UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of DOCD

Control # - S-07616

Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS-G20084 Block - 653 Green Canyon Area

Operator - BHP Billiton Petroleum (GOM) Inc.

Drill, Complete Wells SB103 & SB104

DP Semisubmersible, Drillship

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

7503 FSL, 3554 FEL

7553 FSL, 3583 FEL

G20084/GC/653

G20084/GC/653

WELL/SB103

WELL/SB104

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

Description -

Rig Type -

Subject:

From:

August 6, 2013
.11 

bhpbaliton 

tie future 

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 

April 15, 2013 

July 15, 2013 (Amendment 1) 

Mr. Bob Sebastian 

Regional Supervisor for Leasing and Plans 

U.S. Department of the Interior 

Bureau of Ocean Energy Management 

1201 Elmwood 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 20084, Green Canyon Area, Block 653, Well SB103 

OCS Federal Waters, Gulf of Mexico, Offshore, Louisiana 

Gentlemen: 

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

Notice to Lessees (NTL) 2010-N06, 2009-G27 and 2008-G04, 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 one (1) additional well, installing one (1) associated jumper and commencing production in the 

Green Canyon Area, Block 653, Lease OCS-G 20084, Offshore, Louisiana. 

BHPB anticipates commencing drilling operations on October 1, 2013. 

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 ................................................................................................................................ 2

Bathymetry Map and Location Plat............................................................................................................. 2

Safety and Pollution Prevention Features................................................................................................... 2

Storage Tanks and Production Vessels........................................................................................................ 3

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

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

Operations................................................................................................................................................... 4

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........................................................................................................................................ 6

New or Unusual Technology ....................................................................................................................... 7

Bonding Information ................................................................................................................................... 7

Oil Spill Financial Responsibility (OSFR)....................................................................................................... 7

Deepwater Well Control Statement  ........................................................................................................... 7

Suspensions of Production .......................................................................................................................... 8

Blowout Scenario  ........................................................................................................................................ 8

Chemical Products  .................................................................................................................................... 10

SECTION 3:

GEOLOGICAL AND GEOPHYSICAL INFORMATION................................................................................... 11

Geological Description  .............................................................................................................................. 12

Structure Contour Maps  ........................................................................................................................... 12

Interpreted 2‐D or 3‐D Seismic Lines  ........................................................................................................ 12

Geological Structure Cross‐Sections  ......................................................................................................... 12

Shallow Hazards Report  ............................................................................................................................ 12

Site Specific Shallow Hazards Assessment  ............................................................................................... 12

High Resolution Seismic Lines  .................................................................................................................. 12

PUBLIC INFORMATION COPY
Stratigraphic Column  ................................................................................................................................12

Time Versus Depth Table  .......................................................................................................................... 12

Geochemical Information  ......................................................................................................................... 12

Future G&G Activities  ............................................................................................................................... 12

SECTION 4:

HYDROGEN SULFIDE INFORMATION  ..................................................................................................... 13

Concentration  ........................................................................................................................................... 13

Classification Request  ............................................................................................................................... 13

Contingency Plan  ...................................................................................................................................... 13

Modeling Report  ....................................................................................................................................... 13

SECTION 5:

MINERAL AND RESOURCE CONVERSATION INFORMATION  ................................................................... 14

Technology and Reservoir Engineering Practices and Procedures  .......................................................... 14

Technology and Recovery Practices and Procedures  ............................................................................... 14

Reservoir Development  ............................................................................................................................ 14

SECTION 6:

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION  ............................................................. 15

Chemosynthetic Communities Report  ..................................................................................................... 15

Topographic Features Map ....................................................................................................................... 15

Topographic Features Statement   ............................................................................................................ 15

Live Bottom (Pinnacle Trend) Map  ........................................................................................................... 15

Live Bottom (Low Relief) Map  .................................................................................................................. 15

Potentially Sensitive Biological Features  .................................................................................................. 15

ROV Monitoring Survey Plan  .................................................................................................................... 15

Threatened and Endangered Species Information  ................................................................................... 16

Archaeological Report  .............................................................................................................................. 17

Air and Water Quality Information   .......................................................................................................... 17

Socioeconomic Information  ..................................................................................................................... 17

SECTION 7:

WASTE AND DISCHARGE INFORMATION  ............................................................................................... 18

Projected Generated Wastes  ................................................................................................................... 18

Projected Ocean Discharges  ..................................................................................................................... 18

Modeling Report  ....................................................................................................................................... 18

NPDES Permits   ......................................................................................................................................... 18

PUBLIC INFORMATION COPY
Cooling Water Intakes  .............................................................................................................................. 18

SECTION 8:

AIR EMISSIONS INFORMATION  ............................................................................................................. 19

Screening Checklist  ................................................................................................................................... 19

Summary Table(s) of Plan Emissions......................................................................................................... 19

SECTION 9:

OIL SPILL INFORMATION  ....................................................................................................................... 20

Site Specific OSRP ...................................................................................................................................... 20

Regional or Sub‐Regional OSRP Information............................................................................................. 20

Spill Response Sites................................................................................................................................... 20

OSRO Information ..................................................................................................................................... 20

Worst Case Scenario Determination ......................................................................................................... 21

NTL 2010‐NO6‐ WCD Calculations Overview ............................................................................................ 21

Oil Spill Response Discussion / NEPA Analysis .......................................................................................... 22

Modeling Report........................................................................................................................................ 22

SECTION 10:

ENVIRONMENTAL MONITORING INFORMATION  .................................................................................. 23

Monitoring Systems  .................................................................................................................................. 23

Incidental Takes......................................................................................................................................... 23

Flower Garden Banks National Marine Sanctuary  ................................................................................... 23

SECTION 11:

LEASE STIPULATIONS INFORMATION  .................................................................................................... 24

SECTION 12:

ENVIRONMENTAL MITIGATION MEASURES INFORMATION  .................................................................. 25

Impacts to Marine & Coastal Environments & Habitats, Biota, and Threatened & Endangered Species  25

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

SECTION 13:

DECOMMISSIONING INFORMATION  ..................................................................................................... 26

SECTION 14:

RELATED FACILITIES AND OPERATIONS INFORMATION  ......................................................................... 27

Related OCS Facilities and Operations  ..................................................................................................... 27

Transportation System  ............................................................................................................................. 27

Produced Liquid Hydrocarbons Transportation Vessels  .......................................................................... 27

SECTION 15:

