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-05 124

Type - Revised Development Plan

Lease(s) - OCS-G2 0084 Block - 653 Green Canyon Area

Operator - BHP Billiton Petroleum (GOM) Inc.

S henzi SB101 well

D RILLSHIP

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 Fl uids

............................................................................................................................... ........................ 4

Peak Production Rates / Lif e 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 Sce n ario

............................................................................................................................... ................ 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 Hazar ds Assessment

......................................................................................................... 7

High Resoluti on Seismi c 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, PHYSICA L AN D SOCIOECO NOMIC 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

Threate n ed and Endanger ed 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

Screeni ng 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 Syst e m s

......................................................................................................................................... 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 INFO RMATION

........................................................................................................... 21

RELATED FAC ILITIES 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 Tr ansportation

........................................................................................................... 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 NEPABHP 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 Operati ons 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 Envir onmental Management Systems (SEMS)

These regulations may be further clarified by Sa fety Alerts, and current policy making invoked by the Bureau of Ocean Energy Managemen t, 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 29-39 o



### (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 per sonnel 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 05.04.2011BHP 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 03.11.2011BHP 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 submi tted and will not be affected by this revision.



### (f) Site Specific Shallow Hazards Assessment

A Site Specific Shallow Hazards Assessment wa s previously submitted and will not be affected by this revision.



### (g) High Resolution Seismic Lines

3-D survey information was utilized and previous ly 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 H 2 

### S while conducting our proposed development

activities.



### (b) Classification Request

Based on previous drilling, no H 2 

### S 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 H 2 

### S has been confirmed”.



### (c) Contingency Plan

BHPB does not anticipate encountering H 2 

### S while conducting our proposed development activities therefore a contingency plan is not required at this time.



### (d) Modeling Report

BHPB does not anticipate encountering H 2 

### S 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 CO NVERSATION INFORMATION

(a) Technology and Reservoir Engi neering Practices and Procedures

PROPRIETARY DATA



### (b) Technology and Recovery Practices and Procedures

PROPRIETARY DATA



### (c) Reservoir Development

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

Revision to Initial DOCD 

### PUBLIC INFORMATION COPY Lease OCS-G 20084 

## BIOLOGICAL, PHYSICAL AND SO CIOECONOMIC INFORMATION

(a) Chemosynthetic Communities Report

NTL 2009-G40, effective January 27, 2009, broadened the scope of a chemosyntheticcommunities 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 Sensit ive Biological Features

BHPB does not propose bottom-disturbing activities within 61 meters (200 feet) of potentially sensitive biological features; therefore the m ap 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 report ing 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 a nd 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 G reen 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 16 66 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 – 2 0 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

Uncontamin ated fresh or seawater NA NA

Desalinization unit water Desalinization unit water 12 0 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

Tr ash and debris ; non

- recyclables Refuse generated by personnel on board

MODU 2 yd 3 / day

Non

- hazardous recyclables & s crap metal Non

- haz ardous recyclables & scrap met al 625 lbs / day
Chemical products and general hazardous

waste Paint waste, chemicals, so lvents, 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 o f Waste Amount to be Discharged Discharge Rate Discharge Method

Drill cuttings associated with water

based fluids 1666 bbls 400 bbls/hr Overboard

Drill cuttings associated with synthetic drilling fluids 4891 bbls NA Overboard

Mud / cuttings Gel

- NA

W BM

– 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

Uncontam inated fresh or seawater NA NA NA

Desalinization unit water 12 0 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 03.11.2011BHP 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 leve ls 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 acti vities more than 90% of the amounts calculated using the following formulas: CT = 3400D 2/3 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 asso ciated with your proposed development and production activities process production from eight or more wells? X

Do you expect to encounter H 2 S 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 03.11.2011BHP 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. (C ompany 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 Billit on 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 tempor ary 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 03.11.2011BHP 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 Activity 1 Drilling Drilling

Facility Location (area/block) GC 738 GC 653

Facility Designation 2 Well 001 Well SB101

Distance to Nearest Shoreline (statute miles) 124 120

Volume 3

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

Type of Oil(s) (crude oil, co ndensate, 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 scen ario volume from the appropriate section of your regional OSRP. For EP’s, the wors t-case scenario volume is the daily volume possible from an uncontrolled blowout. Determine this volume using the provisions of 30 CFR 30 CFR 2 54.47(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 appropr iate. 4. Provide API gravity of all oils given unde r “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 subs tance 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 03.11.2011BHP 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 pl ans 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 t he existing field infrastructure under this

Revised Plan.



