### Miller. Karen

From : Sent:

To: Subject: Za in e y, Rober t

F ri day

, April 0 1

, 201 1 11 : 58 AM

M ill er

, Ka r en

N9510

, OCS

- G16 7 86

From: Peuler

, E li zabe th

Sent: Friday, April 01

, 2011 11:55 AM

To: Wilson, Susan

Cc : Webb, James L ; Wetzel , Ni ck; Sauc i er , Mi chae l; Rodi

, John; Za i ney

, Robert ; Angel i co

, E i lee n P
Subject: FW: N9510

, OCS-G16786



### This ernail is to notif

y y ou that the following Initial E xp l oration Plan recei v ed March 24

, 2010

, amended April

5

, 2010

, amend e d April 8

, 2010

, modified August 19

, 2010

, amended October 7

, 2010

, amended October 8

, 2010

, mod i fied December 9

, 2010

, am e nded Decemb e r 22

, 2010

, amended Januar y 13

, 2011

, amended Fe br u ar y

17

, 20 1 1

, a m ende d March 9

, 20 1 1

, a n d ame n ded March 30,2011

, has been d eemed submitted i n acc or dance

with 3 0 CF R 250

. 23 1 (a)and 232(d) as of April 1

, 2011 :

Control No

. : N -9510

T y pe : Init i al Ex pl oratio n Plan

L ease : OC S- G 1 67 86 Bl ock 7 38 Green Canyon A r ea Operator: B HP Billiton Petro l e u m A mericas Inc.

Acti v i ti e s Propo s ed: We ll A 001

Eliza b eth Pe ul er
Ch i ef

, P l ans Section

, Field Operations

Bureau o f Oc e an En e r gy Manag e ment

, R eg ulation

, and Enforc e ment ( BO E MRE)
Gulf of Mexico Region

5 04- 7 36

- 2 581 (p ho ne)

elizabeth

. peuler@boemre

. gov

1

### United States Government Memorandum April 1, 2011

To: Public Information (MS 5030)

From: Plan Coordinator, FO, Plans Section (MS 5231)

Subject: Public information Copy of Plan

Control # N 09510 Type Initial Exploration Plan Lease OCS-G16786 Block 738 Green Canyon Area Operator BHP Billiton Petroleum Americas Inc. Description Well A 001 Rig Type DP Semisubmersible

Attached is a copy of the subject plan.

It has been deemed submitted as of this date and is under review for approval.

James Webb

Plan Coordinator

Site Type/Name Botm Lse/Area/Blk Surface Location Surface Lse/Area/Blk
WellA/001 G16786/GC/738 3428 FSL, 3925 FWL G16786/GC/738

# BHP Billiton Petroleum (GOM) Inc.

Amendment to Initial Exploration Plan Green Canyon Area, Block 738

Lease OCS-G 16786

February 17, 2011

Table of Contents

Contents of Plan

General Information

Geological and Geophysical Information

H 2 

### S Information

Mineral and Resource Conservation Information

Biological, Physical and Socioeconomic Information

Waste and Discharge Information

Air Emissions Information

Oil Spill Information

Environmental Monitoring Information

Lease Stipulations Information

Environmental Mitigation Measures Information

Decommissioning Information

Related Facilities and Operations Information

Support Vessels and Aircraft Information

Onshore Support Facilities Information

Sulphur Operations Information

Coastal Zone Management Act (CZMA) Information

Environmental Impact Analysis (EIA)

Administrative Information

Attachments

Attachment A Plan Information Form Attachment B Well Location Map

Attachment C Air Emissions Tables

Attachment D NTL 2010-N06 WCD Calculations Attachment E Spill Response Discussion for NEPA & CZMBHP Billiton Petroleum (GOM) Inc. 1 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

# Revision to Initial Exploration Plan

Control No. N-09510

for Green Canyon Block 738

Lease OCS-G 16786

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 an Amendment to an Initial Exploration Plan (EP) submitted by BP Exploration & Production Inc. (BP).

 March 23, 2010 - BP submitted an Initial EP (Control No. N-09510), requesting approval to drill three (3) wells in the Green Canyon Block 826 Unit (Agreement No. 754398016) from two surface locations in Green Canyon Area Block 738 (Locations A and B) and one surface location in Green Canyon Area Block 782 (Location U).

 April 7, 2010 - this plan was deemed submitted

 May 3, 2010 - BHP Billiton Petroleum (GOM) Inc. was designated operator of all of Block 738, Green Canyon Area.

 June 1, 2010 - the Bureau of Ocean Energy Management, Regulation and Enforcement (previously Minerals Management Service) notified BP that additional information was required to evaluate the proposed EP to ensure that it complied with all applicable requirements.

 August 19, 2010, BP cancelled Location U proposed in Block 782.

 September 15, 2010, BHP Billiton Petrol eum (GOM) Inc. was approved as unit suboperator for Lease OCS-G 16786 in the Green Canyon Block 826 Unit.

Under this Plan Amendment, BHPB is submitting NTL 2010-N06 required data corresponding to Location A which BHBP proposes to drill in Green Canyon Area, Block 738 (Location A), Lease

OCS-G 16786.



### (a) Plan Information Form

An OCS Plan Information Form (MMS-137) with details of the proposed drilling operations along

with BHPB’s tentative schedule is included as Attachment A

.

The proposed wells will be drilled with the GSF Development Driller I (DDI) using subsurface BOPs. There will be no anchors associated with the drilling operations proposed in this Plan.

Revised 12-17-2010

Revised 01-13-2011BHP Billiton Petroleum (GOM) Inc. 2 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### (b) Bathymetry Map and Location Plat

Included in this section is the Well Location Plat (Attachment B) . The plat shows the surface location of the proposed well being drilled by BHPB. Please note, bottom hole location, MD & TVD depths are omitted from the Public Information Copy.

The Bathymetry Map was previously submitted in Plan N-09510 and will not be affected by the change of operator (or submitter).



### (c) Safety and Pollution Prevention Features

The proposed wells addressed in this Plan will be drilled with the DDI (a semi-submersible drilling unit) 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 O for Well Control and Production Safety Training

These regulations may be further clarified by Sa fety Alerts, and current policy making invoked by the Bureau of Environmental Management, Regulation and Enforcement (BOEMRE), Environmental Protection Agency (EPA) and the U.S. Coast Guard (USCG).

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

will be maintained on the MODU at all times.

The BOEMRE is required to conduct onsite inspections of offshore facilities to confirm operators are complying with lease stipulations, operating regulations, approved plans, and other conditions; as well as to assure safety and pollution prevention requirements are being met. The National Potential Incident of Noncompliance (PINC) List serves as the baseline for these inspections.

The BOEMRE also inspects the stockpiles of equipment listed in the Operator's approved Oil Spill Response Plan that would be used for the containment and cleanup of hydrocarbon spills and is further addressed in the “Oil Spill Information” section of this Plan.

