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: 0 6

/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, U pdated 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, 2011EP N -0 9380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 2 1.0 WORST CASE DISCHARGE SCENARIO

.................................................................................................... 3

1.1 I NTRODUCTION

................................................................................................ ................................................ 3

1.2 F IELD S UMMARY

................................................................................................ .............................................. 3

1.3 W ELL O BJECTIVE

................................................................................................ ............................................. 3

1.4 W ELL P LAN

................................................................................................ ...................................................... 3

1.5 W ELLBORE S ECTIONS USED IN A NALYSIS

........................................................................................................ 3

1.6 A SSUMPTIONS AND D ATA

................................................................................................ ................................ 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 Ch aracteristics of the Fluid

................................................................ 5

1.6.15 Fluid Flow Regimes

.............................................................................................................................. 5

1.6.16 Hydrostatic Pressure

............................................................................................................................ 5

1.7 R EGIONAL O IL S PILL R ESPONSE P LAN C OMPARISON

....................................................................................... 5

2.0 BLOWOUT PREVENTION M EASURES

...................................................................................................... 6

2.1 M INIMUM B ARRIER R EQUIREMENTS

................................................................................................................ 6

2.2 R ISK AND U NCERTAINTY M ANAGEMENT S TANDARD

...................................................................................... 6

2.3 M ANAGEMENT OF C HANGE

.............................................................................................................................. 6

2.4 W ELL C ONTROL

................................................................................................ ............................................... 6

2.5 B LOWOUT C ONTINGENCY P LAN NING

............................................................................................................... 6

2.6 C EMENTING

................................................................................................ ..................................................... 7

3.0 INTERVENTION AND CON TAINMENT

..................................................................................................... 8

3.1 I NTERVENTION

................................................................................................ ........................................... 8

3.2 R ELIEF W ELL P LANS

................................................................................................ ................................ . 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 C ONTAINMENT S CENARIOS

....................................................................................................................... 9

4.0 LIST OF ATTACHMENTS

............................................................................................................................ 11EP N -0 9380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 3 

### 1.0 WORST CASE DISCHARGE SC ENARIO

1.1 Introduction

This report intends to satisfy the requirements for NTL No.2010

- N06 dated June 18 th

, 2010. The docume nt 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 m oratorium. The well was drilled to 24,519 ft measured depth ( MD )

. A 13 5⁄8

- 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 N o. 2010

- N06, only z ones below the currently cased total d epth (TD) will be considered for WCD
Scenario calculations. The 10 5⁄8

- in. open hole section has been se lected for the WCD reporting purposes as the o ther hole sections are safely isolated behind pipe or are not expected to contain significant sand.

Based on system analysis, t he WCD initial flow ra te is calculated to be 51,650 B arrels Oil per Day (B OPD ) and is expected to decline due to transient effects reach ing a

s tabilized rate of 45,317 BOPD after approximately 8 0 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 A ssumptions and Data

PROPRIETARY INFORMATIONEP N -0 9380 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 ( OF P ) 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.

S ystems analysis indicates that an uncontrolled blowout in the 10 5⁄8

- in. open

- hole secti on 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 8 0

da ys at 4 5,317 bopd

.

[Paragraph redacted - Propr ietary 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 Intrusi on

PROPRIETARY INFORMATION

1.6.11 Coning

PROPRIETARY INFORMATION

1.6.12 For mation Sloughing

PROPRIETARY INFORMATION

1.6.13 Bridging

PROPRIETARY INFORMATIONEP N -0 9380 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 R egional 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 1 60 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) 28 o 28 o

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

sce nario 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 -0 9380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 6 

### 2.0 BLOWOUT PREVENTION M EASURES

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

PROPRIE TARY 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 emergen cy response plans

. Chevron has also entered into agreements with industry Subject Matter E xperts (SME s).

At all times from planning through execution, Chevron takes the necessary steps to maintain primary well control to prevent the occurrence of blowout s.

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. Pr essure 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 varian ces.

A djustments can then be made to the mud s ystem to maintain the appropriate

overb alance 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 critic alEP N -0 9380 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.