### (c) Produced Liquid Hydrocar bons 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 vess el(s) to supply diesel oil to s upport 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; t herefore 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 transpor t the following solid or liquid wast es 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 previo usly submitted with the Initial Plan N-9001 and will not be affected by the operations proposed in this Revised Plan.

Revised 03.11.2011BHP 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 immedi ate 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 immedi ate measures for land acquisition or expansion of the existing onshore base facilities t herefore 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-hazardousTrash / 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 inFourchon, 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 ge nerated by onshore support facilitie s 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 03.11.2011BHP 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). A pplicants for an OCS plan submitted to the BOEMRE must provide a certification with nece ssary 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 02.21.2011BHP Billiton Petroleum (GOM) Inc. 2 D Green Canyon Block 653

Revision to Initial DOCD 

### PUBLIC INFORMATION COPY Lease OCS-G 20084

Revised 02.21.2011BHP 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 pr eviously 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 Descripti on (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 Info rmation, 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 tec hnology to conduct your activities? Yes X No

Do you propose any facility that will serve as a host fac ility 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 re viewed 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/Bl ock) 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 COPYOCS 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. Chapt er 35) requires us to inform you that MMS collects this information as part of an applicant’s Exploration Pl an or Development Operations Co ordination Document submitted for MMS approval. We use the information to facilitate our review and data entry for OC S plans. We will protect proprietary data according to the F reedom of Information Act and 30 CFR 250.197. An agency may not conduct or sponsor, and a per son is not required to respond to, a collection of informat ion unless it displays a currently valid Office of Management and Budget Control Number. T he use of this form is voluntary. The public reporting burde n for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that bur den 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 sub part 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

### 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 5 th 

### 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 issu ed 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 per formed 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 Dr iller-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 5 th 

### 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 fo r Relief Well Drilling

Rig Name DD1 C.R. Luigs

Rig Type 5th Gen MODU rated for 7,500 ft wate r 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 Designation 2 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, co ndensate, 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 Cons ervation Information Document to accompany this plan? Yes X No

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

Do you propose any facility that will serve as a hos t 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 ac tivities been previously review ed 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/Bl ock) 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 COPYOCS 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. Chapt er 35) requires us to inform you that MMS collects this information as part of an applicant’s Exploration Pl an or Development Operations Co ordination Document submitted for MMS approval. We use the information to facilitate our review and data entry for OC S plans. We will protect proprietary data according to the F reedom of Information Act and 30 CFR 250.197. An agency may not conduct or sponsor, and a per son is not required to respond to, a collection of informat ion unless it displays a currently valid Office of Management and Budget Control Number. T he use of this form is voluntary. The public reporting burde n for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that bur den 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 sub part 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 04DOCD AIR QUALITY SCREENING CHECKLIST B-DRILL CENTER-PLANOMB Control No. 1010-0151OMB Approval Expires: 12/31/2011COMPANYBHP Billiton Pet. (GOM) Inc.AREAGreen CanyonBLOCK653LEASEOCS-G 20084PLATFORMShenzi TLPWELLSB101COMPANY CONTACTSusan Wilson / Joshua O'BrienTELEPHONE NO.713 599 6349 / 713 599 6132REMARKSrev. 0, 5/15/2007 (Initial) Installation of TLP and subsea flowline / umbilicalsystem and commence productionrev. 1, 3/3/2009 (Supplement) Start-up Flaringrev. 2, 6/25/2010 (Revision) , Platform Flaring and Emission Factor Updaterev. 3, 6/25/2010 (Supplemental) , Drilling Addendumrev. 3.2, 10/12/2010 (Plan-Supplemental) , W-Drill Center Addendumrev. 3.3, 12/21/2010 (Plan-Supplemental) , B, C & G-Drill CentersAddendumLEASE TERM PIPELINE CONSTRUCTION INFORMATION:YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYSPIPELINESMMSFORM MMS-139(December 2008 - Supersedes all previous versions of form MMS-139 which may not be used).Page 1 of 8EMISSIONS 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 % weigh t

