UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Development Plan

Control # - R-05124

Type - Revised Development Plan

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

Operator - BHP Billiton Petroleum (GOM) Inc.

Shenzi SB101 well

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.

 James Webb

Plan Coordinator

Description -

Rig Type -

Subject:

From:

May 6, 2011
BOEM RECORD OF CHANGES

FOR

Plan Control No: R-05124

Shenzi Well SB101

DESCRIPTION OF CHANGE DATE PAGES 

Initial submittal of NTL2010-N06 data 11/07/2010 All 

Amendment of Revised Plan with additional EA information 01/05/2011 All 

Amendment of Complete Plan with corrections excluding Well 

SB201 02/08/2011 All 

Amendment of Louisiana CZM Certificate 02/21/2011 Pgs 27 and 27a 

Amendment of Complete Plan with waste(s) and discharge(s) 

corrections 03/21/2011 All 

Amendment of Storage Tanks Information 05/04/2011 Pg 3 

PUBLIC INFORMATION 

PUBLIC INFORMATION COPY 

Table of Contents

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

Plan Information Form........................................................................................................................................ 1

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

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

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

Service Fees  ........................................................................................................................................................ 3

Pollution Prevention Measures .......................................................................................................................... 3

Additional Measures........................................................................................................................................... 3

GENERAL INFORMATION ...............................................................................................................................4

Applications and Permits.................................................................................................................................... 4

Drilling Fluids....................................................................................................................................................... 4

Peak Production Rates / Life of Reserves ........................................................................................................... 4

Oil Characteristics............................................................................................................................................... 4

New or Unusual Technology ............................................................................................................................... 5

Bonding Information........................................................................................................................................... 5

Oil Spill Financial Responsibility (OSFR).............................................................................................................. 6

Deepwater Well Control Statement  .................................................................................................................. 6

Suspensions of Production.................................................................................................................................. 6

Blowout Scenario  ............................................................................................................................................... 6

Chemical Products  ............................................................................................................................................. 6

GEOLOGICAL AND GEOPHYSICAL INFORMATION...........................................................................................7

Geological Description  ....................................................................................................................................... 7

Structure Contour Maps  .................................................................................................................................... 7

Interpreted 2‐D or 3‐D Seismic Lines  ................................................................................................................. 7

Geological Structure Cross‐Sections  .................................................................................................................. 7

Shallow Hazards Report  ..................................................................................................................................... 7

Site Specific Shallow Hazards Assessment  ......................................................................................................... 7

High Resolution Seismic Lines  ............................................................................................................................ 7

Stratigraphic Column  ......................................................................................................................................... 7

Time Versus Depth Table  ................................................................................................................................... 7

Geochemical Information  .................................................................................................................................. 7
PUBLIC INFORMATION COPY 

Future G&G Activities  ........................................................................................................................................ 7

HYDROGEN SULFIDE INFORMATION  .............................................................................................................8

Concentration  .................................................................................................................................................... 8

Classification Request  ........................................................................................................................................ 8

Contingency Plan  ................................................................................................................................................ 8

Modeling Report  ................................................................................................................................................ 8

MINERAL AND RESOURCE CONVERSATION INFORMATION  ...........................................................................9

Technology and Reservoir Engineering Practices and Procedures  .................................................................... 9

Technology and Recovery Practices and Procedures  ........................................................................................ 9

Reservoir Development  ..................................................................................................................................... 9

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION  ................................................................... 10

Chemosynthetic Communities Report  ............................................................................................................. 10

Topographic Features Map............................................................................................................................... 10

Topographic Features Statement   .................................................................................................................... 10

Live Bottom (Pinnacle Trend) Map  .................................................................................................................. 10

Live Bottom (Low Relief) Map  .......................................................................................................................... 10

Potentially Sensitive Biological Features  ......................................................................................................... 10

ROV Monitoring Survey Plan  ............................................................................................................................ 10

Threatened and Endangered Species Information  .......................................................................................... 12

Archaeological Report  ...................................................................................................................................... 11

Air and Water Quality Information   ................................................................................................................. 11

Socioeconomic Information  ............................................................................................................................. 11

WASTE AND DISCHARGE INFORMATION  ..................................................................................................... 12

Projected Generated Wastes  ........................................................................................................................... 12

Projected Ocean Discharges  ............................................................................................................................ 12

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

NPDES Permits   ................................................................................................................................................ 13

Cooling Water Intakes  ...................................................................................................................................... 13

AIR EMISSIONS INFORMATION  ................................................................................................................... 14

Screening Checklist  .......................................................................................................................................... 14

Summary Table of Emissions  ........................................................................................................................... 14

Spreadsheets  .................................................................................................................................................... 14

OIL SPILL INFORMATION  ............................................................................................................................. 15
PUBLIC INFORMATION COPY 

Site Specific OSRP.............................................................................................................................................. 15

Regional or Sub‐Regional OSRP Information .................................................................................................... 15

Spill Response Sites........................................................................................................................................... 15

OSRO Information............................................................................................................................................. 15

Worst Case Scenario Determination................................................................................................................. 16

NTL 2010‐NO6‐ WCD Calculations Overview.................................................................................................... 16

Oil Spill Response Discussion ............................................................................................................................ 17

Modeling Report............................................................................................................................................... 17

ENVIRONMENTAL MONITORING INFORMATION  ........................................................................................ 18

Monitoring Systems  ......................................................................................................................................... 18

Incidental Takes................................................................................................................................................ 18

Flower Garden Banks National Marine Sanctuary  ........................................................................................... 18

LEASE STIPULATIONS INFORMATION  .......................................................................................................... 19

ENVIRONMENTAL MITIGATION MEASURES INFORMATION  ........................................................................ 20

Impacts to Marine / Coastal Environments / Habitats, Biota, and Threatened and Endangered Species  ...... 20

Incidental Takes................................................................................................................................................ 20

DECOMMISSIONING INFORMATION  ........................................................................................................... 21

RELATED FACILITIES AND OPERATIONS INFORMATION  ............................................................................... 22

Related OCS Facilities and Operations  ............................................................................................................. 22

Transportation System  ..................................................................................................................................... 22

Produced Liquid Hydrocarbons Transportation Vessels  .................................................................................. 22

SUPPORT VESSELS AND AIRCRAFT INFORMATION  ...................................................................................... 23

General.............................................................................................................................................................. 23

Diesel Oil Supply Vessels  .................................................................................................................................. 23

Drilling Fluids Transportation  ........................................................................................................................... 23

Solid and Liquid Wastes Transportation........................................................................................................... 24

Vicinity Map  ..................................................................................................................................................... 24

ONSHORE SUPPORT FACILITIES INFORMATION  ........................................................................................... 25

General  ............................................................................................................................................................. 25

Support Base Construction or Expansion ......................................................................................................... 25

Support Base Construction or Expansion Timetable  ....................................................................................... 25

Waste Disposal  ................................................................................................................................................. 25

Air Emissions  .................................................................................................................................................... 25
PUBLIC INFORMATION COPY 

Unusual Solid and Liquid Wastes  ..................................................................................................................... 25

SULPHUR OPERATIONS INFORMATION  ....................................................................................................... 26

COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION  ....................................................................... 27

Consistency Certification  .................................................................................................................................27

Other Information............................................................................................................................................. 27

ENVIRONMENTAL IMPACT ANALYSIS (EIA)  .................................................................................................. 28

ADMINISTRATIVE INFORMATION  ............................................................................................................... 29

Exempted Information Description (Public Information Copies Only)  ............................................................ 29

Bibliography  ..................................................................................................................................................... 29

Plan Attachments

Attachment A Plan Information Form 

Attachment B Well Location Plats 

Attachment C Worst Case Discharge Assessment and Figures 

Attachment D Air Emission Spreadsheets 

Attachment E Spill Response Discussion for NEPA
BHP Billiton Petroleum (GOM) Inc. 1 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

Revision to Initial Development Operations Coordination 

Document (DOCD) Control No. N-09001 

for 

Green Canyon 654 Unit, Agreement No. 754307012 

Block 653, Lease OCS-G 20084 

Offshore Louisiana

CONTENTS OF PLAN

In accordance with NTL 2010-N06 “Information Requirements for Exploration Plans, 

Development and Production Plans, and Development Operations Coordination Documents”, 

effective June 18, 2010, BHP Billiton Petroleum (GOM) Inc. (herein referred to as BHPB) is 

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

granted to BHPB on September 18, 2007. 

