9:

OIL SPILL INFORMATION  ....................................................................................................................... 23

Site Specific OSRP ...................................................................................................................................... 23

Regional or Sub‐Regional OSRP Information............................................................................................. 23

Spill Response Sites................................................................................................................................... 23

OSRO Information ..................................................................................................................................... 24

Worst Case Scenario Determination ......................................................................................................... 24

NTL 2010‐NO6‐ WCD Calculations Overview ............................................................................................ 24

Oil Spill Response Discussion / NEPA Analysis .......................................................................................... 24

Modeling Report........................................................................................................................................ 24

SECTION 10:

ENVIRONMENTAL MONITORING INFORMATION  .................................................................................. 25

Monitoring Systems  .................................................................................................................................. 25

Incidental Takes......................................................................................................................................... 25

Flower Garden Banks National Marine Sanctuary  ................................................................................... 25

SECTION 11:

LEASE STIPULATIONS INFORMATION  .................................................................................................... 26

SECTION 12:

ENVIRONMENTAL MITIGATION MEASURES INFORMATION  .................................................................. 27

Impacts to Marine & Coastal Environments & Habitats, Biota, and Threatened & Endangered Species  27

Incidental Takes......................................................................................................................................... 27

SECTION 13:

DECOMMISSIONING INFORMATION  ..................................................................................................... 28

SECTION 14:

RELATED FACILITIES AND OPERATIONS INFORMATION  ......................................................................... 29

Related OCS Facilities and Operations  ..................................................................................................... 29

Transportation System  ............................................................................................................................. 29

Produced Liquid Hydrocarbons Transportation Vessels  .......................................................................... 29

SECTION 15:

SUPPORT VESSELS AND AIRCRAFT INFORMATION  ................................................................................ 30

PUBLIC INFORMATION COPY
General ...................................................................................................................................................... 30

Diesel Oil Supply Vessels  .......................................................................................................................... 30

Drilling Fluids Transportation  ................................................................................................................... 30

Solid and Liquid Wastes Transportation.................................................................................................... 30

Vicinity Map  .............................................................................................................................................. 31

SECTION 16:

ONSHORE SUPPORT FACILITIES INFORMATION  ..................................................................................... 32

General  ..................................................................................................................................................... 32

Support Base Construction or Expansion.................................................................................................. 32

Support Base Construction or Expansion Timetable  ................................................................................ 32

Air Emissions  ............................................................................................................................................. 32

Unusual Solid and Liquid Wastes  .............................................................................................................. 32

Waste Disposal  ......................................................................................................................................... 32

SECTION 17:

SULPHUR OPERATIONS INFORMATION  ................................................................................................. 33

SECTION 18:

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION  ................................................................. 34

Consistency Certification  .......................................................................................................................... 34

Other Information ..................................................................................................................................... 34

SECTION 19:

ENVIRONMENTAL IMPACT ANALYSIS (EIA)  ........................................................................................... 35

Impact Producing Factors (IPFs) from the Proposed Activities  ................................................................ 35

Analysis  ..................................................................................................................................................... 36

Environmental Hazards  ............................................................................................................................ 43

Alternatives ............................................................................................................................................... 44

Mitigation Measures  ................................................................................................................................44

Consultation  ............................................................................................................................................. 44

Preparer(s)  ................................................................................................................................................ 44

References  ................................................................................................................................................ 45

PUBLIC INFORMATION COPY
SECTION 20:

ADMINISTRATIVE INFORMATION  ......................................................................................................... 46

Exempted Information Description (Public Information Copies Only)  ..................................................... 46

Bibliography  .............................................................................................................................................. 46

Plan Attachments 

Attachment A Plan Information Forms 

Attachment B Well Location Maps 

Attachment C Bathymetry Map 

Attachment D Pay.gov Service Fee 

Attachment E PROPRIETARY DATA 

Attachment F PROPRIETARY DATA 

Attachment G PROPRIETARY DATA 

Attachment H Solid and Liquid Wastes Transportation 

Attachment I Air Emissions 

Attachment J NEPA / Oil Spill Response Discussion 

Attachment K Subsea Tree Drawing 

Attachment L Vicinity Map 

Attachment M Worst Case Discharge 

 

 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 1 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Supplemental Unit Development Operations Coordination Document (DOCD) 

For 

Green Canyon 654 Unit, Agreement No. 754307012 

Blocks 609, 610, 653 and 654 

Leases OCS-G 16764, 16765, 20084 and 20085 

Offshore Louisiana

SECTION 1 - CONTENTS OF PLAN 

Under this Supplemental DOCD BHP Billiton Petroleum (GOM) Inc. (herein referred to as BHPB) is 

submitting the following information as a Supplement to the Initial DOCD (Control No. N-9001) granted to 

BHPB on September 18, 2007. 

The following is a history of the wells approved under the Initial Plan N-9001 and Supplemental Plans S7446, S-7487, S-7573 and S-7616: 

Initial DOCD – Plan N-9001 – approved September 18, 2007 

Well Name Complete Date Production Start 

Date Status 

B1-1 9/26/2011 9/30/2011 Producing 

B1-2 12/31/2001 3/23/2009 Producing 

B1-3 See Status 09/13/2009 Re-named / drilled as SC102 

B2-1 05/26/2011 05/30/2011 Producing 

B2-3 7/6/2009 09/08/2009 Producing 

C1-3 See Status See Status See Plan S-7487 

C1-4 11/1/2008 07/13/2009 Producing 

G1-1 1/29/2008 03/26/2009 Producing 

G1-2 4/12/2008 03/30/2009 Producing 

G1-3 12/19/2008 04/06/2009 Producing 

G1-4 9/18/2009 09/28/2009 Producing 

G2-3 See Status 04/08/2009 Re-named / drilled as SB202 

G2-4 See Status 03/27/2009 Re-named / drilled as SB204 

Supplemental DOCD – Plan S-7446 – approved February 3, 2011 

Well Name Complete Date Production Start 

Date Status 

WI001 6/8/2011 05/08/2012 Injecting 

WI002 8/9/2012 9/9/2012 Injecting 

WI003 8/12/2013 10/18/2013 Injecting 

Supplemental DOCD – Plan S-7487 – approved November 17, 2011 

Well Name Complete Date Production Start 

Date Status 

SC103 05/29/2013 01/20/2014 Producing 

SH101 06/08/2012 06/12/2012 Producing 

SH102 11/15/2013 11/24/2013 Producing 

SH103 See Status See Status Not drilled yet 

SH103 ST01 See Status See Status Not drilled yet 

SH103 ST01 See Status See Status Not drilled yet 

SH104 See Status See Status Not drilled yet 

Supplemental DOCD – Plan S-7573 – approved November 11, 2012 

Well Name Complete Date Production Start 

Date Status 

WI-A (WI004) 3/27/2013 3/30/2013 Injecting 

WI-B See Status See Status Not drilled yet 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 2 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Supplemental DOCD – Plan S-7616 – approved November 20, 2013 

Well Name Complete Date Production Start 

Date Status 

SB103 Presently Completing See Status CRL on Location 

SB104 See Status See Status Not drilled yet 

Supplemental DOCD – Plan S-7667 (In Review) 

Well Name Complete Date Production Start 

Date Status 

WI-C thru WI-J Pending Pending Pending 

Under this Supplemental DOCD, BHPB proposes the following: 

 Directionally drill and complete subsea Wells H-A, H-B, H-FG and H-H adjacent to the existing 

sled and manifold at Drill Center H in Block 610 

 Directionally drill and complete subsea Well C-A adjacent to the existing sled and manifold at Drill 

Center C in Block 653 

 Well Jumpers will be installed at each successful well 

 Commence production on the first well by November 1, 2015 

 NOTE: BHPB is requesting approval for two (2) additional wells (to be designated H-FGt and CAlt) to be used as “respud” wells in the event an issue arises during drilling of the H-A, H-B, HFG, H-H or C-A well locations. 

Proposed

Locations

Block Latitude Longitude Easting

X (feet)

Northing

Y (feet)

Block Calls

(feet)

H-A (PSL) 

H-A (PBHL) 

GC 610 27° 20’ 32.856” N 90° 05’ 52.554” W 2,582,438.31 9,932,853.37 1173 FSL 518 FWL 

H-B (PSL) 

H-B (PBHL 

GC 610 27° 20’ 32.534” N 90° 05’ 51.041” W 2,582,575.54 9,932,824.02 1144 FSL 656 FWL 

H-FG (PSL) 

H-FG(PBHL) 

GC 610 27° 20’ 32.856” N 90° 05’ 52.554” W 2,582,438.31 9,932,853.37 1173 FSL 518 FWL 

H-FGt (PSL) 

H-FGt(PBHL) 

(respud) 

GC 610 27° 20’ 32.946” N 90° 05’ 52.997” W 2,582,398.13 9,932,861.55 1182 FSL 478 FWL 

H-H (PSL) 

H-H (PBHL 

GC 610 27° 20’ 32.856” N 90° 05’ 52.554” W 2,582,438.31 9,932,853.37 1173 FSL 518 FWL 

C-A (PSL) 

C-A (PBHL) 

GC 653 27° 19’ 36.939” N 90° 08’ 52.533” W 2,566,331.39 9,926,830.22 4850 FNL 251 FWL 

C-Alt 

(respud) 

GC 653 27° 19’ 37.349” N 90° 08’ 52.522” W 2,566,331.39 9,926,871.68 4808 FNL 251 FWL 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 3 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(a) Plan Information Form 

 

An OCS Plan Information Form (BOEM-137) with details of the proposed drilling and completion 

operations and jumper(s) installation along with BHPB’s tentative schedule leading up to commencement 

of production is included as Attachment A. 

The proposed wells will be drilled with a DP drillship (Invictus or CR Luigs) using subsurface BOPs. 

There will be no anchors associated with the operations proposed in this Plan. 

(b) Bathymetry Map and Location Plat 

The Well Location Plats along with a Bathymetry Map are included as Attachments B and C, 

respectively. The location plats illustrate the existing and proposed surface and bottomhole locations of 

the wells addressed in this Plan. 

BHP Billiton proposes to utilize dynamically-positioned drilling vessels; therefore, there will be no anchors 

associated with this activity. 

(c) Safety and Pollution Prevention Features 

The proposed wells addressed in this Plan will be drilled with a DP drillship (Invictus or CR Luigs) using 

subsurface BOPs. 

Safety features on the MODU will include well control, pollution prevention, welding procedure, and 

blowout prevention equipment as described in the following Federal Register Notices, Notice to Lessees 

(NTL) and Subparts located in Title 30 CFR Part 250 and 550: 

 Federal Register, Vol. 77, No. 163, August 22, 2012, Final Rule for Increased Safety Measures 

for Energy Development on the Outer Continental Shelf 

 Federal Register, Vol. 75, No. 198, October 14, 2010, Final Rule for Increased Safety Measures 

for Energy Development on the Outer Continental Shelf 

 NTL 2010-N06 for Information Requirements for Exploration Plans, Development and Production 

Plans, and Development Operations Coordination Documents on the OCS 

 NTL 2010-N10 for Statement of Compliance with Applicable Regulations and Evaluation of 

Information Demonstrating Adequate Spill Response and Well Containment Resources 

These regulations may be further clarified by Safety Alerts, and current policy making invoked by the 

Bureau of Ocean Energy Management, Regulation and Enforcement (BOEM), Environmental Protection 

Agency (EPA) and the U.S. Coast Guard (USCG). 

The appropriate life rafts, life jackets, ring buoys, etc., as prescribed by the U.S. Coast Guard will be 

maintained on the MODU at all times. 

BSEE is required to conduct 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. 

BSEE also inspects the stockpiles of equipment listed in the Operator's approved Regional Oil Spill 

Response Plan that would be used for the containment and cleanup of hydrocarbon spills and is further 

addressed in the “Oil Spill Information” section of this Plan. 

In accordance with Title 30 CFR 250.1501, the goal of our training program is safe and clean OCS 

operations. To accomplish this, BHPB ensures that our employees and contractor personnel engaged in 

well control understand and can properly perform their duties. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 4 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Supervisory and certain designated personnel on-board the facility are to be familiar with the effluent 

limitations and guidelines for overboard discharges into the receiving waters, as outlined in the EPA’s 

NPDES General Permit GMG290000. Some of these pollution prevention measures include installation of 

curbs, gutters, drip pans, and drains on drilling deck areas to collect all contaminants and debris. 

All discharges related to the operations proposed in this Plan are covered under EPA’s NPDES General 

Permit referenced above. BHPB’s permit number is GMG290184. 

(d) Storage Tanks and Production Vessels 

Tanks with a capacity of 25 bbls or more of oil as defined at 30 CFR 254.6 is listed below: 

Type of Storage 

Tank Type of Facility Tank Capacity (bbls) 

Number of 

Tanks 

Total Capacity 

(bbls) 

Fluid Gravity 

(API)

Lube Oil Tank P / S Drillship – CRL 661 2 1322 29-39o 

Dirty Oil Tank AFT Drillship – CRL 296 1 296 29-39o 

Dirty Oil Tank FWD Drillship – CRL 69 1 69 29-39o 

Diesel Oil Drillship – CRL 

8549(2); 7906(2); 

3736(2); 2665(2); 

290(2); 775(4) 

1 49,392 30 - 45 o

Base Oil Drillship – CRL 3541 1 3541 45o 

Type of Storage 

Tank Type of Facility Tank Capacity (bbls) Number of Tanks 

Total Capacity 

(bbls) 

Fluid Gravity 

(API)

Lube Oil Tank P / S Drillship – Invictus 371; 123; 183; 164 4 84 29-39 o 

Dirty Oil Tank Drillship – Invictus 48; 658; 243 3 949 29-39o 

Diesel Oil Drillship – Invictus 

14,960; 14,268(2); 

1,336; 1,413(2); 

1,336; 1,145(2) 

9 51,28 30-45o

Base Oil Drillship – Invictus 5,058; 398 2 5,45 45 o 

(e) Service Fees 

In accordance with 30 CFR 250.125 (a) BHPB has used the following table showing the fees that must be 

paid to BOEM for the activity proposed in this Plan. The fees will be adjusted periodically according to 

the Implicit Price Deflator for Gross Domestic Product by publication of a document in the Federal 

Register. If a significant adjustment is needed to arrive at the new actual cost for any reason other than 

inflation, then a proposed rule containing the new fees will be published in the Federal Register for 

comment. 

Service Fee Table 

Service — processing of the following: Fee amount 30 CFR citation 

Supplemental Development Operations 

Coordination Document (DOCD) 

$4,238 per well §550.241(e) 

A copy of the receipt for payment of the above referenced fee(s) accompanies the submission of this 

document as Attachment D. It is our understanding that once a fee is paid, it is nonrefundable, even if 

an application or other request is withdrawn. If our application is returned as incomplete, we are not 

required to submit a new fee if and when we submit an amended application. 
BHP Billiton Petroleum (GOM) Inc. 5 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(f) Pollution Prevention Measures to Prevent the Discharge of Oils and Greases 

during Rainfall and Routine Operations 

Supervisory and certain designated personnel on-board the MODU and / or the facility are to be familiar 

with the effluent limitations and guidelines for overboard discharges into the receiving waters, as outlined 

in EPA’s NPDES General Permit GMG290000. 

Some of these pollution prevention measures include installation of curbs, gutters, drip pans, and drains 

to collect all contaminants and debris to prevent the discharge of oils and greases from drilling rigs or 

platforms during rainfall and routine operations. 

BHPB will utilize the best management practices available for ensuring all operations are performed in a 

safe and workmanlike conduct in accordance with 30 CFR 250.107 and will ensure that our employees 

and contractor personnel engaged in our offshore drilling operations understand the state and federal 

regulations. 

All discharges related to the operations proposed in this Plan are covered under EPA’s NPDES General 

Permit referenced above. BHPB’s permit number is GMG290184. 

(g) Safety, Pollution Prevention, and Early Spill Detection Measures

In accordance with the provisions of Title 30 CFR Parts 254.2(b), 254.23, 254.24, 254.25 and 254.26(d) 

and as further defined by Notice to Lessees (NTL) 2010-N10, BHPB submitted for review and BOEM has 

accepted a proposed Containment Plan which outlines the response to a complete loss of well control. 

BHPB is a member of the Marine Well Containment Company (MWCC). At this time, MWCC is the 

containment response system of choice for BHPB’s exploration project. 

These are also addressed above in Sections (c) and (f). 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 6 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 2 - GENERAL INFORMATION 

(a) Applications and Permits 

Application / Permit Issuing Agency Status 

APD BSEE District To be submitted via eWell 

Supplemental DWOP BSEE Region In preparation 

Lease Term Pipelines BSEE Region In preparation 

Surface Safety System 

Modification BSEE District In preparation 

Notice of Intent to Discharge EPA Region 4 In preparation 

Modification to Surface 

Commingle / Measurement BSEE Region In preparation 

(b) Drilling Fluids 

(1) The following table provides information on the types and amounts of the drilling fluids BHPB plan 

to use during drilling operations. 

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be Used 

Water-based (SW, FW, Barite) 21,508 BBLS per well 

Oil-based (diesel, mineral oil) NA 

Synthetic-based (internal olefin, ester, etc) 3,742 BBLS per well 

(i) Since BHPB does NOT intend to use oil-based drilling fluid (as shown above) then the 

table of major components is not required at this time.

(ii) Material Safety Data Sheets (MSDS) are not required at this time. 

(c) Peak Production Rates / Life of Reserves 

Well H-A: PROPRIETARY DATA 

Type Average Production Rate Peak Production Rate Life of Reservoir 

Oil 

Gas 

Well H-B: PROPRIETARY DATA 

Type Average Production Rate Peak Production Rate Life of Reservoir 

Oil 

Gas 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 7 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Well H-FG: PROPRIETARY DATA 

Type Average Production Rate Peak Production Rate Life of Reservoir 

Oil 

Gas 

Well H-H: PROPRIETARY DATA 

Type Average Production Rate Peak Production Rate Life of Reservoir 

Oil 

Gas 

 Well C-A: PROPRIETARY DATA 

Type Average Production Rate Peak Production Rate Life of Reservoir 

Oil 

Gas 

(d) Oil Characteristics 

The following two tables provide the chemical and physical characteristics of the oils (see definition under 30 

CFR § 254.6) that will be produced, handled, transported, or stored. The first table summarizes the range of 

properties that have been seen in the Shenzi wells tested to date and should be a good representation of the 

produced fluid. The second table was taken from a representative well. 

Characteristic Units Value Range Analytical Methodologies 

Gravity (API° at 60 °F) 27 – 32 ASTM D-4052 

Flash Point not tested 

Pour Point (°F) (-30) - (-6) ASTM D-97 

Kinematic Viscosity (Cst at 100 oF) 10 – 21 ASTM D445 

Wax Content (wt %) 2.8 - 6.8 UOP-46 

Asphaltene Content (wt %) 2.1 - 8.5 IP 143-84 

Resin Content (wt %) 10 – 19 IFP 9305 

Sulphur (wt %) 1 – 2.6 ASTM D-5453 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 8 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

The following table is the Simulated Distillation by Gas Chromatography, ASTM - D 2887 and the analysis is 

from a sample at 24,560' MD in Shenzi-2 ST2. 

Percent Recovery 90% 

Percent Off (°F) 

IBP 160 

5 233 

10 313 

15 380 

20 441 

25 500 

30 544 

35 587 

40 634 

45 682 

50 737 

55 791 

60 850 

65 913 

70 981 

75 1059 

80 1148 

85 1247 

90 1346 

95 1355 

(e) New or Unusual Technology 

BHPB does not propose the use of any new or unusual technology in the development activities proposed 

under this plan. 

(f) Bonding Information 

The bond requirements for the activities and facilities proposed in this Supplemental Plan are satisfied by 

an area-wide bond furnished and maintained according to 30 CFR Part 256, Subpart I; NTL No. 2000-

G16, “Guidelines for General Lease Surety Bonds”; and National NTL No. 2008-N07, “Supplemental 

Bond Procedures”.

(g) Oil Spill Financial Responsibility (OSFR) 

BHPB (BOEM Operator No. 02010) has demonstrated oil spill financial responsibility for the facilities 

proposed in this Supplemental Plan 30 CFR Part 253, and NTL No. 2008-N05, “Guidelines for Oil Spill 

Financial Responsibility for Covered Facilities”. 

(h) Deepwater Well Control Statement 

BHPB (BOEM Operator No. 02010) has the financial capability to drill a relief well and conduct other 

emergency well control operations. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 9 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(i) Suspensions of Production 

At this time there are no approved or anticipated suspensions of production needed to hold the leases or 

unit involved with our DOCD. 

(j) Blowout Scenario 

The proposed wells will penetrate the objective, hydrocarbon bearing sands with a 12-1/4” x 14” drilling 

assembly below the 13-5/8” x 14” intermediate casing string. It is assumed that a hydrocarbon influx is 

taken while tripping out of the hole, and subsequently an uncontrolled well control event occurs in which 

the BOPs fail to function as designed and subsequently the marine riser fails. The end result is an 

uncontrolled blowout at the sea floor. 

The calculated WCD volume for Shenzi is 131,116 STB oil/day. The estimated cumulative 

discharge volume after 30 days is 3.3 MMSTB oil.

Relief Rig Availability 

BHPB has a Master Service Agreement (MSA) with Transocean Ltd. that will allow access to the multiple 

rigs of opportunity operating in the Gulf of Mexico. 

The rigs listed below are currently contracted in GOM: 

Rig Name Contractor Contractor Rated Water 

Depth (ft) MODU Type Rig Status 

Discoverer Americas Transocean 12,000 DP Drill Ship Contracted GOM 

C.R. Luigs Transocean 10,000 DP Drill Ship Contracted GOM 

Discoverer Deep Seas Transocean 10,000 DP Drill Ship Contracted GOM 

Ensco 8500 ENSCO 8,500 DP Semisubmersible Contracted GOM 

Ensco 8501 ENSCO 8,500 DP Semisubmersible Contracted GOM 

Ensco 8502 ENSCO 8,500 DP Semisubmersible Contracted GOM 

West Sirius Seadrill 10,000 DP Semisubmersible Contracted GOM 

Maersk Developer Maersk 10,000 DP Semisubmersible Contracted GOM 

Danny Adkins Noble 12,000 DP Semisubmersible Contracted GOM 

Relief Rig Package Constraints 

No constraints have been identified. Any of the above listed MODUs are capable of drilling a relief well in 

the covered development area. Furthermore, BHP Billiton actively maintains operational agreements with 

multiple stimulation vessel providers in the GOM which are configured for high rate and pressure pumping 

operations required in dynamic kill operations. 

Relief Rig Timing (Contract) and Rig Mobilization 

A reasonable estimate of 7 to 10 days will be required for the above listed or similar MODUs to safely 

suspend ongoing operations and arrive at the relief well location. Upon arrival at relief well location 

approximately 90 days will be required to drill the relief well and perform kill operations. 