The followin g e q uations were used in formulatin g the conversion factors used in the a pp lication p acka ge kW: h p = ( kW ) x ( 1.341 h p /kW ) . Factor = 1.341 h p /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 r p m is 1

, 800 p er main en g ine. Vessel ( Work ) main en g ines maximum r p m are 1000 r p m

, and g enerators and SDT are 1800 r pm [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 conservativel y assume o p eratin g 7 of 8 en g ines as worst case. The NOx & CO emission factors conservativel y 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 8B-DRILL CENTER-PLAN ANNUAL EMISSIONS CALCULATIONS YEARS 2011-2041COMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONEREMARKSBHP Billiton Pet. (GOM) I Green Canyon653 OCS-G 20084 Shenzi TLP SB101Susan Wilson / Joshua O'Brien 713 599 6349 / 713 599 6132rev. 0, 5/15/2007 (Initial) Installation of TLP and subseaflowline / umbilical system and commence productionrev. 1OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO CO2 PM SOx NOx VOC CO CO2DRILLINGPRIME MOVER>600hpdiesel[1] [2] [3]47000 2270.10 54482.40 24 85 33.16 19.01 1315.12 34.19 250.76 53852.18 33.82 19.39 1341.42 34.88 255.77 54929.23WORKOVERCRANES<600hpdiesel[1] [4] [5]610 54.65 1311.59 24 85 1.34 0.25 18.83 1.51 4.07 1296.42 1.37 0.25 19.20 1.54 4.16 1322.35RECOMPLETIONEmergencyGenerator>600hpdiesel[1]2064 384.20 9220.90 24 85 1.46 0.83 50.05 1.50 10.92 9114.24 1.49 0.85 51.06 1.53 11.14 9296.52WIRELINE <600hpdiesel-POSU-CA PrimaryUnit Engi300 14.49 347.76 24 85 0.66 0.12 9.26 0.74 2.00 343.74 0.67 0.12 9.44 0.76 2.04 350.61WIRELINE <600hpdiesel-Alt. #3 FMCC Type 1[1]300 14.49 347.76 24 85 0.66 0.12 9.26 0.74 2.00 343.74 0.67 0.12 9.44 0.76 2.04 350.61CEMENTING <600hpdiesel(Nitrogenpump)[1]490 23.67 568.01 24 85 1.08 0.20 15.12 1.21 3.27 561.44 1.10 0.20 15.43 1.23 3.34 572.67CEMENTING >600hpdiesel[1] [6]860 41.54 996.91 24 85 0.61 0.35 13.86 0.63 4.55 985.38 0.62 0.35 14.13 0.64 4.64 1005.09CEMENTING >600hpdiesel[1] [6]860 41.54 996.91 24 85 0.61 0.35 13.86 0.63 4.55 985.38 0.62 0.35 14.13 0.64 4.64 1005.09VESSELS>600hpdiesel(crew)(main-2)[1] [7]4520 218.32 5239.58 24 85 3.19 1.83 74.68 3.29 23.92 5178.98 3.25 1.87 76.17 3.35 24.39 5282.56VESSELS<600hpdiesel(crew)(gen.)