UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030) Plan Coordinator, FO, Plans Section (MS 5231)

Public Information copy of plan
Control # - N-09688
Type - Initial Development Operations Coordinations Document
Lease(s) - OCS-G27982 Block - 834 Ewing Bank Area OCS-G33140 Block - 790 Ewing Bank Area OCS-G33177 Block - 793 Mississippi Canyon Area Operator - Walter Oil & Gas Corporation
Wells A001, A002, A003, A004, A005 and A006

4VCNFSTJCMFBOE1MBUGPSN

Attached is a copy of the subject plan.

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

Chiquita Hill Plan Coordinator

G27982/EW/834 G33140/EW/790 G27982/EW/834 G33177/MC/793 G27982/EW/834 G27982/EW/834 1162 FNL, 5802 FEL 1162 FNL, 5802 FEL 1163 FNL, 5810 FEL 1169 FNL, 5806 FEL 1155 FNL, 5797 FEL 1168 FNL, 5790 FEL 1176 FNL, 5803 FEL G27982/EW/834 G27982/EW/834 G27982/EW/834 G27982/EW/834 G27982/EW/834 G27982/EW/834 G27982/EW/834 CT/A WELL/A001 WELL/A002 WELL/A003 WELL/A004 WELL/A005 WELL/A006 Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk Site Type/Name Description -
Rig Type - Subject: From: June 7, 2013

# PUBLIC INFORMATION January, 2013



# JOINT INITIAL DEVELOPMENT OPERATIONS COORDINATION DOCUMENT

Lease Number: OCS-G 33140, 27982 and 33177 Area/Block: Ewing Bank Blocks 790 and 834 and Mississippi Canyon Block 793
Prospect Name: NA

Offshore: Louisiana

Submitted by: Walter Oil & Gas Corporation 1100 Louisiana, Suite 200 Houston, Texas 77002-5299

Paul Rodriguez (713) 659-1222 prodriguez@walteroil.com

Estimated Start-up: August 15, 2015

Authorized Representative: No. Copies Being Submitted: Judy Davidson Proprietary: 1 copy & 1 CD J. Connor Consulting, Inc. Public Info: 1 copy & 1 CD 16225 Park Ten Place, Suite 700 Houston, Texas 77084 For BOEM: (281) 578-3388 Plan No. Judy.Davidson@jccteam.com Assigned to:

### Walter Oil & Gas Corporation Control Number N-9688 Initial DOCD for Ewing Bank Blocks 790 and 834, Mississippi Canyon Block 793 Record of Changes

Date Section Page Remarks 01/29/13 A Attachment A-1 Amend bottomhole location for Well A004 to UTM Zone 16 02-07-13 A A-1 Added Walter designated operator of Ewing Bank Block 790 on February 5, 2013. 03-05-13 A Attachment A-1 Added OCS Plan Information Form for Platform A and Pages 3 and 4 of WCD Information 03-05-13 C Attachment C-2 Revised Seismic Lines

### WALTER OIL & GAS CORPORATION

JOINT INITIAL DEVELOPMENT OPERATIONS COORDINATON DOCUMENT

LEASE OCS-G 33140, 27982, 33177

EWING BANK BLOCKS 790 AND 834, MISSISSIPPI CANYON BLOCK 793

APPENDIX A Plan Contents

APPENDIX B General Information

APPENDIX C Geological, Geophysical Information

APPENDIX D H 2 

### S Information

APPENDIX E Mineral Resources Conservation Information

APPENDIX F Biological, Physical and Socioeconomic Information

APPENDIX G Wastes and Discharge Information

APPENDIX H Air Emissions Information

APPENDIX I Oil Spills Information

APPENDIX J Environmental Monitoring Information

APPENDIX K Lease Stipulations Information

APPENDIX L Environmental Mitigation Measures Information

APPENDIX M Related Facilities and Operations Information

APPENDIX N Support Vessels and Aircraft Information

APPENDIX O Onshore Support Facilities Information

APPENDIX P Coastal Zone Management Act (CZMA) Information

APPENDIX Q Environmental Impact Analysis

APPENDIX R Administrative Information

### LIST OF ATTACHMENTS

Attachment A-1 OCS Plan Information Form Attachment A-2 Platform Schematic Attachment A-3 Well Location Plan Attachment A-4 Bathymetry Map Attachment A-5 Cost Recovery Fee Attachment B-1 Blowout Scenario and Worst-Case Discharge Calculations Attachment C-1 Structure Map Attachment C-2 Cross Section Attachment C-3 Shallow Hazards Assessment Attachment F-1 Geohazard Map Attachment G-1 Generated Wastes Table Attachment H-1 Air Emissions Calculations With Platform Rig Attachment H-2 Air Emissions Calculations With a Platform Rig and Semi-Submersible Rig Attachment I-1 Spill Response Discussion Attachment N-1 Transported Wastes Attachment N-2 Vicinity Map Attachment P-1 Louisiana CZM Certification