The following is a history of the wells approved under Plan N-9001: 

Well 

Name Complete Date Production Start Date Status 

SB101 See Remarks Not drilled yet

SB102 12/31/2001 3/23/2009 Producing 

SB103 See Remarks Not drilled yet 

SB201 See Remarks DSI – due to 2010 moratorium 

SB203 7/6/2009 09/08/2009 Producing 

SC103 See Remarks 09/13/2009 Re-named / drilled as SC102 

SC104 11/1/2008 07/13/2009 Producing 

SG101 1/29/2008 03/26/2009 Producing 

SG102 4/12/2008 03/30/2009 Producing 

SG103 12/19/2008 04/06/2009 Producing 

SG104 9/18/2009 09/28/2009 Producing 

SG203 See Remarks Re-named / drilled as SB202 

 SG204 See Remarks Re-named / drilled as SB204 

Under this Revised Plan, BHPB is updating Plan N-9001 to ultimately obtain approval for the 

drilling, completion and production of Well SB101 in response to the BOEMRE’s news release 

issued on December 13, 2010, via the Office of Public Affairs titled "BOEMRE Issues Guidance 

for Deepwater Drillers to Comply with Strengthened Safety and Environmental Standards" along 

with that guidance document titled "Approval Requirements for Activities That Involve the Use of 

a Subsea Blowout Preventer (BOP) or a Surface BOP On a Floating Facility." 

(a) Plan Information Form 

 

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

production operations along with BHPB’s tentative schedule is included as Attachment A. 

The proposed well will be drilled with the CR Luigs using subsurface BOPs. There will be no 

anchors associated with the drilling operations proposed in this Plan. 
BHP Billiton Petroleum (GOM) Inc. 2 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

(b) Bathymetry Map and Location Plat 

Included as Attachment B are the Well Location Plats. The plats show the surface location of 

proposed Well SB101. Please note, bottom hole location, MD & TVD depths are omitted from 

the Public Information Copy. 

The Bathymetry Map was previously submitted in Plan N-09001 and will not be affected by this 

revision. 

(c) Safety and Pollution Prevention Features

The proposed well addressed in this Plan will be drilled with the CR LUIGS (a drillship) 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. 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 

 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 (BOEMRE), 

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. 

The BOEMRE 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. 

The BOEMRE also inspects the stockpiles of equipment listed in the Operator's approved 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.
BHP Billiton Petroleum (GOM) Inc. 3 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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

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

in the EPA’s NPDES General Permit GMG290000. Some of these pollution prevention 

measures include installation of curbs, gutters, drip pans, and drains on drilling deck areas to 

collect all contaminants and debris. 

(d) Storage Tanks and Production Vessels

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

Type of Storage 

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

Total 

Capacity 

(bbls) 

Fluid Gravity 

(API)

LO Tank P 

LO Tank S 

Dirty Oil Tank AFT 

Dirty Oil Tank FWD 

Base Oil 

Drillship – CRL 

 

884 

884 

393 

91 

4713 

1 

1 

1 

1 

1 

884 

884 

393 

91 

4713 

 29-39o 

(e) Service Fees

A service fee is not required for this type of submittal at this time. 

(f) Pollution Prevention Measures 

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.

(g) Additional 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 BOEMRE has accepted a proposed Containment Plan which outlines the response 

to a complete loss of well control. BHPB is a signatory to the "Agreement for Response 

Resources" between Clean Gulf Associates and Helix Energy Solutions Group Inc, for the "Helix 

Fast Response System (HFRS)". 

At this time, use of the HFRS is at the core of the Containment Plan, however, BHPB also fully 

intends participating in the Marine Well Containment Corp. (MWCC) venture for oil-spill 

containment equipment. MWCC will have interim capabilities to augment our Containment Plan 

in the near term and full capabilities to augment our Plan in the future. 

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

Revised 03.11.2011 

Revised 05.04.2011 
BHP Billiton Petroleum (GOM) Inc. 4 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

GENERAL INFORMATION

(a) Applications and Permits

Application / Permit Issuing Agency Status 

APD BOEMRE District To be submitted via eWell 

CID BOEMRE Regional In preparation 

Supplemental DWOP BOEMRE Regional In preparation 

Surface Safety System BOEMRE District 11/03/2010 

Surface Commingle / 

Measurement BOEMRE Regional Approved 9/27/2010 

Downhole Commingle BOEMRE Regional If required 

Lease Term Pipelines BOEMRE Regional SB101 – SN18127 Approved 9/10/2010 

(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 per well 

Water-based (SW, FW, Barite) 14,273 bbls 

Oil-based (diesel, mineral oil) NA 

Synthetic-based (internal olefin, ester, etc) 13750 bbls 

(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

Peak production rates and life of reserves were previously submitted with Plan N-9001 and are 

not being revised at this time. 

(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. 

Revised 03.11.2011 
BHP Billiton Petroleum (GOM) Inc. 5 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

Characteristic Units Value Range Analytical Methodologies 

Gravity (API° at 60 °F) 27 – 31 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 

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 

Information on the oil composition most likely to result in the largest volume spill is discussed in 

detail in BHPB’s Worst Case Discharge document in Attachment C. 

(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 Revised 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”. 
BHP Billiton Petroleum (GOM) Inc. 6 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

(g) Oil Spill Financial Responsibility (OSFR)

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

facilities proposed in this Revised 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 (BOEMRE Operator No. 02010) has the financial capability to drill a relief well and 

conduct other emergency well control operations. 

(i) Suspensions of Production

Not required for the activities proposed in this plan 

(j) Blow out Scenario

The Notice to Lessees (NTL) 2010-N06 discussion was previously submitted to the BOEMRE 

for Well SB101 by letter dated November 9, 2010. The data has been reviewed by the 

BOEMRE and is included as Attachment C to assist you in your review. 

(k) Chemical Products

This information is not required for the activities proposed in this plan in the BOEMRE GOMR. 
BHP Billiton Petroleum (GOM) Inc. 7 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 

(b) Structure Contour Maps 

PROPRIETARY DATA 

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

PROPRIETARY DATA 

(d) Geological Structure Cross-Sections

PROPRIETARY DATA 

(e) Shallow Hazards Report

A Geohazards Assessment was previously submitted and will not be affected by this revision. 

(f) Site Specific Shallow Hazards Assessment

A Site Specific Shallow Hazards Assessment was previously submitted and will not be affected 

by this revision. 

(g) High Resolution Seismic Lines

3-D survey information was utilized and previously submitted and will not be affected by this 

revision. 

(h) Stratigraphic Column 

PROPRIETARY DATA 

(i) Time Versus Depth Tables 

PROPRIETARY DATA 

 

(j) Geochemical Information

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

(k) Future G&G Activities

This information is not required for the activities proposed in this plan in the BOEMRE GOMR. 
BHP Billiton Petroleum (GOM) Inc. 8 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

HYDROGEN SULFIDE INFORMATION

(a) Concentration

BHPB does not anticipate encountering H2S while conducting our proposed development 

activities. 

(b) Classification Request

Based on previous drilling, no H2S is known to occur in the project area. 

BHPB requests that Green Canyon Area Block 653 be classified as a “Zone where the absence 

of H2S has been confirmed”. 

(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. 
BHP Billiton Petroleum (GOM) Inc. 9 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 
BHP Billiton Petroleum (GOM) Inc. 10 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 highdensity 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. 

Well SB101 is being drilled at a previously approved drill center. 