P reliminary 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

relie f well drilling plans as needed in a timely manner

.

There are contractual arrangements in place with i ndustry SME s , such as Wild Well Control, to assist in the event of a blowout . The SME s also belong to a consortium that will supply the spill response equipment



### .

2.6 Cementing

PROPRIETARY INFORMATIO NEP N -0 9380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 8 

### 3.0 INTERVENTION AND CON TAINMENT

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 5 th or 6 th generation Enterprise or Enhanced Enterprise Class drillship such as the Transocean Discoverer Inspiration (DIN), or
Discoverer Deep Seas (DDS) or Discoverer Cl ear 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 objec tives:

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 typi cal 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 10 5⁄8

- 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 -0 9380 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 INFORMATIO N

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

B OP 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 -0 9380 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).

Equipm ent 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 -0 9380 Additional Information PI January 18, 2011

Public Information Moccasin_KC736_NTLN06_Rev0 Page 11 

### 4.0 LIST OF ATTACHMENTS

PROPRIETARY INFORMATIONKC 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 (H 2 

## S) 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 CONTENT S (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 W ell B 02/19/2011 07/18/2011 150
Drill, Evaluat e and Abandon Exploratory Well C 07/19/2011 12/15/2011 150
Drill, Evaluat e and Abandon Exploratory Well D 12/16/2011 05/13/2012 150
Drill, Evaluat e 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

C hevron 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 w aters 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. Th e “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 pollut ion 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 dr illship 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 ” - Pu blic 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 (H 2 

## S) 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 RE VIEW 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. Emiss ions from the proposed location are estimated using the EPA Publications referenced

in the tables.

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

those estimated.

Included in this section as a ttachment G-1 is the Projected Air Q ualit y Emissions Report worksheets (Form MMS

138 ).

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

= 3400D 2/3 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 H 2 S 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, i n formation 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) 28 o 28 o

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

- cas e 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 web site.

(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 3 0,000 bbls M

- I Swaco

, Port Fourchon Facility 3 00 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 oil

based 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

So lid 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 t o Initial Exploration Plan , PI Copy, N- 9380, following page 19

## ATTACHMENT A -1 1 of 6 

# Public Informat ion 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 Operatio ns 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 7700 2 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 Dis tance 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 s erve 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 previ ously 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 /20 10 0 2/18 /2011 8 0 Drill, Evaluate and Abandon Exploratory We ll B 0 2/19 /2011 0 7/18 /2011 15 0 Drill, Evaluate and Abandon Exploratory Well C 0 7/ 19 /201 1 12/15 /2011 15 0 Drill, Evaluate and Abandon Exploratory Well D 12/16 /2011 05/13 /2012 15 0 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 (Inche s) 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 Informat ion 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: 5 80 F S L

E / W Departure: 715 8 F W L

Lambert X -Y Coordinates X: 184459 8

Y: 95 204 20

Latitude / Longitude Latitude: N 26 **°** 14’ 10.3 8 9”
Longitude: W 92 **°** 22’ 36.8 57 ” Water Depth (Feet)

- 6793 Anchor Locations for Drilling Rig or Construction Barge ( If anchor radius supplied above, not necessary)

Anchor Name or No. Area Bl ock 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 Informat ion 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 Wel ls)

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 Informat ion OCS PLAN INFORMATION FORM (Continued) Include one copy of this page for each proposed well/structure

P roposed 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 / Lo ngitude 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 C oordinate 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 Informat ion 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 Well s)

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 / L ongitude 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 C oordinate 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 Informat ion OCS PLAN INFORMATION FORM (Continued) Include one copy of this page for each proposed well/structure

P roposed 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 / Lo ngitude 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 Co ordinate 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

Octo ber 2010



## ATTACHMENT G -1COMPANY 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 2010EMISSIONS 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 % weightEMISSIONS 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

216.0EMISSIONS 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

216.0EMISSIONS 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

216.0SUMMARY

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 122400.00SPILL RESPONSE DISCUSSION

