SUPPLEMENTAL EXPLORATION PLAN

S-7570

ANADARKO PETROLEUM CORPORATION 

KEATHLEY CANYON BLOCKS 875 & 919 

OCS-G 21444 & 21447 

PUBLIC COPY 

RECORD OF CHANGE LOG 

Submission

Type

Date Sent to 

BOEMRE 

Summary of 

Submission

Page

Numbers

Initial 6/20/2012 Initial plan submittal All 

Amendment 7/3/2012 Change plan type to 

supplemental 

All

Amendment 7/10/2012 Change rig type info 4 

Amendment 7/31/2012 Change proposed rig 

types

4

Amendment 7/31/2012 Change Activity 

Schedule

7

Amendment 7/31/2012 Clarify drilling fluid info 15 

Amendment 7/31/2012 Revise Waste Tables 58-60, 99-100, 

102-103

Amendment 7/31/2012 Revise AQR Tables 61-80 

Change of Record 

Log

8/22/2012 Change of Record Log 1 

Final Copy of Plan 8/22/2012 Complete Final EP 

Submittal 

All
PUBLIC

SUPPLEMENTAL EXPLORATION PLAN

KEATHLEY CANYON BLOCKS 875 & 919 

OCS-G 21444 & 21447 

OFFSHORE, LOUISIANA

Anadarko Petroleum Corporation 

1201 Lake Robbins Drive 

The Woodlands, Texas 77380 

Contact: Jill Fowler 

jill.fowler@anadarko.com 

(832) 636-1554 

1 – Hard Copy Confidential 

1 – CD Confidential 

1 – Hard Copy Public Information 

3 – CDs Public Information

June, 2012 
SUPPLEMENTAL EXPLORATION PLAN 

LEASE OCS-G 21444 & 21447 

KEATHLEY CANYON BLOCKS 875 & 919 

 A. Plan Contents 

 B. General Information 

 C. Geological, Geophysical 

D. Hydrogen Sulfide Information 

 E. Biological, Physical and Socioeconomic Information 

F. Wastes and Discharge Information 

 G. Air Emissions Information 

 H. Oil Spill Information 

I. Environmental Monitoring Information 

 J. Lease Stipulations 

 K. Support Vessels and Aircraft Information 

 L. Onshore Support Facilities Information 

M. Coastal Zone Management Act Information 

N. Environmental Impact Analysis 

O. Administrative Information 
A

PLAN CONTENTS

(a) Plan Information Form 

Under this Supplemental Exploration Plan, Anadarko Petroleum Corporation (Anadarko) proposes to drill and 

complete six wells total in Keathley Canyon Blocks 875 & 919. The KC 919 AA, BB, CC, DD, and EE, and KC 

875 I wells will be drilled using a DP Semisubmersible drilling rig. Drilling and completion operations for all well 

locations will utilize a Subsea BOP stack. OCS Plan Information Form MMS-137 is enclosed as Attachment A-1. 

The activity schedule within the OCS Plan Information Form BOEM-137 of this Supplemental Exploration Plan 

reflects Anadarko’s current plans to conduct activities with respect to leases OCS-G 21444 & 21447, Keathley 

Canyon Blocks 875 & 919. Previously approved, undrilled well locations from Plan Control No.’s N-9428 and S9593 are being carried forward in the activity schedule to reflect Anadarko’s current planning schedule for drilling 

and completion activities within Keathley Canyon Blocks 875 & 919. 

(b) Location 

Enclosed as Attachment A-2 is a well location plat at a scale of 1 inch = 2000 feet that depicts the surface locations 

and water depth of the proposed wells. 

(c) Safety and Pollution Prevention Features 

Safety features on the drilling unit will include well control, pollution prevention, safe welding procedures, and 

blowout prevention equipment as described in Title 30 CFR Part 250, Subparts C, D, E, G and O; and as further 

clarified by BOEM Notices to Lessees, and applicable regulations of the Environmental Protection Agency and the 

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

will be maintained on the facility at all times. 

(d) Storage Tanks and Production Vessels 

The proposed wells will be drilled using a DP Semisubmersible drilling rig. 

Type of Facility Type Of Storage 

Tank

Tank

Capacity

Number 

Of Tanks 

Total

Capacity

Fluid 

Gravity 

(Api)

Total Capacity 

of all Tanks 

for Rig Type 

DP Semi Fuel Oil Hull 

Tanks

4,541 bbls 2 9,082 bbls No. 2 Diesel 7 tanks total= 

16,689 bbls 

 Fuel Oil Hull 

Tanks

3,392 bbls 2 6,784 bbls No. 2 Diesel 

 Fuel Oil Deck Day 

Tank 

629 bbls 1 629 bbls No. 2 Diesel 

 Fuel Oil Deck 

Settling Tank 

164 bbls 1 164 bbls No. 2 Diesel 

 Fuel Oil 

Emergency 

Generator

30 bbls 1 30 bbls No. 2 Diesel 
(e) Pollution Prevention Measures 

The drilling rig utilized for these operations will comply with all applicable regulations regarding 

pollution prevention and control. The rig has a Shipboard Oil Pollution Emergency Plan 

(SOPEP), which is reviewed and approved annually by the American Bureau of Shipping (ABS). 

The SOPEP is provided to assist employees in dealing with an unexpected discharge of oil. Its 

primary purpose is to set in motion the necessary actions to stop or minimize the discharge of oil 

and to mitigate its effects. Effective planning ensures that the necessary actions are taken in a 

structured, logicalm and timely manner. 

Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on deck 

areas to collect all contaminants and debris. Most deck drains and some of the joints at the edge 

of the rig floor go overboard or into the moonpool, respectively. To prevent ocean discharge 

from the drains there is a dedicated drip pan under the rotary table. The pipe racks, mud pump 

room, sack store, and drill floor drains go to a holding tank, which is served by a dedicated oily 

water separator. The well test area, engine room, and other major machinery spaces drains all go 

to slops tanks, which are served by a large general-service, oily water separator. The containment 

devices are temporary. They are not meant for permanent storage of waste. On the rare occasion 

that they contain wastes, they are pumped, mopped, or cleaned within a short period of time. The 

chances of damage to a containment structure during such time as it contains wastes are 

exceedingly small. 

(f) Additional Pollution Prevention Measures 

No additional measures are proposed under this plan. The activities proposed in this plan are not 

located offshore Florida. 
(g) Description of Previously Approved Lease Activities 

Anadarko has no previously approved well locations in Keathley Canyon Block 919. Approval 

was granted on September 8, 2009 to drill and complete KC 875 well locations “A & B” under 

the Initial Exploration Plan for Keathley Canyon Block 875 (Plan Control No. N-9428). A 

Supplemental Exploration Plan (Plan Control No. S-9593) was approved on November 17, 2011 

for KC 875 well locations “D, F, G, & H”: 

Plan

Control

No.

Well

Location

Status of Well Location Potential Future 

Operations

N-9428 A Location was used to drill well #SS001 

ST01. The well is currently shut-in. 

Place on production. 

N-9428 B Location was used to drill well #SS002. 

The well is currently temporarily 

abandoned.

Plan to re-enter and bypass 

well. 

S-9593 D Approved well location for future utility. Future drill location. 

S-9593 F Approved well location for future utility. Future drill location.

S-9593 G Approved well location for future utility. Future drill location.

S-9593 H Approved well location for future utility. Future drill location.

The following reflects Exxon Mobile Corporation’s previously approved activities in Keathley 

Canyon Block 919: 

Plan

Control

No.

Well

Location

Status of Well Location Potential Future 

Operations

N-8115 A Location was drilled in 2004. Place on production. 

N-8115 B Approved well location for future utility. Future drill location. 

S-7330 C Location was drilled in 2010. Well is P&A’d. 

S-7330 D Approved well location for future utility. Future drill location.

S-7330 E Location was spud in 2012 and is 

currently drilling.

Place on production.

S-7330 F Location was drilled in 2011. Place on production.
MMS FORM MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) Page 1 of 5 

U.S. Department of the Interior 

Minerals Management Service OCS PLAN INFORMATION FORM 

OMB Control Number: 1010-0051 

OMB Approval Expires: July 31, 2008 

General Information 

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

Company Name: Anadarko Petroleum Corporation MMS Operator Number: 00981 

Address: 1201 Lake Robbins Drive Contact Person: Jill Fowler 

 The Woodlands, TX 77380 Phone Number: (832) 636-1554 

 E-Mail Address: Jill.fowler@anadarko.com 

Lease(s): G21444 & G21447 Area: KC Block(s): 875 & 919 Project Name (If Applicable): Lucius 

Objective(s): x Oil x Gas Sulphur Salt Onshore Base: Fourchon, LA Distance to Closest Land (Miles): 213 

Description of Proposed Activities (Mark all that apply) 

x Exploration drilling Development drilling 

x Well completion Installation of production platform 

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

Installation of caisson or platform as well protection structure Installation of satellite structure 

x Installation of subsea wellheads and/or manifolds 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? Yes x No

Tentative Schedule of Proposed Activities 

Proposed Activity Start Date End Date No. of Days 

Drill KC 919 AA 02-21-2013 03-21-2013 29 

Drill KC 919 BB 03-22-2013 04-30-2013 40 

Complete KC 919 AA 07-23-2013 09-05-2013 45 

Complete KC 919 BB 12-05-2013 01-18-2014 45 

Drill and Complete KC 919 CC 04-19-2014 09-01-2014 135 

Drill and Complete KC 919 DD 01-01-2015 05-16-2015 135

Drill and Complete KC 919 EE 05-17-2015 09-29-2015 135 

Drill and Complete KC 875 I 01-01-2016 05-15-2016 135 

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): Spar Other (Attach Description) 

Description of Lease Term Pipelines 

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

 
MMS FORM MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) Page 2 of 5 

OCS PLAN INFORMATION FORM 

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): 

AA 

Subsea Completion 

Anchor Radius (if applicable) in feet: 

N/A; DP rig used x Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. 

OCS-G 21444 

Area Name 

Keathley Canyon 

Block No. 

875 

Blockline 

Departures 

(in feet) 

N/S Departure: 1837’FSL 

E/W Departure: 4598’FWL 

Lambert X-Y 

coordinates X: 1,952,917.52 

Y: 9,474,156.99 

Latitude/ 

Longitude Latitude 26.10709 

Longitude 92.04741 

 Water Depth (Feet): 6900’ 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name 

or No. 

Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

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 250.196. 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 hours per response,

or 640 with an accompanying EP, or 690 with an accompanying DP 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 4230, Minerals 

Management Service, 1849 C Street, N.W., Washington, DC 20240. 
MMS FORM MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) Page 3 of 5 

OCS PLAN INFORMATION FORM 

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): 

BB

Subsea Completion 

Anchor Radius (if applicable) in feet: 

N/A; DP rig used x Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. 

OCS-G 21444 

Area Name 

Keathley Canyon 

Block No. 

875 

Blockline 

Departures 

(in feet) 

N/S Departure: 585’FSL 

E/W Departure: 2540’FWL 

Lambert X-Y 

coordinates X: 1,950,860.09 

Y: 9,472,904.95 

Latitude/ 

Longitude Latitude 26.10369 

Longitude 92.05371 

 Water Depth (Feet): 6825’ 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name 

or No. 

Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

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 250.196. 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 hours per response,

or 640 with an accompanying EP, or 690 with an accompanying DP 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 4230, Minerals 

Management Service, 1849 C Street, N.W., Washington, DC 20240. 
MMS FORM MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) Page 4 of 5 

OCS PLAN INFORMATION FORM 

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): 

CC

Subsea Completion 

Anchor Radius (if applicable) in feet: 

N/A; DP rig used x Yes No 

Surface Location 

Lease No. 

OCS-G 21444 

Area Name 

Keathley Canyon 

Block No. 

875 

Blockline 

Departures 

(in feet) 

N/S Departure: 610’FSL 

E/W Departure: 2587’FWL 

Lambert X-Y 

coordinates X: 1,950,907.02 

Y: 9,472,929.74 

Latitude/ 

Longitude Latitude 26.10375 

Longitude 92.05357 

 Water Depth (Feet): 6825’ 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name 

or No. 

Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

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 250.196. 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 hours per response,

or 640 with an accompanying EP, or 690 with an accompanying DP 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 4230, Minerals 

Management Service, 1849 C Street, N.W., Washington, DC 20240. 
MMS FORM MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) Page 5 of 5 

OCS PLAN INFORMATION FORM 

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): 

DD 

Subsea Completion 

Anchor Radius (if applicable) in feet: 

N/A; DP rig used x Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. 

OCS-G 21444 

Area Name 

Keathley Canyon 

Block No. 

875 

Blockline 

Departures 

(in feet) 

N/S Departure: 699’FSL 

E/W Departure: 4806’FWL 

Lambert X-Y 

coordinates X: 1,953,126.49 

Y: 9,473,019.39 

Latitude/ 

Longitude Latitude 26.10396 

Longitude 92.04680 

 Water Depth (Feet): 6825’ 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name 

or No. 

Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

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 250.196. 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 hours per response,

or 640 with an accompanying EP, or 690 with an accompanying DP 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 4230, Minerals 

Management Service, 1849 C Street, N.W., Washington, DC 20240. 
MMS FORM MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) Page 6 of 5 

OCS PLAN INFORMATION FORM 

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): 

EE 

Subsea Completion 

Anchor Radius (if applicable) in feet: 

N/A; DP rig used x Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. 

OCS-G 21444 

Area Name 

Keathley Canyon 

Block No. 

875 

Blockline 

Departures 

(in feet) 

N/S Departure: 708’FSL 

E/W Departure: 4901’FWL 

Lambert X-Y 

coordinates X: 1,953,220.95 

Y: 9,473,028.04 

Latitude/ 

Longitude Latitude 26.10398 

Longitude 92.04651 

 Water Depth (Feet): 6830’ 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name 

or No. 

Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

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 250.196. 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 hours per response,

or 640 with an accompanying EP, or 690 with an accompanying DP 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 4230, Minerals 

Management Service, 1849 C Street, N.W., Washington, DC 20240. 
MMS FORM MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) Page 7 of 5 

OCS PLAN INFORMATION FORM 

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): 

I

Subsea Completion 

Anchor Radius (if applicable) in feet: 

N/A; DP rig used x Yes No 

Surface Location Bottom-Hole Location (For Wells) 

Lease No. 

OCS-G 21444 

Area Name 

Keathley Canyon 

Block No. 

875 

Blockline 

Departures 

(in feet) 

N/S Departure: 1766’FSL 

E/W Departure: 4668’FWL 

Lambert X-Y 

coordinates X: 1,952,988.22 

Y: 9,474,086.26 

Latitude/ 

Longitude Latitude 26.10689 

Longitude 92.04720 

 Water Depth (Feet): 6900’ 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name 

or No. 

Area Block X Coordinate Y Coordinate Length of Anchor 

Chain on Seafloor 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

 X = Y = 

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 250.196. 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 hours per response,

or 640 with an accompanying EP, or 690 with an accompanying DP 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 4230, Minerals 

Management Service, 1849 C Street, N.W., Washington, DC 20240. 
Well Name Loc X Coordinate (ft) Y Coordinate (ft) Latitude Longitude Water Depth

KC 919 "AA" SFL 1,837' FSL 4,598 FWL 1952917.52 9474156.99 26.10709 -92.04741 -6900

KC 919 "BB" SFL 585' FSL 2,540' FWL 1950860.09 9472904.95 26.10369 -92.05371 -6825

KC 919 "CC" SFL 610' FSL 2,587' FWL 1950907.02 9472929.74 26.10375 -92.05357 -6825

KC 919 "DD" SFL 699' FSL 4,806' FWL 1953126.49 9473019.39 26.10396 -92.04680 -6825

KC 919 "EE SFL 708' FSL 4,901' FWL 1953220.95 9473028.04 26.10398 -92.04651 -6830

KC875 "I" SFL 1,766' FSL 4,668' FWL 1952988.22 9474086.26 26.10689 -92.04720 -6900

Footages
B

GENERAL INFORMATION 

(a) Applications and Permits 

Prior to beginning exploration operations the following application(s) will be submitted for approval: 

Application/Permit Issuing Agency Status 

Permits to Drill BSEE To be submitted 

(b) Drilling Fluids 

Type of Drilling Fluid Estimated Volume Per Well 

Water-based (NaCl saturated, seawater, 

freshwater, barite) for Pump and Dump 

18,000 bbls per well* 

Synthetic-based (internal olefin, ester) 11,000 bbls per well 

Oil-based NA 

*The actual volume ordered out will be an estimated 18,000 bbls/well of mud. Once on location this 

volume will be cut back and mixed with seawater to different desired mud weights which will increase the 

volume that is discharged at the seafloor. The estimated volume that will be discharged at the seafloor 

will be approximately 60,000 bbls/well. 

(c) New or Unusual Technology 

Anadarko does not propose to use any new or unusual technology to drill the wells proposed in this plan. 

(d) Bonding Statement 

The bond requirements for the activities and facilities proposed in this EP are satisfied by an area-wide 

bond furnished and maintained according to 30 CFR part 256, subpart I; NTL No. 2000-G16, “Guidelines 

for General Lease Surety Bonds,” and National NTL No. 2008-N07, “Supplemental Bond Procedures”. 

