# 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 P lan, Anadarko Petroleu m Corporation (Anadarko) proposes to drill and complete six wells total in Keathley Canyon Blocks 8 75 & 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 Pl an 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. Previous ly approved, undrilled well locations fro m Plan Control No.’s N-9428 and S9593 are being carried forward in th e activity schedule to reflect Anadarko ’s current planning schedule for drilling and completion activities within Keathl ey 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 cont rol, pollution prev ention, 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 regula tions 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



## Descri p tion of Drillin g Ri g Descri p tion of Production Platform

Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform rig Well protector Compliant tower

Semisubmersible Submersibl e 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 pa rt of an applicant’s Exploration Plan or Development Operations Coordination Docume nt 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 re spond 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 re porting burden for this form is included in the burden for prep aring Exploration Plans and Development Operations Coordination Document s. 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 comple ting and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Inform ation 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 pa rt of an applicant’s Exploration Plan or Development Operations Coordination Docume nt 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 re spond 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 re porting burden for this form is included in the burden for prep aring Exploration Plans and Development Operations Coordination Document s. 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 comple ting and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Inform ation 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 pa rt of an applicant’s Exploration Plan or Development Operations Coordination Docume nt 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 re spond 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 re porting burden for this form is included in the burden for prep aring Exploration Plans and Development Operations Coordination Document s. 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 comple ting and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Inform ation 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 pa rt of an applicant’s Exploration Plan or Development Operations Coordination Docume nt 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 re spond 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 re porting burden for this form is included in the burden for prep aring Exploration Plans and Development Operations Coordination Document s. 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 comple ting and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Inform ation 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 pa rt of an applicant’s Exploration Plan or Development Operations Coordination Docume nt 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 re spond 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 re porting burden for this form is included in the burden for prep aring Exploration Plans and Development Operations Coordination Document s. 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 comple ting and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Inform ation 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 pa rt of an applicant’s Exploration Plan or Development Operations Coordination Docume nt 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 re spond 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 re porting burden for this form is included in the burden for prep aring Exploration Plans and Development Operations Coordination Document s. 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 comple ting and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Inform ation 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” WCDvolume 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 3 rd 

## 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 nearestexisting 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 requiresseafloor 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 proposedwell 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 SpectrumTOPHOLE PROGNOSIS CHARTLOCATION BBLOCK 875, KEATHLEY CANYON AREABML: Below MudlineBSS: Below Sea SurfaceAll depths and thicknesses areapproximate and are based on aseismic depth volume provided byAnadarko



### 4051-ANA-GOM Figure Appendix C-KC875B-1-7000-7500-8000-8500-9000-9500-10000-10500-11000-11500-12000-12500-130008359Trace:Inferred Lithologyand CommentsEvent andUnitDesignationsDepthsBML(ft)BSS(ft)Thickness (ft)UNIT(ft)HazardousShallow GasRiskShallowWater FlowRisk3-D Seismic Record atProposed Location BKeathley Canyon Block 875X = 1,952,916 ft, Y = 9,474,150 ftSeafloor gradient is 4.4o to the west.1,000 ftLine 9380 KC875 B

Depth below sea surface (ft)Unit 1 has normal marine clays.Unit 2 is composed of clay-prone massmovement deposits. The reflectors aresubparallel with moderate to highamplitudes.The upper section of Unit 3 is composedof parallel sandy-clay depositsintercalated with thin mass transportdeposits.The middle section of Unit 3 has highamplitude reflectors interpreted to besandy sediments.The lower section of Unit 3 isrepresented by mass transport clayprone deposits intercalated with sandylayer towards the bottom of the sectionAt the well bore the top of salt is clearlydefined with a slope of 30o to thenortheast.1172SUBUNIT(ft)0 6928164164 7092587751 76792290 921835112692 96204262 1119018106072 13000SEAFLOORUnit 1164NEGLIGIBLE NEGLIGIBLEH 10Unit 2587NEGLIGIBLE NEGLIGIBLEH 201539NEGLIGIBLE NEGLIGIBLEUnit 3402NEGLIGIBLE LOW800NEGLIGIBLE NEGLIGIBLETOPSALT1810NEGLIGIBLE NEGLIGIBLE15701039034624031 10959F1EWNEGLIGIBLE LOW9380.07879.09380.07999.09380.08119.09380.08239.09380.08359.09380.08479.09380.08599.09380.08719.09380.08839.09380.08959.0Line:Trace:50001000015000200002500030000350004000045000Offset:-6000-7000-8000-9000-10000-11000-12000

Depth below sea surface (ft)PositiveRelativeAmplitudeNegative~5000 feet3-D Depth Seismic Record, Line 9380, Location B, Block 875, Southeastern Keathley CanyonWEKC875BKC876



### Figure Appendix C-KC875B-2 

### Report No. 4051-ANA-GOMSeafloorHor. 10Hor. 20Top of SaltKC874BryantCanyonKC875SALT8040.08365.08440.08365.08840.08365.09240.08365.09640.08365.010040.08365.010440.08365.010840.08365.011240.08365.011640.08365.0Line:Trace:50001000015000200002500030000350004000045000Offset:-6000-7000-8000-9000-10000-11000-12000

Depth below sea surface (ft)PositiveRelativeAmplitudeNegative~5000 feet3-D Depth Seismic Record, Crossline 8365, Location B, Block 875, Southeastern Keathley CanyonSNKC875BKC831KC919



### Figure Appendix C-KC875B-3 

### Report No. 4051-ANA-GOMSeafloorHor. 10Hor. 20Top of SaltKC875SALT

## 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

### K C8 7 5

- Amp and P o w er Spectra N ote: Se i sm i c data i s i n the depth doma i n . F re q uency ( Hz ) i s computed from wavenumber by assum i ng a constant ve l oc i ty of 7500 ft / s

.