For the purpose of NEPA and Coastal Zone Management Act analysis, the largest spill volu me 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. Seve ral 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 we st 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 ever y 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 evapor ation/dispersion 7,231

Remaining volume 44,419

Oil addressed by aerial dispersants 7,540

Oil addressed by in-situ burning 2,582Figure 2 outlines equipment, personnel, materials and su pport 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/dis persion 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 gall ons) from two of the DC-3 aircrafts and 4 sorties (8,000 gallons) from the Basler aircraft should di sperse 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 ma y 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 envir onmental 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 as sociated with skimming equipment equals 1,252 barrels. Onshore response may include the deployment of sh oreline boom on beach areas, or protection and sorbent boom on vegetated areas. Stra tegies would be based upon surveillance and real time trajectories that depict areas of potential impa ct given actual sea and weather conditions. The One-Gulf Plan (Area Contingency Plan), the State of Louisiana Initial O il Spill Response Plan for Cameron Parish, and Unified
Command would be consulted to ensu re 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 cl ean-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 th is area, and it describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlan ds, 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 respons e 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 im pacting a land segment have been projected utilizing
Chevron U.S.A. Inc.’s WCD and in formation in the BOEM Oil Spill Risk Analysis Model (OSRAM)

for the Central and Western Gulf of Mexico ava ilable 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

1WCD 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 736Dispersant/SurveillanceDispersantCapacity(gal)StorageCapacityPersonsReq.From Hrs to ProcureHrs toLoadoutTravel tositeTotal HrsBasler 67T2000 NA 2 Houma11 1.33.3DC 31000 NA 2 Houma11 1.73.7DC 31000 NA 2 Houma11 1.73.7Aero CommanderNA NA 2 Houma11 1.33.3Offshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravelto SpillSiteHrs toDeployTotalHrsHOSS Barge43000 4000 3 Tugs 8Houma 4 05 27.3 1 37.3Recovered Oil StorageNo StagingEDRCStorageCapacity(bbl)VOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravelto SpillSiteHrs toDeployTotalHrsCTCo 2404NA 24000 1 Tug 6Amelia4 04 27.50 1 36.50CTCo 2601NA 24000 1 Tug 6Amelia4 04 27.50 1 36.50CTCo 2602NA 24000 1 Tug 6Amelia4 04 27.50 1 36.50CTCo 2603NA 24000 1 Tug 6Amelia4 04 27.50 1 36.50CTCo 2605NA 24000 1 Tug 6Amelia4 04 27.50 1 36.50CTCo 2606NA 24000 1 Tug 6Amelia4 04 27.50 1 36.50CTCo 5001NA 45000 1 Tug 6Amelia4 04 27.50 1 36.50Nearshore Recovered OilStorage No StagingEDRCStorageCapacity(bbl)VOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravelto SpillSiteHrs toDeployTotalHrsCTCo 2604NA225001 Tug 6Amelia4 04 27.50 1 36.50Staging Area: FourchonOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravelto SiteHrs toDeployTotalHrsFRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2.5 20.0 1 26.5FRU (1) + 100 bbl Tank (2) 3770 200 1Utility 6 Galveston1 2 7 20.0 1 31.0FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6Houma 1 21 20.0 1 25.0FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 9.5 20.0 1 33.5FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 4 20.0 1 28.0FRU (2) + 100 bbl Tank (4) 7540 400 1Utility 6 Venice 1 2 4 20.0 1 28.0Koseq Skimming Arms (6) 106974 1500 6Utility 36 Galveston1 12 7.5 20.0 1 41.5Offshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravelto SiteHrs toDeployTotalHrs42” Auto Boom (5000’) NA NA 10 Crew20 Belle Chasse 1 2 2.5 20.0 1 26.542” Auto Boom (5000’) NA NA 10Crew 20 Galveston 1 2 7 20.0 1 31.042” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 21 20.0 1 25.042” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 9.5 20.0 1 33.542” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 4 20.0 1 28.042” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 24 20.0 1 28.0Nearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravel toDeploymentSiteHrs toDeployTotalHrsSWS Egmopol3000 100 NA 3 Galveston 1 2720 12SWS Egmopol3000 100 NA 3Houma(Egmopol)1 2 1 2 0 6SWS Marco3588 34 NA 3 Houma (Marco) 1 2120 6SWS Marco3588 20 NA 3 Lake Charles 1 2420 9Rope Mop77 2 0 3 Belle Chasse 1 2 2.520 7.5RO Storage BargeNA 249 Towed 0 Galveston 1 2 7 2 0 12RO Storage BargeNA 249 Towed 0Houma 1 2120 6RO Storage BargeNA 249 Towed 0 Lake Charles 1 2420 9RO Storage BargeNA 249 Towed 0Venice1 2420 9Beach Boom EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravel toDeploymentSiteHrs toDeployTotalHrsBeach Boom (1000’) NA NA NA4 Belle Chasse 1 2 2.5 1 2 8.5Beach Boom (2000’)NA NA NA 6 Galveston 1 2712 13Beach Boom (2000’)NA NA NA 6Houma 1 2112 7Beach Boom (1000’)NA NA NA4 Ingleside 1 2 9.5 1 2 15.5Beach Boom (2000’)NA NA NA 6 Lake Charles 1 2412 10Beach Boom (2000’)NA NA NA 6 Pascagoula 1 2412 10Wildlife Response EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadOutTravel toStagingTravel toDeploymentSiteHrs toDeployTotalHrsWildlife Support Trailer NA NA NA 2Houma 1 2112 7Bird Scare Guns (24) NA NA NA2 Belle Chasse 1 2 2.5 1 2 8.5Bird Scare Guns (12) NA NA NA 2 Galveston 1 2712 13Bird Scare Guns (24) NA NA NA 2Houma 1 2112 7Bird Scare Guns (12) NA NANA 2 Ingleside 1 2 9.5 1 2 15.5Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2412 10Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2412 10Response AssetTotalOffshore EDRC183,904Offshore Recovered OilCapacity196,200Nearshore / ShallowWater EDRC13,253Nearshore / ShallowWater Recovered OilCapacity23,752Amended 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 U SA Inc. Exploration Plan R- 5096 Keathley Canyon Block 736 1 