(e) Oil Spill Financial Responsibility (OSFR) 

Anadarko Petroleum Corporation (Company Number 00981) has demonstrated oil spill financial 

responsibility for the facilities proposed in this EP according to 30 CFR Part 253, and NTL No. 2008-

N05, “Guidelines for Oil Spill Financial Responsibility for Covered Facilities”. 

(f) Deepwater Well Control Statement 

Anadarko Petroleum Corporation (Company Number 00981) has the financial capability to drill a relief 

well and conduct other emergency well control operations if required. 

(g) Blowout Scenario

Anadarko prepared this blowout scenario pursuant to guidance provided in NTL No. 2010-N06. Keathley 

Canyon Block 919 Location “F” is addressed in this blowout scenario since it is the location with the 

highest potential worst case discharge (WCD). The Keathley Canyon Block 919 Location “F” WCD 
volume was approved under Exxon Mobile Corporation’s Revised Exploration Plan (Plan Control No. R5106). A similar approach would be taken in the event of a blowout for the wells covered under this plan 

in Keathley Canyon Blocks 875 & 919. Based on NTL No. 2010-N06 guidance, the maximum 

hydrocarbon discharge for Keathley Canyon Block 919 Location “F” is calculated to be 252,000 BOPD. 

Purpose

This information provides a generic blowout scenario, additional information regarding any potential oil 

spill, and the measures Anadarko Petroleum will take to prevent a blowout and if necessary promptly 

respond to manage a blowout scenario if one occurs. The following information is pursuant with 30 CFR 

250.213(g), 250.219, 250.250 and NTL No. 2010-N06. 

Background

Anadarko prepared this blowout scenario pursuant to guidance provided in NTL No. 2010-N06. Keathley 

Canyon Block 919 Location “F” is addressed in this blowout scenario since it is the location with the 

highest potential worst case discharge (WCD). The Keathley Canyon Block 919 Location “F” WCD 

volume was approved under Exxon Mobile Corporation’s Revised Exploration Plan (Plan Control No. R5106). A similar approach would be taken in the event of a blowout for the wells covered under this plan 

in Keathley Canyon Blocks 875 & 919. Based on NTL No. 2010-N06 guidance, the maximum 

hydrocarbon discharge for Keathley Canyon Block 919 Location “F” is calculated to be 252,000 BOPD. 

These wells will evaluate objectives similar to those seen by the recent Lucius and Hadrian discoveries. 

This scenario has been developed to document the additional information requirements for Exploration 

Plans as requested by NTL No. 2010-N06. 

Information Requirements: 

Blowout scenario 

The objective is drilled utilizing a MODU rig with a marine riser and sub-sea BOP. A typical sub-sea 

wellhead system, conductor, surface and intermediate casing program will be used. A hydrocarbon 

influx occurs, followed by a well control event from the objective sands. The sub-sea BOP and marine 

riser fails and a blow-out at the seabed occurs. The WCD scenario assumes 12 1⁄4” open hole below salt to 

a 9 7/8” casing point (but casing is not set). 

Estimated flow rate of the potential blowout 

Category Initial EP 

Type of Activity Exploratory Drilling 

Facility Location (area/block) KC 919 

Facility Designation MODU 

Distance to Nearest Shoreline (miles) 213 miles 

Uncontrolled blowout (volume per day) 252,000 bbl 

Type of Fluid(s) Crude 
a) Potential for the well to bridge over:

Formation collapse and bridging is expected in a blowout scenario, sanding would occur 

quickly, perhaps within hours. Complete bridging is expected within four days.

Discussions regarding geologic information are considered proprietary and have been omitted 

from this section of the public copy EP. 

b) Measures to enhance the ability to conduct effective and early intervention in the event of a 

blowout:

The likelihood of surface intervention to stop a blowout is high and is based on the following 

equipment specific to the MODU that has been contracted to do this drilling program: 

x ROV Secondary BOP Control System: The BOP is confirmed to have a ROV 

Intervention Panel and circuits that have the following attributes:

 Hot stab is capable of closing one set of: 

x Blind-Shear Rams – One Set

x Pipe Rams – One Set

x Unlatch the Lower Marine Riser Package

 Hot stab have been function tested in conjunction with the Stump test 

and were tested at the same rate and pressure as the pump installed on 

the ROV used by the rig. 

The panels could also be operated by an ROV from an independent supply 

boat in the event of a loss of rig scenario. 

x Deadman / Autoshear function: The rig is equipped with an automated 

sequence that closes the blind shear rams in the event of any of the following 

scenarios:

x Inadvertent disconnect of the LMRP 

x Loss of both hydraulic pressure and electrical supply from the 

surface BOP control system 

 No human interface is required once these systems are armed. 

c) Availability of a rig to drill a relief well: 

Per the preliminary Mutual Aid agreements that are being worked between E&P Operators in the 

Gulf of Mexico, Anadarko will select from the best rig option available in the Gulf of Mexico 

fleet if and when it is required for relief well work. As of June 12, 2012 there were over 12 

additional rigs capable of operating under these conditions in the Gulf of Mexico. A rig which 

could be used to drill a relief well is the Transocean Discoverer Clear Leader which is a drill ship 

capable of drilling in 12,000’ of water without any constraints. The rig is currently under contract 

to Chevron and is on location at Walker Ridge Block 758. 

There are no nearby platforms from which to drill a relief well. 

It is not feasible to drill a relief well from land. 

d) Rig constraints: 

A rig capable of drilling in 7200 ft of water with a 15k Stack is required for any relief well 

operations. The Transocean Discoverer Clear Leader drill ship meets these requirements. 
e) Time taken to mobilize a rig and drill a relief well: 

An estimate of 7-21 days is required to suspend operations on a deepwater GOM well and begin 

drilling the relief well. This assumes 0-14 days to suspend current operations on an existing well 

and 7 days to mobilize and be ready to spud the relief well. The estimated time to drill the relief 

well is 55 days for an estimated total of 62-76 days from time of blowout to finishing the relief 

well. The drilling days were based on actual days required to drill the KC 875 #1, KC875 #1 ST, 

and KC 875 #2 wells through the objective sand (interval of WCD) with additional time added for 

ranging. 

The time estimate provided for the plan well is inclusive of 'both' drilling 'and' completion 

operations. As a completion is not typically part of relief well operations no time has been 

included for completion operations in the relief well estimate. Therefore the estimated time for a 

relief well should be less than for the plan well. In addition, information and learning from the 

drilling of the original well may provide opportunities to optimize drilling performance for relief 

well operations and thus reduce the required drilling time. 

f) Assumptions and calculations used in approved or proposed Oil Spill Response Plan: 

x Petroleum Experts “Prosper” software was used to estimate the WCD. The WCD was 

calculated to be 252,000 BOPD. 

x At the seafloor, the estimated worst case discharge used for the well is 252,000 BOPD based 

on the objective interval. 

x The maximum total volume during a blowout could potentially be 19,152,000 bbls assuming 

76 days for the maximum duration of a blowout, multiplied by the worst case daily 

uncontrolled blowout volume of 252,000 bbl. 

g) Measures taken to reduce the likelihood of a blow-out 

x Well design: Anadarko utilizes a systematic well design process for the planning and 

construction of a well operation. This process taps into the vast depth of experience 

Anadarko possesses in the Deepwater arena and involves a multi-team peer review of the 

well design, shallow hazards, and formation pressure hazards expected during drilling. This 

process minimizes the potential for an unplanned well control event that could lead to a 

blowout. This process will also include a Professional Engineer review and approval of the 

final casing design and cementing program. A detailed pre-drill assessment of formation 

pressure provided by Anadarko’s Geologic/Geophysical team along with 3rd party consultants 

allows for a mud program that provides an overbalanced mud weight for the safe drilling of 

the well. For an exploration well this may also include taking formation pressures to confirm 

the actual formation pressure during the well construction process and minimize the risk of an 

unplanned well control event. The pore pressure environment is understood due to the nearby 

offset wells, the KC 875#1, KC 875 #1 ST1, KC 875 #2,. KC 919 #3. 

The well construction process also requires a systematic review and management acceptance 

of the start-up preparation work for the rig and crews and the third party technical audit work 

on the rig and the rig’s well control equipment. This measures the rig’s ability to handle an 

unplanned well control event and provide assurance that the rig can successfully mitigate a 

loss of well control event and prevent it from becoming a blowout scenario. 
x Barrier Philosophy: For all well designs, Anadarko requires and uses a redundant barrier 

philosophy, that being two independent barriers for both internal and external flow paths in 

the final wellbore. It is also standard practice to conduct pressure testing, in accordance with 

the law, to confirm integrity on all relevant barriers. In addition, all intermediate and 

production casings returned to the wellhead will be locked down before subsequent wellbore 

construction is proceeded with. 

x BOP and well control equipment: The rig will have an 18-3/4” 15k psi BOP with primary 

and secondary BOP control systems. Prior to commencement of operations, an independent 

third party verification will be obtained that the subsea BOP is designed for the specific 

equipment on the rig and this specific well design 250.416(f) 

x BOP and well control equipment testing: To ensure effectiveness of the BOP and well 

control equipment, a testing program will be conducted prior to running the BOP and then 

during the well operations. This testing program will provide compliance with current 

federal regulations for pressure and function testing and will also provide periodic assurance 

on the performance of both primary and secondary BOP control systems including actual 

interface operations with the ROV and the ROV panel 

x Well control training and drills: Anadarko requires that key nominated onshore and offshore 

positions including rig contractor personnel hold a WellCAP or equivalent well control 

training certificate, renewable every two years for the type of floating drilling operation being 

conducted. Anadarko also monitors compliance for its personnel with the federal regulations 

and Sub-Part O for well control training. 

x A comprehensive program of well control drills will be conducted offshore to ensure readiness 

to identify and then manage a well control situation and thereby minimize the potential for a 

well control event to lead to a blowout scenario. 

h) Arrangements for drilling a relief well 

x Anadarko maintains a master agreement with ‘Wild Well Control’ for advice, management, 

engineering, well kick pre and post modeling and resource support for an unplanned loss of 

well control event. In the event of any well control event, Wild Well Control would be 

contacted and mobilized if required to support Anadarko’s operational team both in the 

onshore and offshore locations. 

x The conceptual relief well design is similar to the design of the KC 874 # 1, in that casing 

weights, grades and setting points would be identical. A two block wide shallow hazard 

assessment has been completed (and submitted) for KC 919 and KC 875. Site Clearance 

letters for surface locations in both blocks have been completed and deemed acceptable for 

drilling. Furthermore, the potential areas for high density chemo-synthetic communities in the 

study area have been identified and can be avoided. Depending on the nature of the blowout 

scenario, well geometry, and total depth required to intersect the blowout, previously 

submitted surface locations and/or additional surface locations would be submitted and all 

reviewed for best suitability for the location of the relief well. 

x Anadarko’s philosophy is to carry adequate inventory in stock to drill a complete well(s) from 

surface to TD. Back-up long lead equipment equivalent to the original well design will be 

carried in stock to allow a rapid response. This includes a spare deepwater sub-sea wellhead 
system and the large OD casing (36”, 28”, 22”, 13 7/8”, 11 7/8”, and 9 7/8”) and connectors 

required for the first part of the well. Smaller OD casing is considered widely available on 

the ground in the GOM and would be resourced out of existing inventory or from suppliers as 

required.

x Existing service agreements will be in place for support services including drilling fluids, 

casing running, cementing, ROV’s, solids control, mud logging, directional drilling, 

LWD/MWD, logging, boats and helicopters. 

x Specialist services for range finding to drill the relief well in close proximity to the original 

wellbore at the reservoir depth will be provided through Vector Magnetics LLC. Sperry 

Drilling and Anadrill have in-house personnel to supplement Vector Magnetics under our 

existing directional drilling agreements. 
C

GEOLOGICAL AND GEOPHYSICAL INFORMATION 

(a) Geological Description 

Discussions regarding geologic information are considered proprietary and have been omitted from this 

section of the public copy EP. 

(b) Structure Contour Maps 

Current structure maps drawn to the top of each productive hydrocarbon sand showing the entire lease 

block, the surface locations of each well and locations of geological cross-sections, are enclosed as 

Attachment C-1.

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

Interpreted seismic lines are enclosed as Attachment C-2.

(d) Geological Structure Cross-Sections 

Interpreted geological structure cross-sections showing the location and depth of each proposed well are 

enclosed as Attachment C-3.

(e) Shallow Hazards Report 

A Shallow Hazards Report prepared by AOA Geophysics, Inc. for Keathley Canyon Block 875 was 

previously submitted with the Initial Exploration Plan Control No. N-9428. 

(f) Shallow Hazards Assessment 

Shallow hazards site clearance letters for the proposed well locations in Keathley Canyon Blocks 875 and 

919 are enclosed as Attachment C-4. The KC 919 “DD & EE” wells will utilize the Site Clearance letter 

from previously approved KC 875 Location D. Wells KC 919 “BB & CC” will use the Site Clearance 

Letter from previously approved KC 875 Location H. Well KC 919 “AA” will utilize the Site Clearance 

Letter from KC 875 Location”I”. 

(g) High-resolution Seismic Lines 

High resolution seismic lines are enclosed as Attachment C-5.

(h) Stratigraphic Column 

A generalized stratigraphic column depicting the wells from the seafloor to total depth is included as 

Attachment C-6. 

(i) Time Vs. Depth Tables 

The proposed activities under this EP are not considered to be in areas where there is no well control. 

Therefore, a seismic travel time versus depth table is not required per NTL No. 2008-G04.
KC875 Proposed B Location 1

AOA Geophysics Inc. 

2500 Tanglewilde, Suite 120 

Houston, TX 77063 

713-532-2624 

Letter Report No. 4051-ANA-GOM-KC875 B 

21 August 2009 

Anadarko Petroleum Corporation 

1201 Lake Robbins 

The Woodlands, Texas 77380 

Attention: Mr. Rick Kincaid 

Site Clearance Letter 

Location B 

Block 875, Keathley Canyon Area 

OCS-G-21444 

UTM Zone 15, NAD 1927 

X = 1,952,916 ft Y = 9,474,150 ft 

Latitude: 26.107071 N Longitude: 92.047418 W 

Nearest Inline 9380 Nearest Crossline 8365 

4596 ft FWL 1830 ft FSL 

Introduction. AOA Geophysics Inc. (AOA) was contracted by Anadarko Petroleum 

Corporation to prepare a site clearance letter for Location B in Block 875, Keathley Canyon 

(OCS-G-21444). The principal scope of this site clearance letter is to assess seafloor disturbance 

from drilling with respect to possible chemosynthetic communities and to identify and assess 

potential drilling hazards in the tophole section to a depth limit of about 4,400 ft below mudline 

(BML). We expect the well will be drilled from a moored drilling rig. We have specifically assessed 

conditions between 5,000 ft and 13,000 ft of the wellbore, as the grounded anchor chains should 

fall between those distances. Please note that this wellsite clearance letter is intended as an 

addendum to the main shallow hazards report (Shallow Hazards Assessment KC875) prepared 

by AOA for Anadarko, dated 21 August 2009. 

Annotated data examples of the nearest line and crossline from the 3-D survey are attached. 

A 1:12,000 water depth and seafloor features map from the shallow hazards interpretation report 

shows the proposed location relative to seafloor features. The proposed location is shown with a 

1,500 ft radius circle as per Minerals Management Service (MMS) Notice to Lessee's (NTL) No. 

2000-G20. The attached chart conforms to the digital structure requirements for drawings as per 

NTL 2008-G05. 

Data Set and Offset Well Information. The 3-D seismic dataset in depth were 

reprocessed by AOA Geophysics to enhance resolution in the tophole section. The depth data 

show significant energy above 50 Hz with good signal to noise ratio and are suitable for 

exploration hazards assessment. The digital 3-D seismic data were loaded onto, and interpreted 

with, a seismic interpretation workstation. The 3-D data in depth cover 9 blocks in Keathley 

Canyon Protraction Area: KC830-832, KC874-876, and KC918-920. Additional time domain data 

cover the subsurface mapping area in KC875 and are used primarily for amplitude extractions to 

assess potential shallow gas. The limit of separability for the depth data (Ȝ/4) is about 35.7 ft at a 

wavenumber of 0.007 which is the depth domain equivalent of 50 Hz. The limit of separability 
KC875 Proposed B Location 2

and were loaded to 50,000 ft and interpreted to approximately 4,400 ft BML. Inlines are spaced 

13.1233 ft apart with an increment of 10. Crosslines are spaced 41.01 ft apart with an increment 

of 3 for the depth data and 2 for the time data. These depth data meet or exceed the current NTL 

requirements including the requirements for the frequency and power content (See Amplitude and 

Power Spectrum figure). 

The nearby well, KC919#1 is in the seafloor study area. The reported water depth at the 

well is used to calibrate horizon depths extracted from the 3-D seismic depth volume. 

Water Depth and Seafloor Gradient. The water depth at proposed Location B is 

predicted to be 6,928 ft below sea surface (BSS). The local seafloor gradient at the proposed 

wellsite is about 4.4 degrees to the west. 

Seafloor Features. The seafloor is slightly undulated and featureless at the proposed 

wellsite. The wellsite is 3 miles west of the relict Bryant Canyon. There is no evidence of seafloor 

instability within 2,000 ft of the well site. The biggest fault near the wellbore is approximately 

2,800 ft northwest, with a seafloor relief of 170 ft. 