### 4 0 51

- ANA

- GOM 

### 0 .4 0

. 5 0

. 6 0

. 7 0

. 8 0

. 9

1Amplitude 

# Repro c e ss e d D ata A m p li t ud e Spe c tr um Propo s e d
We ll Lo c at i on s KC875 B l o ck

0 0

. 1 0

. 2 0

. 3

Fre qu en cy 0 20 4 0 60 80 100 120 1 4 0 Wa v en umb er

KC875 A

KC875 B

KC875 C 50 Hz e q u i va l ent 

### 0 0

. 002 0

. 00 4 0

. 006 0

. 008 0

. 01 0

. 012 0

. 01 4 0

. 016 0

. 018 0

. 02

0 .4 0

. 5 0

. 6 0

. 7 0

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1Power 

# Repro c e ss e d D ata Po w er Spe c tr um Propo s e d
We ll Lo c at i on s KC875 B l o ck

0 0

. 1 0

. 2 0

. 3

0 20 4 0 60 80 100 120 1 4 0

Fre qu en cy Wa v en umb er

KC875 A

KC875 B

KC875 C 50 Hz e q u i va l ent 

### 0 0

. 002 0

. 00 4 0

. 006 0

. 008 0

. 01 0

. 012 0

. 01 4 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 -7200ABKC874G26771Devon Energy Production Company, L.P.Union Oil Company of CaliforniaKC918G32654Petrobras America Inc.KC875G21444Devon Energy Production Company, L.P.Kerr-McGee Oil & Gas CorporationKC919G21447Exxon Mobil CorporationKC920G21448Exxon Mobil CorporationKC876(open)

13,000 ft Radius

5,000 ft RadiusCLocation MapGrid North

E 1,950,000 E 1,955,000

E 1,940,000 E 1,940,000 E 1,945,000N 9,470,000 N 26° 05' 00" N 26° 05' 00"SPHEROID: Clarke 1866 INVERSE FLATTENING:1/294.978698SEMIMAJOR AXIS:6,378,206.40 ftSCALE FACTOR: 0.9996PROJECTION: Transverse Mercator CENTRAL MERIDIAN: 93° WDATUM:NAD27 LATITUDE OF ORIGIN: 0°ZONE:UTM Zone 15 NorthFALSE EASTING:1,640,416.666667 ftLINEAR UNITS:Survey FeetFALSE NORTHING:0 ftGeodetic InformationInterpretive InformationBasemap InformationLN 831032°N97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W25°N26°N27°N28°N29°N30°N31°N32°N25°N26°N27°N28°N29°N30°N31°NAmery TerraceEast BreaksGarden BanksGreen CanyonAtwater ValleyDestin DomeMississippi CanyonDe Soto CanyonLloyd RidgeHendersonFlorida PlainLundLund SouthWalker RidgeKeathley CanyonAlaminos CanyonSigsbee EscarpmentTexasLouisianaMississippiAlabamaFloridaBrownsvilleCorpus ChristiPort LavacaFreeportGalvestonHoustonThe WoodlandsPort ArthurLake CharlesLafayetteMorgan CityNew OrleansBiloxiPascagulaMobilePensacolaHouma0 25 50 100Nautical MilesWestCameronWestCameronWestWestCameronSouthWestDeltaGrandIsleEugeneIslandN 9,465,000N 9,465,000KC875BA 1,500 ft radius circle around well surface location isshown as required by Notice to Lessees 2000-G20Proposed Well Surface Location and DesignationLN 9910TR 84403D Seismic Survey Line, Trace, and Designation(LN=Line) (TR=Trace)Lease Block Boundary: Block Number, Lease Numberwith Operator and Primary Lease Holder shownSubsurface Mapping AreaSeafloor Mapping Area (mig16f_psdm_wem_final_feet)

TR 8050Notes: 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, andAOA 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° 06' 00" N 26° 08' 00" N 26° 06' 00" N 26° 08' 00"Seafloor Mapping Area (mig16f_rtm_0307revtmmigsim)Lowest Contour of Local Depression

-7000Water Depth Contours: 50 ft intervalNormal fault with seafloor expression. Symbol showsdownthrown side and direction of fault dipSmall minibasins and depressionsRidges and gullies associated with Bryant CanyonPossible high-density chemosynthetic communities