### Walter Oil & Gas Corporation Page A-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 and 834, Mississippi Canyon Block 793 

## APPENDIX A PLAN CONTENTS

(A) PLAN INFORMATION FORM Initial Exploration Plans have not been submitted for Ewing Bank Block 790 or Mississippi Canyon Block 793. Walter Oil & Gas Corporation (Walter) submitted an Initial Exploration Plan (N-9234) which was approved for Ewing Bank Block 834 in September, 2008. The Initial Exploration Plan provided for the drilling and completion of two wells, Locations A and B. Supplemental Exploration Plans were also submitted, Control S-7336 provided for one well, Location C, and Control S-7359 provided for three wells, Locations D, E and F. Control S-7336 was approved in August, 2009, and Control S-7359 was approved in November, 2009. To date, one well, the D location has been drilled in Ewing Bank Block 834. An Application for Permit to Drill was submitted and approved for Location A (Well 001), but it was not drilled.

Under this Joint Initial DOCD, Walter proposes the following from a common surface location in Ewing Bank Block 834.

1. Drill, complete and produce Well A002 in Ewing Bank Block 790, NOTE: the Ewing Bank Block 790 Well A002 may be drilled with a semi-submersible drilling rig or platform rig. Walter was designated operator of Ewing Bank Block 790 on 02-05-2013. 2. Re-enter, complete and produce Well 002, Ewing Bank Block 834, and rename Well A001, 3. Drill, complete and produce Wells A003, A005 and A006 in Ewing Bank Block 834, 4. Drill, complete and produce Well A004 in Mississippi Canyon Block 793.

The wells will be drilled with a platform rig; however, the Ewing Bank Block 790 Well A002 may be drilled with a semi-submersible drilling unit. In addition, Platform A will be installed in Ewing Bank Block 834 and two 10 inch right-of-way pipelines will also be installed. Please see attached OCS Plan Information Form – Form BOEM-137, included as Attachment A-1

. Included as Attachment A-2 is a schematic of proposed Platform A.

(B) LOCATION Included as Attachment A-3 is a location map depicting the proposed surface and bottomhole locations and water depth of each proposed well.

(C) SAFETY AND POLLUTION PREVENTION FEATURES Safety of personnel and protection of the environment during the proposed operations is one of the primary concerns of Walter. Walter mandates regulatory compliance with the contractors and vendors associated with the proposed operations as follows:

The Bureau of Ocean Energy Management (BOEM) mandates that the operations described in this DOCD comply with well control, pollution prevention, construction, welding procedures, and training described in BSEE regulations 30 CFR 250 C, D, E, O and S; and as further clarified by BSEE Notices to Lessees.

### Walter Oil & Gas Corporation Page A-2 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 and 834, Mississippi Canyon Block 793 The Bureau of Safety and Environmental Enforcement (BSEE) conducts periodic announced and unannounced onsite inspections of offshore facilities to confirm operators are complying with lease stipulations, operating regulatory regulations, approved plans, and other conditions; as well as to assure safety and pollution prevention requirements are being met. The National Potential Incident of Noncompliance (PINC) List serves as the baseline for these inspections.

U.S. Coast Guard regulations contained in Title 33 CFR Part 144 mandate the appropriate life rafts, life jackets, ring buoys, etc. be maintained on the facilities at all times.

U.S. Environmental Protection Agency regulations contained in the NPDES General Permit GMG290000 mandate that supervisory and certain designated personnel on-board the facility be familiar with the effluent limitations and guidelines for overboard discharges into the receiving
waters.

A description of the drilling unit is included on the OCS Plan Information Form which complies with all relevant regulations. Rig specifications will be made part of each Application for Permit to Drill.

Safety features on the drilling unit will include well control, pollution prevention, and blowout prevention equipment as described in BSEE regulations 30 CFR 250 C, D, E, O and S; and as further clarified by BSEE Notices to Lessees, and current policy making invoked by the BSEE, Environmental Protection Agency and the U.S. Coast Guard. Appropriate life rafts, life jackets, ring buoys, etc., will be maintained on the facility at all times.

Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on drilling deck areas to collect all contaminants and debris.

(D) STORAGE TANKS AND PRODUCTION VESSELS All facility tanks with a capacity of 25 bbls or more.