The potential for high-density chemosynthetic communities at Location B is low. A region 

that has been interpreted as possibly conducive to a high-density chemosynthetic community has 

been identified outside the exclusion zone about 3,500 ft north-northwest of the well site. There 

are no interpreted seafloor macroseepage sites or potential hardgrounds within 1,500 ft of the 

proposed location. 

Man-Made Obstructions. No wells or pipelines are reported in the vicinity of proposed 

Location B. The nearest wellhead is KC919 #1 about 3.1 miles to the southeast. The nearest 

existing pipeline, operated by BP Exploration and Production, is about 68 miles to the northnorthwest of the proposed well location. 

Assessment of Touchdown Area for Notional Anchor Pattern. The MMS NTL 2000-

G20 mandates that proposed seafloor disturbances (including those caused by anchors, anchor 

chains, wire ropes, seafloor template installation, and pipeline construction) be more than 500 ft 

from areas that could support high-density chemosynthetic communities. If design requires 

seafloor disturbances between 250 ft and 500 ft of potential chemosynthetic communities a stateof-the-art positioning system (e.g., differential global positioning system) on anchor-handling 

vessel(s) must be used, and the MMS must receive plats that depict the “as-placed” location of all 

anchors, anchor chains, and wire ropes within 60 days after completion of operations to 

demonstrate that the features or areas were not physically impacted by the anchoring activities. 

The notional anchor touchdown area is between 5,000 and 13,000 ft from the proposed 

well site. The east and southeastern portion of the area contain three interpreted possible highdensity chemosynthetic communities or hardgrounds, one to the east-northeast and two to the 

southeast about 9,600, 9,300, and 12,500 ft, respectively, from the wellsite. 

There are numerous faults in the touchdown area (see Anchor Chart B). The immediate 

vicinity of the fault scarps should be avoided if possible but otherwise the faults should not 

significantly constrain the anchor placement. In the vicinity of the faults, there may be locally 

variable soil properties and steep slopes. Gullies are present south of well B. A minibasin is 

located about 1.8 miles southwest of the wellbore.
KC875 Proposed B Location 3

Tophole Stratigraphy. The seafloor and three subsurface horizons: 10, 20, and top of 

salt were mapped in Block KC875. Depths below sea surface and below mudline to each of these 

intervals are included on the attached Tophole Prognosis Chart. 

Unit 1 is about 164 ft thick and is interpreted to be composed of normal marine clays. 

Unit 2 is about 587 ft thick and composed of clay-prone mass transport deposits. The 

reflectors are subparallel with moderate to high amplitudes. 

Unit 3 is about 3,511 ft thick and composed of sandy-clay prone and clay-rich overbank 

deposits intercalated with mass transport deposits in the lower section. The upper section is 

composed of parallel sandy-clay deposits intercalated with thin mass transport deposits (the 

upper section of Unit 3 is about 1,539 ft thick), the middle section is characterized by high 

amplitude reflectors interpreted to be sandy sediments (402 ft thick), the base of Unit 3 is 

represented by mass transport clay-prone deposits intercalated with sandy layer towards the 

bottom of the section (1,570 ft thick).

At the well bore the top of salt is clearly defined, located at 4,262 ft BML (salt entry slope 

30o northeast). A possible base of the salt could be at 9,546 ft BML. 

Fault Penetrations. A fault plane is interpreted to crosscut the wellbore path at 

proposed wellsite B at 4,031 ft BML. 

Gas Hazards. No amplitude anomalies suggestive of gassy sediments are penetrated at 

the proposed well site. There is a NEGLIGIBLE risk for gas hazards at the proposed wellsite 

location. The nearest gassy sediments are 270 ft northwest of the wellbore at about 10,500 ft 

BML.

Shallow-Water-Flow (SWF). Sediment accumulation rates in the Plio-Pleistocene 

section are not sufficient for problematic natural overpressures caused by compaction 

disequilibrium. A LOW risk for SWF is assessed for potential sands in the middle and lower 

sections of Unit 3, between 2290 and 3462 ft BML. 

Suitability for Temporary Occupation for Drilling. Proposed KC875B is suitable for

temporary occupation for drilling provided that the conditions and constraints that have been 

identified are considered and planned for in the final well design 
KC875 Proposed B Location 4

We appreciate the opportunity to work with you on this project and look forward to 

continuing as your geohazards and marine geoscience consultants. Please call us at 713-532-

2624 (Houston) if you have any questions or if we can offer further assistance. 

Sincerely, 

AOA GEOPHYSICS INC. 

Brenda I. Monsalve 

Geophysicist 

Dan McConnell, P.G. 

Manager-Marine Geohazards 

Attachments: 

x Water Depth & Seafloor Features Showing Potential Anchor Touchdown for Proposed 

Well KC875B, Keathley Canyon (KC), Gulf of Mexico, Anchor Chart B, (1:12,000) 

x Tophole Prognosis Chart Location B, Block 875, Keathley Canyon Area 

x 3-D Reprocessed Seismic Record, Line 9380, Location B, 875, Keathley Canyon Area 

x 3-D Reprocessed Seismic Record, Crossline 8365, Location B, 875, Keathley Canyon 

Area

x 3-D Seismic Data Description 

x Amplitude and Power Spectrum 
TOPHOLE PROGNOSIS CHART

LOCATION B

BLOCK 875, KEATHLEY CANYON AREA

BML: Below Mudline

BSS: Below Sea Surface All depths and thicknesses are approximate and are based on a 

seismic depth volume provided by 

Anadarko

4051-ANA-GOM Figure Appendix C-KC875B-1 -7000 -7500 -8000 -8500 -9000 -9500 -10000 -10500 -11000 -11500 -12000 -12500 -13000 8359 Trace:

Inferred Lithology

and Comments

Event and

Unit

Designations

Depths

BML

(ft)

BSS

(ft)

Thickness (ft)

UNIT

(ft)

Hazardous

Shallow Gas

Risk

Shallow

Water Flow

Risk

3-D Seismic Record at

Proposed Location B

 Keathley Canyon Block 875

X = 1,952,916 ft, Y = 9,474,150 ft

Seafloor gradient is 4.4o to the west. 

1,000 ft Line 9380 KC875 B

Depth below sea surface (ft)

Unit 1 has normal marine clays.Unit 2 is composed of clay-prone mass movement deposits. The reflectors are subparallel with moderate to high amplitudes.The upper section of Unit 3 is composed of parallel sandy-clay deposits intercalated with thin mass transport deposits.The middle section of Unit 3 has high amplitude reflectors interpreted to be sandy sediments. The lower section of Unit 3 is represented by mass transport clayprone deposits intercalated with sandy layer towards the bottom of the sectionAt the well bore the top of salt is clearly defined with a slope of 30o to the northeast. 

1172

SUBUNIT

(ft)

0 6928

164

164 7092

587

751 7679

2290 9218

3511

2692 96204262 11190

1810

6072 13000

SEAFLOOR

Unit 1 164 NEGLIGIBLE NEGLIGIBLE

H 10

Unit 2 587 NEGLIGIBLE NEGLIGIBLE

H 20

1539 NEGLIGIBLE NEGLIGIBLE

Unit 3 402

NEGLIGIBLE LOW

800 NEGLIGIBLE NEGLIGIBLE

TOPSALT

1810 NEGLIGIBLE NEGLIGIBLE

1570 10390 3462

4031 10959 F1

E

W

NEGLIGIBLE LOW
9380.0

7879.0

9380.07999.0

9380.08119.0

9380.08239.0

9380.08359.0

9380.08479.0

9380.08599.0

9380.08719.0

9380.08839.0

9380.08959.0

Line:

Trace:

5000 10000 15000 20000 25000 30000 35000 40000 45000 Offset:

-6000-7000-8000-9000

-10000-11000-12000

Depth below sea surface (ft)

Positive

Relative Amplitude

Negative

~5000 feet

W

3-D Depth Seismic Record, Line 9380, Location B, Block 875, Southeastern Keathley Canyon

E

KC875B

KC876

Report No. 4051-ANA-GOM Figure Appendix C-KC875B-2 Seafloor Hor. 10 Hor. 20 Top of Salt KC874 Bryant Canyon KC875 SALT
8040.0

8365.0

8440.08365.0

8840.08365.0

9240.08365.0

9640.08365.0

10040.0

8365.0

10440.0

8365.0

10840.0

8365.0

11240.0

8365.0

11640.0

8365.0

Line:

Trace:

5000 10000 15000 20000 25000 30000 35000 40000 45000 Offset:

-6000-7000-8000-9000

-10000-11000-12000

Depth below sea surface (ft)

Positive

Relative Amplitude

Negative

~5000 feet

3-D Depth Seismic Record, Crossline 8365, Location B, Block 875, Southeastern Keathley Canyon

S

N

KC875B

KC831 KC919

Report No. 4051-ANA-GOM Figure Appendix C-KC875B-3 Seafloor Hor. 10 Hor. 20 Top of Salt KC875 SALT
DATA DESCRIPTION 

Description of 3-D Seismic Data Sets: 

The 3-D seismic survey data that have been provided to AOA Geophysics Inc., by Anadarko are of good 

quality to interpret the shallow section. The 3D seismic data volume called 

“mig16f_psdm_wem_final_feet” is a depth volume interpreted around the proposed well sites and is used 

for seafloor and subsurface interpretation. The 3D seismic data volume in time and called 

“mig16f_rtm_0307revtmmigsim” is used for amplitude extraction to define shallow gas in the subsurface 

area Block 875, Keathley Canyon Protraction Area. Both datasets are from the same survey but the depth 

volume is processed in depth by CGG-Veritas and the time volume was processed by Staag Imaging 

(acquired by Schlumberger in 2008), and both volumes are thirty-two-bit format. The 3-D seismic 

parameters for the survey are described in the table below:

3-D Seismic Data mig16f_psdm_wem_final_feet (Dataset used for majority of interpretation) 

Spacing, Increment, and 

Orientation 

Spacing Increment Orientation

Inlines 13.122 ft 10 W to E 

Traces 41.01 ft 3 S to N 

Frequency Content in Tophole 

Section

Spectral analysis shows significant amplitude or power at 50 Hz in the depth 

data at each of the proposed well locations. 

Reprocessed for Shallow 

Section?

Yes, Spectral Whitening 

Processed sample interval Acquired at 2 ms- Processed at 32 ft 

Acquisition Parameters x Acquisition Contractor CGGVeritas 

x Vessel Princess 

x Source Airgun 

x Streamer length 7,200 meters 

x Shotpoint Interval 37.5 m flip-flop 

x CMP Xline 40 m 

x Group Spacing 25 m 

x Record Length 12.5 seconds 

x Nominal Fold 48 

Main Processing Parameters x Wave Equation PSDM (CGG Veritas) 

x Reverse Time (Staag Imaging) 

Quality of Primary 3-D Data with 

respect to NTL Comments 

x The 32 bit data were loaded for interpretation and these data show good 

quality. 

x The data show significant energy in the 50 Hz equivalent range. 

x The limit of separability for the depth data (Ȝ /4) is about 35.7 ft at a 

wavenumber of 0.007 which is the depth domain equivalent of 50 Hz. 

x The limit of separability (Ȝ /4) of the time data is about 27.5 ft at 50 Hz. 

x There are no indications of over migration artifacts in the shallow section. 

x The seabed reflector is continuous at faults and is characterized by a 

wavelet of stable form. 

x No multiple is identified in the shallow section. 

x The data are good at imaging gas. 

x Faults are well imaged in the data. 

Report No. 4051-ANA-GOM Data Description 
KC875-Amp and Power Spectra

Note: Seismic data is in the depth domain. Frequency (Hz) is computed from wavenumber by assuming a constant velocity of 7500 ft/s.

4051-ANA-GOM

0.4

0.5

0.6

0.7

0.8

0.9

1

A

mplitude

Reprocessed Data Amplitude Spectrum Proposed 

Well Locations KC875 Block

0

0.1

0.2

0.3

Frequency

0 20 40 60 80 100 120 140

Wavenumber

KC875 A

KC875 B

KC875 C

50 Hz equivalent

0 0.002 0.004 0.006 0.008 0.01 0.012 0.014 0.016 0.018 0.02

0.4

0.5

0.6

0.7

0.8

0.9

1

Po

wer

Reprocessed Data Power Spectrum Proposed 

Well Locations KC875 Block

0

0.1

0.2

0.3

0 20 40 60 80 100 120 140

Frequency

Wavenumber

KC875 A

KC875 B

KC875 C

50 Hz equivalent

0 0.002 0.004 0.006 0.008 0.01 0.012 0.014 0.016 0.018 0.02
-7200

-7200

-7200

-7000

-7000

-7000

-7200

-7200

-7200

-7200

-7200

-7200

-7200

-7200

-7000

-6800

-7200

-7200

-7000 -7000

-7000

-7200

A

B

KC874

G26771

Devon Energy Production Company, L.P.

Union Oil Company of California

KC918

G32654

Petrobras America Inc.

KC875

G21444

Devon Energy Production Company, L.P.

Kerr-McGee Oil & Gas Corporation

KC919

G21447

Exxon Mobil Corporation

KC920

G21448

KC876

Exxon Mobil Corporation

(open) 13,000 ft Radius

5,000 ft Radius C

Location Map

Grid North

E 1,950,000

E 1,955,000

E 1,940,000 E 1,940,000

E 1,945,000

N 9,470,000

N 26° 05' 00"

N 26° 05' 00"

SPHEROID: Clarke 1866 INVERSE FLATTENING: 1/294.978698SEMIMAJOR AXIS: 6,378,206.40 ft SCALE FACTOR: 0.9996

PROJECTION: Transverse Mercator CENTRAL MERIDIAN: 93° W

DATUM: NAD27 LATITUDE OF ORIGIN: 0°

ZONE: UTM Zone 15 North FALSE EASTING: 1,640,416.666667 ft

LINEAR UNITS: Survey Feet FALSE NORTHING: 0 ft

Geodetic Information

Interpretive Information

Basemap Information

LN 8310

32°N

97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W

97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W

32°N31°N30°N29°N28°N27°N26°N25°N

31°N30°N29°N28°N27°N26°N25°N

Amery Terrace

East Breaks

Garden Banks Green Canyon Atwater Valley

Destin Dome

Mississippi Canyon De Soto Canyon

Lloyd Ridge

Henderson

Florida Plain

Lund

Lund South

Walker Ridge Keathley Canyon Alaminos Canyon

Sigsbee Escarpment

Texas

Louisiana

Mississippi Alabama

Florida

Brownsville

Corpus Christi

Port Lavaca

Freeport

Galveston

The Woodlands

Houston Port Arthur

Lake Charles Lafayette

Morgan City New Orleans

Biloxi

Pascagula

Mobile

Pensacola

Houma

0 25 50 100

Nautical Miles

West

Cameron

West

Cameron

West

West

Cameron

South

West

Delta

Grand

Isle

Eugene

Island

N 9,465,000 N 9,465,000

KC875

B Proposed Well Surface Location and Designation

A 1,500 ft radius circle around well surface location isshown as required by Notice to Lessees 2000-G20

TR 8440LN 9910

Lease Block Boundary: Block Number, Lease Number

with Operator and Primary Lease Holder shown

3D Seismic Survey Line, Trace, and Designation

(LN=Line) (TR=Trace)

Seafloor Mapping Area (mig16f_psdm_wem_final_feet)Subsurface Mapping Area

TR 8050

Notes: 1. mig16f_psdm_wem_final_feet survey :

 Lines have an azimuth of 90°/270°, Traces have an azimuth of 0°/180°. Data Spacing for 3D seismic survey: Line 131.233 ft, Trace 123.031 ft. Line numbering increment is 10, Trace numbering increment is 3. Locations of every 100th Line and every 30th Trace are shown. 2. mig16f_rtm_0307revtmmigsim survey :

 Lines have an azimuth of 90°/270°, Traces have an azimuth of 0°/180°. Data Spacing for 3D seismic survey: Line 131.233 ft, Trace 123.031 ft. Line numbering increment is 10, Trace numbering increment is 3. Locations of every 100th Line and every 30th Trace are shown. 3. Infrastructure information primarily from MMS database, these data, and AOA database updated as of August 2009.