(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 Revised Plan are located in Grid 

13. Grid 13 has been identified by BOEMRE as an area with adequate ROV survey coverage. 
BHP Billiton Petroleum (GOM) Inc. 11 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

(h) Threatened and Endangered Species Information

The Marine Mammal Protection Act (MMPS) 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. Five marine mammal 

species (sea otters, manatees, dugong, walrus and polar bear) fall under the jurisdiction of the 

Department of the Interior and its US Fish and Wildlife Service (USFWS). The cetaceans 

(whales, porpoises and dolphins) and all pinnipeds (seals and sea lions – except for walrus) are 

managed by the Department of Commerce’s National Marine Fisheries Service (NMFS). 

Endangered Species Act of 1973 (ESA) provides for the conservation of species that are 

endangered or threatened throughout all of a significant portion of their range, and the 

conservation of the ecosystems / critical habitat on which they depend. 

The bottlenose dolphin is a common inhabitant of the continental shelf and upper slope waters 

of the northern GOM. 

Five baleen whales (the northern right, blue, fin, sei, and humpback), one toothed whale (the 

sperm whale), and one sirenian (the West Indian manatee) occur in the GOM and are listed as 

endangered under the Endangered Species Act (ESA). The sperm whale is common in oceanic 

waters of the northern GOM and appears to be a resident species, while the baleen whales are 

considered rare or extralimital in the Gulf (Würsig et al., 2000). The West Indian manatee 

typically inhabits only coastal marine, brackish, and freshwater areas. 

BHPB 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. 

BHPB is not aware of the presence of any threatened or endangered species specifically within 

Green Canyon Block 653. 

(i) Archaeolo gical Report

Green Canyon Block 653 is not specified by NTL 2005-G07 or 2008-G20, as a lease block that 

has been determined to have a high potential for containing archaeological properties; therefore 

an assessment was not required. 

(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) Socioecon omic Information

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

information is not required. 
BHP Billiton Petroleum (GOM) Inc. 12 Green Canyon Block 653

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084

WASTE AND DISCHARGE INFORMATION

(a) Projected Generated Wastes

Type of Waste Composition Projected Amount

Spent drilling fluids Water-Based 14273 bbls

Spent drilling fluids Synthetic-based 4614 bbls

Cuttings Drill cuttings associated with water-based 

fluids 1666 bbls

Cuttings containing SBM Cuttings coated with ester-based synthetic 

drilling muds 4891 bbls

Mud / cuttings Gel, WBM, Cuttings, SW & caustic

Gel - NA

WBM – 14273 bbls

Cuttings – 6000 bbls

SW & caustic – 20 bbls

Sanitary wastes Sanitary wastes 20 gal/person/day

Domestic waste Domestic waste 30 gal/person/day

Deck drainage Water / rainfall 3309 bbl/year

Based on 65” / year rainfall average

Well treatment, workover or completion 

fluids Fluids generated from completion 30,800 bbl/ well

Uncontaminated fresh or seawater NA NA

Desalinization unit water Desalinization unit water 120 bbl/day (max unit capacity)

Uncontaminated bilge water NA NA

Uncontaminated ballast water NA NA 

Used & Waste Oil Oil filters, rags, pads, empty drums 4 bbls / day

Trash and debris; non-recyclables Refuse generated by personnel on board 

MODU 2 yd3 / day

Non-hazardous recyclables & scrap metal Non-hazardous recyclables & scrap metal 625 lbs / day

Chemical products and general hazardous 

waste Paint waste, chemicals, solvents, etc. 35 lbs / day

Produced Sand NA NA

Produced Water Produced Water 75,000 bbls / day

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:

Type of Waste Amount to be Discharged Discharge Rate Discharge Method

Drill cuttings associated with waterbased fluids 1666 bbls 400 bbls/hr Overboard

Drill cuttings associated with 

synthetic drilling fluids 4891 bbls NA Overboard

Mud / cuttings 

Gel - NA

WBM – 14273 bbls

Cuttings – 6000 bbls

SW & caustic – 20 bbls

NA Overboard / seafloor

Sanitary wastes 20 gal/person/day NA chlorinate and discharge

Domestic waste 30 gal/person/day NA remove floating solids and 

discharge

Deck drainage

3309 bbl/year

Based on 65” / year rainfall 

average

102 bbl

Based on 2” / hour of 

rainfall

filter oil and grease and 

discharge

Well treatment, workover or 

completion fluids 30,800 bbl/ well 100 bbl / hr Discharge used fluids overboard, return excess to shore for credit

Uncontaminated fresh or seawater NA NA NA

Desalinization unit water 120 bbl/day (max unit capacity) NA overboard

Uncontaminated bilge water NA NA NA

Uncontaminated ballast water NA NA NA

Produced Water 27,000,000 / year 75,000 / day overboard

Revised 03.11.2011
BHP Billiton Petroleum (GOM) Inc. 13 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

(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 BOEMRE GOMR. 

(e) Cooling Water Intakes

This information is not required for the activities proposed in this plan in the BOEMRE GOMR. 
BHP Billiton Petroleum (GOM) Inc. 14 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

AIR EMISSIONS INFORMATION

(a) Screening Checklist

Included in this section, (if applicable) is the Projected Air Emissions Worksheet prepared in 

accordance with NTL Nos. 2008-G04 and 2009-G27. 

There would be a limited degree of air quality degradation in the immediate vicinity of the 

production and development activities in the Shenzi Field. The Projected Air Quality Emissions 

Reports indicate that the BOEM exemption levels will not be exceeded during the operations for 

the Shenzi “B” Drill Center in this Plan. The Shenzi TLP and the Drill Centers’ activities are not 

collocated activities.

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 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: 

Joshua O’Brien, BHP Billiton Petroleum, (713) 599-6132. 

(b) Summary Table of Emissions

COMPANY AREA BLOCK LEASE PLATFORM WELL 

BHP Billiton Pet. 

(GOM) Inc. Green Canyon 653 OCS-G 20084 0 SB101 

Year Emitted Substance 

 PM SOx NOx VOC CO 

2011 71.67 39.24 2362.6 3 74.33 518.38 

Allowable 3996.00 3996.00 3996.00 3996.00 82717.95 

(c) Spreadsheets

Air Emission Spreadsheets are included as Attachment D.

Revised 03.11.2011 
BHP Billiton Petroleum (GOM) Inc. 15 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 Subregional OSRP Information

BHP Billiton Petroleum (GOM) Inc. (Company No. 02010) is covered under BHP 

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

proposed activities and facilities in this Revised Plan will be covered by the Oil 

Spill Response Plan filed by BHP Billiton Petroleum (Americas) (Company No. 

00362) in accordance with 30 CFR 254 and approved on August 31, 2009. The 

OSRP was most recently updated on March 9, 2011 by including updates to the 

WCD response scenarios, the removal of NRCC storage barges, and the 

addition of newly required language throughout the plan. The OSRP certification 

letter was accepted by BOEMRE on March 10, 2011. The Helix Well 

Containment Plan was approved by the BOEM on March 10, 2011. BHP Billiton 

Petroleum (Americas) Inc. is a member of the Helix Well Containment Group. 

 (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 Revised 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). The Marine 

Spill Response Corporation's (MSRC) STARS network will provide closest 

available personnel, as well as an MSRC supervisor to operate the equipment. 

BHPB has access to additional temporary storage, provided by National 

Response Corporation (NRCC). In the event of a large spill, the NRC Defender 

and/or NRC Valiant would be available. 