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 8680LN 8410LN 8510LN 8610LN 8710LN 8810LN 8910LN 9010LN 9110LN 9210LN 9310LN 9410LN 9510LN 9610LN 9710LN 9810LN 9910LN 10010LN 10110LN 10210LN 10310N 9,475,000N 9,480,000N 9,485,000N 9,470,000N 9,475,000N 9,480,000N 9,485,000

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"1:12,000Anchor Chart BPrepared for:Anadarko Petroleum CorporationFeet0 500 1000 2000 3000 4000 5000INTERPRETATION: B. Monsalve, J. GharibGIS/CAD: B. DillardDATE: 8/21/2009REPORT NO: 4051-ANA-GOMFILE: 4051_Anchor_Chart_KC875_B_12.dwg2500 Tanglewilde, Suite 120Houston, TX 77063(713) 532-26247532 Sandholdt Road, Suite 6Moss Landing, CA 95039(831) 633-7400Gulf of MexicoKC875Water Depth & Seafloor FeaturesShowing Potential Anchor TouchdownArea for Proposed Well KC875 BKeathley Canyon (KC)KC875 and VicinityApproximate 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 8680LN 10410LN 8310LN 8410LN 8510LN 8610LN 8710LN 8810LN 8910LN 9010LN 9110LN 9210LN 9310LN 9410LN 9510LN 9610LN 9710LN 9810LN 9910LN 10010LN 10110LN 10210LN 10310LN 10410

E 1,965,000 E 1,965,000N 9,460,000N 9,460,000Irregular relief associated with shallow salt andBryant Canyon001002001 13,000 ft Radius

5,000 ft RadiusDEFGHKC874G26771Devon Energy Production Company, L.P.Union Oil Company of CaliforniaKC918G32654Exxon Mobil CorporationPetrobras America Inc.KC875G21444Devon Energy Production Company, L.P.Kerr-McGee Oil & Gas CorporationKC919G21447Exxon Mobil CorporationKC920(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

-7200Location MapGrid North

E 1,950,000 E 1,955,000

E 1,940,000 E 1,940,000 E 1,945,000N 9,470,000 N 26° 05' 00" N 26° 05' 00"SPHEROID: Clarke 1866 INVERSE FLATTENING:1/294.978698SEMIMAJOR AXIS:6,378,206.40 ftSCALE FACTOR: 0.9996PROJECTION: Transverse Mercator CENTRAL MERIDIAN: 93° WDATUM:NAD27 LATITUDE OF ORIGIN: 0°ZONE: UTM Zone 15 North FALSE EASTING:1,640,416.666667 ftLINEAR UNITS:Survey FeetFALSE NORTHING: 0 ftGeodetic InformationInterpretive InformationBasemap InformationLN 851032°N97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W25°N26°N27°N28°N29°N30°N31°N32°N25°N26°N27°N28°N29°N30°N31°NAmery TerraceEast BreaksGarden BanksGreen CanyonAtwater ValleyDestin DomeMississippi CanyonDe Soto CanyonLloyd RidgeHendersonFlorida PlainLundLund SouthWalker RidgeKeathley CanyonAlaminos CanyonSigsbee EscarpmentTexasLouisianaMississippiAlabamaFloridaBrownsvilleCorpus ChristiPort LavacaFreeportGalvestonHoustonThe WoodlandsPort ArthurLake CharlesLafayetteMorgan CityNew OrleansBiloxiPascagulaMobilePensacolaHouma0 25 50 100Nautical MilesWestCameronWestCameronWestWestCameronSouthWestDeltaGrandIsleEugeneIslandN 9,465,000N 9,465,000KC875DA 2,000 ft radius circle around well surface location isshown as required by Notice to Lessees 2009-G40Proposed Well Surface Location and DesignationLN 9910TR 84403D Seismic Survey Line, Trace, and Designation(LN=Line) (TR=Trace)Lease Block Boundary: Block Number, Lease Numberwith Operator and Primary Lease Holder shownSubsurface Mapping AreaSeafloor Mapping Area (mig16f_psdm_wem_final_feet)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, andAOA 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° 06' 00" N 26° 08' 00" N 26° 06' 00" N 26° 08' 00"Seafloor Mapping Area (mig16f_rtm_0307revtmmigsim)Lowest Contour of Local Depression

-7000Water Depth Contours: 50 ft intervalNormal fault with seafloor expression. Symbol showsdownthrown side and direction of fault dipSmall minibasins and depressionsRidges and gullies associated with Bryant CanyonPossible high-density deepwater benthic communities

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 8590LN 8610LN 8710LN 8810LN 8910LN 9010LN 9110LN 9210LN 9310LN 9410LN 9510LN 9610LN 9710LN 9810LN 9910LN 10010LN 10110LN 10210LN 10310LN 8510LN 8610LN 8710LN 8810LN 8910LN 9010LN 9110LN 9210LN 9310LN 9410LN 9510LN 9610LN 9710LN 9810LN 9910LN 10010LN 10110LN 10210LN 10310N 9,475,000N 9,480,000N 9,485,000N 9,470,000N 9,475,000N 9,480,000N 9,485,000

