UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - R-05096

Type - Revised Exploration Plan

Lease(s) - OCS-G22367 Block - 736 Keathley Canyon Area

Operator - Chevron U.S.A. Inc.

Subsea Wells B, C, D, and E

DRILLSHIP

Attached is a copy of the subject plan for public comments on issues that 

should be addressed in an Environmental Assessment.

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

Michelle Griffitt

Plan Coordinator

Description -

Rig Type -

Subject:

From:

June 30, 2011
Record Log Corrected: 06/09/2011 Public Information

EXPLORATION PLAN 

R-5096

CHEVRON U.S.A. INC. 

KEATHLEY CANYON BLOCK 736 

OCS-G 22367 

OFFSHORE LOUISIANA 

“MOCCASIN” PROSPECT

RECORD CHANGE LOG

Submission 

Type

Date Received Document Type Page Number

Initial 10/25/2010 NTL No. 2010-N06 Additional 

Information

2-12

Amended 11/16/2010 Amended Exploration Plan 13-39

Amended 11/22/2010 Oil Spill Response Discussion (OSRD) 39-45

Amended 12/13/2010 LA CZM Certificate 46-47

Amended 1/18/2011 NTL No. 2010-N06 Public Information 

Copy

2-11

Amended 2/25/2011 Oil Characteristics, High Density 

Benthic Communities Information, 

Waste and Discharge Information, 

WCD Comparison Table, Spill 

Response Discussion, Solid and Liquid 

Wastes Transportation, Waste 

Disposal

48-58

Amended 4/20/2011 Water Quality Tables 60-62

Amended 6/9/2011 Updated Site Clearance Letters 63- 102

Amended 6/9/2011 Updated Activity Schedule, Updated 

MMS 137 Form, Updated Air Quality 

Spreadsheet

103-117
PUBLIC INFORMATION 

CHEVRON U.S.A. INC.

NTL No. 2010-N06

Additional Information

Initial Exploration Plan

Control Number: N-09380

Keathley Canyon Block 736

Offshore Louisiana

“Moccasin” Prospect

Amended January 18, 2011
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 2

1.0 WORST CASE DISCHARGE SCENARIO .................................................................................................... 3

1.1 INTRODUCTION ................................................................................................................................................ 3

1.2 FIELD SUMMARY.............................................................................................................................................. 3

1.3 WELL OBJECTIVE............................................................................................................................................. 3

1.4 WELL PLAN...................................................................................................................................................... 3

1.5 WELLBORE SECTIONS USED IN ANALYSIS........................................................................................................ 3

1.6 ASSUMPTIONS AND DATA ................................................................................................................................ 3

1.6.1 Blowout Scenario Rates and Volumes.................................................................................................. 4

1.6.2 Geological Data ................................................................................................................................... 4

PROPRIETARY INFORMATION ........................................................................................................................ 4

1.6.3 Reservoir Pressure and Temperature Data .......................................................................................... 4

1.6.4 Reservoir Drainage Area and Drive Mechanisms................................................................................ 4

1.6.5 Reservoir Depletion Rates.................................................................................................................... 4

1.6.6 Casing and Tubing Friction Factors.................................................................................................... 4

1.6.7 Production History ............................................................................................................................... 4

1.6.8 Static and Flowing Bottom Hole Pressures.......................................................................................... 4

1.6.9 Skin Damage......................................................................................................................................... 4

1.6.10 Water Intrusion..................................................................................................................................... 4

1.6.11 Coning .................................................................................................................................................. 4

1.6.12 Formation Sloughing............................................................................................................................ 4

1.6.13 Bridging................................................................................................................................................ 4

1.6.14 Pressure/Temperature/Volume Characteristics of the Fluid ................................................................ 5

1.6.15 Fluid Flow Regimes.............................................................................................................................. 5

1.6.16 Hydrostatic Pressure ............................................................................................................................ 5

1.7 REGIONAL OIL SPILL RESPONSE PLAN COMPARISON....................................................................................... 5

2.0 BLOWOUT PREVENTION MEASURES...................................................................................................... 6

2.1 MINIMUM BARRIER REQUIREMENTS................................................................................................................ 6

2.2 RISK AND UNCERTAINTY MANAGEMENT STANDARD ...................................................................................... 6

2.3 MANAGEMENT OF CHANGE.............................................................................................................................. 6

2.4 WELL CONTROL............................................................................................................................................... 6

2.5 BLOWOUT CONTINGENCY PLANNING............................................................................................................... 6

2.6 CEMENTING ..................................................................................................................................................... 7

3.0 INTERVENTION AND CONTAINMENT..................................................................................................... 8

3.1 INTERVENTION........................................................................................................................................... 8

3.2 RELIEF WELL PLANS................................................................................................................................. 8

3.2.1 Relief Well Data.................................................................................................................................... 8

3.2.2 Relief Well Summary ............................................................................................................................ 9

3.2.3 Relief Well West.................................................................................................................................... 9

3.2.4 Relief Well Plan West ........................................................................................................................... 9

3.3 CONTAINMENT SCENARIOS ....................................................................................................................... 9

4.0 LIST OF ATTACHMENTS............................................................................................................................11
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 3

1.0 WORST CASE DISCHARGE SCENARIO

1.1 Introduction

This report intends to satisfy the requirements for NTL No.2010-N06 dated June 18th, 

2010. The document addresses the following location: 

Plan Number OCS Area OCS Block Lease Number Well Name

N-9380 Keathley Canyon 736 22367 KC 736 “A” (OCS-G 22367 001)

The Keathley Canyon (KC) Block 736 001 well is currently temporarily plugged and 

abandoned due to the drilling moratorium. The well was drilled to 24,519 ft measured 

depth (MD). A 135⁄8-in. Liner has been set at 24,347 ft MD in the Lower Miocene Tertiary 

section, 2,646 ft below the base of salt. The Worst Case Discharge (WCD) scenario will 

use the KC 736 001 as the representative well. In compliance with NTL No. 2010-N06, 

only zones below the currently cased total depth (TD) will be considered for WCD 

Scenario calculations. The 105⁄8-in. open hole section has been selected for the WCD 

reporting purposes as the other hole sections are safely isolated behind pipe or are not 

expected to contain significant sand.

Based on system analysis, the WCD initial flow rate is calculated to be 51,650 Barrels 

Oil per Day (BOPD) and is expected to decline due to transient effects reaching a 

stabilized rate of 45,317 BOPD after approximately 80 days. A constant pressure outer 

boundary condition has been used in the analysis and reservoir depletion is not 

expected to occur in the time required to drill a relief well.

[Paragraph redacted- Proprietary information]

 

1.2 Field Summary

PROPRIETARY INFORMATION

1.3 Well Objective

PROPRIETARY INFORMATION

1.4 Well Plan

PROPRIETARY INFORMATION

1.5 Wellbore Sections used in Analysis

PROPRIETARY INFORMATION

1.6 Assumptions and Data

PROPRIETARY INFORMATION
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 4

1.6.1 Blowout Scenario Rates and Volumes

The initial Open Flow Potential (OFP) rate has been calculated with systems analysis 

using the Prosper nodal software package from Petroleum Experts Ltd. Single layer, 

multi-layer and transient models have been investigated.

Systems analysis indicates that an uncontrolled blowout in the 105⁄8-in. open-hole section 

will lead to a maximum WCD rate of 51,650 BOPD. This rate is based on transient 

analysis and does not include the effects of heavy fluid unloading or filter cake cleanup. 

Assuming a 500 acre drainage volume, the production rate would stabilize in about 80 

days at 45,317 bopd. 

[Paragraph redacted- Proprietary information]

[Paragraph redacted- Proprietary information]

1.6.2 Geological Data

PROPRIETARY INFORMATION

1.6.3 Reservoir Pressure and Temperature Data

PROPRIETARY INFORMATION

1.6.4 Reservoir Drainage Area and Drive Mechanisms

PROPRIETARY INFORMATION

1.6.5 Reservoir Depletion Rates

PROPRIETARY INFORMATION

1.6.6 Casing and Tubing Friction Factors

PROPRIETARY INFORMATION

1.6.7 Production History

PROPRIETARY INFORMATION

1.6.8 Static and Flowing Bottom Hole Pressures

PROPRIETARY INFORMATION

1.6.9 Skin Damage

PROPRIETARY INFORMATION

1.6.10 Water Intrusion

PROPRIETARY INFORMATION

1.6.11 Coning

PROPRIETARY INFORMATION

1.6.12 Formation Sloughing

PROPRIETARY INFORMATION

1.6.13 Bridging

PROPRIETARY INFORMATION
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 5

1.6.14 Pressure/Temperature/Volume Characteristics of the Fluid

PROPRIETARY INFORMATION

1.6.15 Fluid Flow Regimes

PROPRIETARY INFORMATION

1.6.16 Hydrostatic Pressure

PROPRIETARY INFORMATION

1.7 Regional Oil Spill Response Plan Comparison

The WCD scenario and results described in this document have been compared to the 

revised Chevron GOM Regional Oil Spill Response Plan (OSRP). A summary of the 

parameters used in the proposed Regional OSRP analysis and results from the potential 

spill estimation is included as Appendix 2. 

Category Regional OSRP EP 

Type of Activity Exploration Well Exploration Well

Facility Location (Area/Block) WR 143 KC 736

Facility Designation Mobile Rig DP Drillship

Distance to Nearest Shoreline 160 miles 216 miles

Uncontrolled blowout, (volume per day) 156,994 bbls 51,650 bbls

Type of Oil(s) Crude oil Crude oil

API Gravity(s) 28o 28o

Since Chevron has the capability to respond to the appropriate worst-case spill scenario 

included in its revised Regional OSRP submitted on October 25, 2010, and since the 

worst-case scenario determined for our EP does not replace the appropriate worst-case 

scenario in our revised Regional OSRP, we hereby certify that Chevron 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 Plan.1

 

1 This certification is provided as required by NTL No. 2008-G04 at page 19.
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 6

2.0 BLOWOUT PREVENTION MEASURES

2.1 Minimum Barrier Requirements

PROPRIETARY INFORMATION

2.2 Risk and Uncertainty Management Standard

PROPRIETARY INFORMATION

2.3 Management of Change

PROPRIETARY INFORMATION

2.4 Well Control

PROPRIETARY INFORMATION

2.5 Blowout Contingency Planning

In order for Chevron to address its ability to prevent blowouts, reduce the likelihood of 

blowouts, and conduct effective/early intervention in the event of a blowout, Chevron has 

developed standards for well control, personnel safety, and emergency response plans. 

Chevron has also entered into agreements with industry Subject Matter Experts (SMEs). 

At all times from planning through execution, Chevron takes the necessary steps to 

maintain primary well control to prevent the occurrence of blowouts. 

The drilling team works in conjunction with the geological and exploration teams to use 

their knowledge and good judgment to create best possible well plans and program for 

any particular prospect. All relevant geological information is used to understand the 

risks and uncertainties that are unique to the location. Appropriate plans are then 

generated to eliminate or mitigate the identified risks. Special equipment for contingency 

plans is sourced and qualified personnel are identified for conducting the various tasks. 

Prior to the execution phase, all the well control equipment on the rig undergoes a 

rigorous inspection and acceptance process/procedure by the Chevron Global Well 

Intervention group.

To reduce the likelihood of a blowout, appropriate offset information is used to generate 

pore pressure models that predict localized area pore pressure. Maximum Anticipated 

Surface Pressure (MASP) is calculated to ensure that the working pressure of the BOP 

equipment is not exceeded at any time during well construction. Pressure While Drilling 

(PWD) and Log While Drilling (LWD) data, such as gamma ray, resistivity, sonic, are 

used during the drilling operation to monitor real time pore pressure variances. 

Adjustments can then be made to the mud system to maintain the appropriate

overbalance on the pore pressure. Mud tank volumes and trip tank volumes are 

constantly monitored while drilling for early detection of changes in anticipated trends. 

Routine maintenance and testing of blowout prevention equipment ensures the 

equipment is in good working condition during operations. Data sheets and critical 
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 7

wellbore information which are needed in well control situations are maintained at the 

well site. 

Preliminary plans are developed for potential relief well locations(s) during the planning 

phase for the primary well(s). These preliminary plans can be used to develop detailed 

relief well drilling plans as needed in a timely manner. 

There are contractual arrangements in place with industry SMEs, such as Wild Well 

Control, to assist in the event of a blowout. The SMEs also belong to a consortium that 

will supply the spill response equipment. 

2.6 Cementing

PROPRIETARY INFORMATION 
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 8

3.0 INTERVENTION AND CONTAINMENT

3.1 Intervention

At the first indication of loss of primary well control, every attempt will be made to regain 

primary well control via well control measures. 

In the event an uncontrolled blowout is imminent, the next action would be to disconnect 

from the well and move the rig away from the blowout well. Preparations would 

commence to drill a relief well and mobilize external well control specialists. The 

specialists would be integrated into the blowout well response team and begin planning 

intervention and containment actions.

3.2 Relief Well Plans

3.2.1 Relief Well Data

1. The relief well would be drilled by a 5th or 6th generation Enterprise or Enhanced 

Enterprise Class drillship such as the Transocean Discoverer Inspiration (DIN), or 

Discoverer Deep Seas (DDS) or Discoverer Clear Leader (DCL).

2. The DIN, DDS, and DCL are already under contract to Chevron operating in GOM 

and would be the primary rig(s) for the relief well effort.

3. The DIN, DDS, and DCL do not have any equipment constraints with respect to 

drilling a relief well.

4. Estimated days to drill a relief well:

a. Demob from an existing well = 10

b. Mobilize to relief well surface location = 4 

c. Drilling and intercepting = 

144 days

130

Note: Total days= 10 days TA current loc (demob) + 4 days mob + 

[Exploration well EV est.] * 1.3 contingency factor

A total of 144 days is estimated to engage a rig from Chevron DWEP operations and 

drill/intercept the blowout well.

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

6. The relief well would consider the following objectives:

a. Surface location approximately 1⁄2 mile away from the blowout well location; 

approximately 2,500 ft is used to comply with Transocean dynamic 

positioning practices.

b. Upwind & up current where possible from the blowout well location.

c. Constrained to typical parameters such as maximum inclination, benign 

water-bottom and salt entry/exit points, and subsurface hazard avoidance.

7. The relief well would be designed to intercept the blowout well at the 11 7⁄8 -in. liner 

with a 105⁄8-in. hole.

8. The relief well casing design would be similar to the Moccasin well casing design.

9. The directional plan would have the following parameters:
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 9

a. Twinning/ranging section of 15 ft separation from the blowout well at a point 

250 - 300 ft above the deepest liner depth.

b. Final section with 2 ft separation from the blowout well at the deepest set liner 

depth.

c. A liner will be set in the relief well before intercepting the blowout well.