In accordance with Title 30 CFR 250.1501, the goal of our training program is safe and clean OCS operations. To accomplish this, BHPB ensures that our employees and contractor personnel engaged in well control understand and can properly perform their duties.

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 3 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### 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)

Fuel Oil SemiSubmersible 2,023 11 22,260 39-43 o



### Base Oil SemiSubmersible 4,535 1 4,535 39-43 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

BHPB does not propose any additional safety, pollution prevention, and early spill detection measures beyond those required by 30 CFR Part 250. These are also addressed above in sections (c) and (f).

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 4 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## GENERAL INFORMATION

(a) Applications and Permits

Application / Permit Issuing Agency Status

APD BOEMRE District Submitted



### (b) Drilling Fluids

The following table provides information on t he 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) 59,100 bbls

Synthetic-based (internal olefin, ester, etc) 2,200 bbls



### (c) Peak Production Rates / Life of Reserves

Not applicable for exploration plans.



### (d) Oil Characteristics

Oil characteristics, analytical methodologies and oil identification are required for EP’s that propose to conduct an activity that requires an Application for Permit to Drill (APD) and involves use of a subsea blowout preventer (BOP) or a surface BOP on a floating facility.

The chemical and physical characteristics of the oils (as defined under 30 CFR §254.6) that will be produced, handled, transported, or stored at this location are listed below:

Physical and Chemical Properties of Ba se Oil (MSDS 03-Jan-2008 / Accolade Base)
pH Not Determined
Specific Gravity @20C(Water=1) 0.8 – 0.82 Density @ 20C (lbs/gal) 6.75 Bulk Density @ 20C (lbs/ft3) Not Determined
Boiling Point/Range (F) 464 Boiling Point/Range (C) 240 Freezing Point/Range (F) -22 Freezing Point/Range (C) -30
Vapor Pressure @ 20C (mmHg) Not Determined
Vapor Density (Air=1) Not Determined

Percent Volatiles 0 Evaporation Rate (Butyl Acetate=1) Not Determined
Solubility in Water (g/100ml) Insoluble
Solubility in Solvents (g/100ml) Not Determined VOCs (lbs/gallon) Not Determined
Viscosity, Dynamic @ 20 C (c entipoises) Not Determined
Viscosity, Kinematic @ 20 C (centistrokes) Not Determined

Partition Coefficient/n-Octanol/Water 1.69 (OECD117) Molecular Weight (g/mole) Not Determined

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 5 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 Physical and Chemical Properties of Base Oil (MSDS 0192-M1A0.3-Rev.C 06/30/06))
Appearance Clear, yellow to red liquid

Odor Mild hydrocarbon odor
Boiling Point 309F – 700F Specific Gravity (water=1) 0.8400 – 0.9000
Vapor Pressure <2.6 mm Hg @ 122F Vapor Density (air=1) >4

Soluble in water Insoluble
Evaporation Rate (ether=1) Slower
pH Not Determined



### 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 D

.



### (e) New or Unusual Technology

BHPB does not propose the use of any new or unusual technology in the activities proposed under this plan.



### (f) Bonding Information

The bond requirements for the activities and facilities proposed in this Plan Amendment 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”.



### (g) Oil Spill Financial Responsibility (OSFR)

BHPB (BOEMRE Operator No. 02010) has demonstrated oil spill financial responsibility for the facilities proposed in this Plan Amendment 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) Blowout Scenario

The Mad Dog North well will penetrate the objective, hydrocarbon bearing sands with a 12-1/4” x 14” drilling assembly below the 13-5/8” 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 subsequently the

marine riser fails. The end result is an uncontrolled blowout at the sea floor.

The expected spill rate for this scenario would be 29 MSTB/Day of 26.8o API gravity oil. It is assumed that the well will not bridge over and will continue to flow until the well is either capped by subsea containment devices or is killed via a relief well. BHPB has two (2) rigs contracted and working in the Gulf of Mexico that are capable of drilling in 7,500 ft of water if a relief well is required.

Revised 12-17-2010BHP Billiton Petroleum (GOM) Inc. 6 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### It is estimated that it would take 7-10 days to move a rig onto location approximately 71 days to drill the relief well and perform kill operations. It is estimated that the blowout rate will have reduced to 27 MSTB/Day in 81 days, at the completion of the relief well.



### 1. RELIEF WELL

Relief Rig Availability

In addition to the DDI, BHPB has the CR Luigs contracted and working in the Gulf of Mexico and is capable of drilling in 10,000 ft of water if a relief well is required.

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 operations. Several stimulation vessels in the GOM could be used for kill operations.

Relief Rig Timing (Contract) and Rig Mobilization

BHPB has two rigs on contract operating in the Gulf of Mexico. A reasonable assumption would be that it would take 7 – 10 days for the relief well rig to safely suspend operations on the current well and move to the Green Canyon 738 #1 relief well location. Upon arrival at location, it would be expected to take approximately 71 days to drill the relief well and perform kill operations.

Location & Strategy of Relief Well

As the Mad Dog North well is located 126 miles off the coast of Louisiana, a relief well

from an onshore location is not feasible.

The Mad Dog Spar is approximately 13,300ft aw ay, too far to plan a relief well from. Additionally, the spar no longer has a rig for performing drilling operations.



### 2. BLOWOUT PREVENTION AND INTERVENTION

Summary of Prevention Measures

BHPB maintains and adheres to an ISO 14001 / OSHAS 18001 Conformance Certified Management System which includes Well Control, Well Integrity [including barrier analyses], and Well Design Standards which have been updated to include the initial learning’s from the Deepwater Horizon incident.

BHPB have established procedures for performing drilling operations that are continually updated and designed to be “fit for purpose” to ensure each well is planned to prevent a

well control scenario.

BHPB employs an industry leading expert to provide initial pore pressure and fracture gradient predictions. Having this expertise and knowledge in house allows for the successful planning of a well to minimize the chances of a blowout.

Revised 12-17-2010BHP Billiton Petroleum (GOM) Inc. 7 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### Well hazard assessments are performed on every well focusing particularly on well integrity, well control and emergency response arrangements.

A well risk assessment is conducted as part of the well planning process, and a risk register is completed and documented in the drilling program addressing each of the

risks.

If while drilling a well situations change such that the original drilling program requires to be amended, a Management of Change is issued and if necessary, a barrier analysis is conducted. The management of change form is signed off by management and issued to operations personnel for implementation.

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

BHPB employs experienced and trained Field Operations Personnel.

BHPB conducts periodic well control audits of our contracted drilling rigs by both BHPB drilling management and independent third party (well examiner) auditors.

Reduce the Likelihood of a Blowout

Real time pressure and well data is monitored from the BHPB Houston office during drilling operations. This includes utilizing Gamma Ray and Resistivity LWD and in certain cases formation pressure while drilling tools.

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

 Liners will be run across hydrocarbon bearing formations.

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

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

 All displacements to less dense fluids will be performed on a closed system where fluid volumes can be closely and accurately monitored.