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"1:12,000Anchor Chart DPrepared for:Anadarko Petroleum CorporationFeet0 500 1000 2000 3000 4000 5000INTERPRETATION: B. Monsalve, J. GharibGIS/CAD: B. DillardDATE: 3/4/2010REPORT NO: 4051-ANA-GOMFILE: 4051_Anchor_Chart_KC875_D_12.dwg2500 Tanglewilde, Suite 120Houston, TX 77063(713) 532-26247532 Sandholdt Road, Suite 6Moss Landing, CA 95039(831) 633-7400Gulf of MexicoKC875Water Depth & Seafloor FeaturesShowing Potential Anchor TouchdownArea for Proposed Well KC875 DKeathley Canyon (KC)KC875 and Vicinity

E 1,965,000 E 1,965,000N 9,460,000N 9,460,000

N 26° 04' 00" N 26° 04' 00"

TR 8620 TR 8650 TR 8680

TR 8620 TR 8650 TR 8680001LN 8410LN 8310LN 8210LN 8410LN 8310LN 8210

TR 8710 TR 8710

TR 8020 TR 8020Approximate Maximum Anchor Radius - 13,000 ftApproximate Touchdown Point - 5,000 ft1,000 ft buffer beyond approximate maximum anchor radius001

-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 RadiusDEFGH002001KC874G26771Devon Energy Production Company, L.P.Union Oil Company of CaliforniaKC918G32654Exxon Mobil CorporationPetrobras America Inc.KC875G21444Devon Energy Production Company, L.P.Kerr-McGee Oil & Gas CorporationKC919G21447Exxon Mobil CorporationKC920(open)KC876(open)

1,000 ft BufferLocation MapGrid North

E 1,950,000 E 1,955,000

E 1,940,000 E 1,940,000 E 1,945,000N 9,470,000 N 26° 05' 00" N 26° 05' 00"SPHEROID:Clarke 1866INVERSE FLATTENING:1/294.978698SEMIMAJOR AXIS:6,378,206.40 ftSCALE FACTOR: 0.9996PROJECTION: Transverse Mercator CENTRAL MERIDIAN: 93° WDATUM: NAD27 LATITUDE OF ORIGIN: 0°ZONE: UTM Zone 15 North FALSE EASTING:1,640,416.666667 ftLINEAR UNITS:Survey FeetFALSE NORTHING:0 ftGeodetic InformationInterpretive InformationBasemap InformationLN 851032°N97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W97°W 96°W 95°W 94°W 93°W 92°W 91°W 90°W 89°W 88°W 87°W 86°W25°N26°N27°N28°N29°N30°N31°N32°N25°N26°N27°N28°N29°N30°N31°NAmery TerraceEast BreaksGarden BanksGreen CanyonAtwater ValleyDestin DomeMississippi CanyonDe Soto CanyonLloyd RidgeHendersonFlorida PlainLundLund SouthWalker RidgeKeathley CanyonAlaminos CanyonSigsbee EscarpmentTexasLouisianaMississippiAlabamaFloridaBrownsvilleCorpus ChristiPort LavacaFreeportGalvestonHoustonThe WoodlandsPort ArthurLake CharlesLafayetteMorgan CityNew OrleansBiloxiPascagulaMobilePensacolaHouma0 25 50 100Nautical MilesWestCameronWestCameronWestWestCameronSouthWestDeltaGrandIsleEugeneIslandN 9,465,000N 9,465,000KC875HA 2,000 ft radius circle around well surface location isshown as required by Notice to Lessees 2009-G40Proposed Well Surface Location and DesignationLN 9910TR 84403D Seismic Survey Line, Trace, and Designation(LN=Line) (TR=Trace)Lease Block Boundary: Block Number, Lease Numberwith Operator and Primary Lease Holder shownSubsurface Mapping AreaSeafloor Mapping Area (mig16f_psdm_wem_final_feet)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, andAOA 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° 06' 00" N 26° 08' 00" N 26° 06' 00" N 26° 08' 00"Seafloor Mapping Area (mig16f_rtm_0307revtmmigsim)Lowest Contour of Local Depression

-7000Water Depth Contours: 50 ft intervalNormal fault with seafloor expression. Symbol showsdownthrown side and direction of fault dipSmall minibasins and depressionsRidges and gullies associated with Bryant Canyon

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 8590LN 8610LN 8710LN 8810LN 8910LN 9010LN 9110LN 9210LN 9310LN 9410LN 9510LN 9610LN 9710LN 9810LN 9910LN 10010LN 10110LN 10210LN 10310LN 8510LN 8610LN 8710LN 8810LN 8910LN 9010LN 9110LN 9210LN 9310LN 9410LN 9510LN 9610LN 9710LN 9810LN 9910LN 10010LN 10110LN 10210LN 10310N 9,475,000N 9,480,000N 9,485,000N 9,470,000N 9,475,000N 9,480,000N 9,485,000