 

3.2.2 Relief Well Summary

Option Surface Location

X (Easting) Y (Northing) Comment

(ft) (ft)

Relief Well West 1,842,138 9,520,859

3.2.3 Relief Well West

The relief well surface location is planned to be approximately 2,500 ft west of the 

surface location of the blowout well. It is up current and upwind of the blowout well 

surface location.

The relief well will have a build and hold trajectory with a maximum inclination of 30 

degrees.

The relief well will have a “twinned” section for the magnetic ranging data acquisition.

Additional relief well planning information is included as Appendix 3.

3.2.4 Relief Well Plan West

PROPRIETARY INFORMATION 

3.3 Containment Scenarios

Depending on the location in the wellbore of hydrocarbon flow, surface intervention 

would be implemented as appropriate with one of the following scenarios:

• Scenario 1: Subsea containment spool landed on BOP with Lower Marine 

Riser Package (LMRP) removed.

• Scenario 2: Subsea containment spool landed on LMRP after removing 

drilling riser.

• Scenario 3a: Subsea containment spool landed on casing after removing 

BOP and cutting/removing wellhead system (limited excavation required).

• Scenario 3b: Subsea containment spool landed on casing after removing 

BOP, excavating to some depth below casing failure (30 - 40 feet), and 

cutting/removing surface casing.

Note: Scenarios 3a and 3b excavating concept and silo/caisson design will be 

made available at a later date.
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 10

Scenarios 1 and 2 are based on standard industry designs and use the containment 

capability and equipment provided by an industry consortium. If additional containment 

equipment is needed, it is readily available as in stock items from various GOM suppliers 

and vendors.

This immediate containment capability and equipment will be provided by the recently 

formed Marine Well Containment Company (MWCC).

Equipment available from the industry is outlined below:

Containment equipment description for well attachment

• Riser flange x H-4 connector profile

• BOP on BOP (H-4 ExF connector, Spacer DSA)

• Connectors (BOP Mandrel, wellhead), various

Installation workover & control system

• Umbilical and reeler, UTA, hydraulic flying lead, electrical 

flying lead

• Hydraulic pumping unit

• CIU

• Peripheral / Interconnect components

• Down line winches

BOP controls systems

• MUX Cables / Reelers

• Wet connects

• Test plates for tie-in (LMRP removed)
EP N-09380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 11

4.0 LIST OF ATTACHMENTS

PROPRIETARY INFORMATION 
KC 736 EP Information Public.docx PUBLIC INFORMATION

CHEVRON U.S.A. INC.

EXPLORATION PLAN R-5096

KEATHLEY CANYON BLOCK 736

OCS-G 22367

OFFSHORE LOUISIANA

“MOCCASIN” PROSPECT

SECTION A PLAN CONTENTS 

SECTION B GENERAL INFORMATION 

SECTION C GEOLOGICAL AND GEOPHYSICAL INFORMATION 

SECTION D HYDROGEN SULFIDE (H2S) INFORMATION

SECTION E BIOLOGICAL, PHYSICAL, AND SOCIOECONOMIC INFORMATION

SECTION F WASTE AND DISCHARGE INFORMATION

SECTION G AIR EMISSIONS INFORMATION

SECTION H OIL SPILLS INFORMATION

SECTION I ENVIRONMENTAL MONITORING INFORMATION

SECTION J LEASE STIPULATIONS INFORMATION

SECTION K ENVIRONMENTAL MITIGATION MEASURES INFORMATION

SECTION L SUPPORT VESSELS AND AIRCRAFT INFORMATION

SECTION M ONSHORE SUPPORT FACILITIES INFORMATION

SECTION O ENVIRONMENTAL IMPACT ANALYSIS (EIA) 
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 1 Public Information

SECTION A PLAN CONTENTS (30 CFR 250.211 and 250.241)

(a) PLAN INFORMATION FORM

Included as attachment A-1 at the end of this section is Form MMS-137 “OCS Plan Information Form”.

Well A (OCS-G 22367 001) was spud on March 12, 2010 and suspended on June 9, 2010. A Revised Permit to Drill 

(RPD) was submitted on November 5, 2010 to the BOEMRE and is pending approval. Once the RPD is approved 

drilling operations will resume on the OCS-G 22367 001 well. 

Proposed Schedule

Proposed Activity Estimated 

Start Date

Estimated 

End Date

Estimated 

No. of Days

Drill, Evaluate and Abandon Exploratory Well A 12/01/2010 02/18/2011 80

Drill, Evaluate and Abandon Exploratory Well B 02/19/2011 07/18/2011 150

Drill, Evaluate and Abandon Exploratory Well C 07/19/2011 12/15/2011 150

Drill, Evaluate and Abandon Exploratory Well D 12/16/2011 05/13/2012 150

Drill, Evaluate and Abandon Exploratory Well E 05/14/2012 10/11/2012 150

(b) BATHYMETRY MAP

Included in Initial Exploration Plan, PI Copy, N-9380, Section A, Attachment A-2

(c) SAFETY and POLLUTION PREVENTION FEATURES 

Chevron plans to use a drillship to drill the wells proposed in this plan. The drillship is equipped with a Subsea BOP. 

Rig specifications will be provided with the Applications for Permit to Drill. If another rig type is used, any differences 

regarding air emissions, safety, drilling or pollution control equipment will be addressed in a revised Exploration 

Plan.

In accordance with 30 CFR 250.406, Chevron will ensure that safety features will include well control, pollution 

prevention, welding procedure, and blowout prevention equipment and as further clarified by BOEMRE Notices to 

Lessees and current policy making invoked by the BOEMRE. 

The rig will be monitored daily by a Chevron drilling representative and any waste or fuel resulting in pollution of the 

Gulf waters will be reported to the representative in charge for immediate isolation and correction of the problem. 

Any spill will be reported to governmental agencies. Chevron will comply with all BOEMRE Regulations during the 

course of the activities. 

The rig is equipped with safety, fire fighting, and lifesaving equipment required to comply with USCG, ABS, SOLAS, 

and IMO code requirements. 

Chevron will comply with all pertinent regulations in 30 CFR 250.203, NTL’s, and all federal and state documents to 

ensure that the proposed activities are safe and that there is minimal impact on the environment. Chevron will 

maintain compliance with the EPA NPDES Permit and lease agreement during these proposed activities.

(d) TABLE of STORAGE TANKS and PRODUCTION VESSELS

Included in Initial Exploration Plan, PI Copy, N-9380, Section A, page 2
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 2 Public Information

(g) ADDITIONAL SAFETY, POLLUTION PREVENTION, AND EARLY SPILL DETECTION MEASURES BEYOND 

THOSE REQUIRED IN 30 CFR 250.

In addition to pollution prevention measures utilized by Chevron, the drill ship has a comprehensive, proactive plan 

to address emergency situations that could result in an unanticipated oil/chemical release. The “Shipboard Oil 

Pollution Emergency Plan” has specific checklists and procedures to address accidental releases due to fuel/oil 

transfer, tank overflow, hull leakage, fire, explosion, collision and grounding. This plan is reviewed annually and oil 

pollution prevention drills are conducted as specified by MARPOL regulations. There is a fully stocked 

environmental equipment locker located on the main deck, forward of the Moonpool and numerous spill kits located 

throughout the main deck. The decks of the drillship are fully contained, a comprehensive scupper management 

plan in place, and any spills on the deck would be immediately cleaned up using absorbents or permitted solvents.

ATTACHMENTS TO SECTION A

A-1 - Form MMS-137 “OCS Plan Information Form” - Public Information Copy
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 3 Public Information

SECTION B GENERAL INFORMATION (30 CFR 250.213 and 250.243)

(a) APPLICATIONS AND PERMITS

In the table below, information is provided on the filing or approval status of the Federal, State, and local application 

approvals or permits that must be obtained to conduct the proposed activities. Only those individual or site-specific 

application approvals that must be obtained are listed.

Application/Permit Issuing Agency Status

Revised Permit to Drill BOEMRE Pending Approval

 

(b) DRILLING FLUIDS

(1) Information on the types (including chemical constituents) and amounts of the drilling fluids planned for use in 

drilling the proposed wells:

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

Used per Well

Water-based (seawater, brine, freshwater) 75,000 bbls

Oil-based (diesel, mineral oil) 0 bbls

Synthetic-based (internal olefin, ester) 10,000 bbls

(2) Major Components of Synthetic-based drilling fluid listed above:

Product Name Amount to be Used Reference Number MSDS No.

Lime (Calcium Hydroxide) 900 50-lb bags CAS # 1302-78-9 10046

Calcium Chloride 2500 50-lb bags CAS # 10043-52-4 10109

VG Plus 400 50-lb bags CAS # 68153-30-0 10128

VG Supreme 100 50-lb bags CAS # 14808-60-7 12207

Rheflat 2500 gals CAS # 68855-60-7 12246

Rhethik 1000 gals CAS # 111-46-6 12247

Rheduce 500 gals 12248

Suremul 4500 gals CAS#111-76-2,112-34-5 12243

Surewet 2500 gals CAS # 112-80-1 12245

SafeCarb 2000 50-lb bags CAS # 471-34-1 10337

M-I BAR 5000 tons CAS # 7727-43-7 10617

Synthetic B 8000 bbls 12269

G-Seal 960 bags CAS # 7782-42-5 10391

(e) NEW OR UNUSUAL TECHNOLOGY

Included in Initial Exploration Plan, PI Copy, N-9380, Section B, page 3 

(f) BONDING STATEMENT

Included in Initial Exploration Plan, PI Copy, N-9380, Section B, page 3 

(g) OIL SPILL FINANCIAL RESPONSIBILITY (OSFR)

Included in Initial Exploration Plan, PI Copy, N-9380, Section B, page 3 

(h)DEEPWATER WELL CONTROL STATEMENT

Included in Initial Exploration Plan, PI Copy, N-9380, Section B, page 3 
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 4 Public Information

SECTION C GEOLOGICAL AND GEOPHYSICAL INFORMATION (30 CFR 250.214 and 

250.244)

(a) GEOLOGICAL DESCRIPTION

Proprietary Information

(b) STRUCTURE CONTOUR MAPS

Proprietary Information 

(c) INTERPRETED 2-D AND/OR 3-D SEISMIC LINES

Proprietary Information

 

(d)GEOLOGICAL STRUCTURE CROSS-SECTION

Proprietary Information

 

(e)SHALLOW HAZARDS REPORT

Proprietary Information

(f)SHALLOW HAZARDS ASSESSMENT

Non-Proprietary version included in the Pubic Information Copy of Initial EP, N-9380, Section C, pages 4 - 6 

(g) HIGH RESOLUTION SEISMIC LINES

Proprietary Information

(h)STRATIGRAPHIC COLUMN

Proprietary Information

(i)TIME vs. DEPTH TABLE

Proprietary Information
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 5 Public Information

SECTION D HYDROGEN SULFIDE (H2S) INFORMATION (30 CFR 250.215 and 250.245)

(a)CONCENTRATION

Included in Initial Exploration Plan, PI Copy, N-9380, Section D, page 8

(b)CLASSIFICATION

Included in Initial Exploration Plan, PI Copy, N-9380, Section D, page 8

SECTION E BIOLOGICAL, PHYSICAL, AND SOCIOECONOMIC INFORMATION (30 

CFR 250.216 and 250.247)

(a)CHEMOSYNTHETIC COMMUNITIES REVIEW

Included in Initial Exploration Plan, PI Copy, N-9380, Section E, page 9

(g)REMOTELY OPERATED VEHICLE (ROV) MONITORING SURVEY PLAN

Included in Initial Exploration Plan, PI Copy, N-9380, Section E, page 10

(h)THREATENED OR ENDANGERED SPECIES, CRITICAL HABITAT, AND MARINE MAMMAL INFORMATION

Included in Initial Exploration Plan, PI Copy, N-9380, Section E, page 10
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 6 Public Information

SECTION F WASTE AND DISCHARGE INFORMATION (30 CFR 250.217 and 250.248)

(a) PROJECTED GENERATED WASTES

Table providing information on the projected solid and liquid wastes likely to be generated by the proposed activities:

Type of Waste Composition Projected Amount Method of Treating, 

Storing, or Downhole 

Disposal at Facility

Spent drilling fluids Water-based drilling muds 75,000 bbls/well Returns to seafloor

Cuttings generated with 

water based mud

Cuttings 3,000 bbls Returns to seafloor

Cuttings containing 

Synthetic-based mud

Cuttings coated with 

Synthetic drilling mud’s

6,500 bbls/well Processed with Solids 

removal equipment and 

discharged overboard.

Spent Synthetic-based 

mud

Synthetic-Based drilling 

mud’s

30,000 bbls/well Returned to mud pits on 

rig and reused. Returned 

to Liquid mud facility by 

transport vessel and 

reused.

(b) PROJECTED OCEAN DISCHARGES

A table providing information on any solid or liquid wastes to be discharged overboard:

Type of Waste Total Amount to be 

Discharged

Discharge Rate Discharge Method

Cuttings containing 

synthetic-based mud

2,835 bbls 6,500 bbls/well Processed and Shunt 

through downpipe to below 

water line

Synthetic based drilling 

fluid adhering to cuttings

717 bbls 7,150 bbs/well Processed and Shunt 

through downpipe to below 

water line

Spent drilling fluids 46,000 bbls 75,000 bbls/well Returns to seafloor

Cuttings generated with 

water based mud

2,927 bbls 3,000 bbls/well Returns to seafloor
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 7 Public Information

SECTION G AIR EMISSIONS INFORMATION (30 CFR 250.218 and 250.249)

EMISSIONS WORKSHEETS AND SCREENING QUESTIONS

The Complex Total Emissions are the same as the Plan Emissions, and therefore only one set of emissions 

calculations is included. Emissions from the proposed location are estimated using the EPA Publications referenced 

in the tables. 

All calculations are based on worst possible situations. Actual emissions are expected to be considerably below 

those estimated.

Included in this section as attachment G-1 is the Projected Air Quality Emissions Report worksheets (Form MMS138). 

SCREENING QUESTIONS FOR EP’S YES NO

Is any calculated Complex Total (CT) Emission amount (in tons) associated with your proposed 

exploration activities more than 90% of the amounts calculated using the following formulas: CT 

= 3400D2/3 for CO, and CT = 33.3D for the other pollutants (where D = distances to shore in 

miles)?

Do your emissions calculations include any emission reduction measures or modified emissions 

factors?

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

Do you expect to encounter H2S at concentrations greater than 20 parts per million (ppm)?

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

well?

Do you propose to burn produced hydrocarbon liquids?

CONTACT INFORMATION

Philip Von Dullen

Chevron U.S.A. Inc.