Revised 03.11.2011 
BHP Billiton Petroleum (GOM) Inc. 16 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

(iv) Worst Case Scenario Determination

The activities proposed in this Revised Plan are ten miles or more seaward from the 

coastline, therefore BHPB has referenced the “far-shore” worst case scenario in our 

approved regional OSRP. BHPB has determined that the worst-case discharge (WCD) 

proposed in this Revised Plan does not supersede the worst-case discharge as 

approved in our Regional OSRP. The Worst Case Discharge comparison is 

summarized in the table below: 

Category Regional OSRP Revised DOCD 

Type of Activity1 Drilling Drilling 

Facility Location (area/block) GC 738 GC 653 

Facility Designation2 Well 001 Well SB101 

Distance to Nearest Shoreline (statute miles) 124 120 

Volume3 

Uncontrolled blowout (volume per day) 184,000 131,116 

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

API Gravity(s)4 26.8 ̊ 32.1 ̊

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.

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 Revised Plan. 

NTL 2010-N06 – WCD Calculations Overview

The Notice to Lessees (NTL) 2010-N06 discussion was previously submitted to the BOEMRE 

for Well SB101 by letter dated November 9, 2010. The data presently being reviewed by the 

BOEMRE is included in this Plan as Attachment C to assist you in your review. 
BHP Billiton Petroleum (GOM) Inc. 17 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

(b) Oil Spill Response Discussion

BHPB’s spill response discussion is included as Attachment E. 

 

(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 BOEMRE GOMR for guidance in preparing the report and the 

BOEMRE GOMR would be provided with two copies. 

Revised 03.11.2011 
BHP Billiton Petroleum (GOM) Inc. 18 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

ENVIRONMENTAL MONITORING INFORMATION

(a) Monitorin g Systems

BHPB is aware of the requirements of NTL No. 2009-G02 whereby BOEMRE 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. 
BHP Billiton Petroleum (GOM) Inc. 19 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

LEASE STIPULATIONS INFORMATION

BOEMRE did not invoke any lease stipulations for Leases OCS-G 20084, Green Canyon Block 

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

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(a) Impacts to Marine and Coastal En vironments and Habitats, Biota, and 

Threatened and Endangered Species

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

therefore this information is not required. 

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

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

DECOMMISSIONING INFORMATION

This information is not required for plans submitted in the BOEMRE GOMR. 
BHP Billiton Petroleum (GOM) Inc. 22 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

RELATED FACILITIES AND OPERATIONS INFORMATION

(a) Related OCS Facilities and Operations

Related OCS facilities and operations were discussed in depth in the Initial DOCD 

Control Plan No. N-9001. There will be no changes to the existing field development 

under this Revised Plan. 

(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 

Revised 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. 
BHP Billiton Petroleum (GOM) Inc. 23 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 

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

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

Helicopter 440 gals 1 As needed 

(b) Diesel Oil Supply Vessels

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

Revised 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. 
BHP Billiton Petroleum (GOM) Inc. 24 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

(d) Solid and Liquid Wastes Transportation

When necessary, BHPB will transport the following solid or liquid wastes from the MODU to permanent 

onshore facilities for disposal or recycling. 

Type of Waste / 

approximate 

composition

Total Amount Name/Location of 

Disposal Facility Rate Transport Method

Non-hazardous 

Trash and Debris 

Non-recyclables 

190 yd3 

River Birch Landfill, 

Avondale, LA via 

Galliano Waste 

Disposal, Galliano, LA 

2 yd3/ day 

Transport in bags and 

baskets on vessel to 

shore base – Picked up 

at shore base and 

trucked to private facility 

Non-hazardous 

recyclables & 

scrap metal 

37.5 tons 

ARC, New Iberia, LA ; 

approved scrap metal 

facility 

625 lbs / day 

Transport in bags and 

baskets on vessel to 

shorebase – Picked up 

at shorebase and 

trucked to private facility 

Chemical products 

and general 

hazardous waste 

3000 lbs 

L&L Oilfield Services 

in Fourchon, LA ; 

Safety-Kleen Systems, 

Inc. Transfer facility in 

Kenner, LA or Denton, 

TX 

35 lbs / day 

Transport in bags, drums 

and baskets on vessel to 

shore base – Picked up 

at shore base and 

trucked to private facility 

RCRA C-exempt 

E&P waste 

(drilling fluids, well 

treatment, 

workover, or 

completion fluids, 

produced water, 

produced sand, 

etc.) 

30,000 bbls / 

well 

Newpark 

Environmental 

Services Transfer 

facility in Fourchon, LA 

or U.S. Liquids of 

Louisiana transfer 

facility in Fourchon, LA 

NA 

Transport in drums or 

portable tanks on vessel 

to private facility or 

shorebase – Picked up 

at shore base and 

trucked to private facility 

Waste & Used Oil 480 bbls 

L&L Oilfield Services 

in Fourchon, LA ; 

Safety-Kleen Systems, 

Inc. Transfer facility in 

Kenner, LA or Denton, 

TX 

4 bbls / day 

Transport in drums on 

crew boat to shore base 

– Picked up at shore 

base and recycled or fuel 

blended 

(e) Vicinit y Map

A vicinity map showing the location of Green Canyon Block 653 relative to the shoreline and the onshore 

base located in Port Fourchon, Louisiana was previously submitted with the Initial Plan N-9001 and will 

not be affected by the operations proposed in this Revised Plan. 

Revised 03.11.2011 
BHP Billiton Petroleum (GOM) Inc. 25 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 

(b) 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. 

(c) 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. 

(d) Waste Disposal

Name / Location of 

Facility

Type of Waste Amount Rate Disposal Method

River Birch Landfill, 

Avondale, LA via Galliano 

Waste Disposal, Galliano, 

LA 

Non-hazardous 

Trash / Debris; nonrecyclables 

190 yd3 2 yd3/ day Landfill 

ARC, New Iberia, LA ; 

approved scrap metal facility 

Non-hazardous 

recyclables & scrap 

metal 

37.5 tons 625 lbs / day Recycle 

L&L Oilfield Services in 

Fourchon, LA ; Safety-Kleen 

Systems, Inc. Transfer facility 

in Kenner, LA or Denton, TX 

Chemical products 

and general 

hazardous waste 

3000 lbs 35 lbs / day Landfill, treatment, 

incineration or transfer 

Newpark Environmental 

Services Transfer facility 

in Fourchon, LA or U.S. 

Liquids of Louisiana 

transfer facility in 

Fourchon, LA 

RCRA C-exempt 

E&P waste (drilling 

fluids, well 

treatment, workover, 

or completion fluids, 

produced water, 

produced sand, etc.) 

30,000 bbls / 

well NA Transfer to approved injection facility 

L&L Oilfield Services in 

Fourchon, LA; SafetyKleen Systems, Inc. 

transfer facility in Kenner, 

LA 

Waste & Used Oil 480 bbls 4 bbls / day Transfer for recycle or 

fuel blending 

(e) Air Emissions

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

plans submitted in the BOEMRE GOMR. 

(f) 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 BOEMRE GOMR. 

Revised 03.11.2011 
BHP Billiton Petroleum (GOM) Inc. 26 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

SULPHUR OPERATIONS INFORMATION

BHPB is not proposing to conduct sulphur operations in this plan. 
BHP Billiton Petroleum (GOM) Inc. 27 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 

BOEMRE 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

A Coastal Zone Management Consistency Certification from the State of Louisiana is required 

for the development activities proposed in this Revised Plan.

(b) Other Information

State of Louisiana:

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

with. 