Location & Strategy of Relief Well 

The proposed wells are located approximately 116 and 119 statute miles off the coast of Louisiana, a 

relief well from an onshore location is not an option. 

There are no structures in the vicinity of this project to use for relief well drilling operations. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 10 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Summary of Prevention Measures 

BHPB maintains and adheres to an ISO 14001 / OSHAS 18001 Conformance Certified Management 

System which includes Well Control, Well Integrity [including barrier analyses], and Well Design 

Standards which have been updated to include the initial learning’s from the Deepwater Horizon incident. 

BHPB have established procedures for performing drilling operations that are continually updated and 

designed to be “fit for purpose” to ensure each well is planned to prevent a well control scenario: 

 BHPB employs an industry leading expert to provide initial pore pressure and fracture gradient 

predictions. Having this expertise and knowledge in-house allows for the successful planning of a 

well to minimize the chances of a blowout. 

 Well hazard assessments are performed on every well focusing particularly on well integrity, well 

control and emergency response arrangements. 

 A well risk assessment is conducted as part of the well planning process, and a risk register is 

completed and documented in the drilling program addressing each of the risks. 

 If while drilling a well, situations change such that the original drilling program requires to be 

amended, a Management of Change is issued, and if necessary, a barrier analysis is conducted. 

The Management of Change form is signed off by management and issued to operations 

personnel for implementation. 

 BHPB Senior Leadership personnel are actively engaged in daily rig operations. 

 BHPB employs experienced and trained Field Operations Personnel. 

 BHPB conducts periodic well control audits of our contracted drilling rigs by both BHPB drilling 

management and independent third party (well examiner) auditors. 

Reduce the Likelihood of a Blowout 

Real time pressure and well data is monitored from the BHPB Houston office during drilling operations. 

This includes utilizing Gamma Ray and Resistivity LWD and in certain cases formation pressure while 

drilling tools. 

The following BHPB policies directly reduce the likelihood of a blowout: 

 Liners will be run across hydrocarbon bearing formations. 

 No auto-fill float equipment will be run when hydrocarbon zones are exposed. 

 No surface fluid transfers to occur while displacing to a less dense fluid. 

 All displacements to less dense fluids will be performed on a closed system where fluid volumes 

can be closely and accurately monitored. 

A well control drill matrix is maintained on the rig as per 30 CFR 250 Subpart O. 

The BOP stacks on the C.R. Luigs and Invictus rigs are both six (6) ram stacks configured to provide 

enhanced well control and emergency response capability, including dual blind shear rams, casing shear 

rams, and three variable bore pipe rams. Procedures pertinent to these BOP configurations are well 

established and familiar to the drillers, tool pushers, and BHPB Drilling Supervisors. 

Likelihood for Surface Intervention to Stop the Blowout 

The likelihood for surface intervention to stop the blowout is high. 

The 13-5/8” intermediate long string will design for a full column of oil to the mudline. As a result, it would 

be possible to install a containment device (such as a capping stack) which would subsequently allow for 

the blowout to be stopped. 

BHPB has standardized the BOP wellhead connector for both of its contracted MODU’s, the Invictus and 

the C.R. Luigs, to ensure that either rig is capable of latching onto an existing BHPB wellhead. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 11 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Plans for Effective and Early Intervention 

Both rigs contracted by BHPB have a Deadman / Autoshear which will function in the event of a LMRP 

disconnect or a loss of both hydraulic pressure and electrical communication with the BOP control system 

on surface. 

“Surface” deployment of ROVs to close any open BOPs which could affect well closure: 

 The ROV panel will be tested subsea with the BOP on a wellhead. 

 BHPB has upgraded the pump skid on the rigs’ ROV’s with a more powerful pump capable of 

producing higher flow rates. Additionally, the receptacles have been changed to allow for more 

flow rate to reduce closing times. 

 BHPB has designed, built, tested and deployed dedicated subsea accumulator banks to the 

seafloor to further improve the ROV closure response times. 

BHPB is a member of the Marine Well Containment Company (MWCC) group, which maintains capping 

and well control equipment for its member companies. 

Relief Well Arrangements 

Suitable surface locations for a relief well would fall within the stand-off zone defined by a 5000’ radius 

with its center at the proposed surface location. Shallow hazards analysis indicates favorable relief well 

locations within this area provided that existing infrastructure, localized areas of steep seafloor slope, and 

scattered gas anomalies are avoided. 

The well design should reflect the original well, depending on the root cause of the blowout. 

KEY RIG SPECIFICATIONS FOR RELIEF WELL 

RIG NAME INVICTUS C.R. LUIGS 

Rig Type 

DSME 12000 TBN #1 MODU rated 

for 12,000 ft water depth, 

Dynamically Positioned 

5th Gen MODU rated for 10,000 ft 

water depth, dynamically positioned 

BOP Size & Pressure Rating: 18.75 – 15,000 psi 18.75 - 15,000 psi 

Max Hookload (kips): 2,800 kips 1,800 kips 

Drawworks Power (hp): 9,000 hp 5,000 hp 

Mud Pumps Power & Pressure (hp/psi): 4x AKMH Wirth model TPK-7-1/2 

pumps with 2,200 hp, 7,500 psi WP 

4 x 14-P-220 NOV pumps with 2,200 

7,475 psi WP 

Mud Pit Volume (bbls): 20,000 bbls 13,267 bbls 

Variable Loading (kips): 50,706 kips NA 

Top Drive Power & Torque (hp/ftlbs): Aker MH MDDM-1250-AC-2M NOV TDS-4 

Dry Bulk Storage Capacity (cu. ft): Total Bulk 28,250 cuft Total Bulk 27,000 cuft 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 12 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Other Measures Taken 

Prior to drilling BHBP will have readily available all of the materials and equipment needed to spud, drill, 

case and cement a relief well. 

BHPB has established commercial relationships with those suppliers of contingency equipment and 

services that we have identified as necessary to kill a blown out well. 

(k) Chemical Products 

This information is not required for the activities proposed in this plan in the BOEM GOMR. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 13 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 3 - GEOLOGICAL AND GEOPHYSICAL INFORMATION 

In accordance with 43 CFR, Appendix B, those items considered proprietary have been omitted from the 

Public Information copy and have been referenced accordingly. 

(a) Geological Description 

PROPRIETARY DATA 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 14 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

PROPRIETARY DATA

 

(b) Structure Contour Maps 

PROPRIETARY DATA 

(c) Interpreted 2-D or 3-D Seismic Lines 

PROPRIETARY DATA 

(d) Geological Structure Cross-Sections 

PROPRIETARY DATA 

(e) Shallow Hazards Report 

A Site Specific Shallow Drilling Hazards Report for Drill Center H located in Green Canyon Block 610, 

Lease OCS-G 16765 was prepared by Shawn C. Williamson, P.G. Geohazards Interpreter for BHPB on 

April 12, 2011. 

A copy of this report was submitted to the BOEM for review under S-07487. The wells proposed in this 

plan are being drilled adjacent to existing Drill Center H in GC 610 and Drill Center C in GC 653. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 15 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(f) Site Specific Shallow Hazards Assessment 

The wells proposed in this plan are being drilled adjacent to existing Drill Center H in GC 610 and Drill 

Center C in GC 653; a shallow hazards assessment is not required at this time. 

(g) High Resolution Seismic Lines 

The wells proposed in this plan are being drilled adjacent to existing Drill Center H in GC 610 and Drill 

Center C in GC 653; high resolution seismic lines are not required at this time. 

(h) Stratigraphic Column 

This information is not required for DOCD’s. 

(i) Time Versus Depth Tables 

This information is not required for DOCD’s. 

 

(j) Geochemical Information 

This information is not required for the activities proposed in this plan in the BOEM GOMR. 

(k) Future G&G Activities 

This information is not required for the activities proposed in this plan in the BOEM GOMR. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 16 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 4 - HYDROGEN SULFIDE INFORMATION

(a) Concentration 

BHPB does not anticipate encountering H2S while conducting our proposed development activities. 

(b) Classification Request 

In accordance with Title 30 CFR 250.490(c), BHPB requests the area of operations in Green Canyon 

Blocks 609, 610 and 653, Leases OCS-G 16764, 16765 and 20084, be classified by the BOEM as an 

area where the “absence” of Hydrogen sulfide has been confirmed based upon the following: 

PROPRIETARY DATA 

(c) Contingency Plan 

BHPB does not anticipate encountering H2S while conducting our proposed development activities 

therefore a contingency plan is not required at this time. 

(d) Modeling Report

BHPB does not anticipate encountering H2S while conducting our proposed development activities 

therefore a modeling report is not required at this time. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 17 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 5 - MINERAL AND RESOURCE CONVERSATION INFORMATION

(a) Technology and Reservoir Engineering Practices and Procedures 

PROPRIETARY DATA 

(b) Technology and Recovery Practices and Procedures 

PROPRIETARY DATA 

(c) Reservoir Development 

PROPRIETARY DATA

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 18 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 6 - BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION 

(a) Chemosynthetic Communities Report 

NTL 2009-G40, effective January 27, 2009, broadened the scope of a chemosynthetic communities 

report to cover all high-density deepwater benthic communities (not just high-density chemosynthetic 

communities), changed the definition of deepwater from 400 meters (1,312 feet) to 300 meters (984 feet), 

increased the separation distance from muds and cuttings discharge locations from 1,500 feet to 2,000 

feet and provided for an additional 1,000-foot buffer area beyond maximum anchor areas. 

The wells proposed in this plan are being drilled adjacent to existing Green Canyon 610 Drill Center H 

and Green Canyon 653 Drill Center C. There will be no new impact(s) to this area. There are no 

hydrocarbon macro-seeps or hard bottom areas capable of supporting high-density benthic communities 

within 2,000ft of the existing drill centers. 

(b) Topographic Features Map 

There are no topographic features located on Green Canyon 609, 610 or 653. 

(c) Topographic Features Statement 

Since there are no topographic features located on Green Canyon 609, 610 or 653 the statement for 

shunting described in NTL No. 2009-G39 “Biologically Sensitive Underwater Features and Areas” is not 

required. 

(d) Live Bottom (Pinnacle Trend) Map 

The activities proposed in this plan are not affected by a live bottom (Pinnacle Trend) stipulation attached 

to the lease. 

(e) Live Bottom (Low Relief) Map 

The activities proposed in this plan are not affected by a live bottom (low relief) stipulation attached to the 

lease. 

(f) Potentially Sensitive Biological Features 

BHPB does not propose bottom-disturbing activities within 61 meters (200 feet) of potentially sensitive 

biological features; therefore the map described in NTL No. 2009-G39 “Biologically Sensitive Underwater 

Features and Areas” is not required. 

(g) ROV Monitoring Survey Plan 

BHPB is familiar with the ROV survey and reporting provisions of NTL 2008-G06 for “Remotely Operated 

Vehicles in Deepwater”. The wells proposed in this Supplemental Plan are located in Grid 13. Grid 13 has 

been identified by BOEM as an area with adequate ROV survey coverage. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 19 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(h) Threatened and Endangered Species Information 

Congress passed the Endangered Species Act (ESA) on December 28, 1973, recognizing that the natural 

heritage of the United States was of “esthetic, ecological, educational, recreational, and scientific value to 

our Nation and its people.” It was understood that, without protection, many of our nation’s living 

resources would become extinct. The purpose of the ESA is to conserve threatened and endangered 

species and their ecosystems. There are more than 1,900 species listed under the ESA. A species is 

considered endangered if it is in danger of extinction throughout all or a significant portion of its range. A 

species is considered threatened if it is likely to become endangered in the future. The U.S. Fish and 

Wildlife Service (USFWS) and the National Marine Fisheries Service (NMFS) share responsibility for 

implementing the ESA. NMFS is responsible for 69 marine species, from whales to sea turtles and 

salmon to Johnson’s sea grass. 

The Marine Mammal Protection Act (MMPA) of 1972 was written to establish American federal 

responsibility to conserve marine mammals. Some species were in immediate danger of extinction while 

other populations were becoming severely depleted. 

Below is a list of endangered and threated species and critical habitats under the jurisdiction of NOAA 

Fisheries Service in the Gulf of Mexico: 

Listed Species Scientific Name Status Date Listed 

Marine Mammals 

Blue Whale Balaenoptera Musculus Endangered 12/02/1970 

Finback Whale Balaenoptera Physalus Endangered 12/02/1970 

Humpback Whale Megaptera Novaeangliae Endangered 12/02/1970 

Sei Whale Balaenoptera Borealis Endangered 12/02/1970 

Sperm Whale Physeter Macrocephalus Endangered 12/02/1970 

Turtles 

Green Sea Turtle Chelonia Mydas Threatened1 07/28/1978 

Hawksbill Sea Turtle Eretmochelys Imbricata Endangered 06/02/1970 

Kemp’s Ridley Sea 

Turtle 

Lepidochelys Kempii Endangered 12/02/1970 

Leatherback Sea Turtle Dermochelys Coriacea Endangered 06/02/1970 

Loggerhead Sea Turtle Caretta Caretta Threatened2 09/22/2011 

Fish 

Gulf Sturgeon Acipenser Oxyrinchus Desotoi Threatened 09/30/1991 

Smalltooth Sawfish Pristis Pectinata Endangered 04/01/2003 

Invertebrates 

Elkhorn Coral Acropora Palmata Threatened 05/09/2006 

Staghorn Coral Acropora Cervicornis Threatened 05/09/2006 

1 Green turtles are listed as threatened, except for breeding populations of green turtles in Florida and on the Pacific Coast of Mexico, which are listed as endangered. 

2 Northwest Atlantic Ocean (NWA) Distinct Population Segment (DPS) was listed as threatened. NMFS and USFWS issued a final rule changing the listing of 

loggerhead sea turtles from a single, threatened species to nine DPSs listed as either threatened or endangered in 2012 (76 FR 58868). 

BHP is aware of the above referenced federal acts and will ensure that all offshore personnel, including 

contractors and other support services-related personnel have an understanding of the need to conserve 

marine mammals and the conservation of their ecosystems. Several NTL’s were issued to address 

conservation measures to be taken by offshore operators and contractors. 

Further discussions on threatened and endangered species are included in Section 19 (EIA).

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 20 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(i) Archaeological Report

The Shenzi Field is not located within an area designated to have a high probability for archaeological 

resources as defined by NTL No. 2005-G07 and 2011-JOINT-G01. However, BHP Billiton is aware of the 

Bureau of Ocean Energy Management’s (BOEM) March 2011 Pre-Seabed Disturbance Survey Mitigation 

and has submitted an archaeological assessment report issued by Geoscience Earth & Marine Services 

(GEMS) in November 2011. None of the sonar contacts identified in the Shenzi AUV survey area were 

recommended for archaeological avoidance or investigation. 

(j) Air and Water Quality Information 

The State of Florida is not an affected State for the activities proposed in this plan; therefore this 

information is not required. 

(k) Socioeconomic Information 

The State of Florida is not an affected State for the activities proposed in this plan; therefore this 

information is not required. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 21 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 7 - WASTE AND DISCHARGE INFORMATION 

(a) Projected Generated Wastes

All projected solid and liquid wastes likely to be generated by our proposed activities are included in 

Attachment H (Table 1). This table includes both operational wastes permitted by the appropriate 

NPDES permit and any other identified wastes. 

BHPB does not plan to treat, store or dispose of any of the above wastes down hole at our proposed 

drilling location. 

(b) Projected Ocean Discharges 

All projected solid and liquid wastes likely to be discharged overboard during our proposed activities are 

included in Attachment H (Table 1). This table includes both operational wastes permitted by the 

appropriate NPDES permit and any other identified wastes. 

(c) Modeling Report 

Not required by EPA under the OCS General Permit. 

(d) NPDES Permits 

This information is not required for the activities proposed in this plan in the BOEM GOMR. 

(e) Cooling Water Intakes 

This information is not required for the activities proposed in this plan in the BOEM GOMR. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 22 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 8 - AIR EMISSIONS INFORMATION 

(a) Screening Checklist 

Included in this section, (if applicable) are the Projected Air Emissions Worksheets prepared in 

accordance with NTLs 2009-G27 and 2008-G04, associated with the new proposed well Locations H-A, 

H-B, H-FG, H-H and C-A. 

Screening Questions for DOCD’s Yes No 

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

activities more than 90% of the amounts calculated using the following formulas: CT = 3400D2/3 for CO, and 

CT = 33.3D for other air pollutants (where D = distance to shore in miles)? 

X 

Do your emission calculations include any emission reduction measures or modified emission factors? X 

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

production from eight or more wells? 

X 

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

Do you propose to flare or vent natural gas in excess of the criteria set forth under 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 from shore? X 

Are your proposed development and production activities located within 200 kilometers of the Breton 

Wilderness Area? X 

The following information was prepared by Bill Bruscino with Trinity Consultants, (614) 433-0733, based 

upon drilling and completion information provided by BHP Billiton Petroleum Drilling group. 

(b) Summary Table of Plan Emissions 

Below are the Total Plan Emissions for the drilling and completion of well Locations H-A, H-B, H-FG, H-H 

and C-A. 

COMPANY AREA BLOCK LEASE PLATFORM WELL 

BHP Billiton Pet. 

(GOM) Inc. Green Canyon 609, 610, 653 OCS-G 16764, 

16765, 20084 NA H-A, H-B, H-FG, H-H 

and C-A (CRL) 

Year Emitted Substance 

PM SOx NOx VOC CO 

2015 43.66 0.71 1338.67 53.61 332.17 

2016 43.66 0.71 1338.67 53.61 332.17 

2017 43.66 0.71 1338.67 53.61 332.17 

2018 43.66 0.71 1338.67 53.61 332.17 

2019 43.66 0.71 1338.67 53.61 332.17 

Allowable 3862.80 3862.80 3862.80 3862.80 80869.40 

COMPANY AREA BLOCK LEASE PLATFORM WELL 

BHP Billiton Pet. 

(GOM) Inc. Green Canyon 609, 610, 653 OCS-G 16764, 

16765, 20084 NA H-A, H-B, H-FG, H-H 

and C-A (Invictus) 

Year Emitted Substance 

PM SOx NOx VOC CO 

2015 87.77 1.40 2107.01 107.86 746.32 

2016 87.77 1.40 2107.01 107.86 746.32 

2017 87.77 1.40 2107.01 107.86 746.32 

2018 87.77 1.40 2107.01 107.86 746.32 

2019 87.77 1.40 2107.01 107.86 746.32 

Allowable 3862.80 3862.80 3862.80 3862.80 80869.40 

Detailed spreadsheets are included as Attachment I.

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 23 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 9 - OIL SPILL INFORMATION

(a) Oil Spill Response Planning 

 (1) Site-Specific OSRP 

Leases OCS-G 16764, 16765 and 20084 are not located in the Eastern Gulf of Mexico 

therefore a site-specific OSRP is not required. 

 (2)(i) Regional or Sub-Regional OSRP Information 

BHP Billiton Petroleum (GOM) Inc. (Company No. 02010) has an approved Regional 

OSRP (No. O-43). 

The calculated WCD for the operations in this Supplemental DOCD does not supersede 

the Regional OSRP’s WCD. 

All the proposed activities and facilities in this Supplemental DOCD will be covered by the 

Oil Spill Response Plan filed by BHP Billiton Petroleum (GOM) Inc. (Company No. 

02010) that was approved on November 21, 2013. A revision was submitted to the 

OSRP on September 12, 2014 which does not affect the proposed activities or facilities in 

this Supplemental DOCD. 

 (ii) Spill Response Sites 

 

The location of BHPB’s primary spill response equipment and the planned staging 

area(s) that would be used should we have an oil spill resulting from the activities 

proposed in our Supplemental Plan is provided in the table below: 

Primary Response Equipment Location Preplanned Staging Location(s) 

Port Fourchon or Houma, LA Port Fourchon, LA 

 (iii) OSRO Information 

BHPB’s primary equipment provider is Clean Gulf Associates (CGA). Clean Gulf 

Associates Services, LLC (CGAS) will provide closest available personnel, as well as a 

CGAS supervisor to operate the equipment. 
BHP Billiton Petroleum (GOM) Inc. 24 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(iv) Worst Case Scenario Determination 

*The Regional OSRP calculations and assumptions for blowout during drilling were previously submitted 

and accepted under Plan S-7487. 

** The WCD for the Shenzi Field was verified and accepted by BOEM under Plan R-5124. 

The calculated WCD for this Supplemental DOCD does not supersede the Regional OSRP’s WCD or the 

Shenzi WCD as verified in Plan N-9001. 

Category Regional 

OSRP 

Supplemental 

DOCD 

Regional 

OSRP 

Supplemental 

DOCD 

Type of Activity

Drilling Drilling

>10 Miles

Production

>10 Miles

Production

Facility Location (area/block) GC 610 GC 653 GC 653 GC 653

Facility Designation2 Well SH103

ST01 WELL SB101 Shenzi TLP Shenzi TLP

Distance to Nearest Shoreline (miles) 120 120 120 120

Volume3

 Storage tanks (total) 

 Flowlines (on facility) 

 Lease term pipelines 

 Uncontrolled blowout (volume per day) 

Total Volume

NA

NA

  NA  

255,200

255,200 *

NA

NA

  NA  

131,116  

131,116 **

4,098

8,474

NA  

111,084

123,656

4,098

8,474

NA  

111,084

123,656

Type of Oil(s) (crude oil, condensate, diesel) Crude Crude Crude Crude

API Gravity(s)4 32.1° 32.1° 30° 30°

Footnotes: 

1. Types of activities include pipeline, platform, caisson, subsea completion or manifold, and mobile drilling rig. 

2. E.g., Well No. 2, Platform JA, Pipeline Segment No. 6373. 

3. Take your regional OSRP worst-case scenario volume from the appropriate section of your regional OSRP. For EP’s, the worst-case scenario 

volume is the daily volume possible from an uncontrolled blowout. Determine this volume using the provisions of 30 CFR 30 CFR 254.47(b). 

For DOCD’s, determine the volume of your worst-case scenario using the provisions of 30 CFR 30 CFR 254.47(a) or (b), as appropriate. 

4. Provide API gravity of all oils given under “Type of Oil(s)” above. Estimate for EP’s.

Since BHPB has the capability to respond to the appropriate worst-case spill scenario included in 

its regional OSRP approved on November 21, 2013, and since the worst-case scenario determined 

for our Supplemental DOCD does not replace the appropriate worst-case scenario in our regional 

OSRP, I hereby certify that BHPB has the capability to respond, to the maximum extent 

practicable, to a WCD, or a substantial threat of such a discharge, resulting from the activities 

proposed in our Supplemental DOCD. 

NTL 2010-N06 – WCD Calculations Overview 

The WCD for the Shenzi Field was verified and accepted by BOEM under Plan R-5124. BHPB has 

included the WCD calculations for Well H-H for information purposes in Attachment M. 