1500 Louisiana Street

Houston, Texas 77002

(832) 854-3644

pvondullen@chevron.com

MODELING REPORT

A Modeling Report is not required for activities proposed in this plan.

ATTACHMENTS TO SECTION G 

• G-1 – Form MMS-138 “Projected Air Quality Emissions Report”
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 8 Public Information

SECTION H OIL SPILLS INFORMATION (30 CFR 250.219 and 250.250)

(a) SPILL REPONSE PLANNING

REGIONAL OSRP INFORMATION

All the proposed activities and facilities in this EP will be covered by the Oil Spill Response Plan (Reference Number 

02335), filed by Chevron U.S.A. Inc., BOEMRE company number 00078, in accordance with 30 CFR 254, approved 

April 15, 2010. Chevron submitted a Revised Regional Oil Spill Response Plan to the BOEMRE on October 25, 

2010, currently pending approval.

SPILL RESPONSE SITES

In the table below, information is provided on the location of the primary spill response equipment and the location of 

the planned staging area(s) that would be used should an oil spill occur resulting from activities proposed in this 

plan.

Primary Response Equipment Location Preplanned Staging Location(s)

Leeville, LA Leeville, LA

OIL SPILL REMOVAL ORGANIZATION (OSRO) INFORMATION

Clean Gulf Associates (CGA) and Marine Spill Response Corporation (MSRC) are our primary oil spill removal 

organizations that will supply equipment and personnel. CGA and MSRC have equipment pre-staged around the 

Gulf of Mexico. The major locations of this equipment are Lake Charles, Houma, Fort Jackson and Venice, 

Louisiana; Galveston and Ingleside, Texas; and Pascagoula, Mississippi.
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 9 Public Information

WORST CASE SCENARIO DETERMINATION

The table below provides a comparison of the worst-case scenario from Chevron’s proposed Regional OSRP with 

the worst-case scenario from the proposed activities in this plan

Category

Regional OSRP 

“Mobile Rig 

Exploration Drilling 

Ops.” Worst-Case 

Discharge Scenario

EP 

Type of Activity (Types of activities 

include pipeline, platform, caisson, subsea 

completion or manifold, and mobile drilling 

rig)

Exploratory Drilling Exploratory Drilling

Spill Location (area/block)

Walker Ridge Block 

143

 

Keathley Canyon Block 736

Facility Designation (e.g., Well No. 2, 

Platform JA, Pipeline Segment No. 6373)

Mobile Rig Drillship

Distance to Nearest Shoreline 160 miles 216 miles

Volume

Uncontrolled blowout (volume per day) 165,994 barrels 51,650 barrels

Type of Oil(s) - (crude oil, condensate, 

diesel)

Crude Oil Crude Oil

Gravity(s) API - (Provide API gravity of 

all oils given under “Type of Oil(s)” above.

Estimate for EP’s)

28o 28o 

Since Chevron has the capability to respond to the appropriate worst-case spill scenario included in its revised 

Regional OSRP submitted on October 25, 2010, and since the worst-case scenario determined for our EP does not 

replace the appropriate worst-case scenario in our revised Regional OSRP, we hereby certify that Chevron 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 Plan.1

(b) OIL SPILL RESPONSE DISCUSSION

A discussion of the response to an oil spill resulting from the activities proposed in this plan:

In the event that a blowout would occur, Chevron U.S.A. Inc. would respond in accordance with our approved 

regional Oil Spill Response Plan. Chevron U.S.A. Inc. has contracted with Clean Gulf Associates (CGA) and Marine 

Spill Response Corp. (MSRC) as the primary Oil Spill Removal Organization. On notification of the spill, Chevron 

U.S.A. Inc. would contact CGA and request a full mobilization of equipment. The primary staging area would be 

Leeville, LA. Other staging areas would be utilized as warranted. The Incident Management System would be used 

to manage the response effort. The Emergency Response Operations Center would be established at Chevron 

U.S.A. Inc.'s, Covington, Louisiana office.

 

1 This certification is provided as required by NTL No. 2008-G04 at page 19.
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 10 Public Information

SECTION I ENVIRONMENTAL MONITORING IN FORMATION (30 C FR 25 0.221 an d 

250.252)

(a) MONITORING SYSTEMS

Provide a description of any existing and planned monitoring systems that are measuring, or will measure, 

environmental conditions and/or will provide project-specific data or information on the impacts of your proposed 

activities.

The Drillship is installed with surface current monitoring equipment. This equipment is a 75 kHz Acoustic Doppler 

Current Profile (ADCP) unit. This unit monitors current to a depth of 603 meters / 1,978’. The data from this meter is 

reported to the BOEMRE via the NDBC website.

(b) INCIDENTAL TAKES 

Included in Initial Exploration Plan, PI Copy, N-9380, Section I, page 15

SECTION J LEASE STIPULATIONS INFORMATION (30 CFR 250.222 and 250.253)

Included in Initial Exploration Plan, PI Copy, N-9380, Section J, page 15

SECTION K ENVIRONMENTAL MITIGATION MEASURES INFORMATION (30 CFR 

250.223 and 250.254)

(b) INCIDENTAL TAKES

Included in Initial Exploration Plan, PI Copy, N-9380, Section K, page 16

SECTION L SUPPORT VESSELS AND AIRCRAFT INFORMATION (30 CFR 250.224 and 

250.257)

(a) GENERAL

Included in Initial Exploration Plan, PI Copy, N-9380, Section L, page 16

(e) VICINITY MAP

Included in Initial Exploration Plan, PI Copy, N-9380, Section L, page 16 as Attachment L-1 

(b) DIESEL OIL SUPPLY VESSELS

Information on the vessels used to supply diesel oil. Any vessels that will transfer diesel oil you will use for purposes 

other than fuel.

Size of Fuel Supply 

Vessel

Capacity of Fuel Supply 

Vessel

Frequency of Fuel 

Transfers

Route Fuel Supply 

Vessel Will Take

280 foot 860,000 gals quarterly From shore base to block

280 foot 275,000 gals 4-6 weeks From shore base to block
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 11 Public Information

(d) SOLID AND LIQUID WASTES TRANSPORTATION

Information is provided regarding the transport of solid and liquid wastes from the site of the proposed activities to 

other offshore structures or to temporary or permanent onshore facilities for storage or disposal.

Type of Waste

Approximate 

Composition

Total

Amount

Name/Location Rate Transport Method

Spent synthetic-based 

drilling fluids

30,000 bbls M-I Swaco, Port 

Fourchon Facility

300 bbls/day Internal Mud tanks 

on motor vessel

Chemical product 

wastes

360 bbls Mars Facility, 

Morgan City, LA

3 bbls/day Drums on crew boat

Trash and Debris 210,317 lb * Morgan City Landfill 1753 lb/day Storage bins on 

crew boat
Chevron USA Inc. Exploration Plan 

Keathley Canyon Block 736 12 Public Information

SECTION M ONSHORE SUPPORT FACILITIES INFORMATION (30 CFR 250.225 and 

250.258)

(a) GENERAL

Included in Initial Exploration Plan, PI Copy, N-9380, Section M, page 17

(c)SUPPORT BASE CONSTRUCTION OR EXPANSION

Included in Initial Exploration Plan, PI Copy, N-9380, Section M, page 17

(d) WASTE DISPOSAL

The table below provides information on the onshore facilities that will be used to store and dispose of any solid and 

liquid wastes generated by the proposed activities.

Name/Location of 

Facility

Type of Waste Amount Rate Disposal Method

Newpark 

Environmental 

Services/Venice, LA

Spent water-based 

drilling fluids and 

cuttings

~1,000 bbls/well 500 bbl/day Transport by boat in 

cutting bins to 

shorebase; truck to 

disposal facility

Newpark 

Environmental 

Services,

Venice, LA

Spent synthetic oilbased drilling fluids 

and cuttings

~2,500 bbls/well 200 bbl/day Transport by boat in 

cutting bins to 

shorebase; truck to 

disposal facility

Newpark 

Environmental 

Services,

Venice, LA

Wash Water ~425 bbls/well 2 bbl/day Transport by boat in 

tanks to shorebase; 

truck to disposal 

facility

Solid Waste 

Disposal Inc, 

Riverbirch Landfill, 

Avondale, LA

Trash and debris ~210,317 lb. 1753 lb/day Transport by boat in 

storage bins to 

shorebase

SECTION O ENVIRONMENTAL IMPACT ANALYSIS (EIA) (30 CFR 250.227 and 

250.261)

A project-specific EIA was attached to Initial Exploration Plan, PI Copy, N-9380, following page 19
ATTACHMENT A-1 1 of 6 Public Information

U.S. Department of the Interior OMB Control Number: 1010-0049

Minerals Management Service OMB Approval Expires: August 31, 2006

 

OCS PLAN INFORMATION FORM

General Information

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

Company Name: Chevron U.S.A. Inc. MMS Operator Number: 00078

Address: 1500 Louisiana Street Contact Person: Philip A. Von Dullen III 

 Houston, TX 77002 Phone Number: (832) 854-3644 

E-Mail Address: pvondullen@chevron.com 

Lease(s):

OCS-G 22367 

Area:

Keathley Canyon 

Block(s)

736 

Project Name (If Applicable):

Moccasin

Objective(s) X Oil X Gas Sulphur Salt Onshore Base: Leeville, LA Distance to closest land (Miles): 216

Description of Proposed Activities (Mark all that Apply)

X Exploration Drilling Development Drilling

Well completion Installation of production platform

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

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

Installation of sub sea 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 sub sea development? Yes X No

Do you propose any activities that may disturb an MMS-designated high-probability archaeological area? Yes X No

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

Tentative Schedule of Proposed Activities

Proposed Activity Start Date End Date No. of Days

Drill, Evaluate and Abandon Exploratory Well A 12/01/2010 02/18/2011 80

Drill, Evaluate and Abandon Exploratory Well B 02/19/2011 07/18/2011 150

Drill, Evaluate and Abandon Exploratory Well C 07/19/2011 12/15/2011 150

Drill, Evaluate and Abandon Exploratory Well D 12/16/2011 05/13/2012 150

Drill, Evaluate and Abandon Exploratory Well E 05/14/2012 10/11/2012 150

Description of Drilling Rig Description of Production Platform

Jack up X Drill ship Caisson Tension leg platform

Gorilla Jack up Platform rig Well protector Compliant tower

Semi submersible Submersible Fixed platform Guyed tower

DP Semi submersible Other (attach description) Sub sea 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 (August 2003 – Supersedes all previous editions of form MMS-137, which may not be used.)

Page 1 of 2
ATTACHMENT A-1 2 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “A” (OCS-G 22367 001)

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 580 F S L

E / W Departure: 7158 F W L

Lambert X-Y Coordinates X: 1844598

Y: 9520420

Latitude / Longitude Latitude: N 26° 14’ 10.389”

Longitude: W 92° 22’ 36.857”

Water Depth (Feet) -6793

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=
ATTACHMENT A-1 3 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “B” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 2159 F S L 

E / W Departure: 2570 F W L 

Lambert X-Y Coordinates X: 1840010

Y: 9521999

Latitude / Longitude Latitude: N 26° 14’ 26.246”

Longitude: W 92° 23’ 27.176”

Water Depth (Feet) -6842

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=

 
ATTACHMENT A-1 4 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “C” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 5469 F S L 

E / W Departure: 6048 F W L 

Lambert X-Y Coordinates X: 1843488

Y: 9525309

Latitude / Longitude Latitude: N 26° 14’ 58.878”

Longitude: W 92° 22’ 48.793”

Water Depth (Feet) -6673

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=

 
ATTACHMENT A-1 5 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “D” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 2720 F S L 

E / W Departure: 6142 F W L

Lambert X-Y Coordinates X: 1843582

Y: 9522560

Latitude / Longitude Latitude: N 26° 14’ 31.637”

Longitude: W 92° 22’ 47.905”

Water Depth (Feet) -6720

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=

 
ATTACHMENT A-1 6 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “E” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 3712 F S L 

E / W Departure: 6137 F W L

Lambert X-Y Coordinates X: 1843577

Y: 9523552

Latitude / Longitude Latitude: N 26° 14’ 41.466”

Longitude: W 92° 22’ 47.908”

Water Depth (Feet) -6755

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=

 
AIR EMISSIONS REPORT

Exploration Plan Additional Information

Keathley Canyon Block 736

Lease OCS-G 22367

 

 

Drillship

 

Prepared by:

Philip A. Von Dullen III

Chevron U.S.A. Inc.

1500 Louisiana Street

Houston, TX 77002

(832) 854-3644

October 2010

ATTACHMENT G-1 
COMPANY Chevron U.S.A. Inc.

AREA Keathley Canyon

BLOCK 736

LEASE OCS-G 22367

PLATFORM Drillship

WELL 5-Wells

COMPANY CONTACT Philip Von Dullen III

TELEPHONE NO. (832) 854-3644

REMARKS Exploration Plan (EP) November 2010
EMISSIONS FACTORS

Form MMS-138 (March 2000)

Page 2 of 6

KC 736 Moccasin Revised EP Air Emissions.xls

4:47 PM 11/10/2010

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

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

Equipment/Emission Factors units OCS-G 22367 SOx NOx VOC CO REF. DATE

NG Turbines gms/hp-hr 5-Wells 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96

NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96

NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96

NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96

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

Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96

Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3-12,14 9/98

NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 14-2, & 14 7/98

NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91

Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98

Tank Vapors lbs/bbl 0.03 E&P Forum 1/93

Fugitives lbs/hr/comp. 0.0005 API Study 12/93

Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991

Gas Venting lbs/scf 0.0034

Sulfur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight
EMISSIONS CALCULATIONS 1ST YEAR

Form MMS-138 (March 2000)

Page 3 of 6 KC 736 Moccasin Revised EP Air Emissions.xls

4:47 PM 11/10/2010

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Chevron U.S.A. Inc. Keathley Canyon 736 OCS-G 22367 Drillship 5-Wells Philip Von Dullen III (832) 854-3644 Initial Exploration Plan (EP)

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 31 6.89 31.60 236.77 7.10 51.66 2.56 11.75 88.08 2.64 19.22

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 31 6.89 31.60 236.77 7.10 51.66 2.56 11.75 88.08 2.64 19.22

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 31 6.89 31.60 236.77 7.10 51.66 2.56 11.75 88.08 2.64 19.22

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 31 6.89 31.60 236.77 7.10 51.66 2.56 11.75 88.08 2.64 19.22

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 31 4.59 21.07 157.85 4.74 34.44 1.71 7.84 58.72 1.76 12.81

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 31 4.59 21.07 157.85 4.74 34.44 1.71 7.84 58.72 1.76 12.81

Emergency Generator-diesel 3257 157.3131 3775.51 1 31 2.30 10.53 78.91 2.37 17.22 0.04 0.16 1.22 0.04 0.27