[1]165 7.97 191.27 24 85 0.36 0.07 5.09 0.41 1.10 189.06 0.37 0.07 5.19 0.42 1.12 192.842 vesselsVESSELS>600hpdiesel(work)(main-2)[1] [7]6598 318.68 7648.40 24 85 9.31 5.34 245.22 9.60 69.82 15119.86 9.50 5.45 250.13 9.79 71.22 15422.26VESSELS>600hp diesel(work) (gen.-2)[1] [7]2500 120.75 2898.00 24 85 3.53 2.02 82.61 3.64 26.46 5728.96 3.60 2.06 84.26 3.71 26.98 5843.53VESSELS>600hpdiesel(work)(SDT)[1] [7]1100 53.13 1275.12 24 85 1.55 0.89 36.35 1.60 11.64 2520.74 1.58 0.91 37.08 1.63 11.87 2571.16VESSELS<600hpdiesel(work)(E-Generator)[1]251 12.11 290.69 24 85 0.55 0.10 7.74 0.62 1.68 287.33 0.56 0.10 7.89 0.63 1.71 293.07VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATIONINSTALLATION Vessel diesel[1]45000 2173.5 52164.00 24 20 31.75 18.20 1091.29 32.74 238.10 51560.60 7.62 4.37 261.91 7.86 57.14 12374.54INSTALLATION Vessel diesel(E-Generator)[1]1341 64.7703 1554.49 24 20 0.95 0.54 32.52 0.98 7.10 1536.51 0.23 0.13 7.80 0.23 1.70 368.76SUPPORT VESSEL diesel[1]12000 579.6 13910.40 24 20 8.47 4.85 291.01 8.73 63.49 13749.49 2.03 1.17 69.84 2.10 15.24 3299.88VESSELS>600hpdiesel(crew)[1]4685 226.2855 5430.85 24 20 3.31 1.90 113.62 3.41 24.79 5368.03 0.79 0.45 27.27 0.82 5.95 1288.33VESSELS>600hpdiesel(supply)[1]10449 504.6867 12112.48 24 20 7.37 4.23 253.40 7.60 55.29 11972.37 1.77 1.01 60.82 1.82 13.27 2873.372011 YEAR TOTAL (ANNUAL)109.90 61.20 3678.89 113.75 805.51 180694.43 71.67 39.24 2362.63 74.33 518.38 118642.46EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES3996.00 3996.00 3996.00 3996.00 82717.95120[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 Errors, #8,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 calculations conservativelyassume operating 8 of 8 engines.[3] PRIME MOVER>600hp diesel: Based on TOI's CRL. For all pollutants except NOx and CO, the maximum hourly emissions (lbs/hr) are calculated based on the appropriate AP-42 and EPA emission factor and the totalengine rating of 5875 HP (mechanical), as the AP-42 and EPA emission factors are based on brake HP. COMM Engineering testing of Transocean International's (TOI) C.R. Luigs' (CRL) eight (8) main engines for NOx and COwas 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 per main engine. Vessel(Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm.MMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 3 of 8SUMMARY