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"1:12,000Anchor Chart HPrepared for:Anadarko Petroleum CorporationFeet0 500 1000 2000 3000 4000 5000INTERPRETATION: B. Monsalve, J. GharibGIS/CAD: B. DillardDATE: 3/4/2010REPORT NO: 4051-ANA-GOMFILE: 4051_Anchor_Chart_KC875_H_12.dwg2500 Tanglewilde, Suite 120Houston, TX 77063(713) 532-26247532 Sandholdt Road, Suite 6Moss Landing, CA 95039(831) 633-7400Gulf of MexicoKC875Water Depth & Seafloor FeaturesShowing Potential Anchor TouchdownArea for Proposed Well KC875 HKeathley Canyon (KC)KC875 and VicinityN 9,460,000N 9,460,000

N 26° 04' 00" N 26° 04' 00"

TR 8620 TR 8620001LN 8410LN 8310LN 8210LN 8410LN 8310LN 8210

TR 8020

TR 7990 TR 8020

TR 7990Approximate Maximum Anchor Radius - 13,000 ftApproximate Touchdown Point - 5,000 ft1,000 ft buffer beyond approximate maximum anchor radius

TR 8650 TR 8650

TR 7960 TR 7960Possible high-density deepwater benthic communities

# D
HYDROGEN SULFIDE INFORMATION

Wells in adjacent Keathley Canyon 875, 919, and 964 bloc ks have tested a similar age section as the wells proposed within this plan without encountering any H 2 

# S. 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, Keath ley Canyon (ExxonMob il) 919 OCS-G 21447 #3 and #3BP1, and the Keathley Canyon (ExxonMobil) 964 OCS-G 21451 #1. As no H 2 

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

H 2 

# S 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 fo r 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 Gulf of Mexico Lease Area Coastal
Marine Mammals Sperm whale Physeter macrocephalus E X -- None West Indian manatee Trichechus manatus latirostris E -- X Florida (Peninsular)
Blue whale B alaenoptera musculus E X a 

### -- None Fin whale B alaenoptera physalus E X a 

### -- None Humpback whale M egaptera novaeangliae E X a 

### -- None North Atlantic right whal e Eubalaena glacialis E X a 

### -- None Sei whale B alaenoptera borealis E X a 

### -- None Sea Turtles Loggerhead turtle Caretta caretta T X X None Green turtle Chelonia mydas T, E b 

### X X None Leatherback turtle D ermochelys coriacea E X X None Hawksbill turtle Eretmochelys imbricata E X X None Kemp’s ridley turtle L epidochelys 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 A cropora 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 co vering the proposed Keathley Canyon Blocks 875 and 919 well locations was previously submitted to BOEM on D ecember 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 activ ities for which the State of Flor ida 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. Therefor e, socioeconomic information required per NTL 2008-G04 is no t 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 wettedwith 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 20 0 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 locatio n 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 sea floor 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 20 0 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 sea floor 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) Emissi on amount (in tons) associated with your proposed exploration activities more than 90% of the amounts calculated using the following formulas: CT = 3400D 2/3 