(b) Oil Spill Response Discussion / NEPA Analysis 

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

from the proposed activity would be a well blowout during drilling operations, estimated to be 131,116 

barrels of crude oil with an API gravity of 32.1°. 

BHPB’s detailed spill response discussion is included as Attachment J. 

(c) Modeling Report 

A modeling report for a potential oil or hazardous substance spill is not required for the activities proposed 

in this plan. In the event BHPB proposes to prepare such a report, we would contact the Regional 

Supervisor of the BOEM GOMR for guidance in preparing the report and the BOEM GOMR would be 

provided with two copies. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 25 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 10 - ENVIRONMENTAL MONITORING INFORMATION 

(a) Monitoring Systems 

BHPB is aware of the requirements of NTL No. 2009-G02 whereby BOEM established and implemented 

a program to monitor ocean currents and require operators to share the data for all floating MODU’s and 

production facilities operating or installed in water depths greater than 400 meters (1,312 feet). 

In the event BHPB were to monitor ocean currents during this operation, BHPB will report ocean current 

data to the National Oceanic and Atmospheric Administration (NOAA) National Data Buoy Center (NDBC) 

Internet website as required. 

(b) Incidental Takes 

BHPB does not believe that protected species may be incidentally taken during the development activities 

proposed in this plan. 

(c) Flower Garden Banks National Marine Sanctuary 

BHPB’s activity under this Plan is not located within the Protective Zones of the Flower Garden Banks or 

Stetson Bank and therefore is not required to monitor the impacts of an oil spill. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 26 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 11 - LEASE STIPULATIONS INFORMATION 

BOEM did not invoke any lease stipulations for Leases OCS-G 16764, 16765 and 20084, Green Canyon 

Blocks 609, 610 and 653. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 27 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 12 - ENVIRONMENTAL MITIGATION MEASURES INFORMATION 

(a) Impacts to Marine and Coastal Environments and Habitats, Biota, and Threatened 

and Endangered Species 

BOEM and BSEE issue Notices to Lessees (NTLs) which more fully describe measures 

implemented in support of certain statutes and regulations, as well as measures identified by the 

U.S. Fish and Wildlife Service and NMFS arising from, among others, conservation 

recommendations, rulemakings pursuant to the MMPA, or consultation. 

BHPB and its personnel and subcontractors, while undertaking activities authorized under this 

lease, must implement and comply with the specific mitigation measures outlined in: 

 NTL No. 2012-JOINT-G01 (Vessel Strike Avoidance and Injured/Dead Protected Species 

Reporting), 

 NTL No. 2012-JOINT-G02 (Implementation of Seismic Survey Mitigation Measures and 

Protected Species Observer Program), and 

 NTL No. 2012-BSEE-G01 (Marine Trash and Debris Awareness and Elimination). 

BHPB personnel and contractors will comply with the most current measures to protect 

species in place at the time an activity is undertaken under this lease, including but not 

limited to new or updated versions of the NTLs identified in this paragraph. 

BHPB personnel and contractors will be required to comply with the mitigated measures, 

identified in the above referenced NTLs, and additional measures in the conditions of 

approvals for their plans or permits. 

(b) Incidental Takes 

BHPB does not believe that any of the endangered species or marine mammals as listed in the 

ESA will be taken during the development activities proposed in this plan. 

BHPB understands that the use of explosives or seismic devices may affect marine life in the 

vicinity. There are no operations proposed in this plan that will be using explosives or seismic 

instruments. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 28 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 13 - DECOMMISSIONING INFORMATION 

This information is not required for plans submitted in the BOEM GOMR. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 29 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 14 - RELATED FACILITIES AND OPERATIONS INFORMATION 

(a) Related OCS Facilities and Operations 

A subsea tree will be installed on each well with the rig prior to leaving the location (SST drawing 

in Attachment K). The well jumpers will be installed with either the rig or an intervention vessel. 

Related OCS facilities and operations were discussed in depth in the Initial Unit DOCD (Plan No. 

N-9001). There are no changes to the host facility under this Plan. 

Under this Supplemental Unit DOCD five (5) lease term flowlines (well jumpers) will be installed. 

Description of Lease Term Pipelines 

Diameter 

(Inches) From To Length Product Max SI Time 

06 GC610 / Well H-A GC610 / Manifold H 60 Oil 25,000 

bopd 45 seconds 

06 GC610 / Well H-B GC610 / Manifold H 60 Oil 25,000 

bopd 45 seconds 

06 GC610 / Well H-FG GC610 / Manifold H 60 Oil 25,000 

bopd 45 seconds 

06 GC610 / Well H-H GC610 / Manifold H 60 Oil 25,000 

bopd 45 seconds 

06 GC653 / Well C-A GC653 / Manifold C1 60 Oil 25,000 

bopd 45 seconds 

(b) Transportation System 

Oil and gas production is exported via existing right-of-way pipelines to existing pipeline delivery 

systems. There will be no changes to the existing field infrastructure under this Supplemental 

Plan. 

(c) Produced Liquid Hydrocarbons Transportation Vessels 

There will be no produced liquid Hydrocarbons, including well test fluids, transported by means 

other than a pipeline for the activities proposed in this plan. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 30 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 15 - SUPPORT VESSELS AND AIRCRAFT INFORMATION 

(a) General 

The following list provides information regarding the vessels and aircraft BHPB will use to support our 

proposed activities. 

Type of Vessel Maximum Fuel Tank 

Storage Capacity 

Maximum No. in 

Area at Any Time 

Trip Frequency or 

Duration during Drilling 

Trip Frequency or 

Duration during 

Production (See Note 

Below) 

Supply boat(s) 25,000 - 370,000 gals 2 7 times / week 7 times / week 

Crew boat(s) 5,000 – 15,000 gals 1 7 times / week 7 times / week 

Helicopter 440 gals 1 As needed As needed 

NOTE: Vessel trips during production are the same as previously reported. There will be no additional 

vessel trips due to the additional production operations. 

Type of Vessel Maximum Fuel Tank 

Storage Capacity (bbls) 

Maximum No. in 

Area at Any Time Total Duration 

Installation of Risers, Flowlines, Jumpers, Manifolds, etc. 

Installation Vessel (Deep 

Blue – flowlines, jumpers, 

umbilicals) 

29606 1 4 days 

Support vessel – subsea 

commissioning 11100 1 4 days 

(b) Diesel Oil Supply Vessels 

BHPB proposes to use one of the following vessel(s) to supply diesel oil to support the drilling operation 

in this Supplemental Plan. 

Size of Fuel Supply 

Vessel

Capacity of Fuel Supply 

Vessel (in bbls) 

Frequency of Fuel 

Transfers 

Route Fuel Supply Vessel 

will Take 

280 ft PSV 16800 1 / month 

From the shorebase in Port 

Fourchon, LA to the MODU, 

then back to shorebase 

280 ft PSV 8930 2 / week 

From the shorebase in Port 

Fourchon, LA to the MODU, 

then back to shorebase 

(c) Drilling Fluids Transportation 

The proposed development activities do not affect the State of Florida; therefore information on the 

projected drilling fluids transportation is not required at this time. 

(d) Solid and Liquid Wastes Transportation 

All projected solid and liquid wastes likely to be transported during our proposed activities are included in 

Attachment H (Table 2). 

 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 31 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(e) Vicinity Map 

Drill Center C is located approximately 119 statute miles from the nearest Louisiana shoreline and 

approximately 122 miles from the onshore support base located in Port Fourchon, LA. 

Drill Center H is located approximately 116 statute miles from the nearest Louisiana shoreline and 

approximately 120 miles from the onshore support base located in Port Fourchon, LA. 

A Vicinity Plat showing the location of the proposed development activities relative to the shoreline and 

the onshore base is included as Attachment L. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 32 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 16 - ONSHORE SUPPORT FACILITIES INFORMATION 

(a) General 

BHPB proposes to utilize the following existing onshore base for support: 

Name Location Existing, New or Modified 

Chouest Base Port Fourchon, LA Existing 

 (1) Support Base Construction or Expansion 

The proposed operations do not mandate any immediate measures for land acquisition or 

expansion of the existing onshore base facilities. 

 (2) Support Base Construction or Expansion Timetable 

 The proposed operations do not mandate any immediate measures for land acquisition or 

 expansion of the existing onshore base facilities therefore a timetable is not required. 

(b) Air Emissions 

Information regarding air emissions generated by onshore support facilities is not required to accompany 

plans submitted in the BOEM GOMR. 

(c) Unusual Solid and Liquid Wastes 

Information regarding unusual solid and liquid wastes generated by onshore support facilities is not 

required to accompany plans submitted in the BOEM GOMR. 

(d) Waste Disposal 

All projected solid and liquid wastes likely to be disposed of during and after our proposed activities are 

included in Attachment H (Table 2). 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 33 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 17 - SULPHUR OPERATIONS INFORMATION 

BHPB is not proposing to conduct sulphur operations in this plan. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 34 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 18 - COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION

The States of Texas, Louisiana, Mississippi, Alabama and Florida have federally approved coastal zone 

management programs (CZMP). Applicants for an OCS plan submitted to the BOEM must provide a 

certification with necessary data and information for the affected State to determine that the proposed 

activity(s) complies with the enforceable policies of each States’ approved program, and that such activity 

will be conducted in a manner consistent with the program. 

(a) Consistency Certification 

The Coastal Zone Management Consistency Certification from the State of Louisiana is not required for 

the supplemental development activities proposed in this Supplemental Plan. 

(b) Other Information 

State of Louisiana: 

The enforceable policies of the State of Louisiana have been considered and will be complied with. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 35 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 19 - ENVIRONMENTAL IMPACT ANALYSIS (EIA) 

(a) And (b) BHPB has placed an “X” in each IPF category that we believe (by using good 

engineering judgment) would be impacted by the activity proposed in this plan. 

Environmental 

Resources 

Impact Producing Factors (IPFs) Categories and Examples 

Emissions 

(air, noise, 

light, etc.) 

Effluents 

(muds, cuttings, 

other 

discharges to 

the water 

column or 

seafloor) 

Physical 

disturbances 

to the seafloor 

(rig or anchor 

emplacements, 

etc.) 

Wastes 

sent to 

shore for 

treatment 

or 

disposal 

Accidents 

(e.g., oil 

spills, 

chemical 

spills, H2S 

releases) 

Other 

IPFs you 

identify 

Site-specific at Offshore 

Location 

Designated topographic features (1) (1) (1) 

Pinnacle Trend area live bottoms (2) (2) (2) 

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

Chemosynthetic communities (4) (4) (4) 

Water quality X X X 

Fisheries X X X 

Marine mammals (8) X X (8) X 

Sea turtles (8) X X (8) X 

Air quality (9) 

Shipwreck sites (known or 

potential) 

 

(7) 

 

Prehistoric archaeological sites (7) 

Vicinity of Offshore Location 

Essential fish habitat X (6) X 

Marine and pelagic birds X X X 

Public health and safety (5) 

Coastal and Onshore 

Beaches X (6) X 

Wetlands (6) X 

Shore birds and coastal nesting 

birds 

 

(6) X 

Coastal wildlife refuges X 

Wilderness areas X 

Other Resources You Identify 

 None 

 

 

 

Footnotes for Environmental Impact Analysis Matrix

1. Activities that may affect a marine sanctuary or topographic feature. Specifically, if the well or platform site or any anchors will be on the seafloor 

within the: 

(a) 4-mile zone of the Flower Garden Banks, or the 3-mile zone of Stetson Bank, 

(b) 1000-m, 1-mile or 3-mile zone of any topographic feature (submarine bank) protected by the Topographic Features Stipulation attached to 

an OCS lease; 

(c) Essential Fish Habitat (EFH) criteria of 500 ft 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 Features 

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 BOEM as being in water depths 400 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 judge would impact these environmental 

resources. If the proposed action is located a sufficient distance from a resource that no impact would occur, the EIA can note that in a sentence 

or two. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 36 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

7. All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block designated by the BOEM as having highprobability for the occurrence of shipwrecks or prehistoric sites, including such blocks that will be affected that are adjacent to the lease block in 

which your planned activity will occur. If the proposed activities are located a sufficient distance from a shipwreck or prehistoric site that no 

impact would occur, the EIA can note that in a sentence or two. 

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

habitats. 

9. Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges.

(c) ANALYSIS 

Site-specific at Green Canyon Blocks 609, 610 and 653 

1. Designated Topographic Features 

The topographic features of the Central Gulf provide habitat for coral reef community organisms. Since 

1973 stipulations have been made a part of leases on or near these biotic communities so that impacts 

from nearby oil and gas activities were mitigated to the greatest extent possible. This stipulation does not 

prevent the recovery of oil and gas resources, but serves to protect valuable and sensitive biological 

resources. 

There are no IPF’s (including effluents, physical disturbances to the seafloor and accidents) that could 

cause impacts from the proposed development activities in Green Canyon Blocks 609, 610 and 653 to 

topographic features. The site-specific offshore location of the proposed development activities is not 

located near a designated topographic feature. 

The activities proposed in this plan will be covered by our Regional OSRP. 

2. Pinnacle Trend Area Live Bottoms 

A small portion of the Central Planning Area and the Eastern Gulf of Mexico OCS planning areas include 

portions of approximately 70 lease blocks that have been classified as being within the “pinnacle trend” 

area. The Department of the Interior, Bureau of Ocean Energy Management is the agency with 

jurisdiction over these leases. 

The term “live bottom” is used to refer to the biological assemblages attached to hard substrates found 

interspersed between sand and mud bottoms of the continental shelf. These assemblages often consist 

of colorful sponges, corals, sea whips and sea fans rising from the benthic environment. Some of these 

features have extensive vertical relief rising far into the water column and serving as a reefal habitat for 

numerous commercially and recreationally important fish species. 

A special “Live Bottom (Pinnacle Trend) Stipulation” is assigned to leases in those blocks intended to 

protect the pinnacle trend and associated hard-bottom communities from damage and, at the same time, 

provide for recovery of potential oil and gas resources. This stipulation was not invoked with the issuance 

of these leases. 

There are no IPF’s (including effluents, physical disturbances to the seafloor, and accidents) from the 

proposed development activities in Green Canyon Blocks 609, 610 and 653 that could cause impacts to 

pinnacle trend area live bottoms. 

The activities proposed in this plan will be covered by our Regional OSRP 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 37 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

3. Eastern Gulf Live Bottoms 

A small portion of the Central Planning Area and the Eastern Gulf of Mexico OCS planning areas include 

portions of approximately 70 lease blocks that have been classified as being within the “pinnacle trend” 

area. The Department of the Interior, Bureau of Ocean Energy Management, Regulation and 

Enforcement is the agency with jurisdiction over these leases. 

The term “live bottom” is used to refer to the biological assemblages attached to hard substrates found 

interspersed between sand and mud bottoms of the continental shelf. These assemblages often consist 

of colorful sponges, corals, sea whips and sea fans rising from the benthic environment. Some of these 

features have extensive vertical relief rising far into the water column and serving as a reefal habitat for 

numerous commercially and recreationally important fish species. 

A special “Live Bottom (Pinnacle Trend) Stipulation” is assigned to leases in those blocks intended to 

protect the pinnacle trend and associated hard-bottom communities from damage and, at the same time, 

provide for recovery of potential oil and gas resources. This stipulation was not invoked with the issuance 

of these leases. 

There are no IPF’s (including effluents, physical disturbances to the seafloor, and accidents) from the 

proposed development activities in Green Canyon Blocks 609, 610 and 653 that could cause impacts to 

Eastern Gulf live bottoms. 

The activities proposed in this plan will be covered by our Regional OSRP. 

4. Chemosynthetic Communities 

Chemosynthetic communities are defined as persistent, largely sessile assemblages of marine organisms 

dependent upon chemosynthetic bacteria as their primary found source (MacDonald, 1992). 

Chemosynthetic clams, mussels, and tubeworms have been discovered in association with hydrocarbon 

seeps in the northern Gulf of Mexico. Initial discoveries of cold-water seep communities indicated that 

they are primarily associated with hydrocarbon and H2S seep areas (Kennicutt and Gallaway, 1985; 

Brooks et al., 1986a). Since the initial discovery in 1986 of chemosynthetic communities dependent on 

hydrocarbon seepage in the Gulf of Mexico, their geographic range has been found to include the Texas, 

Louisiana and Alabama continental slope with a depth range varying from less than 500 m to 2200 m 

(MacDonald, 1992). To date, there are 43 sites (in 40 blocks) across the northern Gulf of Mexico 

continental slope where the presence of chemosynthetic metazoans (dependent on hydrocarbon 

seepage) has been definitively documented (MacDonald, 1992). 

There are no documented high-density chemosynthetic communities in Green Canyon Blocks 609, 610 or 

653 according to Notice to Lessees and Operators (NTL) No. 2009-G40. Development activities have 

been carefully planned to avoid seafloor disturbance in the vicinity of features that could support highdensity chemosynthetic communities. 

There are no IPF’s (including effluents, physical disturbances to the seafloor, and accidents) from the 

proposed supplemental development activities in Green Canyon Blocks 609, 610 and 653 that could 

cause impacts to Chemosynthetic Communities (refer to information referenced in Section 6(a), 

Chemosynthetic Communities). 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 38 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

5. Water Quality 

There are no IPF’s (including effluents, physical disturbances to the seafloor, and accidents) from the 

proposed supplemental development activities in Green Canyon Blocks 609, 610 and 653 that could 

potentially cause impacts to water quality. The major discharges from offshore oil and gas production 

activities include produced water, ballast water, and uncontaminated seawater. Minor discharges from the 

offshore oil and gas industry include well completion and workover fluids; deck drainage; and other 

sanitary and domestic wastes, and miscellaneous discharges. Since all discharges will be made in 

accordance with a general National Pollutant Discharge Elimination System (NPDES) permit issued by 

U.S. Environmental Protection Agency (USEPA), operational discharges are not expected to cause 

significant adverse impacts to water quality. 

With regards to marine trash and debris, effective January 01, 2012, the Bureau of Safety and 

Environmental Enforcement issued BSEE NTL No. 2012-G01 pursuant to 30 CFR 250.103 to provide 

guidance and assist the operators in preventing intentional and / or accidental introduction of trash and 

debris into the marine environment. With this assistance and with laws such as MARPOL-Annex V, the 

Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies 

including the U.S. Coast Guard and the U.S. Environmental Protection Agency, our employees will 

ensure that all offshore personnel, including contractors and other support services-related personnel 

have complete understanding of the requirement that Operators be proactive in avoiding accidental loss 

of solid waste items on the OCS. 

Offshore accidents, such as blowouts and spills could also occur and have the potential to alter offshore 

water quality. Given the low frequency of blowouts documented by the BOEM, minimum impacts on 

water quality due to resuspension of sediments are expected. 

Oil spills related to the proposed action are assumed to be mostly very small events (and for spills greater 

than 50 bbl) to occur very infrequently. It is unlikely that an accidental oil spill would occur from the 

proposed development activities. If a spill were to occur, the dissolved components and small oil droplets 

would temporarily affect the water quality of marine waters. Dispersion by currents and microbial 

degradation would remove the oil from the water column or dilute the constituents to background levels. 

The activities proposed in this plan will be covered by our Regional OSRP. 

6. Fisheries 

Effects on commercial fisheries from development activities associated with this plan in Green Canyon 

Blocks 609, 610 or 653 could come from oil spills and subsurface blowouts. 

An accidental oil spill that may occur as a result of the proposed development has the potential to cause 

some detrimental effects to fisheries. However, it is unlikely that an accidental surface or subsurface oil 

spill would occur from the proposed development activities. 

 

Subsurface blowouts have the potential to adversely affect commercial fishery resources. Sandy 

sediments will be quickly redeposited within 400 m of the blowout site and finer sediments will be widely 

dispersed and redeposited over a period of 30 days or longer within a few thousand meters. 

If a spill were to occur in open waters of the OCS proximate to mobile adult finfish or shellfish, the effects 

would likely be sublethal 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. The effect of oil spills on fisheries is expected to cause less than 1 percent decrease in 

commercial populations or in commercial fishing. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 39 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Drilling mud discharges contain chemicals toxic to marine fishes; however, this is only at concentrations 4 

or 5 orders of magnitude higher than those found more than a few meters from the discharge point. 

Offshore discharges of drilling muds will dilute to background levels within 1000 meters of the discharge 

point and have a negligible effect on Central Gulf fisheries. 

The activities proposed in this plan will be covered by our Regional OSRP. 

7. Marine Mammals 

Marine mammals may be adversely impacted by several IPF’s (including vessel traffic, noise, accidental 

oil spills, and loss of trash and debris), all of which could occur due to the proposed development activity 

in Green Canyon Blocks 609, 610 and 653. 

Chronic and sporadic sublethal effects could 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 oil spills, chance collisions with service vessels and ingestion of 

plastic material. Oil spills of any size are estimated to be aperiodic events that may contact cetaceans. 

Disturbance (e.g., noise) may stress animals, weaken their immune systems, and make them more 

vulnerable to parasites and diseases that normally would not be fatal. 

The net result of any disturbance would depend on the size and percentage of the population affected, 

ecological importance of the disturbed area, environmental and biological parameters that influence an 

animal’s sensitivity to disturbance and stress, and the accommodation time in response to prolonged 

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

BSEE and BOEM issued JOINT NTL No. 2012-G01 pursuant to 30 CFR 250.103, 550.103 and also 

250.282 and 550.282 to explain how Operators must implement measures to minimize the risk of vessel 

strikes to protected species and report observations of injured or dead protected species effective 

January 1, 2012. We will ensure that our contract vessel operators are aware of their requirement to 

report sightings of any injured or dead protected species immediately to the BOEM Protected Species 

Biologist by telephone. 

With regards to marine trash and debris, effective January 1, 2012, BSEE issued BSEE NTL No. 2012-

G01 pursuant to 30 CFR 250.103 to provide guidance and assist the operators in preventing intentional 

and / or accidental introduction of trash and debris into the marine environment. With this assistance and 

with laws such as MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act, and 

regulations imposed by various agencies including the U.S. Coast Guard and the U.S. Environmental 

Protection Agency, our employees will ensure that all offshore personnel, including contractors and other 

support services-related personnel have complete understanding of the requirement that Operators be 

proactive in avoiding accidental loss of solid waste items on the OCS. 

8. Sea Turtles 

IPF’s that could impact sea turtles include vessel traffic, noise, trash and debris, and accidental oil spills. 