SUPPORT VESSELS AND AIRCRAFT INFORMATION  ................................................................................ 28

PUBLIC INFORMATION COPY
General ...................................................................................................................................................... 28

Diesel Oil Supply Vessels  .......................................................................................................................... 28

Drilling Fluids Transportation  ................................................................................................................... 28

Solid and Liquid Wastes Transportation.................................................................................................... 28

Vicinity Map  .............................................................................................................................................. 28

SECTION 16:

ONSHORE SUPPORT FACILITIES INFORMATION  ..................................................................................... 29

General  ..................................................................................................................................................... 29

Support Base Construction or Expansion.................................................................................................. 29

Support Base Construction or Expansion Timetable  ................................................................................ 29

Air Emissions  ............................................................................................................................................. 29

Unusual Solid and Liquid Wastes  .............................................................................................................. 29

Waste Disposal  ......................................................................................................................................... 29

SECTION 17:

SULPHUR OPERATIONS INFORMATION  ................................................................................................. 30

SECTION 18:

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION  ................................................................. 31

Consistency Certification  .......................................................................................................................... 31

Other Information ..................................................................................................................................... 31

SECTION 19:

ENVIRONMENTAL IMPACT ANALYSIS (EIA)  ........................................................................................... 32

Impact Producing Factors (IPFs) from the Proposed Activities  ................................................................ 32

Analysis  ..................................................................................................................................................... 33

Environmental Hazards  ............................................................................................................................ 40

Alternatives ............................................................................................................................................... 41

Mitigation Measures  ................................................................................................................................41

Consultation  ............................................................................................................................................. 41

Preparer(s)  ................................................................................................................................................ 41

References  ................................................................................................................................................ 42

PUBLIC INFORMATION COPY
SECTION 20:

ADMINISTRATIVE INFORMATION  ......................................................................................................... 43

Exempted Information Description (Public Information Copies Only)  ..................................................... 43

Bibliography  .............................................................................................................................................. 43

Plan Attachments 

Attachment A Plan Information Forms 

Attachment B Well Location Maps 

Attachment C Bathymetry Map 

Attachment D Pay.gov Service Fee 

Attachment E Structure Map 

Attachment F Seismic Cross Section 

Attachment G Seismic Lines 

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 Block 653 

Supplemental DOCD Leases OCS-G 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 

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 to 

install a TLP (Platform A) and the infrastructure to produce thirteen (13) subsea wells. All subsea wells 

were proposed to be drilled and completed under Initial or Supplemental Exploration Plans. 

Under this Supplemental DOCD, BHPB proposes the following: 

1. Drill and complete Wells SB103 and SB104 adjacent to an existing manifold at Drill Center B in 

Block 653. 

2. Install two (2) well jumpers 

3. Commence production 

The following is a history of the wells approved under the Initial Plan N-9001 and Supplemental Plans N7446 and N-7487: 

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 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 Re-named / drilled as SB202 

G2-4 See Status 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 See Status Rig on location 4/2013 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 2 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

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

Well Name Complete Date Production Start 

Date Status 

SC103 Presently Completing Rig on location 

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

SH102 See Status Not drilled yet 

SH103 See Status Not drilled yet 

SH104 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 Not drilled yet 

(a) Plan Information Form 

 

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

operations and jumper 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 either a DP drill ship (CRL) or a DP semi-submersible (DD1)

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 the either a DP drillship or a DP semisubmersible 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: 

 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 

 Subpart C for Pollution Prevention and Control 

 Subpart D for Oil and Gas Drilling Operations 

 Subpart E for Oil and Gas Well-Completion Operations 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 3 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

 Subpart J for Pipelines and Pipeline Right-of-Ways 

 Subpart K for Oil and Gas Production Requirements 

 Subpart M for Unitization 

 Subpart O for Well Control and Production Safety Training Subpart 

 Subpart S for Safety and Environmental Management Systems (SEMS) 

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. 

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) 

12 49,392 29-39o

Base Oil Drillship – CRL 3541 1 3541 29-39o 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 4 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

Type of Storage 

Tank Type of Facility Tank Capacity (bbls) 

Number of 

Tanks 

Total Capacity 

(bbls) 

Fluid Gravity 

(API)

Fuel Tanks (005, 

006, 007, 008) DP Semisubmersible DD-1 77178 4 308,712 29-39o

Fuel Tank (009) DP Semisubmersible DD-1 3003 1 3,003 29-39o

Fuel Tank (010) DP Semisubmersible DD-1 2585 1 2,585 29-39o

Fuel Tank (011) DP Semisubmersible DD-1 5228 1 5,228 29-39o

Base Oil DP Semisubmersible DD-1 3541 1 3541 29-39o

(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 §250.211 

[70 FR 49875, Aug. 25, 2005, as amended at 71 FR 40909, July 19, 2006; 72 FR 25199, May 4, 2007; 73 FR 49946, Aug. 25, 2008; 75 FR 20288, Apr. 

19, 2010] 

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. 

(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. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 5 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

(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 Block 653 

Supplemental DOCD Leases OCS-G 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 

Surface Safety System 

Modification BSEE District In preparation 

Notice of Intent to Discharge EPA Region 4 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) 19175 

Oil-based (diesel, mineral oil) NA 

Synthetic-based (internal olefin, ester, etc) 10329 

(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 

PROPRIETARY DATA

(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. 7 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 8 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 two 5th generation rigs on contract capable of drilling in at least 7,500ft of water.  Both rigs are

planned to continue to operate in the Gulf of Mexico.

Relief Rig Package Constraints 

No constraints have been identified preventing either rig from drilling a relief well. Both MODU’s are 

rigged up for fracturing / high rate pumping operations. There are several stimulation vessels in the GOM 

which could also be used for kill operations. 

Relief Rig Timing (Contract) and Rig Mobilization 

BHPB has two rigs on contract operating in the Gulf of Mexico. A reasonable assumption would be that it 

would take 7 – 10 days for the relief well rig to safely suspend operations on the current well and move to 

the Green Canyon relief well location. Upon arrival at location, it would be expected to take 

approximately 120 days to drill the relief well and perform kill operations. 

Location & Strategy of Relief Well 

As the Shenzi wells are located approximately 120 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. 9 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 

 Senior BHPB drilling management is actively engaged in daily rig operations. 

 BHPB employs experienced and trained Drilling Supervisors. 

 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 (not full casing strings) 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 lighter 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 Subpart O. 