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

The BOP stacks on the C.R. Luigs and Development Driller-1 rigs are both six ram stacks configured to provide enhanced well control and emergency response capability, including dual blind shear rams, casing shear rams, and three variable bore pipe rams. These configurations have been in place since the rigs first began work with BHPB (since 2000 for the CRL and 2005 for the DD1). As such, procedures pertinent to these BOP configurations are well established and familiar to the drillers, tool pushers, and BHPB Drilling Supervisors.

Likelihood for Surface Intervention to Stop the Blowout

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

The 13-5/8” intermediate long string will design for a full column of oil to the mudline. As a result, it would be possible to install a containment device (such as a capping stack) which would subsequently allow for the blowout to be stopped.

BHPB has standardized the connector on the BOP stack for the GSF Development Driller I and the GSF C.R. Luigs to ensure that either rig would be capable of latching onto an existing BHPB wellhead.

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 8 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### Plans for Effective and Early Intervention

Both rigs contracted by BHPB have a Deadman / Autoshear which will function in the event of a LMRP disconnect or a loss of both hydraulic pressure and electrical communication with the BOP control system on surface.

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

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

 BHPB has upgraded the pump skid on the rigs’ ROV’s with a more powerful pump capable of producing higher flow rate s. Additionally, the receptacles have been changed to allow for more flow rate to reduce closing times.

 BHPB plans to utilize a dedicated accumulator bank for the ROV to further improve the response times.

BHPB would make plans to build a capping stack to effectively shut off the flow of hydrocarbons, or use an ava ilable containment system.

Relief Well Arrangements

BHPB has two 5 th 

### generation rigs on contract capable of drilling in a minimum of 7,500ft of water. Both rigs are planned to continue to operate in the Gulf of Mexico.

The best possible surface locations for the drilling of a relief well have been reviewed by looking at the drilling hazards associated with the potential locations.

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

blowout.

Key Rig Specifications for Relief Well

Rig Name DD1 C.R. Luigs

Rig type 5th Gen MODU rated for 7,500 ft water
depth, Dynamically Positioned 5th Gen MODU rated for 10,000 ft
water depth, Dynamically Positioned

BOP size & pressure rating 18.75 - 15,000 psi 18.75 - 15,000 psi

Max Hookload (kips) 2,000 kips 1,800 kips

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

Mud pumps Power & Pressure (hp/psi) 4 x 14-P-220 NOV pumps with 2,200
7,475 psi working 4 x 14-P-220 NOV pumps with 2,200
7,475 psi working

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

Variable Loading (kips) 15,432 kips Drilling N/A Drill Ship
Top Drive Power & Torque (hp/ftlbs) Hydralift HPS 1000 2E (AC) NOV TDS-4

Dry bulk storage capacity (cu.ft) 16,950 cu/ft Cement & 10,416 cu /ft
Barite (VDL Limited) Total Bulk 27,000 cuft

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 9 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### Other Measures Taken

BHBP will have readily available, prior to spudding the subject well, all the materials and equipment needed to spud, drill, and case off a relief well.

BHPB has established commercial relationships with those suppliers of contingency equipment and services that we have identified as necessary to kill a blown out well.



### (k) Chemical Products

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

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 10 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## GEOLOGICAL AND GEOPHYSICAL INFORMATION

In accordance with 43 CFR 2.13 (c) (9), those items considered proprietary have been omitted from the Public Information copy and have been referenced accordingly.



### (a) Geological Description

PROPRIETARY DATA



### (b) Structure Contour Maps

PROPRIETARY DATA



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

PROPRIETARY DATA



### (d) Geological Structure Cross-Sections

PROPRIETARY DATA



### (e) Shallow Hazards Report

A Geohazards Assessment was previously submitted and will not be affected by the change of operator (or submitter).



### (f) Site Specific Shallow Hazards Assessment

A Site Specific Shallow Hazards Assessment wa s previously submitted and will not be affected by the change of operator (or submitter).



### (g) High Resolution Seismic Lines

3-D survey information was utilized and previously submitted and will not be affected by the change of operator (or submitter).



### (h) Stratigraphic Column

A stratigraphic column was previously submitted and will not be affected by the change of operator (or submitter).



### (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.BHP Billiton Petroleum (GOM) Inc. 11 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### (k) Future G&G Activities

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

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 12 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## HYDROGEN SULFIDE INFORMATION

(a) Concentration

BHPB does not anticipate encountering H 2 

### S while conducting our proposed exploratory

activities.



### (b) Classification Request

PROPRIETARY DATA



### (c) Contingency Plan

BHPB does not anticipate encountering H 2 

### S while conducting our proposed exploratory 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 exploratory activities therefore a modeling report is not required at this time.BHP Billiton Petroleum (GOM) Inc. 13 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## MINERAL AND RESOURCE CO NVERSATION INFORMATION

(a) Technology and Reservoir Engi neering Practices and Procedures

Not Required for Exploration Plans



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

Not Required for Exploration Plans



### (c) Reservoir Development

Not Required for Exploration PlansBHP Billiton Petroleum (GOM) Inc. 14 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## 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.

With regards to proposed Location A there are no hydrocarbon macro-seeps or hard bottom areas capable of supporting high-density benthic communities within 2,000 ft of the location.



### (b) Topographic Features Map

There are no topographic features located on Green Canyon 738.



### (c) Topographic Features Statement

Since there are no topographic features located on Green Canyon 738 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 Plan Amendment 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. 15 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### (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 738.



### (i) Archaeological Report

Green Canyon Block 738 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) Socioeconomic 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. 16 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## WASTE AND DISCHARGE INFORMATION

(a) Projected Generated Wastes

The following is a list of projected solid and liquid wastes likely to be generated by these exploration operations (as per 12/13/2010 Press Release).

Type of Waste Composition Projected Amount

Spent drilling fluids Water-Based 59100 bbls
Spent drilling fluids Synthetic-based 2200 bbls

Cuttings Drill cuttings associated with water-based

fluids 2750 bbls

Cuttings containing SBM Cuttings coated with ester-based synthetic drilling muds 4050 bbls

Mud, cuttings and cement Gel, WBM, Cuttings, SW & caustic Gel - NA

WBM – 59100 bbls Cuttings – 6800 bbls

SW & caustic – 20 bbls
Sanitary wastes Sanitary wastes 20 gal/person/day

Domestic waste Domestic waste 30 gal/person/day

Deck drainage Water / rainfall 3309 bbl/year Based on 65” / year rainfall average
Well treatment, workover or completion

fluids Fluids generated from completion 800 bbl/ well

Uncontaminated fresh or seawater NA NA

Desalinization unit water 110 bbl/day (max unit capacity) 110 bbl/day (max unit capacity)
Uncontaminated bilge water NA NA

Uncontaminated ballast water NA NA

Spent oil-based drilling fluids and cuttings Fluid and cuttings coated with oil-based mud

NA

Used Oil Lubricating Oils NA

Trash and debris Refuse generated by personnel on board

MODU 20 ft 3 / 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:

The following is a list of solid and liquid wastes which may be discharged overboard during these exploration operations (as per 12/13/2010 Press Release).