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

VESSELS>600hp diesel(crew) 5200 251.16 6027.84 16 5 3.67 16.81 125.99 3.78 27.49 0.15 0.67 5.04 0.15 1.10

VESSELS>600hp diesel(supply) 5200 251.16 6027.84 16 31 3.67 16.81 125.99 3.78 27.49 0.91 4.17 31.25 0.94 6.82

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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

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

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 1875000 24 21 1.11 133.88 113.06 728.44 0.28 33.74 28.49 183.57

2010 YEAR TOTAL 46.36 213.79 1727.54 160.87 1076.15 14.76 67.98 541.00 43.71 294.24

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 7192.80 7192.80 7192.80 7192.80 122400.00

216.0
EMISSIONS CALCULATIONS 2ND YEAR

Form MMS-138 (March 2000)

Page 4 of 6 KC 736 Moccasin Revised EP Air Emissions.xls

4:47 PM 11/10/2010

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Chevron U.S.A. Inc. Keathley Canyon 736 OCS-G 22367 Drillship 5-Wells Philip Von Dullen III (832) 854-3644 Initial Exploration Plan (EP)

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 365 6.89 31.60 236.77 7.10 51.66 30.17 138.40 1037.04 31.11 226.26

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 365 6.89 31.60 236.77 7.10 51.66 30.17 138.40 1037.04 31.11 226.26

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 365 6.89 31.60 236.77 7.10 51.66 30.17 138.40 1037.04 31.11 226.26

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 365 6.89 31.60 236.77 7.10 51.66 30.17 138.40 1037.04 31.11 226.26

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 365 4.59 21.07 157.85 4.74 34.44 20.11 92.27 691.39 20.74 150.85

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 365 4.59 21.07 157.85 4.74 34.44 20.11 92.27 691.39 20.74 150.85

Emergency Generator-diesel 3257 157.3131 3775.51 1 365 2.30 10.53 78.91 2.37 17.22 0.42 1.92 14.40 0.43 3.14

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

VESSELS>600hp diesel(crew) 5200 251.16 6027.84 16 52 3.67 16.81 125.99 3.78 27.49 1.52 6.99 52.41 1.57 11.44

VESSELS>600hp diesel(supply) 5200 251.16 6027.84 16 365 3.67 16.81 125.99 3.78 27.49 10.70 49.10 367.89 11.04 80.27

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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

VESSELS>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 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 1875000 24 14 1.11 133.88 113.06 728.44 0.19 22.49 18.99 122.38

2011 YEAR TOTAL 46.36 213.79 1727.54 160.87 1076.15 173.55 796.33 5988.14 197.96 1423.97

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 7192.80 7192.80 7192.80 7192.80 122400.00

216.0
EMISSIONS CALCULATIONS 3RD YEAR

Form MMS-138 (March 2000)

Page 5 of 6 KC 736 Moccasin Revised EP Air Emissions.xls

4:47 PM 11/10/2010

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Chevron U.S.A. Inc. Keathley Canyon 736 OCS-G 22367 Drillship 5-Wells Philip Von Dullen III (832) 854-3644 Initial Exploration Plan (EP)

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 284 6.89 31.60 236.77 7.10 51.66 23.47 107.68 806.90 24.21 176.05

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 284 6.89 31.60 236.77 7.10 51.66 23.47 107.68 806.90 24.21 176.05

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 284 6.89 31.60 236.77 7.10 51.66 23.47 107.68 806.90 24.21 176.05

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 284 6.89 31.60 236.77 7.10 51.66 23.47 107.68 806.90 24.21 176.05

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 284 4.59 21.07 157.85 4.74 34.44 15.65 71.79 537.96 16.14 117.37

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 284 4.59 21.07 157.85 4.74 34.44 15.65 71.79 537.96 16.14 117.37

Emergency Generator-diesel 3257 157.3131 3775.51 1 284 2.30 10.53 78.91 2.37 17.22 0.33 1.50 11.21 0.34 2.44

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

VESSELS>600hp diesel(crew) 5200 251.16 6027.84 16 41 3.67 16.81 125.99 3.78 27.49 1.20 5.52 41.33 1.24 9.02

VESSELS>600hp diesel(supply) 5200 251.16 6027.84 16 284 3.67 16.81 125.99 3.78 27.49 8.33 38.20 286.25 8.59 62.45

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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

VESSELS>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 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 1875000 24 14 1.11 133.88 113.06 728.44 0.19 22.49 18.99 122.38

2012 YEAR TOTAL 46.36 213.79 1727.54 160.87 1076.15 135.05 619.72 4664.80 158.26 1135.24

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 7192.80 7192.80 7192.80 7192.80 122400.00

216.0
SUMMARY

Page 1 of 1

COMPANY AREA BLOCK LEASE PLATFORM WELL

Chevron U.S.A. Inc. Keathley Canyon Keathley Canyon OCS-G 22367 Drillship 5-Wells

Emitted Substance

Year

PM Sox NOx VOC CO

2010 14.76 67.98 541.00 43.71 294.24

2011 173.55 796.33 5988.14 197.96 1423.97

2012 135.05 619.72 4664.80 158.26 1135.24

2013 0.00 0.00 0.00 0.00 0.00

2014 0.00 0.00 0.00 0.00 0.00

2015 0.00 0.00 0.00 0.00 0.00

2016 0.00 0.00 0.00 0.00 0.00

2017 0.00 0.00 0.00 0.00 0.00

2018 0.00 0.00 0.00 0.00 0.00

2019 0.00 0.00 0.00 0.00 0.00

Allowable 7192.80 7192.80 7192.80 7192.80 122400.00
SPILL RESPONSE DISCUSSION 

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

from the proposed activity would be a well blowout during drilling operations, estimated to be 51,650 

barrels of crude oil with an API gravity of 28.2°. 

Land Segment and Resource Identification

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

information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of 

Mexico available on the BOEM website. The results are shown in Figure 1. The BOEM OSRAM identifies 

a 2% probability of impact to the shorelines of Matagorda County, TX, Galveston County, TX and/or 

Cameron Parish, LA within 30 days. 

Matagorda County stretches from Matagorda Bay, across the Colorado River and up to the border of San 

Bernard Wildlife Refuge (immediately west of the San Bernard River). The county includes Matagorda 

Peninsula on the Gulf coast and Matagorda Bay. This area is primarily open beach. However, marshland 

exists along the east side of Matagorda Bay. Several bird rookeries are present around the peninsula. 

Sea grass is present off of Matagorda Peninsula on the bay side. 

Galveston County includes the Gulf Beach from the west end of Galveston Island at Texas Highway 3005 

to the east coast of High Island at the Jefferson County line. Habitats include marshes at the west end of 

Seawall Boulevard and on the east end of the island and open beaches and avian feeding areas all along 

the coastline, including a National Audubon Society Sanctuary. The waters of Galveston Bay are 

classified as an EPA National Estuary. 

Cameron Parish includes the east side of Sabine Lake, Sabine National Wildlife Refuge, Calcasieu Lake, 

Lacassine National Wildlife Refuge (inland) and Grand Lake. Cameron Parish also includes the area 

along the coastline from Sabine Pass to Big Constance Lake in Rockefeller Wildlife Refuge. This region is 

composed of open public beaches, marshlands and swamps. It serves as a habitat for numerous birds, 

finfish and other animals, including several rare, threatened and endangered species. 

Response

Chevron U.S.A. Inc. will make every effort to respond to the Worst Case Discharge as effectively as 

possible. A description of the response equipment available to contain and recover the Worst Case 

Discharge is shown in Figure 2. 

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

run on a similar product from the ADIOS oil database. The results indicate 14% or 7,231 barrels of crude 

oil would be evaporated/dispersed within 24 hours, with 44,419 barrels remaining. 

Offshore Spill Response Barrels of Oil 

WCD Volume 51,650 

Less 11% natural evaporation/dispersion 7,231 

Remaining volume 44,419 

Oil addressed by aerial dispersants 7,540 

Oil addressed by in-situ burning 2,582 
Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary storage 

equipment available to respond to a spill of 44,419 barrels. The volume accounts for the amount 

remaining after evaporation/dispersion at 24 hours. The list estimates individual times needed for 

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

be supported. 

If aerial dispersants are utilized, 8 sorties (8,000 gallons) from two of the DC-3 aircrafts and 4 sorties 

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

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

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

Horizon spill of 2010, up to 5% or 2,582 barrels of the total daily Worst Case Discharge volume could be 

burned. Slick containment boom would be immediately called out and on-scene as soon as possible. 

Offshore response strategies may include attempting to skim utilizing the HOSS Barge, nine Fast 

Response Units, and six sets of Koseq skimming arms, with a total derated skimming capacity of 183,904 

barrels. Temporary storage associated with skimming equipment equals 7,200 barrels. If additional 

storage is needed, six 24,000 barrel storage barges and a 45,000 barrel storage barge may be mobilized. 

Safety is first priority. Air monitoring will be accomplished and operations deemed safe prior to 

any containment/skimming attempts. 

If the spill went unabated, shoreline impact in Matagorda County, TX, Galveston County, TX, and 

Cameron Parish, LA would depend upon existing environmental conditions. Shoreline protection would 

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

capacity of 13,253 barrels. Temporary storage associated with skimming equipment equals 1,252 barrels. 

Onshore response may include the deployment of shoreline boom on beach areas, or protection and 

sorbent boom on vegetated areas. Strategies would be based upon surveillance and real time trajectories 

that depict areas of potential impact given actual sea and weather conditions. The One-Gulf Plan (Area 

Contingency Plan), the State of Louisiana Initial Oil Spill Response Plan for Cameron Parish, and Unified 

Command would be consulted to ensure that environmental and special economic resources would be 

correctly identified and prioritized to ensure optimal protection. Shoreline protection strategies depict the 

protection response modes applicable for oil spill clean-up operations. In the One-Gulf Plan, each 

response mode is schematically represented to show optimum deployment and operation of the 

equipment in areas of environmental concern. The State of Louisiana Initial Oil Spill Response Plan 

provides detailed shoreline protection strategies for this area, and it describes necessary action to keep 

the oil spill from entering Louisiana’s coastal wetlands, based on the assumption that removal of the 

released oil will be much easier and less damaging to fragile coastal ecosystems if done in the open 

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

operation of equipment allowing a more effective response to site-specific circumstances. Chevron U.S.A. 

Inc.’s contract Spill Management Team holds a copy of the One-Gulf Plan and the State of Louisiana 

Initial Oil Spill Response Plan. 
FIGURE 1 

TRAJECTORY BY LAND SEGMENT 

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

Chevron U.S.A. Inc.’s WCD and information in the BOEM Oil Spill Risk Analysis Model (OSRAM) 

for the Central and Western Gulf of Mexico available on the BOEM website using 30 day impact. 

The results are tabulated below. 

Area/Block OCS-G Launch 

Area 

Land Segment and/or 

Resource 

Conditional 

Probability (%) within 

30 days 

Drill, evaluate and 

abandon 5 wells 

KC 736 

216 miles from shore 

G22367 Western 

Planning 

Area 29 

Kenedy County, TX 

Kleberg County, TX 

Aransas County, TX 

Calhoun County, TX 

Matagorda County, TX 

Brazoria County, TX 

Galveston County, TX 

Jefferson County, TX 

Cameron Parish, LA 

Vermilion Parish, LA 

1 

1 

1 

1 

2 

1 

2 

1 

2 

1 
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (216 miles from shore) 

44,419 bbls of crude oil* API Gravity 28.2° 

FIGURE 2 – Equipment Response Time to Keathley Canyon 736 

Dispersant/Surveillance 

Dispersant 

Capacity 

(gal) 

Storage 

Capacity

Persons 

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

Basler 67T 2000 NA 2 Houma 1 1 1.3 DC 3 1000 NA 2 Houma 1 1 1.7 DC 3 1000 NA 2 Houma 1 1 1.7 Aero Commander NA NA 2 Houma 1 1 1.3 

Offshore Equipment No 

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

HOSS Barge 43000 4000 3 Tugs 8 Houma 4 0 5 

Recovered Oil Storage 

No Staging EDRC 

Storage 

Capacity 

(bbl) 

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

CTCo 2404 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2601 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2602 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2603 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2605 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 2606 NA 24000 1 Tug 6 Amelia 4 0 4 CTCo 5001 NA 45000 1 Tug 6 Amelia 4 0 4 
Nearshore Recovered Oil 

Storage No Staging EDRC 

Storage 

Capacity 

(bbl) 

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

CTCo 2604 NA 22500 1 Tug 6 Amelia 4 0 4 

Staging Area: Fourchon 

Offshore Equipment With 

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

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2.5 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 7 FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 1 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 9.5 FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 4 FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6 Venice 1 2 4 Koseq Skimming Arms (6) 106974 1500 6 Utility 36 Galveston 1 12 7.5 

Offshore Equipment With 

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

42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2.5 42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 7 42” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 2 1 42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 9.5 42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 4 42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 
Nearshore and Inland 

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

Dep

SWS Egmopol 3000 100 NA 3 Galveston 1 2 7 SWS Egmopol 3000 100 NA 3 Houma (Egmopol) 1 2 1 SWS Marco 3588 34 NA 3 Houma (Marco) 1 2 1 SWS Marco 3588 20 NA 3 Lake Charles 1 2 4 Rope Mop 77 2 0 3 Belle Chasse 1 2 2.5 RO Storage Barge NA 249 Towed 0 Galveston 1 2 7 RO Storage Barge NA 249 Towed 0 Houma 1 2 1 RO Storage Barge NA 249 Towed 0 Lake Charles 1 2 4 RO Storage Barge NA 249 Towed 0 Venice 1 2 4 

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

Dep

Beach Boom (1000’) NA NA NA 4 Belle Chasse 1 2 2.5 Beach Boom (2000’) NA NA NA 6 Galveston 1 2 7 Beach Boom (2000’) NA NA NA 6 Houma 1 2 1 Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 9.5 Beach Boom (2000’) NA NA NA 6 Lake Charles 1 2 4 Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 
Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Load Out Travel to Staging T

Dep

Wildlife Support Trailer NA NA NA 2 Houma 1 2 1 Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 2.5 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 7 Bird Scare Guns (24) NA NA NA 2 Houma 1 2 1 Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 9.5 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 4 Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 

Response Asset Total 

Offshore EDRC 183,904 Offshore Recovered Oil Capacity 196,200 Nearshore / Shallow Water EDRC 13,253 Nearshore / Shallow Water Recovered Oil Capacity 23,752 


Amended February 25, 2011

CHEVRON U.S.A. INC.