The BOP stacks on the C.R. Luigs and Development Driller-1 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. These configurations have been in place since the 

rigs first began work with BHPB (since 2000 for the CRL and 2005 for the DD1). As such, 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 13-3/8” intermediate casing can withstand a full column of oil to the mudline per screening tool 

analysis. 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 shut in. 

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

Driller I 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. 10 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 GC 653 Drill Center B (see Attachment C). Shallow hazards mapping indicates relief 

wells would have to be drilled from surface locations in the southwestern half of the 5000-ft-radius circle 

to avoid geologically active faults and protected benthic communities associated with tar mounds to the 

northeast. 

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

Key Rig Specifications for Relief Well

Rig Name DD1 C.R. Luigs 

Rig type 5th Gen MODU rated for 7,500 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) 2,000 kips 1,800 kips

Drawworks power (hp) 6,900 hp 5,000 hp

Mud pumps Power & Pressure (hp/psi) 4 x 14-P-220 NOV pumps with 2,200 

7,475 psi working 

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

7,475 psi working 

Mud pit volume (bbls) 19,298 bbls (VDL limited) 13,267 bbls

Variable Loading (kips) 15,432 kips Drilling N/A Drill Ship

Top Drive Power & Torque (hp/ftlbs) Hydralift HPS 1000 2E (AC) NOV TDS-4

Dry bulk storage capacity (cu.ft) 16,950 cu/ft Cement & 10,416 cu/ft 

Barite (VDL Limited) Total Bulk 27,000 cuft

Other Measures Taken 

Prior to drilling in GC653, 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. 11 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

SECTION 3 - GEOLOGICAL AND GEOPHYSICAL INFORMATION 

In accordance with 43 CFR 2.13 (c) (9), 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. 12 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

(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 

“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 approved by MMS on February 26, 2003. 

Wells SB103 and SB104 are being drilled from the existing Manifold B1 in GC 653. 

(f) Site Specific Shallow Hazards Assessment 

Wells SB103 and SB104 are being drilled adjacent to an existing surface location; a shallow hazards 

assessment is not required at this time. 

(g) High Resolution Seismic Lines 

Wells SB103 and SB104 are being drilled adjacent to an existing surface location; 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. 13 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 Green Canyon Block 653, Lease OCS-G 

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. 14 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 15 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 

Wells SB103 and SB104 are being drilled at a previously approved drill center. 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 proposed location. 

(b) Topographic Features Map 

There are no topographic features located on Green Canyon 653. 

(c) Topographic Features Statement 

Since there are no topographic features located on Green Canyon 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. 16 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 17 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

(i) Archaeological Report

BHP Billiton Petroleum Inc., (BHPB) provided an archaeological assessment of previously collected 

Autonomous Underwater Vehicle (AUV) data to comply with the Bureau of Ocean Energy Management 

Regulation and Enforcement’s (BOEM) newly issued “Pre-Seabed Disturbance Survey Mitigation” 

guidelines to BOEM by letter dated December 23, 2011. The control number assigned by BOEM for 

this document is 23512. 

This report is intended to provide details pertaining directly to the area of potential effect of BHPB’s 

proposed wells in GC 654 Drill Center B. A review of all available AUV and ROV data for the survey area 

delineated no potential submerged cultural resources in Blocks 564-566, 608-610, 652-654 and 696-698, 

Green Canyon Area. 

(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. 18 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 19 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 wells SB103 and 

SB104. 

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 wells SB103 and SB104. 

The SB103 well activity is not a collocated activity. The planned emissions are associated with drilling 

and completing of the well with the drillship C.R. Luigs or DP semisubmersible DD1 and installing 

jumpers. 

COMPANY AREA BLOCK LEASE PLATFORM WELL 

BHP Billiton Pet. 

(GOM) Inc. Green Canyon 653 OCS-G 20084 NA SB103 (CRL) 

Year 

Emitted Substance 

PM SOx NOx VOC CO 

2013 65.47 37.77 2162.71 76.53 440.83 

2014 117.59 67.82 3891.16 136.73 795.68 

Allowable 3996.00 3996.00 3996.00 3996.00 82717.95 

COMPANY AREA BLOCK LEASE PLATFORM WELL 

BHP Billiton Pet. 

(GOM) Inc. Green Canyon 653 OCS-G 20084 NA SB103 (DD1) 

Year 

Emitted Substance 

PM SOx NOx VOC CO 

2013 88.12 32.26 1099.78 80.77 306.72 

2014 156.49 58.35 2065.69 144.02 565.37 

Allowable 3996.00 3996.00 3996.00 3996.00 82717.95 

Detailed spreadsheets containing the SB103 and SB104 Plan emissions are included as Attachment I.

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 20 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

SECTION 9 - OIL SPILL INFORMATION

(a) Oil Spill Response Planning 

 (1) Site-Specific OSRP 

Lease OCS-G 20084 is 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) is covered under BHP Billiton 

Petroleum (Americas) Inc. (Company No. 00362) Regional OSRP. 

The calculated WCD for the proposed drilling operations in Lease OCS-G 20084 does 

not supersede the Regional OSRP’s WCD. 

The proposed activities in this Plan will be covered by the Oil Spill Response Plan that 

was approved on April 6, 2010. 

The biennial update was submitted in July 2011 with further revisions thereafter. The 

OSRP is presently in review. 

 (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. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 21 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

(iv) Worst Case Scenario Determination 

The calculated WCD for this Supplemental DOCD on Lease OCS-G 20084 does not 

supercede 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 SB103 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  

20,600  

20,600

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° 33° 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 April 6, 2010, 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 calculated WCD volume for SB103 at day one is 6,800 STB oil/day and 241,500 bbl water/day. The 

estimated cumulative discharge volume after 30 days is 0.473 MMSTB oil. Table 1 shows the expected 

WCD rates at intervals from day one (initial) out to 90 days. 

PROPRIETARY DATA

A more detailed WCD is located in Attachment M. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 22 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

(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 20,600 

barrels of crude oil with an API gravity of 33°. 

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. 23 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 24 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

SECTION 11 - LEASE STIPULATIONS INFORMATION 

BOEM did not invoke any lease stipulations for Lease OCS-G 20084, Green Canyon Block 653. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 25 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 26 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 27 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

SECTION 14 - RELATED FACILITIES AND OPERATIONS INFORMATION 

(a) Related OCS Facilities and Operations 

A subsea tree will be installed 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 facility under this Plan. 