## for CO, and CT = 33.3D for 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
Amounts 1 

## (tons) Calculated Exemption
Amounts 2 

## (tons) Calculated Complex Total
Emission Amounts 3 

## (tons) Particulate matter (PM) 50.48 7092.90 69.77 Sulphur dioxide (SO 2 

## ) 231.61 7092.90 311.95 Nitrogen oxides (NO

x 

## ) 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.comEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0049OMB Approval Expires: September 30, 2003COMPANYAnadarko Petroleum CorporationAREAKeathley CanyonBLOCK875 & 919LEASEOCS-G 21444 & 21447PLATFORMWELLProposed wells under this SEP: KC 875 I & KC 919 AA, BB, CC, DD, EECOMPANY CONTACTJill FowlerTELEPHONE NO.832-636-1554REMARKSDrill and complete 6 wellsForm MMS-138 (May 2001)Page 1 of 8EMISSIONS FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6La. DEQ 1991Gas Venting lbs/scf 0.0034Sulfur Content Source Value UnitsFuel Gas 3.33 ppmDiesel Fuel 0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightForm MMS-138 (May 2001)Page 2 of 8EMISSIONS CALCULATIONS 2ND YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC9Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 1.90VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 9.322013 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 26.08 119.66 898.23 28.34 204.93EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 4 of 8EMISSIONS CALCULATIONS 3RD YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC9Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 2.05VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 18.652014 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 28.31 129.91 976.67 32.09 230.99EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 5 of 8EMISSIONS CALCULATIONS 4TH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 3.66VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 18.652015 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 50.48 231.61 1738.71 54.95 397.26EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 6 of 8EMISSIONS CALCULATIONS 5TH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 1.86VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 9.322016 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 25.15 115.40 866.33 27.39 197.97EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 7 of 8SUMMARYCOMPANY AREA BLOCK LEASE PLATFORM WELLAnadarko Petrol Keathley Canyon 875 & 919 OCS-G 21444 & 21447Proposed wells undertEmitted SubstanceYearPM SOx NOx VOC CO2012 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 0.00Allowable7092.90 7092.90 7092.90 7092.90 121264.03Form MMS-138 (May 2001)Page 8 of 8January Febuary March April MayJune July August September October November DecemberTotal: Average2010 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 295292 285333 4559380January Febuary March April MayJune July August September October November DecemberTotal: Average2011 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 557594411323 395340 4927411-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 useACTUAL FUEL USAGE FACTORS ASSUMED FOR AQR EMMISSION CALCULATIONSEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0049OMB Approval Expires: September 30, 2003COMPANYAnadarko Petroleum CorporationAREAKeathley CanyonBLOCK875 & 919LEASEOCS-G 21444 & 21447PLATFORMWELLProposed wells under this SEP: KC 875 I & KC 919 AA, BB, CC, DD, EEPreviously approved wells being carried forward: KC 875 #002 ST01, D, F, G, H; KC 874 #001; & KC 919 #003COMPANY CONTACTJill FowlerTELEPHONE NO.832-636-1554REMARKSDrill and complete 6 wellsForm MMS-138 (May 2001)Page 1 of 8EMISSIONS FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6La. DEQ 1991Gas Venting lbs/scf 0.0034Sulfur Content Source Value UnitsFuel Gas 3.33 ppmDiesel Fuel 0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightForm MMS-138 (May 2001)Page 2 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorporaKeathley Canyon 875 & 919 OCS-G 21444 & Proposed wells under this SEP: KC 875 I & KCJill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 0.05VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 0.002012 YEAR TOTAL19.12 87.73 657.38 19.72 143.43 0.56 2.56 19.19 0.58 4.19EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 3 of 8EMISSIONS CALCULATIONS 2ND YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC9Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 4.95VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 27.972013 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 67.99 311.95 2342.35 74.46 537.91EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 4 of 8EMISSIONS CALCULATIONS 3RD YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC9Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 3.28VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 37.302014 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 45.26 207.71 1562.83 52.47 376.78EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 5 of 8EMISSIONS CALCULATIONS 4TH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 3.66VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 18.652015 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 50.48 231.61 1738.71 54.95 397.26EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 6 of 8EMISSIONS CALCULATIONS 5TH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorpKeathley Canyon 875 & 919 OCS-G 21444&Proposed wells under this SEP: KC 875 I & KC 91 Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 3.19VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 18.652016 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 43.96 201.70 1514.58 48.23 348.35EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES7092.90 7092.90 7092.90 7092.90 121264.03213.0Form MMS-138 (May 2001)Page 7 of 8COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSAnadarko Petroleum CorKeathley Canyon 875 & 919 OCS-G 21444 & 21 Proposed wells under this SEP: KC 875 I&Jill Fowler 832-636-1554OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HRGAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING 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 0.00PRIME MOVER>600hp diesel 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME 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 0.003 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 1.38VESSELS>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 0.00FACILITY 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 0.00VESSELS>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 0.00Flowback 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 9.322017 YEAR TOTAL19.12 88.32 728.78 80.02 531.93 18.63 85.49 642.20 20.66 149.07EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES7092.90 7092.90 7092.90 7092.90 121264.03213.0SUMMARYCOMPANY AREA BLOCK LEASE PLATFORM WELLAnadarko Petrol Keathley Canyon 875 & 919 OCS-G 21444 & 21447Proposed wells undertEmitted SubstanceYearPM SOx NOx VOC CO2012 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 0.00Allowable7092.90 7092.90 7092.90 7092.90 121264.03Form MMS-138 (May 2001)Page 8 of 8January Febuary March April MayJune July August September October November DecemberTotal: Average2010 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 295292 285333 4559380January Febuary March April MayJune July August September October November DecemberTotal: Average2011 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 557594411323 395340 4927411-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 useACTUAL 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 30.1 o 

## 30.7 o 

## 28.0 o



### * Note–for the OSRP exploratory worst case discharge scenario only the Area/Block is referenced in the OSRP. Exploratory drilli ng 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-N 06 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 91 9(> 10 miles from shore): 252,000 BOPD

## Table H-2

Trajectory by Land Segment

Following are the average co nditional probabilities (expressed as percent chance) that an oil spill starting at a particular launch area will contact a land segment as in cluded 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. Th e 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 --