Type of Waste Amount to be Discharged Discharge Rate Discharge Method

Drill cuttings associated with waterbased fluids 2750 bbls 400 bbls/hr Overboard

Drill cuttings associated with synthetic drilling fluids 4050 bbls NA Overboard

Mud, cuttings and cement Gel - NA

WBM – 59100 bbls Cuttings – 6800 bbls

SW & caustic – 20 bbls NA Overboard / seafloor

Sanitary wastes 20 gal/person/da y 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 800 bbl/ well 100 bbl / hr Discharge used fluids overboard,

return excess to shore for credit

Uncontaminated fresh or seawater NA NA NA

Desalinization unit water 110 bbl/day (max unit capacity) NA overboard
Uncontaminated bilge water NA NA NA

Uncontaminated ballast water NA NA NA

Revised 12.07.2010

Revised 02.14.2011BHP Billiton Petroleum (GOM) Inc. 17 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### (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. 18 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## 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.

For this plan, there are no existing facilities or activities co-located with the current proposed activities; therefore, the Complex Total Emissions are the same as the Plan Emissions.

Screening Questions for EP Yes No Is any calculated Complex Total (CT) Emission amount (in tons) associated with your proposed exploration activities more than 90% of the amounts calculated using the following formulas: CT = 3400D 2/3 

### for CO, and CT = 33.3D for other air pollutants (where D = distance to shore in miles)? X

Do your emission calculations include any emission reduction measures or

modified emission factors? X Are your proposed exploration activities located east of 87.5 o 

### W longitude? 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 for more than 48 continuous hours from any proposed well? X Do you propose to burn produced Hydrocarbon liquids? 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 738 OCS-G 16786 0 A

Emitted Substance

Year

PM SOx NOx VOC CO

2010 0 0 0 0 0

2011 79.25 43.96 218 4.72 82.07 487.70

Allowable 4129.20 4129.20 4129. 20 4129.20 84546.06



### (c) Spreadsheets

Air Emission Spreadsheets are included as Attachment C.

Revised 12-07-2010BHP Billiton Petroleum (GOM) Inc. 19 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## OIL SPILL INFORMATION

(a) Oil Spill Response Planning

(1) Site-Specific OSRP

Lease OCS-G16786 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 Amendment to the Initial Exploration Plan will be covered by the Oil Spill Response Plan filed by BHP Billiton Petroleum (Americas) (Company No. 00362) in accordance with 30 CFR 254 and approved on August 31, 2009. The OSRP was most recently updated on April 5, 2010 by including changes to the Exploratory Worst Case Discharge.



### (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 Plan Amendment 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.BHP Billiton Petroleum (GOM) Inc. 20 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### (iv) Worst Case Scenario Determination

The activities proposed in this Plan Amendment 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 Mad Dog Worst Case Discharge

Scenario is summarized in the table below:

Category Regional OSRP Amendment for N06

Type of Activity 1 Exploratory Drilling Exploratory Drilling

Facility Location (area/block) GC 738 GC 738

Facility Designation 2 Well 001 Well 001

Distance to Nearest Shoreline (statute miles) 124 124

Volume 3

Uncontrolled blowout (volume per day) 184,000 28,000

Type of Oil(s) (crude oil, co ndensate, diesel) Crude Crude

API Gravity(s) 4 26.8  ̊ 26.8  ̊

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 Plan Amendment.



### NTL 2010-N06 – WCD Calculations Overview

Mad Dog North, Green Canyon Block 738 #1 (MDN) well is a Mad Dog appraisal well targeting the M9/M10 (DD, EE, FF) sands. At the MDN location it is expected that the M3, M6, M7, M8, and M9 (CC) zones will be encountered above the target M9/M10 (DD, EE, FF). These zones are expected to be water wet at the MDN location and are assessed as a water producing zone for Worst Case Discharge (WCD) calculations. This was the only hole section examined for this WCD report and is the worst case scenario. Petroleum Experts Software: Prosper was used for nodal analysis. Integrated programs MBAL and GAP were combined with Prosper to determine forecasted initial and transient flow rates. This WCD follows guidelines within NTL No. 06 regarding assumptions for blowout conditions of the well.BHP Billiton Petroleum (GOM) Inc. 21 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### Table 1 shows the results of the discharge rate work performed and outlined in this report. The complete report is included as Attachment D.



### EXPECTED DISCHARGE RATES

Initial 30 day

Units Discharge Units Discharge Total Liquid

Rate MSTB/Day 423 Total Liquid Rate MSTB/Day 417

Oil Rate MSTB/Day 29 Oil Rate MSTB/Day 28

Gas Rate MMscf/Day N/A Gas Rate MMscf/Day N/A

Condensate Rate STB/Day N/A Condensate Rate STB/Day N/A 60 day 81 day (Relief well completion time)

Units Discharge Units Discharge Total Liquid

Rate MSTB/Day 412 Total Liquid Rate MSTB/Day 408

Oil Rate MSTB/Day 28 Oil Rate MSTB/Day 27

Gas Rate MMscf/Day N/A Gas Rate MMscf/Day N/A

Condensate Rate STB/Day N/A Condensate Rate STB/Day N/A 90 day

Units Discharge Total Liquid

Rate MSTB/Day 406

Oil Rate MSTB/Day 27

Gas Rate MMscf/Day N/A

Condensate Rate STB/Day N/A

Table 1: Summary Rates

The “Expected Case WCD” is based upon the expected outcome of the well. Of course, there

are other possible outcomes, and Cases 1

– 3 capture the WCDs of these.

Expected Case Case 1 Case 2 Case 3

M3 Fluid Content Water Gas Gas

M6 Fluid Content Water Oil Oil

M7 Fluid Content Water Water

M8 Fluid Content Water Water

M9 Fluid Content Oil Oil Oil

M10 Fluid Content Oil Oil Oil

Initial Oil Rate (MSTB/D) 28 78 66 65

81 day Oil Rate (MSTB/D) 27 41 51 54
Expected Case

– WCD as detailed in MDN NTL N.06 Worst Case Discharge

Case 1

– WCD if upper 2 zones contain hydrocarbons, and only these sands are open to flow

Case 2

– WCD if upper 2 zones contain hydrocarbons instead of water

Case 3

– WCD if a contingency liner is set below the M8 sand (only M9 & M10 in open hole)BHP Billiton Petroleum (GOM) Inc. 22 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

### (b) Oil Spill Response Discussion

BHPB will make every effort to respond to the worst case discharge as effectively as possible. BHPB’s approved regional oil spill response plan outlines equipment, personnel, materials and support vessels as well as temporary storage equipment to be considered in order to cope with an initial spill from the Mad Dog North Project. The information related to response equipment is provided in several figures included in Appendix E of the above mentioned oil spill response plan.