EXPLORATION PLAN R-5096

KEATHLEY CANYON BLOCK 736

OCS-G 22367

OFFSHORE LOUISIANA

“MOCCASIN” PROSPECT

SECTION B GENERAL INFORMATION (d) OIL CHARACTERISTICS

 

SECTION E BIOLOGICAL, PHYSICAL, AND SOCIOECONOMIC INFORMATION (a) HIGH-DENSITY DEEPWATER BENTHIC COMMUNITIES INFORMATION

SECTION F WASTE AND DISCHARGE INFORMATION (a) PROJECTED GENERATED WASTES

 (b) PROJECTED OCEAN DISCHARGES

SECTION H OIL SPILLS INFORMATION (a) WORST CASE DISCHARGE COMPARISON TABLE

 (b) SPILL RESPONSE DISCUSSION

SECTION L SUPPORT VESSELS AND AIRCRAFT INFORMATION (d) SOLID AND LIQUID WASTES TRANSPORTATION

SECTION M ONSHORE SUPPORT FACILITIES INFORMATION (d) WASTE DISPOSAL
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 1

SECTION B GENERAL INFORMATION (30 CFR 250.213)

(d) OIL CHARACTERISTICS

Characteristic Analytical Methodologies Should be Compatible with:

(1) Gravity (API): 27-29 ASTM D4052

(2) Flash Point (°C): 15 ASTM D93 / IP 34

(3) Pour Point (°C): -9 ASTM D97

(4) Viscosity (Centipoise at 25°C): 22-49 ASTM D445

(5) Wax Content (wt %): 1.0-3.5 Precipitates with 2-butanon/dichloromethane (1 to 1 

volume) at -10 °C

(6) Asphaltene Content (wt %): 5-11 IP-Method 143/84

(7) Resin Content (wt %): 5-8 Jokuty et al. (1996)

(8) Boiling point distribution including, for each 

fraction, the percent volume or weight and the boiling 

point range in degrees C

BOILING POINT (SIMDIS) YIELDS, VOL % 

Lt Gasoline (55-175 oF) 2.7 

Lt Naphtha (175-300 oF) 8.3 

Hvy Naptha (300-400 oF) 8.3 

Kerosene (400-500 oF) 9.2 

Atm Gas Oil (500-650 oF) 14.2 

Lt Vac Gas Oil (650-800 oF) 13.5 

Hvy Vac Gas Oil (800-1050 oF) 18.7 

Vac Resid (1050-FBP oF) 24.9 

ASTM D2892 (TBP distillation), or ASTM D2887/5307

(9) Sulphur (wt %): 2.0 ASTM D4294

Oil from one well

Area/Block: Keathley Canyon 872

MMS Platform ID:

API Well No: 

Completion perforation interval: 26,967 – 28,091’

MMS reservoir name: OCS-G 25823 #1

Sample date: 11/18/2008, 1/13/2009

Sample No. (if more than one): N/A
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 2

SECTION E BIOLOGICAL, P HYSICAL, A ND S OCIOECONOMIC IN FORMATION (30 

CFR 250.216)

(a) HIGH-DENSITY DEEPWATER BENTHIC COMMUNITIES INFORMATION

Geoscience Earth & Marine Services, Inc. ®, (GEMS) was contracted by Chevron U.S.A. Inc., (Chevron) to provide 

an assessment of the shallow conditions at the proposed drilling locations A, B, C, D, and E in Block 736, of the

Keathley Canyon Area, Gulf of Mexico. The assessments address specific seafloor and subsurface geologic

conditions around the proposed locations to the Top of Salt. The reports comply with the various Bureau of Ocean 

Energy Management, Regulation, and Enforcement (BOEMRE) Notice to Lessees (NTL’s) 2008-G05 and 2009-G40 

(MMS, 2008a and 2010). The proposed wellsites will be required to follow NTL 2008-G06 with respect to pre- and 

post-spud ROV visual inspection surveys (MMS, 2008b). The Federal lease block KC 736 is not considered 

archaeologically significant (MMS, 2008c); therefore, requirements set forth in NTL 2005-G07 are not applicable 

(MMS, 2005).

The proposed wells will be drilled with a dynamically positioned drillship, so there or no associated anchors, anchor 

chain or wire ropes.

Deepwater Benthic Communities Summary Statement for each of the proposed wells:

Wellsite “A” 

There is no indication of fluids or gas venting from nearby faults at the seabed. Features or areas that could support 

high-density deepwater benthic communities are not located within 2,000 ft of the proposed location. The Seafloor 

Amplitude Map shows normal or ambient amplitudes along the seabed at, and near, the proposed wellsite.

Wellsite “B” 

There is no indication of fluids or gas venting from nearby faults at the seabed. Features or areas that could support 

high-density deepwater benthic communities are not located within 2,000 ft of the proposed location. The Seafloor 

Amplitude Map shows normal or ambient amplitudes along the seabed at, and near, the proposed wellsite.

Wellsite “C” 

There is no indication of fluids or gas venting from nearby faults at the seabed. Features or areas that could support 

high-density deepwater benthic communities are not located within 2,000 ft of the proposed location. The Seafloor 

Amplitude Map shows normal or ambient amplitudes along the seabed at, and near, the proposed wellsite.

Wellsite “D” 

There is no indication of fluids or gas venting from nearby faults at the seabed. Features or areas that could support 

high-density deepwater benthic communities are not located within 2,000 ft of the proposed location. The Seafloor 

Amplitude Map shows normal or ambient amplitudes along the seabed at, and near, the proposed wellsite. 

Wellsite “E” 

There is no indication of fluids or gas venting from nearby faults at the seabed. Features or areas that could support 

high-density deepwater benthic communities are not located within 2,000 ft of the proposed location. The Seafloor 

Amplitude Map shows normal or ambient amplitudes along the seabed at, and near, the proposed wellsite.

The complete GEMS wellsite assessments are proprietary enclosures to this plan.
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 3

SECTION F WASTE AND DISCHARGE INFORMATION (30 CFR 250.217)

(a) PROJECTED GENERATED WASTES

Table providing information on the projected solid and liquid wastes likely to be generated by the proposed drilling 

activities in EP N-9380:

Type of Waste Composition Projected Amount Describe how it will it be 

treated, stored, or 

downhole

disposed of

at your facility

Spent Drilling Fluids Synthetic-based drilling 

muds

17,000 bbls/well Re-used.

Spent Drilling Fluids Water based drilling fluid 57,203 bbls/well Discharge at mudline prior 

to 

riser installation.

Washed Cuttings

from water based

hole interval

Cuttings coated with water

based drilling muds

1,493 bbls/well Discharge at mudline prior 

to 

riser installation.

Washed Drill cuttings

from synthetic based

hole interval

Drill cuttings 7,338 bbls/well Treated cuttings will be

discharged overboard 

during drilling of SBM 

interval. Cuttings will pass 

through cuttings dryer 

substantially reducing 

ROC percentage

from worst case quoted

below. Or stored in cutting 

boxes and transported to 

shore.

Sanitary Waste Treated human body 

waste 

from toilets

187 bbls per day USCG-approved MSD with

chlorination.

Starboard Caisson

Domestic Waste Gray water (laundry, 

galley,

lavatory)

377 bbl per day Food grinder.

Starboard Caisson

Chemical Waste Used oil, hazardous waste 360 bbls/well Store in drums. Transport 

on crew boat to shore for 

disposal.

Produced water Formation water N/A N/A

Desalination unit

brine water

Rejected water from

watermaker unit

1827 bbl per day Hull Discharge Overboard

Deck drainage Platform washings and

rainwater

1137 bbl per day Hull Discharge Overboard

Trash and debris Plastic, Paper, Aluminum,

Glass, and other refuse

270,000 lbs/well Storage containers. 

Transport on crew boat to 

shore for disposal.

Cooling water Seawater with no addition 

of

chemicals

500,000 bbl per day Hull Discharge Overboard
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 4

Fire water Seawater with no addition 

of

chemicals

51,428 bbl per day when 

flaring only.

Hull Discharge Overboard

Ballast water Uncontaminated seawater

used to maintain proper 

draft

154,144 bbls per month 

(average)

Hull Discharge Overboard

Blowout Preventer

Fluid

Stackmagic 200/0/5%

glycol based on 2% 

mixture

with potable water

250 bbl per well Discharged at mudline
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 5

(b) PROJECTED OCEAN DISCHARGES

A table providing information on any solid or liquid wastes to be discharged overboard generated by the proposed 

drilling activities in EP N-9380:

Type of Waste Total Amount to be

Discharged

Discharge Rate Discharge Method

Water based mud 286,015 bbls 57,203 bbls/well Seafloor discharge prior

to marine riser

installation

Washed Drill

cuttings from

synthetic based hole

interval

36,690 bbls 7,338 bbls/well Shunt through a

downpipe to 25’ below

the water’s surface

Drill Cuttings from

water base drilling

interval

7,465 bbls 1,493 bbls/well Seafloor discharge prior

to marine riser

installation

Excess cement 3,200 bbls 800 bbl / well Discharged at the

seafloor during riserless

drilling

Cooling water 375,000,000 bbls 75,000,000 bbls/well Discharged overboard

Sanitary waste 140,250 bbls 28,050 bbls/well Treated in the MSD**

prior to discharge to

meet NPDES limits

Domestic waste 282,750 bbls 56,550 bbls/well Grinded to less than 25

mm mesh size and

discharge overboard

Desalination unit

brine water

1,370,250 bbls 274,050 bbls/well Discharged overboard

Deck drainage 852,750 bbls 170,550 bbls/well Discharged overboard

Ballast water 3,853,600 bbls 770,720 bbls/well Discharged overboard

Firewater Bypass 168,117,750 bbls 224,157 bbls/day

33,623,550 /Well

Discharged overboard
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 6

SECTION H OIL SPILLS INFORMATION (30 CFR 250.219)

(a) WORST CASE DISCHARGE COMPARISON TABLE

The table below provides a comparison of the worst-case scenario from Chevron’s proposed Regional OSRP with 

the worst-case scenario from the proposed activities in this plan

Category

Regional OSRP 

“Mobile Rig 

Exploration Drilling 

Ops.” Worst-Case 

Discharge Scenario

EP 

Type of Activity (Types of activities 

include pipeline, platform, caisson, subsea 

completion or manifold, and mobile drilling 

rig)

Exploratory Drilling Exploratory Drilling

Spill Location (area/block)

Green Canyon 640 Keathley Canyon Block 736

Facility Designation (e.g., Well No. 2, 

Platform JA, Pipeline Segment No. 6373)

GC 640 PS006 KC 736 “A”

Distance to Nearest Shoreline 118 miles 216 miles

Volume

Uncontrolled blowout (volume per day) 186,452 barrels 51,650 barrels

Type of Oil(s) - (crude oil, condensate, 

diesel)

Crude Oil Crude Oil

Gravity(s) API - (Provide API gravity of 

all oils given under “Type of Oil(s)” above.

Estimate for EP’s)

30o 28o 

Since Chevron has the capability to respond to the appropriate worst-case spill scenario included in its revised 

Regional OSRP submitted on February 24, 2011, and since the worst-case scenario determined for our EP does not 

replace the appropriate worst-case scenario in our revised Regional OSRP, we hereby certify that Chevron 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 Plan.1

 

 

1 This certification is provided as required by NTL No. 2008-G04 at page 19.
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 7

(b) SPILL RESPONSE DISCUSSION

Oil spill response related activities for facilities included in this document are governed by the Chevron Gulf of 

Mexico Business Unit Regional Oil Spill Response Plan (OSRP). This OSRP meets all requirements contained in 30 

CFR 250. The existing Chevron Regional OSRP was approved by BOEMRE on April 19, 2010. Chevron submitted 

a revised OSRP to the BOEMRE on February 24, 2011. The below information is from the Chevron revised OSRP. 

Chevron also submitted to the BOEMRE Regional Supervisor, in accordance with 30 CFR 254.2(b), a letter dated 

October 22, 2010 stating that Chevron has the capability to respond, to the maximum extent practicable, to a worst 

case discharge or a substantial threat of such a discharge for all Chevron Gulf of Mexico facilities. The Chevron 

Gulf of Mexico Business Unit Regional OSRP encompasses all facilities operated by Chevron, U.S.A. Inc. and, 

herein the jurisdiction of the BOEMRE. 

The worst case discharge for Keathley Canyon 736 is 51,650 barrels per day. This was calculated using the 

guidance provided in NTL 2010-N06. 

Response Discussion (§ 256.26 (d))

Chevron maintains numerous resources, equipment and expertise to respond to an oil spill in the Gulf of Mexico. 

Chevron has oil spill response service contracts with both local and international companies and cooperatives, and 

has a large corps of dedicated Chevron emergency responders that can work in the Gulf of Mexico. Chevron has 

contracts with the following oil spill response service providers.

Oil Spill Removal Organizations (OSRO). These companies have on-hand shoreline protection and cleanup 

equipment to respond to a spill in the Gulf of Mexico. 

• Oil Mop LLC

• U.S. Environmental Services

• ES&H Consulting

• American Pollution Control

Oil Spill Cooperatives (OSC). OSCs have equipment pre-staged in the Gulf of Mexico including Lake Charles, 

Intracoastal City, Houma, Grand Isle, Fort Jackson and Venice, Louisiana; Galveston, Texas; and Pascagoula, 

Mississippi. OSCs provide resources to respond to offshore incidents including areas identified in this permit.

• Clean Gulf Associates (CGA) – This major cooperative strictly dedicated to Gulf of Mexico oil and gas 

developers and producers. 

• Marine Spill Response Corporation (MSRC) – This national cooperative has extensive dedicated offshore 

resource located in the Gulf of Mexico

• Clean Caribbean and Associates (CCA) – This is a major cooperative located in the Caribbean. 

• Oil Spill Response, Ltd. (OSR) – This one of the largest international cooperatives operating out of the UK, 

Bahrain and Singapore. 

Well Control Emergency Response Companies

• Wild Well Control Inc.

• Boots & Coots 

• IWC Services, Inc.
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 8

Oil Spill Management and Response Consultants 

• O’Brien’s Oil Pollution Services

• The Response Group (TRG) 

Chemical Dispersant Companies (capable of delivering air and vessel dispersants) 

• Airborne Support, Inc 

• MSRC

• CCA

• OSRL

Chevron has numerous staging areas in the Gulf of Mexico including Chevron’s three shorebases located in 

Intracoastal City, Leeville and Venice, Louisiana. Other staging areas will be pursued as warranted by any specific 

response. Chevron primary equipment locations are located Leeville, Houma, Fourchon, Venice, Lake Charles, L 

and Pascagoula, MS. 