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 drill rigs, production facilities, and 

service vessels. Drilling rigs and project vessels produce noise that could disrupt normal behavior 

patterns and create some stress potentially making sea turtles more susceptible to disease. Oil spills and 

oil-spill-response activities are potential threats that could have lethal effects on turtles. Contact with oil, 

consumption of oil particles, and oil-contaminated prey could seriously affect individual sea turtles. Oilspill-response planning and the habitat protection requirements of the Oil Pollution Act of 1990 should 

mitigate these threats. Most OCS-related impacts on sea turtles are expected to be sublethal. Chronic 

sublethal effects (e.g., stress) resulting in persistent physiological or behavioral changes and / or 

avoidance of affected areas could cause declines in survival or productivity, resulting in gradual 

population declines. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 40 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

BSEE and BOEM issued JOINT NTL No. 2012-G01 pursuant to 30 CFR 250.103, 550.103 and also 

250.282 and 550.282 to explain how Operators must implement measures to minimize the risk of vessel 

strikes to protected species and report observations of injured or dead protected species effective 

January 1, 2012. We will ensure that our contract vessel operators are aware of their requirement to 

report sightings of any injured or dead protected species immediately to the BOEM Protected Species 

Biologist by telephone. 

With regards to marine trash and debris, effective January 1, 2012, BSEE issued BSEE NTL No. 2012-

G01 pursuant to 30 CFR 250.103 to provide guidance and assist the operators in preventing intentional 

and / or accidental introduction of trash and debris into the marine environment. With this assistance and 

with laws such as MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act, and 

regulations imposed by various agencies including the U.S. Coast Guard and the U.S. Environmental 

Protection Agency, our employees will ensure that all offshore personnel, including contractors and other 

support services-related personnel have complete understanding of the requirement that Operators be 

proactive in avoiding accidental loss of solid waste items on the OCS. 

The activities proposed in this plan will be covered by our Regional OSRP. 

9. Air Quality 

The proposed drilling and development activities are located 116 to 119 statute miles from the nearest 

Louisiana shoreline. 

Although the proposed operations are temporary in nature, there would be a limited degree of air quality 

degradation in the immediate vicinity. Emissions from drilling activities consist mainly of NOx and CO. 

These emissions are temporary in nature. Emissions of pollutants into the atmosphere from the drilling 

operations proposed are not expected to have significant impacts on onshore air quality because of the 

prevailing atmospheric conditions, emission heights, emission rates, and the distance of these emissions 

from the coastline. 

The Projected Air Quality Emissions Report indicates that the BOEM exemption level will not be 

exceeded during the operations proposed in the Supplemental DOCD. There are no existing facilities or 

activities co-located with the current proposed activities; therefore, the Complex Total Emissions are the 

same as the Plan Emissions. 

10. Shipwreck Sites (Known or Potential) 

There are no IPF’s (including physical disturbances to the seafloor) from the proposed supplemental 

activities in Green Canyon Blocks 609, 610 and 653 that could cause impacts to known or potential 

shipwreck sites. The proposed activities are not located in or adjacent to an OCS Block designated by 

BOEM as having high-probability for the occurrence of shipwrecks. 

However, in the event items of significant cultural resource potential are discovered during the proposed 

operations, BHPB will immediately halt all operations and notify the appropriate department at the Bureau 

of Ocean Energy Management for further evaluation and assistance. 

11. Prehistoric Archaeological Sites 

There are no IPF’s (including physical disturbances to the seafloor) from the proposed supplemental 

activities in Green Canyon Blocks 609, 610 and 653 that could cause impacts to prehistoric 

archaeological sites. The proposed activities are not located in or adjacent to an OCS Block designated 

by BOEM as having high-probability for the occurrence of prehistoric archaeological sites. 

However, in the event items of significant cultural resource potential are discovered during the proposed 

operations, BHPB will immediately halt all operations and notify the appropriate department at the Bureau 

of Ocean Energy Management for further evaluation and assistance. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 41 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

Vicinity of Offshore Location: 

1. Essential Fish Habitat 

IPF’s that could impact essential fish habitats as a result of the proposed development operations in the 

Shenzi Field include effluents and accidents. The major effluent discharges from offshore oil and gas 

production activities include produced water, ballast water, and uncontaminated seawater. Minor 

discharges from the offshore oil and gas industry include well completion and workover fluids; deck 

drainage; and other sanitary and domestic wastes, and miscellaneous discharges. Since all discharges 

will be made in accordance with a general National Pollutant Discharge Elimination System (NPDES) 

permit issued by U.S. Environmental Protection Agency (USEPA), operational discharges are not 

expected to cause significant adverse impacts to water quality. 

Offshore oil spillage from OCS operations is small compared with the volume of oil produced. Since 

1980, OCS operators have produced about 5.5 BBO of oil, while the amount of oil spilled offshore totaled 

about 61,500 bbl (0.001%) or 1 bbl spilled for every 89,500 produced. In 1994, BOEM revised its oil-spill 

occurrence rates for large spills (Anderson and LaBelle, 1994). An examination of the two major sources 

of OCS-related offshore spills (platforms and pipelines) shows that the greater risk of a large spill is from 

a pipeline. There have been no spills ≥1000 bbls from OCS platforms since 1980. 

An accidental oil spill that may occur as a result of the proposed development activity has the potential to 

cause some detrimental effects on essential fish habitat. However, it is unlikely that an accidental surface 

or subsurface oil spill would occur from the proposed activities. 

If a spill were to occur in open waters of the OCS proximate to mobile adult finfish or shellfish, the effects 

would likely be sublethal and the extent of damage would be limited and lessened due to the capability of 

adult fish and shellfish to avoid a spill, to metabolize hydrocarbons, and to excrete both metabolites and 

parent compounds. 

The activities proposed in this plan will be covered by our Regional OSRP. 

2. Marine and Pelagic Birds 

IPF’s that could impact marine and pelagic birds as a result of the proposed operations in Green Canyon 

Block 609, 610 or 653 include air emissions, accidents and discarded trash and debris. 

Emissions of pollutant into the atmosphere from the activities associated with the proposed development 

operations in this plan are not projected to have significant impacts on air quality that could harm marine 

and pelagic birds because of the prevailing atmospheric conditions, emission heights, emission rates and 

pollutant concentrations. 

An accidental oil spill that may occur as a result of the proposed action has the potential to cause some 

detrimental effects on marine and pelagic birds. Some physical oiling could occur during dives, as well as 

secondary toxic effects through the uptake of prey. 

The activities proposed in this plan will be covered by our Regional OSRP. 

With regards to marine trash and debris, coastal and marine birds can commonly become entangled and 

snared in discarded trash and debris. Effective January 1, 2012 BSEE issued BSEE NTL No. 2012-G01 

pursuant to 30 CFR 250.103 to provide guidance and assist the operators in preventing intentional and / 

or accidental introduction of trash and debris into the marine environment. With this assistance and with 

laws such as MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act, and regulations 

imposed by various agencies including the U.S. Coast Guard and the U.S. Environmental Protection 

Agency, our employees will ensure that all offshore personnel, including contractors and other support 

services-related personnel have complete understanding of the requirement that Operators be proactive 

in avoiding accidental loss of solid waste items on the OCS. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 42 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

3. Public Health and Safety Due to Accidents 

There are no IPF’s (including an accidental H2S releases) from the proposed development activities in the 

Shenzi Field that could cause impacts to public health and safety. 

In accordance with 30 CFR 250.490(c), NTL’s 2008-G04 and 2009-G27, we have submitted sufficient 

information to justify our request that the area of our proposed activities be classified by BOEM as H2S 

absent. (Refer to specific information submitted in Section 4 of the Plan.) 

Coastal and Onshore: 

1. Beaches 

There are no IPF’s (including accidents and marine trash and debris) associated with the development of 

the Shenzi Field that could pose a major threat to the enjoyment and use of recreational beaches. The 

operations proposed in this plan are not projected to have significant impacts on coastal beaches. 

The operations proposed in this Plan are 116 to 119 statute miles from the nearest shoreline. In the 

event of an accidental oil spill, the level of response will be based on volume, weather, and the 

characteristics of the product spilled. BHPB’s objectives for spill response are to ensure the safety of 

citizens and response personnel; control the source of the spill, have a coordinated response effort; 

maximize the protection of environmental sensitive areas; contain, recover and remove as much of the 

spill product as possible; recover and rehabilitate injured wildlife; minimize economic impacts; and keep 

the general public informed of the response activities. 

The activities proposed in this plan will be covered by our Regional OSRP. 

With regards to marine trash and debris, effective January 01, 2012, the BSEE issued BSEE NTL No. 

2012-G01 pursuant to 30 CFR 250.103 to provide guidance and assist the operators in preventing 

intentional and / or accidental introduction of trash and debris into the marine environment. With this 

assistance and with laws such as MARPOL-Annex V, the Marine Plastic Pollution Research and Control 

Act, and regulations imposed by various agencies including the U.S. Coast Guard and the U.S. 

Environmental Protection Agency, our employees will ensure that all offshore personnel, including 

contractors and other support services-related personnel have complete understanding of the 

requirement that Operators be proactive in avoiding accidental loss of solid waste items on the OCS. 

2. Wetlands 

There are no IPF’s (including accidents) associated with the development of the Shenzi Field that are 

projected to have a significant impact on wetlands. 

The operations proposed in this Plan are 116 to 119 statute miles from the nearest shoreline. In the 

event of an accidental oil spill, the level of response will be based on volume, weather, and the 

characteristics of the product spilled. BHPB’s objectives for spill response are to ensure the safety of 

citizens and response personnel; control the source of the spill, have a coordinated response effort; 

maximize the protection of environmental sensitive areas; contain, recover and remove as much of the 

spill product as possible; recover and rehabilitate injured wildlife; minimize economic impacts; and keep 

the general public informed of the response activities. 

The activities proposed in this plan will be covered by our Regional OSRP. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 43 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

3. Shore Birds and Coastal Nesting Birds 

There are no IPF’s (including accidents) associated with the development of Green Canyon Blocks 609, 

610 and 653 that are projected to have a significant impact on shore birds and coastal nesting birds. 

The operations proposed in this Plan are 116 to 119 statute miles from the nearest shoreline. In the 

event of an accidental oil spill, the level of response will be based on volume, weather, and the 

characteristics of the product spilled. BHPB’s objectives for spill response are to ensure the safety of 

citizens and response personnel; control the source of the spill, have a coordinated response effort; 

maximize the protection of environmental sensitive areas; contain, recover and remove as much of the 

spill product as possible; recover and rehabilitate injured wildlife; minimize economic impacts; and keep 

the general public informed of the response activities. 

The activities proposed in this plan will be covered by our Regional OSRP. 

4. Coastal Wildlife Refuges 

There are no IPF’s (including accidents) associated with the development of Green Canyon Blocks 609, 

610 and 653 that are projected to have a significant impact on coastal wildlife refuges. 

The operations proposed in this Plan are 116 to 119 statute miles from the nearest shoreline. In the 

event of an accidental oil spill, the level of response will be based on volume, weather, and the 

characteristics of the product spilled. BHPB’s objectives for spill response are to ensure the safety of 

citizens and response personnel; control the source of the spill, have a coordinated response effort; 

maximize the protection of environmental sensitive areas; contain, recover and remove as much of the 

spill product as possible; recover and rehabilitate injured wildlife; minimize economic impacts; and keep 

the general public informed of the response activities. 

The activities proposed in this plan will be covered by our Regional OSRP. 

 

5. Wilderness Areas 

There are no IPF’s (including accidents) associated with the development of Green Canyon Blocks 609, 

610 and 653 that are projected to have a significant impact on wilderness areas. 

The operations proposed in this Plan are 116 to 119 statute miles from the nearest shoreline. In the 

event of an accidental oil spill, the level of response will be based on volume, weather, and the 

characteristics of the product spilled. BHPB’s objectives for spill response are to ensure the safety of 

citizens and response personnel; control the source of the spill, have a coordinated response effort; 

maximize the protection of environmental sensitive areas; contain, recover and remove as much of the 

spill product as possible; recover and rehabilitate injured wildlife; minimize economic impacts; and keep 

the general public informed of the response activities. 

The activities proposed in this plan will be covered by our Regional OSRP. 

Other Environmental Resources Identified: None 

(d) Environmental Hazards 

The site-specific environmental conditions have been taken into account for the proposed activities under 

this plan. Being located in the Gulf of Mexico, all oil and gas exploratory and development operations 

may at sometime experience hurricane force winds, tropical storm activity and unusual surge and sea 

currents. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 44 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

In accordance with requirements set forth in Title 33 CFR 146.140, an Emergency Evacuation Plan (EEP) 

is prepared and submitted to the appropriate USCG Marine Safety Office or Unit for review and ultimate 

approval. This plan provides descriptions to help define the type of storm based on the winds associated 

with it (i.e. major gulf storm, squall, tropical depression, tropical storm, gale warning, storm warning, 

hurricane, etc). Major hurricanes (storm having wind speeds in excess of 74 mph) in the Gulf normally 

form in the southern Gulf or Caribbean Sea. Tropical disturbances (storms having wind speeds greater 

than 40 mph but less than 73 mph) that originate near the facility do not provide much warning, but 

usually pass the rig or facility prior to attaining hurricane status. 

Each tropical disturbance will be evaluated on its own merit and the operations modified accordingly. No 

impacts are expected on the proposed activities from site-specific environmental conditions. 

(e) Alternatives 

There are no alternatives other than those required by regulation to be considered to reduce the 

environmental impacts of the activities proposed in this plan. 

(f) Mitigation Measures 

No mitigation measures other than those required by regulation will be considered to avoid, lessen or 

eliminate potential impacts on environmental resources. 

(g) Consultation 

There were no outside agencies or persons consulted regarding the potential environmental impacts 

associated with the activities proposed under this Supplemental DOCD. 

(h) Preparer(s) 

Kathy Camp 

K. Camp & Associates 

Phone: 713.201.9627 

Email: Kathy.camp@kcampassociates.com 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 45 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

(i) References 

Geoscience Earth & Marine Services, Inc. Archaeological Assessment for BHP Billiton Petroleum, 

(BHPB) for Blocks 564-566, 608-610, 652-654, and 696-698, Green Canyon Area, in the U.S. Gulf of 

Mexico, based on previously collected AUV (Autonomous Underwater Vehicle) data and supplemented 

with recently acquired ROV (Remotely Operated Vehicle) data. 

Fugro GeoServices, Inc., Report No. 2405-2079 (SHE-FUG-05-GT-REP-0009), entitled EngineeringGeological Assessment - Shenzi Development, Green Canyon Area in the Gulf of Mexico

“Shenzi Prospect, Green Canyon Block 653, OCS-G-20084, Shallow Drilling Hazard Assessment for 

Supplemental Locations D and E” was prepared by Robert J. Bruce (Consulting Geophysicist) and 

submitted in conjunction with EP Control No. S 6112. 

Federal Register, Tuesday, August 30, 2005, 30 CFR Parts 250 and 282, Oil and Gas Sulphur 

Operations in the Outer Continental Shelf – Plans and Information; Final Rule effective September 29, 

2005 

Federal Register, Vol. 77, No. 163, August 22, 2012, Final Rule for Increased Safety Measures for 

Energy Development on the Outer Continental Shelf 

Federal Register, Vol. 75, No. 198, October 14, 2010, Final Rule for Increased Safety Measures for 

Energy Development on the Outer Continental Shelf 

NTL 2010-N06 effective June 18, 2010 for Information Requirements for Exploration Plans, Development 

and Production Plans, and Development Operations Coordination Documents on the OCS 

NTL 2009-G40 effective January 27, 2010 for Deepwater Benthic Communities 

NTL 2009-G39 effective January 27, 2010 for Biologically-Sensitive Underwater Features and Areas 

NTL 2009-G27 effective September 9, 2009 for Submitting Exploration Plans and Development 

Operations Coordination Documents 

NTL 2008-G04 effective May 1, 2008 for Information Requirements for Exploration Plans and 

Development Operations Coordination Documents 

BSEE NTL No. 2012-G01 effective January 1, 2012 for Marine Trash and Debris Awareness and 

Elimination 

JOINT NTL No. 2012-G01 effective January 1, 2012 for Vessel Strike Avoidance and Injured / Dead 

Protected Species Reporting 

Final EIS, Western Planning Area Sales (204, 207, 210, 215 & 218), and Central Planning Area Sales 

(025, 206, 208, 213, 216 & 222) 

Marine Mammal Protection Act of 1972 (MMPA) 

Endangered Species Act of 1973 (ESA) 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 46 Green Canyon Blocks 609, 610, 653 

Supplemental DOCD Leases OCS-G 16764, 16765, 20084 

SECTION 20 - ADMINISTRATIVE INFORMATION 

(a) Exempted Information Description (Public Information Copies Only) 

In accordance with 43 CFR Part 2, Appendix B, the following information is exempt from disclosure and 

has been omitted from the Public Information copy of this plan: 

 The geologic objectives, BHL, TVD, and MD information on form BOEM-137 (OCS Plan 

Information Form) in Attachment A 

 All items under Geological and Geophysical Information, except for the non-proprietary version of 

shallow hazards assessment 

 Correlative well information used to justify H2S classification request under Hydrogen Sulfide 

Information 

(b) Bibliography 

Initial DOCD (Control No. N-9001) approved for BHPB on September 18, 2007 

Revised DOCD (Control No. R-5124) approved for BHPB on May 31, 2011 

Supplemental DOCD (Control No. S-7487) approved for BHPB on November 16, 2011 

Geoscience Earth & Marine Services, Inc. Archaeological Assessment for BHP Billiton Petroleum, 

(BHPB) for Blocks 564-566, 608-610, 652-654, and 696-698, Green Canyon Area, in the U.S. Gulf of 

Mexico, based on previously collected AUV (Autonomous Underwater Vehicle) data and supplemented 

with recently acquired ROV (Remotely Operated Vehicle) data. 

Fugro GeoServices, Inc., Report No. 2405-2079 (SHE-FUG-05-GT-REP-0009), entitled EngineeringGeological Assessment - Shenzi Development, Green Canyon Area in the Gulf of Mexico

“Shenzi Prospect, Green Canyon Block 653, OCS-G-20084, Shallow Drilling Hazard Assessment for 

Supplemental Locations D and E” was prepared by Robert J. Bruce (Consulting Geophysicist) and 

submitted in conjunction with EP Control No. S 6112. 

PUBLIC INFORMATION COPY
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) X Development Operations Coordination Document 

Company Name: BHP Billiton Petroleum (GOM) Inc. BOEM Operator Number: 02010

Address: 1360 Post Oak Blvd, Suite 150 Contact Person: Kathy Camp

 Houston, TX 77056 Phone Number: 713.201.9627

Email Address: Kathy.camp@kcampassociates.com

 If a service fee is required under 30 CFR 550.125(a), provide the Amount paid 29,666.00 Receipt No. 74598493701 

Project and Worst Case Discharge (WCD)Information 

Lease(s): 16764, 16765, 20084 Area: GC Block(s): 609,        

610 , 653 Project Name (if applicable): Shenzi

Objective(s): X Oil X Gas Sulphur Salt Onshore Support Base(s): Fourchon, LA

Platform/Well Name Total Volume of WCD 131,116 STB/D API Gravity: 32.1̊

Distance to Closest Land (Miles): 116 & 119 Volume from uncontrolled blowout: 3.3 MMSTB

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

If so, provide the Control Number of the EP or DOCD with which this information was provided. S-7487 

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

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

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

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

Proposed Activity Start Date End Date No. of Days 

DRILL & COMPLETE H-A 07/01/2015 10/16/2015 108

Install 1 jumper 10/16/2015 10/20/2015 4

Commence Production 11/1/2015    

DRILL & COMPLETE H-FG (or H-FGt respud) 01/01/2016 04/18/2016 108

Install 1 jumper 04/18/2016 04/22/2016 4

Commence Production 06/01/2016    

DRILL & COMPLETE C-A (or C-Alt respud) 01/01/2017 04/18/2017 108

Install 1 jumper 04/18/2017 04/22/2017 4

Commence Production 06/01/2017    

DRILL & COMPLETE H-B 07/01/2018 10/16/2018 108

Install 1 jumper 10/16/2018 10/20/2018 4

Commence Production 11/01/2018    

DRILL & COMPLETE H-H 01/01/2019 04/18/2019 108

Install 1 jumper 04/18/2019 04/22/2019 4

Commence Production 06/01/2019

Description of Drilling Rig Description of Structure 

Jackup X Drillship Caisson Tension leg platform 

Gorilla Jackup Fixed platform Compliant tower 

Semisubmersible Submersible Spar Guyed tower 

DP Semisubmersible Other (attach description) Floating production 

system 

Other (Attach Description) 

Drilling Rig Name (if known): Invictus or CRL

Description of Lease Term Pipelines 

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

Four (4) GC 610 H-A, H-B, H-FG, H-H GC 610 Manifold H 6 60 

One (1) GC 653 C-A GC 653 Manifold C-1 6 60 

FORM BOEM-0137 (December 2011 - Supersedes all previous editions of this form which may not be used. Page 1 of 10

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) H-A

Previously reviewed under an approved EP or 

DOCD? 

 Yes 

X

No 

Is this an existing well or 

structure? 

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

Complex ID or API No. 

Complex ID. 

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

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day) 

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 

Surface Location Bottom-Hole Location (For 

Wells) 

Completion (For multiple 

completions, enter separate lines) 

Lease No. G-16765 

Area Name GC 

Block No. 610 

Block Line 

Departures 

(in feet) 

N/S Departure: 1173.37 FSL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 518.31 FWL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,582,438.31 X: 

X: 

X: 

Y: 9,932,853.37 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 20’ 32.856”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 05’ 52.554”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4275 MD (Feet): TVD (Feet): MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

NONE 

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 10 

 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) H-B

Previously reviewed under an approved EP or 

DOCD? 

 Yes 

X

No 

Is this an existing well or 

structure? 

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

Complex ID or API No. 

Complex ID. 

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

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day) 

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 

Surface Location Bottom-Hole Location (For 

Wells) 

Completion (For multiple 

completions, enter separate lines) 

Lease No. G-16765 

Area Name GC 

Block No. 610 

Block Line 

Departures 

(in feet) 

N/S Departure: 1144.02 FSL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 655.54 FWL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,582,575.54 X: 

X: 

X: 

Y: 9,932,824.02 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 20’ 32.534”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 05’ 51.041”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4275 MD (Feet): TVD (Feet): MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

NONE 

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 3 of 10 

 PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) H-FG

Previously reviewed under an approved EP or 

DOCD? 

 Yes 

X

No 

Is this an existing well or 

structure? 

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

Complex ID or API No. 

Complex ID. 

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

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day) 

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 

Surface Location Bottom-Hole Location (For 

Wells) 

Completion (For multiple 

completions, enter separate lines) 

Lease No. G-16765 

Area Name GC 

Block No. 610 

Block Line 

Departures 

(in feet) 

N/S Departure: 1173.37 FSL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 518.31 FWL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,582,438.31 X: 

X: 

X: 

Y: 9,932,853.37 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 20’ 32.856”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 05’ 52.554”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4275 MD (Feet): TVD (Feet): MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

NONE 

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 4 of 10 

 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) H-FGt

Previously reviewed under an approved EP or 

DOCD? 

 Yes 

X

No 

Is this an existing well or 

structure? 

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

Complex ID or API No. 

Complex ID. 