Revised 02.21.2011 
BHP Billiton Petroleum (GOM) Inc. 2D Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

Revised 02.21.2011 
BHP Billiton Petroleum (GOM) Inc. 28 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

ENVIRONMENTAL IMPACT ANALYSIS (EIA)

An Environmental Impact Analysis (EIA) was previously submitted with Initial DOCD (Control 

No. N-9001) and will not be affected by Revisions proposed in this Plan. 
BHP Billiton Petroleum (GOM) Inc. 29 Green Canyon Block 653 

Revision to Initial DOCD PUBLIC INFORMATION COPY Lease OCS-G 20084 

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 MMS-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 

Fugro GeoServices, Inc., Report No. 2405-2079 (SHE-FUG-05-GT-REP-0009), entitled 

Engineering-Geological Assessment - Shenzi Development, Green Canyon Area in the Gulf of 

Mexico
ATTACHMENT A 

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

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

OCS PLAN INFORMATION FORM 

General Information 

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

Company Name: BHP Billiton Petroleum (GOM) Inc. MMS Operator Number: 02010

Address: 

 

1360 Post Oak Blvd., Suite 150 

Houston, Texas 77056-3020

Contact Person: Susan Wilson

Phone Number: 713.599.6349

E-Mail Address: susan.wilson@bhpbilliton.com or Kathy.camp@kcampassociates.com

Lease(s): G20084 Area: Green Canyon Block(s): 653 Project Name (If Applicable): Shenzi

Objective(s): X Oil X Gas Sulphur Salt Onshore Base: Fourchon, LA Distance to Closest Land (Miles): 120 

Description of Proposed Activities (Mark all that apply) 

Exploration drilling X Development drilling 

X Well completion Installation of production platform 

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

Installation of caisson or platform as well protection 

structure Installation of satellite structure 

X Installation of subsea wellheads and/or manifolds X Commence production 

 Installation of lease term pipelines Other (Specify and describe) 

Have you submitted or do you plan to submit a Conservation Information Document to accompany this plan? 

PREVIOUSLY SUBMITTED Yes X No 

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

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

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

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

Tentative Schedule of Proposed Activities 

Proposed Activity Start Date End Date No. of Days 

Drill SB101 05/30/2011 07/21/2011 55 

Complete Well SB101 07/21/2011 08/20/2011 30 

 

Description of Drilling Rig Description of Production Platform 

Jackup X Drillship Caisson Tension leg platform 

Gorilla Jackup Platform rig Well protector Compliant tower 

Semisubmersible Submersible Fixed platform Guyed tower 

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

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

Description of Lease Term Pipelines 

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

 

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

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: Well SB101 Subsea Completion 

Anchor Radius (if applicable) in feet: NA X Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. OCS-G 20084 

Area Name Green Canyon 

Block No. 653 

Block line 

Departures 

(in feet)

N/S Departure: 7636.29’ FSL 

E/W Departure: 3491.55’ FEL 

Lambert X-Y 

coordinates 

X: 2,578,428.45 

Y: 9,923,476.29 

Latitude/ 

Longitude

Latitude: 27° 19’ 00.999” N 

Longitude: 90° 06’ 39.386” W 

TVD (Feet): MD (Feet): Water Depth (Feet): 4232 

Anchor Locations for Drilling Rig or Construction Barge 

Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

1 

2 

3 

4 

5 

6 

7 

8 

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35) requires us to inform you that MMS 

collects this information as part of an applicant’s Exploration Plan or Development Operations Coordination Document submitted for MMS approval. We 

use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act 

and 30 CFR 250.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a 

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

included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 

per response, or 640 with an accompanying EP (1,000 hours in AKOSCR), or 690 (1,700 in AKOCSR) with an accompanying DPP or DOCD, including 

the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments 

regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 5438, Minerals Management 

Service, 1849 C Street, N.W., Washington, DC 20240.

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

PUBLIC INFORMATION COPY 
Public Data
PUBLIC INFORMATION COPY
PUBLIC INFORMATION COPY
11/08/10 PUBLIC INFORMATION COPY 1 

BHP Billiton Petroleum (GOM) Inc. 

Green Canyon 654 Unit 

Block 653, Well No. SB101 

Lease OCS-G 20084 

NTL 2010-N06 Supplemental Data to Initial DOCD 

Control No. N-09001 

In accordance with NTL2010-N06 “Information Requirements for Exploration Plans, Development and 

Production Plans, and Development Operations Coordination Documents on the OCS”, BHP Billiton 

Petroleum Inc., herein referred to as “BHPB”, is submitting the following information as an addendum 

to the Initial DOCD approved by your office on September 21, 2007. 

Green Canyon Block 653, Well No. SB101 has not been drilled. BHPB is proposing to submit an APD 

via eWell on or before December 15, 2010. 

In support of this submittal the following information is included: 

• Blowout Scenario 

• Relief Well Data 

• Blowout Prevention and Intervention Data 

• Oil Spill Information 

• Plan Information Form 

• Location Plat 

• Worst Case Discharge 

BLOWOUT SCENARIO 

The Shenzi SB101 well will penetrate the objective, hydrocarbon-bearing sands with a 12-1/4” 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 BOP’s fail to function as designed and the marine riser then fails. The end result is an 

uncontrolled blowout at the sea floor. 

RELIEF WELL 

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 frac’ing / high rate pumping operations. There are several stimulation vessels in the 

GOM which could also be used for kill operations. 
11/08/10 PUBLIC INFORMATION COPY 2 

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 its current well and 

move to the Shenzi SB101 relief well location. Upon arrival at location, it would be expected to take 

approximately 70 days to drill the relief well and perform kill operations. 

Location & Strategy of Relief Well

As the Shenzi SB101 well is located 120 miles off the coast of Louisiana, a relief well from an 

onshore location is not an option. 

The Shenzi TLP is approximately 9,800ft away, too far to plan a relief well from. More importantly, 

the TLP has no rig package for performing drilling operations. 

BLOWOUT PREVENTION AND INTERVENTION 

Summary of Prevention Measures

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

Management System, including Well Control, Well Integrity [barrier analysis], and Well Design 

Standards, all of which have been updated to include the initial learnings from the Deepwater Horizon 

incident. 

BHPB has established procedures for performing drilling operations that are continually updated to 

maintain “fitness for purpose” and to ensure that each well is planned to prevent a well control event 

from occurring. 

BHPB employs an industry-leading expert to provide pre-spud 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 to address each of the risks identified. 

If, while drilling a well, circumstances change such that the original drilling program requires 

amendment, a Management of Change document is issued and, if necessary, a barrier analysis is 

conducted. The MoC form is signed off by management and issued to Drilling Supervisors for 

implementation. 

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

BHPB employs trained and experienced Drilling Supervisors. 

BHPB conducts periodic well control audits of its contracted drilling rigs, using both BHPB drilling 

management and independent third party (well examiner) auditors. 
11/08/10 PUBLIC INFORMATION COPY 3 

Reduce the Likelihood of a Blowout

Real time pressure and drilling data are monitored from the BHPB Houston office while drilling is 

ongoing. This includes using at a minimum 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 – and 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 will occur while displacing to a lighter mud weight. 

• All displacements to lighter fluids will be performed on a closed circulating 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 ram stacks configured 

to provide enhanced well control, 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, toolpushers, and BHPB Drilling 

Supervisors. 

Likelihood for Surface Intervention to Stop the Blowout

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

The 13-5/8” x 14” intermediate casing can withstand a full column of oil to the mudline. As a result, it 

would be possible to install a containment device (such as a capping stack), which would 

subsequently allow for the blowout to be 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. 

Plans for Effective and Early Intervention

Both rigs contracted by BHPB have “autoshear” and “deadman” features 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. 

Deployment of ROVs to close any open BOPs: 

• The ROV panel will be tested on surface and subsea with the BOP latched onto a wellhead. 

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

producing higher flow rates. Additionally, the receptacles on the BOP stack have been 

upgraded to decrease control line back pressure and allow for higher flow rates and reduced 

closing times. 

• BHPB has acquired dedicated subsea accumulator banks to be deployed to the seafloor to 

further improve the ROV closure response times. 
11/08/10 PUBLIC INFORMATION COPY 4 

BHPB would use an available containment system or would make plans to fabricate a capping stack if 

required to effectively shut off the flow of hydrocarbons. 

Relief Well Arrangements

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. 

The best possible surface locations for drilling a relief well have been reviewed by assessing the 

drilling hazards associated with the likely relief well locations. 

The well design of the relief well should reflect the original well, depending of course upon the cause 

of the blowout. 