Figure H.3a in the oil spill response plan, lists the individual times needed for procurement, load out, travel time to the site and deployment. It al so indicates how operations will be supported. If the slick moved offshore, the initial response may include the utilization of dispersants, which should be effective on this type product. If dispersants are utilized, sorties from the Basler 67T and from the DC-3 would be able to be delivered from existing stockpiles.

Offshore response strategies may also include attempting to skim utilizing the CGA HOSS Barge, nine FRU’s, four FRV’s, 3 Marco skimmers, 2 EGMOPOLs, 3 FOILEX TDS 150s, 4 Drum Skimmers, 1 rope mop and 11 pairs of KOSEQ skimming arms with a total derated skimming capacity of 359,296 barrels. Temporary storage associated with the identified skimming equipment is also provided currently up to a level of 255,048barrels. SAFETY IS

FIRST PRIORITY. AIR MONITORING WILL BE ACCOMPLISHED AND OPERATIONS

DEEMED SAFE PRIOR TO ANY CONTAINMENT/SKIMMING ATTEMPTS.

If the spill went unabated, shoreline impact in a number of Louisiana parishes and Texas counties would depend upon existing environmental conditions. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. Strategies would be based upon surveillance and real time trajectories that depict areas of potential impact given actual sea and weather conditions. Strategies from the Area Contingency Plan(s), and Unified Command would be consulted to ensure that environmental and special economic resources would be correctly identified and prioritized to ensure optimal protection. Shoreline protection strategies depict the protection response modes applicable for oil spill clean-up operations. Each response mode is schematically represented to show optimum deployment and operations of the equipment in areas of environmental concern. Supervisory personnel have the opti on to modify the deployment and operation of equipment allowing a more effective response to site-specific circumstances.

See Attachment E for Spill Response Discussion for NEPA and CZM



### (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 MMS GOMR for guidance o preparing the report and the MMS GOMR would be provided with two copies.

Revised 12.07.2011

Revised 02.14.2011BHP Billiton Petroleum (GOM) Inc. 23 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## ENVIRONMENTAL MONITORING INFORMATION

(a) Monitoring 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 exploratory activities proposed in this plan.



### (c) Flower Garden Banks National Marine Sanctuary

BHPB’s activities under this Plan are 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. 24 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## LEASE STIPULATIONS INFORMATION

Oil and gas exploration and development activities on the OCS are subject to stipulations developed before the lease sale and would be attached to the lease instrument, as necessary, in the form of mitigating measures. The BOEMRE is responsible for ensuring full compliance with stipulations.

BHPB is aware the BOEMRE (previously Miner als Management Service) invoked the following stipulations for Green Canyon Area, Block 738, OCS-G16786, Sale No. 157:

 Lease Stipulation for Protected Species (Sea Turtles, Marine Mammals, Gulf Sturgeon, Brown Pelican, Whooping Cranes, and Other Federally Protected Species

NOTE: The Minerals Management Service issued NTL 2007-G02 pursuant to 30 CFR 250.103, to explain how to implement seismi c survey mitigation measures, requiring ramp-up procedures, protected species observer training, visual monitoring and reporting. This NTL applies to all marine mammals, some of which may be encountered in water depths less than 200 meters in certain areas of the Gulf of Mexico.

NOTE: The Minerals Management Service issued NTL 2007-G03 pursuant to 30 CFR 150.103 to provide guidance and assist the operators in preventing intentional and / or

accidental introduction of trash and debris into the marine environment. With this assistance and with laws such as MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the

U.S. Coast Guard and the U.S. Environmental Protection Agency, our employees willensure that all offshore personnel, including contractors and other support servicesrelated personnel have complete understanding of the requirement that Operators be proactive in avoiding accidental loss of solid waste items on the OCS.

NOTE: The Minerals Management Service i ssued NTL 2007-G04 pursuant to 30 CFR 250.103, 250.23(o) and 250.204(s) to explain ho w Operators must implement measures to minimize the risk of vessel strikes to protected species and report observations of injured or dead protected species effective February 7, 2007. We will ensure that our contract vessel operators are aware of their requirement to report sightings of any injured or dead protected species immediately to the MMS Protected Species Biologist by telephone.

 Military Areas – MWA W-92 – BHPB or the vessel contractor will contact the command headquarters for Military Warning Area W-92 for the purposes of entering into an agreement concerning the control of elec tromagnetic emission and the use of boats and aircraft in the warning area, if required.BHP Billiton Petroleum (GOM) Inc. 25 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## 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 exploratory 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. 26 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## DECOMMISSIONING INFORMATION

This information is not required for pl ans submitted in the BOEMRE GOMR.BHP Billiton Petroleum (GOM) Inc. 27 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## RELATED FACILITIES AND OPERATIONS INFORMATION

(a) Related OCS Facilities and Operations

This discussion is not required for EP’s.



### (b) Transportation System

This discussion is not required for EP’s.



### (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. 28 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## SUPPORT VESSELS AND AIRCRAFT INFORMATION

(a) General

The following list provides information regardi ng 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 - 35,000 gals 1 7 times / week Crew boat(s) 25,000 – 35,000 gals 1 7 times / week
Helicopter 440 gals 1 As needed



### (b) Diesel Oil Supply Vessels

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

Size of Fuel Supply

Vessel Capacity of Fuel Supply Vessel (in bbls) Frequency of Fuel

Transfers Route Fuel Supply Vessel will

Take

280 ft PSV 8930 2 / month From the shorebase in Port Fourchon, LA to the MODU, then

back to shorebase



### (c) Drilling Fluids Transportation

This information is not required by the State of Louisiana for the exploratory activity proposed in this plan.



### (d) Solid and Liquid Wastes Transportation

When necessary, BHPB will transpor t the following solid or liquid wastes from the MODU to permanent onshore facilities for disposal or recycling (per 12/13/2010 Press Release).

Type of Waste /

approximate composition Total Amount (See Plan

Information

Form for Total Days) Name/Location of Disposal Facility Rate Transport Method

Non-hazardous Trash

and Debris Non-recyclables 54.5 mt River Birch Landfill, Avondale,

LA via Galliano Waste Disposal, Galliano, LA 54.5 mt /

year Transport in bags and baskets

on vessel to shorebase – Picked up at shore base and trucked to private facility

Chemical products and

general hazardous

waste 1.5 mt Safety-Kleen Systems, Inc. Transfer facility in Kenner, LA 1.5 mt /

year Transport in drums on vessel to shorebase – Picked up at

shorebase 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

Used Oil 590 bbls/year L&L Oilfield Services in Fourchon, LA; Safety-Kleen Systems, Inc. transfer facility
in Kenner, LA 590 bbls/year Transport in drums on crew boat to shore base – Picked up at

shore base and recycled



### (e) Vicinity Map

A vicinity map showing the location of Green Canyon Block 738 relative to the shoreline and the onshore base located in Port Fourchon, Louisiana was previ ously submitted with Plan N-09510 and will not be affected by the change of operator (or submitter).

