Miller. Karen

From:

Sent:

To:

Subject:

Zainey, Robert

Friday, April 01, 2011 11:58 AM

Miller, Karen

N9510,OCS-G16786

From: Peuler, Elizabeth

Sent: Friday, April 01, 2011 11:55 AM

To: Wilson, Susan

Cc: Webb, James L; Wetzel, Nick; Saucier, Michael; Rodi, John; Zainey, Robert; Angelico, Eileen P

Subject: FW: N9510, OCS-G16786

This ernail is to notify you that the following Initial Exploration Plan received March 24, 2010, amended April

5,2010, amended April 8, 2010, modified August 19,2010, amended October 7, 2010, amended October 8,

2010, modified December 9,2010, amended December 22,2010, amended January 13,2011, amended February

17,2011, amended March 9,2011, and amended March 30,2011, has been deemed submitted in accordance

with 30 CFR 250.231(a)and 232(d) as of April 1, 2011:

Control No.: N-9510

Type: Initial Exploration Plan

Lease: OCS-G 16786 Block 738 Green Canyon Area

Operator: BHP Billiton Petroleum Americas Inc.

Activities Proposed: Well A 001

Elizabeth Peuler

Chief, Plans Section, Field Operations

Bureau of Ocean Energy Management, Regulation, and Enforcement (BOEMRE)

Gulf of Mexico Region

504-736-2581 (phone)

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 

H2S 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 & CZM 


BHP 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 Petroleum (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 01-13-2011 
BHP 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 Operations Coordination Documents on the OCS 

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

of Information Demonstrating Adequate Spill Response and Well Containment 

Resources 

 Subpart C for Pollution Prevention and Control 

 Subpart D for Oil and Gas Drilling Operations 

 Subpart E for Oil and Gas Well-Completion Operations 

 Subpart O for Well Control and Production Safety Training 

These regulations may be further clarified by Safety 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 12-07-2010 
BHP 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 39-43o 

 

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

(e) Service Fees

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

(f) Pollution Prevention Measures 

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

familiar with the effluent limitations and guidelines for overboard discharges into the receiving 

waters, as outlined in EPA’s NPDES General Permit GMG290000. 

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

and drains to collect all contaminants and debris to prevent the discharge of oils and greases 

from drilling rigs or platforms during rainfall and routine operations. 

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

performed in a safe and workmanlike conduct in accordance with 30 CFR 250.107 and will 

ensure that our employees and contractor personnel engaged in our offshore drilling operations 

understand the state and federal regulations.

(g) Additional Measures

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 12-07-2010 
BHP 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 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) 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 Base 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 (centipoises) Not Determined 

Viscosity, Kinematic @ 20 C (centistrokes) Not Determined 

Partition Coefficient/n-Octanol/Water 1.69 (OECD117) 

Molecular Weight (g/mole) Not Determined 

Revised 12-07-2010 
BHP 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 12-17-2010 
BHP 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 away, 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 12-17-2010 
BHP 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 12-07-2010 
BHP 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 rates. 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 available containment system. 

Relief Well Arrangements

BHPB has two 5th 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 12-07-2010 
BHP 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 12-07-2010 
BHP 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 was 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 12-07-2010 
BHP 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 H2S while conducting our proposed exploratory 

activities. 

(b) Classification Request

PROPRIETARY DATA

(c) Contingency Plan 

BHPB does not anticipate encountering H2S while conducting our proposed exploratory 

activities therefore a contingency plan is not required at this time. 

(d) Modeling Report

BHPB does not anticipate encountering H2S 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 CONVERSATION INFORMATION

(a) Technology and Reservoir Engineering 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 Plans 
BHP Billiton Petroleum (GOM) Inc. 14 Green Canyon Block 738 

Revision to Initial EP Lease OCS-G 16786 

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

(a) Chemosynthetic Communities Report

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

communities report to cover all high-density deepwater benthic communities (not just highdensity chemosynthetic communities), changed the definition of deepwater from 400 meters 

(1,312 feet) to 300 meters (984 feet), increased the separation distance from muds and cuttings 

discharge locations from 1,500 feet to 2,000 feet and provided for an additional 1,000-foot buffer 

area beyond maximum anchor areas. 

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 Sensitive Biological Features

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

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

Sensitive Underwater Features and Areas” is not required. 

(g) ROV Monitoring Survey Plan

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

Operated Vehicles in Deepwater”. The wells proposed in this 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 and Wildlife Service (USFWS). The cetaceans 

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

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

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

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

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

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

of the northern GOM. 