Chevron uses a layered approach to respond to a worst case discharge from its Tahiti facility by conducting 

simultaneous response operations at the well site, in the offshore environment and in nearshore and shoreline 

areas. Plans will be implemented, resources deployed and response operations established within these 

environmental areas to accomplish the following objectives:

• Ensure the safety of responders and the general public

• Intervene at the well site to stop the flow of oil 

• Minimize the spread of oil at the surface 

• Minimize encroachment to the coastline environment

• Protect coastal and natural resources 

Upon notification of a worst case discharge oil spill at the location listed in this permit Chevron will mobilize 

resources listed in the attached enclosures. This information comes directly from the Chevron Gulf of Mexico 

Business Unit Regional Oil Spill Response Plan and relates to a worst case discharge volume of 186,452 barrels per 

day that could occur at a Chevron facility located in Green Canyon 641. These same assets would be mobilized to 

all sites contained in this permit. The on water recovery vessels, barges and systems listed below have an effective 

daily recovery capacity of 816,651 barrels per day. 

Chevron will also take the following general actions to mobilize and coordinate response operations:

• Set up and staff its command center in Covington, LA

• Set up a source control group in Houston, TX, or Covington, LA

• Mobilize well site resources to cap, contain and disperse oil at the well head

• Mobilize assets to drill relief wells

• Mobilize assets to contain and collect surface oil at the well site and in the offshore environment

• Mobilize assets to disperse and burn surface oil at the well site and in the offshore environment

• Establish a deepwater staging area from a LA port or location

• Deploy assets to track the movement of oil on the surface

Follow up actions will include the following:

• Locate, monitor, track and project the movement of the oil spill
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 9

• Mobilize nearshore skimming and booming vessels, barges and systems to shorebase locations for rapid 

deployment in the nearshore environment

• Mobilize oil spill removal organization (OSRO) resources and assets to staging areas for rapid deployment 

of shoreline protection resources

• Mobilize wildlife protection and rehabilitation resources to staging areas for rapid deployment of resources

• Determine Incident Command Post (ICP) locations based on intervention operations and results and 

surface oil spill trajectories

• Determine ICP Operations Branch locations based on intervention operations and results and surface oil 

spill trajectories

• Determine additional staging areas based on the spill trajectory

Offshore On-Water Collection and Storage

Keathley Canyon 785 WCD is 51,650 barrels per day. The following vessels and barges will be deployed to collect 

and store on-water oil. This information is taken directly from Appendix H to the Chevron OSRP (pages Appendix H74 through 82). 

Vessel or Barge EDRC Storage Capacity

MSRC LA Responder 10,567 4,000

MSRC Gulf Coast Responder 10,567 4,000

MSRC TX Responder 10,567 4,000

MSRC MS Responder 10,567 4,000

MSRC Southern Responder 10,567 4,000

MSRC FL Responder 10,567 4,000

MSRC VA Responder 10,567 4,000

CGA HOSS Barge 43,000 4,000

MSRC Offshore Barge 452 45,000

MSRC Offshore Barge 570 56,900

MSRC Offshore Barge 402 40,300

MSRC Offshore Barge 403 40,300

MSRC Offshore Barge 360 36,000

MSRC Offshore Barge 350 35,000

MSRC Offshore Barge 680 68,000

MSRC Offshore Barge 401 40,000

MSRC Offshore Barge 381 38,000

MSRC Offshore Barge 520 52,000

MSRC Offshore Barge 620 62,000

These assets have more than adequate EDRC and large storage capabilities to collect and store a 51,650 barrel per 

day oil spill. These large skimming and storage assets maximize Chevron’s ability to collect and store oil and 

minimize time needed to offload oil from the skimming vessels to storage. 

Other offshore mechanical skimming assets (Koseq skimming arms, Fast Response Units, deployable skimmers) 

that require a vessel of opportunity will be deployed as secondary assets to collect surface oil. Additionally, Clean 

Gulf Associates has signed an agreement with K-Sea Transportation to access their offshore tank barges to store 
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 10

recovered oil during an offshore spill. The attached agreement details K-Sea storage capabilities. These storage 

barges will be coupled with Koseq skimming systems to effectively collect and store surface oil. 

Shoreline Protection

OSRAM projects that there is a 2% chance that an oil spill from KC 785 could reach Matagorda and Galveston 

Counties and Cameron Parish within 30 days. 

The May 2, 2010 State of Louisiana Deepwater Horizon Incident plan identified 21,798’ of protective boom were 

needed to protect Cameron Parish. Coast Guard ACPs do not provide similar information for Matagorda and 

Galveston Counties. Chevron has developed Shoreline Response Guides that detail tactical strategies to protect 

and clean impacted land areas. Our guides indicate that 5,400’ of boom is needed to protect Matagorda County and 

34,900’ of boom is needed to protect Galveston County. A total of 62,098’ of boom are therefore needed to protect 

these three areas. 

Chevron has contracts with four major Oil Spill Removal Organizations (OSRO) who provide shoreline protection 

and cleanup services: AMPOL, Oil Mop, U.S. Environmental Services and ES&H. These four OSROs have a 

combined 113,450’ of containment boom located in the Gulf of Mexico (see table on page Appendix H – 94 to the 

Chevron OSRP) that can be immediately deployed to Matagorda County, Galveston County and Cameron Parish. 

This boom is sufficient to protect the two counties and one parish.

Additionally, Oil Stop, a wholly-owned subsidiary of AMPOL, manufactures offshore and shoreline protection boom. 

Chevron through the service contract with AMPOL can quickly obtain additional boom that can be deployed within 

the 30 day predicted landfall of oil to these areas. 
Chevron USA Inc. Exploration Plan R-5096 

Keathley Canyon Block 736 11

SECTION L SUPPORT VESSELS AND AIRCRAFT INFORMATION (30 CFR 250.224)

(d) SOLID AND LIQUID WASTES TRANSPORTATION

Information is provided regarding the transport of solid and liquid wastes from the site of the proposed activities to 

other offshore structures or to temporary or permanent onshore facilities for storage or disposal.

Type of Waste

Approximate 

Composition

Total

Amount*

Name/Location Rate Transport Method

Spent synthetic-based 

drilling fluids

85,000 bbls M-I Swaco, Port 

Fourchon Facility

17,000 bbls/well Internal Mud tanks 

on motor vessel

Cuttings containing 

synthetic-based mud

5,000 bbls Newpark, Port 

Fourchon, LA

1,000 bbls/well Cuttings box on 

workboat/crewboat

Wash water 3,750 bbls Newpark,

Port Fourchon, LA

2-5 bbls/day Transport by boat in 

tanks to shorebase.

Chemical product 

wastes

2,250 bbls Mars Facility, 

Morgan City, LA

3 bbls/day Drums on crew boat.

Trash and Debris 1,350,000 lb Morgan City Landfill 1800 lb/day Storage bins on 

crew boat.

*Total Amount assumes 5 wells at 150 days/well.

SECTION M ONSHORE SUPPORT FACILITIES INFORMATION (30 CFR 250.225)

(d) WASTE DISPOSAL

The table below provides information on the onshore facilities that will be used to store and dispose of any solid and 

liquid wastes generated by the proposed activities.

Name/Location of 

Facility

Type of Waste Amount Rate Disposal Method

Newpark 

Environmental 

Services,

Port Fourchon, LA

Spent syntheticbased drilling fluids 

and cuttings

~1,500 bbls/well 5-10 bbl/day Transport by boat in 

cutting bins to 

shorebase; truck to 

disposal facility

Newpark 

Environmental 

Services,

Port Fourchon, LA

Wash Water ~750 bbls/well 2-5 bbl/day Transport by boat in 

tanks to shorebase; 

truck to disposal 

facility

Solid Waste 

Disposal Inc, 

Riverbirch Landfill, 

Avondale, LA

Trash and debris ~270,000 lb/well 1800 lb/day Transport by boat in 

storage bins to 

shorebase

Mars Facility, 

Morgan City, LA

Chemical product 

wastes

~450 bbls/well 3 bbls/day Transport in drums 

on crew boat to 

shorebase; truck to 

disposal facility
please specify if the amount reported is a total or per well amount

Projected generated waste Projected ocean discharges 

Type of Waste Composition Projected Amount Discharge rate Discharge Method 

Will drilling occur ? If yes, you should list muds and cuttings

EXAMPLE: Cuttings wetted with synthetic based fluid Cuttings generated while using 

synthetic based drilling fluid.

X bbl/well X bbl/day/well discharge overboard 

Water-based drilling fluid Water-based drilling muds 286,015 bbls 57,203 bbls/well Discharge at mudline prior to riser installation. Cuttings wetted with water-based fluid Cuttings coated with water-based 

drilling muds

7,465 bbls 1,493 bbls/well Discharge at mudline prior to riser installation. 

Cuttings wetted with synthetic-based fluid Cuttings coated with Synthetic drilling 

muds, including drilled out cement

36,690 bbls 7,338 bbls/well Treated cuttings will be discharged overboard 

during drilling of SBM interval. Cuttings will pathrough curttings dryer substantially reducing ROC percentage from worst case quoted beloOr stored in cutting boxes and transported to shore.

Will humans be there? If yes, expect conventional waste

EXAMPLE: Sanitary waste water Sanitary waste from living quarters X bbl/well X bbl/hr/well chlorinate and discharge overboard Domestic waste Gray water from living quarters,control 282,750 bbls 56,550 bbls/well Food grinder. Starboard Caisson. 

Sanitary waste Sanitary waste from living 

quarters,control rooms, and common 

140,250 bbls 28,050 bbls/well USCG-approved MSD with chlorination. 

Starboard Caisson.

Is there a deck? If yes, there will be Deck Drainage

Deck Drainage Deck drainage from drilling floor, 852,750 bbls 170,550 bbls/well Hull discharge overboard. 

Will you conduct well treatment, completion, or workover? 

Well treatment fluids N/A N/A N/A N/A 

Well completion fluids Calcium/Zinc Bromide 40,000 bbls 0 N/A Workover fluids N/A N/A N/A N/A 

Miscellaneous discharges. If yes, only fill in those associated with your activity. 

Desalinization unit discharge Rejected water from watermaker unit 1,370,250 bbls 274,050 bbls/well Hull discharge overboard. 

Blowout prevent fluid Stackmagic 200/0/5% glycol based on 

2% mixture with potable water

1,250 bbls 250 bls/well discharge at sea floor, or w/ deck drainage 

when tested on the surface

Ballast water Uncontaminated seawater used to 

maintain proper draft

3,853,600 bbls 770,720 bbls/well Hull discharge overboard. 

Bilge water N/A N/A N/A N/A Excess cement 4,000 bbls 800 bbls/well Discharged at seafloor during riserless drilling Fire water Seawater with no addition of chemicals 168,117,750 bbls 224,157 bbls/day Hull discharge overboard. 

Cooling water Seawater with no addition of chemicals 375,000,000 bbls 75,000,000 bbls/well Hull discharge overboard. Hydrate control fluid Glycol 125 gals 25 gals/well Discharge at seafloor Sub sea wellhead preservation fluid Sub sea wellhead preservation fluid 10 bbls 2 bbls/well Discharge at seafloor Leak tracer dye Lignite 105,000 lbs 21,000 lbs/well Discharge at seafloor 

Riser tensioner fluids Riser tensioner fluids 0 0 

Will you produce hydrocarbons? If yes fill in for produced water.

Produced water N/A N/A N/A N/A 

TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM
Projected generated waste Projected ocean discharges 

Type of Waste Composition Projected Amount Discharge rate Discharge Method 

Will you be covered by an individual or general NPDES permit ? GeneralNOTE: If you will not have a type of waste, enter NA in the row. 
please specify whether the amount reported is a total or per wel

Projected 

generated waste

Solid and Liquid Wastes 

transportation 

Type of Waste Composition Transport Method Name/Location of Facility Amount 

Will drilling occur ? If yes, fill in the muds and cuttings.

EXAMPLE: Synthetic-based drilling fluid or mud internal olefin, ester

Below deck storage tanks on offshore support vessels

Newport Environmental Services Inc., Ingleside, TX X bbl/well 

Oil-based drilling fluid or mud N/A N/A N/A N/A Synthetic-based drilling fluid or mud Synthetic-based drilling muds Internal mud tanks on motor vessel Newpark, Port Fourchon, LA 17,000 bbCuttings wetted with Water-based fluid N/A N/A N/A N/A Cuttings wetted with Synthetic-based fluid Cuttings coated with 

Synthetic drilling muds, including drilled out cement

Cuttings box on workboat/crewboat Newpark, Port Fourchon, LA 1.000 bb

Cuttings wetted with oil-based fluids N/A N/A N/A N/A 

Will you produce hydrocarbons? If yes fill in for produced sand.

Produced sand N/A N/A N/A N/A EXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage bin ARC, New Iberia, LA X lb/well 

Trash and debris Plastic, paper, aluminum, 

glass, and other refuse

Storage bins on crew boat SWIDI, Leeville, LA 1,800 lb

Wash water Transport by boat in tanks to shorebase Newpark, Port Fourchon, LA 2-5 bblsChemical product wastes Used oil, hazardous waste Drums on crew boat Chemical Waste Management, 

Sulfur, La; WMI Woodside, Walker, LA; Aaron Oil, Saraland, AL

3 bbls/

Completion Fluids Calcium/Zinc Bromide Excess fluid transported by boat in 

tanks to shorebase

M-I Swaco, Fourchon, LA 2,000 bbls

NOTE: If you will not have a type of waste, enter NA in the row. 

Waste Dis

TABLE 2. WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHORE 

Will you have additional wastes that are not permitted for discharge? If yes, fill in the appropriate rows. 
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92° 22' 00" W

26° 14' 00" N

-6820

-6800

-6820

-6720

-6740

-6760

-6800

-6780

-6760

-6740

-6880

-6860

-6840

-6800

-6780

-6740

-6760

-6760

-6720 -6740

-6740

-6820

-6800

-6760

-6780

-6760

-6780

-6740

-6720-6700

-6680

-6760

-6780

-6840

X = 1,845,000'

Y = 9,517,500'

Y = 9,519,998'

Y = 9,519,838'

Y = 9,522,500'

X = 1,842,500'

X = 1,847,500'

INLINE 12910

CROSSLINE 5724

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-A-1

CONTOUR INTERVAL: 20 FEET FILE NAME: 91600_WELLS2.DWG

BATHYMETRY MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

WATER DEPTH CONTOUR IN FEET. -6800

 RID ORTH

GEMS

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

- - 6680

- - 6700

- - 6720

- - 6740

- - 6760

- - 6780

- - 6800

- - 6820

- - 6840

- - 6860

- - 6880

- - 6900

WATER DEPTH IN FEET
FAULTS

92° 22' 00" W

26° 14' 00" N

GRABEN

FAULTS

FAULTS

X = 1,845,000'

Y = 9,517,500'

Y = 9,519,998'

Y = 9,519,838'

Y = 9,522,500'

X = 1,842,500'

X = 1,847,500'

INLINE 12910

CROSSLINE 5724

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-A-2

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

SHALLOW

DEEP

RELATIVE WATER DEPTH

 RID ORTH

GEMS

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.
FAULTS

92° 22' 00" W

26° 14' 00" N

GRABEN

FAULTS

FAULTS

X = 1,845,000'

Y = 9,517,500'

Y = 9,519,998'

Y = 9,519,838'

Y = 9,522,500'

X = 1,842,500'

X = 1,847,500'

INLINE 12910

CROSSLINE 5724

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-A-3

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR AMPLITUDE RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

PROPOSED WELL LOCATION.