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 Managem ent Act analysis, the largest spill volume originating from the proposed acti vity would be a well blowout during drilling operations , estimated to be 131,116 barrels of crude oil wi th 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 Lak e, 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 bird s, finfish and other animals, including several rare, threatened and endangered species. Plaquemines Pa rish includes Barataria Bay, the Mississippi River Delta, Breton Sound and the affiliated islands and bays. Th is region is an extremely sensitive habitat and serves as a migratory, breeding, feedi ng and nursery habitat for numerous species of wildlife. Beaches in this area vary in grain part icle size and can be classified as fine sand, shell or perched shell beaches. Sandy and mu ddy 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 descripti on of the response equipment available to contain and recover the Worst Case Discharge is shown in Figure 2

.

Using the estimated chem ical and physical characteristics of crude oil, an ADIOS weathering model was run on a similar product from the ADIOS o il 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, ma terials 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.

### 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 disp erse approximately 7,540 barre ls of product. If the conditions are favorable for in-situ burning, the proper approval s 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 immedi ately called out and on-scene as soon as possible. Offshor e response strategies may include a ttempting to skim utilizing the HOSS Barge, nine Fast Response Units and five sets of Koseq skimming arms, with a total derated skimming capacity of 17 3,207 barrels. Temporary storage associated with skimming equipment equals 15,700 barrels. If additional temporary st orage is needed, one 20,000 barrel storage barges, three 23,000 barrel storage barges, one 25,000 ba rrel storage barge, and one 47,000 barrel storage barge may be mobilized and centrally located to provide temporary storage a llowing the skimmers to stay in the area of operati ons 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, shoreli ne impacts in either Cameron Parish and/or Plaquemines Parish, Louisiana would depend upon existing environmenta l 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 ma y 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 inclu de the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated ar eas. 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 t hat depict areas of potent ial 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 consul ted to ensure that environmental and special economic resources would be correctly identified and prioritized to ensure optimal protection. Shoreline pr otection strategies depict the pr otection response modes applicable for oil spill clean-up operations. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection strategi es 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 person nel have the option to modify the deployment and operation of equipment allowing a more effective response to site-specif ic circumstances. BHP Billiton Petroleum (Americas) Inc.’s contract Sp ill Management Team holds a copy of the State of Louisiana Initial Oil Spill Response Plan.

### Tactics

Initial Response Considerations Actual actions taken during an oil spill response will be based on many factor s 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 res ponse 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 pr ovide an “in-depth” protection strategy meant to recover as much oil as possible as far from environm entally 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 wate r phase can be siphoned or decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill recovery.Offshore Response Actions

Equipment Deployment

Surveillance

• Surveillance Aircraft: 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, airc raft, and support equipment and personnel to Corpus

Christi

• Confirm dispersant availability for current and long range operations

• Start ordering dispersant stoc ks 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 timeVessels of Opportunity (VOO)

• Use BHP Billiton Petroleum (A mericas) Inc.’s contracted re sources 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 planNear Shore Response Actions

Timing

• Put near shore assets on standby and deploym ent 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 (A mericas) Inc.’s contracted re sources 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 patchesShoreline 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 Stat e 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 weathe r 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 movem ent for resource redeployment as necessary

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

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

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

areas

### FIGURE 1

TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it im pacting a land segment have been projected utilizing BHP Billiton Petroleum (Americas) In c.’s WCD and information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BOEM website using 30 day impact. The results are tabulated below.