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

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

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

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

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

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

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

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

need to conserve marine mammals and the conservation of their ecosystems. 

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

Green Canyon Block 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 ft3

 / 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/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 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 02.14.2011 
BHP 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 = 3400D2/3 for CO, and CT = 33.3D for other air 

pollutants (where D = distance to shore in miles)? 

X 

Do your emission calculations include any emission reduction measures or 

modified emission factors? X 

Are your proposed exploration activities located east of 87.5o W longitude? X 

Do you expect to encounter H2S at concentrations greater than 20 parts per 

million (ppm)? 

 

X 

Do you propose to flare or vent natural gas 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 2184.72 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 12-07-2010 
BHP 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. (Company 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 temporary storage, provided by National 

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

and/or NRC Valiant would be available. 
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 Activity1 Exploratory Drilling Exploratory Drilling 

Facility Location (area/block) GC 738 GC 738 

Facility Designation2 Well 001 Well 001 

Distance to Nearest Shoreline (statute miles) 124 124 

Volume3 

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

Type of Oil(s) (crude oil, condensate, 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 scenario volume from the appropriate section of your regional OSRP. For EP’s, the worst-case scenario 

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

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

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

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

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

the activities proposed in our 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 also 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 option 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 substance spill is not required for the activities 

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

the Regional Supervisor of the MMS GOMR for guidance o preparing the report and the MMS 

GOMR would be provided with two copies. 

Revised 12.07.2011 

Revised 02.14.2011 
BHP 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 Minerals 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 seismic 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 will 

ensure that all offshore personnel, including contractors and other support servicesrelated personnel have complete understanding of the requirement that Operators be 

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

NOTE: The Minerals Management Service issued NTL 2007-G04 pursuant to 30 CFR 

250.103, 250.23(o) and 250.204(s) to explain how Operators must implement measures 

to minimize the risk of vessel strikes to protected species and report observations of 

injured or dead protected species effective February 7, 2007. We will ensure that our 

contract vessel operators are aware of their requirement to report sightings of any 

injured or dead protected species immediately to the 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 electromagnetic 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 Environments 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 plans 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 Hydrocarbons Transportation Vessels

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

means other than a pipeline for the activities proposed in this plan. 
BHP Billiton Petroleum (GOM) Inc. 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 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 - 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 transport 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 previously submitted with Plan N-09510 and will not be 

affected by the change of operator (or submitter). 

Revised 12.17.2010 

Revised 02.14.2011 
BHP 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 in 

Fourchon, 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 02.14.2011 
BHP 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). Applicants for an OCS plan submitted to the 

BOEMRE (formerly Minerals Management Service) must provide a certification with necessary 

data and information for the affected State to determine that the proposed activity(s) complies 

with the enforceable policies of each States’ approved program, and that such activity will be 

conducted in a manner consistent with the program. 

(a) Consistency Certification

A Coastal Zone Management Consistency Certification 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 previously submitted with Initial EP (Control No. N09510) and will not be affected by the change of operator (or submitter). 

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

Revision to Initial EP Lease OCS-G 16786 

ADMINISTRATIVE INFORMATION

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

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

exempt from disclosure and has been omitted from the Public Information copy of this plan: 

 The geologic objectives, BHL, TVD, and MD information on form MMS-137 (OCS Plan 

Information Form) in Attachment A 

 All items under Geological and Geophysical Information, except for the non-proprietary 

version of shallow hazards assessment 

 Correlative well information used to justify H2S classification request under Hydrogen 

Sulfide Information 

(b) Bibliography

Initial 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: 1010-0151 

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: 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): 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

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 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 high-probability archaeological area? Yes X No

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

Tentative Schedule of Proposed Activities

Proposed Activity Start Date End Date No. of Days 

Drill Location A 01/01/2011 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

Semisubmersible 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 COPY
OCS PLAN INFORMATION FORM (CONTINUED)

Include one copy of this page for each proposed well / structure

Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name: Well 001 (LOC A) Subsea 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: 2,522,485.00

Y: 9,887,588.00

Latitude/

Longitude

Latitude: 27° 13’ 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 

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

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

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

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

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

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

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

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

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

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

PUBLIC INFORMATION COPY

EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB A

COMPANY BHP Billiton Pet. (GOM) Inc.