Under this Supplemental Unit DOCD two (2) lease term flowlines (well jumpers) will be installed. 

Description of Lease Term Pipelines 

Diameter 

(Inches) From To Length Product Max SI Time 

06 GC653 / Well SB103 GC653 / Manifold B1 60 ft Oil 25,000 

bopd 45 seconds 

06 GC653 / Well SB104 GC653 / Manifold B1 60 ft 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. 28 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 

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 

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 I (Table 2). 

 

(e) Vicinity Map 

Drill Center B is located approximately 120 statute miles from the nearest Louisiana shoreline and 

approximately 124 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. 29 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 30 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 31 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 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. 32 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 

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BHP Billiton Petroleum (GOM) Inc. 33 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 Block 653, Wells SB103 & SB104 (Drill Center B) 

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 Block 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, 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 Block 653that 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. 34 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 Block 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 Block 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 high-density 

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 Block 653 that could cause impacts to 

Chemosynthetic Communities (refer to information referenced in Section 6.1, Chemosynthetic 

Communities). 

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 Block 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. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 35 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

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 and 30 CFR 

550.103 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 servicesrelated 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 

Block 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. 

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, 653 or 654. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 36 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

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 

February 7, 2007. 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 and 30 CFR 550.103 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. 

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. 

PUBLIC INFORMATION COPY
BHP Billiton Petroleum (GOM) Inc. 37 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

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

G01 pursuant to 30 CFR 250.103 and 30 CFR 550.103 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 122 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 Block 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 highprobability 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 Block 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 highprobability 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. 38 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 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 and 30 CFR 550.103 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. 39 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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 4.0 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. 

Wells SB103 and SB104 are 120 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 and 30 CFR 550.103 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. 

Wells SB103 and SB104 are 120 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. 40 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

3. Shore Birds and Coastal Nesting Birds 

There are no IPF’s (including accidents) associated with the development of Green Canyon Block 653 

that are projected to have a significant impact on shore birds and coastal nesting birds. 

Wells SB103 and SB104 are 120 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 Block 653 

that are projected to have a significant impact on coastal wildlife refuges. 

Wells SB103 and SB104 are 120 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 Block 653 

that are projected to have a significant impact on wilderness areas. 

Wells SB103 and SB104 are 120 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. 41 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 42 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 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. 43 Green Canyon Block 653 

Supplemental DOCD Leases OCS-G 20084 

SECTION 20 - ADMINISTRATIVE INFORMATION 

(a) Exempted Information Description (Public Information Copies Only) 

In accordance with 43 CFR Part 2, Appendix E, sections (4) and (9), 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 

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 

for SB103 4238.00 Receipt No. 25A89VDA / 74432445867 

 If a service fee is required under 30 CFR 550.125(a), provide the Amount paid 

for SB104 4238.00 Receipt No. 25AQPKN7 / 

74451833576 

Project and Worst Case Discharge (WCD)Information 

Lease(s): G20084 Area: GC Block(s): 653 Project Name (if applicable): Shenzi

Objective(s): X Oil X Gas Sulphur Salt Onshore Support Base(s): Fourchon, LA

Platform/Well Name: SB103 Total Volume of WCD: 131,116 BOPD API Gravity: 32.1

Distance to Closest Land (Miles): 120 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. N-9001 

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 

Development Drilling / Completion SB103 10/01/2013 02/03/2014 125 

Install / hookup jumper for SB103 02/04/2014 02/08/2014 4 

Commence production SB103 02/09/2014 02/08/2020 6 years 

Development Drilling / Completion SB104 03/01/2014 07/05/2014 125 

Install / hookup jumper for SB104 07/06/2014 07/10/2014 4 

Commence production SB104 07/11/2014 

 

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 

X DP Semisubmersible Other (attach description) Floating production 

system 

Other (Attach Description) 

Drilling Rig Name (if known): DD1 or CRL

Description of Lease Term Pipelines 

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

GC 653 #SB103 GC 653 Manifold B1 06 60 

GC 653 #SB104 GC 653 Manifold B1 06 60 

 

FORM BOEM-0137 (December 2011 - Supersedes all previous editions of this form which may not be used. Page 1 of 5

 

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) SB103

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) 20,600

For structures, volume of all storage 

and pipelines (Bbls) 

API Gravity of 

fluid 33o 

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: 7503.45 FSL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 3554.22 FEL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,578,365.78 X: 

X: 

X: 

Y: 9,923,343.45 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 18’ 59.699”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 06’ 40.114”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4236 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 5 

 

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) SB104

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: 7552.51 FSL N/S Departure: F____L 

N/S Departure: F____L 

N/S Departure: F____L 

E/W Departure: 3582.54 FEL E/W Departure: F____L 

E/W Departure: F____L 

E/W Departure: F____L 

Lambert X-Y 

coordinates 

X: 2,578,337.46 X: 

X: 

X: 

Y: 9,923,392.51 Y: 

Y: 

Y: 

Latitude / 

Longitude 

Latitude: 27o 19’ 00.191”N Latitude: 

Latitude: 

Latitude: 

Longitude: 90o 06’ 40.416”W Longitude: 

Longitude: 

Longitude: 

Water Depth (Feet): 4237 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 5 

 

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 TVD 

 

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 

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 

 

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 

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 4 of 5 

PUBLIC INFORMATION COPY
OCS PLAN INFORMATION FORM (CONTINUED) 

Sand 1 Sand 2 Sand 3 Sand 4 Sand 5 

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 5 of 5 

PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
Suprasalt Hazards Map w/ Bathy Contour Overlay 

for Relief Well Location Screening at Drill Center B

SB104

SB103

DC G

WI003/WI004

DC B
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 Water-Based 16,035 bbls 128 bbl/day overboard / seafloor NoCuttings wetted with water-based fluid Cuttings wetted with 

seawater, gel, and 10.5 ppg fresh water pad mud residue from riserless hole sections

1,694 bbls 14 bbl/day seafloor No

Synthetic-based drilling fluid Baroid Accolade SBM 3,613 bbls 29 bbl/day overboard No

Cuttings wetted with synthetic-based fluid Cuttings wetted with residue 

of Baroid Accolade SBM

5,022 bbls 40 bbl/day overboard No

Will humans be there? If yes, expect conventional waste

Domestic waste Kitchen waste 34,375 bbls 275 bbl/day remove floating solids 

and discharge

No

Sanitary waste Sanitary waste 9,875 bbls 79 bbl/day chlorinate and discharge No

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

Deck Drainage Rainfall & potable water 22,500 bbls 180 bbl/day filter oil and grease and 

discharge

No

Will you conduct well treatment, completion, or workover? 