HIGH

LOW

RELATIVE AMPLITUDE

 RID ORTH

GEMS

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.
92° 22' 00" W

26° 14' 00" N

X = 1,845,000'

Y = 9,517,500'

Y = 9,519,998'

Y = 9,519,838'

Y = 9,522,500'

X = 1,842,500'

X = 1,847,500'

INLINE 12910

CROSSLINE 5724

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-A-4

FILE NAME: 91600_WELLS2.DWG

GEOLOGIC FEATURES MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

AMPLITUDE ANOMALIES

AMPLITUDE ANOMALIES BETWEEN

HORIZON 10 AND HORIZON 20.

 RID ORTH

GEMS

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

AMPLITUDE ANOMALIES BETWEEN

SEAFLOOR AND TOP OF SALT.

NOTE: AMPLITUDE ANOMALIES BETWEEN THE

 SEAFLOOR AND TOP OF SALT WERE

 MAPPED TO INCLUDE THOSE AMPLITUDE

 EVENTS THAT DO NOT OCCUR BETWEEN

AREA CONTAINING NUMEROUS MAPPED HORIZONS.

SEAFLOOR FAULTS.

SEAFLOOR FAULTS. ONLY

REPRESENTATIVE FAULTS MAPPED

TO IDENTIFY FAULT TREND. TICKS

INDICATE DOWNTHROWN SIDE

OF FAULT.
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-6680

-6700

-6720

-6740

-6720

-6740

-6760

-6780

-6800-6820-6840-6860 -6880

-6880

-6840

-6820

-6800

-6700

-6580

-6600

-6600

-6580

-6560

-6820

-6840

-6780

INLINE 13030

CROSSLINE 5612

26° 14' 00" N

92° 24' 00" W

Chevron U.S.A. Inc.

OCS-G-27756

KC 780

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,837,440'

X = 1,837,500'

X = 1,840,000'

X = 1,842,500'

- - 6560

- - 6580

- - 6600

- - 6620

- - 6640

- - 6660

- - 6680

- - 6700

- - 6720

- - 6740

- - 6760

- - 6780

- - 6800

- - 6820

- - 6840

- - 6860

- - 6880

- - 6900

PROJECT NO.: 0109-1600

MAP NO. KC736-B-1

CONTOUR INTERVAL: 20 FEET FILE NAME: 91600_WELLS2.DWG

BATHYMETRY MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

WATER DEPTH CONTOUR IN FEET. -6800

 RID ORTH

GEMS

WATER DEPTH IN FEET

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.
GRABEN

FAULTS

FAULTS

INLINE 13030

CROSSLINE 5612

26° 14' 00" N

92° 24' 00" W

Chevron U.S.A. Inc.

OCS-G-27756

KC 780

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,837,440'

X = 1,837,500'

X = 1,840,000'

X = 1,842,500'

GRABEN

FAULTS

FAULTS

PROJECT NO.: 0109-1600

MAP NO. KC736-B-2

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

SHALLOW

DEEP

RELATIVE WATER DEPTH

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.
GRABEN

FAULTS

FAULTS

INLINE 13030

CROSSLINE 5612

26° 14' 00" N

92° 24' 00" W

Chevron U.S.A. Inc.

OCS-G-27756

KC 780

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,837,440'

X = 1,837,500'

X = 1,840,000'

X = 1,842,500'

GRABEN

FAULTS

FAULTS

PROJECT NO.: 0109-1600

MAP NO. KC736-B-3

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR AMPLITUDE RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

HIGH

LOW

RELATIVE AMPLITUDE

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.
INLINE 13030

CROSSLINE 5612

26° 14' 00" N

92° 24' 00" W

Chevron U.S.A. Inc.

OCS-G-27756

KC 780

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,837,440'

X = 1,837,500'

X = 1,840,000'

X = 1,842,500'

PROJECT NO.: 0109-1600

MAP NO. KC736-B-4

FILE NAME: 91600_WELLS2.DWG

GEOLOGIC FEATURES MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

AMPLITUDE ANOMALIES

 RID ORTH

GEMS

AMPLITUDE ANOMALIES BETWEEN

SEAFLOOR AND TOP OF SALT.

AMPLITUDE ANOMALIES BETWEEN

HORIZON 10 AND HORIZON 20.

NOTE: AMPLITUDE ANOMALIES BETWEEN THE

 SEAFLOOR AND TOP OF SALT WERE

 MAPPED TO INCLUDE THOSE AMPLITUDE

 EVENTS THAT DO NOT OCCUR BETWEEN

 MAPPED HORIZONS. AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

SEAFLOOR FAULTS. ONLY

REPRESENTATIVE FAULTS MAPPED

TO IDENTIFY FAULT TREND. TICKS

INDICATE DOWNTHROWN SIDE

OF FAULT.
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-6540

-6520

-6580

-6560

-6600

-6700

-6800

-6820

-6800

-6800

-6840

-6820

-6860

-6880

-6880

-6840

-6840

-6860

-6680

-6660

-6620

-6640

-6720

-6740

-6760

-6780

-6720

-6780

-6760

-6740

-6540

INLINE 13285

CROSSLINE 5697

Y = 9,527,500'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Y = 9,522,500'

Y = 9,525,000'

- - 6900

- - 6500 PROJECT NO.: 0109-1600

MAP NO. KC736-C-1

CONTOUR INTERVAL: 20 FEET FILE NAME: 91600_WELLS2.DWG

BATHYMETRY MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

WATER DEPTH CONTOUR IN FEET. -6800

 RID ORTH

GEMS

WATER DEPTH IN FEET

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

- - 6520

- - 6540

- - 6560

- - 6580

- - 6600

- - 6620

- - 6640

- - 6660

- - 6680

- - 6700

- - 6720

- - 6740

- - 6760

- - 6780

- - 6800

- - 6820

- - 6840

- - 6860

- - 6880
GRABEN

FAULTS INLINE 13285

CROSSLINE 5697

Y = 9,527,500'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Y = 9,522,500'

Y = 9,525,000'

PROJECT NO.: 0109-1600

MAP NO. KC736-C-2

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

SHALLOW

DEEP

RELATIVE WATER DEPTH

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.
GRABEN

FAULTS INLINE 13285

CROSSLINE 5697

Y = 9,527,500'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Y = 9,522,500'

Y = 9,525,000'

PROJECT NO.: 0109-1600

MAP NO. KC736-C-3

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR AMPLITUDE RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

HIGH

LOW

RELATIVE AMPLITUDE

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.
INLINE 13285

CROSSLINE 5697

Y = 9,527,500'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Y = 9,522,500'

Y = 9,525,000'

PROJECT NO.: 0109-1600

MAP NO. KC736-C-4

FILE NAME: 91600_WELLS2.DWG

GEOLOGIC FEATURES MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

AMPLITUDE ANOMALIES

AMPLITUDE ANOMALIES BETWEEN

HORIZON 10 AND HORIZON 20.

 RID ORTH

GEMS

AMPLITUDE ANOMALIES BETWEEN

SEAFLOOR AND TOP OF SALT.

NOTE: AMPLITUDE ANOMALIES BETWEEN THE

 SEAFLOOR AND TOP OF SALT WERE

 MAPPED TO INCLUDE THOSE AMPLITUDE

 EVENTS THAT DO NOT OCCUR BETWEEN

 MAPPED HORIZONS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

SEAFLOOR FAULTS. ONLY

REPRESENTATIVE FAULTS MAPPED

TO IDENTIFY FAULT TREND. TICKS

INDICATE DOWNTHROWN SIDE

OF FAULT.
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-6620

-6640 -6660

-6680

-6700

-6720

-6740

-6800

-6820

-6760

-6780

-6800

-6840

-6880

-6800

-6780

-6800

-6820

-6840

-6860

-6860

-6840 -6800

-6700

-6900

-6880

-6820

-6760

-6760

-6760

INLINE 13075

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

- - 6620

- - 6900

PROJECT NO.: 0109-1600

MAP NO. KC736-D-1

CONTOUR INTERVAL: 20 FEET FILE NAME: 91600_WELLS2.DWG

BATHYMETRY MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

WATER DEPTH CONTOUR IN FEET. -6800

WATER DEPTH IN FEET

 RID ORTH

GEMS

- - 6640

- - 6660

- - 6680

- - 6700

- - 6720

- - 6740

- - 6760

- - 6780

- - 6800

- - 6820

- - 6840

- - 6860

- - 6880

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.
GRABEN

FAULTS

FAULTS

INLINE 13075

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-D-2

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

SHALLOW

DEEP

RELATIVE WATER DEPTH

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.
GRABEN

FAULTS

FAULTS

INLINE 13075

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-D-3

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR AMPLITUDE RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

HIGH

LOW

RELATIVE AMPLITUDE

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.
INLINE 13075

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-D-4

FILE NAME: 91600_WELLS2.DWG

GEOLOGIC FEATURES MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

AMPLITUDE ANOMALIES

AMPLITUDE ANOMALIES BETWEEN

SEAFLOOR AND TOP OF SALT.

AMPLITUDE ANOMALIES BETWEEN

HORIZON 10 AND HORIZON 20.

 RID ORTH

GEMS

NOTE: AMPLITUDE ANOMALIES BETWEEN THE

 SEAFLOOR AND TOP OF SALT WERE

 MAPPED TO INCLUDE THOSE AMPLITUDE

 EVENTS THAT DO NOT OCCUR BETWEEN

 MAPPED HORIZONS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

SEAFLOOR FAULTS. ONLY

REPRESENTATIVE FAULTS MAPPED

TO IDENTIFY FAULT TREND. TICKS

INDICATE DOWNTHROWN SIDE

OF FAULT.
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FRQWLQHQWDO VKHOI *XOI RI 0H[LFR 2&6 UHJLRQ ,QIRUPDWLRQ 5HTXLUHPHQWV IRU ([SORUDWLRQ 3ODQV DQG 'HYHORSPHQW

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0LQHUDOV0DQDJHPHQW6HUYLFHF1RWLFHWROHVVHHVDQGRSHUDWRUVRIIHGHUDORLOJDVDQGVXOSKXUOHDVHVLQWKHRXWHU

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0LQHUDOV0DQDJHPHQW6HUYLFHG1RWLFHWROHVVHHVDQGRSHUDWRUV17/RIIHGHUDORLODQGJDVOHDVHVDQGSLSHOLQH

ULJKWRIZD\52:KROGHUVRQWKHRXWHUFRQWLQHQWDOVKHOI2&6*XOIRI0H[LFR2&6UHJLRQ*2055HYLVLRQVWR

WKHOLVW RI2&6OHDVH EORFNV UHTXLULQJ DUFKDHRORJLFDO UHVRXUFHVXUYH\V DQG UHSRUWV8 6'HSDUWPHQW RIWKH ,QWHULRU

0LQHUDOV0DQDJHPHQW6HUYLFH*XOIRI0H[LFR17/*

0LQHUDOV 0DQDJHPHQW 6HUYLFH  1RWLFH WR OHVVHHV DQG RSHUDWRUV RI IHGHUDO RLO DQG JDV OHDVHV LQ WKH RXWHU

FRQWLQHQWDO VKHOI *XOI RI 0H[LFR 2&6 UHJLRQ 'HHSZDWHU EHQWKLF FRPPXQLWLHV 8 6 'HSDUWPHQW RI WKH ,QWHULRU

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-6620

-6640

-6660

-6680

-6700

-6720

-6820

-6800

-6780

-6760

-6740

-6840

-6820

-6880

-6860

-6860

-6800 -6820-6840

-6800

-6840

-6820

-6780-6760

-6600

-6580

-6560

-6880

-6840

-6800

-6800

-6860

-6900

INLINE 13150

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

- - 6540

- - 6900

PROJECT NO.: 0109-1600

MAP NO. KC736-E-1

CONTOUR INTERVAL: 20 FEET FILE NAME: 91600_WELLS2.DWG

BATHYMETRY MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

WATER DEPTH CONTOUR IN FEET. -6800

 RID ORTH

GEMS

WATER DEPTH IN FEET

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

- - 6560

- - 6580

- - 6600

- - 6620

- - 6640

- - 6660

- - 6680

- - 6700

- - 6720

- - 6740

- - 6760

- - 6780

- - 6800

- - 6820

- - 6840

- - 6860

- - 6880

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.
GRABEN

FAULTS

FAULTS

INLINE 13150

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-E-2

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

SHALLOW

DEEP

RELATIVE WATER DEPTH

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.
GRABEN

FAULTS

FAULTS

INLINE 13150

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-E-3

FILE NAME: 91600_WELLS2.DWG

SEAFLOOR AMPLITUDE RENDERING

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

HIGH

LOW

RELATIVE AMPLITUDE

AZIMUTH - 60°

ELEVATION - 50°

V.E. - 5.4x

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.
INLINE 13150

CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840'

Y = 9,522,500'

Y = 9,525,000' X = 1,840,000'

X = 1,842,500'

X = 1,845,000'

Chevron U.S.A. Inc.

OCS-G-22367

KC 736

PROJECT NO.: 0109-1600

MAP NO. KC736-E-4

FILE NAME: 91600_WELLS2.DWG

GEOLOGIC FEATURES MAP

KEATHLEY CANYON AREA

BLOCK 736

GULF OF MEXICO

0 500 1000 1500 2000

SCALE 1 : 12,000 or 1" = 1,000'

CIRCLE REPRESENTS

2000 FT RADIUS AROUND

PROPOSED WELLSITE.

PROPOSED WELL LOCATION.

 RID ORTH

GEMS

AMPLITUDE ANOMALIES

AMPLITUDE ANOMALIES BETWEEN

SEAFLOOR AND TOP OF SALT.

AMPLITUDE ANOMALIES BETWEEN

HORIZON 10 AND HORIZON 20.

NOTE: AMPLITUDE ANOMALIES BETWEEN THE

 SEAFLOOR AND TOP OF SALT WERE

 MAPPED TO INCLUDE THOSE AMPLITUDE

 EVENTS THAT DO NOT OCCUR BETWEEN

 MAPPED HORIZONS.

NOTE: ENTIRE MAP AREA SHOWN LIES

 ALONG THE HIGHLY FAULTED

 SHALLOW SALT RIDGE.

AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS.