AREA Green CanyonBLOCK 738/782LEASE OCS-G 16786 / 15610PLATFORMWELL A

COMPANY CONTACT Susan Wilson / Joshua O'BrienTELEPHONE NO. 713 599 6349 / 713 599 6132REMARKS

rev. 2, 10/4/2010 (Revision) Exploration Wellrev. 2.1, 11/29/2010 (Revision) Exploration Well, Rig change

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 1 of 8
EMISSIONS FACTORS

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

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

Btu/hp-hr 2543.5

Equipment/Emission Factors units PM SOx NOx VOC CO CO2-e [1] REF. DATE

Diesel Turbines lb/MMBtu 0.0203 0.05050 0.88 0.00803 0.0124 163.6 AP-42 3.1-2a & 

Background 3.4-2 04/00

Diesel Recip. < 600 hp. lb/MMBtu 0.31 0.29 4.41 0.36 0.95 163.6 AP-42 3.3-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 0.1835 14 1.12 3.03 AP42 3.3-1 10/96

Diesel Recip. < 600 hp.-EPA Tier 2 [2] 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 % weight

The following equations were used in formulating the conversion factors used in the application package

kW: hp = (kW) x (1.341 hp/kW). Factor = 1.341 hp/kW.

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

[5] Diesel Recip. > 600 hp.-EPA Marine Tier 1: VESSELS: EPA Marine Engine Tier 1 for NOx: 45.0 x N^(-0.20) g/kW-hr, where N is maximum/rated engine rpm. Vessel (Crew) 

maximum rpm is 1,800 per main engine. Vessel (Work) main engines maximum rpm are 1000 rpm, and generators and SDT are 1800 rpm

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

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

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

[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 8
EMISSIONS CALCULATIONS 2010 YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE 

BHP Billiton Pet. (GOM) InGreen Canyon 738/782 OCS-G 16786 / 0 A Susan Wilson / Joshua O'Brien 713 599 6349 / 713 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

Burners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC 

DRILLINGDP PRIME MOVER>600hp diesel [1] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 

Emergency Generator>600hp diesel 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 WIRELINE <600hp diesel-POSU-CA PU Eng./Hydraulic Generator Alt. #2 FMCC Type 2 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 WIRELINE <600hp diesel-Alt. #3 FMCC Type 1 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 CEMENTING <600hp diesel-Batch Mixer[2] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 CEMENTING >600hp diesel [3] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 CEMENTING >600hp diesel [3] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 

ECO VESSELS>600hp diesel(crew) (2-main) [4] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 

VESSELS<600hp diesel(crew) (gen.) 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 

ECO VESSELS>600hp diesel(work) (2-main) [4] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 

2 vessels VESSELS>600hp diesel(work) (2-gen.) [4] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 

VESSELS>600hp diesel(work) (SDT) [4] 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 VESSELS<600hp diesel(work) (Emergency Generator) 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 

PRODUCTION 0 0 0.00 0 0 0.00 0.00 0.00 0.00 

2010 YEAR TOTAL 0.00 0.00 0.00 0.00 

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 

124

[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 mhp/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 conservatmaximum 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.

MMS FORM MMS-138 (December 2008 - Supersedes all previous versions of form MMS-138 which may not be used). Page 3 of 8
EMISSIONS CALCULATIONS 2011 YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE 

BHP Billiton Pet. (GOM) InGreen Canyon 738/782 OCS-G 16786 / 0 A Susan Wilson / Joshua O'Brien 713 599 6349 / 713 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

Burners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC 

DRILLINGDP PRIME MOVER>600hp diesel [1] 38624 1865.54 44772.94 24 95 27.25 15.63 892.79 28.10 

Emergency Generator>600hp diesel 2145 103.60 2486.48 24 95 1.51 0.87 52.02 1.56 WIRELINE <600hp diesel-POSU-CA PU Eng./Hydraulic Generator Alt. #2 FMCC Type 2 300 14.49 347.76 24 95 0.66 0.12 9.26 0.74 WIRELINE <600hp diesel-Alt. #3 FMCC Type 1 300 14.49 347.76 24 95 0.66 0.12 9.26 0.74 CEMENTING <600hp diesel-Batch Mixer[2] 250 12.08 289.80 24 95 0.55 0.10 2.63 0.62 

CEMENTING >600hp diesel [3] 860 41.54 996.91 24 95 0.61 0.35 13.86 0.63 CEMENTING >600hp diesel [3] 860 41.54 996.91 24 95 0.61 0.35 13.86 0.63 

ECO VESSELS>600hp diesel(crew) (2-main) [4] 4520 218.32 5239.58 24 95 3.19 1.83 74.68 3.29 