Existing Well Location and Designation

W 92° 05' 00"

W 92° 04' 00"

W 92° 03' 00"

W 92° 02' 00"

W 92° 04' 00"

W 92° 03' 00"

W 92° 02' 00"

W 92° 01' 00"

N 26° 08' 00"N 26° 06' 00"

N 26° 08' 00"

N 26° 06' 00"

Seafloor Mapping Area (mig16f_rtm_0307revtmmigsim)Lowest Contour of Local Depression

-7000

Water Depth Contours: 50 ft interval

Normal fault with seafloor expression. Symbol shows

downthrown side and direction of fault dip

Possible high-density chemosynthetic communitiesRidges and gullies associated with Bryant Canyon

Small minibasins and depressions

TR 8080

TR 8110

TR 8140

TR 8170

TR 8200

TR 8230

TR 8260

TR 8290

TR 8320

TR 8350

TR 8380

TR 8410

TR 8440

TR 8470

TR 8500

TR 8530

TR 8560

TR 8590

TR 8620

TR 8650

TR 8680

LN 9910LN 9810LN 9710LN 9610LN 9510LN 9410LN 9310LN 9210LN 9110LN 9010LN 8910LN 8810LN 8710LN 8610LN 8510LN 8410

LN 10310LN 10210LN 10110LN 10010

N 9,485,000N 9,480,000N 9,475,000

N 9,485,000N 9,480,000N 9,475,000N 9,470,000

E 1,945,000

E 1,950,000

E 1,955,000

E 1,960,000

W 92° 01' 00"

W 92° 05' 00"

E 1,960,000

N 26° 07' 00"

N 26° 07' 00"

1:12,000

Anchor Chart B

Prepared for:

Anadarko Petroleum Corporation

Feet

0 500 1000 2000 3000 4000 5000

INTERPRETATION: B. Monsalve, J. GharibGIS/CAD: B. Dillard

DATE: 8/21/2009REPORT NO: 4051-ANA-GOMFILE: 4051_Anchor_Chart_KC875_B_12.dwg

2500 Tanglewilde, Suite 120

Houston, TX 77063

(713) 532-2624

7532 Sandholdt Road, Suite 6

Moss Landing, CA 95039

(831) 633-7400

Gulf of Mexico

KC875

Water Depth & Seafloor Features

Showing Potential Anchor Touchdown

Area for Proposed Well KC875 B

Keathley Canyon (KC)

KC875 and Vicinity

Approximate Maximum Anchor Radius - 13,000 ftApproximate Touchdown Point - 5,000 ft

TR 8050

TR 8080

TR 8110

TR 8140

TR 8170

TR 8200

TR 8230

TR 8260

TR 8290

TR 8320

TR 8350

TR 8380

TR 8410

TR 8440

TR 8470

TR 8500

TR 8530

TR 8560

TR 8590

TR 8620

TR 8650

TR 8680

LN 10410 LN 10410

LN 10310LN 10210LN 10110LN 10010LN 9910LN 9810LN 9710LN 9610LN 9510LN 9410LN 9310LN 9210LN 9110LN 9010LN 8910LN 8810LN 8710LN 8610LN 8510LN 8410LN 8310

E 1,965,000 E 1,965,000 N 9,460,000 N 9,460,000 Irregular relief associated with shallow salt and Bryant Canyon










001 002

001

13,000 ft Radius

5,000 ft Radius D

E

F G H

KC874

G26771

Devon Energy Production Company, L.P.

Union Oil Company of California

KC918

G32654

Exxon Mobil Corporation

Petrobras America Inc.

KC875

G21444

Devon Energy Production Company, L.P.

Kerr-McGee Oil & Gas Corporation

KC919

G21447

Exxon Mobil Corporation

KC920

(open)

KC876

(open)

1,000 ft

Buffer

-7000

-6800

-7000

-7000

-7200

-7200

-7200

-7200

-7200

-7000

-7400

-7200

-7200

-7200

-7200

-7200

-7000

-7000

-7200

-7000

-7400

-7200

-7200

-7200

-7200

Location Map

Grid North

E 1,950,000

E 1,955,000

E 1,940,000 E 1,940,000

E 1,945,000

N 9,470,000

N 26° 05' 00"

N 26° 05' 00"

SPHEROID: Clarke 1866 INVERSE FLATTENING: 1/294.978698SEMIMAJOR AXIS: 6,378,206.40 ft SCALE FACTOR: 0.9996

PROJECTION: Transverse Mercator CENTRAL MERIDIAN: 93° WDATUM: NAD27 LATITUDE OF ORIGIN: 0°

ZONE: UTM Zone 15 North FALSE EASTING: 1,640,416.666667 ft

LINEAR UNITS: Survey Feet FALSE NORTHING: 0 ft

Geodetic Information

Interpretive Information

Basemap Information

LN 8510

32°N

97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W

97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W

32°N31°N30°N29°N28°N27°N26°N25°N

31°N30°N29°N28°N27°N26°N25°N

Amery Terrace

East Breaks

Garden Banks Green Canyon Atwater Valley

Destin Dome

Mississippi Canyon De Soto Canyon

Lloyd Ridge

Henderson

Florida Plain

Lund

Lund South

Walker Ridge Keathley Canyon Alaminos Canyon

Sigsbee Escarpment

Texas

Louisiana

Mississippi Alabama

Florida

Brownsville

Corpus Christi

Port Lavaca

Freeport

Galveston

The Woodlands

Houston Port Arthur

Lake Charles Lafayette

Morgan City New Orleans

Biloxi

Pascagula

Mobile

Pensacola

Houma

0 25 50 100

Nautical Miles

West

Cameron

West

Cameron

West

West

Cameron

South

West

Delta

Grand

Isle

Eugene

Island

N 9,465,000 N 9,465,000

KC875

D

Proposed Well Surface Location and Designation

A 2,000 ft radius circle around well surface location isshown as required by Notice to Lessees 2009-G40

TR 8440LN 9910

Lease Block Boundary: Block Number, Lease Number

with Operator and Primary Lease Holder shown

3D Seismic Survey Line, Trace, and Designation

(LN=Line) (TR=Trace)

Seafloor Mapping Area (mig16f_psdm_wem_final_feet)Subsurface Mapping Area

Notes: 1. mig16f_psdm_wem_final_feet survey :

 Lines have an azimuth of 90°/270°, Traces have an azimuth of 0°/180°. Data Spacing for 3D seismic survey: Line 131.233 ft, Trace 123.031 ft. Line numbering increment is 10, Trace numbering increment is 3. Locations of every 100th Line and every 30th Trace are shown. 2. mig16f_rtm_0307revtmmigsim survey : Lines have an azimuth of 90°/270°, Traces have an azimuth of 0°/180°. Data Spacing for 3D seismic survey: Line 131.233 ft, Trace 82.021 ft. Line numbering increment is 10, Trace numbering increment is 2. Locations of every 100th Line and every 30th Trace are shown. 3. Infrastructure information primarily from MMS database, these data, and AOA database updated as of February 2010. 4. Water depth has been revised and calibrated by KC875 #1 well.

Existing Well Location and Designation

W 92° 05' 00"

W 92° 04' 00"

W 92° 03' 00"

W 92° 02' 00"

W 92° 04' 00"

W 92° 03' 00"

W 92° 02' 00"

W 92° 01' 00"

N 26° 08' 00"N 26° 06' 00"

N 26° 08' 00"

N 26° 06' 00"

Seafloor Mapping Area (mig16f_rtm_0307revtmmigsim)

Lowest Contour of Local Depression

-7000

Water Depth Contours: 50 ft interval

Normal fault with seafloor expression. Symbol shows

downthrown side and direction of fault dip

Possible high-density deepwater benthic communitiesRidges and gullies associated with Bryant Canyon

Small minibasins and depressions

TR 8050

TR 8080

TR 8110

TR 8140

TR 8170

TR 8200

TR 8230

TR 8260

TR 8290

TR 8320

TR 8350

TR 8380

TR 8410

TR 8440

TR 8470

TR 8500

TR 8530

TR 8560

TR 8590

TR 8050

TR 8080

TR 8110

TR 8140

TR 8170

TR 8200

TR 8230

TR 8260

TR 8290

TR 8320

TR 8350

TR 8380

TR 8410

TR 8440

TR 8470

TR 8500

TR 8530

TR 8560

TR 8590

LN 9910LN 9810LN 9710LN 9610LN 9510LN 9410LN 9310LN 9210LN 9110LN 9010LN 8910LN 8810LN 8710LN 8610

LN 10310LN 10210LN 10110LN 10010

LN 10310LN 10210LN 10110LN 10010LN 9910LN 9810LN 9710LN 9610LN 9510LN 9410LN 9310LN 9210LN 9110LN 9010LN 8910LN 8810LN 8710LN 8610LN 8510

N 9,485,000N 9,480,000N 9,475,000

N 9,485,000N 9,480,000N 9,475,000N 9,470,000

E 1,945,000

E 1,950,000

E 1,955,000

E 1,960,000

W 92° 01' 00"

W 92° 05' 00"

E 1,960,000

N 26° 07' 00"

N 26° 07' 00"

1:12,000

Anchor Chart D

Prepared for:

Anadarko Petroleum Corporation

Feet

0 500 1000 2000 3000 4000 5000

INTERPRETATION: B. Monsalve, J. Gharib

GIS/CAD: B. Dillard

DATE: 3/4/2010REPORT NO: 4051-ANA-GOMFILE: 4051_Anchor_Chart_KC875_D_12.dwg

2500 Tanglewilde, Suite 120

Houston, TX 77063

(713) 532-2624

7532 Sandholdt Road, Suite 6

Moss Landing, CA 95039

(831) 633-7400

Gulf of Mexico

KC875

Water Depth & Seafloor Features

Showing Potential Anchor Touchdown

Area for Proposed Well KC875 D

Keathley Canyon (KC)

KC875 and Vicinity

E 1,965,000 E 1,965,000 N 9,460,000 N 9,460,000 N 26° 04' 00" N 26° 04' 00"

TR 8620

TR 8650

TR 8680

TR 8620

TR 8650

TR 8680

 001

LN 8410LN 8310LN 8210

LN 8410LN 8310LN 8210

TR 8710 TR 8710

TR 8020 TR 8020 1,000 ft buffer beyond approximate maximum anchor radius Approximate Maximum Anchor Radius - 13,000 ft Approximate Touchdown Point - 5,000 ft










001

-7000

-6800

-7000

-7000

-7200

-7200

-7200

-7200

-7200

-7000

-7400

-7200

-7200

-7200

-7200

-7000

-7000

-7000

-7400

-7200

-7200

-7200

-7000

-7200

13,000 ft Radius

5,000 ft Radius

D

E

F G H

002

001

KC874

G26771

Devon Energy Production Company, L.P.

Union Oil Company of California

KC918

G32654

Exxon Mobil Corporation

Petrobras America Inc.

KC875

G21444

Devon Energy Production Company, L.P.

Kerr-McGee Oil & Gas Corporation

KC919

G21447

Exxon Mobil Corporation

KC920

(open)

KC876

(open)

1,000 ft

Buffer

Location Map

Grid North

E 1,950,000

E 1,955,000

E 1,940,000 E 1,940,000

E 1,945,000

N 9,470,000

N 26° 05' 00"

N 26° 05' 00" SPHEROID: Clarke 1866 INVERSE FLATTENING: 1/294.978698

SEMIMAJOR AXIS: 6,378,206.40 ft SCALE FACTOR: 0.9996

PROJECTION: Transverse Mercator CENTRAL MERIDIAN: 93° W

DATUM: NAD27 LATITUDE OF ORIGIN: 0°

ZONE: UTM Zone 15 North FALSE EASTING: 1,640,416.666667 ft

LINEAR UNITS: Survey Feet FALSE NORTHING: 0 ft

Geodetic Information

Interpretive Information

Basemap Information

LN 8510

32°N

97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W

97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W

32°N31°N30°N29°N28°N27°N26°N25°N

31°N30°N29°N28°N27°N26°N25°N

Amery Terrace

East Breaks

Garden Banks Green Canyon Atwater Valley

Destin Dome

Mississippi Canyon De Soto Canyon

Lloyd Ridge

Henderson

Florida Plain

Lund

Lund South

Walker Ridge Keathley Canyon Alaminos Canyon

Sigsbee Escarpment

Texas

Louisiana

Mississippi Alabama

Florida

Brownsville

Corpus Christi

Port Lavaca

Freeport

Galveston

The Woodlands

Houston Port Arthur

Lake Charles Lafayette

Morgan City New Orleans

Biloxi

Pascagula

Mobile

Pensacola

Houma

0 25 50 100

Nautical Miles

West

Cameron

West

Cameron

West

West

Cameron

South

West

Delta

Grand

Isle

Eugene

Island

N 9,465,000 N 9,465,000

KC875

H Proposed Well Surface Location and Designation

A 2,000 ft radius circle around well surface location isshown as required by Notice to Lessees 2009-G40

TR 8440LN 9910

Lease Block Boundary: Block Number, Lease Number

with Operator and Primary Lease Holder shown

3D Seismic Survey Line, Trace, and Designation(LN=Line) (TR=Trace)

Seafloor Mapping Area (mig16f_psdm_wem_final_feet)Subsurface Mapping Area

Notes: 1. mig16f_psdm_wem_final_feet survey :

 Lines have an azimuth of 90°/270°, Traces have an azimuth of 0°/180°. Data Spacing for 3D seismic survey: Line 131.233 ft, Trace 123.031 ft. Line numbering increment is 10, Trace numbering increment is 3. Locations of every 100th Line and every 30th Trace are shown. 2. mig16f_rtm_0307revtmmigsim survey :

 Lines have an azimuth of 90°/270°, Traces have an azimuth of 0°/180°. Data Spacing for 3D seismic survey: Line 131.233 ft, Trace 82.021 ft. Line numbering increment is 10, Trace numbering increment is 2. Locations of every 100th Line and every 30th Trace are shown. 3. Infrastructure information primarily from MMS database, these data, and AOA database updated as of February 2010. 4. Water depth has been revised and calibrated by KC875 #1 well.

Existing Well Location and Designation

W 92° 05' 00"

W 92° 04' 00"

W 92° 03' 00"

W 92° 02' 00"

W 92° 04' 00"

W 92° 03' 00"

W 92° 02' 00"

W 92° 01' 00"

N 26° 08' 00"N 26° 06' 00"

N 26° 08' 00"

N 26° 06' 00"

Seafloor Mapping Area (mig16f_rtm_0307revtmmigsim)

Lowest Contour of Local Depression

-7000

Water Depth Contours: 50 ft interval

Normal fault with seafloor expression. Symbol shows

downthrown side and direction of fault dip

Ridges and gullies associated with Bryant Canyon

Small minibasins and depressions

TR 8050

TR 8080

TR 8110

TR 8140

TR 8170

TR 8200

TR 8230

TR 8260

TR 8290

TR 8320

TR 8350

TR 8380

TR 8410

TR 8440

TR 8470

TR 8500

TR 8530

TR 8560

TR 8590

TR 8050

TR 8080

TR 8110

TR 8140

TR 8170

TR 8200

TR 8230

TR 8260

TR 8290

TR 8320

TR 8350

TR 8380

TR 8410

TR 8440

TR 8470

TR 8500

TR 8530

TR 8560

TR 8590

LN 9910LN 9810LN 9710LN 9610LN 9510LN 9410LN 9310LN 9210LN 9110LN 9010LN 8910LN 8810LN 8710LN 8610

LN 10310LN 10210LN 10110LN 10010

LN 10310LN 10210LN 10110LN 10010LN 9910LN 9810LN 9710LN 9610LN 9510LN 9410LN 9310LN 9210LN 9110LN 9010LN 8910LN 8810LN 8710LN 8610LN 8510

N 9,485,000N 9,480,000N 9,475,000

N 9,485,000N 9,480,000N 9,475,000N 9,470,000

E 1,945,000

E 1,950,000

E 1,955,000

E 1,960,000

W 92° 01' 00"

W 92° 05' 00"

E 1,960,000

N 26° 07' 00"

N 26° 07' 00"

1:12,000

Anchor Chart H

Prepared for:

Anadarko Petroleum Corporation

Feet

0 500 1000 2000 3000 4000 5000

INTERPRETATION: B. Monsalve, J. GharibGIS/CAD: B. Dillard

DATE: 3/4/2010REPORT NO: 4051-ANA-GOMFILE: 4051_Anchor_Chart_KC875_H_12.dwg

2500 Tanglewilde, Suite 120

Houston, TX 77063

(713) 532-2624

7532 Sandholdt Road, Suite 6

Moss Landing, CA 95039

(831) 633-7400

Gulf of Mexico

KC875

Water Depth & Seafloor Features

Showing Potential Anchor Touchdown

Area for Proposed Well KC875 H

Keathley Canyon (KC)

KC875 and Vicinity

N 9,460,000 N 9,460,000

N 26° 04' 00"

N 26° 04' 00"

TR 8620 TR 8620 001 LN 8410 LN 8310 LN 8210 LN 8410 LN 8310 LN 8210

TR 8020

TR 7990

TR 8020

TR 7990

1,000 ft buffer beyond approximate maximum anchor radiusApproximate Maximum Anchor Radius - 13,000 ftApproximate Touchdown Point - 5,000 ft

TR 8650 TR 8650

TR 7960 TR 7960 Possible high-density deepwater benthic communities
D

HYDROGEN SULFIDE INFORMATION 

Wells in adjacent Keathley Canyon 875, 919, and 964 blocks have tested a similar age section as the 

wells proposed within this plan without encountering any H2S. These wells include the Keathley 

Canyon (Anadarko) 875 OCS-G 21444 #1 and #1 ST1, Keathley Canyon (Anadarko) 875 OCS-G 

21444 #2 (Pliocene only), Keathley Canyon (ExxonMobil) 919 OCS-G 21447 #1, Keathley 

Canyon (ExxonMobil) 919 OCS-G 21447 #2, Keathley Canyon (ExxonMobil) 919 OCS-G 21447 

#3 and #3BP1, and the Keathley Canyon (ExxonMobil) 964 OCS-G 21451 #1. As no H2S was 

encountered in any of these wells we request the area be classified as a "zone where the absence of 

H2S has been confirmed.” 
E

 BIOLOGICAL, PHYSICAL, AND SOCIOECONOMIC INFORMATION 

(a) Chemosynthetic Communities Report 

The seafloor disturbing activities proposed in this plan are in approximately 6,825’-7,025’ of

water. The wells will be drilled with DP Semisubmersible drilling unit. 