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1Table H-3WCD 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 DeratedCapacity(bbls)Storage(bbls)No. ofUnits/PersonsOwner/Location Staging Hours toProcure(1)Hours toLoad Out(2)Travel(Staging/Spill)(3)Hours toDeploy(4)TotalEstimatedHoursDC 3 Spray AircraftAero Commander--------22 eachASI/Houma Houma1 1 1.5 0 3.5Basler Spray AircraftAero Commander--------12CGA/Houma Houma1 1 1.25 0 3.25HOSS BargeOperatorsTugs43,000 4,000 183CGA/HarveySTARSVOOHarvey7 0 37.5 1 43.5FRUOperatorsUtility Boat4,251 200 161CGA/GalvestonSTARSVOOGalveston1 2 27 1 31FRUOperatorsUtility Boat4,251 200 161CGA/Lake CharlesSTARSVOOCameron1 2 24 1 28FRUOperatorsUtility Boat4,251 100 161CGA/HarveySTARSVOOHarvey1 2 21 1 25FRUOperatorsUtility Boat8,502 400 2122CGA/VeniceSTARSVOOVenice1 2 24 1 26FRUOperatorsUtility Boat8,502 400 2122CGA/LeevilleSTARSVOOLeeville1 2 20 1 24FRUOperatorsUtility Boat4,251 200 161CGA/Morgan CitySTARSVOOMorgan City1 2 22 1 26Koseq Skimming ArmsOperatorsVessel w/ storage/hull89,15010,0005 sets301CGA/GalvestonSTARSVOOGalveston4 12 27 2 45Koseq Skimming ArmsOperatorsVessel w/ storage/hull53,4906,0003 sets181CGA/LeevilleSTARSVOOLeeville4 12 20 2 38Koseq Skimming ArmsOperatorsVessel w/ storage/hull17,8302,0001 set61CGA/FourchonSTARSVOOFourchon4 12 21 2 37Gulf Coast ResponderTransrec 350 + OSRV5,280'44"Sea Sentry Boom2,640'67"LAMOR10,567 4,000 1114 crew MSRC/Lake Charles Cameron2 0 24 1 27Deep Blue Responder 18,086 4,000 1 MSRC/Fourchon FourchonType DeratedCapacity(bbls)Storage(bbls)No. ofUnits/PersonsOwner/Location Staging Hours toProcure(1)Hours toLoad Out(2)Travel(Staging/Spill)(3)Hours toDeploy(4)TotalEstimatedHoursLFF 100 Brush + OSRV6,600'44"Sea Sentry Boom660'67"LAMOR114 crew2 0 21 1 24Louisiana ResponderTransrec 350 + OSRV2,640'44"Sea Sentry II Boom5,280'67"LAMOR10,567 4,000 1114 crewMSRC/Fort Jackson Venice2 0 24 1 27PSV – HOS Centerline1 Crucial Disk 88/301,320' EFC11,122 10,626 114 crew MSRC/Fourchon Fourchon2 0 25 1 28PSV – HOS Strongline1 Crucial Disk 88/301,320' EFC11,122 10,626 114 crew MSRC/Fourchon Fourchon2 0 25 1 28Stress I Skimmer/BladderUtility Boat15,840 500 16 crewMSRC/Fourchon Fourchon1 2 23 1 27MSRC 570 Offshore BargeTugs2 Crucial Disk 88/302,640'44"Sea Sentry II Boom22,244 56,900 1316 crewMSRC/GalvestonVOOGalveston2 0 36 1 39MSRC 452 Offshore BargeTugs1 Crucial Disk 88/301,980'44"Sea Sentry II Boom660'67"LAMOR11,122 45,000 1316 crewMSRC/Fort JacksonVOOVenice2 0 28 1 31CTCo 5001OperatorsTug-- 47,000 161EMS-CGA/AmeliaEMSVOOAmelia4 12 31 1 48CTCo 2604OperatorsTug-- 20,000 161EMS-CGA/AmeliaEMSVOOAmelia4 12 31 1 48PacificOperatorsTug-- 80,000 161K-Sea-CGA/VeniceK-SeaVOOVenice4 12 26 1 43DBL 76OperatorsTug-- 83,937 161K-Sea-CGA/VeniceK-SeaVOOVenice4 12 26 1 435,000' 42" Auto BoomVOO-- -- 2010 crewCGA/GalvestonSTARSGalveston1 2 27 1 315,000' 42" Auto BoomVOO-- -- 2010 crewCGA/Lake CharlesSTARSCameron1 2 24 1 2810,000' 42" Auto BoomVOO-- -- 4020 crewCGA/HarveySTARSHarvey1 2 20 1 242,500' 42" Auto BoomVOO-- -- 126 crewCGA/PascagoulaSTARSPascagoula1 2 25 1 294,290' 44" Sea Sentry II BoomVOO-- -- 2010 crewMSRC/GalvestonSTARS Galveston 1 2 27 1 316,679' 44" Sea Sentry II BoomVOO-- -- 2010 crewMSRC/Lake CharlesSTARSCameron1 2 24 1 28Type DeratedCapacity(bbls)Storage(bbls)No. ofUnits/PersonsOwner/Location Staging Hours toProcure(1)Hours toLoad Out(2)Travel(Staging/Spill)(3)Hours toDeploy(4)TotalEstimatedHours1,980' 44" Sea Sentry II BoomVOO-- -- 126 crewMSRC/Fort JacksonSTARSVenice1 2 25 1 293,190' 44" Sea Sentry II BoomVOO-- -- 2010 crewMSRC/PascagoulaSTARSPascagoula1 2 25 1 29Spotter HeloSurveillance HeloHand Held Radios------------1130PHI/FourchonPHI/FourchonSTARSSpill SiteSpill SiteFourchon111.5------222------333.5Estimated