## SECTION B GENERAL INFORMATION (30 CFR 250.213)

(d) O IL 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 e ach 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 Na ptha (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:

A PI 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 U SA Inc. Exploration Plan R- 5096 Keathley Canyon Block 736 2 

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

CFR 25 0.216 )

(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 location s 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 location s to the Top of Salt. The report s 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 wellsite s will be required to follow NTL 2008

- G06 with respect to pre

- and post

- spud ROV visual inspection surveys (MMS, 200 8b). 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 se abed. 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 wellsi te.
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 Amplit ude 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 U SA Inc. Exploration Plan R- 5096 Keathley Canyon Block 736 3 

## SECTION F WASTE AND DISCHARGE INFORMATI ON (30 CFR 250.217 )

(a) P ROJECTED 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, o r 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

fro m 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

d ischarged 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

was te

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 1 137 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 U SA 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 Disc harge Overboard

Blowout Preventer

Fluid Stackmagic 200/0/5% glycol based on 2%

mixture with potable water 250 bbl per well Discharged at mudline

### Chevron U SA 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

Wa shed 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 r iser

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**

p

rior 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 8 52,750 bbls 1 70,550 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 U SA Inc. Exploration Plan R- 5096 Keathley Canyon Block 736 6 

## SECTION H OIL SPILLS INFORMATION (30 CFR 25 0.21 9)

(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) 30 o 28 o

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 U SA 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 BOEM RE 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 51,65 0 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 se rvice 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 Con trol

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 resourc es 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)

– Thi s 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 internati onal cooperatives operating out of the UK, Bahrain and Singapore.