Well treatment fluids NA 0 NA NA No

Well completion fluids Water Based fluids and Sea 

Water

3,140 bbls 25 bbl/day discharge used fluids 

overboard

No

Workover fluids NA NA NA NA No

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

Desalinization unit discharge Max capacity 3,076,500 bbls 24,612 bbl/day overboard NoBlowout prevent fluid Stack Magic ECO-FV2 6,250 bbls 50 bbl/day overboard No

Ballast water Sea Water 146,875 bbls 1,175 bbl/day overboard NoBilge water Oil/Water Mixture 3,125 bbls 25 bbl/day 0<15ppm overboard No

Excess cement at seafloor Class H 721 bbls 6 bbl/day seafloor No

Fire water Sea Water 906,250 bbls 7,250 bbl/day overboard NoCooling water Sea Water 56,232,500 bbls 449,860 bbl/day overboard No

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

Produced water NA NA NA NA No

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

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

Projected 

Downhole 

Disposal

Projected

Ocean

Discharges 

TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM - C.R. Luigs

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

Projected 

generated waste

Solid and Liquid Wastes 

transportation 

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

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

EXAMPLE: Synthetic-based drilling fluid or mud

internal olefin, ester Below deck storage tanks on offshore 

support vessels

Newpark Environmental Services Inc., Ingleside, TX

X bbl/well Recycled

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

Oil-based drilling fluid or mud NA NA NA NA NACuttings wetted with oil-based fluids NA NA NA NA NA

Synthetic-based drilling fluid or mud Whole mud sent back in after 

well has been abandoned for 

reconditioning & reuse

Pipeline from dock Baroid facility at Fourchon 

shore base

7500 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

1750 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 NA NA NA NA NA

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

2 cu yds / day 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 625 lbs / day 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

4 bbls /day 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.

0 gal/well

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

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. 
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 Water-Based 16,035 bbls 128 bbl/day overboard / seafloor NoCuttings wetted with water-based fluid Cuttings wetted with 

seawater, gel, and 10.5 ppg fresh water pad mud residue from riserless hole sections

1,694 bbls 14 bbl/day seafloor No

Synthetic-based drilling fluid Baroid Accolade SBM 3,613 bbls 29 bbl/day overboard No

Cuttings wetted with synthetic-based fluid Cuttings wetted with residue 

of Baroid Accolade SBM

5,022 bbls 40 bbl/day overboard No

Will humans be there? If yes, expect conventional waste

Domestic waste Kitchen waste 43,750 bbls 350 bbl/day remove floating solids 

and discharge

No

Sanitary waste Sanitary waste 12,500 bbls 100 bbl/day chlorinate and discharge No

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

Deck Drainage Rainfall & potable water 22,500 bbls 180 bbl/day filter oil and grease and 

discharge

No

Will you conduct well treatment, completion, or workover? 

Well treatment fluids NA 0 NA NA No

Well completion fluids Water Based fluids and Sea 

Water

3,140 bbls 25 bbl/day discharge used fluids 

overboard

No

Workover fluids NA NA NA NA No

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

Desalinization unit discharge Max capacity 1,636,125 bbls 13,089 bbl/day overboard NoBlowout prevent fluid Stack Magic ECO-FV2 2,663 bbls 21 bbl/day overboard No

Ballast water Sea Water 31,438 bbls 252 bbl/day overboard NoBilge water Oil/Water Mixture 375 bbls 3 bbl/day 0<15ppm overboard No

Excess cement at seafloor Class H 721 bbls 8 bbl/min seafloor NoFire water Sea Water 937,500 bbls 7,500 bbl/day overboard NoCooling water Sea Water 99,213,375 bbls 793,707 bbl/day overboard No

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

Produced water NA NA NA NA No

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

TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM - Development Driller 1

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

Projected 

Downhole 

Disposal

Projected

Ocean

Discharges 

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

Projected 

generated waste

Solid and Liquid Wastes 

transportation 

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

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

EXAMPLE: Synthetic-based drilling fluid or mud

internal olefin, ester Below deck storage tanks on offshore 

support vessels

Newpark Environmental Services Inc., Ingleside, TX

X bbl/well Recycled

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

Oil-based drilling fluid or mud NA NA NA NA NACuttings wetted with oil-based fluids NA NA NA NA NA

Synthetic-based drilling fluid or mud Whole mud sent back in after 

well has been abandoned for 

reconditioning & reuse

Pipeline from dock Baroid facility at Fourchon 

shore base

7500 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

1750 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 NA NA NA NA NA

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

2 cu yds / day 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 625 lbs / day 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

4 bbls /day 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.

0 gal/well

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

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. 
OMB Control No. 1010-0151

OMB Approval Expires: 12/31/2011

COMPANY BHP Billiton Pet. (GOM) Inc.

AREA Green CanyonBLOCK 653LEASE OCS-G 20084PLATFORM Shenzi FieldWELL SB103, SB104COMPANY CONTACT Kathy CampTELEPHONE NO. 7132019627REMARKS

Drill and complete Wells SB103 and SB104 with CR Luigs; install 2 jumpers; 

commence production

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

2013 0 02014 2 8

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 0.05050 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 0.000360 0.031 0.0025141 0.00668 1.2 AP-42 3.3-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 0.1835 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 0.050500 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 0.000405 0.024 0.00064155 0.0055 163.6 AP-42 3.4-1 10/96

Diesel Recip. > 600 hp. gms/hp-hr 0.32 0.1835 11 0.33 2.4 163.6 AP42 3.4-1 10/96

Duel Fuel (NG & Diesel) lb/MMBtu 0.0573 0.183154 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 0.3025 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] 0.05 % 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.