Key Rig Specifications for Relief Well Drilling 

Rig Name DD1 C.R. Luigs 

Rig Type 5th Gen MODU rated for 7,500 ft water

depth (riser inventory-limited), 

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 2,000 kips 1,800 kips 

Drawworks Power 6,900 hp 5,000 hp 

Mud Pumps 4ea 14-P-220 NOV 2,200 hp pumps 

with 7,475 psi working pressure rating 

4ea 14-P-220 NOV 2,200 hp pumps 

with 7,475 psi working pressure rating 

Mud Pit Capacity 19,298 bbls (VDL-limited) 13,267 bbls 

Variable Loading Capacity 15,432 kips Drilling N/A (Drillship) 

Top Drive Hydralift HPS 1000 2E (AC) NOV TDS-1000 

Dry Bulk Storage Capacity 16,950 cu.ft. cement & 10,416 cu.ft. 

barite (VDL-limited) 

Total 27,000 cu.ft. 
11/08/10 PUBLIC INFORMATION COPY 5 

OIL SPILL INFORMATION 

Site-Specific OSRP

Lease OCS-G 20084 is not located in the Eastern Gulf of Mexico therefore a site-specific 

OSRP is not required. 

Regional or Subregional OSRP Information

BHP Billiton Petroleum (GOM) Inc. (Company No. 02010) is covered under BHP Billiton 

Petroleum (Americas) Inc. (Company No. 00362) Regional OSRP. All proposed activities and 

facilities in this Initial DOCD addendum will be covered by the Oil Spill Response Plan filed by 

BHP Billiton Petroleum (Americas) (Company No. 00362) in accordance with 30 CFR 254 and 

approved on August 31, 2009. The OSRP was most recently updated on April 5, 2010 by 

including changes to the Exploratory Worst Case Discharge.

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 

addendum is provided in the table below: 

Primary Response Equipment Location Preplanned Staging Location(s) 

Port Fourchon or Houma, LA Port Fourchon, LA 

OSRO Information

The activities proposed in this addendum are ten miles or more seaward from the coastline, 

therefore BHPB has referenced the “far-shore” worst case scenario in our approved regional 

OSRP. BHPB has determined that the worst-case discharge (WCD) proposed in this Plan 

Amendment does not supersede the worst-case discharge as approved in our Regional 

OSRP. 

The Worst Case Discharge Scenario for Well SB101 is summarized in the table below: 

Worst Case Scenario Determination

Category Regional OSRP NTL 2010-N06

Type of Activity Drilling Drilling 

Facility Location (area/block) GC 738 GC 653 

Facility Designation2 Well 001 Well SB101 

Distance to Nearest Shoreline (miles) 124 120 

Potential 24-hour volume in Bbls 184,000 131,116 

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

API Gravity(s)4 36.8° 32.1° 

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 Plan Amendment. 
11/08/10 PUBLIC INFORMATION COPY 6 

NTL 2010-N06 

WORST CASE DISCHARGE CALCULATION SUMMARY 

PROPRIETARY DATA

The calculated WCD volume for SB101 is 131,116 STB oil/day. The estimated cumulative discharge

volume after 30 days is 3.3 MMSTB oil. Table 1 shows the expected WCD rates at intervals from day

one (initial) out to 90 days.  

Please refer to BHPB’s detailed worst case discharge calculations and report attached (Document 

Control Number SHE-BHPB-06-RG-REP-0002-REV4). 
ATTACHMENT A 

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

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

OCS PLAN INFORMATION FORM 

General Information 

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

Company Name: BHP Billiton Petroleum (GOM) Inc. MMS Operator Number: 02010

Address: 

 

1360 Post Oak Blvd., Suite 150 

Houston, Texas 77056-3020

Contact Person: Susan Wilson

Phone Number: 713.599.6349

E-Mail Address: susan.wilson@bhpbilliton.com

Lease(s): 

 G20084 Area: Green Canyon Block(s): 653 Project Name (If Applicable): Shenzi

Objective(s): Oil Gas Sulphur Salt Onshore Base: Fourchon, LA Distance to Closest Land (Miles): 120 

Description of Proposed Activities (Mark all that apply) 

Exploration drilling Development drilling 

Well completion Installation of production platform 

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

Installation of caisson or platform as well protection 

structure Installation of satellite structure 

Installation of subsea wellheads and/or manifolds Commence production 

 Installation of lease term pipelines X Other (Specify and describe) NTL 2010 N06 DATA

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

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

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

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

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

Tentative Schedule of Proposed Activities 

Proposed Activity Start Date End Date No. of Days 

SUBMITTAL FOR NTL2010 N06 

 

Description of Drilling Rig Description of Production Platform 

Jackup Drillship Caisson Tension leg platform 

Gorilla Jackup Platform rig Well protector Compliant tower 

Semisubmersible Submersible Fixed platform Guyed tower 

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

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

Description of Lease Term Pipelines 

From (Facility/Area/Block) To (Facility/Area/Block) Diame ter (Inches) Length (Feet) 

 

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

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: Well SB101 Subsea Completion 

Anchor Radius (if applicable) in feet: NA X Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. OCS-G 20084 

Area Name Green Canyon 

Block No. 653 

Block line 

Departures 

(in feet)

N/S Departure: 7636.29’ FSL 

E/W Departure: 3491.55’ FEL 

Lambert X-Y 

coordinates 

X: 2,578,428.45 

Y: 9,923,476.29 

Latitude/ 

Longitude

Latitude: 27° 10’ 00.999” N 

Longitude: 90° 06’ 39.386” W 

TVD (Feet): MD (Feet): Water Depth (Feet): 4232 

Anchor Locations for Drilling Rig or Construction Barge 

Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

1 

2 

3 

4 

5 

6 

7 

8 

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35) requires us to inform you that MMS 

collects this information as part of an applicant’s Exploration Plan or Development Operations Coordination Document submitted for MMS approval. We 

use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act 

and 30 CFR 250.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a 

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

included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 

per response, or 640 with an accompanying EP (1,000 hours in AKOSCR), or 690 (1,700 in AKOCSR) with an accompanying DPP or DOCD, including 

the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments 

regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 5438, Minerals Management 

Service, 1849 C Street, N.W., Washington, DC 20240.

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

PUBLIC INFORMATION COPY 

Gulf o f Mexico Production Unit

NTL No. 2010‐N06 WORST CASE DISCHARGE

Shenzi SB101 Production Well

OCS‐G‐20084

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

01 10/21/2010 Initial Document JH DB

02 10/25/2010 Rev 2 JH DB

03 10/28/2010 Rev 3 JH DB

04 11/1/2010 Final Review JH DB

    

Next Review Date: Review Period:

DOCUMENT CONTROL NUMBER

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

SHE BHPB 06 RG REP 0002 04

PUBLIC INFORMATION COPY
DOCD AIR QUALITY SCREENING CHECKLIST B-DRILL CENTER-PLAN

OMB A

COMPAN

Y BHP Billiton Pet. (GOM) Inc.

ARE

A Green Canyon

BLOC

K 653

LEASE OCS-G 20084PLATFORM Shenzi TLPWELL SB101COMPANY CONTACT Susan Wilson / Joshua O'BrienTELEPHONE NO. 713 599 6349 / 713 599 613

2

REMARKS

rev. 0, 5/15/2007 (Initial) Installation of TLP and subsea flowline / usystem and commence productionrev. 1, 3/3/2009 (Supplement) Start-up Flaringrev. 2, 6/25/2010 (Revision) , Platform Flaring and Emission Factor rev. 3, 6/25/2010 (Supplemental) , Drilling Addendumrev. 3.2, 10/12/2010 (Plan-Supplemental) , W-Drill Center Addendurev. 3.3, 12/21/2010 (Plan-Supplemental) , B, C & G-Drill Centers Addendum

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

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

Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATE

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

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. gms/hp-hr 1 0.1835 14 1.12 3.03 AP42 3.3-1 10/96

Diesel Recip. < 600 hp.-EPA Tier 2 [2] gms/kW-hr 0.2 6.4 3.5 EPA Tier 2

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 [3] g/kW-hr 17.02 2.42 COMM Test Apr-10

Diesel Recip. > 600 hp.-IMO Tier 1 [4] g/kW-hr 9.8 IMO Tier 1

Diesel Recip. > 600 hp.-EPA Marine 

Tier 1 [5] g/kW-hr 45*(n)^(-0.2) EPA Marine Tier 1

Diesel Recip. > 600 hp.-DD1-Main [6] 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 AP-42 3.4-1 10/96

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

Duel Fuel (NG & Diesel) lb/MMBtu 0.0573 0.003048 2.7 0.02 1.16 122.6 AP-42 3.4-1 10/96

Duel Fuel (NG & Diesel) lb/hp-hr 0.0007 0.000023 0.018 0.00132 0.0075 AP-42 3.4-1 10/96

Diesel Boiler lbs/bbl 0.084 0.3025 0.84 0.008 0.21 AP-42 1.3-12,14 9/98

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel [7] 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.