Revised 12.17.2010

Revised 02.14.2011BHP Billiton Petroleum (GOM) Inc. 29 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## ONSHORE SUPPORT FACILITIES INFORMATION

(a) General

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

Name Location Existing, New or

Modified
Chouest Base Port Fourchon, LA Existing



### (b) Support Base Construction or Expansion

The proposed operations do not mandate any immediate measures for land acquisition or expansion of the existing onshore base facilities.



### (c) Support Base Construction or Expansion Timetable

This discussion is not required for the activities proposed in this plan.



### (d) Waste Disposal

The following is a list of onshore facilities that BHPB will utilize if transporting solid or liquid wastes from the MODU for disposal or recycling (per NTL 2008-G04).

Name / Location of Facility Type of Waste Amount Rate Disposal Method

River Birch Landfill,
Avondale, LA via

Galliano Waste Disposal, Galliano, LA Non-hazardous Trash/ Debris; nonrecyclables 9900 cu ft /

yr 90 cu ft / day Landfill

Safety-Kleen Systems, Inc. Transfer facility in
Kenner, LA Chemical products and general

hazardous waste 120 lbs .8 lbs / day Temporary storage

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 bbl /

well NA Temporary storage

L&L Oilfield Services inFourchon, LA; SafetyKleen Systems, Inc. transfer facility in
Kenner, LA Used Oil 7.4 bbl / yr 0.06 Bbls / yr Temporary storage



### (e) Air Emissions

This discussion is not required to accompany EP’s submitted in the BOEMRE GOMR.



### (f) Unusual Solid and Liquid Wastes

This discussion is not required to accompany EP’s submitted in the BOEMRE GOMR.

Revised 12.07.2010

Revised 02.14.2011BHP Billiton Petroleum (GOM) Inc. 30 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## SULPHUR OPERATIONS INFORMATION

BHPB is not proposing to conduct sulphur operations in this plan.BHP Billiton Petroleum (GOM) Inc. 31 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## 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 (formerly Minerals Management Service) mu st provide a certification with necessary data and information for the affected State to determine that the proposed activity(s) complies with the enforceable policies of each States’ approved program, and that such activity will be conducted in a manner consistent with the program.

(a) Consistency Certification

A Coastal Zone Management Consistency Certification for the State of Louisiana is not required for the exploratory activities proposed in this Revision to plan Control No. N-09510.

(b) Other Information



### State of Louisiana:

Although a Coastal Zone Management consistency certification is not required, the enforceable policies of the State of Louisiana have been considered and will be complied with.BHP Billiton Petroleum (GOM) Inc. 32 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## ENVIRONMENTAL IMPACT ANALYSIS (EIA)

An Environmental Impact Analysis (EIA) was prev iously submitted with Initial EP (Control No. N09510) and will not be affected by the change of operator (or submitter).

Revised 12.07.2010BHP Billiton Petroleum (GOM) Inc. 33 Green Canyon Block 738

Revision to Initial EP Lease OCS-G 16786 

## 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 Exploration Plan (Control No. N-09510) submitted by BP Exploration & Production Inc. on
March 23, 2010.

### ATTACHMENT A

U.S. Department of the Interior OMB Control Number: 1010 -0 151 Minerals Management Service OMB Approval Expires: 12/31/2011 

### OCS PLAN INFORMATION FORM

General Information

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

Company Name: BHP Billiton Petroleum (GOM) Inc. MMS Operator Number : 0 2010

Address:

1360 Post Oak Blvd. , Suite 1 50 Houston, Texas 770 56

- 3020 Contact Per son: Susan Wilson

Phone Number: 713.599.6349

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

Lease (s) : G16786 Area: Green Canyon Block (s) : 738 Project Name (If Applicable): Mad Dog

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

124

Description of Proposed Activities (Mark all that apply)

X Exploration drilling Development drilling

We ll 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 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? Yes X No

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

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

Do you propose any activities that may disturb an MMS

- designated hig h- probability archaeological area? Yes X No

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

Tentative Schedule of Proposed Activities

Proposed Activity Start Date End Date No. of Day s

Drill Location A 01/01/201 1 04/05/2011 95

Description of Drilling Rig Description of Production Platform

Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform rig Well protector Compliant tower

Semisubme rsible Submersible Fixed platform Guyed tower

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

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

Description of Lease Term Pipelines

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

NA NA NA NA



### 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 CO PYOCS 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 001 (LOC A) Subs ea Completion

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

Surface Location Bottom

- Hole Location (For Wells)

Lease No. OCS

- G 16786

Area Name Green Canyon

Block No. 738

Block line Departures (in feet) N/S Departure: 3428 .00 ’ FSL

E/W Departure: 3925.00 ’ FWL

Lambert X

- Y

coordinates X: 2,5 2 2, 485 .00

Y: 9, 887

, 58 8.00

Latitude/ Longitude Latitude: 27 ° 1 3 ’ 18.296 ” N

Longitude: 90 ° 17 ’ 07.738 ” W

TVD (Feet): MD (Feet): Water Depth (Feet): 4468

Anchor Locations for Drilling Rig or Construction Barge

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

Chain on Seafloor

1

2

3

4

5

6

7

8

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

coll ects this information as part of an applicant’s Exploration Plan or Development Operations Coordination Document submitted for MMS approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act

and 30 CFR 250.19 7 . An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 per response, or 640 with an accompanying EP (1,000 hours in AKOSCR), or 690 (1,700 in AKOCSR) with an accompanying DPP or DOCD, including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with s ubpart 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 F ORM MMS

- 137 ( December 200 8 – Supersed es all previous editions of form MMS

- 137 which may not be used.) Page 2 of 2



# PUBLIC INFORMATION CO PYEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2011COMPANYBHP Billiton Pet. (GOM) Inc.AREAGreen CanyonBLOCK738/782LEASEOCS-G 16786 / 15610PLATFORMWELLACOMPANY CONTACTSusan Wilson / Joshua O'BrienTELEPHONE NO.713 599 6349 / 713 599 6132REMARKSrev. 2, 10/4/2010 (Revision) Exploration Wellrev. 2.1, 11/29/2010 (Revision) Exploration Well, Rig changeMMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 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] g/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.

[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 [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.