Well Control Emergency Response Companies

**•** Wild Well Control Inc.

**•** Boots & Coots

**•** IWC Services, Inc.

### Chevron U SA 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

Intraco astal 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 deploye d 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. T hese 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

**•** Mob ilize 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 U SA 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 pro tection 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 H

74 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 4 5,000 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 Barg e 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 ve ssel 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 U SA 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 immedi ately 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 U SA Inc. Exploration Plan R- 5096 Keathley Canyon Block 736 11 

## SECTION L SUPPORT VESSELS AND AIRCRAFT INFORMA TION (30 CFR 250.224 )

(d) SOLID AND LIQ UID 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 Was te 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, L A 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 INFORMA TION (30 CFR 250.225 )

(d) WASTE DIS POSAL 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

En vironmental
Services,
Port Fourchon, LA Spent synthetic

based 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 Wate r ~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

Mar s Facility, Morgan City, LA Chemical product

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

on crew boat to
shorebase; truck to disposal facilityplease specify if the amount reported is a total or per well amountProjected generated waste Projected ocean dischargesType of Waste Composition Projected Amount Discharge rate Discharge Method Answer yes or noWill drilling occur ? If yes, you should list muds and cuttingsEXAMPLE: Cuttings wetted with synthetic based fluid Cuttings generated while usingsynthetic based drilling fluid.X bbl/well X bbl/day/well discharge overboard NoWater-based drilling fluidWater-based drilling muds 286,015 bbls 57,203 bbls/well Discharge at mudline prior to riser installation. NoCuttings wetted with water-based fluidCuttings coated with water-baseddrilling muds7,465 bbls 1,493 bbls/well Discharge at mudline prior to riser installation. NoCuttings wetted with synthetic-based fluidCuttings coated with Synthetic drillingmuds, including drilled out cement36,690 bbls 7,338 bbls/well Treated cuttings will be discharged overboardduring drilling of SBM interval. Cuttings will passthrough curttings dryer substantially reducingROC percentage from worst case quoted below.Or stored in cutting boxes and transported toshore.NoWill humans be there? If yes, expect conventional wasteEXAMPLE: Sanitary waste water Sanitary waste from living quarters X bbl/well X bbl/hr/well chlorinate and discharge overboard NoDomestic wasteGray water from living quarters,control282,750 bbls 56,550 bbls/well Food grinder. Starboard Caisson. NoSanitary wasteSanitary waste from livingquarters,control rooms, and common140,250 bbls 28,050 bbls/well USCG-approved MSD with chlorination.Starboard Caisson.NoIs there a deck? If yes, there will be Deck DrainageDeck DrainageDeck drainage from drilling floor,852,750 bbls 170,550 bbls/well Hull discharge overboard. NoWill you conduct well treatment, completion, or workover?Well treatment fluidsN/A N/A N/A N/A N/AWell completion fluidsCalcium/Zinc Bromide 40,000 bbls 0 N/A NoWorkover fluidsN/A N/A N/A N/A N/AMiscellaneous discharges. If yes, only fill in those associated with your activity.Desalinization unit dischargeRejected water from watermaker unit 1,370,250 bbls 274,050 bbls/well Hull discharge overboard. NoBlowout prevent fluidStackmagic 200/0/5% glycol based on2% mixture with potable water1,250 bbls 250 bls/welldischarge at sea floor, or w/ deck drainagewhen tested on the surfaceNoBallast waterUncontaminated seawater used tomaintain proper draft3,853,600 bbls 770,720 bbls/well Hull discharge overboard. NoBilge waterN/A N/A N/A N/A N/AExcess cement4,000 bbls 800 bbls/well Discharged at seafloor during riserless drilling NoFire waterSeawater with no addition of chemicals168,117,750 bbls 224,157 bbls/day Hull discharge overboard. NoCooling waterSeawater with no addition of chemicals375,000,000 bbls 75,000,000 bbls/well Hull discharge overboard. NoHydrate control fluidGlycol125 gals 25 gals/well Discharge at seafloor NoSub sea wellhead preservation fluidSub sea wellhead preservation fluid10 bbls 2 bbls/well Discharge at seafloor NoLeak tracer dyeLignite105,000 lbs 21,000 lbs/well Discharge at seafloor NoRiser tensioner fluidsRiser tensioner fluids0 0NoWill you produce hydrocarbons? If yes fill in for produced water.Produced waterN/A N/A N/A N/A N/ATABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TOTHE GOMProjectedDownholeDisposalProjected generated waste Projected ocean dischargesType of Waste Composition Projected Amount Discharge rate Discharge Method Answer yes or noDownholeDisposalWill 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 welProjectedgenerated wasteSolid and Liquid WastestransportationType of WasteComposition Transport Method Name/Location of FacilityAmountDisposal MethodWill drilling occur ? If yes, fill in the muds and cuttings.EXAMPLE: Synthetic-based drilling fluidor mudinternal olefin, esterBelow deck storage tanks on offshoresupport vesselsNewport Environmental ServicesInc., Ingleside, TXX bbl/well RecycledOil-based drilling fluid or mudN/AN/A N/A N/A N/ASynthetic-based drilling fluid or mudSynthetic-based drilling muds Internal mud tanks on motor vessel Newpark, Port Fourchon, LA 17,000 bbls/well Transport by boat in cuttingbins to shorebase; truck todisposal facility. RycycledCuttings wetted with Water-based fluidN/A N/A N/A N/A N/ACuttings wetted with Synthetic-based fluidCuttings coated withSynthetic drilling muds,including drilled out cementCuttings box on workboat/crewboat Newpark, Port Fourchon, LA 1.000 bbs/well Transport by boat in cuttingbins to shorebase; truck todisposal facility. Treated andlandfilled.Cuttings wetted with oil-based fluidsN/A N/A N/A N/A N/AWill you produce hydrocarbons? If yes fill in for produced sand.Produced sandN/A N/A N/A N/A N/AEXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage binARC, New Iberia, LAX lb/well RecycledTrash and debrisPlastic, paper, aluminum,glass, and other refuseStorage bins on crew boat SWIDI, Leeville, LA 1,800 lbs/day Transport by boat in storagebins to shorebase. Landfilled.Wash waterTransport by boat in tanks to shorebase Newpark, Port Fourchon, LA 2-5 bbls/day Transport by boat in cuttingbins to shorebase; truck todisposal facility. Injected.Chemical product wastesUsed oil, hazardous waste Drums on crew boat Chemical Waste Management,Sulfur, La; WMI Woodside,Walker, LA; Aaron Oil, Saraland,AL3 bbls/day Transport in drums on crewboat to shorebase; truck todisposal facility. Recycled orincinerated.Completion FluidsCalcium/Zinc Bromide Excess fluid transported by boat intanks to shorebaseM-I Swaco, Fourchon, LA 2,000 bbls/well RecycledNOTE: If you will not have a type of waste, enter NA in the row.Waste DisposalTABLE 2. WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHOREWill you have additional wastes that are not permitted for discharge? Ifyes, fill in the appropriate rows.6+$'2::22''5,9(