[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 653 OCS-G 20084 Shenzi Field SB103, SB104 Kathy Camp 7132019627 Drill and complete Wells SB103 and SB104 with CR Luigs; install 2 jumpers; commence production

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 53743 2595.79 62298.89 24 92 40.58 21.73 1461.93 44.10 232.14 61579.48 44.80 23.99 1613.97 48.69 256.28 67983.75

PRIME MOVER>600hp diesel [2] [3] 47000 2270.10 54482.40 33.16 19.01 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 0.49 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 0.83 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 0.13 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 0.24 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 0.06 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.06 4.96 0.40 1.07 184.00 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 0.20 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 0.35 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 0.35 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 0.002427 0.14 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 92 2.96 3.64 106.53 6.55 47.62 10311.95 3.27 4.02 117.61 7.23 52.57 11384.40

VESSELS ≥37kw diesel(crew) (gens-3) [9] 1083 52.31 1255.41 24 92 0.36 0.44 12.82 2.67 8.90 1240.87 0.39 0.48 14.15 2.95 9.83 1369.92

Work/Supply VESSELS>600hp diesel(work) (main-2) [10] 13196 637.37 15296.80 24 92 9.31 5.34 245.22 9.60 69.82 15119.62 10.28 5.89 270.73 10.60 77.08 16692.06

2 vessels VESSELS>600hp diesel(work) (gen.-2) [10] 4881 235.76 5658.33 24 92 3.44 1.97 80.65 3.55 25.83 5592.79 3.80 2.18 89.04 3.92 28.51 6174.44

VESSELS>600hp diesel(work) (SDT) [10] 2200 106.26 2550.24 24 92 1.55 0.89 36.35 1.60 11.64 2520.70 1.71 0.98 40.13 1.77 12.85 2782.85VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 92 1.11 0.20 15.48 1.24 3.35 574.64 1.22 0.22 17.09 1.37 3.70 634.41

INSTALLATION INSTALLATION Vessel >600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

SUPPORT VESSEL >600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRODUCTION 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2013 YEAR TOTAL (ANNUAL) 99.88 55.94 3420.91 113.42 631.44 158519.54 65.47 37.77 2162.71 76.53 440.83 107021.82

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3996.00 3996.00 3996.00 3996.00 82717.95

120

[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.

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 653 OCS-G 20084 Shenzi Field SB103, SB104 Kathy Camp 7132019627 Drill and complete Wells SB103 and SB104 with CR Luigs; install 2 jumpers; commence production

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 53743 2595.79 62298.89 24 158 40.58 21.73 1461.93 44.10 232.14 61579.48 76.94 41.20 2771.81 83.62 440.13 116754.69

PRIME MOVER>600hp diesel [2] [3] 47000 2270.10 54482.40 33.16 19.01 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 0.49 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 0.83 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 0.13 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 0.24 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 0.06 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.06 4.96 0.40 1.07 184.00 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 0.20 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 0.35 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 0.35 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 0.002427 0.14 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 24 158 2.96 3.64 106.53 6.55 47.62 10311.95 5.61 6.90 201.99 12.41 90.29 19551.46

VESSELS ≥37kw diesel(crew) (gens-3) [9] 1083 52.31 1255.41 24 158 0.36 0.44 12.82 2.67 8.90 1240.87 0.68 0.83 24.31 5.07 16.88 2352.69

Work/Supply VESSELS>600hp diesel(work) (main-2) [10] 13196 637.37 15296.80 24 158 9.31 5.34 245.22 9.60 69.82 15119.62 17.65 10.12 464.94 18.20 132.38 28666.79

2 vessels VESSELS>600hp diesel(work) (gen.-2) [10] 4881 235.76 5658.33 24 158 3.44 1.97 80.65 3.55 25.83 5592.79 6.53 3.74 152.91 6.73 48.97 10603.93

VESSELS>600hp diesel(work) (SDT) [10] 2200 106.26 2550.24 24 158 1.55 0.89 36.35 1.60 11.64 2520.70 2.94 1.69 68.92 3.03 22.07 4779.25VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 158 1.11 0.20 15.48 1.24 3.35 574.64 2.10 0.38 29.35 2.35 6.35 1089.52

INSTALLATION INSTALLATION Vessel >600hp diesel 47000 2270.1 54482.40 24 8 33.16 19.01 1139.80 34.19 248.68 53851.31 3.18 1.83 109.42 3.28 23.87 5169.73

SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 8 11.99 6.88 412.27 12.37 89.95 19478.13 1.15 0.66 39.58 1.19 8.64 1869.90

VESSELS>600hp diesel(supply) 12000 579.6 13910.40 24 8 8.47 4.85 291.01 8.73 63.49 13749.27 0.81 0.47 27.94 0.84 6.10 1319.93

PRODUCTION 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2014 YEAR TOTAL (ANNUAL) 153.50 86.69 5263.98 168.71 1033.56 245598.25 117.59 67.82 3891.16 136.73 795.68 192157.90

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3996.00 3996.00 3996.00 3996.00 82717.95

120

[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.

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 653 OCS-G 20084 Shenzi Field SB103, SB104

Emitted Substance

Year

PM SOx NOx VOC CO

2013 65.47 37.77 2162.71 76.53 440.83

2014 117.59 67.82 3891.16 136.73 795.68

Allowable 3996.00 3996.00 3996.00 3996.00 82717.95

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 653LEASE OCS-G 20084PLATFORM Shenzi FieldWELL SB103, SB104COMPANY CONTACT Kathy CampTELEPHONE NO. 7132019627

REMARKS

Drill / complete Wells SB103 & SB104 with DD1; install 2 jumpers; commence production

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

2013 0 02014 2 8

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 0.05050 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 0.000360 0.031 0.0025141 0.00668 1.2 AP-42 3.3-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 0.1835 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 0.050500 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 0.8930 7.2267 0.6167 1.4533 878.7 Compliance 

Test Apr-13

Diesel Recip. > 600 hp. lb/hp-hr 0.0007 0.000405 0.024 0.00064155 0.0055 163.6 AP-42 3.4-1 10/96

Diesel Recip. > 600 hp. gms/hp-hr 0.32 0.1835 11 0.33 2.4 163.6 AP42 3.4-1 10/96

Duel Fuel (NG & Diesel) lb/MMBtu 0.0573 0.183154 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 0.3025 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] 0.05 % 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 500 ppm in diesel fuel 

assuming that 100 percent of sulfur in the fuel is oxidized to SO2. 