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 2 of 8EMISSIONS CALCULATIONS 2010 YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONEREMARKSBHP Billiton Pet. (GOM) InGreen Canyon738/782 OCS-G 16786 / 0 ASusan Wilson / Joshua O'Brien 713 599 6349 / 713 599 6132rev. 2, 10/4/2010 (Revision) Exploration Wellrev. 2.1, 11/29/2010 (Revision) Exploration Well, Rig changeOPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUELRUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HRGAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOxVOC CO CO2 PM SOx NOxVOC CO CO2DRILLINGDPPRIME MOVER>600hpdiesel[1]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Emergency Generator>600hp diesel 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-POSU-CA PUEng./Hydraulic Generator Alt. #2 FMCC Type 20 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WIRELINE <600hp diesel-Alt. #3 FMCC Type 1 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING <600hpdiesel-Batch Mixer[2]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hpdiesel[3]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00CEMENTING >600hpdiesel[3]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00ECOVESSELS>600hpdiesel(crew)(2-main)[4]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS<600hp diesel(crew) (gen.) 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00ECOVESSELS>600hpdiesel(work)(2-main)[4]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002 vesselsVESSELS>600hp diesel(work) (2-gen.)[4]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hpdiesel(work)(SDT)[4]0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS<600hp diesel(work) (Emergency Generator) 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>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 0.00PRODUCTION 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 0.002010YEAR TOTAL0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES4129.20 4129.20 4129.20 4129.20 84546.06124[1] PRIME MOVER > 600 hp.-diesel: COMM Engineering testing of TOI'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 4828hp/3500 kW with normal operation involves operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines. The NOx & CO emission factors conservatively utilized themaximum NOx and CO emission rates of the tests.[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.-IMO Tier 1: NOx emission factors for IMO Tier 1 diesel engines on certain wireline and cement unit engines.MMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 3 of 8EMISSIONS CALCULATIONS 2011 YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONEREMARKSBHP Billiton Pet. (GOM) InGreen Canyon738/782 OCS-G 16786 / 0 ASusan Wilson / Joshua O'Brien 713 599 6349 / 713 599 6132rev. 2, 10/4/2010 (Revision) Exploration Wellrev. 2.1, 11/29/2010 (Revision) Exploration Well, Rig changeOPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUELRUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HRGAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOxVOC CO CO2 PM SOx NOxVOC CO CO2DRILLINGDPPRIME MOVER>600hpdiesel[1]38624 1865.54 44772.94 24 95 27.25 15.63 892.79 28.10 125.73 44255.04 31.06 17.81 1017.78 32.03 143.33 50450.74Emergency Generator>600hp diesel 2145 103.60 2486.48 24 95 1.51 0.87 52.02 1.56 11.35 2457.72 1.73 0.99 59.30 1.78 12.94 2801.80WIRELINE <600hp diesel-POSU-CA PUEng./Hydraulic Generator Alt. #2 FMCC Type 2300 14.49 347.76 24 95 0.66 0.12 9.26 0.74 2.00 343.74 0.75 0.14 10.56 0.84 2.28 391.86WIRELINE <600hp diesel-Alt. #3 FMCC Type 1 300 14.49 347.76 24 95 0.66 0.12 9.26 0.74 2.00 343.74 0.75 0.14 10.56 0.84 2.28 391.86CEMENTING <600hpdiesel-Batch Mixer[2]250 12.08 289.80 24 95 0.55 0.10 2.63 0.62 1.67 286.45 0.63 0.12 3.00 0.70 1.90 326.55CEMENTING >600hpdiesel[3]860 41.54 996.91 24 95 0.61 0.35 13.86 0.63 4.55 985.38 0.69 0.40 15.80 0.71 5.19 1123.33CEMENTING >600hpdiesel[3]860 41.54 996.91 24 95 0.61 0.35 13.86 0.63 4.55 985.38 0.69 0.40 15.80 0.71 5.19 1123.33ECOVESSELS>600hpdiesel(crew)(2-main)[4]4520 218.32 5239.58 24 95 3.19 1.83 74.68 3.29 23.92 5178.98 3.64 2.08 85.14 3.75 27.26 5904.03VESSELS<600hp diesel(crew) (gen.) 165 7.97 191.27 24 95 0.36 0.07 5.09 0.41 1.10 189.06 0.41 0.08 5.81 0.46 1.26 215.52ECOVESSELS>600hpdiesel(work)(2-main)[4]13196 637.37 15296.80 24 95 18.62 10.68 490.45 19.20 139.64 30239.72 21.23 12.17 559.11 21.89 159.19 34473.282 vesselsVESSELS>600hp diesel(work) (2-gen.)[4]8000 386.40 9273.60 24 95 11.29 6.47 264.35 11.64 84.66 18332.66 12.87 7.38 301.36 13.27 96.51 20899.23VESSELS>600hpdiesel(work)(SDT)[4]2200 106.26 2550.24 24 95 3.10 1.78 72.70 3.20 23.28 5041.48 3.54 2.03 82.87 3.65 26.54 5747.29VESSELS<600hp diesel(work) (Emergency Generator) 502 24.22 581.38 24 95 1.11 0.20 15.48 1.24 3.35 574.65 1.26 0.23 17.65 1.41 3.82 655.10VESSELS>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 0.00PRODUCTION 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 0.002011YEAR TOTAL69.52 38.56 1916.42 71.99 427.81 109213.98 79.25 43.96 2184.72 82.07 487.70 124503.94EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES4129.20 4129.20 4129.20 4129.20 84546.06124[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.[1] PRIME MOVER > 600 hp.-diesel: COMM Engineering testing of TOI'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 4828hp/3500 kW with normal operation involves operating four (4) of eight (8) main engines. These calculations conservatively assume operating 8 of 8 engines. The NOx & CO emission factors conservatively utilized themaximum NOx and CO emission rates of the tests.[3] Diesel Recip. > 600 hp.-IMO Tier 1: NOx emission factors for IMO Tier 1 diesel engines on certain wireline and cement unit engines.MMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 3 of 8SUMMARYCOMPANY AREABLOCKLEASEPLATFORM WELLBHP Billiton Pet.Green Canyon 738/782OCS-G 16786 / 15610 0AEmittedSubstanceYearPMSOxNOxVOCCO2010 0.000.000.000.000.002011 79.2543.96 2184.72 82.07487.70Allowable4129.20 4129.20 4129.20 4129.20 84546.06MMSFORM MMS-138(December 2008 - Supersedes all previous versions of form MMS-138 which may not be used).Page 8 of 8

# MADDOG
Gulf o f Mexico Joint Interest Unit



# MDN NTL 2010

‐ N06 WORST CASE DISCHARGE

Mad Dog North Appraisal Well

Surface Location: Lat. (D,M,S) N27 13 18.298; Long. (D,M,S) W ‐ 90 17 07.738

Originator: Date:

Role:

Checker: Date:

Role:

Reviewer: Date:

Role:

Approver: Date:

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

Next Review Date: Review Period:

DOCUMENT CONTROL

NUMBER Project ID Originator Function Discipline Doc. Type Sequence

No Revision

No 

## GOMPU B HP B 00 HS P P R 0001 00

### 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 28,000 barrels of crude oil wi th an API gravity of 26.8°.

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 re sults 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 des cription 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 oil da tabase. The results indicate 19% or 5,320 barrels of crude oil would be evaporated/ dispersed within 24 hours, wi th 22,680 barrels remaining.