Maps

A map prepared using 3-D seismic data to depict bathymetry, seafloor and shallow geological 

features, surface locations of the proposed wells, and positions of anchors and chains relative to 

the proposed operations is included in Section A.

Analysis

Features or areas that could support high-density chemosynthetic communities are not located 

within 2000 feet of each proposed muds and cuttings discharge location. 

Features or areas that could support high-density chemosynthetic communities are not located 

within 250 feet of any seafloor disturbances.

(b) Topographic Features Map 

The proposed activities are not within 1,000 feet of a no-activity zone or within the 3-mile radius 

zone of an identified topographic feature. Therefore, no map is required per NTL No. 2008-G04. 

(c) Topographic Features Statement (Shunting) 

Anadarko does not plan to drill more than two wells from the same surface location within the 

Protective Zone of an identified topographic feature. Therefore, the topographic features 

statement required by NTL No. 2008-G04 is not applicable.

(d) Live Bottoms (Pinnacle Trend) Map 

The activities proposed in this plan are not within 200 feet of any pinnacle trend feature with 

vertical relief equal to or greater than 8 feet. Therefore, no map is required per NTL No. 2008-

G04.

(e) Live Bottoms (Low Relief) Map 

The activities proposed in this plan are not within 100 feet of any live bottom low relief features. 

Therefore, no map is required per NTL No. 2008-G04. 
(f) Potentially Sensitive Biological Features 

The activities proposed in this plan are not within 200 feet of any potentially sensitive biological 

features. Therefore, no map is required per NTL No. 2008-G04. 

(g) Remotely Operated Vehicle (ROV) Monitoring Survey Plan 

Keathley Canyon Blocks 875 & 919 are located within Deepwater Grid Area 8. This grid is 

considered to have “inadequate ROV survey coverage”, and, therefore, under the guidance set 

out in NTL No. 2008-G06, a Remotely Operated Vehicle Monitoring Survey Plan is required. 

Pursuant to NTL 2008-G06, operators may be required to conduct remotely operated vehicle 

(ROV) surveys during the proposed operations for the purpose of biological and physical 

observations.

Anadarko is familiar with the ROV survey and reporting provisions of NTL 2008-G06; and if 

required, will conduct a survey. 

Anadarko will utilize ROV equipped with video imaging capabilities. The survey pattern will 

consist of six transects centered on the well location with tracks extending approximately 100 

meters away from the well on bearings of 30 degrees, 90 degrees, 150 degrees, 210 degrees, 270 

degrees and 330 degrees. The seafloor will be videotaped continuously along each track. 

Anadarko will make biological and physical observations as described in the subject NTL and 

Form MMS-141 prior to commencing operations and prior to moving off location. The 

observations will be documented using Form MMS-141, or a facsimile and submitted along with 

videotapes, and any other imagery obtained, to the BOEMRE within 60 days after completion of 

the final ROV survey.

(h) Threatened and Endangered Species Information 

Under Section 7 of the Endangered Species Act (ESA) all federal agencies must ensure that any 

actions they authorize, fund, or carry out are not likely to jeopardize the continued existence of a 

listed species, or destroy or adversely modify its designated critical habitat. 

In accordance with the 30 CFR 250, Subpart B, effective May 14, 2007, and further outlined in 

Notice to Lessees (NTL) 2008-G04, lessees/operators are required to address site-specific 

information on the presence of federally listed threatened or endangered species and critical 

habitat designated under the ESA and marine mammals protected under the Marine Mammal 

Protection Act (MMPA) in the area of proposes activities under this plan. 

Currently there are no designated critical habitats for the listed species in the Gulf of Mexico 

Outer Continental Shelf; however, it is possible that one or more of these species could be seen 

in the area of our operations. The following table reflects the Federally-listed endangered and 

threatened species in the lease area and along the northern Gulf coast: 
Species Scientific Name Status Potential Presence Critical Habitat Designated in

Lease Area Coastal Gulf of Mexico 

Marine Mammals 

Sperm whale Physeter macrocephalus E X -- None

West Indian manatee Trichechus manatus latirostris E -- X Florida (Peninsular)

Blue whale Balaenoptera musculus E Xa -- None

Fin whale Balaenoptera physalus E Xa -- None

Humpback whale Megaptera novaeangliae E Xa -- None

North Atlantic right whale Eubalaena glacialis E Xa -- None

Sei whale Balaenoptera borealis E Xa -- None

Sea Turtles 

Loggerhead turtle Caretta caretta T X X None

Green turtle Chelonia mydas T, Eb X X None

Leatherback turtle Dermochelys coriacea E X X None

Hawksbill turtle Eretmochelys imbricata E X X None

Kemp’s ridley turtle Lepidochelys kempii E X X None

Birds

Piping Plover Charadrius melodus T -- X 

Coastal Texas, Louisiana, 

Mississippi, Alabama, and 

Florida (Panhandle)

Whooping Crane Grus americana E -- X 

Coastal Texas 

(Aransas National Wildlife 

Refuge) 

Fishes 

Gulf sturgeon Acipenser oxyrinchus desotoi T -- X 

Coastal Louisiana, 

Mississippi, Alabama, and 

Florida (Panhandle)

Smalltooth sawfish Pristis pectinata E -- X Southwest Florida and the 

Florida Keys 

Invertebrates

Elkhorn coral Acropora palmata T -- X Flower Garden Banks

Terrestrial Mammals 

Beach mice (Alabama, 

Choctawhatchee,

Perdido Key, St. Andrew) 

Peromyscus polionotus E -- X Alabama and Florida 

(Panhandle) beaches 

Abbreviations:E = Endangered; T = Threatened. a

 The blue, fin, humpback, North Atlantic right, and sei whales are rare or extralimital in the Gulf of Mexico and are unlikely to be present in

the lease area. b

 The green sea turtle is threatened, except for the Florida breeding population, which is listed as endangered.

The Environmental Impact Analysis in Section N of this plan further discusses potential impacts and mitigation 

measures related to threatened and endangered species. 

(i) Archaeological Report 

Keathley Canyon Blocks 875 and 919 are not located in an area designated as an area of high archaeological 

potential and, as such, an Archaeological Report is not required per NTL No. 2011-JOINT-G01. However, an 

Archaeological Report prepared by Fugro Geoservices, Inc covering the proposed Keathley Canyon Blocks 875 and 

919 well locations was previously submitted to BOEM on December 20, 2011 attached to plan Control No. N-9593 

and plan Control No. N-9428. The survey was conducted in accordance with the latest guidelines established by the 

BOEMRE in 2011. 

(j) Air and Water Quality Information

This EP does not propose activities for which the State of Florida is an affected State. Therefore, the discussion 

required per NTL 2008-G04 is not applicable to this EP. 

(k) Socioeconomic Information 

The activities proposed in this plan are not located offshore Florida. Therefore, socioeconomic information required 

per NTL 2008-G04 is not applicable to this EP. 
F

WASTE AND DISCHARGE INFORMATION 

The following estimates were prepared utilizing Anadarko’s experience with similar drilling operations. 

Estimated maximum discharge rates are reflected below. Projected amounts may vary during the course 

of drilling operations. 

(a) Projected Generated Wastes 

Type of Waste Composition Projected Amount Treatment/Storage/Disposal 

Synthetic-based

drilling fluids 

Synthetic-based

drilling muds 

11,000 bbls/well Re-use and/or transport to 

shore in DOT approved 

containers to Fourchon, 

Louisiana and on to 

base/transfer station. If 

recycled, returned to vendor 

(Bariod or MI). 

Cuttings wetted 

with syntheticbased fluids 

Cuttings coated 

with synthetic 

drilling

muds/fluids, 

including drilled 

out cement 

2,000 bbls/well Treated and discharge 

overboard 

*Note, an estimated 5-10% of 

cuttings may be transported to 

shore in DOT approved 

containers and on to the 

base/transfer station if oil still 

remains.

Water-based 

drilling fluids 

Water based 

drilling muds 

(NaCl saturated, 

seawater, 

freshwater, barite) 

60,000 bbls/well** Discharge overboard or at 

seafloor

Cuttings wetted 

with water-based 

fluids

Cuttings coated 

with water-based 

drilling muds/fluids 

3,000 bbls/well Discharge overboard 

Chemical product 

waste (well 

treatment fluids) 

Ethylene glycol 

Methanol

2,330 bbls total 

582.5 total

Transport to shore in DOT 

approved containers to Fourchon, 

Louisiana for pick up. 

Completion 

Fluids 

Brine, spent acid, 

prop sand, debris 

3,000 bbls/well Transport to shore in DOT 

approved containers to Fourchon, 

Louisiana and on to Newpark 

Base. 

Non-pollutant 

completion fluids 

Low density 

uninhibited 

completion brines 

5,000 bbls/well Discharge overboard 

Workover fluids Brine, spent acid, 

prop sand, debris 

3,000 bbls/well Transport to shore in DOT 

approved containers to Fourchon, 

Louisiana and on to Newpark 

Base.

Trash Refuse generated 

during operations 

1,165 bbls total Transport to shore in disposal bags 

by vessel to shorebase for pickup 

by municipal operations. 
*Sanitary Wastes Treated human 

body waste 

3,495,000 gals total Chlorinate and discharge 

overboard 

*Domestic Waste Gray water 3,495,000 gals total Chlorinate and discharge 

overboard 

Deck drainage Platform washings 

and rainwater 

2,446,500 bbls total Treat for oil and grease and 

discharge overboard 

Produced water N/A N/A N/A 

Desalinization

Unit

Seawater 244,650 bbls total Discharge overboard 

Wash water Drill water (fresh) 34,950 bbls total Discharge overboard 

Blowout

preventer fluid 

Blend (3% Stack 

Magic & Filtered 

Fresh Water) 

92,368 gals total Discharge at seafloor 

Ballast water Seawater 47,650 m3/year Discharge overboard 

Bilge water Seawater 3,984 bbls total Discharge overboard through 

15 ppm equipment 

Excess cement at 

the seafloor 

Nitrified cement 

slurry

1,200 bbls/well Discharge at seafloor 

Fire water Seawater 137,142 

bbls/day/well 

Discharge overboard 

Cooling water Seawater 137,142 

bbls/day/well 

Discharge overboard 

Produced Sand N/A N/A N/A 

Used oil Excess oil from 

engines

2,504.7 bbls total Transport in DOT approved 

containers to shore for recycling 

*The rig is designed for maximum personnel capacity of 200 people. The discharge rates are based off of maximum 

personnel capacity but will generally not have this many personnel onboard during drilling and/or completion 

operations. 

**The actual volume ordered out will be an estimated 18,000 bbls/well of mud. Once on location this volume will 

be cut back and mixed with seawater to different desired mud weights which will increase the volume that is 

discharged at the seafloor. The estimated volume that will be discharged at the seafloor will be approximately 

60,000 bbls/well. 

(b) Projected Ocean Discharges

Type of Waste Total Amount to 

be Discharged 

Discharge Rate Discharge Method 

*Sanitary Wastes 3,495,000 gals 

total

25 gals/person/day/well 

*5000 gals/day/well

Chlorinate and discharge 

overboard 

*Domestic waste 3,495,000 gals 

total

25 gals/person/day/well 

*5000 gals/day/well

Chlorinate and discharge 

overboard 

Deck drainage 2,446,500 bbls 

total

3500 bbls/day/well Treat for oil and grease and 

discharge

Blowout preventer 

fluid

92,368 gals total 925 gals/week/well; 

Vents on a weekly 

basis 

Discharge at seafloor 

Desalinization Unit 244,650 bbls total 350 bbls/day/well Discharge overboard 

Wash water 34,950 bbls total 50 bbls/day/well Discharge overboard 
Ballast water 91,253 m3 total 47,650 m3/year; not 

continuous 

Discharge overboard 

Bilge water 3,984 bbls total 5.7 bbls/day/well Discharge overboard through 

15 ppm equipment 

Excess cement at the 

seafloor

1,200 bbls/well 20 bbls/min Discharge at seafloor 

Fire water 95,862,258 bbls 

total

137,142 

bbls/day/well 

Discharge overboard 

Cooling water 95,862,258 bbls 

total

137,142 

bbls/day/well 

Discharge overboard 

Cuttings wetted with 

Water-based fluids 

3,000 bbls/well 1,000 bbls/hr max Discharge overboard 

Water-based drilling 

fluids

60,000 

bbls/well** 

1,000 bbls/hr max Discharge at seafloor or 

overboard 

Cuttings wetted with 

Synthetic-based fluids 

2,000 bbls/well NA Treated and discharge 

overboard *Note, an 

estimated 5-10% of cuttings 

may be transported to shore 

in DOT approved containers 

and on to the base/transfer 

station if oil still remains.

Non-pollutant 

completion fluids 

5,000 bbl/well 100 bbl/hour Discharge overboard 

*The rig is designed for maximum personnel capacity of 200 people. The discharge rates are based off of maximum 

personnel capacity but will generally not have this many personnel onboard during drilling and/or completion 

operations. 

**The actual volume ordered out will be an estimated 18,000 bbls/well of mud. Once on location this volume will 

be cut back and mixed with seawater to different desired mud weights which will increase the volume that is 

discharged at the seafloor. The estimated volume that will be discharged at the seafloor will be approximately 

60,000 bbls/well. 

 (c) Modeling Report 

The proposed activities under this plan do not meet the U.S. Environmental Protection Agency 

requirements for an individual NPDES permit. Therefore, modeling report requirements per NTL No. 

2008-G04 is not applicable to this EP. 
G

AIR EMISSIONS INFORMATION 

(a) Screening Questions 

Screening Questions for EP’s 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 the other air pollutants 

(where D = distance to shore in miles)? 

 No 

Do your emission calculations include any emission reduction measures or modified 

emission factors? 

Yes 

Are your proposed exploration activities located east of 87.5 W longitude? No 

Do you expect to encounter H2S at concentrations greater than 20 parts per million (ppm)? No 

Do you propose to flare or vent natural gas for more than 48 continuous hours from any 

proposed well? 

 No 

Do you propose to burn produced hydrocarbon liquids? No 

(b) Emissions Worksheets 

Air emissions worksheets have been prepared using fuel usage data from the Ensco 8500, a DP 

Semisubmersible drilling unit. Air emissions worksheets are enclosed as Attachment G-1.

(c) Summary Information 

Summary information regarding the peak year emissions generated from the Plan Emissions and Complex 

Total Emissions: 

If drilled with the Ensco 8500 (DP Semisubmersible Rig): 

Air Pollutant Plan Emission 

Amounts1

 (tons)

Calculated

Exemption

Amounts2

 (tons)

Calculated

Complex Total 

Emission Amounts3

(tons)

Particulate matter (PM) 50.48 7092.90 69.77 

Sulphur dioxide (SO2) 231.61 7092.90 311.95 

Nitrogen oxides (NOx) 1738.71 7092.90 2342.35 

Volatile organic compounds 

(VOC)

54.95 7092.90 74.46 

Carbon monoxide (CO) 397.26 121264.03 537.91 

Air emissions from undrilled well locations under previously approved plans are being carried 

forward in the following table to reflect Anadarko’s current drilling schedule. No revisions are 

being requested to the previously approved well locations under this plan: 

Proposed Activity Start Date End Date No. of Days 

Drill KC 875 #002 ST01 (location B previously approved under R-5138) 12-28-2012 02-20-2013 55 

Drill KC 919 AA 02-21-2013 03-21-2013 29 

Drill KC 919 BB 03-22-2013 04-30-2013 40 

Drill KC 875 D (previously approved under N-9593) 05-01-2013 06-07-2013 38 

Complete KC 875 D (previously approved under N-9593) 06-08-2013 07-22-2013 45 
Complete KC 919 AA 07-23-2013 09-05-2013 45 

Drill and Complete KC 875 H (previously approved under N-9593) 09-06-2013 12-04-2013 90 

Complete KC 919 BB 12-05-2013 01-18-2014 45 

Complete KC 919 #003 (previously approved under S-7330) 01-19-2014 03-04-2014 45 

Complete KC 874 #001 (location B previously approved under N-9593) 03-05-2014 04-18-2014 45 

Drill and Complete KC 919 CC 04-19-2014 09-01-2014 135 

Drill and Complete KC 919 DD 01-01-2015 05-16-2015 135

Drill and Complete KC 919 EE 05-17-2015 09-29-2015 135 

Drill and Complete KC 875 I 01-01-2016 05-15-2016 135 

Drill and Complete KC 875 F (previously approved under N-9593) 05-16-2016 08-24-2016 100 

Drill and Complete KC 875 G (previously approved under N-9593) 01-01-2017 04-11-2017 100 

The air emission calculations were calculated by: 

Jill Fowler 

Regulatory Analyst 

(832) 636-1554 

jill.fowler@anadarko.com
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Control No. 1010-0049

OMB Approval Expires: September 30, 2003 COMPANY Anadarko Petroleum Corporation

AREA Keathley Canyon

BLOCK 875 & 919LEASE OCS-G 21444 & 21447

PLATFORMWELL Proposed wells under this SEP: KC 875 I & KC 919 AA, BB, CC, DD, EECOMPANY CONTACT Jill FowlerTELEPHONE NO. 832-636-1554REMARKS Drill and complete 6 wells

Form MMS-138 (May 2001)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

Equipment/Emission Factors units PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 3.3-1 10/96

Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 14-2, & 14 7/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03 E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005 API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991Gas Venting lbs/scf 0.0034