Area/Block OCS-G Launch

Area Land Segment and/or

Resource Conditional Probability (%) within 30 days

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

3WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(120 miles from shore)131,116 bbls of crude oilAPI Gravity 32.1°FIGURE 2 – Equipment Response Time to Green Canyon 653Dispersants/SurveillanceDispersant/SurveillanceDispersantCapacity (gal)StorageCapacityPersonsReq.FromHrs toProcureHrs toLoadoutTravel tositeTotal HrsCGABasler 67T2000NA2 Houma 11 0.82.8ASIDC 31200NA2 Houma 11 1.13.1DC 31200NA2 Houma 11 1.13.1Aero CommanderNANA2 Houma 11 0.82.8Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge43000 4000 3 Tugs 8Houma 4 0 5 15.3 1 25.3Recovered Oil StorageNo StagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsEnterprise Marine Services LLC (available through contract with CGA)CTCo 2603NA 25000 1 Tug 6Amelia4 0 4 20 1 29CTCo 2604NA 20000 1 Tug 6Amelia4 0 4 20 1 29CTCo 2607NA 23000 1 Tug 6Amelia4 0 4 20 1 29CTCo 2608NA 23000 1 Tug 6Amelia4 0 4 20 1 29CTCo 2609NA 23000 1 Tug 6Amelia4 0 4 20 1 29CTCo 5001NA 47000 1 Tug 6Amelia4 0 4 20 1 29Offshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoad OutTravel toStagingTravelto SiteHrs toDeployTotalHrsStaging Area: FourchonT&T Marine (available through contract with CGA)Koseq Skimming Arms (1) 17829 2000 1Utility 6 Fourchon4 12 0 10.4 1 27.4CGAFRU (1) + 100 bbl Tank (2) 3770 200 1Utility 6 Galveston1 2 7 10.4 1 21.4FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6Houma 1 21 10.4 1 15.4FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 9.5 10.4 1 23.9FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 4 10.4 1 18.442” Auto Boom (5000’) NA NA 10Crew 20 Galveston 1 2 7 10.4 1 21.442” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 21 10.4 1 15.442” Auto Boom (2500’) NA NA 6Crew 12 Ingleside 1 2 9.5 10.4 1 23.942” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 4 10.4 1 18.4Staging Area: LeevilleT&T Marine (available through contract with CGA)Koseq Skimming Arms (3) 53487 60003 Utility 18 Leeville 4 12 0 11.4 1 28.4Staging Area: VeniceT&T Marine (available through contract with CGA)Koseq Skimming Arms (1) 17829 2000 1Utility 6 Venice 4 12 0 9.8 1 26.8CGAFRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2 9.8 1 15.8FRU (2) + 100 bbl Tank (4) 7540 400 1Utility 6 Venice 1 2 0 9.8 1 13.842” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 9.8 1 15.842” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 24 9.8 1 17.81000’ Hydro-Fire Boom(In-Situ Burn Boom)NA NA 8 Utility 40 Belle Chasse 1 4 2 9.8 6 22.8Nearshore ResponseNearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoad OutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGAStaging Area: FourchonSWS Egmopol3000 100 NA 3 Galveston 1 2720 12SWS Egmopol3000 100 NA 3Houma 1 2120 6SWS Marco3588 34 NA 3Houma 1 2120 6SWS Marco3588 20 NA 3 Lake Charles 1 2420 9RO Storage BargeNA 249 Towed 0 Galveston 1 2 7 2 0 12RO Storage BargeNA 249 Towed 0Houma 1 2120 6RO Storage BargeNA 249 Towed 0 Lake Charles 1 2420 9Staging Area: VeniceRope Mop77 2 0 3 Belle Chasse 1 2220 7RO Storage BargeNA 249 Towed 0Venice1 2020 5Nearshore EquipmentNo StagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGA46’ FRV5000 65 NA 4Houma 1 0 2 3.6 0 6.646’ FRV5000 65 NA 4Venice 1 0 12 0 446’ FRV5000 65 NA 4 Lake Charles 1 0 1 9.6 0 11.646’ FRV5000 65 NA 4 Galveston 1 0 1 13.2 0 14.2Enterprise Marine Services LLC (available through contract with CGA)CTCo 2605NA 20000 1 Tug 6Amelia 4 0 420 1 29CTCo 2606NA 20000 1 Tug 6Amelia 4 0 420 1 29Shoreline ProtectionShorelineProtection BoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoad OutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsES&HStaging Area: Cameron50,000’ 18” Shoreline Boom 9 Crew 15 Lake Charles, LA .5 .5121519Staging Area: Fourchon50,000’ 18” Shoreline Boom 30 Crew 15Houma, LA.5 .512151950,000’ 18” Shoreline Boom 8 Crew 15 Houston, TX.5 .572152520,000’ 18” Shoreline Boom 3 Crew 10 Belle Chasse, LA .5 .5 2.52611.5Beach Boom EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoad OutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGABeach Boom (2000’)NA NA NA 6 Galveston 1 2712 13Beach Boom (1000’)NA NA NA4 Ingleside 1 2 9.5 1 2 15.5Beach Boom (2000’)NA NA NA 6 Pascagoula 1 2412 10Wildlife Response EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoad OutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGAWildlife Support Trailer NA NA NA 2Houma 1 2112 7Bird Scare Guns (24) NA NA NA2 Belle Chasse 1 2 2.5 1 2 8.5Bird Scare Guns (12) NA NA NA 2 Galveston 1 2712 13Bird Scare Guns (24) NA NA NA 2Houma 1 2112 7Bird Scare Guns (12) NA NANA 2 Ingleside 1 2 9.5 1 2 15.5Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2412 10Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2412 10Response AssetTotalResponse Asset TotalOffshore EDRC173,207Nearshore / ShallowWater EDRC33,253Offshore Recovered OilCapacity176,700Nearshore / ShallowWater Recovered OilCapacity41,512