SEAFLOOR FAULTS. ONLY

REPRESENTATIVE FAULTS MAPPED

TO IDENTIFY FAULT TREND. TICKS

INDICATE DOWNTHROWN SIDE

OF FAULT.
KC 736 EP Amended PublicInfo 6_9_11.docx PUBLIC INFORMATION

CHEVRON U.S.A. INC.

EXPLORATION PLAN 

R-5096

KEATHLEY CANYON BLOCK 736

OCS-G 22367

OFFSHORE LOUISIANA

“MOCCASIN” PROSPECT

SECTION A PLAN CONTENTS 

SECTION G AIR EMISSIONS INFORMATION

Amended: 06/09/2011
Chevron USA Inc. Exploration Plan

Keathley Canyon Block 736 1 PUBLIC INFORMATION

SECTION A PLAN CONTENTS (30 CFR 250.211 and 250.241)

(a) PLAN INFORMATION FORM

Included as attachment A-1 at the end of this section is the public information copy of Form MMS-137 “OCS Plan 

Information Form”. 

Well A (OCS-G 22367 001) was spud on March 12, 2010 and suspended on June 9, 2010. A Revised Permit to Drill 

(RPD) was submitted on November 5, 2010 and approved on March 24, 2011. Drilling operations for the OCS-G 

22367 001 well resumed on March 26, 2011.

Proposed Schedule

Proposed Activity Estimated 

Start Date

Estimated 

End Date

Estimated 

No. of Days

Drill, Complete and Abandon Exploratory Well A 03/26/2011* 07/15/2011 112

Drill, Complete and Abandon Exploratory Well B 01/31/2012 06/28/2012 150

Drill, Complete and Abandon Exploratory Well C 06/29/2012 11/25/2012 150

Drill, Complete and Abandon Exploratory Well D 01/01/2013 05/30/2013 150

Drill, Complete and Abandon Exploratory Well E 05/31/2013 10/27/2013 150

* Actual start date
ATTACHMENT A-1 1 of 6 Public Information

U.S. Department of the Interior OMB Control Number: 1010-0049

Minerals Management Service OMB Approval Expires: August 31, 2006

OCS PLAN INFORMATION FORM

General Information

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

Company Name: Chevron U.S.A. Inc. MMS Operator Number: 00078

Address: 1500 Louisiana Street Contact Person: Philip A. Von Dullen III 

 Houston, TX 77002 Phone Number: (832) 854-3644 

E-Mail Address: pvondullen@chevron.com 

Lease(s):

OCS-G 22367

Area:

Keathley Canyon

Block(s)

736

Project Name (If Applicable):

Moccasin

Objective(s) X Oil X Gas Sulphur Salt Onshore Base: Leeville, LA Distance to closest land (Miles): 216

Description of Proposed Activities (Mark all that Apply)

X Exploration Drilling Development Drilling

X Well completion Installation of production platform

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

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

Installation of sub sea 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 sub sea development? Yes X No

Do you propose any activities that may disturb an MMS-designated high-probability archaeological area? Yes X No

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

Tentative Schedule of Proposed Activities

Proposed Activity Start Date End Date No. of Days

Drill, Complete and Abandon Exploratory Well A 03/26/2011* 07/15/2011 112

Drill, Complete and Abandon Exploratory Well B 01/31/2012 06/28/2012 150

Drill, Complete and Abandon Exploratory Well C 06/29/2012 11/25/2012 150

Drill, Complete and Abandon Exploratory Well D 01/01/2013 05/30/2013 150

Drill, Complete and Abandon Exploratory Well E 05/31/2013 10/27/2013 150

*Actual start date

Description of Drilling Rig Description of Production Platform

Jack up X Drill ship Caisson Tension leg platform

Gorilla Jack up Platform rig Well protector Compliant tower

Semi submersible Submersible Fixed platform Guyed tower

DP Semi submersible Other (attach description) Sub sea 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 (August 2003 – Supersedes all previous editions of form MMS-137, which may not be used.)

Page 1 of 2
ATTACHMENT A-1 2 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “A” (OCS-G 22367 001)

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 580 F S L

E / W Departure: 7158 F W L

Lambert X-Y Coordinates

X: 1844598

Y: 9520420

Latitude / Longitude Latitude: N 26° 14’ 10.389”

Longitude: W 92° 22’ 36.857”

Water Depth (Feet) -6793

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=
ATTACHMENT A-1 3 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “B” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 2159 F S L

E / W Departure: 2570 F W L

Lambert X-Y Coordinates X: 1840010

Y: 9521999

Latitude / Longitude Latitude: N 26° 14’ 26.246”

Longitude: W 92° 23’ 27.176”

Water Depth (Feet) -6842

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=
ATTACHMENT A-1 4 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “C” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 5469 F S L

E / W Departure: 6048 F W L

Lambert X-Y Coordinates X: 1843488

Y: 9525309

Latitude / Longitude Latitude: N 26° 14’ 58.878”

Longitude: W 92° 22’ 48.793”

Water Depth (Feet) -6673

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=
ATTACHMENT A-1 5 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “D” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 2720 F S L

E / W Departure: 6142 F W L

Lambert X-Y Coordinates X: 1843582

Y: 9522560

Latitude / Longitude Latitude: N 26° 14’ 31.637”

Longitude: W 92° 22’ 47.905”

Water Depth (Feet) -6720

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=
ATTACHMENT A-1 6 of 6 Public Information

OCS PLAN INFORMATION FORM (Continued)

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

Proposed Well / Structure Location

Well or Structure Name / Number (If renaming well or structure, reference previous name):

KC 736 “E” 

Sub sea Completion

Anchor Radius (if applicable) in feet Yes X No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 22367

Area 

Name KEATHLEY CANYON PROPRIETARY INFORMATION

Block No. 736

Block line Departures

(in feet)

N / S Departure: 3712 F S L

E / W Departure: 6137 F W L

Lambert X-Y Coordinates X: 1843577

Y: 9523552

Latitude / Longitude Latitude: N 26° 14’ 41.466”

Longitude: W 92° 22’ 47.908”

Water Depth (Feet) -6755

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=
Chevron USA Inc. Exploration Plan

Keathley Canyon Block 736 2 PUBLIC INFORMATION

SECTION G AIR EMISSIONS INFORMATION (30 CFR 250.218 and 250.249)

EMISSIONS WORKSHEETS AND SCREENING QUESTIONS

The Complex Total Emissions are the same as the Plan Emissions, and therefore only one set of emissions 

calculations is included. Emissions from the proposed location are estimated using the EPA Publications referenced 

in the tables. 

All calculations are based on worst possible situations. Actual emissions are expected to be considerably below 

those estimated.

Included in this section as attachment G-1 is the Projected Air Quality Emissions Report worksheets (Form MMS138).

SCREENING QUESTIONS FOR EP’S YES NO

Is any calculated Complex Total (CT) Emission amount (in tons) associated with your proposed 

exploration activities more than 90% of the amounts calculated using the following formulas: CT 

= 3400D2/3 for CO, and CT = 33.3D for the other pollutants (where D = distances to shore in 

miles)?

Do your emissions calculations include any emission reduction measures or modified emissions 

factors?

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

Do you expect to encounter H2S at concentrations greater than 20 parts per million (ppm)?

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

well?

Do you propose to burn produced hydrocarbon liquids?

CONTACT INFORMATION

Philip Von Dullen

Chevron U.S.A. Inc.

1500 Louisiana Street

Houston, Texas 77002

(832) 854-3644

pvondullen@chevron.com

MODELING REPORT

A Modeling Report is not required for activities proposed in this plan.

ATTACHMENTS TO SECTION G

• G-1 – Form MMS-138 “Projected Air Quality Emissions Report”
COMPANY Chevron U.S.A. Inc.

AREA Keathley Canyon

BLOCK 736

LEASE OCS-G 22367

PLATFORM Drillship

WELL 5-Wells

COMPANY CONTACT Philip Von Dullen III

TELEPHONE NO. (832) 854-3644

REMARKS Exploration Plan (EP) R-5096 6/9/2011
EMISSIONS FACTORS

Form MMS-138 (March 2000)

Page 2 of 6

KC 736 Moccasin EP Air Emissions6_9_11.xls

2:15 PM 6/9/2011

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

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

Equipment/Emission Factors units OCS-G 22367 SOx NOx VOC CO REF. DATE

NG Turbines gms/hp-hr 5-Wells 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96

NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96

NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96

NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96

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

Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96

Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3-12,14 9/98

NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 14-2, & 14 7/98

NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91

Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98

Tank Vapors lbs/bbl 0.03 E&P Forum 1/93

Fugitives lbs/hr/comp. 0.0005 API Study 12/93

Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991

Gas Venting lbs/scf 0.0034

Sulfur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight
EMISSIONS CALCULATIONS 1ST YEAR

Form MMS-138 (March 2000)

Page 3 of 6 KC 736 Moccasin EP Air Emissions6_9_11.xls

2:15 PM 6/9/2011

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Chevron U.S.A. Inc. Keathley Canyon 736 OCS-G 22367 Drillship 5-Wells Philip Von Dullen III (832) 854-3644 Exploration Plan (EP) R-5096 6/9/2011

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 112 6.89 31.60 236.77 7.10 51.66 9.26 42.47 318.21 9.55 69.43

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 112 6.89 31.60 236.77 7.10 51.66 9.26 42.47 318.21 9.55 69.43

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 112 6.89 31.60 236.77 7.10 51.66 9.26 42.47 318.21 9.55 69.43

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 112 6.89 31.60 236.77 7.10 51.66 9.26 42.47 318.21 9.55 69.43

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 112 4.59 21.07 157.85 4.74 34.44 6.17 28.31 212.15 6.36 46.29

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 112 4.59 21.07 157.85 4.74 34.44 6.17 28.31 212.15 6.36 46.29

Emergency Generator-diesel 3257 157.3131 3775.51 1 112 2.30 10.53 78.91 2.37 17.22 0.13 0.59 4.42 0.13 0.96

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

VESSELS>600hp diesel(crew) 5200 251.16 6027.84 16 16 3.67 16.81 125.99 3.78 27.49 0.47 2.15 16.13 0.48 3.52

VESSELS>600hp diesel(supply) 5200 251.16 6027.84 16 112 3.67 16.81 125.99 3.78 27.49 3.28 15.07 112.89 3.39 24.63

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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

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

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 1875000 24 21 1.11 133.88 113.06 728.44 0.28 33.74 28.49 183.57

2011 YEAR TOTAL 46.36 213.79 1727.54 160.87 1076.15 53.25 244.58 1864.33 83.41 582.97

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 5194.80 5194.80 5194.80 5194.80 98528.53

156.0
EMISSIONS CALCULATIONS 2ND YEAR

Form MMS-138 (March 2000)

Page 4 of 6 KC 736 Moccasin EP Air Emissions6_9_11.xls

2:15 PM 6/9/2011

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Chevron U.S.A. Inc. Keathley Canyon 736 OCS-G 22367 Drillship 5-Wells Philip Von Dullen III (832) 854-3644 Exploration Plan (EP) R-5096 6/9/2011

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 300 4.59 21.07 157.85 4.74 34.44 16.53 75.84 568.27 17.05 123.99

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 300 4.59 21.07 157.85 4.74 34.44 16.53 75.84 568.27 17.05 123.99

Emergency Generator-diesel 3257 157.3131 3775.51 1 300 2.30 10.53 78.91 2.37 17.22 0.34 1.58 11.84 0.36 2.58

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

VESSELS>600hp diesel(crew) 5200 251.16 6027.84 16 43 3.67 16.81 125.99 3.78 27.49 1.26 5.78 43.34 1.30 9.46

VESSELS>600hp diesel(supply) 5200 251.16 6027.84 16 300 3.67 16.81 125.99 3.78 27.49 8.80 40.35 302.38 9.07 65.97

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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

VESSELS>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 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 1875000 24 21 1.11 133.88 113.06 728.44 0.28 33.74 28.49 183.57

2011 YEAR TOTAL 46.36 213.79 1727.54 160.87 1076.15 142.65 654.68 4937.27 175.60 1253.43

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 5194.80 5194.80 5194.80 5194.80 98528.53

156.0
EMISSIONS CALCULATIONS 3RD YEAR

Form MMS-138 (March 2000)

Page 5 of 6 KC 736 Moccasin EP Air Emissions6_9_11.xls

2:15 PM 6/9/2011

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Chevron U.S.A. Inc. Keathley Canyon 736 OCS-G 22367 Drillship 5-Wells Philip Von Dullen III (832) 854-3644 Exploration Plan (EP) R-5096 6/9/2011

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

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 9772 471.9876 11327.70 24 300 6.89 31.60 236.77 7.10 51.66 24.80 113.75 852.36 25.57 185.97

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 300 4.59 21.07 157.85 4.74 34.44 16.53 75.84 568.27 17.05 123.99

PRIME MOVER>600hp diesel 6515 314.6745 7552.19 24 300 4.59 21.07 157.85 4.74 34.44 16.53 75.84 568.27 17.05 123.99

Emergency Generator-diesel 3257 157.3131 3775.51 1 300 2.30 10.53 78.91 2.37 17.22 0.34 1.58 11.84 0.36 2.58

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

VESSELS>600hp diesel(crew) 5200 251.16 6027.84 16 43 3.67 16.81 125.99 3.78 27.49 1.26 5.78 43.34 1.30 9.46

VESSELS>600hp diesel(supply) 5200 251.16 6027.84 16 300 3.67 16.81 125.99 3.78 27.49 8.80 40.35 302.38 9.07 65.97

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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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

VESSELS>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 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

WELL TEST GAS FLARE 1875000 24 21 1.11 133.88 113.06 728.44 0.28 33.74 28.49 183.57

2012 YEAR TOTAL 46.36 213.79 1727.54 160.87 1076.15 142.65 654.68 4937.27 175.60 1253.43

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 5194.80 5194.80 5194.80 5194.80 98528.53

156.0
SUMMARY

Page 1 of 1

COMPANY AREA BLOCK LEASE PLATFORM WELL

Chevron U.S.A. Inc. Keathley Canyon 736 OCS-G 22367 Drillship 5-Wells

Emitted Substance

Year

PM Sox NOx VOC CO

2011 53.25 244.58 1864.33 83.41 582.97

2012 142.65 654.68 4937.27 175.60 1253.43

2013 142.65 654.68 4937.27 175.60 1253.43

2014 0.00 0.00 0.00 0.00 0.00

2015 0.00 0.00 0.00 0.00 0.00

2016 0.00 0.00 0.00 0.00 0.00

2017 0.00 0.00 0.00 0.00 0.00

2018 0.00 0.00 0.00 0.00 0.00

2019 0.00 0.00 0.00 0.00 0.00

2020 0.00 0.00 0.00 0.00 0.00

Allowable 5194.80 5194.80 5194.80 5194.80 98528.53