Sulfur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight

Form MMS-138 (May 2001)Page 2 of 8
EMISSIONS CALCULATIONS 2ND YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 9Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24.00 140.00 15.18 69.62 521.70 15.65 113.83 25.50 116.97 876.46 26.29 191.23Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6.00 60 1.83 8.41 63.00 1.89 13.74 0.33 1.51 11.34 0.34 2.472 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6.00 40 2.11 9.70 72.69 2.18 15.86 0.25 1.16 8.72 0.26 1.90

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 2 0.59 71.40 60.30 388.50 0.01 1.71 1.45 9.32

2013 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 26.08 119.66 898.23 28.34 204.93

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 4 of 8
EMISSIONS CALCULATIONS 3RD YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 9Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 152 15.18 69.62 521.70 15.65 113.83 27.68 126.99 951.58 28.55 207.62Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 65 1.83 8.41 63.00 1.89 13.74 0.36 1.64 12.28 0.37 2.682 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 43 2.11 9.70 72.69 2.18 15.86 0.27 1.25 9.38 0.28 2.05

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 4 0.59 71.40 60.30 388.50 0.03 3.43 2.89 18.65

2014 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 28.31 129.91 976.67 32.09 230.99

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 5 of 8
EMISSIONS CALCULATIONS 4TH YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 271 15.18 69.62 521.70 15.65 113.83 49.35 226.41 1696.57 50.90 370.16Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 116 1.83 8.41 63.00 1.89 13.74 0.64 2.93 21.92 0.66 4.782 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 77 2.11 9.70 72.69 2.18 15.86 0.49 2.24 16.79 0.50 3.66

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 4 0.59 71.40 60.30 388.50 0.03 3.43 2.89 18.65

2015 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 50.48 231.61 1738.71 54.95 397.26

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 6 of 8
EMISSIONS CALCULATIONS 5TH YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 135 15.18 69.62 521.70 15.65 113.83 24.59 112.79 845.15 25.35 184.40Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 58 1.83 8.41 63.00 1.89 13.74 0.32 1.46 10.96 0.33 2.392 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 39 2.11 9.70 72.69 2.18 15.86 0.25 1.13 8.50 0.26 1.86

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 2 0.59 71.40 60.30 388.50 0.01 1.71 1.45 9.32

2016 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 25.15 115.40 866.33 27.39 197.97

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 7 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELLAnadarko Petrol Keathley Canyon 875 & 919 OCS-G 21444 & 21447 Proposed wells under t

Emitted Substance

Year

 PM SOx NOx VOC CO

2012 0.00 0.00 0.00 0.00 0.002013 26.08 119.66 898.23 28.34 204.932014 28.31 129.91 976.67 32.09 230.992015 50.48 231.61 1738.71 54.95 397.262016 25.15 115.40 866.33 27.39 197.972017 0.00 0.00 0.00 0.00 0.002018 0.00 0.00 0.00 0.00 0.002019 0.00 0.00 0.00 0.00 0.002020 0.00 0.00 0.00 0.00 0.002021 0.00 0.00 0.00 0.00 0.00

Allowable 7092.90 7092.90 7092.90 7092.90 121264.03

Form MMS-138 (May 2001)Page 8 of 8
January Febuary March April May June July August September October November December Total: Average

2010 Monthly Averages (bbls) 6957 6242 7778 6291 6436 6157 5958 6459 5989 5550 5490 6040 75,347 62792010 Single Highest Day Rate (bbls) 398 343 468 388 428 527 502 300 295 292 285 333 4559 380

January Febuary March April May June July August September October November December Total: Average

2011 Monthly Averages (bbls) 5842 5839 6462 6493 6183 6500 7664 8616 5931 6276 6619 5999 78,424 65352011 Single Highest Day Rate (bbls) 282 384 334 372 344 591 557 594 411 323 395 340 4927 411

-Highest daily fuel for 2010 & 2011= 594 bbls/day-594 bbls x 42 = 24,948 gals/day-24,948 gals / 24 = 1040 gals/ hour-1040 gals / 0.04830 (gal/hp-hr BOEM diesel fuel use factor ) = 21,532 equivalent horsepower-21,532 equivalent horsepower used based on BOEM fuel factor and average fuel use

ACTUAL FUEL USAGE FACTORS ASSUMED FOR AQR EMMISSION CALCULATIONS
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB Control No. 1010-0049

OMB Approval Expires: September 30, 2003 COMPANY Anadarko Petroleum Corporation

AREA Keathley Canyon

BLOCK 875 & 919LEASE OCS-G 21444 & 21447

PLATFORMWELL Proposed wells under this SEP: KC 875 I & KC 919 AA, BB, CC, DD, EE

Previously approved wells being carried forward: KC 875 #002 ST01, D, F, G, H; KC 874 #001; & KC 919 #003

COMPANY CONTACT Jill FowlerTELEPHONE NO. 832-636-1554REMARKS Drill and complete 6 wells

Form MMS-138 (May 2001)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

Equipment/Emission Factors units PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96

Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 3.3-1 10/96

Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 14-2, & 14 7/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03 E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005 API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991Gas Venting lbs/scf 0.0034

Sulfur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight

Form MMS-138 (May 2001)Page 2 of 8
EMISSIONS CALCULATIONS 1ST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorporaKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KCJill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 3 15.18 69.62 521.70 15.65 113.83 0.55 2.51 18.78 0.56 4.10Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 1 1.83 8.41 63.00 1.89 13.74 0.01 0.03 0.19 0.01 0.042 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 1 2.11 9.70 72.69 2.18 15.86 0.01 0.03 0.22 0.01 0.05

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 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

MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2012 YEAR TOTAL 19.12 87.73 657.38 19.72 143.43 0.56 2.56 19.19 0.58 4.19

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 3 of 8
EMISSIONS CALCULATIONS 2ND YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 9Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24.00 365.00 15.18 69.62 521.70 15.65 113.83 66.47 304.95 2285.05 68.55 498.56Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6.00 156 1.83 8.41 63.00 1.89 13.74 0.86 3.93 29.48 0.88 6.432 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6.00 104 2.11 9.70 72.69 2.18 15.86 0.66 3.03 22.68 0.68 4.95

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 6 0.59 71.40 60.30 388.50 0.04 5.14 4.34 27.97

2013 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 67.99 311.95 2342.35 74.46 537.91

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 4 of 8
EMISSIONS CALCULATIONS 3RD YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 9Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 243 15.18 69.62 521.70 15.65 113.83 44.26 203.02 1521.28 45.64 331.92Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 104 1.83 8.41 63.00 1.89 13.74 0.57 2.62 19.65 0.59 4.292 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 69 2.11 9.70 72.69 2.18 15.86 0.44 2.01 15.05 0.45 3.28

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 8 0.59 71.40 60.30 388.50 0.06 6.85 5.79 37.30

2014 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 45.26 207.71 1562.83 52.47 376.78

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 5 of 8
EMISSIONS CALCULATIONS 4TH YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 271 15.18 69.62 521.70 15.65 113.83 49.35 226.41 1696.57 50.90 370.16Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 116 1.83 8.41 63.00 1.89 13.74 0.64 2.93 21.92 0.66 4.782 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 77 2.11 9.70 72.69 2.18 15.86 0.49 2.24 16.79 0.50 3.66

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 4 0.59 71.40 60.30 388.50 0.03 3.43 2.89 18.65

2015 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 50.48 231.61 1738.71 54.95 397.26

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 6 of 8
EMISSIONS CALCULATIONS 5TH YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554 

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 236 15.18 69.62 521.70 15.65 113.83 42.98 197.17 1477.46 44.32 322.35Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 101 1.83 8.41 63.00 1.89 13.74 0.56 2.55 19.09 0.57 4.162 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 67 2.11 9.70 72.69 2.18 15.86 0.43 1.95 14.61 0.44 3.19

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 4 0.59 71.40 60.30 388.50 0.03 3.43 2.89 18.65

2016 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 43.96 201.70 1514.58 48.23 348.35

EXEMPTION

CALCULATION

DISTANCE FROM LAND IN 

MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0

Form MMS-138 (May 2001)Page 7 of 8
COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Anadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444 & 21 Proposed wells under this SEP: KC 875 I &Jill Fowler 832-636-1554

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21,532 1039.9956 24959.89 24 100 15.18 69.62 521.70 15.65 113.83 18.21 83.55 626.04 18.78 136.59Ensco 8500 PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 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

3 trips/week VESSELS>600hp diesel(crew) 2600 125.58 3013.92 6 43 1.83 8.41 63.00 1.89 13.74 0.24 1.08 8.13 0.24 1.772 trips/week VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 29 2.11 9.70 72.69 2.18 15.86 0.18 0.84 6.32 0.19 1.38

VESSELS>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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00 

Flowback After OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Completion GAS FLARE 1000000 24 2 0.59 71.40 60.30 388.50 0.01 1.71 1.45 9.32

2017 YEAR TOTAL 19.12 88.32 728.78 80.02 531.93 18.63 85.49 642.20 20.66 149.07

EXEMPTION

CALCULATION DISTANCE FROM LAND IN MILES 7092.90 7092.90 7092.90 7092.90 121264.03

213.0
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELLAnadarko Petrol Keathley Canyon 875 & 919 OCS-G 21444 & 21447 Proposed wells under t

Emitted Substance

Year

 PM SOx NOx VOC CO

2012 0.56 2.56 19.19 0.58 4.192013 67.99 311.95 2342.35 74.46 537.912014 45.26 207.71 1562.83 52.47 376.782015 50.48 231.61 1738.71 54.95 397.262016 43.96 201.70 1514.58 48.23 348.352017 18.63 85.49 642.20 20.66 149.072018 0.00 0.00 0.00 0.00 0.002019 0.00 0.00 0.00 0.00 0.002020 0.00 0.00 0.00 0.00 0.002021 0.00 0.00 0.00 0.00 0.00

Allowable 7092.90 7092.90 7092.90 7092.90 121264.03

Form MMS-138 (May 2001)Page 8 of 8
January Febuary March April May June July August September October November December Total: Average

2010 Monthly Averages (bbls) 6957 6242 7778 6291 6436 6157 5958 6459 5989 5550 5490 6040 75,347 62792010 Single Highest Day Rate (bbls) 398 343 468 388 428 527 502 300 295 292 285 333 4559 380

January Febuary March April May June July August September October November December Total: Average

2011 Monthly Averages (bbls) 5842 5839 6462 6493 6183 6500 7664 8616 5931 6276 6619 5999 78,424 65352011 Single Highest Day Rate (bbls) 282 384 334 372 344 591 557 594 411 323 395 340 4927 411

-Highest daily fuel for 2010 & 2011= 594 bbls/day-594 bbls x 42 = 24,948 gals/day-24,948 gals / 24 = 1040 gals/ hour-1040 gals / 0.04830 (gal/hp-hr BOEM diesel fuel use factor ) = 21,532 equivalent horsepower-21,532 equivalent horsepower used based on BOEM fuel factor and average fuel use

ACTUAL FUEL USAGE FACTORS ASSUMED FOR AQR EMMISSION CALCULATIONS
H

OIL SPILL INFORMATION 

(a) Oil Spill Response Planning 

(i) OSRP Information 

All the proposed activities and facilities in this EP are covered by the Regional Oil Spill 

Response Plan (OSRP) approved on June 24, 2009 and the Oil Spill Response Certification letter 

accepted by BOEM on July 27, 2011 for Anadarko Petroleum Corporation and its subsidiaries, 

Anadarko US Offshore Corporation and Anadarko E&P Company L.P. (Company Numbers 

00981, 02219 and 00148, respectively) in accordance with 30 CFR Part 254. Anadarko 

submitted a revision to its Regional OSRP on July 21, 2011 updating the exploratory WCD to 

Garden Banks Block 346 (Plan Control No. N-9579), and May 17, 2012 updating the > 10 mile 

production WCD volume for Green Canyon 680 A. The revisions are pending approval. 

(ii) Spill Response Sites 

Primary Response Equipment Location(s) Preplanned Staging Location(s) 

Houma, Louisiana 

Harvey, Louisiana 

Venice, Louisiana 

Lake Charles, Louisiana 

Galveston, Texas 

Fourchon, Louisiana 

Harvey, Louisiana 

Venice, Louisiana 

Cameron, Louisiana 

Galveston, Texas 

(iii) OSRO Information 

Anadarko maintains a contract with Clean Gulf Associates (CGA) for spill response equipment. 

Various equipment locations are staged throughout the Gulf of Mexico. CGA equipment can be 

referenced on their website: http://www.cleangulfassoc.com/. Personnel would be obtained from 

the Marine Spill Response Corporation’s (MSRC) STARS network, including a supervisor to 

operate the equipment. 

In addition Anadarko has a contract with the Marine Spill Response Corporation (MSRC) for 

spill response equipment. MSRC stages equipment throughout the Gulf of Mexico and has 

recently completed a large expansion of its resources, with particular focus on deepwater. The expansion 

is known as “Deep Blue”. MSRC capabilities and a complete equipment listing are available online at: http://www.msrc.org/. 

Anadarko is a member of the Helix Well Containment Group (HWCG), a combination of the 

Helix Fast Response System (HFRS) and the common equipment and services. This agreement 

allows access to subsea well containment and well shut-in equipment. 

Anadarko is also a member of the Marine Well Containment Company (MWCC), which 

provides access to containment response capabilities and includes subsea dispersant injection 

equipment. 
(iv) Worst-Case Scenario Determination 

Category Regional OSRP EP EP

Type of Activity Exploratory Exploratory Exploratory 

Facility Location 

(area/block) GB 346 KC 875 KC 919 

Facility Designation * GB 346 “A” KC 875 #002 ST01 KC 919 “F” 

Distance to Nearest 

Shoreline 118 miles 213 miles 213 miles 

 Storage Tanks (total) N/A N/A N/A 

 Flowlines (on facility) N/A N/A N/A 

 Pipelines N/A N/A N/A 

 Uncontrolled Blowout 350,000 bopd** 173,910 bopd 252,000 BOPD 

Type of Oil(s) Oil Oil Oil

API Gravity 30.1o 30.7o 28.0 o

* Note–for the OSRP exploratory worst case discharge scenario only the Area/Block is referenced in the OSRP. Exploratory drilling facility 

designations (proposed well location names) are typically not included in the OSRP. 

** The volume denoted in the Regional OSRP is higher than the NTL No. 2010-N06 (256,700 bopd) and BOEMRE (321,108 

bopd) calculations approved under EP Plan Control No. N-9579. Anadarko elected to denote a higher volume in the 

Regional OSRP for planning purposes to demonstrate equipment response capabilities per previous discussions with Rusty 

Wright.

Anadarko has determined that the worst-case scenarios from the activities proposed in this 

Supplemental EP do not supersede the worst-case scenario for Garden Banks Block 346.

Since Anadarko has the capability to respond to the worst-case spill scenario included in our 

Regional OSRP, and since the worst-case scenarios determined for our EP does not replace the 

worst-case scenario in our revised Regional OSRP submitted on May 17, 2012, I hereby certify 

that Anadarko has the capability to respond, to the maximum extent practicable, to a worst-case 

discharge, or a substantial threat of such a discharge, resulting from the activities proposed in our 

EP.

(b) Worst-Case Discharge Volume Assumptions 

Worst-case discharge (WCD) calculations and assumptions within this section utilized guidelines 

and requirements pursuant with NTL No. 2010-N06. A Revised EP (Control No. R-05138) was 

previously approved for Keathley Canyon Block 875 on April 27, 2011; the revised plan 

included the information necessary to comply with NTL No. 2010-N06. Within the approved 

Revised EP, the WCD volume for Keathley Canyon Block 875 was determined to be 173,910 

BOPD. The supplemental well location requested within this plan does not exceed the 

previously approved WCD volume for Keathley Canyon Block 875; therefore, no additional 

WCD volume assumptions are provided for Keathley Canyon Block 875 in this plan. 

Exxon Mobile Corporation, Anadarko’s partner in the Lucius project and previous operator of 

Keathley Canyon Block 919, received an approved Revised EP (Control No. R-05296) for 

Keathley Canyon Block 919 on November 23, 2011; the revised plan included the information 

necessary to comply with NTL No. 2010-N06. Within the approved Revised EP, the WCD 
volume for Keathley Canyon Block 919 was determined to be 252,000 BOPD. Anadarko has 

determined that the Keathley Canyon Block 919 well locations requested within this plan do not 

exceed the previously approved WCD volume for Keathley Canyon Block 919. Anadarko 

agrees with Exxon’s WCD assumptions used to calculate their total WCD volume. Since 

Anadarko Petroleum Corporation and Exxon Mobile Corporation are partners in Keathley 

Canyon Block 919, no additional WCD volume assumptions for Keathley Canyon Block 919 are 

provided in this plan. 

(c) Oil Spill Response Discussion

For the purpose of NEPA analysis, the largest spill volume originating from the proposed 

activity would be an uncontrolled blowout of the well during drilling operations at 252,000 

BOPD with API gravity of 28.0°. A discussion of the blowout scenario from this proposed 

activity is included within this Supplemental EP in accordance with NTL No. 2010-N06. 

Land Segment and Resource Identification Modeling

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

utilizing information in the Oil Spill Risk Analysis Model (OSRAM) for the Central Gulf of 

Mexico. Additional information may be referenced in the “Oil-Spill Risk Analysis: Contingency 

Planning Statistics for Gulf of Mexico OCS Activities” (OCS Report MMS 2004-026), using the 

average conditional probability for 3, 10, and 30 day impacts. 