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

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day) 

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 

Surface Location Bottom-Hole Location (For 

Wells) 

Completion (For multiple 

completions, enter separate lines) 

Lease No. G-16765 

Area Name GC 

Block No. 610 

Block Line 

Departures 

(in feet) 

N/S Departure: 1181.55 FSL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 478.13 FWL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,582,398.13 X: 

X: 

X: 

Y: 9,932,861.55 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 20’ 32.946”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 05’ 52.997”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4275 MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

NONE 

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 5 of 10 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) H-H

Previously reviewed under an approved EP or 

DOCD? 

 Yes 

X

No 

Is this an existing well or 

structure? 

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

Complex ID or API No. 

Complex ID. 

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

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day) 111,701

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 32.1̊

Surface Location Bottom-Hole Location (For 

Wells) 

Completion (For multiple 

completions, enter separate lines) 

Lease No. G-16765 

Area Name GC 

Block No. 610 

Block Line 

Departures 

(in feet) 

N/S Departure: 1173.37 FSL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 518.31 FWL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,582,438.31 X: 

X: 

X: 

Y: 9,932,853.37 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 20’ 32.856”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 05’ 52.554”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4275 MD (Feet): TVD (Feet): MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

NONE 

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 6 of 10 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) C-A

Previously reviewed under an approved EP or 

DOCD? 

 Yes 

X

No 

Is this an existing well or 

structure? 

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

Complex ID or API No. 

Complex ID. 

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

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day) 

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 

Surface Location Bottom-Hole Location (For 

Wells) 

Completion (For multiple 

completions, enter separate lines) 

Lease No. G-20084 

Area Name GC 

Block No. 653 

Block Line 

Departures 

(in feet) 

N/S Departure: 4849.78 FNL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 251.39 FWL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,566,331.39 X: 

X: 

X: 

Y: 9,926,830.22 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 19’ 36.939”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 08’ 52.533”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4356 MD (Feet): TVD (Feet): MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

NONE 

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 7 of 10 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) C-Alt

Previously reviewed under an approved EP or 

DOCD? 

 Yes 

X

No 

Is this an existing well or 

structure? 

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

Complex ID or API No. 

Complex ID. 

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

WCD info For wells, volume of uncontrolled 

blowout (Bbls/day) 

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 

Surface Location Bottom-Hole Location (For 

Wells) 

Completion (For multiple 

completions, enter separate lines) 

Lease No. G-20084 

Area Name GC 

Block No. 653 

Block Line 

Departures 

(in feet) 

N/S Departure: 4808.32 FNL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 251.39 FWL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,566,331.39 X: 

X: 

X: 

Y: 9,926,871.68 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 19’ 37.349”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 08’ 52.522”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4356 MD (Feet): TVD (Feet): MD (Feet): 

MD (Feet): 

MD (Feet): 

TVD (Feet): 

TVD (Feet): 

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

NONE 

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 8 of 10 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

Provide the following information for the well with the highest Worst Case Discharge volume: 

Worst Case Discharge (WCD) Well Information 

WCD Well 

Name 

Surface Lease Surface 

Area/Block 

Bottom Lease Bottom 

Area/Block 

Product Type MD (feet) TVD (feet) 

 

Analog Well(s) 

Area/Block OCS Lease Well No. API No. 

 

 

 

 

 

Geologic Data for WCD 

Open Hole Interval for WCD 

Top (TVD in feet) Base (TVD in feet) 

 

Sand 1 Sand 2 Sand 3 Sand 

4 

Sand 5 Sand 6 Sand 7 Sand 8 

Formation Data 

Sand Name 

Estimated Top TVD 

Estimated Base TVD 

Estimated Net Sand Height 

MD (Net Pay if 

hydrocarbon) 

 

Estimated Net Sand Height 

TVT (net Pay if 

hydrocarbon) 

 

 

Fluid Type 

Used in WCD? (Yes/No) 

Seismic Survey Used 

Seismic Depth Volume Rich Azimuth Tier 3 Reverse Time Migration Depth Volume (RAZT3_RTM24_SB4_TTI_SS_Final_21Jun10) 

 

Engineering Data for WCD 

WCD Engineering Items 

WCD (STB/Day) 

WCD Calculated at Mudline Yes No Atmosphere Yes No 

Flow Correlation 

Outlet Pressure (Psia) 

Gas Turbulence Factor 

Software Model Used 

Sand 1 Sand 2 Sand 3 Sand 4 Sand 5 Sand 6 

Formation Data 

Sand Name 

Permeability (mD) 

Initial Pressure (PSIA) 

Sand 7 Sand 8 

Formation Data 

Sand Name 

Permeability (mD) 

Initial Pressure (PSIA) 

FORM BOEM-0137 (December 2011- Supersedes all previous editions of this form which may not be used.) Page 9 of 10 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED)

Sand 1 Sand 2 Sand 3 Sand 4 Sand 5 Sand 6 Sand 7 Sand 8 

Formation Data 

Reservoir Temperature (F) 

Porosity (0.00) 

Water Saturation (0.00) 

Rock Compressibility 

(microsips) 

Water Salinity (ppm) 

Drive Mechanism 

Drainage Area (acres) 

Oil Reservoir Data 

Bubble Point Pressure 

(PSIA) 

Initial Bo (RB/STB) 

Bo (RB/STB) @ Bubble 

Point 

Rsi (SCF/STB) 

Initial Oil Viscosity (Cp) 

Oil Viscosity (CP) @ 

Bubble Point 

Oil Compressibility 

(1/PSIA) 

Oil API Gravity (API) 

Specific Gas Gravity (0.00) 

Gas Reservoir Data 

Condensate API Gravity 

(API) 

Specific Gas Gravity (0.00) 

Yield (STB/MMCF) 

Source of Permeability Used 

Permeability from MDT 

Permeability from Core Analysis Percussion core Rotary sidewall core Conventional core: 

Pressure Transient Analysis 

Permeability from CMR or NMR log 

analysis 

Permeability from other source 

Provide Model Input Values for Relative Permeability: 

Residual Oil to Gas fraction (=1-Slc-Swc) 

Residual Oil to Water fraction (=Soc) 

Critical Gas fraction (Sgc, Gas/Oil-Water Systems) 

Residual Gas to Water fraction (Sgc, Gas/Gas-Water Systems) 

Kro Oil Curve Endpoint (fraction of absolute permeability) 

Krg Gas Curve Endpoint (fraction of absolute permeability) 

Krw Water Curve Endpoint (fraction of absolute permeability) 

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. 2501 et seq.) requires us to inform you that BOEM 

collects this information as part of an applicant’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We 

use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 

30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently 

valid Office of Management and Budget Control Number. Responses are mandatory (43 U.S.C. 1334). The public reporting burden for this form is included 

in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours with an 

accompanying EP, or 700 hours with an accompanying DPP or DOCD, including the time for reviewing instructions, gathering and maintaining data, and 

completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the 

Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170. 

FORM BOEM-0137 (December 2011- Supersedes all previous editions of this form which may not be used.) Page 10 of 10

PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
WATER DEPTH AND SEAFLOOR/ NEAR SEAFLOOR FEATURES MAP

PROPOSED SHENZI C-A LOCATION

 BLOCK 653, GREEN CANYON AREA, GULF OF MEXICO

N

Scale = 1: 12000

Legend

Drawn by: JRP 3/10/2014

PUBLIC INFORMATION COPY
WATER DEPTH AND SEAFLOOR/ NEAR SEAFLOOR FEATURES MAP

PROPOSED SHENZI H-A,-FG,-H, and H-B LOCATION

 BLOCK 610, GREEN CANYON AREA, GULF OF MEXICO

N

Scale = 1: 12000

Legend

Drawn by: JRP 3/10/2014

ATTACHMENT C PUBLIC INFORMATION COPY
Online Payment

Step 3: Confirm Payment 1 | 2 | 3

Thank you.

Your transaction has been successfully completed.

Pay.gov Tracking Information

Application Name: BOEM Development/DOCD Plan - BD

Pay.gov Tracking ID: 25F6LBG4

Agency Tracking ID: 74598493701

Transaction Date and Time: 04/08/2014 15:44 EDT

Payment Summary

Address Information

Account Holder 

Name: SUSAN WILSON 

Billing Address:

1360 POST OAK 

BLVD 

Billing Address 

2: SUITE 150 

City: HOUSTON 

State / 

Province: TX 

Zip / Postal 

Code: 77056 

Country: USA 

Account Information

Card Type: American Express 

Card 

Number: ************1009 

Region: Gulf of Mexico 

Contact: 

SUSAN WILSON 

713-599-6349 

Company 

Name/No: 

BHP BILLITON 

PETROLEUM (GOM), 

02010 

Lease 

Number(s): 

16764, 16765, 20084, 

, 

Area-Block: 

Green Canyon GC, 

609: , 610: , 653: , : , 

Type-Wells: Supplemental Plan, 7 

Payment Information

Payment Amount: $29,666.00

Transaction Date 

and Time:

04/08/2014 

15:44 EDT

Pay.gov - Online Payment Page 1 of 1

https://www.pay.gov/paygov/payments/authorizePlasticCardPayment.html 4/8/2014

PUBLIC INFORMATION COPY
please specify if the amount reported is a total or per well amount

Amount is per well 

Projected generated waste

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

Water-based drilling fluid NaCl brine; Evaporated Salt; 

Xanthan Gum; Barite 21,508 bbls 269 bbl/day

overboard / seafloor No

Cuttings wetted with water-based fluid Cuttings wetted with 

seawater, gel, and fresh water pad mud residue from riserless hole sections

3,112 bbls 39 bbl/day

seafloor No

Synthetic-based drilling fluid amount adhering to cuttings Baroid Accolade SBM 3,742 bbls 47 bbl/day overboard No

Cuttings wetted with synthetic-based fluid Cuttings wetted with residue 

of Baroid Accolade SBM 4,996 bbls 62 bbl/day overboard No

Will humans be there? If yes, expect conventional waste

Domestic waste Kitchen waste 31,760 bbls 397 bbl/day remove floating solids and discharge No

Sanitary waste Sanitary waste 3,840 bbls 48 bbl/day chlorinate and discharge No

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

Deck Drainage Rainfall & potable water 17,680 bbls 221 bbl/day filter oil and grease and discharge No

Will you conduct well treatment, completion, or workover? 

Well treatment fluids N/A N/A N/A N/A No

Well completion fluids Water based fluids & sea 

water 2,000 bbls 25 bbl/day Overboard w/ successful static sheen/O&G No

Workover fluids N/A N/A N/A N/A No

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

Desalinization unit discharge Max capacity 106,240 bbls 1,328 bbl/day overboard No

Blowout prevent fluid Stack Magic ECO-FV2 320 bbls 4 bbl/day overboard No

Ballast water Sea Water 98,209 bbls 500 bbl/day overboard No

Bilge water Oil/Water Mixture 2,000 bbls 25 bbl/day 0<15ppm overboard No

Excess cement at seafloor Class H 486 bbls 5 bbl/min seafloor No

Fire water Sea Water 86,240 bbls 1,078 bbl/day overboard No

Cooling water Sea Water 53,075,920 bbls 663,449 bbl/day overboard No

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

Produced water N/A N/A N/A N/A No

Will you be covered by an individual or general NPDES permit ? General PermitNOTE: 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 DISCHARGE TO THE GOM - Deepwater Invictus

Projected 

Downhole 

Disposal

Projected

Ocean

Discharges 

ATTACHMEN

PUBLIC INFORMATION COPY
please specify whether the amount reported is a total or per well

Projected 

generated waste

Solid and Liquid Wastes 

transportation 

Type of Waste - based on (1) 90-day well Composition Transport Method Name/Location of Facility Amount Disposal Method

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

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

Oil-based drilling fluid or mud N/A N/A N/A N/A N/ACuttings wetted with oil-based fluids N/A N/A N/A N/A N/ASynthetic-based drilling fluid or mud Whole mud sent back in after 

well has been abandoned for 

reconditioning & reuse

Below deck storage tanks on offshore 

support vessels

Baroid facility at Fourchon 

shore base

7,500 bbls/well recycled

Synthetic-based drilling fluid or mud Tank washings from offshore 

workboats (9.0 ppg Baroid 

Accolade SBM)

Below deck storage tanks on offshore 

support vessels

Newpark Environmental 

Services Inc., Fourchon, La

1,750 bbls/well injected

Cuttings wetted with Synthetic-based fluid Cuttings wetted with residue 

of Baroid 9.0 ppg Accolade

Cuttings boxes on offshore support 

vessels

Newpark Environmental 

Services Inc., Fourchon, La

750 bbls/well injected

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

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

Trash and debris non-recyclable / nonhazardous refuse generated 

by personnel on board MODU

transport in bags / baskets on vessel to shorebase - picked up at shorebase and trucked to private facility

River Birch Landfill in Avondale, LA via Galliano Waste Disposal in Galliano, LA

160 cu yds / well Landfill

Trash and debris non-hazardous recyclables 

and scrap metal

transport in bags / baskets on vessel to shorebase - picked up at shorebase and trucked to private facility

ARC in New Iberia, LA 50,000 lbs / well Recycle

Waste and Used oil oil filters, rags, pads, empty 

drums

transfer for recycle or fuel blending L&L Oilfield Services in 

Fourchon, LA or SafetyKleen Systems, Inc. transfer facility in Kenner, LA

320 lbs / well Recycle or fuel 

blend

Wash water water with trace amounts of 

internal olefin & ester

Picked up at shorebase & trucked to private facility 

Newpark Environmental Services Inc., Fourchon, La

1000 bbls/well injected

Chemical product wastes paint waste, chemicals, 

solvents, etc. N/A N/A N/A N/A

Waste Disposal

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

Will you have additional wastes that are not permitted for discharge? If yes, fill in the appropriate rows. 

NOTE: This corresponds to the cuttings wetted with synthetic base fluid that are captured in cutting boxes if the per well average limit of 6.9% ROC by weight is forecasted to be exceeded or in the event that "Tar" is encountered and "Zero" descharge is required.

ATTACHMENT H PUBLIC INFORMATION COPY
OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2011

COMPANY BHP Billiton Pet. (GOM) Inc.

AREA Green CanyonBLOCK 609, 610, 653LEASE OCS-G 16764, 16765, 20084PLATFORM Shenzi FieldWELL H-A, H-B, H-FG, H-H and C-ACOMPANY CONTACT Susan WilsonTELEPHONE NO. 713 599 6349REMARKS Drill and complete wells with Drillship (CR Luigs)

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

2015 42016 42017 42018 42019 4

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 1 of 8

PUBLIC INFORMATION COPY
EMISSIONS FACTORS

Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATE

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

Btu/hp-hr 2543.5

Equipment/Emission Factors units PM SOx NOx VOC CO CO2-e [1] REF. DATE

Diesel Turbines lb/MMBtu 0.0203 0.00152 0.88 0.00803 0.0124 163.6 AP-42 3.1-2a & 

Background 3.4-2 04/00

Diesel Recip. < 600 hp. lb/MMBtu 0.31 0.29 4.41 0.36 0.95 163.6 AP-42 3.3-1 10/96

Diesel Recip. < 600 hp. lb/hp-hr 0.0022 1.08E-05 0.031 0.0025141 0.00668 163.6 AP-42 3.3-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 4.89E-03 14 1.12 3.03 163.6 AP42 3.3-1 10/96

Diesel Recip. < 600 hp.-EPA Tier 1 [2] gms/kW-hr 0.54 9.2 1.3 11.4 EPA Tier 1

Diesel Recip. < 600 hp.-EPA Tier 1 [2] lb/hp-hr 0.000888 0.0151 0.00214 0.0187 EPA Tier 1

Diesel Recip. < 600 hp.-EPA Tier 2 [3] gms/kW-hr 0.2 6.4 3.5 EPA Tier 2

Diesel Recip. < 600 hp.-EPA Tier 2 [3] lb/hp-hr 0.000329 0.0109 0.00576 EPA Tier 2

Diesel Recip. < 600 hp.-EPA Tier 3 [4] gms/kW-hr 0.2 4 3.5 EPA Tier 3

Diesel Recip. < 600 hp.-EPA Tier 3 [4] lb/hp-hr 0.000329 0.00658 0.00576 EPA Tier 3

Diesel Recip. > 600 hp. lb/MMBtu 0.0573 0.001515 3.2 0.0819 0.85 163.6 AP-42 3.4-1 10/96

Diesel Recip. > 600 hp.-CRL-Main [5] g/kW-hr 17.02 2.42 COMM Test Apr-10

Diesel Recip. > 600 hp.-IMO Tier 1 (=> 

2000 rpm) [6] g/kW-hr 9.8 7.2 IMO Tier 1

Diesel Recip. > 600 hp.-Marine Tier 1 

(130-1999 rpm) [7] g/kW-hr 45*(N)^(-0.2) 40CFR94.8(a)(

1) 12/07

Diesel Recip. ≥37kw -Marine Tier 2 

(displacement 1.2 L - >5.0 L/cyl.) [8] g/kW-hr 0.2 7.20 5.0 40CFR94.8(a)(

2) 12/07

Diesel Recip. > 600 hp.-DD1-Main [9] g/kW-hr 14.06 1.98 COMM Test May-10

Diesel Recip. > 600 hp. lb/hp-hr 0.0007 0.000011 0.024 0.00064155 0.0055 163.6 AP-42 3.4-1 10/96

Diesel Recip. > 600 hp. gms/hp-hr 0.32 4.89E-03 11 0.33 2.4 163.6 AP42 3.4-1 10/96

Duel Fuel (NG & Diesel) lb/MMBtu 0.0573 0.183150 2.7 0.02 1.16 122.6 AP-42 3.4-1 10/96

Duel Fuel (NG & Diesel) lb/hp-hr 0.0007 0.001352 0.018 0.00132 0.0075 122.6 AP-42 3.4-1 10/96

Diesel Boiler lbs/bbl 0.084 0.009075 0.84 0.008 0.21 163.6 AP-42 1.3-12,14 9/98

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel [10] 0.0015 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 2.86 % weight

The following equations were used in formulating the conversion factors used in the application package

kW: hp = (kW) x (1.341 hp/kW). Factor = 1.341 hp/kW.

[10] BHPB utilizes Low Sulfur Diesel for all diesel combustion sources. Therefore, SO2 emissions have been calculated based on a maximum sulfur content of 15 ppm in diesel fuel 

assuming that 100 percent of sulfur in the fuel is oxidized to SO2. 

[9] Diesel Recip. > 600 hp.-DD1-Main: COMM Engineering testing of Transocean International's Development Driller 1 (DD-1) eight (8) main engines for NOx and CO was conducted 

May 2010. The NOx & CO emission factors conservatively utilized the maximum NOx and CO emission rates of the tests.

[1] The calculated emission factors for CO2-e (CO2, CH4 and N2O) are based on 40 CFR 98, Tables C-1 & C-2.

[5] Diesel Recip. > 600 hp.-CRL-Main: COMM Engineering testing of Transocean International's C.R. Luigs' (CRL) eight (8) main engines for NOx and CO was conducted April 2010. 

The NOx emission factor was conservatively calculated 110% of the test average; the CO emission factor utilizes the maximum CO emission rate of the tests.

[6] Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 rpm): NOx emission factors for IMO Tier 1 diesel engines on certain cement unit engines with rated engine rpm is equal to or greater 

than 2000.

[8] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.

[7] Diesel Recip. > 600 hp.-Marine Tier 1, for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm from 130-1999. Vessel (Crew) maximum rpm is 1,800 per main 

engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

[2] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, and CO emission factors for EPA Tier 1 diesel engines on certain wireline and cement unit engines.

[3] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines on certain wireline and cement unit engines.

[4] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline and cement unit engines.

FORM BOEM-139(October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). 