[9] Diesel Recip. > 600 hp.-DD1-Main: Compliance testing of Transocean International's Development Driller 1 (DD-1) eight (8) main engines for PM, NOX, VOC, CO, and CO2 was 

conducted April 2013. The emission factors for the said pollutants conservatively utilized the maximum of the three run averaged emission rates obtained from 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) Inc. Green Canyon 653 OCS-G 20084 Shenzi Field SB103, SB104 Kathy Camp 7132019627

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 Semi SEMI-SUBMERSIBLE 48204 2328.25 55878.08 24 158 65.75 19.40 621.74 52.75 145.58 67420.36 124.66 36.79 1178.82 100.01 276.02 127829.01

PRIME MOVER>600hp diesel [2] [3] 40768 1969.09 47258.27 59.85 16.49 484.36 41.33 97.41 58891.32 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2229 107.66 2583.86 1.57 0.90 54.06 1.62 11.79 2553.93 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-POSU-CA PU Eng. [4] 600 28.98 695.52 0.20 0.24 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 0.06 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE ,600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.06 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 [5] 250 12.08 289.80 0.08 0.10 2.73 0.62 1.44 286.44 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [6] 490 23.67 568.01 0.44 0.20 7.41 1.05 9.18 561.43 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [7] 860 41.54 996.91 0.61 0.35 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [7] 860 41.54 996.91 0.61 0.35 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Fast Rescue 142 6.86 164.61 0.31 0.05 4.40 0.36 0.95 163.30 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Lifeboat 440 21.25 510.05 0.97 0.16 13.64 1.11 2.94 506.00 0.00 0.00 0.00 0.00 0.00 0.00

SEISMIC OP ENGINE <600hp diesel [10] 1245 60.13 1443.20 0.41 0.45 13.57 3.13 7.17 1431.75 0.00 0.00 0.00 0.00 0.00 0.00

Crew VESSELS ≥37kw diesel(crew) (main-4) [8] 9000 434.70 10432.80 24 158 2.96 3.64 106.53 6.55 47.62 10311.95 5.61 6.90 201.99 12.41 90.29 19551.46

VESSELS ≥37kw diesel(crew) (gens-3) [8] 1083 52.31 1255.41 24 158 0.36 0.44 12.82 2.67 8.90 1240.87 0.68 0.83 24.31 5.07 16.88 2352.69

Work/Supply VESSELS>600hp diesel(work) (main-2) [9] 6598 318.68 7648.40 24 158 4.65 2.67 122.61 4.80 34.91 7559.81 8.83 5.06 232.47 9.10 66.19 14333.40

VESSELS>600hp diesel(work) (gen.-2) [9] 4881 235.76 5658.33 24 158 3.44 1.97 80.65 3.55 25.83 5592.79 6.53 3.74 152.91 6.73 48.97 10603.93VESSELS>600hp diesel(work) (SDT) [9] 2200 106.26 2550.24 24 158 1.55 0.89 36.35 1.60 11.64 2520.70 2.94 1.69 68.92 3.03 22.07 4779.25VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 158 1.11 0.20 15.48 1.24 3.35 574.64 2.10 0.38 29.35 2.35 6.35 1089.52

INSTALLATION INSTALLATION Vessel >600hp diesel 47000 2270.1 54482.40 24 8 33.16 19.01 1139.80 34.19 248.68 53851.31 3.18 1.83 109.42 3.28 23.87 5169.73

SUPPORT VESSEL >600hp diesel 17000 821.1 19706.40 24 8 11.99 6.88 412.27 12.37 89.95 19478.13 1.15 0.66 39.58 1.19 8.64 1869.90VESSELS>600hp diesel(supply) 12000 579.6 13910.40 24 8 8.47 4.85 291.01 8.73 63.49 13749.27 0.81 0.47 27.94 0.84 6.10 1319.93

PRODUCTION 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2014 YEAR TOTAL (ANNUAL) 199.19 79.37 3461.00 181.20 825.53 249720.21 156.49 58.35 2065.69 144.02 565.37 188898.82

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3996.00 3996.00 3996.00 3996.00 82717.95

120

Drill / complete Wells SB103 & SB104 with DD1; install 2 jumpers; commence production

[2] PRIME MOVER >600hp diesel-DD1: TOI's DD-1 maximum output per main engine is 5096 hp/3800 kW with normal operation involves operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines.[3] PRIME MOVER >600 hp. diesel-DD1: 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 5096 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of TOI'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.[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.[5] 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.[6] 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.[7] 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. [9] 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.[10] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines.

≥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.

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 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 653 OCS-G 20084 Shenzi Field SB103, SB104 Kathy Camp 7132019627

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

DP Semi SEMI-SUBMERSIBLE 48204 2328.25 55878.08 24 92 65.75 19.40 621.74 52.75 145.58 67420.36 72.59 21.42 686.40 58.23 160.72 74432.08

PRIME MOVER>600hp diesel [2] [3] 40768 1969.09 47258.27 59.85 16.49 484.36 41.33 97.41 58891.32 0.00 0.00 0.00 0.00 0.00 0.00

Emergency Generator>600hp diesel 2229 107.66 2583.86 1.57 0.90 54.06 1.62 11.79 2553.93 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE <600hp diesel-POSU-CA PU Eng. [4] 600 28.98 695.52 0.20 0.24 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 0.06 4.96 0.40 1.07 184.00 0.00 0.00 0.00 0.00 0.00 0.00

WIRELINE ,600hp diesel-Generator DHPS 160 7.73 185.47 0.35 0.06 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 [5] 250 12.08 289.80 0.08 0.10 2.73 0.62 1.44 286.44 0.00 0.00 0.00 0.00 0.00 0.00

CEMENTING <600hp diesel (Nitrogen pump) [6] 490 23.67 568.01 0.44 0.20 7.41 1.05 9.18 561.43 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [7] 860 41.54 996.91 0.61 0.35 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hp diesel [7] 860 41.54 996.91 0.61 0.35 13.86 0.63 4.55 985.36 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Fast Rescue 142 6.86 164.61 0.31 0.05 4.40 0.36 0.95 163.30 0.00 0.00 0.00 0.00 0.00 0.00EMERGENCY EQUIP <600hp diesel-Lifeboat 440 21.25 510.05 0.97 0.16 13.64 1.11 2.94 506.00 0.00 0.00 0.00 0.00 0.00 0.00

SEISMIC OP ENGINE <600hp diesel [10] 1245 60.13 1443.20 0.41 0.45 13.57 3.13 7.17 1431.75 0.00 0.00 0.00 0.00 0.00 0.00

Crew VESSELS ≥37kw diesel(crew) (main-4) [8] 9000 434.70 10432.80 24 92 2.96 3.64 106.53 6.55 47.62 10311.95 3.27 4.02 117.61 7.23 52.57 11384.40