Keathley Canyon Block 919 is located within Launch Area 29. According to the BOEMRE 

OSRAM, the trajectory indicates a 2% probability of potential impact to the shoreline in 

Cameron Parish, Louisiana, Matagorda County, Texas, and/or Galveston County, Texas. The 

results are shown in Table H-2. 

Cameron Parish and/or Matagorda County are identified as the most probable potential impacted 

parish or county within the Gulf of Mexico for this operation. Cameron Parish is located in 

Louisiana and includes Cameron Prairie National Wildlife Refuge (NWR), East Cove Unit (a 

part of the Cameron Prairie NWR), Lacassine NWR, and Sabine NWR. Matagorda County is 

located Texas and includes Big Boggy NWR, a portion of San Bernard NWR, and Mad Island 

Wildlife Management Area (WMA). 

Response

Anadarko will make every effort to respond to the worst-case discharge as effectively as 

possible. Response equipment available to respond to the worst-case discharge and the estimated 

time of a spill response from oil spill detection to equipment deployment on-site is included in 

Table H-3. The table estimates individual times needed for procurement, load out, travel time to 

the site and deployment. In the event of an actual incident equipment and times can vary. 

For the purpose of response scenario discussion, an uncontrolled blowout of the well would be 

considered the largest potential spill volume at 252,000 BOPD. An ADIOS weathering model 

was run based on a similar type of oil expected to be produced from this well. Based on this 
information, approximately 13% (32,760 bbls) of the initial volume would be 

evaporated/dispersed within 24 hours.

If approved and appropriate, 4 sorties (8,000 gallons) from the Basler aircraft and 8 sorties 

(9,600 gallons) from two DC-3 aircrafts could disperse approximately 7,540 barrels of oil. 

If the conditions are appropriate, and the necessary approvals and permits have been obtained, 

in-situ burning may be utilized. Based on in-situ burn operations during Deepwater Horizon, 

approximately 5% (10,962 bbls) of the worst case discharge volume after natural 

evaporation/dispersion could potentially be burned. 

Although unlikely in a spill lasting thirty (30) days, potential shoreline impacts in Cameron 

Parish, Louisiana, Matagorda County, Texas, and/or Galveston County, Texas could occur 

depending on environmental conditions (wind, currents and temperature) at the time of an 

incident. Nearshore response may include the use of shoreline boom on beach areas, or 

protection/sorbent boom on vegetated areas. Surveillance and real time trajectories would aide in 

determining the most appropriate strategies to respond to a spill.

Table H.3 provides an example of offshore and nearshore equipment, response times, and 

personnel to respond to a spill of 219,240 BOPD, which is the estimated amount that would 

remain considering natural evaporation/dispersion at 24 hours. This amount could be further 

reduced through the application of aerial and subsea dispersants, provided such applications were 

approved.

Anadarko’s contingency plan for dealing with this worst-case discharge would be to activate its 

Spill Management Team and equipment resources as described in its Gulf of Mexico Regional 

Oil Spill Response Plan (OSRP) and provide continuous support for the duration of the event. 

Response resources are activated and supplemented according to need. These resources would 

remain engaged in the response until the incident is deemed complete or until released by 

Unified Command. 

Anadarko is a member of the Helix Well Containment Group (HWCG), a combination of the 

Helix Fast Response System (HFRS) and the common equipment and services. This agreement 

allows access to subsea well containment and well shut-in equipment. 

Anadarko is also a member of the Marine Well Containment Company (MWCC), which 

provides access to containment response capabilities and includes subsea dispersant injection 

equipment. 

In the event of a blowout, Anadarko may: 

 1. Evacuate personnel, if necessary. Deploy emergency responders in an effort to preserve 

human life, if necessary. 

 2. Assess the damage and attempt to stop the flow at the source, if safe to do so, to reduce 

the amount of oil discharged. 
 3. Notify agencies. 

 4. Assess the amount of oil that has been spilled and calculate additional potential of oil 

flow. A continuous aerial surveillance program would be used to assess the growth of the 

slick and the volume of oil on the water. Observations of the size of the slick on the 

water, combined with observations at the source, would be used to provide a constant 

update. Additional potential to release fuel from the remaining tanks onboard the 

dynamically positioned (DP) semi-submersible drilling rig would be determined by 

marine surveyors. Operations and Unified Command would continue to assess the 

adequacy of response equipment capacities based on this continually updated mass 

balance.

 5. Convene the Spill Management Team (SMT). Organize Unified Command and establish 

objectives and priorities. 

 6. Monitor the oil spill with aerial surveillance and obtain trajectories. If oil is seaward 

bound, going away from land, discuss additional strategies with Unified Command. 

 7. If oil is moving in the direction of a shoreline and weather conditions are favorable, 

request approval to utilize dispersants. 

 a. Prior to commencing application operations, conduct an on-site survey in consultation 

with natural resource specialists to determine if any threatened or endangered species 

are present in the projected application area or otherwise at risk from dispersant 

application.

 b. Upon approval, mobilize one Basler aircraft and two DC-3 aircrafts from Houma, with 

surveillance aircraft and spotter. Mobilize MSRC contracted aircraft(s) if needed. 

Rotate aircraft, spraying the leading edge of the spill and working back to the source. 

Monitor/sample for effectiveness (USCG SMART Team). Truck additional 

dispersants from CGA/MSRC stockpile to Houma, if necessary. 

 c. Dispersants are most effective when applied as soon after discharge as possible, since 

weathering of the oil decreases dispersant effectiveness. The estimated window of 

opportunity for most effective use of dispersants is within 48-72 hours post-release. 

The oil may still be dispersible after 72 hours on the water surface, but the 

effectiveness of dispersant use would likely be diminished after the oil has been on the 

water for more than three days. Ultimately, the USCG SMART monitoring protocol 

will be used to determine whether or not dispersant operations are effective. 

 d. Once the CGA HOSS barge is on location and in the skimming mode, dispersants 

would only be used if required and approved. 

 8. Deploy offshore mechanical oil containment and recovery equipment. Attempt to recover 

as much oil at sea as possible, utilizing: 
 a. The CGA HOSS barge, will be positioned in a stationary mode, will be situated downwind and down-current from location for long-duration, high-volume skimming. 

Based on average travel times, the HOSS barge could be on location within 

approximately 48 hours of the release. The de-rated skimming capacity of the HOSS 

barge is 43,000 bbls per day. However, only the oil encountered by a skimmer can be 

recovered. In order to maximize oil encounter rate, boom will be deployed in a 

V-configuration in front of the HOSS barge to funnel oil to the skimmers. If 

necessary, temporary barges can be activated to support continuous skimming 

operations. (These barges arrive on-site at approximately the same time as the HOSS 

barge.) For an on-going release, multiple barges are deployed to provide for 

continuous off-loading of skimmer storage vessels and shuttling of recovered oil to an 

onshore waste handling facility. Sufficient barges are available to provide enough 

temporary storage for continuous recovery operations. 

 b. CGA’s Fast Response Units (FRU) would arrive on-scene between approximately 

19.75-24 hours of the initial release. These skimmers operate downstream of the 

HOSS barge and are used to recover pockets and streamers of oil that may move past 

the large stationary skimmer. Each FRU has 200 barrels of on-board storage. 

Approval will be requested to decant water after gravity separation, through a hose 

forward of the skimmer, to optimize temporary storage capacity. A 42" Boom will be 

utilized to concentrate oil so that it is thick enough to be skimmed. 

 9. Dispersants, Fast Response Units (FRU), Oil Spill Response Vessels (OSRV or R/V) 

would typically work daylight hours only. The HOSS barge can operate continuously, 

including night operations. Available technology will be considered such as remote 

sensing devices that will enable 24 hour surveillance, trajectories, and planning. All 

response vessels are designed to be able to remain offshore continuously throughout the 

response. Even if sea conditions prohibit effective skimming, these resources would 

remain offshore until skimming operations could be commenced again. Safety would 

remain the first priority. 

 10. Prepare Site-Specific Waste Management Plan, Site Safety Plan, Decontamination Plans, 

Communications and Medical Plans. 

 11. If oil becomes a threat to any shoreline, data from the aerial surveillance, weather reports, 

and trajectories would be used to direct onshore teams to deploy protection/containment 

boom with reference to Area Contingency Plans and in coordination with State and 

Federal On-Scene Coordinators. 

 a. Implement pre-designated strategies. 

 b. Identify resources at risk in spill vicinity. 

 c. Develop/implement appropriate protection tactics. 

 12. Establish Site-Specific Wildlife Rescue and Rehabilitation Plan. 
The following types of additional support may be required for a blowout lasting 120 days. 

x Additional Oil Spill Removal Organization (OSRO) personnel to relieve equipment 

operators 

x Vessels for supporting offshore operations 

x Field safety personnel 

x Continued surveillance and monitoring of oil movement 

x Helicopter, video cameras 

x Infra red (night time spill tracking) capabilities, X-band radar 

x Barge to transport recovered oil from offshore skimming system, and temporary 

storage barges to onshore disposal sites that are identified in Area Contingency Plans 

(ACP)

x Logistics needed to support equipment: 

- Staging areas 

- Parts, trailers, and mechanics to maintain skimmers and boom 

- Fueling facilities 

- Decontamination stations 

- Dispersant stockpile transported from Houston to Houma or other potential 

command post locations 

- Communications equipment and technicians 

x Logistics needed to support responder personnel 

- Medical aid stations 

- Safety personnel

- Food

- Berthing

- Additional clothing/safety supplies 

- Decontamination stations 

Louisiana CZM Containment Response Information 

Anadarko has the capability to respond and contain, to the maximum extent practicable as 

defined in 30 CFR 254.6 and 30 CFR 250.26(d)(1), to the estimated worst case discharge (WCD) 

associated with the proposed activity within 30 days. Deployment time for surface containment 

equipment is subject to availability and location, weather conditions, potential security zones 

around the spill site, and site/well specific assessment data. Personnel safety is always first and 

foremost. Refer to further details on equipment and timing provided in Section H–Oil Spill 

Information and Table H-3 of the EP. 

The potential WCD will be further evaluated during the Application for Permit to Drill (APD) 

process, including the Well Containment Screening Tool (WCST) and associated subsea 

containment plan for enhanced planning purposes. 

There will be no new or unusual technology deployed that has not been previously deployed for 

Gulf of Mexico oil spill prevention, control, and/or cleanup. 
Table H-1 

Worst Case Discharge Calculation 

(Based on Blowout during Drilling Operations)

Calculations for Uncontrolled Blowout> 10 miles from shore: Block 919 

 i. Type of Oil (crude, condensate, diesel) Crude 

 ii. API Gravity 28.0°

 iii. EP Location Used for NTL No. 2010-N06 WCD for KC 919 EP location “F” 

 iv. Largest Anticipated WCD Rate during blowout 252,000 BOPD 

 v. WCD Total for Drilling Operations for KC 919(> 10 miles from shore): 252,000 BOPD 
Table H-2 

Trajectory by Land Segment 

Following are the average conditional probabilities (expressed as percent chance) that an oil spill starting at a 

particular launch area will contact a land segment as included in the Oil Spill Risk Analysis Model (OSRAM) for 

the Central and Western Gulf of Mexico. This information can be found on the BSEE website using 3/10/30 day 

potential impact, as applicable. The results are listed below. 

Area/Block OCS-G Launch 

Area Land Segment and/or Resource 

Conditional Probability (%) 

3

days 

10

days 

30

days 

Keathley Canyon 

Block 919 

Drilling 

(213 miles from 

shore)

G21447 29 

Western 

Planning 

Area

Kennedy County, TX 

Kleberg County, TX 

Aransas County, TX 

Calhoun County, TX 

Matagorda County, TX 

Brazoria County, TX 

Galveston County, TX 

Jefferson County, TX 

Cameron Parish, LA 

Vermilion Parish, LA 

--

--

--

--

--

--

--

--

--

--

--

--

--

--

--

--

--

--

--

--

1

1

1

1

2

1

2

1

2

1
Table H-3 

WCD Scenario Drilling Activities – Based on a single well uncontrolled blowout (213 miles from shore) Keathley Canyon 919 (Location “F”) 252,000 BOPD (initial volume) 219,240 BOPD (after evaporation/dispersion) API Gravity 28.0°

Offshore Equipment from Spill Detection to Equipment Deployment Response Time: Keathley Canyon 919, Location “F” 

Type Derated 

Capacity 

(bbls) 

Storage 

(bbls) 

No. of 

Units/ 

Persons 

Owner/Location Staging Hours to 

Procure 

(1) 

Hours to 

Load Out 

(2) 

Travel 

(Staging/ 

Spill) 

(3) 

Hours to 

Deploy 

(4) 

Total 

Estimated 

Hours 

DC 3 Spray Aircraft Aero Commander 

-- -- 

-- -- 

2

2 each ASI/Houma Houma 1 1 1.5 0 3.5 

Basler Spray Aircraft Aero Commander 

-- -- 

-- -- 

12 CGA/Houma Houma 1 1 1.25 0 3.25 

HOSS Barge Operators Tugs 

43,000 4,000 1 

83

CGA/Harvey STARS VOO 

Harvey 

7 0 37.5 1 43.5 

FRU Operators Utility Boat 

4,251 200 1 

61

CGA/Galveston STARS VOO 

Galveston 

1 2 27 1 31 

FRU Operators Utility Boat 

4,251 200 1 

61

CGA/Lake Charles STARS VOO 

Cameron 

1 2 24 1 28 

FRU Operators Utility Boat 

4,251 100 1 

61

CGA/Harvey STARS VOO 

Harvey 

1 2 21 1 25 

FRU Operators Utility Boat 

8,502 400 2 

12 

2

CGA/Venice STARS VOO 

Venice 

1 2 24 1 26 

FRU Operators Utility Boat 

8,502 400 2 

12 

2

CGA/Leeville STARS VOO 

Leeville 

1 2 20 1 24 

FRU Operators Utility Boat 

4,251 200 1 

61

CGA/Morgan City STARS VOO 

Morgan City 

1 2 22 1 26 

Koseq Skimming Arms Operators Vessel w/ storage/hull 

89,150 

10,000 

5 sets 

30 

1

CGA/Galveston STARS VOO 

Galveston 

4 12 27 2 45 

Koseq Skimming Arms Operators Vessel w/ storage/hull 

53,490 

6,000 

3 sets 

18 

1

CGA/Leeville STARS VOO 

Leeville 

4 12 20 2 38 

Koseq Skimming Arms Operators Vessel w/ storage/hull 

17,830 

2,000 

1 set 

61

CGA/Fourchon STARS VOO 

Fourchon 

4 12 21 2 37 

Gulf Coast Responder Transrec 350 + OSRV 5,280' 44" Sea Sentry Boom 

2,640' 67" LAMOR 

10,567 4,000 1 

1

14 crew MSRC/Lake Charles Cameron 

2 0 24 1 27 

Deep Blue Responder 18,086 4,000 1 MSRC/Fourchon Fourchon 
Type Derated 

Capacity 

(bbls) 

Storage 

(bbls) 

No. of 

Units/ 

Persons 

Owner/Location Staging Hours to 

Procure 

(1) 

Hours to 

Load Out 

(2) 

Travel 

(Staging/ 

Spill) 

(3) 

Hours to 

Deploy 

(4) 

Total 

Estimated 

Hours 

LFF 100 Brush + OSRV 6,600' 44" Sea Sentry Boom 

660' 67" LAMOR 

1

14 crew 

2 0 21 1 24 

Louisiana Responder Transrec 350 + OSRV 2,640' 44" Sea Sentry II Boom 

5,280' 67" LAMOR 

10,567 4,000 1 

1

14 crew MSRC/Fort Jackson Venice 

2 0 24 1 27 

PSV – HOS Centerline 1 Crucial Disk 88/30 1,320' EFC

11,122 10,626 1 

14 crew MSRC/Fourchon Fourchon 

2 0 25 1 28 

PSV – HOS Strongline 1 Crucial Disk 88/30 1,320' EFC

11,122 10,626 1 

14 crew MSRC/Fourchon Fourchon 

2 0 25 1 28 

Stress I Skimmer/Bladder Utility Boat 

15,840 500 1 

6 crew MSRC/Fourchon Fourchon 1 2 23 1 27 

MSRC 570 Offshore Barge Tugs 2 Crucial Disk 88/30 2,640' 44" Sea Sentry II Boom 

22,244 56,900 1 

31

6 crew 

MSRC/Galveston VOO 

Galveston 

2 0 36 1 39

MSRC 452 Offshore Barge Tugs 1 Crucial Disk 88/30 1,980' 44" Sea Sentry II Boom 

660' 67" LAMOR 

11,122 45,000 1 

31

6 crew 

MSRC/Fort Jackson VOO 

Venice 

2 0 28 1 31 

CTCo 5001 Operators Tug 

-- 47,000 1 

61

EMS-CGA/Amelia EMS VOO 

Amelia 

4 12 31 1 48 

CTCo 2604 Operators Tug 

-- 20,000 1 

61

EMS-CGA/Amelia EMS VOO 

Amelia 

4 12 31 1 48 

Pacific Operators Tug 

-- 80,000 1 

61

K-Sea-CGA/Venice K-Sea VOO 

Venice 

4 12 26 1 43 

DBL 76 Operators Tug 

-- 83,937 1 

61

K-Sea-CGA/Venice K-Sea VOO 

Venice 

4 12 26 1 43 

5,000' 42" Auto Boom VOO 

-- -- 20 

10 crew 

CGA/Galveston STARS Galveston 1 2 27 1 31 

5,000' 42" Auto Boom VOO 

-- -- 20 

10 crew 

CGA/Lake Charles STARS Cameron 1 2 24 1 28 

10,000' 42" Auto Boom VOO 

-- -- 40 

20 crew 

CGA/Harvey STARS Harvey 1 2 20 1 24 

2,500' 42" Auto Boom VOO 

-- -- 12 

6 crew 

CGA/PascagoulaSTARS Pascagoula 1 2 25 1 29 

4,290' 44" Sea Sentry II Boom VOO 

-- -- 20 

10 crew 

MSRC/GalvestonSTARS Galveston 1 2 27 1 31 

6,679' 44" Sea Sentry II Boom VOO 

-- -- 20 

10 crew 

MSRC/Lake Charles STARS Cameron 1 2 24 1 28 
Type Derated 

Capacity 

(bbls) 