PUBLIC 

 Page 2 of 8

INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-A Susan Wilson 713 599 6349 Drill and complete wells with Drillship (CR Luigs)

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILL SHIP [1] 53737 2595.50 19924.50 24 108 40.58 0.58 1461.93 44.09 232.14 61578.13 16.82 0.24 606.02 18.28 96.23 25526.26

CRL PRIME MOVER>600hp diesel [2] [3] 47000 2270.10 54482.40 33.16 0.51 1315.12 34.19 186.99 53852.18 0.00 0.00 0.00 0.00 0.00 0.00

CRANES<600hp diesel [4] [5] 1220 58.93 1414.22 2.69 0.01 37.66 3.01 8.15 1397.84 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2064 99.69 2392.59 1.46 0.02 50.05 1.50 10.92 2364.87 0.00 0.00 0.00 0.00 0.00 0.00

EMERGENCY EQUIP<600hp diesel 323 15.60 374.42 0.71 0.00 9.97 0.80 2.16 370.08 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-POSU-CA PU Eng. [6] 600 28.98 695.52 0.20 0.01 3.95 1.48 3.46 687.46 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel--GSU-W Generator 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [7] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 561.43 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00BLACK START AIR COMPRESSOR 6 0.29 6.96 0.01 0.00 0.19 0.01 0.04 6.87 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS ≥37kw diesel(crew) (main-4) [9] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 47.62 10311.95 3.84 0.13 138.07 8.49 61.72 13364.29

VESSELS ≥37kw diesel(crew) (gens-3) [9] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.67 8.90 1240.87 0.46 0.02 16.61 3.47 11.54 1608.17

Work/Supply VESSELS>600hp diesel(work) (main-2) [10] 13196 637.37 15296.80 24 108 9.31 0.14 245.22 9.60 69.82 15119.62 12.07 0.18 317.81 12.44 90.49 19595.02

2 vessels VESSELS>600hp diesel(work) (gen.-2) [10] 4881 235.76 5658.33 24 108 3.44 0.05 80.65 3.55 25.83 5592.79 4.46 0.07 104.52 4.60 33.47 7248.26

VESSELS>600hp diesel(work) (SDT) [10] 2200 106.26 2550.24 24 108 1.55 0.02 36.35 1.60 11.64 2520.70 2.01 0.03 47.11 2.07 15.09 3266.83VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.48 1.24 3.35 574.64 1.43 0.01 20.06 1.60 4.34 744.74

INSTALLATION INSTALLATION Vessel >600hp diesel 47000 2270.1 54482.40 24 4 33.16 0.51 1139.80 34.19 248.68 53851.31 1.59 0.02 54.71 1.64 11.94 2584.86jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.99 0.18 412.27 12.37 89.95 19478.13 0.58 0.01 19.79 0.59 4.32 934.95umbilical VESSELS >600hp diesel (supply) 12000 579.6 13910.40 24 4 8.47 0.13 291.01 8.73 63.49 13749.27 0.41 0.01 13.97 0.42 3.05 659.97

2015 YEAR TOTAL (ANNUAL) 112.92 1.73 3802.06 124.60 801.42 184017.42 43.66 0.71 1338.67 53.61 332.17 75533.34

EXEMPTION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

[9] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[1] DRILL SHIP: TOI's CRL's average daily fuel usage for the period June 1, 2011 through May 31, 2012 was 13,283 gallons/day. Actual fuel usage is conservatively estimated at 150% of this average.[2] PRIME MOVER>600hp diesel: TOI's CRL's maximum output per main engine is 5875 hp/4184 kW with normal operation involving operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines.[3] PRIME MOVER>600hp diesel: Based on TOI's CRL. For all pollutants except NOx and CO, the maximum hourly emissions (lbs/hr) are calculated based on the appropriate AP-42 and EPA emission factor and the total engine rating of 5875 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of Transocean International's (TOI) C.R. Luigs' (CRL) eight (8) main engines for NOx and CO was conducted April 2010. The NOx emission factor was conservatively calculated 110% of the test average; the CO emission factor utilizes the maximum CO emission rate of the tests.[4] CRANES<600hp diesel: Based on TOI's CRL. Assumes operation of 4 of 4 cranes (305 hp each) at any one time.[5] CRANES<600hp diesel: Based on TOI's CRL. From TOI, each crane engine consumes 0.066 tonnes diesel /hr @ 75% load (27.32 gal per hour @ 100% load and 7.1 lb/gal.)[6] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline unit engines.[7] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.[8] Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 rpm): NOx emission factors for IMO Tier 1 diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[10] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-FG Susan Wilson 713 599 6349 Drill and complete wells with Drillship (CR Luigs)

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILL SHIP [1] 53737 2595.50 19924.50 24 108 40.58 0.58 1461.93 44.09 232.14 61578.13 16.82 0.24 606.02 18.28 96.23 25526.26

CRL PRIME MOVER>600hp diesel [2] [3] 47000 2270.10 54482.40 33.16 0.51 1315.12 34.19 186.99 53852.18 0.00 0.00 0.00 0.00 0.00 0.00

CRANES<600hp diesel [4] [5] 1220 58.93 1414.22 2.69 0.01 37.66 3.01 8.15 1397.84 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2064 99.69 2392.59 1.46 0.02 50.05 1.50 10.92 2364.87 0.00 0.00 0.00 0.00 0.00 0.00

EMERGENCY EQUIP<600hp diesel 323 15.60 374.42 0.71 0.00 9.97 0.80 2.16 370.08 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-POSU-CA PU Eng. [6] 600 28.98 695.52 0.20 0.01 3.95 1.48 3.46 687.46 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel--GSU-W Generator 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [7] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 561.43 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00BLACK START AIR COMPRESSOR 6 0.29 6.96 0.01 0.00 0.19 0.01 0.04 6.87 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS ≥37kw diesel(crew) (main-4) [9] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 47.62 10311.95 3.84 0.13 138.07 8.49 61.72 13364.29

VESSELS ≥37kw diesel(crew) (gens-3) [9] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.67 8.90 1240.87 0.46 0.02 16.61 3.47 11.54 1608.17

Work/Supply VESSELS>600hp diesel(work) (main-2) [10] 13196 637.37 15296.80 24 108 9.31 0.14 245.22 9.60 69.82 15119.62 12.07 0.18 317.81 12.44 90.49 19595.02

2 vessels VESSELS>600hp diesel(work) (gen.-2) [10] 4881 235.76 5658.33 24 108 3.44 0.05 80.65 3.55 25.83 5592.79 4.46 0.07 104.52 4.60 33.47 7248.26

VESSELS>600hp diesel(work) (SDT) [10] 2200 106.26 2550.24 24 108 1.55 0.02 36.35 1.60 11.64 2520.70 2.01 0.03 47.11 2.07 15.09 3266.83VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.48 1.24 3.35 574.64 1.43 0.01 20.06 1.60 4.34 744.74

INSTALLATION INSTALLATION Vessel >600hp diesel 47000 2270.1 54482.40 24 4 33.16 0.51 1139.80 34.19 248.68 53851.31 1.59 0.02 54.71 1.64 11.94 2584.86jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.99 0.18 412.27 12.37 89.95 19478.13 0.58 0.01 19.79 0.59 4.32 934.95umbilical VESSELS >600hp diesel (supply) 12000 579.6 13910.40 24 4 8.47 0.13 291.01 8.73 63.49 13749.27 0.41 0.01 13.97 0.42 3.05 659.97

2016 YEAR TOTAL (ANNUAL) 112.92 1.73 3802.06 124.60 801.42 184017.42 43.66 0.71 1338.67 53.61 332.17 75533.34

EXEMPTION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

[7] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.[8] Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 rpm): NOx emission factors for IMO Tier 1 diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[9] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[1] DRILL SHIP: TOI's CRL's average daily fuel usage for the period June 1, 2011 through May 31, 2012 was 13,283 gallons/day. Actual fuel usage is conservatively estimated at 150% of this average.[2] PRIME MOVER>600hp diesel: TOI's CRL's maximum output per main engine is 5875 hp/4184 kW with normal operation involving operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines.[3] PRIME MOVER>600hp diesel: Based on TOI's CRL. For all pollutants except NOx and CO, the maximum hourly emissions (lbs/hr) are calculated based on the appropriate AP-42 and EPA emission factor and the total engine rating of 5875 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of Transocean International's (TOI) C.R. Luigs' (CRL) eight (8) main engines for NOx and CO was conducted April 2010. The NOx emission factor was conservatively calculated 110% of the test average; the CO emission factor utilizes the maximum CO emission rate of the tests.[4] CRANES<600hp diesel: Based on TOI's CRL. Assumes operation of 4 of 4 cranes (305 hp each) at any one time.[5] CRANES<600hp diesel: Based on TOI's CRL. From TOI, each crane engine consumes 0.066 tonnes diesel /hr @ 75% load (27.32 gal per hour @ 100% load and 7.1 lb/gal.)[6] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline unit engines.[10] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field C-A Susan Wilson 713 599 6349 Drill and complete wells with Drillship (CR Luigs)

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILL SHIP [1] 53737 2595.50 19924.50 24 108 40.58 0.58 1461.93 44.09 232.14 61578.13 16.82 0.24 606.02 18.28 96.23 25526.26

CRL PRIME MOVER>600hp diesel [2] [3] 47000 2270.10 54482.40 33.16 0.51 1315.12 34.19 186.99 53852.18 0.00 0.00 0.00 0.00 0.00 0.00

CRANES<600hp diesel [4] [5] 1220 58.93 1414.22 2.69 0.01 37.66 3.01 8.15 1397.84 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2064 99.69 2392.59 1.46 0.02 50.05 1.50 10.92 2364.87 0.00 0.00 0.00 0.00 0.00 0.00

EMERGENCY EQUIP<600hp diesel 323 15.60 374.42 0.71 0.00 9.97 0.80 2.16 370.08 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-POSU-CA PU Eng. [6] 600 28.98 695.52 0.20 0.01 3.95 1.48 3.46 687.46 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel--GSU-W Generator 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [7] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 561.43 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00BLACK START AIR COMPRESSOR 6 0.29 6.96 0.01 0.00 0.19 0.01 0.04 6.87 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS ≥37kw diesel(crew) (main-4) [9] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 47.62 10311.95 3.84 0.13 138.07 8.49 61.72 13364.29

VESSELS ≥37kw diesel(crew) (gens-3) [9] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.67 8.90 1240.87 0.46 0.02 16.61 3.47 11.54 1608.17

Work/Supply VESSELS>600hp diesel(work) (main-2) [10] 13196 637.37 15296.80 24 108 9.31 0.14 245.22 9.60 69.82 15119.62 12.07 0.18 317.81 12.44 90.49 19595.02

2 vessels VESSELS>600hp diesel(work) (gen.-2) [10] 4881 235.76 5658.33 24 108 3.44 0.05 80.65 3.55 25.83 5592.79 4.46 0.07 104.52 4.60 33.47 7248.26

VESSELS>600hp diesel(work) (SDT) [10] 2200 106.26 2550.24 24 108 1.55 0.02 36.35 1.60 11.64 2520.70 2.01 0.03 47.11 2.07 15.09 3266.83VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.48 1.24 3.35 574.64 1.43 0.01 20.06 1.60 4.34 744.74

INSTALLATION INSTALLATION Vessel >600hp diesel 47000 2270.1 54482.40 24 4 33.16 0.51 1139.80 34.19 248.68 53851.31 1.59 0.02 54.71 1.64 11.94 2584.86jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.99 0.18 412.27 12.37 89.95 19478.13 0.58 0.01 19.79 0.59 4.32 934.95umbilical VESSELS >600hp diesel (supply) 12000 579.6 13910.40 24 4 8.47 0.13 291.01 8.73 63.49 13749.27 0.41 0.01 13.97 0.42 3.05 659.97

2017 YEAR TOTAL (ANNUAL) 112.92 1.73 3802.06 124.60 801.42 184017.42 43.66 0.71 1338.67 53.61 332.17 75533.34

EXEMPTION DISTANCE FROM LAND IN MILES 3962.70 3962.70 3962.70 3962.70 82257.76

119

[7] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.[8] Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 rpm): NOx emission factors for IMO Tier 1 diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[9] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[1] DRILL SHIP: TOI's CRL's average daily fuel usage for the period June 1, 2011 through May 31, 2012 was 13,283 gallons/day. Actual fuel usage is conservatively estimated at 150% of this average.[2] PRIME MOVER>600hp diesel: TOI's CRL's maximum output per main engine is 5875 hp/4184 kW with normal operation involving operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines.[3] PRIME MOVER>600hp diesel: Based on TOI's CRL. For all pollutants except NOx and CO, the maximum hourly emissions (lbs/hr) are calculated based on the appropriate AP-42 and EPA emission factor and the total engine rating of 5875 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of Transocean International's (TOI) C.R. Luigs' (CRL) eight (8) main engines for NOx and CO was conducted April 2010. The NOx emission factor was conservatively calculated 110% of the test average; the CO emission factor utilizes the maximum CO emission rate of the tests.[4] CRANES<600hp diesel: Based on TOI's CRL. Assumes operation of 4 of 4 cranes (305 hp each) at any one time.[5] CRANES<600hp diesel: Based on TOI's CRL. From TOI, each crane engine consumes 0.066 tonnes diesel /hr @ 75% load (27.32 gal per hour @ 100% load and 7.1 lb/gal.)[6] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline unit engines.[10] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-B Susan Wilson 713 599 6349 Drill and complete wells with Drillship (CR Luigs)

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILL SHIP [1] 53737 2595.50 19924.50 24 108 40.58 0.58 1461.93 44.09 232.14 61578.13 16.82 0.24 606.02 18.28 96.23 25526.26

CRL PRIME MOVER>600hp diesel [2] [3] 47000 2270.10 54482.40 33.16 0.51 1315.12 34.19 186.99 53852.18 0.00 0.00 0.00 0.00 0.00 0.00

CRANES<600hp diesel [4] [5] 1220 58.93 1414.22 2.69 0.01 37.66 3.01 8.15 1397.84 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2064 99.69 2392.59 1.46 0.02 50.05 1.50 10.92 2364.87 0.00 0.00 0.00 0.00 0.00 0.00

EMERGENCY EQUIP<600hp diesel 323 15.60 374.42 0.71 0.00 9.97 0.80 2.16 370.08 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-POSU-CA PU Eng. [6] 600 28.98 695.52 0.20 0.01 3.95 1.48 3.46 687.46 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel--GSU-W Generator 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [7] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 561.43 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00BLACK START AIR COMPRESSOR 6 0.29 6.96 0.01 0.00 0.19 0.01 0.04 6.87 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS ≥37kw diesel(crew) (main-4) [9] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 47.62 10311.95 3.84 0.13 138.07 8.49 61.72 13364.29

VESSELS ≥37kw diesel(crew) (gens-3) [9] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.67 8.90 1240.87 0.46 0.02 16.61 3.47 11.54 1608.17

Work/Supply VESSELS>600hp diesel(work) (main-2) [10] 13196 637.37 15296.80 24 108 9.31 0.14 245.22 9.60 69.82 15119.62 12.07 0.18 317.81 12.44 90.49 19595.02

2 vessels VESSELS>600hp diesel(work) (gen.-2) [10] 4881 235.76 5658.33 24 108 3.44 0.05 80.65 3.55 25.83 5592.79 4.46 0.07 104.52 4.60 33.47 7248.26

VESSELS>600hp diesel(work) (SDT) [10] 2200 106.26 2550.24 24 108 1.55 0.02 36.35 1.60 11.64 2520.70 2.01 0.03 47.11 2.07 15.09 3266.83VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.48 1.24 3.35 574.64 1.43 0.01 20.06 1.60 4.34 744.74

INSTALLATION INSTALLATION Vessel >600hp diesel 47000 2270.1 54482.40 24 4 33.16 0.51 1139.80 34.19 248.68 53851.31 1.59 0.02 54.71 1.64 11.94 2584.86jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.99 0.18 412.27 12.37 89.95 19478.13 0.58 0.01 19.79 0.59 4.32 934.95umbilical VESSELS >600hp diesel (supply) 12000 579.6 13910.40 24 4 8.47 0.13 291.01 8.73 63.49 13749.27 0.41 0.01 13.97 0.42 3.05 659.97

2018 YEAR TOTAL (ANNUAL) 112.92 1.73 3802.06 124.60 801.42 184017.42 43.66 0.71 1338.67 53.61 332.17 75533.34

EXEMPTION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

[7] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.[8] Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 rpm): NOx emission factors for IMO Tier 1 diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[9] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[1] DRILL SHIP: TOI's CRL's average daily fuel usage for the period June 1, 2011 through May 31, 2012 was 13,283 gallons/day. Actual fuel usage is conservatively estimated at 150% of this average.[2] PRIME MOVER>600hp diesel: TOI's CRL's maximum output per main engine is 5875 hp/4184 kW with normal operation involving operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines.[3] PRIME MOVER>600hp diesel: Based on TOI's CRL. For all pollutants except NOx and CO, the maximum hourly emissions (lbs/hr) are calculated based on the appropriate AP-42 and EPA emission factor and the total engine rating of 5875 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of Transocean International's (TOI) C.R. Luigs' (CRL) eight (8) main engines for NOx and CO was conducted April 2010. The NOx emission factor was conservatively calculated 110% of the test average; the CO emission factor utilizes the maximum CO emission rate of the tests.[4] CRANES<600hp diesel: Based on TOI's CRL. Assumes operation of 4 of 4 cranes (305 hp each) at any one time.[5] CRANES<600hp diesel: Based on TOI's CRL. From TOI, each crane engine consumes 0.066 tonnes diesel /hr @ 75% load (27.32 gal per hour @ 100% load and 7.1 lb/gal.)[6] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline unit engines.[10] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-H Susan Wilson 713 599 6349 Drill and complete wells with Drillship (CR Luigs)

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILL SHIP [1] 53737 2595.50 19924.50 24 108 40.58 0.58 1461.93 44.09 232.14 61578.13 16.82 0.24 606.02 18.28 96.23 25526.26

CRL PRIME MOVER>600hp diesel [2] [3] 47000 2270.10 54482.40 33.16 0.51 1315.12 34.19 186.99 53852.18 0.00 0.00 0.00 0.00 0.00 0.00

CRANES<600hp diesel [4] [5] 1220 58.93 1414.22 2.69 0.01 37.66 3.01 8.15 1397.84 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2064 99.69 2392.59 1.46 0.02 50.05 1.50 10.92 2364.87 0.00 0.00 0.00 0.00 0.00 0.00

EMERGENCY EQUIP<600hp diesel 323 15.60 374.42 0.71 0.00 9.97 0.80 2.16 370.08 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-POSU-CA PU Eng. [6] 600 28.98 695.52 0.20 0.01 3.95 1.48 3.46 687.46 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel--GSU-W Generator 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.94 0.40 1.07 183.32 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [7] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 561.43 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [8] 860 41.54 996.91 0.61 0.01 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00BLACK START AIR COMPRESSOR 6 0.29 6.96 0.01 0.00 0.19 0.01 0.04 6.87 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS ≥37kw diesel(crew) (main-4) [9] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 47.62 10311.95 3.84 0.13 138.07 8.49 61.72 13364.29

VESSELS ≥37kw diesel(crew) (gens-3) [9] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.67 8.90 1240.87 0.46 0.02 16.61 3.47 11.54 1608.17

Work/Supply VESSELS>600hp diesel(work) (main-2) [10] 13196 637.37 15296.80 24 108 9.31 0.14 245.22 9.60 69.82 15119.62 12.07 0.18 317.81 12.44 90.49 19595.02

2 vessels VESSELS>600hp diesel(work) (gen.-2) [10] 4881 235.76 5658.33 24 108 3.44 0.05 80.65 3.55 25.83 5592.79 4.46 0.07 104.52 4.60 33.47 7248.26

VESSELS>600hp diesel(work) (SDT) [10] 2200 106.26 2550.24 24 108 1.55 0.02 36.35 1.60 11.64 2520.70 2.01 0.03 47.11 2.07 15.09 3266.83VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.48 1.24 3.35 574.64 1.43 0.01 20.06 1.60 4.34 744.74

INSTALLATION INSTALLATION Vessel >600hp diesel 47000 2270.1 54482.40 24 4 33.16 0.51 1139.80 34.19 248.68 53851.31 1.59 0.02 54.71 1.64 11.94 2584.86jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.99 0.18 412.27 12.37 89.95 19478.13 0.58 0.01 19.79 0.59 4.32 934.95umbilical VESSELS >600hp diesel (supply) 12000 579.6 13910.40 24 4 8.47 0.13 291.01 8.73 63.49 13749.27 0.41 0.01 13.97 0.42 3.05 659.97

2019 YEAR TOTAL (ANNUAL) 112.92 1.73 3802.06 124.60 801.42 184017.42 43.66 0.71 1338.67 53.61 332.17 75533.34

EXEMPTION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

[7] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.[8] Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 rpm): NOx emission factors for IMO Tier 1 diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[9] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[1] DRILL SHIP: TOI's CRL's average daily fuel usage for the period June 1, 2011 through May 31, 2012 was 13,283 gallons/day. Actual fuel usage is conservatively estimated at 150% of this average.[2] PRIME MOVER>600hp diesel: TOI's CRL's maximum output per main engine is 5875 hp/4184 kW with normal operation involving operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines.[3] PRIME MOVER>600hp diesel: Based on TOI's CRL. For all pollutants except NOx and CO, the maximum hourly emissions (lbs/hr) are calculated based on the appropriate AP-42 and EPA emission factor and the total engine rating of 5875 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of Transocean International's (TOI) C.R. Luigs' (CRL) eight (8) main engines for NOx and CO was conducted April 2010. The NOx emission factor was conservatively calculated 110% of the test average; the CO emission factor utilizes the maximum CO emission rate of the tests.[4] CRANES<600hp diesel: Based on TOI's CRL. Assumes operation of 4 of 4 cranes (305 hp each) at any one time.[5] CRANES<600hp diesel: Based on TOI's CRL. From TOI, each crane engine consumes 0.066 tonnes diesel /hr @ 75% load (27.32 gal per hour @ 100% load and 7.1 lb/gal.)[6] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline unit engines.[10] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELL

BHP Billiton Pet. (GOM) Inc. Green Canyon 609, 610, 653 OCS-G 16764, 16765, Shenzi Field H-A, H-B, H-FG, H-H and C

Emitted Substance

Year

PM SOx NOx VOC CO

2015 43.66 0.71 1338.67 53.61 332.17

2016 43.66 0.71 1338.67 53.61 332.17

2017 43.66 0.71 1338.67 53.61 332.17

2018 43.66 0.71 1338.67 53.61 332.17

2019 43.66 0.71 1338.67 53.61 332.17

Allowable 3862.80 3862.80 3862.80 3862.80 80869.40

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 8 of 8

PUBLIC INFORMATION COPY
OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2011

COMPANY BHP Billiton Pet. (GOM) Inc.

AREA Green CanyonBLOCK 609, 610, 653LEASE OCS-G 16764, 16765, 20084

PLATFORM Shenzi FieldWELL H-A, H-B, H-FG, H-H and C-ACOMPANY CONTACT Susan WilsonTELEPHONE NO. 713 599 6349REMARKS Drill and complete wells with Drillship (Invictus)

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

2015 42016 42017 42018 42019 4

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 1 of 8

PUBLIC INFORMATION COPY
EMISSIONS FACTORS

Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATE

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

Btu/hp-hr 2543.5

Equipment/Emission Factors units PM SOx NOx VOC CO CO2-e [1] REF. DATE

Diesel Turbines lb/MMBtu 0.0203 0.00152 0.88 0.00803 0.0124 163.6 AP-42 3.1-2a & 

Background 3.4-2 04/00

Diesel Recip. < 600 hp. lb/MMBtu 0.31 0.29 4.41 0.36 0.95 163.6 AP-42 3.3-1 10/96

Diesel Recip. < 600 hp. lb/hp-hr 0.0022 1.08E-05 0.031 0.0025141 0.00668 1.15 AP-42 3.3-1 10/96

Diesel Recip. < 600 hp. g/hp-hr 1 4.89E-03 14.06 1.14 3.03 521.6 AP42 3.3-1 10/96

Diesel Recip. < 600 hp.-EPA Tier 1 [2] g/kW-hr 0.54 9.2 1.3 11.4 EPA Tier 1

Diesel Recip. < 600 hp.-EPA Tier 1 [2] lb/hp-hr 0.000888 0.0151 0.00214 0.0187 EPA Tier 1

Diesel Recip. > 600 hp.-EPA Tier 1 [10] g/kW-hr 0.54 9.2 1.3 11.4 EPA Tier 1

Diesel Recip. < 600 hp.-EPA Tier 2 [3] g/kW-hr 0.2 6.4 3.5 EPA Tier 2

Diesel Recip. < 600 hp.-EPA Tier 2 [3] lb/hp-hr 0.000329 0.0109 0.00576 EPA Tier 2

Diesel Recip. < 600 hp.-EPA Tier 3 [4] g/kW-hr 0.3 4 5 EPA Tier 3

Diesel Recip. < 600 hp.-EPA Tier 3 [4] lb/hp-hr 0.000329 0.00658 0.00576 EPA Tier 3

Diesel Recip. > 600 hp. lb/MMBtu 0.0573 0.001515 3.2 0.0819 0.85 163.6 AP-42 3.4-1 10/96

Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 

rpm) [5] g/kW-hr 9.8 7.2 IMO Tier 1

Diesel Recip. > 600 hp.-Marine Tier 1 (130-

1999 rpm) [6] g/kW-hr 45*(N)^(-0.2) 40CFR94.8(a)(1) 12/07

Diesel Recip. ≥37kw -Marine Tier 2 

(displacement 1.2 L - >5.0 L/cyl.) [7] g/kW-hr 0.2 7.20 5.0 40CFR94.8(a)(2) 12/07

Diesel Recip. > 600 hp.-Invictus-Main [8] g/kW-hr 9.7 Main Engines 

Manufacturer Data

Diesel Recip. > 600 hp. lb/hp-hr 7.00E-04 1.08E-05 0.024 0.0007 0.0055 1.16 AP-42 3.4-1 10/96

Diesel Recip. > 600 hp. g/hp-hr 0.32 4.89E-03 11 0.33 2.49 526.2 AP42 3.4-1 10/96

Duel Fuel (NG & Diesel) lb/MMBtu 0.0573 0.183150 2.7 0.02 1.16 122.6 AP-42 3.4-1 10/96

Duel Fuel (NG & Diesel) lb/hp-hr 0.0007 0.001352 0.018 0.00132 0.0075 122.6 AP-42 3.4-1 10/96

Diesel Boiler lbs/bbl 0.084 0.009075 0.84 0.008 0.21 163.6 AP-42 1.3-12,14 9/98

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel [9] 0.0015 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 2.86 % weight

The following equations were used in formulating the conversion factors used in the application package

kW: hp = (kW) x (1.341 hp/kW). Factor = 1.341 hp/kW.