Total:348,148 390,089EDRC StorageSpill Team Area Responders (STARS) called out by Marine Spill Response Corporation (MSRC)Vessel of Opportunity=VOOEMS=Enterprise Marine Services (available through contract with CGA)Nearshore Equipment from Spill Detectionto Equipment Deployment Response Time: Keathley Canyon 919, Location “F”Type DeratedCapacity(bbls)Storage(bbls)No. ofUnits/PersonsOwner/Location NearshoreStagingHours toProcure(1)Hours toLoad Out(2)Travel(Staging/Spill)(3)Hours toDeploy(4)TotalEstimatedHoursDC 3 Spray AircraftAero Commander--------22 eachASI/Houma Houma1 1 10 3Basler Spray AircraftAero Commander--------12CGA/Houma Houma1 1 .5 0 2.5SWS EgmopolOperators3,000 100 13CGA/GalvestonSTARSGalveston1 2 5.5 2 8.5SWS MarcoOperators3,588 20 13CGA/Lake CharlesSTARSCameron1 2 30 6SWS MarcoOperators3,588 34 13CGA/LeevilleSTARSFourchon1 2 60 9SWS MarcoOperators3,588 34 13CGA/VeniceSTARSVenice1 2 8.5 0 11.5Trinity SWSOperators21,500 249 14CGA/GalvestonSTARSGalveston1 2 4.5 0 7.5Trinity SWSOperators21,500 249 14CGA/LeevilleSTARSFourchon1 2 50 8Trinity SWSOperators21,500 249 14CGA/VeniceSTARSVenice1 2 7.5 0 10.5R/V Grand BayOperators5,000 65 13CGA/VeniceSTARSVenice2 .5 11 0 13.5R/V RW ArmstrongOperators5,000 65 13CGA/LeevilleSTARSFourchon2 .5 8.5 0 11R/V Bastian BayOperators5,000 65 13CGA/Lake CharlesSTARSCameron2 .5 5 0 7.5R/V Timbalier BayOperators5,000 65 13CGA/GalvestonSTARSGalveston2 .5 4 0 6.5Foilex 250 SkimmerStorage Bladder3,977 500 13MSRC/Galveston Galveston2 .5 5 .5 8Foilex 250 SkimmerStorage Bladder3,977 500 13MSRC/Lake Charles Cameron2 .5 6 .5 9Foilex 250 SkimmerStorage Bladder3,977 500 13MSRC/Fort Jackson Fourchon2 .5 4 .5 7GT 185Storage Bladder1,371 500 13MSRC/Pascagoula Pascagoula2 .5 7.5 .5 10.5CTCo 2603OperatorsTug-- 25,000 161EMS-CGA/AmeliaEMSVOOAmelia4 12 15 1 32CTCo 2605OperatorsTug-- 20,000 161EMS-CGA/AmeliaEMSVOOAmelia4 12 15 1 32CTCo 2606OperatorsTug-- 20,000 161EMS-CGA/AmeliaEMSVOO Amelia 4 12 15 1 32CTCo 2608 -- 23,000 1 EMS-CGA/Amelia AmeliaType DeratedCapacity(bbls)Storage(bbls)No. ofUnits/PersonsOwner/Location NearshoreStagingHours toProcure(1)Hours toLoad Out(2)Travel(Staging/Spill)(3)Hours toDeploy(4)TotalEstimatedHoursOperatorsTug61EMSVOO 4 12 15 1 32CTCo 2609OperatorsTug-- 23,000 161EMS-CGA/AmeliaEMSVOOAmelia4 12 13 1 302,000' Beach Boom -- -- 6 CGA/Pascagoula Pascagoula 1 2 3 2 810,000' 18" BoomVOO-- -- 104 crewOil Mop/Port Arthur Galveston01 1 2.5 3 7.510,000' 18" BoomVOO-- -- 104 crewOil Mop/New Iberia Morgan City1 1 7 3 1210,000' 18" BoomVOO-- -- 104 crewOil Mop/Port Allen Fourchon01 1 6.25 3 11.2510,000' 18" BoomVOO-- -- 104 crewOil Mop/Houma Fourchon.51 1 6 3 1120,000' 18" BoomVOO-- -- 208 crewOil Mop/Belle Chasse Venice.51 1 7 6 1515,000' 18" BoomVOO-- -- 146 crewOil Mop/Gretna Venice01 1 8 4 1442,000 18" BoomVOO-- -- 4016 crewAMPOL/New Iberia Morgan City01 0 7 12 20Wildlife Support Trailer -- -- 1/ 2 crew CGA/Harvey Venice 1 1 2 2 6Bird Scare Cannons -- -- 1 CGA/Galveston Galveston 1 1 1 2 5Bird Scare Cannons -- -- 2 CGA/Lake Charles Cameron 1 1 3.5 2 7.5Bird Scare Cannons -- -- 2 CGA/Harvey Venice 1 1 1.5 2 5.5Bird Scare Cannons -- -- 2 CGA/Venice Venice 1 1 2 2 6Bird Scare Cannons -- -- 2 CGA/Pascagoula Pascagoula 1 1 4.5 2 8.5Spotter HeloSurveillance HeloHand Held Radios------------1130PHI/FourchonPHI/FourchonSTARSSpill SiteSpill SiteFourchon111.5------.5.51.5------1.51.53Estimated Total:111,566 114,195EDRC 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 ve ssel 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 withsyntheticbased 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 completeKeathleyCanyonBlocks875and919June2012EnvironmentalImpactAnalysisforSupplementalExplorationPlanPage2Figure1.LocationofKeathleyCanyonBlocks875and919.