VESSELS<600hp diesel(crew) (gen.) 165 7.97 191.27 24 95 0.36 0.07 5.09 0.41 

ECO VESSELS>600hp diesel(work) (2-main) [4] 13196 637.37 15296.80 24 95 18.62 10.68 490.45 19.20 

2 vessels VESSELS>600hp diesel(work) (2-gen.) [4] 8000 386.40 9273.60 24 95 11.29 6.47 264.35 11.64 

VESSELS>600hp diesel(work) (SDT) [4] 2200 106.26 2550.24 24 95 3.10 1.78 72.70 3.20 VESSELS<600hp diesel(work) (Emergency Generator) 502 24.22 581.38 24 95 1.11 0.20 15.48 1.24 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 

PRODUCTION 0 0 0.00 0 0 0.00 0.00 0.00 0.00 

2011 YEAR TOTAL 69.52 38.56 1916.42 71.99 

EXEMPTION 

CALCULATION DISTANCE FROM LAND IN MILES 

124

[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 mhp/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 conservatmaximum 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.

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

COMPANY AREA BLOCK LEASE PLATFORM WELL

BHP Billiton Pet.Green Canyon 738/782 OCS-G 16786 / 15610 0 A

Emitted Substance

Year

 PM SOx NOx VOC CO

2010 0.00 0.00 0.00 0.00 0.00

2011 79.25 43.96 2184.72 82.07 487.70

Allowable 4129.20 4129.20 4129.20 4129.20 84546.06

MMS FORM 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 BHPB 00 HS PPR 0001 00 

PUBLIC INFORMATION COPY
SPILL RESPONSE DISCUSSION 

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

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

be 28,000 barrels of crude oil with 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 results are shown in Figure 1. The BOEM OSRAM 

identifies a 3% probability of impact to the shorelines of Cameron Parish and/or Plaquemines Parish, 

Louisiana within 30 days. Cameron Parish includes the east side of Sabine Lake, Sabine National 

Wildlife Refuge, Calcasieu Lake, Lacassine National Wildlife Refuge (inland) and Grand Lake. 

Cameron Parish also includes the area along the coastline from Sabine Pass to Big Constance Lake 

in Rockefeller Wildlife Refuge. This region is composed of open public beaches, marshlands and 

swamps. It serves as a habitat for numerous birds, finfish and other animals, including several rare, 

threatened and endangered species. Plaquemines Parish includes Barataria Bay, the Mississippi 

River Delta, Breton Sound and the affiliated islands and bays. This region is an extremely sensitive 

habitat and serves as a migratory, breeding, feeding and nursery habitat for numerous species of 

wildlife. Beaches in this area vary in grain particle size and can be classified as fine sand, shell or 

perched shell beaches. Sandy and muddy tidal flats are also abundant. 

Response

BHP Billiton Petroleum (Americas) Inc. will make every effort to respond to the Worst Case 

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

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

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

was run on a similar product from the ADIOS oil database. The results indicate 19% or 5,320 barrels 

of crude oil would be evaporated/dispersed within 24 hours, with 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, materials and support vessels as well as temporary storage 

equipment available to respond to a spill of 28,000 barrels The list estimates individual times needed 

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

operations will be supported. 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
If aerial dispersants are utilized, 8 sorties (9,600 gallons) from two of the DC-3 aircrafts and 4 sorties 

(8,000 gallons) from the Basler aircraft should disperse approximately 7,540 barrels of product. If the 

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

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

Deepwater Horizon spill of 2010, up to 5% or 1,400 barrels of the total daily Worst Case Discharge 

volume could be burned. Slick containment boom would be immediately called out and on-scene as 

soon as possible. Offshore response strategies may include attempting to skim utilizing the HOSS 

Barge 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 barges may be mobilized. Safety is first priority. 

Air monitoring will be accomplished and operations deemed safe prior to any 

containment/skimming attempts. 

If the spill went unabated, shoreline impacts in either Cameron Parish and/or Plaquemines Parish, 

Louisiana would depend upon existing environmental conditions. Shoreline protection would include 

the use of CGA’s near shore and shallow water skimmers with a totaled derated skimming capacity 

of 40,475 barrels. Temporary storage associated with skimming equipment equals 1,636 barrels. If 

additional storage is needed, one 24,000 barrel storage 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 vegetated 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 that environmental and 

special economic resources would be correctly identified and prioritized to ensure optimal protection. 