[10] Diesel Recip. > 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.

[9] BHPB utilizes Ultra Low Sulfur Diesel for all diesel combustion sources. Therefore, SO2 emissions have been calculated based on a maximum sulfur content of 15 ppm in diesel fuel assuming tha

100 percent of sulfur in the fuel is oxidized to SO2. 

[8] Diesel Recip. > 600 hp.-Invictus-Main: NOx emission factor is based on the TOI Invictus engine manufacturer's data. The main engines on Invictus are IMO Tier II certified engines.

[1] The calculated emission factors for CO2-e (CO2, CH4 and N2O) are based on 40 CFR 98, Tables C-1 & C-2.

[5] Diesel Recip. > 600 hp.-IMO Tier 1 (=> 2000 rpm): NOx emission factors for IMO Tier 1 diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.

[7] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.

[6] Diesel Recip. > 600 hp.-Marine Tier 1, for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm from 130-1999. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel 

(Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

[2] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, and CO emission factors for EPA Tier 1 diesel engines on certain wireline and cement unit engines.

[3] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines on certain wireline and cement unit engines.

[4] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline and cement unit engines.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). 

PUBLIC 

 Page 2 of 8

INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Inc. Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-A Susan Wilson 713 599 6349

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILLSHIP 64865 3132.98 75191.51 24 108 46.05 0.70 1047.17 54.77 378.57 75205.34 59.69 0.91 1357.14 70.98 490.62 97466.12

PRIME MOVER>600hp diesel [1] [2] 56310 2719.77 65274.55 39.42 0.61 897.98 40.97 309.71 65319.60 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2279 110.08 2641.82 1.60 0.02 54.70 1.66 12.53 2643.64 0.00 0.00 0.00 0.00 0.00 0.002-300 HP WIRELINE <600hp diesel-POSU-CA PU Eng. [3] 600 28.98 695.52 0.20 0.01 3.95 1.51 3.46 690.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-GSU-W Generator 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel-Batch Mixer [4] 250 12.08 289.80 0.08 0.00 2.73 0.63 1.44 287.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel (Nitrogen pump) [5] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 563.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Fast Rescue 149 7.20 172.72 0.33 0.00 4.62 0.37 1.00 171.35 0.00 0.00 0.00 0.00 0.00 0.006-29HP EMERGENCY EQUIP <600hp diesel-Lifeboat 174 8.40 201.70 0.38 0.00 5.39 0.44 1.16 200.10 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Air Compressor 38 1.84 44.05 0.08 0.00 1.18 0.10 0.25 43.70 0.00 0.00 0.00 0.00 0.00 0.00

3-415 HP SEISMIC OP ENGINE <600hp diesel [8] 1245 60.13 1443.20 0.41 0.01 13.57 3.13 7.17 1431.75 0.00 0.00 0.00 0.00 0.00 0.00

SLICKLINE <600hp diesel [9] 106 5.12 122.88 0.23 0.00 1.60 0.27 0.71 121.90 0.00 0.00 0.00 0.00 0.00 0.00

FLUID FILTRATION PUMP <600hp diesel [10] 174 8.40 201.70 0.09 0.00 1.14 0.44 1.43 200.10 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING POWER PACK <600hp diesel [11] 260 12.56 301.39 0.23 0.00 3.93 0.56 4.87 299.00 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING PUMP >600hp diesel [12] 750 36.23 869.40 0.67 0.01 11.34 1.60 14.06 870.00 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS>600hp diesel(crew) (main-4) [13] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 49.50 10440.00 3.84 0.13 138.07 8.49 64.15 13530.24

VESSELS<600hp diesel(crew) (gens-3) [13] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.72 8.90 1245.45 0.46 0.02 16.61 3.53 11.54 1614.10

Work/Supply VESSELS>600hp diesel(work) (main-2) [7] 13196 637.37 15296.80 24 108 9.24 0.14 245.22 9.60 72.58 15307.36 11.97 0.18 317.81 12.44 94.06 19838.34

2 vessels VESSELS>600hp diesel(work) (gen.-2) [7] 8000 386.40 9273.60 24 108 5.60 0.09 132.18 5.82 44.00 9280.00 7.26 0.11 171.30 7.54 57.02 12026.88

VESSELS>600hp diesel(work) (SDT) [7] 2200 106.26 2550.24 24 108 1.54 0.02 36.35 1.60 12.10 2552.00 2.00 0.03 47.11 2.07 15.68 3307.39VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.55 1.26 3.35 581.78 1.43 0.01 20.15 1.63 4.34 753.99

INSTALLATION INSTALLATION Vessel >600hp diesel 4700 227.01 5448.24 24 4 3.29 0.05 112.80 3.42 25.85 17319.46 0.16 0.00 5.41 0.16 1.24 831.33jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.90 0.18 408.00 12.37 93.50 62644.87 0.57 0.01 19.58 0.59 4.49 3006.95umbilical VESSELS>600hp diesel(supply) 12000 579.6 13910.40 24 4 8.40 0.13 288.00 8.73 66.00 44219.91 0.40 0.01 13.82 0.42 3.17 2122.56

2015 YEAR TOTAL (ANNUAL) 90.44 1.43 2404.62 106.84 754.35 238796.17 87.77 1.40 2107.01 107.86 746.32 154497.90

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

Drill and complete wells with Drillship (Invictus)

[1] PRIME MOVER >600hp diesel-Invictus: TOI's Invictus maximum output per main engine is 9385 hp/7000 kW. These calculations conservatively assume operating 6 of 6 engines.[2] PRIME MOVER >600 hp. diesel-Invictus: NOx emission factor is based on the TOI Invictus engine manufacturer's data. The main engines on Invictus are IMO Tier II certified engines.[3] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline and cement unit engines.[4] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines on certain wireline and cement unit engines.[5] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.[6] Diesel Recip. > 600 hp.-IMO Tier I (=> 2000 rpm): NOx emission factors for IMO Tier I diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[7] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.[8] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines.[13] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[9] Diesel Recip. < 600 hp.-EPA Tier 1: NOx emission factor for EPA Tier 1 diesel engines.[10] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines.[11] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.[12] Diesel Recip. > 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Inc. Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-FG Susan Wilson 713 599 6349

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILLSHIP 64865 3132.98 75191.51 24 108 46.05 0.70 1047.17 54.77 378.57 75205.34 59.69 0.91 1357.14 70.98 490.62 97466.12

PRIME MOVER>600hp diesel [1] [2] 56310 2719.77 65274.55 39.42 0.61 897.98 40.97 309.71 65319.60 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2279 110.08 2641.82 1.60 0.02 54.70 1.66 12.53 2643.64 0.00 0.00 0.00 0.00 0.00 0.002-300 HP WIRELINE <600hp diesel-POSU-CA PU Eng. [3] 600 28.98 695.52 0.20 0.01 3.95 1.51 3.46 690.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-GSU-W Generator 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel-Batch Mixer [4] 250 12.08 289.80 0.08 0.00 2.73 0.63 1.44 287.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel (Nitrogen pump) [5] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 563.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Fast Rescue 149 7.20 172.72 0.33 0.00 4.62 0.37 1.00 171.35 0.00 0.00 0.00 0.00 0.00 0.006-29HP EMERGENCY EQUIP <600hp diesel-Lifeboat 174 8.40 201.70 0.38 0.00 5.39 0.44 1.16 200.10 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Air Compressor 38 1.84 44.05 0.08 0.00 1.18 0.10 0.25 43.70 0.00 0.00 0.00 0.00 0.00 0.00

3-415 HP SEISMIC OP ENGINE <600hp diesel [8] 1245 60.13 1443.20 0.41 0.01 13.57 3.13 7.17 1431.75 0.00 0.00 0.00 0.00 0.00 0.00

SLICKLINE <600hp diesel [9] 106 5.12 122.88 0.23 0.00 1.60 0.27 0.71 121.90 0.00 0.00 0.00 0.00 0.00 0.00

FLUID FILTRATION PUMP <600hp diesel [10] 174 8.40 201.70 0.09 0.00 1.14 0.44 1.43 200.10 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING POWER PACK <600hp diesel [11] 260 12.56 301.39 0.23 0.00 3.93 0.56 4.87 299.00 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING PUMP >600hp diesel [12] 750 36.23 869.40 0.67 0.01 11.34 1.60 14.06 870.00 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS>600hp diesel(crew) (main-4) [13] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 49.50 10440.00 3.84 0.13 138.07 8.49 64.15 13530.24

VESSELS<600hp diesel(crew) (gens-3) [13] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.72 8.90 1245.45 0.46 0.02 16.61 3.53 11.54 1614.10

Work/Supply VESSELS>600hp diesel(work) (main-2) [7] 13196 637.37 15296.80 24 108 9.24 0.14 245.22 9.60 72.58 15307.36 11.97 0.18 317.81 12.44 94.06 19838.34

2 vessels VESSELS>600hp diesel(work) (gen.-2) [7] 8000 386.40 9273.60 24 108 5.60 0.09 132.18 5.82 44.00 9280.00 7.26 0.11 171.30 7.54 57.02 12026.88

VESSELS>600hp diesel(work) (SDT) [7] 2200 106.26 2550.24 24 108 1.54 0.02 36.35 1.60 12.10 2552.00 2.00 0.03 47.11 2.07 15.68 3307.39VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.55 1.26 3.35 581.78 1.43 0.01 20.15 1.63 4.34 753.99

INSTALLATION INSTALLATION Vessel >600hp diesel 4700 227.01 5448.24 24 4 3.29 0.05 112.80 3.42 25.85 17319.46 0.16 0.00 5.41 0.16 1.24 831.33jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.90 0.18 408.00 12.37 93.50 62644.87 0.57 0.01 19.58 0.59 4.49 3006.95umbilical VESSELS>600hp diesel(supply) 12000 579.6 13910.40 24 4 8.40 0.13 288.00 8.73 66.00 44219.91 0.40 0.01 13.82 0.42 3.17 2122.56

2016 YEAR TOTAL (ANNUAL) 90.44 1.43 2404.62 106.84 754.35 238796.17 87.77 1.40 2107.01 107.86 746.32 154497.90

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

[12] Diesel Recip. > 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.[13] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[5] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.[6] Diesel Recip. > 600 hp.-IMO Tier I (=> 2000 rpm): NOx emission factors for IMO Tier I diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[7] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.[8] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines.[9] Diesel Recip. < 600 hp.-EPA Tier 1: NOx emission factor for EPA Tier 1 diesel engines.[10] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines.[11] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.

Drill and complete wells with Drillship (Invictus)

[1] PRIME MOVER >600hp diesel-Invictus: TOI's Invictus maximum output per main engine is 9385 hp/7000 kW. These calculations conservatively assume operating 6 of 6 engines.[2] PRIME MOVER >600 hp. diesel-Invictus: NOx emission factor is based on the TOI Invictus engine manufacturer's data. The main engines on Invictus are IMO Tier II certified engines.[3] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline and cement unit engines.[4] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines on certain wireline and cement unit engines.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Inc. Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field C-A Susan Wilson 713 599 6349

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILLSHIP 64865 3132.98 75191.51 24 108 46.05 0.70 1047.17 54.77 378.57 75205.34 59.69 0.91 1357.14 70.98 490.62 97466.12

PRIME MOVER>600hp diesel [1] [2] 56310 2719.77 65274.55 39.42 0.61 897.98 40.97 309.71 65319.60 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2279 110.08 2641.82 1.60 0.02 54.70 1.66 12.53 2643.64 0.00 0.00 0.00 0.00 0.00 0.002-300 HP WIRELINE <600hp diesel-POSU-CA PU Eng. [3] 600 28.98 695.52 0.20 0.01 3.95 1.51 3.46 690.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-GSU-W Generator 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel-Batch Mixer [4] 250 12.08 289.80 0.08 0.00 2.73 0.63 1.44 287.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel (Nitrogen pump) [5] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 563.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Fast Rescue 149 7.20 172.72 0.33 0.00 4.62 0.37 1.00 171.35 0.00 0.00 0.00 0.00 0.00 0.006-29HP EMERGENCY EQUIP <600hp diesel-Lifeboat 174 8.40 201.70 0.38 0.00 5.39 0.44 1.16 200.10 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Air Compressor 38 1.84 44.05 0.08 0.00 1.18 0.10 0.25 43.70 0.00 0.00 0.00 0.00 0.00 0.00

3-415 HP SEISMIC OP ENGINE <600hp diesel [8] 1245 60.13 1443.20 0.41 0.01 13.57 3.13 7.17 1431.75 0.00 0.00 0.00 0.00 0.00 0.00

SLICKLINE <600hp diesel [9] 106 5.12 122.88 0.23 0.00 1.60 0.27 0.71 121.90 0.00 0.00 0.00 0.00 0.00 0.00

FLUID FILTRATION PUMP <600hp diesel [10] 174 8.40 201.70 0.09 0.00 1.14 0.44 1.43 200.10 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING POWER PACK <600hp diesel [11] 260 12.56 301.39 0.23 0.00 3.93 0.56 4.87 299.00 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING PUMP >600hp diesel [12] 750 36.23 869.40 0.67 0.01 11.34 1.60 14.06 870.00 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS>600hp diesel(crew) (main-4) [13] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 49.50 10440.00 3.84 0.13 138.07 8.49 64.15 13530.24

VESSELS<600hp diesel(crew) (gens-3) [13] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.72 8.90 1245.45 0.46 0.02 16.61 3.53 11.54 1614.10

Work/Supply VESSELS>600hp diesel(work) (main-2) [7] 13196 637.37 15296.80 24 108 9.24 0.14 245.22 9.60 72.58 15307.36 11.97 0.18 317.81 12.44 94.06 19838.34

2 vessels VESSELS>600hp diesel(work) (gen.-2) [7] 8000 386.40 9273.60 24 108 5.60 0.09 132.18 5.82 44.00 9280.00 7.26 0.11 171.30 7.54 57.02 12026.88

VESSELS>600hp diesel(work) (SDT) [7] 2200 106.26 2550.24 24 108 1.54 0.02 36.35 1.60 12.10 2552.00 2.00 0.03 47.11 2.07 15.68 3307.39VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.55 1.26 3.35 581.78 1.43 0.01 20.15 1.63 4.34 753.99

INSTALLATION INSTALLATION Vessel >600hp diesel 4700 227.01 5448.24 24 4 3.29 0.05 112.80 3.42 25.85 17319.46 0.16 0.00 5.41 0.16 1.24 831.33jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.90 0.18 408.00 12.37 93.50 62644.87 0.57 0.01 19.58 0.59 4.49 3006.95umbilical VESSELS>600hp diesel(supply) 12000 579.6 13910.40 24 4 8.40 0.13 288.00 8.73 66.00 44219.91 0.40 0.01 13.82 0.42 3.17 2122.56

2017 YEAR TOTAL (ANNUAL) 90.44 1.43 2404.62 106.84 754.35 238796.17 87.77 1.40 2107.01 107.86 746.32 154497.90

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3962.70 3962.70 3962.70 3962.70 82257.76

119

[5] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.

Drill and complete wells with Drillship (Invictus)

[1] PRIME MOVER >600hp diesel-Invictus: TOI's Invictus maximum output per main engine is 9385 hp/7000 kW. These calculations conservatively assume operating 6 of 6 engines.[2] PRIME MOVER >600 hp. diesel-Invictus: NOx emission factor is based on the TOI Invictus engine manufacturer's data. The main engines on Invictus are IMO Tier II certified engines.[3] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline and cement unit engines.[4] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines on certain wireline and cement unit engines.[12] Diesel Recip. > 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.[13] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[6] Diesel Recip. > 600 hp.-IMO Tier I (=> 2000 rpm): NOx emission factors for IMO Tier I diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[7] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.[8] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines.[9] Diesel Recip. < 600 hp.-EPA Tier 1: NOx emission factor for EPA Tier 1 diesel engines.[10] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines.[11] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Inc. Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-B Susan Wilson 713 599 6349

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILLSHIP 64865 3132.98 75191.51 24 108 46.05 0.70 1047.17 54.77 378.57 75205.34 59.69 0.91 1357.14 70.98 490.62 97466.12

PRIME MOVER>600hp diesel [1] [2] 56310 2719.77 65274.55 39.42 0.61 897.98 40.97 309.71 65319.60 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2279 110.08 2641.82 1.60 0.02 54.70 1.66 12.53 2643.64 0.00 0.00 0.00 0.00 0.00 0.002-300 HP WIRELINE <600hp diesel-POSU-CA PU Eng. [3] 600 28.98 695.52 0.20 0.01 3.95 1.51 3.46 690.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-GSU-W Generator 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel-Batch Mixer [4] 250 12.08 289.80 0.08 0.00 2.73 0.63 1.44 287.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hp diesel (Nitrogen pump) [5] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 563.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Fast Rescue 149 7.20 172.72 0.33 0.00 4.62 0.37 1.00 171.35 0.00 0.00 0.00 0.00 0.00 0.006-29HP EMERGENCY EQUIP <600hp diesel-Lifeboat 174 8.40 201.70 0.38 0.00 5.39 0.44 1.16 200.10 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Air Compressor 38 1.84 44.05 0.08 0.00 1.18 0.10 0.25 43.70 0.00 0.00 0.00 0.00 0.00 0.00

3-415 HP SEISMIC OP ENGINE <600hp diesel [8] 1245 60.13 1443.20 0.41 0.01 13.57 3.13 7.17 1431.75 0.00 0.00 0.00 0.00 0.00 0.00

SLICKLINE <600hp diesel [9] 106 5.12 122.88 0.23 0.00 1.60 0.27 0.71 121.90 0.00 0.00 0.00 0.00 0.00 0.00

FLUID FILTRATION PUMP <600hp diesel [10] 174 8.40 201.70 0.09 0.00 1.14 0.44 1.43 200.10 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING POWER PACK <600hp diesel [11] 260 12.56 301.39 0.23 0.00 3.93 0.56 4.87 299.00 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING PUMP >600hp diesel [12] 750 36.23 869.40 0.67 0.01 11.34 1.60 14.06 870.00 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS>600hp diesel(crew) (main-4) [13] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 49.50 10440.00 3.84 0.13 138.07 8.49 64.15 13530.24

VESSELS<600hp diesel(crew) (gens-3) [13] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.72 8.90 1245.45 0.46 0.02 16.61 3.53 11.54 1614.10

Work/Supply VESSELS>600hp diesel(work) (main-2) [7] 13196 637.37 15296.80 24 108 9.24 0.14 245.22 9.60 72.58 15307.36 11.97 0.18 317.81 12.44 94.06 19838.34

2 vessels VESSELS>600hp diesel(work) (gen.-2) [7] 8000 386.40 9273.60 24 108 5.60 0.09 132.18 5.82 44.00 9280.00 7.26 0.11 171.30 7.54 57.02 12026.88

VESSELS>600hp diesel(work) (SDT) [7] 2200 106.26 2550.24 24 108 1.54 0.02 36.35 1.60 12.10 2552.00 2.00 0.03 47.11 2.07 15.68 3307.39VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.55 1.26 3.35 581.78 1.43 0.01 20.15 1.63 4.34 753.99

INSTALLATION INSTALLATION Vessel >600hp diesel 4700 227.01 5448.24 24 4 3.29 0.05 112.80 3.42 25.85 17319.46 0.16 0.00 5.41 0.16 1.24 831.33jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.90 0.18 408.00 12.37 93.50 62644.87 0.57 0.01 19.58 0.59 4.49 3006.95umbilical VESSELS>600hp diesel(supply) 12000 579.6 13910.40 24 4 8.40 0.13 288.00 8.73 66.00 44219.91 0.40 0.01 13.82 0.42 3.17 2122.56

2018 YEAR TOTAL (ANNUAL) 90.44 1.43 2404.62 106.84 754.35 238796.17 87.77 1.40 2107.01 107.86 746.32 154497.90

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

[5] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.