[7] 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. 

[2] 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.

[3] 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. CRL's maximum output per main engine is 5875 hp/4184 kW with normal operation involves operating four (4) of eight (8) main engines. These calculations conservatively 

assume operating 7 of 8 engines as worst case. 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] Diesel Recip. > 600 hp.-IMO Tier 1: NOx emission factors for IMO Tier 1 diesel engines on certain wireline and cement unit engines.

[1] The calculated emission factors for CO2-e (CO2, CH4 and N2O) are based on 40 CFR 98, Tables C-1 & C-2.

[5] Diesel Recip. > 600 hp.-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

[6] Diesel Recip. > 600 hp.-DD1-Main: COMM Engineering testing of Transocean International's Development Driller 1 (DD-1) eight (8) main engines for NOx and CO was 

conducted May 2010. DD-1's maximum output per main engine is 4828 hp/3500 kW with normal operation involves operating four (4) of eight (8) main engines. These 

calculations conservatively assume operating 7 of 8 engines as worst case. The NOx & CO emission factors conservatively utilized the maximum NOx and CO emission rates o

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 2 of 8
B-DRILL CENTER-PLAN ANNUAL EMISSIONS CALCULATIONS YEARS 2011-2041

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE 

BHP Billiton Pet. (GOM) I Green Canyon 653 OCS-G 20084 Shenzi TLP SB101 Susan Wilson / Joshua O'Brien 713 599 6349 / 71

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR 

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 

DRILLING PRIME MOVER>600hp diesel [1] [2] [3] 47000 2270.10 54482.40 24 85 33.16 19.01 1315.12 34.19 

WORKOVER CRANES<600hp diesel [1] [4] [5] 610 54.65 1311.59 24 85 1.34 0.25 18.83 1.51 

RECOMPLETION Emergency Generator>600hp diesel [1] 2064 384.20 9220.90 24 85 1.46 0.83 50.05 1.50 

WIRELINE <600hp diesel-POSU-CA Primary Unit Engi 300 14.49 347.76 24 85 0.66 0.12 9.26 0.74 

WIRELINE <600hp diesel-Alt. #3 FMCC Type 1 [1] 300 14.49 347.76 24 85 0.66 0.12 9.26 0.74 

CEMENTING <600hp diesel (Nitrogen pump) [1] 490 23.67 568.01 24 85 1.08 0.20 15.12 1.21 CEMENTING >600hp diesel [1] [6] 860 41.54 996.91 24 85 0.61 0.35 13.86 0.63 CEMENTING >600hp diesel [1] [6] 860 41.54 996.91 24 85 0.61 0.35 13.86 0.63 VESSELS>600hp diesel(crew) (main-2) [1] [7] 4520 218.32 5239.58 24 85 3.19 1.83 74.68 3.29 

VESSELS<600hp diesel(crew) (gen.) [1] 165 7.97 191.27 24 85 0.36 0.07 5.09 0.41 

2 vessels VESSELS>600hp diesel(work) (main-2) [1] [7] 6598 318.68 7648.40 24 85 9.31 5.34 245.22 9.60 

VESSELS>600hp diesel(work) (gen.-2) [1] [7] 2500 120.75 2898.00 24 85 3.53 2.02 82.61 3.64 VESSELS>600hp diesel(work) (SDT) [1] [7] 1100 53.13 1275.12 24 85 1.55 0.89 36.35 1.60 VESSELS<600hp diesel(work) (E-Generator) [1] 251 12.11 290.69 24 85 0.55 0.10 7.74 0.62 

VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 

INSTALLATION INSTALLATION Vessel diesel [1] 45000 2173.5 52164.00 24 20 31.75 18.20 1091.29 32.74 

INSTALLATION Vessel diesel (E-Generator) [1] 1341 64.7703 1554.49 24 20 0.95 0.54 32.52 0.98 

SUPPORT VESSEL diesel [1] 12000 579.6 13910.40 24 20 8.47 4.85 291.01 8.73 

VESSELS>600hp diesel(crew) [1] 4685 226.2855 5430.85 24 20 3.31 1.90 113.62 3.41 

VESSELS>600hp diesel(supply) [1] 10449 504.6867 12112.48 24 20 7.37 4.23 253.40 7.60 

2011 YEAR TOTAL (ANNUAL) 109.90 61.20 3678.89 113.75 

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 

120

[6] Diesel Recip. > 600 hp.-IMO Tier 1: NOx emission factors for IMO Tier 1 diesel engines on certain wireline and cement unit engines.[1] FIELD INSTALLATION: Activities associated with these sources are not currently planned but are included as a contingency, per BOEM guidance, Tips to Avoid Common Emissions Spreadsheet Err

http://www.gomr.boemre.gov/homepg/regulate/environ/airquality/tips.html

[2] PRIME MOVER>600hp diesel: Based on TOI's CRL's maximum output per main engine is 5875 hp/4184 kW with normal operation involves operating four (4) of eight (8) main engines. These calculaassume 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 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 was conducted April 2010. The NOx emission factor was conservatively calculated at 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 2 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.)[7] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) maximum rpm is 1,800 pe(Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.

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

COMPANY AREA BLOCK LEASE PLATFORM WELL

BHP Billiton Pet.Green Canyon 653 OCS-G 20084 Shenzi TLP SB101

Emitted Substance

Year

 PM SOx NOx VOC CO

2011 71.67 39.24 2362.63 74.33 518.38

Allowable 3996.00 3996.00 3996.00 3996.00 82717.95

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

of 8
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 BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of 

Mexico available on the BOEM website. The results are shown in Figure 1. The BOEM OSRAM 

identifies a 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 (Americas) Inc. will make every effort to respond to the Worst Case 

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

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

Using the estimated chemical and physical characteristics of crude oil, an ADIOS weathering model 

was run on a similar product from the ADIOS oil database. The results indicate 14% or 18,356 

barrels of crude oil would be evaporated/dispersed within 24 hours, with 112,760 barrels remaining. 

Spill Response GC 653 Barrels of Oil 

WCD Volume 131,116 

Less 14% natural evaporation/dispersion 18,356 

Remaining volume 112,760 

Oil addressed by aerial dispersants 7,540 

Oil addressed by in-situ burning 6,555 

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

equipment available to respond to a spill of 131,116 barrels. The list estimates individual times 

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

how operations will be supported. 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
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 should disperse approximately 7,540 barrels of product. If the 

conditions are favorable for in-situ burning, the proper approvals have been obtained and the proper 

planning is in place, in-situ burning of oil may be attempted. Using estimates based on the 

Deepwater Horizon spill of 2010, up to 5% or 6,555 barrels of the total daily Worst Case Discharge 

volume could be burned. 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 and five sets of Koseq skimming arms, with a total derated 

skimming capacity of 173,207 barrels. Temporary storage associated with skimming equipment 

equals 15,700 barrels. If additional temporary storage is needed, one 20,000 barrel storage barges, 

three 23,000 barrel storage barges, one 25,000 barrel storage barge, 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. 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 impacts in either Cameron Parish 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 33,253 barrels. Temporary storage associated with skimming equipment equals 1,512 barrels. If 

additional storage is needed, two 20,000 barrel storage barges may be mobilized and centrally 

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

much as possible. 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 170,000 feet of 18” shoreline protection boom. Figure 2 outlines estimated 

times needed for procurement, load out, travel time to the site and deployment. Strategies would be 

based upon surveillance and real time trajectories that depict areas of potential impact given actual 

sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan for Cameron 

Parish and/or Plaquemines Parish and Unified Command would be consulted to ensure that 

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

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

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

detailed shoreline protection strategies for this area, and it describes necessary action to keep the oil 

spill from entering Louisiana’s coastal wetlands, based on the assumption that removal of the 

released oil will be much easier and less damaging to fragile coastal ecosystems if done in the open 

waters of the Gulf of Mexico. Supervisory personnel have the option to modify the deployment and 

operation of equipment allowing a more effective response to site-specific circumstances. BHP 

Billiton Petroleum (Americas) Inc.’s contract Spill Management Team holds a copy of the State of 

Louisiana Initial Oil Spill Response Plan. 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
Tactics 

Initial Response Considerations 

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

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 (Americas) 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. 