VESSELS ≥37kw diesel(crew) (gens-3) [8] 1083 52.31 1255.41 24 92 0.36 0.44 12.82 2.67 8.90 1240.87 0.39 0.48 14.15 2.95 9.83 1369.92

Work/Supply VESSELS>600hp diesel(work) (main-2) [9] 6598 318.68 7648.40 24 92 4.65 2.67 122.61 4.80 34.91 7559.81 5.14 2.95 135.36 5.30 38.54 8346.03

VESSELS>600hp diesel(work) (gen.-2) [9] 4881 235.76 5658.33 24 92 3.44 1.97 80.65 3.55 25.83 5592.79 3.80 2.18 89.04 3.92 28.51 6174.44VESSELS>600hp diesel(work) (SDT) [9] 2200 106.26 2550.24 24 92 1.55 0.89 36.35 1.60 11.64 2520.70 1.71 0.98 40.13 1.77 12.85 2782.85VESSELS<600hp diesel(work) (E-Generator) 502 24.22 581.38 24 92 1.11 0.20 15.48 1.24 3.35 574.64 1.22 0.22 17.09 1.37 3.70 634.41

INSTALLATION INSTALLATION Vessel >600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

SUPPORT VESSEL >600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRODUCTION 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2013 YEAR TOTAL (ANNUAL) 145.57 48.63 1617.92 125.91 423.41 162641.50 88.12 32.26 1099.78 80.77 306.72 105124.13

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 3996.00 3996.00 3996.00 3996.00 82717.95

120

Drill / complete Wells SB103 & SB104 with DD1; install 2 jumpers; commence production

[8] Diesel Recip. [9] 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.[10] Diesel Recip. < 600 hp.-EPA Tier 2: PM, NOx, and CO emission factors for EPA Tier 2 diesel engines.

≥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.

[2] PRIME MOVER >600hp diesel-DD1: TOI's DD-1 maximum output per main engine is 5096 hp/3800 kW with normal operation involves operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines.[3] PRIME MOVER >600 hp. diesel-DD1: 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 5096 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of TOI'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.[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.[5] 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.[6] 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.[7] 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.

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 WELLBHP Billiton Pet.Green Canyon 653 OCS-G 20084 Shenzi Field SB103, SB104

Emitted Substance

Year

PM SOx NOx VOC CO

2013 88.12 32.26 1099.78 80.77 306.72

2014 156.49 58.35 2065.69 144.02 565.37

Allowable 3996.00 3996.00 3996.00 3996.00 82717.95

Drill / complete Wells SB103 & SB104 with DD1; install 2 jumpers; commence

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
Page 2 of 15 

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
Page 3 of 15 

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 

PUBLIC INFORMATION COPY
Page 4 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. 

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
Page 5 of 15 

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. 

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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 

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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 

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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. 

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 

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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. 

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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 

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WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (120 miles from s

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 Trave

CGA 

Basler 67T 2000 NA 2 Houma 1 1 0

ASI 

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

Offshore Response

Offshore Equipment No 

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

Sp

CGA 

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

T&T Marine (available through contract with CGA) 

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

Recovered Oil Storage No 

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

S

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 

K-Sea Operating (available through contract with CGA) 

PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 2 DBL 76 1212984 NA 83937 1 Tug 6 Venice 4 12 2 

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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 

CGA 

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 8 FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 1 2 1.75 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Ingleside 1 2 11 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 5.5 FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 3.5 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 3.25 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 Hydro-Fire Boom NA NA 8 Utility 40 Harvey 1 4 1.75 

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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 T

Sp

CGA 

46’ FRV 5000 65 NA 4 Leeville 1 0 2 46’ FRV 5000 65 NA 4 Venice 1 0 1 Trinity SWS 21500 249 NA 4 Leeville 1 2 2 Trinity SWS 21500 249 NA 4 Venice 1 2 2 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 

Staging Area: Venice

Nearshore and Inland Skimmers 

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

D

SWS Egmopol 3000 100 NA 3 Galveston 1 2 8 SWS Egmopol 3000 100 NA 3 Morgan City 1 2 3.25 SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 SWS Marco 3588 34 NA 3 Leeville 1 2 3.5 SWS Marco 3588 34 NA 3 Venice 1 2 0 Rope Mop 77 2 0 3 Harvey 1 2 8 Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 1 2 5.5 Foilex Skim Package (TDS 150) 891 45 NA 3 Galveston 1 2 8 Foilex Skim Package (TDS 150) 891 45 NA 3 Harvey 1 2 1.75 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 1 2 5.5 4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 1 2 1.75 2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Lake Charles 1 2 5.5 

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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 

ES&H (available through MSA) 

50,000’ 18” Shoreline Boom 20 Crew 50 Houston, TX .5 .5 7.5 2 50,000’ 18” Shoreline Boom 20 Crew 50 Lake Charles, LA .5 .5 5.5 2 20,000’ 18” Shoreline Boom 8 Crew 20 New Iberia, LA .5 .5 4 2 

1,000’ 18” Shoreline Boom 2 Crew 6 Morgan City, LA .5 .5 3.25 2 

20,000’ 18” Shoreline Boom 8 Crew 20 Belle Chasse, LA .5 .5 1.5 2 15,000’ 18” Shoreline Boom 6 Crew 14 Mobile, AL .5 .5 4.25 2 

5,000’ 18” Shoreline Boom 2 Crew 6 Dallas Ft. Worth, TX .5 .5 10.25 2 

50,000’ 18” Shoreline Boom 20 Crew 50 Houma, LA .5 .5 3 2 

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

Deploy

CGA 

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 8 1 Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 11 1 Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 1 

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

Deploym

CGA 

Wildlife Support Trailer NA NA NA 2 Houma 1 2 3 1 Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 1.5 1 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 1 Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 1 Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 11 1 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 1 Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 1 

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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PUBLIC INFORMATION COPY ATTACHMENT L
Gulf of Mexico Production Unit

NTL No. xxxxx WORST CASE DISCHARGE 

Shenzi SB103 Production Well 

Rev No. Issue Date Reason for and Description of change ORIG CHECKER APPROVER 

01 4/10/2013 SB103 worst case discharge report SL WM 

 

 

 

 

 

 

 

Next Review Date: Review Period: 

DOCUMENT CONTROL NUMBER 

Project ID Originator Function Discipline Doc. Type Sequence No. Revision No. 

 

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