Storage 

(bbls) 

No. of 

Units/ 

Persons 

Owner/Location Staging Hours to 

Procure 

(1) 

Hours to 

Load Out 

(2) 

Travel 

(Staging/ 

Spill) 

(3) 

Hours to 

Deploy 

(4) 

Total 

Estimated 

Hours 

1,980' 44" Sea Sentry II Boom VOO 

-- -- 12 

6 crew 

MSRC/Fort Jackson STARS Venice 1 2 25 1 29 

3,190' 44" Sea Sentry II Boom VOO 

-- -- 20 

10 crew 

MSRC/Pascagoula STARS Pascagoula 1 2 25 1 29 

Spotter Helo Surveillance Helo Hand Held Radios 

-- -- -- 

-- -- -- 

11

30 

PHI/Fourchon PHI/Fourchon STARS 

Spill Site Spill Site Fourchon 

11

1.5 

-- -- -- 

222

-- -- -- 

33

3.5 

Estimated Total: 348,148 390,089 

EDRC Storage 

Spill Team Area Responders (STARS) called out by Marine Spill Response Corporation (MSRC) Vessel of Opportunity=VOO EMS=Enterprise Marine Services (available through contract with CGA) 
Nearshore Equipment from Spill Detection to Equipment Deployment Response Time: Keathley Canyon 919, Location “F” 

Type Derated 

Capacity 

(bbls) 

Storage 

(bbls) 

No. of 

Units/ 

Persons 

Owner/Location Nearshore 

Staging 

Hours to 

Procure 

(1) 

Hours to 

Load Out 

(2) 

Travel 

(Staging/ 

Spill) 

(3) 

Hours to 

Deploy 

(4) 

Total 

Estimated 

Hours 

DC 3 Spray Aircraft Aero Commander 

-- -- 

-- -- 

2

2 each ASI/Houma Houma 1 1 10 3

Basler Spray Aircraft Aero Commander 

-- -- 

-- -- 

12 CGA/Houma Houma 1 1 .5 0 2.5 

SWS Egmopol Operators 

3,000 100 1 

3

CGA/Galveston STARS Galveston 1 2 5.5 2 8.5 

SWS Marco Operators 

3,588 20 1 

3

CGA/Lake Charles STARS Cameron 1 2 30 6

SWS Marco Operators 

3,588 34 1 

3

CGA/Leeville STARS Fourchon 1 2 60 9

SWS Marco Operators 

3,588 34 1 

3

CGA/Venice STARS Venice 1 2 8.5 0 11.5 

Trinity SWS Operators 

21,500 249 1 

4

CGA/Galveston STARS Galveston 1 2 4.5 0 7.5 

Trinity SWS Operators 

21,500 249 1 

4

CGA/Leeville STARS Fourchon 1 2 50 8

Trinity SWS Operators 

21,500 249 1 

4

CGA/Venice STARS Venice 1 2 7.5 0 10.5 

R/V Grand Bay Operators 

5,000 65 1 

3

CGA/Venice STARS Venice 2 .5 11 0 13.5 

R/V RW Armstrong Operators 

5,000 65 1 

3

CGA/Leeville STARS Fourchon 2 .5 8.5 0 11 

R/V Bastian Bay Operators 

5,000 65 1 

3

CGA/Lake Charles STARS Cameron 2 .5 5 0 7.5 

R/V Timbalier Bay Operators 

5,000 65 1 

3

CGA/Galveston STARS Galveston 2 .5 4 0 6.5 

Foilex 250 Skimmer Storage Bladder 

3,977 500 1 

3 MSRC/Galveston Galveston 2 .5 5 .5 8

Foilex 250 Skimmer Storage Bladder 

3,977 500 1 

3 MSRC/Lake Charles Cameron 2 .5 6 .5 9

Foilex 250 Skimmer Storage Bladder 

3,977 500 1 

3 MSRC/Fort Jackson Fourchon 2 .5 4 .5 7

GT 185 Storage Bladder 

1,371 500 1 

3 MSRC/Pascagoula Pascagoula 2 .5 7.5 .5 10.5 

CTCo 2603 Operators Tug 

-- 25,000 1 

61

EMS-CGA/Amelia EMS VOO 

Amelia 

4 12 15 1 32 

CTCo 2605 Operators Tug 

-- 20,000 1 

61

EMS-CGA/Amelia EMS VOO 

Amelia 

4 12 15 1 32 

CTCo 2606 Operators Tug 

-- 20,000 1 

61

EMS-CGA/Amelia EMS VOO Amelia 4 12 15 1 32 

CTCo 2608 -- 23,000 1 EMS-CGA/Amelia Amelia 
Type Derated 

Capacity 

(bbls) 

Storage 

(bbls) 

No. of 

Units/ 

Persons 

Owner/Location Nearshore 

Staging 

Hours to 

Procure 

(1) 

Hours to 

Load Out 

(2) 

Travel 

(Staging/ 

Spill) 

(3) 

Hours to 

Deploy 

(4) 

Total 

Estimated 

Hours 

Operators Tug 

61

EMS VOO 4 12 15 1 32 

CTCo 2609 Operators Tug 

-- 23,000 1 

61

EMS-CGA/Amelia EMS VOO 

Amelia 

4 12 13 1 30 

2,000' Beach Boom -- -- 6 CGA/Pascagoula Pascagoula 1 2 3 2 8 10,000' 18" Boom VOO 

-- -- 10 

4 crew Oil Mop/Port Arthur Galveston 01 1 2.5 3 7.5 

10,000' 18" Boom VOO 

-- -- 10 

4 crew Oil Mop/New Iberia Morgan City 1 1 7 3 12 

10,000' 18" Boom VOO 

-- -- 10 

4 crew Oil Mop/Port Allen Fourchon 01 1 6.25 3 11.25 

10,000' 18" Boom VOO 

-- -- 10 

4 crew Oil Mop/Houma Fourchon .5 1 1 6 3 11 

20,000' 18" Boom VOO 

-- -- 20 

8 crew Oil Mop/Belle Chasse Venice .5 1 1 7 6 15 

15,000' 18" Boom VOO 

-- -- 14 

6 crew Oil Mop/Gretna Venice 01 1 8 4 14 

42,000 18" Boom VOO 

-- -- 40 

16 crew AMPOL/New Iberia Morgan City 01 0 7 12 20 

Wildlife Support Trailer -- -- 1/ 2 crew CGA/Harvey Venice 1 1 2 2 6 Bird Scare Cannons -- -- 1 CGA/Galveston Galveston 1 1 1 2 5 Bird Scare Cannons -- -- 2 CGA/Lake Charles Cameron 1 1 3.5 2 7.5 Bird Scare Cannons -- -- 2 CGA/Harvey Venice 1 1 1.5 2 5.5 Bird Scare Cannons -- -- 2 CGA/Venice Venice 1 1 2 2 6 Bird Scare Cannons -- -- 2 CGA/Pascagoula Pascagoula 1 1 4.5 2 8.5 Spotter Helo Surveillance Helo Hand Held Radios 

-- -- -- 

-- -- -- 

11

30 

PHI/Fourchon PHI/Fourchon STARS 

Spill Site Spill Site Fourchon 

11

1.5 

-- -- -- 

.5 .5 

1.5 

-- -- -- 

1.5 1.5 

3

Estimated Total: 111,566 114,195 

EDRC Storage 

*Some equipment may be used offshore up to approximately 25 miles from shore
 

H-3 (continued) 

Operational Limitations of Response Equipment 

x HOSS Barge–8 foot seas 

x Fast Response Unit (FRU)–8 foot seas 

x Oil Spill Response Vessel (OSRV and R/V)–4 foot seas 

x Boom–3 foot seas, 20 knot winds 

x Dispersants–winds more than 25 knots, visibility less than 3 nautical miles or ceiling less than 

1,000 feet 
 

I

Environmental Monitoring and Environmental Mitigation Measures 

(a) Monitoring 

If required, Anadarko will monitor loop currents per NTL 2005-G05. 

Anadarko subscribes to Wilkins Weather Service which provides real-time weather 

conditions such as tropical depressions, storms and/or hurricanes entering the Gulf. 

(b) Incidental Takes

Although marine mammals may be seen in the area, Anadarko does not believe that its 

operations proposed under this EP will result in the harassment, capture, collection or 

killing of any mammals covered by the Marine Mammal Protection Act. 

Anadarko will operate in accordance with applicable regulations, including: 

NTL No. 2007-G02 – “Implementation of Seismic Survey Mitigation Measures and 

Protected Species Observer Program” 

BSEE NTL No. 2012-G01 “Marine Trash and Debris Awareness and Elimination”, and 

JOINT NTL No. 2012-G01 “Vessel Strike Avoidance and Injured/Dead Protected 

Species Reporting” 
 

J

LEASE STIPULATIONS INFORMATION 

Lease Sale # 174: 

Keathley Canyon Blocks 875 and 919 are not located in a Biologically Sensitive Area, 

Military Warning Area or Shipping Fairway. 

Marine Protected Species: This stipulation requires operators to collect and remove 

flotsam resulting from their activities; to post signs detailing why release of debris must 

be eliminated; watch for protected marine mammals and see turtles (includes speed and 

distance parameters if mammals or turtles are sited); reports sightings and locations of 

dead or injured marine mammals or turtles and if the operators activities are responsible 

remain available to assist in the recovery and comply with applicable mitigation measures 

when conducting seismic operations. It also requires operators to comply with applicable 

Notices to Lessees which contain further restrictions regarding protection of marine 

mammals and turtles. 
 

K

Support Vessels and Aircraft Information 

(a) General 

Type Max. Total Fuel Tank 

Storage Capacity 

Max. No. in Area at 

any Time 

Trip Frequency or 

Duration 

Supply Vessel 336,227 gallons 1 2 trips/week 

Helicopter 735.3 gallons 1 10 trips/week 

Crew Vessel 50,000 gallons 1 3 trips/week 

Tug Boats 218,300 gallons 1-2 Duration of operation 

Anchor Handling Vessel 450,698 gallons 1-2 Duration of operation 

(b) Diesel Oil Supply Vessels 

Fuel for the rig will be transported via a supply vessel as follows: 

a. Size of fuel supply vessel: 230 feet 

b. Carrying capacity of fuel supply vessel: 336,227 gallons 

c. Frequency that fuel supply vessel will visit the facilities: twice per week 

d. Routes the fuel supply vessel will use to travel between 

the onshore support base and proposed facility: 

6 miles from Port Fourchon to the mouth of 

Bayou Lafourche, then approximately 230 miles 

to KC 875/919. 

(c) Vicinity Map 

A vicinity map is included in this section as Attachment K-1. 

(d) Produced Liquid Hydrocarbons Transportation Vessels 

Produced liquid hydrocarbons from future flow tests on wells in Keathley Canyon Blocks 875 & 

919 will be transported by barge. Flow tests will not exceed 48 hours/well without further 

approval. 

Transport Method Vessel Capacity Average Volume to be Loaded 

(per transfer) 

No. of Transfers 

(Yearly Average) 

Barge 30,000-50,000 bbls 25,000 bbls 2-3 

Production will be routed from the well through surface well test equipment and safety controls 

aboard the rig. Gas will be flared and liquids (oil, condensate & water) will be collected in US 

Coast Guard approved tanks and a barge. We propose to route the production (approximately 

15,000bbls) to test separators located on the rig and to measure the liquid hydrocarbons using 

various meters. A three phase separator will be used to analyze water cut if present. Liquid 

hydrocarbons will then be transferred to a coast guard approved barge via tested & approved 

petroleum transfer hose. We will have a Safe Breakaway Coupling (KLAW) installed between 

the hoses connecting the barge-end and the rig-end. If this device parts the KLAW is designed to 

contain all fluids from both hoses.
 

(e) Solid and Liquid Wastes Transportation 

Type of 

Waste 

Composition Total 

Projected 

Amount 

Rate Transport 

Method 

Name/Location of 

Facility 

Disposal 

Method 

Syntheticbased drilling 

fluid or mud 

Syntheticbased drilling 

muds

66,000 bbls 11,000 bbls/well Re-use 

and/or

transport to 

shore in 

DOT

approved

containers.

Waste - Port Fourchon, 

LA and on to Newpark 

Fourchon Transfer 

Station #1 & #2. 

Newpark Transfer 

Station Morgan City. 

Newpark Transfer 

Station Port Arthur. 

USLL Galveston and 

Fourchon Transfer 

Station. If recycled, 

returned to vendor 

(Bariod or MI). 

Re-used and/or 

recycled; if can’t 

be reused and/or 

recycled the waste 

is disposed of at 

Newpark (injection 

disposal facility) or 

USLL (landfarm). 

Cuttings

wetted with 

syntheticbased muds 

Cuttings

coated with 

synthetic 

drilling muds, 

including 

drilled out 

cement 

600-1,200

bbls

100-200

bbls/well* 

*An estimated 

5-10% of cuttings 

may be 

transported to 

shore

Re-use

and/or

transport to 

shore in 

DOT

approved

containers.

Waste - Port Fourchon, 

LA and on to Newpark 

Fourchon Transfer 

Station #1 & #2. 

Newpark Transfer 

Station Morgan City. 

Newpark Transfer 

Station Port Arthur. 

USLL Galveston and 

Fourchon Transfer 

Station. If recycled, 

returned to vendor 

(Bariod or MI). 

Re-used and/or 

recycled; if can’t 

be reused and/or 

recycled the waste 

is disposed of at 

Newpark (injection 

disposal facility) or 

USLL (landfarm). 

Chemical 

product waste 

(well

treatment 

fluids)

Ethylene 

glycol 

Methanol

2,330 bbls 

582.5 bbls 

100

bbls/month/well

25

bbls/month/well

Transport to 

shore in 

DOT

approved

containers

for pick up 

Chemwaste in Sulphur, 

LA and Veolia Port 

Arthur, TX or to 

Newpark, Port Arthur 

as non-hazardous waste. 

Can be returned to 

vendor and/or used 

at another facility; 

MEG is solidified 

and disposed of in 

a landfill. 

Methanol is 

incinerated or used 

for fuels blending. 

Completion 

fluids

Brine, spent 

acid, prop 

sand, debris 

18,000 bbls 3,000 bbls/well Transport to 

shore in 

DOT

approved

containers

and/or vessel 

tanks for 

pick up 

Sent to Port Fourchon, 

LA and on to Newpark 

Fourchon Transfer 

Station #1 & #2. 

Newpark Transfer 

Station Morgan City. 

Newpark Transfer 

Station Port Arthur. 

USLL Galveston and 

Fourchon Transfer 

Station 

Unused brine can 

be returned to 

vendor and/or 

stored for use on 

another job. Used 

brine and spent 

acid is transferred 

to Newpark's 

Processing & 

Transfer facility 

for injection. 

Workover

fluids

Brine, spent 

acid, prop 

sand, debris 

18,000 bbls 3,000 bbls/well Transport to 

shore in 

DOT

approved

containers

and/or vessel 

tanks for 

pick up 

Sent to Port Fourchon, LA 

and on to Newpark 

Fourchon Transfer Station 

#1 & #2. Newpark 

Transfer Station Morgan 

City. Newpark Transfer 

Station Port Arthur. USLL 

Galveston and Fourchon 

Transfer Station 

Unused brine can be 

returned to vendor 

and/or stored for use 

on another job. Used 

brine and spent acid 

is transferred to 

Newpark's Processing 

& Transfer facility 

for injection. 
 

Trash and 

debris

Refuse

generated 

during

operations

1,165 bbls 50 bbls/month/well Transport to 

shore in 

disposal

bags by 

vessel to 

shorebase 

for pickup 

by municipal 

operations

Recycled Material in 

ARC, New Iberia, LA. 

Trash disposed of at 

SWDI landfill. 

Recycled and/or 

disposed in 

landfill. 

Used oil Excess oil 

from engines 

2,504.7 bbls 430 bbls/120 

days/well 

Transport in 

DOT

approved

containers to 

shore for 

pick up 

American Recovery 

Fourchon, LA 

Recycled 

*Total amount assumes 6 wells will take a total of 699 days to drill and complete 
Keathley Canyon Blocks 875 and 919 June 2012

Environmental Impact Analysis for Supplemental Exploration Plan Page 2

Figure 1. Location of Keathley Canyon Blocks 875 and 919.