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0LQHUDOV 0DQDJHPHQW 6HUYLFH  1RWLFH WR OHVVHHV DQG RSHUDW RUV 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 0LQHUDOV0DQDJHPHQW6HUYLFH*XOIRI0H[LFR17/*(II HFWLYH'DWH-DQXDU\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

**-6780 -6760**  **-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 12910CROSSLINE 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** 

## FAULTS92° 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 12910CROSSLINE 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.

## FAULTS92° 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 12910CROSSLINE 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" NX = 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 12910CROSSLINE 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

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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. AREA CONTAINING NUMEROUS

SEAFLOOR FAULTS. SEAFLOOR FAULTS. ONLY

REPRESENTATIVE FAULTS MAPPED

TO IDENTIFY FAULT TREND. TICKS

INDICATE DOWNTHROWN SIDE

OF FAULT.6+$'2::22''5,9(

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**-6700**

**-6740 -6720**  **-6720**

**-6740 -6760** 

**-6780 -6800** 

**-6820 -6840** 

**-6860 -6880**  **-6880 -6840**  **-6820 -6800**  **-6700 -6580** 

**-6600 -6600**  **-6580 -6560**  

### -6840 **-6820**



## -6780 INLINE 13030CROSSLINE 5612

26° 14' 00" N92° 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 736X = 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 13030CROSSLINE 5612