Spill Response Green Canyon 738 Barrels of Oil

WCD Volume 28,000

Less 19% natural evaporation/dispersion 5,320

Remaining volume 22,680

Oil addressed by aerial dispersants 7,540

Oil addressed by in-situ burning 1,400

Figure 2 outlines equipment, personnel, ma terials and support vessels as well as temporary storage equipment available to respond to a spill of 28,000 barrels The list estimate s 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 1,400 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 and nine Fast Response Units (FRUs), with a total derated skimming capacity of 76,930 barrels. Temporary storage associated with skimming equipment equals 5,700 barrels. If additional storage is needed, three 24,000 barrel storage bar ges may be mobilized. Safety is first priority. Air monitoring will be accomplished a nd 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 40,475 barrels. Temporary storage associated with skimming equipment equals 1,636 barrels. If additional storage is needed, one 24,000 barrel st orage barge and one 22,500 barrel storage barge may be mobilized. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegeta ted areas. Strategies would be based upon surveillance and real time trajectories that depict areas of potential impact given actual sea and

weather conditions. The State of Louisiana Initial Oil Spill Response Plan for Cameron Parish and/or Plaquemines Parish and Unified Command would be consulted to ensure t hat environmental and special economic resources would be correctly identified and prioritiz ed to ensure optimal protection. Shoreline protection strategies depict the protection response modes applicable for oil spill clean-up operations. The State of Louisiana Initial Oil Spill Response Pl an provides detailed shoreline protection strategies for this area, and it describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands , based on the assumption that re moval of the released oil will be much easier and less damaging to fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. Supervisory personnel have the option to modify the depl oyment and operation of equipment allowing a more effective response to si te-specific circumstances. BHP Billiton Petroleum (Americas) Inc.’s contract Spill Management Team holds a copy of the State of Louisiana Initial Oil Spill Response Plan.

### 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 738

124 miles from shore G16786 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

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3WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(124 miles from shore)28,000 bbls of crude oilAPI Gravity 26.8°FIGURE 2 – Equipment Response Time to Green Canyon 738Dispersants/SurveillanceDispersant/SurveillanceDispersantCapacity(gal)StorageCapacityPersonsReq.From Hrs to ProcureHrs toLoadoutTravel to siteTotalHrsBasler 67T2000 NA 2 Houma110.9 2.9DC 31200 NA 2 Houma111.2 3.2DC 31200 NA 2 Houma111.2 3.2Aero CommanderNA NA 2 Houma110.9 2.9Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravelto SpillSiteHrs toDeployTotalHrsHOSS Barge43000 4000 3 Tugs 8 Houma 4 05 15.3 1 25.3Recovered Oil StorageNo StagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravelto SpillSiteHrs toDeployTotalHrsCTCo 2404NA 24000 1 Tug 6Amelia4 04 15.63 1 24.63CTCo 2601NA 24000 1 Tug 6Amelia4 04 15.63 1 24.63CTCo 2602NA 24000 1 Tug 6Amelia4 04 15.63 1 24.63Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravel toSiteHrs toDeployTotalHrsFRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2 10.3 1 16.3FRU (1) + 100 bbl Tank (2) 3770 200 1Utility 6 Galveston1 2 8 10.3 1 22.3FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 3 10.3 1 17.3FRU (1) + 100 bbl Tank (2) 3770 200 1Utility 6 Ingleside 1 2 11 10.3 1 25.3FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 5.5 10.3 1 19.8FRU (2) + 100 bbl Tank (4) 7540 400 1Utility 6 Venice 1 2 0 10.3 1 14.3Offshore EquipmentWith StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravelto SiteHrs toDeployTotalHrs42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 10.3 1 16.342” Auto Boom (5000’) NA NA 10Crew 20 Galveston 1 2 8 10.3 1 22.342” Auto Boom (5000’) NA NA 10 Crew 20 Houma1 23 10.3 1 17.342” Auto Boom (2500’) NA NA 6Crew 12 Ingleside 1 2 11 10.3 1 25.342” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 10.3 1 19.842” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 24 10.3 1 18.3Nearshore ResponseNearshore EquipmentNo StagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravelto SpillSiteHrs toDeployTotalHrs46’ FRV5000 65 NA 4 Galveston 1 00 3.2 0 4.246’ FRV5000 65 NA 4Houma 1 02 2.4 0 5.446’ FRV5000 65 NA 4 Lake Charles 1 01 2.0 0 4.046’ FRV5000 65 NA 4Venice 1 01 2.0 0 4.0Nearshore RecoveredOil Storage No StagingEDRCStorageCapacity(bbl)VOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravelto SpillSiteHrs toDeployTotalHrsCTCo 2603NA 24000 1 Tug 6Amelia4 04 15.63 1 24.63CTCo 2604NA 22500 1 Tug 6Amelia4 04 15.63 1 24.63Staging Area: VeniceNearshore and InlandSkimmers WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrstoLoadOutTravel toStagingTravel toDeploymentSiteHrs toDeployTotalHrsSWS Egmopol3000 100 NA 3 Galveston 1 2 820 13SWS Egmopol3000 100 NA 3 Houma 1 2 320 8SWS Marco3588 34 NA 3Venice 1 2 020 5SWS Marco3588 34 NA 3 Houma 1 2 320 8SWS Marco3588 20 NA 3 Lake Charles 1 2 5.520 10.5Foilex Skim Package(TDS 150)891 45 NA 3 Lake Charles 1 2 5.5 2 0 10.5Foilex Skim Package(TDS 150)891 45 NA 3 Houma 1 2 3 2 0 84 Drum Skimmer(Magnum 100)686 NA NA 3 Lake Charles 1 2 5.5 2 0 10.54 Drum Skimmer(Magnum 100)686 NA NA 3 Houma 1 2 3 2 0 82 Drum Skimmer (TDS118)240 NA NA 3 Lake Charles 1 2 5.5 2 0 10.52 Drum Skimmer (TDS118)240 NA NA 3 Houma 1 2 3 2 0 8Rope Mop77 2 0 3 Belle Chasse 1 2 220 7RO Storage Barge NA 249 Towed 0 Galveston 1 2 8 2 0 13RO Storage Barge NA 249 Towed 0 Houma 1 2 320 8RO Storage Barge NA 249 Towed 0Lake Charles 1 2 5.5 2 0 10.5RO Storage Barge NA 249 Towed 0Venice 1 2 020 5Shoreline ProtectionStaging Area: FourchonBeach Boom EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravel toDeploymentSiteHrs toDeployTotalHrsBeach Boom (2000’) NA NA NA 6 Galveston 1 2 712 13Beach Boom (1000’) NA NA NA4 Ingleside 1 2 9.5 1 2 15.5Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 412 10Wildlife Response EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrstoLoadOutTravel toStagingTravel toDeploymentSiteHrs toDeployTotalHrsWildlife Support Trailer NA NA NA 2 Houma 1 2 312 9Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 212 8Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 812 14Bird Scare Guns (24) NA NA NA 2 Houma 1 2 312 9Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 1112 17Bird Scare Guns (24) NA NA NA2 Lake Charles 1 2 5.5 1 2 11.5Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 412 10Response AssetTotalOffshore EDRC76,930Offshore Recovered OilStorage77,700Nearshore / Shallow WaterEDRC40,475Nearshore / Shallow WaterRecovered Oil Storage48,136