Shoreline protection strategies depict the protection response modes applicable for oil spill clean-up 

operations. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline 

protection strategies for this area, and it describes necessary action to keep the oil spill from 

entering Louisiana’s coastal wetlands, based on the assumption that removal of the released oil will 

be much easier and less damaging to fragile coastal ecosystems if done in the open waters of the 

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

equipment allowing a more effective response to site-specific circumstances. BHP Billiton Petroleum 

(Americas) Inc.’s contract Spill Management Team holds a copy of the State of Louisiana Initial Oil 

Spill Response Plan. 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
FIGURE 1 

TRAJECTORY BY LAND SEGMENT 

Trajectory of a spill and the probability of it impacting a land segment have been projected utilizing 

BHP Billiton Petroleum (Americas) Inc.’s WCD and information in the BOEM Oil Spill Risk Analysis 

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

30 day impact. The results are tabulated below. 

Area/Block OCS-G Launch 

Area 

Land Segment and/or 

Resource 

Conditional 

Probability (%) within 

30 days 

Green Canyon 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 

1 

1 

3 

ATTACHMENT E 

SPILL RESPONSE DISCUSSION FOR NEPA & CZM
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (124 miles from shore) 

28,000 bbls of crude oil API Gravity 26.8° 

FIGURE 2 – Equipment Response Time to Green Canyon 738 

Dispersants/Surveillance 

Dispersant/Surveillance 

Dispersant 

Capacity 

(gal) 

Storage 

Capacity

Persons 

Req. From Hrs to Procure Hrs to Loadout Travel to sit

Basler 67T 2000 NA 2 Houma 1 1 0.9 DC 3 1200 NA 2 Houma 1 1 1.2 DC 3 1200 NA 2 Houma 1 1 1.2 Aero Commander NA NA 2 Houma 1 1 0.9 

Offshore Response 

Offshore Equipment No 

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

t

HOSS Barge 43000 4000 3 Tugs 8 Houma 4 0 5 

Recovered Oil Storage 

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

CTCo 2404 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2601 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2602 NA 24000 1 Tug 6 Amelia 4 0 4 
Staging Area: Venice 

Offshore Equipment With 

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

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 8 FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 3 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 11 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 5.5 FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6 Venice 1 2 0 

Offshore Equipment 

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

42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2 42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 42” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 2 3 42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 

Nearshore Response 

Nearshore Equipment 

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

t

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

Oil Storage No Staging EDRC 

Storage 

Capacity 

(bbl) 

VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

CTCo 2603 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2604 NA 22500 1 Tug 6 Amelia 4 0 4 

Staging Area: Venice 

Nearshore and Inland 

Skimmers With 

Staging 

EDRC Storage Capacity VOO Persons Req. From Hrs to Procure 

Hrs 

to 

Load 

Out 

Travel to 

Staging 

Trav

Deplo

Si

SWS Egmopol 3000 100 NA 3 Galveston 1 2 8 2 SWS Egmopol 3000 100 NA 3 Houma 1 2 3 2 SWS Marco 3588 34 NA 3 Venice 1 2 0 2 SWS Marco 3588 34 NA 3 Houma 1 2 3 2 SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 2 Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 1 2 5.5 2 Foilex Skim Package (TDS 150) 891 45 NA 3 Houma 1 2 3 2 4 Drum Skimmer (Magnum 100) 686 NA NA 3 Lake Charles 1 2 5.5 2 4 Drum Skimmer (Magnum 100) 686 NA NA 3 Houma 1 2 3 2 2 Drum Skimmer (TDS 118) 240 NA NA 3 Lake Charles 1 2 5.5 2 2 Drum Skimmer (TDS 118) 240 NA NA 3 Houma 1 2 3 2 Rope Mop 77 2 0 3 Belle Chasse 1 2 2 2 RO Storage Barge NA 249 Towed 0 Galveston 1 2 8 2 RO Storage Barge NA 249 Towed 0 Houma 1 2 3 2 RO Storage Barge NA 249 Towed 0 Lake Charles 1 2 5.5 2 RO Storage Barge NA 249 Towed 0 Venice 1 2 0 2 
Shoreline Protection 

Staging Area: Fourchon 

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

Dep

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

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

Hrs 

to 

Load 

Out 

Travel to 

Staging 

Trav

Deplo

S

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

Response Asset Total 

Offshore EDRC 76,930 Offshore Recovered Oil Storage 77,700 Nearshore / Shallow Water EDRC 40,475 Nearshore / Shallow Water Recovered Oil Storage 48,136