26° 14' 00" N92° 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 736X = 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 13030CROSSLINE 5612

26° 14' 00" N92° 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 736X = 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 13030CROSSLINE 5612

26° 14' 00" N92° 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 736X = 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.6+$'2::22''5,9(

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## -6540 **-6520** 

## -6580

**-6560 -6600** 

**-6700 -6800**  

## -6820 **-6800 -6800**  **-6820 -6840** 
**-6860**

**-6880 -6880** 

**-6840** 

### -6840 **-6860 -6680**  **-6660**



## -6620 **-6640**

**-6720**



## -6740 **-6760** 

## -6780
**-6720 -6780** 

**-6760 -6740**  **-6540**

INLINE 13285CROSSLINE 5697

Y = 9,527,500'

**Chevron U.S.A. Inc. OCS-G-22367**  

# KC 736X = 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 13285CROSSLINE 5697

Y = 9,527,500'

**Chevron U.S.A. Inc. OCS-G-22367**  

# KC 736X = 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 13285CROSSLINE 5697

Y = 9,527,500'

**Chevron U.S.A. Inc. OCS-G-22367**  

# KC 736X = 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 13285CROSSLINE 5697

Y = 9,527,500'

**Chevron U.S.A. Inc. OCS-G-22367**  

# KC 736X = 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.6+$'2::22''5,9(

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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 13075CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840' Y = 9,522,500' Y = 9,525,000'X = 1,842,500'X = 1,845,000'X = 1,840,000'

**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 13075CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840' Y = 9,522,500' Y = 9,525,000'X = 1,842,500'X = 1,845,000'X = 1,840,000'

**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 13075CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840' Y = 9,522,500' Y = 9,525,000'X = 1,842,500'X = 1,845,000'X = 1,840,000'

**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 13075CROSSLINE 5699

Y = 9,520,000'

Y = 9,519,840' Y = 9,522,500' Y = 9,525,000'X = 1,842,500'X = 1,845,000'X = 1,840,000'

**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

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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.6+$'2::22''5,9(

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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 13150CROSSLINE 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 13150CROSSLINE 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 13150CROSSLINE 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 13150CROSSLINE 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 CONTENT S (30 CFR 25 0.211 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 Ju ne 9, 2010. A Revised Permit to Drill (RPD) was submitted on November 5, 2010 and approved on March 24, 2011

. D rilling operations for the OCS

- G

22367 001 well resume d 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 * 0 7/15 /201 1 112
Drill, Complete and Abandon Exploratory W ell 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 Operatio ns 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 7700 2 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 Dis tance 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 o f 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 prev iously 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 G uyed 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/B lock) 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 p roposed 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: 5 80 F S L

E / W Departure: 715 8 F W L

Lambert X

- Y Coordinate s X: 184459 8

Y: 95204 20

Latitude / Longitude Latitude: N 26 **°** 14’ 10.3 8 9”
Longitude: W 92 **°** 22’ 36.8 57 ” Water Depth (Feet)

- 6793 Anchor Locations for Drilling Rig or Construction Barge ( If anchor radius supplied above, not necessary)

Ancho r 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 pr oposed 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

- H ole 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 prop osed 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

- Hol e 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: 95 25309

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 B lock 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 pro posed 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

- Ho le 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: 9 522560

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 B lock 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 prop osed 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

- Hol e 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: 95 23552

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 Bl ock 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 25 0.218 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. Emiss ions from the proposed location are estimated using the EPA Publications re ferenced

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 a ttachment G

- 1 is the Projected Air Q ualit y Emissions Report worksheets (Form MMS

138 )

.

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

= 3400D 2/3 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 H 2 S 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 hydrocarbo n 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 6/9/2011EMISSIONS 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 % weightEMISSIONS 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

156.0EMISSIONS 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

156.0EMISSIONS 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

156.0SUMMARY

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