Drill and complete wells with Drillship (Invictus)

[1] PRIME MOVER >600hp diesel-Invictus: TOI's Invictus maximum output per main engine is 9385 hp/7000 kW. These calculations conservatively assume operating 6 of 6 engines.[2] PRIME MOVER >600 hp. diesel-Invictus: NOx emission factor is based on the TOI Invictus engine manufacturer's data. The main engines on Invictus are IMO Tier II certified engines.[3] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline and cement unit engines.[4] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines on certain wireline and cement unit engines.[12] Diesel Recip. > 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.[13] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[6] Diesel Recip. > 600 hp.-IMO Tier I (=> 2000 rpm): NOx emission factors for IMO Tier I diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[7] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.[8] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines.[9] Diesel Recip. < 600 hp.-EPA Tier 1: NOx emission factor for EPA Tier 1 diesel engines.[10] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines.[11] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

BHP Billiton Pet. (GOM) Inc. Green Canyon 609, 610, 653 G 16764, 16765, Shenzi Field H-H Susan Wilson 713 599 6349

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 CO2 PM SOx NOx VOC CO CO2

DRILLINGDP DRILLSHIP 64865 3132.98 75191.51 24 108 46.05 0.70 1047.17 54.77 378.57 75205.34 59.69 0.91 1357.14 70.98 490.62 97466.12

PRIME MOVER>600hp diesel [1] [2] 56310 2719.77 65274.55 39.42 0.61 897.98 40.97 309.71 65319.60 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2279 110.08 2641.82 1.60 0.02 54.70 1.66 12.53 2643.64 0.00 0.00 0.00 0.00 0.00 0.00

2-300 HP WIRELINE <600hp diesel-POSU-CA PU Eng. [3] 600 28.98 695.52 0.20 0.01 3.95 1.51 3.46 690.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-GSU-W Generator 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.00 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel-Batch Mixer [4] 250 12.08 289.80 0.08 0.00 2.73 0.63 1.44 287.50 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [5] 490 23.67 568.01 0.44 0.01 7.41 1.05 9.18 563.50 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [6] 860 41.54 996.91 0.60 0.01 13.86 0.63 4.73 997.60 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Fast Rescue 149 7.20 172.72 0.33 0.00 4.62 0.37 1.00 171.35 0.00 0.00 0.00 0.00 0.00 0.006-29HP EMERGENCY EQUIP <600hp diesel-Lifeboat 174 8.40 201.70 0.38 0.00 5.39 0.44 1.16 200.10 0.00 0.00 0.00 0.00 0.00 0.00

EMERGENCY EQUIP <600hp diesel-Air Compressor 38 1.84 44.05 0.08 0.00 1.18 0.10 0.25 43.70 0.00 0.00 0.00 0.00 0.00 0.00

3-415 HP SEISMIC OP ENGINE <600hp diesel [8] 1245 60.13 1443.20 0.41 0.01 13.57 3.13 7.17 1431.75 0.00 0.00 0.00 0.00 0.00 0.00

SLICKLINE <600hp diesel [9] 106 5.12 122.88 0.23 0.00 1.60 0.27 0.71 121.90 0.00 0.00 0.00 0.00 0.00 0.00

FLUID FILTRATION PUMP <600hp diesel [10] 174 8.40 201.70 0.09 0.00 1.14 0.44 1.43 200.10 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING POWER PACK <600hp diesel [11] 260 12.56 301.39 0.23 0.00 3.93 0.56 4.87 299.00 0.00 0.00 0.00 0.00 0.00 0.00COIL TUBING PUMP >600hp diesel [12] 750 36.23 869.40 0.67 0.01 11.34 1.60 14.06 870.00 0.00 0.00 0.00 0.00 0.00 0.00

ECO Crew VESSELS>600hp diesel(crew) (main-4) [13] 9000 434.70 10432.80 24 108 2.96 0.10 106.53 6.55 49.50 10440.00 3.84 0.13 138.07 8.49 64.15 13530.24

VESSELS<600hp diesel(crew) (gens-3) [13] 1083 52.31 1255.41 24 108 0.36 0.01 12.82 2.72 8.90 1245.45 0.46 0.02 16.61 3.53 11.54 1614.10

Work/Supply VESSELS>600hp diesel(work) (main-2) [7] 13196 637.37 15296.80 24 108 9.24 0.14 245.22 9.60 72.58 15307.36 11.97 0.18 317.81 12.44 94.06 19838.34

2 vessels VESSELS>600hp diesel(work) (gen.-2) [7] 8000 386.40 9273.60 24 108 5.60 0.09 132.18 5.82 44.00 9280.00 7.26 0.11 171.30 7.54 57.02 12026.88

VESSELS>600hp diesel(work) (SDT) [7] 2200 106.26 2550.24 24 108 1.54 0.02 36.35 1.60 12.10 2552.00 2.00 0.03 47.11 2.07 15.68 3307.39VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 108 1.11 0.01 15.55 1.26 3.35 581.78 1.43 0.01 20.15 1.63 4.34 753.99

INSTALLATION INSTALLATION Vessel >600hp diesel 4700 227.01 5448.24 24 4 3.29 0.05 112.80 3.42 25.85 17319.46 0.16 0.00 5.41 0.16 1.24 831.33jumper / flowline SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 4 11.90 0.18 408.00 12.37 93.50 62644.87 0.57 0.01 19.58 0.59 4.49 3006.95umbilical VESSELS>600hp diesel(supply) 12000 579.6 13910.40 24 4 8.40 0.13 288.00 8.73 66.00 44219.91 0.40 0.01 13.82 0.42 3.17 2122.56

2019 YEAR TOTAL (ANNUAL) 90.44 1.43 2404.62 106.84 754.35 238796.17 87.77 1.40 2107.01 107.86 746.32 154497.90

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3862.80 3862.80 3862.80 3862.80 80869.40

116

[5] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines on certain cement unit engines.

Drill and complete wells with Drillship (Invictus)

[1] PRIME MOVER >600hp diesel-Invictus: TOI's Invictus maximum output per main engine is 9385 hp/7000 kW. These calculations conservatively assume operating 6 of 6 engines.[2] PRIME MOVER >600 hp. diesel-Invictus: NOx emission factor is based on the TOI Invictus engine manufacturer's data. The main engines on Invictus are IMO Tier II certified engines.[3] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines on certain wireline and cement unit engines.[4] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines on certain wireline and cement unit engines.[12] Diesel Recip. > 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.[13] Diesel Recip. ≥37kw -Marine Tier 2: VESSELS: EPA Marine Engine Tier 2 for marine engines maunfactured after 2004 with a per cylinder displacement of 1.2 L - >5.0 L.[6] Diesel Recip. > 600 hp.-IMO Tier I (=> 2000 rpm): NOx emission factors for IMO Tier I diesel engines on certain cement unit engines with rated engine rpm is equal to or greater than 2000.[7] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.[8] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines.[9] Diesel Recip. < 600 hp.-EPA Tier 1: NOx emission factor for EPA Tier 1 diesel engines.[10] Diesel Recip. < 600 hp.-EPA Tier 3: PM, NOx, and CO emission factors for EPA Tier 3 diesel engines.[11] Diesel Recip. < 600 hp.-EPA Tier 1: PM, NOx, VOC and CO emission factors for EPA Tier 1 diesel engines.

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 3 of 8

PUBLIC INFORMATION COPY
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELL

BHP Billiton Pet. (GOM) Inc. Green Canyon 609, 610, 653 OCS-G 16764, 16765, 20Shenzi Field H-A, H-B, H-FG, H-H and C-A

Emitted Substance

Year

PM SOx NOx VOC CO

2015 87.77 1.40 2107.01 107.86 746.32

2016 87.77 1.40 2107.01 107.86 746.32

2017 87.77 1.40 2107.01 107.86 746.32

2018 87.77 1.40 2107.01 107.86 746.32

2019 87.77 1.40 2107.01 107.86 746.32

Allowable 3862.80 3862.80 3862.80 3862.80 80869.40

FORM BOEM-139 (October 2011 - Supersedes all previous versions of form BOEM-139 which may not be used). Page 8 of 8

PUBLIC INFORMATION COPY
Page 1 of 15 

SPILL RESPONSE DISCUSSION 

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

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

estimated to be 131,116 barrels of crude oil with an API gravity of 32.1°. 

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 BSEE Oil Spill Risk Analysis Model (OSRAM) for the Central and 

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

BSEE OSRAM identifies a 3% probability of impact to the shorelines of Cameron Parish and/or 

Plaquemines Parish, Louisiana within 30 days. Cameron Parish includes the east side of Sabine 

Lake, Sabine National Wildlife Refuge, Calcasieu Lake, Lacassine National Wildlife Refuge 

(inland) and Grand Lake. Cameron Parish also includes the area along the coastline from Sabine 

Pass to Big Constance Lake in Rockefeller Wildlife Refuge. This region is composed of open 

public beaches, marshlands and swamps. It serves as a habitat for numerous birds, finfish and 

other animals, including several rare, threatened and endangered species. Plaquemines Parish 

includes Barataria Bay, the Mississippi River Delta, Breton Sound and the affiliated islands and 

bays. This region is an extremely sensitive habitat and serves as a migratory, breeding, feeding 

and nursery habitat for numerous species of wildlife. Beaches in this area vary in grain particle 

size and can be classified as fine sand, shell or perched shell beaches. Sandy and muddy tidal 

flats are also abundant. 

Response

BHP Billiton Petroleum (GOM) Inc. will make every effort to respond to the Worst Case 

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

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

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

model was run on a similar product from the ADIOS oil database. The results indicate 19% or 

approximately 24,912 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 106,204 barrels remaining. 

Spill Response GC 653, Well SB101 Barrels of Oil 

WCD Volume 131,116 

Less 19% natural evaporation/dispersion 24,912 

Remaining volume 106,204 

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

storage equipment available to respond to a spill of approximately 106,204 barrels. The volume 

accounts for the amount remaining after evaporation/dispersion at 24 hours. The list estimates 

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

2 also indicates how operations will be supported. 

BHP Billiton Petroleum (GOM) Inc.’s Oil Spill Response Plan includes alternative response 

technologies such as dispersants and in-situ burn. Strategies will be decided by Unified 

PUBLIC INFORMATION COPY
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Command based on the size of the spill, weather and potential impacts. If aerial dispersants are 

utilized, 8 sorties (9,600 gallons) from two of the DC-3 aircrafts and 4 sorties (8,000 gallons) 

from the Basler aircraft would provide a daily dispersant capability of 7,540 barrels. If the 

conditions are favorable for in-situ burning, the proper approvals have been obtained and the 

proper planning is in place, in-situ burning of oil may be attempted. Slick containment boom 

would be immediately called out and on-scene as soon as possible. Offshore response strategies 

may include attempting to skim utilizing the HOSS Barge, nine Fast Response Units (FRUs), and 

eleven sets of Koseq skimming arms, with a total derated skimming capacity of 277,378 barrels. 

Temporary storage associated with skimming equipment equals 27,700 barrels. If additional 

storage is needed, three 23,000 barrel storage barges, one 20,000 barrel storage barge, one 

80,000 barrel storage barge, and one 83,937 barrel storage barge may be mobilized and centrally 

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

much as possible. Safety is first priority. Air monitoring will be accomplished and 

operations deemed safe prior to any containment/skimming attempts. 

If the spill went unabated, shoreline impact in Cameron and/or Plaquemines Parish, Louisiana 

would depend upon existing environmental conditions. Shoreline protection would include the 

use of CGA’s near shore and shallow water skimmers with a totaled derated skimming capacity 

of 74,126 barrels. Temporary storage associated with skimming equipment equals 1,353 barrels. 

If additional storage is needed, two 20,000 barrel storage barges and one 47,000 barrel storage 

barge may be mobilized and centrally located to provide temporary storage allowing the 

skimmers to stay in the area of operations as much as possible. Onshore response may include 

the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated 

areas. A Master Services Contract with ES&H will ensure access to 211,000 feet of 18” 

shoreline protection boom. Figure 2 outlines individual times needed for procurement, load out, 

travel time to the site and deployment. Strategies would be based upon surveillance and real 

time trajectories that depict areas of potential impact given actual sea and weather conditions. 

The State of Louisiana Initial Oil Spill Response Plans for Cameron Parish and 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 cleanup operations. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline 

protection strategies for this area, and it describes necessary action to keep the oil spill from 

entering Louisiana’s coastal wetlands, based on the assumption that removal of the released oil 

will be much easier and less damaging to fragile coastal ecosystems if done in the open waters of 

the Gulf of Mexico. Supervisory personnel have the option to modify the deployment and 

operation of equipment allowing a more effective response to site-specific circumstances. BHP 

Billiton Petroleum (GOM) Inc.’s contract Spill Management Team holds a copy of the State of 

Louisiana Initial Oil Spill Response Plan. 

Based on the anticipated worst case discharge scenario, BHP Billiton Petroleum (GOM) Inc. can 

be onsite with contracted oil spill recovery equipment with adequate response capacity to contain 

and recover surface hydrocarbons, and prevent land impact, to the maximum extent practicable, 

within an estimated 77 hours (based on the equipment’s Effective Daily Recovery Capacity 

(EDRC)). 

PUBLIC INFORMATION COPY
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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 

BHP Billiton Petroleum (GOM) Inc. will take action to provide a safe, aggressive response to 

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

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

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

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

Coordination of response assets will be supervised by the designation of a SIMOPS group as 

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

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

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

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

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

the Source Control Section Chief. 

In addition, these activities will be monitored by the spill management team (SMT) and Unified 

Command via a structured Common Operating Picture (COP) established to track resource and 

slick movement in real time. 

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

• Information will be confirmed 

• An assessment will be made and initial objectives set 

• OSROs and appropriate agencies will be notified 

• ICS 201, Initial Report Form will be completed 

• Initial Safety plan will be written and published 

• Unified Command will be established 

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

objectives 

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

site 

o On-site command and control established 

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Decanting Strategy 

Recovered oil and water mixtures will typically separate into distinct phases when left in a 

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

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

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

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

recovery. 

Offshore Response Actions 

Equipment Deployment

Surveillance 

• Surveillance Aircraft will be deployed within two hours of Qualified Individual (QI) 

notification, or at first light

• Provide trained observer to provide on site status reports 

• Provide command and control platform at the site if needed 

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

and visual confirmation 

• Continual monitoring of vessel assets using vessel monitoring systems 

Dispersant application assets 

• Put Airborne Support Inc. (ASI) on standby 

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

appropriateness of dispersant application 

• Gain FOSC approval for use of dispersants on the surface 

• Deploy aircraft in accordance with a plan developed for the actual situation 

• Coordinate movement of dispersants, aircraft, and support equipment and personnel 

• Confirm dispersant availability for current and long range operations 

• Start ordering dispersant stocks required for expected operations 

Containment boom 

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

• Ensure boom handling and mooring equipment is deployed with boom 

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

their most effective containment 

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

Dedicated off-shore skimming systems 

General 

• Deployed to the highest concentration of oil 

• Assets deployed at safe distance from aerial dispersant and in-situ burn operations 

PUBLIC INFORMATION COPY
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CGA HOSS Barge 

• Use in areas with heaviest oil concentrations 

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

CGA FRUs 

• To the area of the thickest oil 

• Use as far off-shore as allowed 

• VOOs 140’ – 180’ in length 

• VOOs with minimum of 18’ x 38’ or 23’ x 50’ of optimum deck space 

• VOOs in shallow water should have a draft of <10 feet when fully loaded 

Storage Vessels 

• Establish availability of CGA contracted assets 

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

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

systems 

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

Vessels of Opportunity (VOO) 

• Use BHP Billiton Petroleum (GOM) Inc.’s contracted resources as applicable 

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

Systems (VOSS) 

• Acquire additional resources as needed 

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

• Expect mission specific and safety training to be required 

• Plan with the US Coast Guard for vessel inspections 

In-situ Burn assets 

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

affected State On-Scene Coordinator (SOSC) 

• Determine availability of fire boom and selected ignition systems 

• Start ordering fire boom stocks required for expected operations 

• Contact boom manufacturer to provide training if required 

• Determine assets to perform on water operation 

• Build operations into safety plan 

• Conduct operations in accordance with an approved plan 

Adverse Weather Operations: 

In adverse weather, when seas are > 3 feet, the use of larger recovery and storage vessels, 

oleophilic skimmers, and large offshore boom will be maximized. Safety will be the overriding 

factor in all operations and will cease at the order of the Unified Command, vessel captain, or in 

an emergency, ”stop work” may be directed by any crew member. 

PUBLIC INFORMATION COPY
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Near Shore Response Actions 

Timing 

• Place near shore assets on standby and deploy in accordance with planning based on the 

actual situation, actual trajectories and oil budgets 

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

• Outfitting of VOOs for specific missions 

• Deployment of assets based on actual movement of oil 

Considerations 

• Water depth, vessel draft 

• Shoreline gradient 

• State of the oil 

• Use of VOOs 

• Distance of surf zone from shoreline 

Equipment Deployment 

Surveillance 

• Provide trained observer to direct skimming operations 

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

and visual confirmation 

• Continual monitoring of vessel assets 

Dispersant Use 

• Generally will not be approved within 3 miles of shore or with less than 10 meters of 

water depth 

• Approval would be at Regional Response Team level (Region 6) 

Vessel Deployment 

Dedicated Near Shore skimming systems 

• Fast Response Vessels (FRV) 

• Egmopol and Marco Shallow Water Skimmer (SWS) 

• Operate with aerial spotter directing systems to observed oil slicks 

VOO 

• Use BHP Billiton Petroleum (GOM) Inc.’s contracted resources as applicable 

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

Systems (VOSS) 

• Acquire additional resources as needed 

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

• Expect mission specific and safety training to be required 

• Plan with the US Coast Guard for vessel inspections 

• Operate with aerial spotter directing systems to oil patches 

PUBLIC INFORMATION COPY
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Shoreline Protection Operations 

Response Planning Considerations 

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

• Time to acquire personnel and equipment and their availability 

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

currently for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep 

Water Horizon, dated 2 May 2010 

Actions 

Placement of boom 

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

appropriate ACP 

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

impact. Consider: 

o Trajectories 

o Weather forecast 

o Oil Impact forecast 

o Verified spill movement 

o Boom, manpower and vessel (shallow draft) availability 

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

Beach Preparation 

Considerations and Actions 

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

• Shoreline Cleanup and Assessment Team Reports and recommendations 

• Determination of Archeological sites and gaining authority to enter 

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

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

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

possible to maximize on-site work time 

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

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

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

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

and/or sweep obtained 

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

inland areas 

PUBLIC INFORMATION COPY
Page 8 of 15 

Decanting Strategy 

Recovered oil and water mixtures will typically separate into distinct phases when left in a 

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

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

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

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

recovery. 

CGA Equipment Limitations 

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

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

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

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

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

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

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

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

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

Boom 3 foot seas, 20 knot winds 

Dispersants Winds more than 25 knots 

Visibility less than 3 nautical miles 

Ceiling less than 1,000 feet. 

FRU 8 foot seas 

HOSS Barge/OSRB 8 foot seas 

Koseq Arms 8 foot seas 

OSRV 4 foot seas 

PUBLIC INFORMATION COPY
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Environmental Conditions in the GOM

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

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

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

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

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

flooding is prominent. 

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

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

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

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

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

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

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

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

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

month. 

PUBLIC INFORMATION COPY
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FIGURE 1 

TRAJECTORY BY LAND SEGMENT 

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

utilizing BHP Billiton Petroleum (GOM) Inc.’s WCD and information in the BSEE Oil 

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

available on the BSEE 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 

GC 653, Well SB101 

120 miles from shore 

G20084 C46 Matagorda County, TX 

Brazoria County, TX 

Galveston County, TX 

Jefferson County, TX 

Cameron Parish, LA 

Vermilion Parish, LA 

Terrebonne Parish, LA 

Lafourche Parish, LA 

Plaquemines Parish, LA 

1 

1 

2 

1 

3 

1 

1 

1 

3 

PUBLIC INFORMATION COPY
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WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (120 miles from shore) 

106,204 bbls of crude oil (Volume considering natural weathering) API Gravity 32.1° 

FIGURE 2 – Equipment Response Time to GC 653, Well SB101 

Dispersants/Surveillance

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

CGA 

Basler 67T 2000 NA 2 Houma 1 1 0.8 2.8 

ASI 

DC 3 1200 NA 2 Houma 1 1 1.1 3.1 DC 3 1200 NA 2 Houma 1 1 1.1 3.1 Aero Commander NA NA 2 Houma 1 1 0.8 2.8 

Offshore Response

Offshore Equipment No 

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

CGA 

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 15 1 28 Boom Barge (CGA-300) 42” Auto Boom (25000’) NA NA 1 Tug 50 Crew 4 (Barge) 2 (Per Crew) Leeville 4 0 6 18.6 1.5 30.1 

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 24 24 1 25.8 2 76.8 Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 24 24 2 10.4 2 62.4 Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 24 24 1 10.4 2 61.4 Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 24 24 2 9.6 2 61.6 

Recovered Oil Storage No 

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

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38 CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38 CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38 CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38 

K-Sea Operating (available through contract with CGA) 

PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 2 14.38 1 33.38 DBL 76 1212984 NA 83937 1 Tug 6 Venice 4 12 2 14.38 1 33.38 

PUBLIC INFORMATION COPY
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Staging Area: Venice

Offshore Equipment With 

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

CGA 

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 8 9.6 1 21.6 FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 1 2 1.75 9.6 1 15.3 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Ingleside 1 2 11 9.6 1 24.6 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 5.5 9.6 1 19.1 FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 3.5 9.6 1 17.1 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 3.25 9.6 1 16.8 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 9.6 1 13.6 Hydro-Fire Boom NA NA 8 Utility 40 Harvey 1 4 1.75 9.6 6 22.3 

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Nearshore Response 

Nearshore Equipment No 

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

CGA 

46’ FRV 5000 65 NA 4 Leeville 1 0 2 2 0 5 46’ FRV 5000 65 NA 4 Venice 1 0 1 2 0 4 Trinity SWS 21500 249 NA 4 Leeville 1 2 2 2 0 7 Trinity SWS 21500 249 NA 4 Venice 1 2 2 2 0 7 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38 CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38 CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 19.38 1 40.38 

Staging Area: Venice

Nearshore and Inland Skimmers 

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

SWS Egmopol 3000 100 NA 3 Galveston 1 2 8 2 0 13 SWS Egmopol 3000 100 NA 3 Morgan City 1 2 3.25 2 0 8.25 SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 2 0 10.5 SWS Marco 3588 34 NA 3 Leeville 1 2 3.5 2 0 8.5 SWS Marco 3588 34 NA 3 Venice 1 2 0 2 0 5 Rope Mop 77 2 0 3 Harvey 1 2 8 2 0 13 Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 1 2 5.5 2 0 8 Foilex Skim Package (TDS 150) 891 45 NA 3 Galveston 1 2 8 2 0 8 Foilex Skim Package (TDS 150) 891 45 NA 3 Harvey 1 2 1.75 2 0 11 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 1 2 5.5 2 0 8 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 1 2 1.75 2 0 11 2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Lake Charles 1 2 5.5 2 0 8 

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Shoreline Protection 

Staging Area: Venice

Shoreline Protection Boom VOO Persons Req. Storage/Warehouse Location Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total Hrs 

ES&H (available through MSA) 

50,000’ 18” Shoreline Boom 20 Crew 50 Houston, TX .5 .5 7.5 2 15 25.5 50,000’ 18” Shoreline Boom 20 Crew 50 Lake Charles, LA .5 .5 5.5 2 15 23.5 20,000’ 18” Shoreline Boom 8 Crew 20 New Iberia, LA .5 .5 4 2 6 13 

1,000’ 18” Shoreline Boom 2 Crew 6 Morgan City, LA .5 .5 3.25 2 1 7.25 

20,000’ 18” Shoreline Boom 8 Crew 20 Belle Chasse, LA .5 .5 1.5 2 6 10.5 15,000’ 18” Shoreline Boom 6 Crew 14 Mobile, AL .5 .5 4.25 2 4 11.25 

5,000’ 18” Shoreline Boom 2 Crew 6 Dallas Ft. Worth, TX .5 .5 10.25 2 2 15.25 

50,000’ 18” Shoreline Boom 20 Crew 50 Houma, LA .5 .5 3 2 15 21 

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

CGA 

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 8 1 2 14 Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 11 1 2 17 Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 1 2 10 

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

CGA 

Wildlife Support Trailer NA NA NA 2 Houma 1 2 3 1 2 9 Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 1.5 1 2 7.5 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 1 2 14 Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 1 2 9 Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 11 1 2 17 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 1 2 11.5 Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 1 2 10 

Response Asset Total 

Offshore EDRC 277,378 

Offshore Recovered Oil Storage 280,637 

Nearshore / Shallow Water EDRC 74,126 

Nearshore / Shallow Water Recovered Oil Storage 88,353 

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ATTACHMENT K

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PUBLIC INFORMATION COPY ATTACHMENT L
Worst Case Discharge Mod

Shenzi H-H (H102H)