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 completed 

• Initial Safety plan will be written and published 

• Unified Command will be established 

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

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

o On-site command and control established 

Decanting Strategy 

Recovered oil and water mixtures will typically separate into distinct phases when left in a quiescent state. 

When separation occurs, the relatively clean water phase can be siphoned or decanted back to the 

recovery point with minimal, if any, impact. Decanting therefore increases the effective on-site oil storage 

capacity and equipment operating time. FOSC/SOSC approval will be requested prior to decanting 

operations. This practice is routinely used for oil spill recovery. 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
Offshore Response Actions 

Equipment Deployment

Surveillance 

• Surveillance Aircraft: within two hours of 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 ASI on standby 

• With the FOSC, conduct analysis to determine appropriateness of dispersant application (refer to 

Section 18) 

• 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 to Corpus 

Christi 

• Confirm dispersant availability for current and long range operations 

• Start ordering dispersant stocks required for expected operations 

Containment boom 

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

• Ensure boom handling and mooring equipment is deployed with boom 

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

most effective containment 

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

Dedicated off-shore skimming systems 

General 

• Deployed to the highest concentration of oil 

• Assets deployed at safe distance from aerial dispersant and in-situ burn operations 

CGA HOSS Barge 

• Use in areas with heaviest oil concentrations 

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

CGA FRUs 

• To the area of the thickest oil 

• Use as far off-shore as allowed 

T&T Koseq Skimming Systems 

• To the area of the thickest oil 

• Use as far off-shore as allowed 

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

Storage Vessels 

• Establish availability of CGA contracted assets (See Appendix E) 

• 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 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
Vessels of Opportunity (VOO) 

• Use BHP Billiton Petroleum (Americas) 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 

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 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
Near Shore Response Actions 

Timing 

• Put near shore assets on standby and deployment 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 

• FRVs 

• Egmopol and Marco SWS 

• Operate with aerial spotter directing systems to observed oil slicks 

VOO 

• Use BHP Billiton Petroleum (Americas) Inc.’s contracted resources as applicable 

• Industry vessel 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 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
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 (March 2011) 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 time 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 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 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
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 (Americas) Inc.’s WCD and information in the BOEM Oil Spill Risk Analysis 

Model (OSRAM) for the Central and Western Gulf of Mexico available on the BOEM website using 

30 day impact. The results are tabulated below. 

Area/Block OCS-G Launch 

Area 

Land Segment and/or 

Resource 

Conditional 

Probability (%) within 

30 days 

Green Canyon 653 

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 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (120 miles from shore) 

131,116 bbls of crude oil API Gravity 32.1° 

FIGURE 2 – Equipment Response Time to Green Canyon 653 

Dispersants/Surveillance 

Dispersant/Surveillance Dispersant Capacity (gal) Storage Capacity Persons Req. From Hrs to Procure Hrs to Loadout Trave

site 

CGA 

Basler 67T 2000 NA 2 Houma 1 1 0.8 

ASI 

DC 3 1200 NA 2 Houma 1 1 1.1 DC 3 1200 NA 2 Houma 1 1 1.1 Aero Commander NA NA 2 Houma 1 1 0.8 

Offshore Response 

Offshore Equipment No 

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

S

CGA 

HOSS Barge 43000 4000 3 Tugs 8 Houma 4 0 5 

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 2603 NA 25000 1 Tug 6 Amelia 4 0 4 CTCo 2604 NA 20000 1 Tug 6 Amelia 4 0 4 CTCo 2607 NA 23000 1 Tug 6 Amelia 4 0 4 CTCo 2608 NA 23000 1 Tug 6 Amelia 4 0 4 CTCo 2609 NA 23000 1 Tug 6 Amelia 4 0 4 CTCo 5001 NA 47000 1 Tug 6 Amelia 4 0 4 
Offshore Equipment With 

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

Staging Area: Fourchon

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 4 12 0 

CGA 

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 7 FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 1 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 9.5 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 4 42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 7 42” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 2 1 42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 9.5 42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 4 Staging Area: Leeville 

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 4 12 0 Staging Area: Venice 

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Venice 4 12 0 

CGA 

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2 FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6 Venice 1 2 0 42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 1000’ Hydro-Fire Boom (In-Situ Burn Boom) NA NA 8 Utility 40 Belle Chasse 1 4 2 
Nearshore Response 

Nearshore and Inland 

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

Dep

CGA 

Staging Area: Fourchon SWS Egmopol 3000 100 NA 3 Galveston 1 2 7 SWS Egmopol 3000 100 NA 3 Houma 1 2 1 SWS Marco 3588 34 NA 3 Houma 1 2 1 SWS Marco 3588 20 NA 3 Lake Charles 1 2 4 RO Storage Barge NA 249 Towed 0 Galveston 1 2 7 RO Storage Barge NA 249 Towed 0 Houma 1 2 1 RO Storage Barge NA 249 Towed 0 Lake Charles 1 2 4 Staging Area: Venice Rope Mop 77 2 0 3 Belle Chasse 1 2 2 RO Storage Barge NA 249 Towed 0 Venice 1 2 0 

Nearshore Equipment 

No Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM Tra

Sp

CGA 

46’ FRV 5000 65 NA 4 Houma 1 0 2 46’ FRV 5000 65 NA 4 Venice 1 0 1 46’ FRV 5000 65 NA 4 Lake Charles 1 0 1 46’ FRV 5000 65 NA 4 Galveston 1 0 1 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2605 NA 20000 1 Tug 6 Amelia 4 0 4 CTCo 2606 NA 20000 1 Tug 6 Amelia 4 0 4 
Shoreline Protection 

Shoreline 

Protection Boom VOO Persons Req. Storage/Warehouse Location Hrs to Procure Hrs to Load Out Travel to Staging Travel to Deployment 

ES&H 

Staging Area: Cameron 

50,000’ 18” Shoreline Boom 9 Crew 15 Lake Charles, LA .5 .5 1 2 

Staging Area: Fourchon 

50,000’ 18” Shoreline Boom 30 Crew 15 Houma, LA .5 .5 1 2 50,000’ 18” Shoreline Boom 8 Crew 15 Houston, TX .5 .5 7 2 20,000’ 18” Shoreline Boom 3 Crew 10 Belle Chasse, LA .5 .5 2.5 2 

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

Dep

CGA 

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 7 Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 9.5 Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 

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

Dep

CGA 

Wildlife Support Trailer NA NA NA 2 Houma 1 2 1 Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 2.5 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 7 Bird Scare Guns (24) NA NA NA 2 Houma 1 2 1 Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 9.5 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 4 Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 
Response Asset Total Response Asset Total 

Offshore EDRC 173,207 Nearshore / Shallow Water EDRC 33,253 

Offshore Recovered Oil 

Capacity 176,700 

Nearshore / Shallow 

Water Recovered Oil 

Capacity 

41,512