Type of Storage Tank Type of Facility Tank Capacity (bbls) Number of Tanks Total Capacity (bbls) Fluid Gravity (API) Fuel Oil (Marine Diesel) Platform 25 1 25 45 0

Production Platform 1300 1 1300 23 0

Fuel Oil (Marine Diesel) SemiSubmersible 18,000 4 70,000 45 0



### (E) POLLUTION PREVENTION MEASURES (FLORIDA ONLY) Pollution prevention measures are not required to be submitted with this plan.

(F) ADDITIONAL MEASURES Walter does not propose additional safety, pollution prevention, or early spill detection measures beyond those required by 30 CFR Part 250.

### Walter Oil & Gas Corporation Page A-3 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 and 834, Mississippi Canyon Block 793 (G) COST RECOVERY FEE Included as Attachment A-5 is a pay.gov receipt in the amount of $23,826.00 to cover operations proposed in this plan.U.S. Department of the Interior OMB Control Number: 1010-0151 Bureau of Ocean Energy Management OMB Approval Expires: 12/31/2011* 

## OCS PLAN INFORMATION FORM
GENERAL INFORMATION Type of OCS Plan: Exploration Plan (EP) x Development Operations Coordination Document (DOCD) Name: Walter Oil & Gas Corporation BOEM Operator Number: 0730 Address: 1100 Louisiana, Suite 200 Houston, Texas 77002 Contact Person: Judy Davidson

Phone Number: (281) 578-3388 Email Address: judy.davidson@jccteam.com

Lease(s):33140, 27982, 33177 Area: EW, MC Block(s): 790, 834, 793 Project Name (If Applicable): NA

Objective(s): Oil Gas Sulphur Salt Onshore Base:Fourchon Distan ce to Closest Land (Miles): 63 

### Description of Proposed Activities (Mark all that apply) Exploration drilling Development drilling Well completion Installation of production platform Well test flaring (for more than 48 hours) Installation of production facilities Installation of caisson or platform as well protection structure Installation of satellite structure
Installation of subsea wellheads and/or manifolds Commence production Installation of lease term pipelines Other (Specify and describe) Have you submitted or do you plan to submit a Conser vation Information Document to accompany this plan? Yes x No Do you propose to use ne w or unusual technology to conduct your activities? Yes x No Do you propose any facility that will serve as a host facility for deepwater subsea development? Yes x No Do you propose any activities that may disturb an BO EM-designated high-probability archaeological area? Yes x No Have all of the surface locations of your proposed activities b een previously reviewed and approved by BOEM? x Yes No 

### Tentative Schedule of Proposed Activities Proposed Activity Start Date End Date No. of Days Install Platform A and production facilities 09-01-2015 10-15-2015 45 Re-enter and complete and place Well A001 (formerly Well No. 2) on production 01-01-2016 01-16-2016 15 Drill, complete and place Well A002 on production 01-17-2016 04-16-2016 90 Drill, complete and place Well A003 on production 04-17-2016 07-16-2016 90 Drill, complete and place Well A004 on production 07-17-2016 10-15-2016 90 Drill, complete and place Well A005 on production 01-01-2017 03-12-2017 70 Drill, complete and place Well A006 on production 03-13-2017 05-12-2017 60 Description of Drilling Rig Description of Production Platform Jackup Drillship Caisson Tension leg platform Gorilla Jackup Platform rig Well protector Compliant tower
Semisubmersible Submersible Fixed platform Guyed tower
DP Semisubmersible Other (Attach Description) Subsea manifold Floating production system Drilling Rig Name (If Known): Spar Other (Attach description) Description of Lease Term Pipelines From (Facility/Area/Block) To (Facility/Area/Block) Diameter (inches) Length (Feet)

Form BOEM-0137 (October 2011

– Supersedes all previous editions of form BOEM-0137, which may not be used.)



## ATTACHMENT A-1

### 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): Platform A Subsea Completion

Anchor Radius (if applicable) in feet: NA Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 27982

Area Name EW

Block No. 834

Blockline Departures (in feet) N/S Departure: 1162.98 FNL

E/W Departure: 5802.93 FEL

Lambert X-Y coordinates X: 2,623,637.07

Y: 10,231,477.02

Latitude/ Longitude Latitude: 28 0 09' 37.216"

Longitude: 89 0 56' 54.036"

TVD (Feet): MD (Feet): Water Depth (Feet): 1,183' Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor
X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y = 

### Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (4 4 U.S.C. Chapter 35) requires us to inform you that BOEM collects this informati on as part of an Walter Oil & Gas Corpora tion’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a curren tly valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 ho urs in AKOCSR), or 690 (1,700 in AKOCSR) with an acWaltering DPP or DOCD including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170.

### 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 stru cture, reference previous name): A001 (formerly No. 002 ) Subsea Completion

Anchor Radius (if applicable) in feet: Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 27982

Area Name EW

Block No. 834

Blockline Departures (in feet) N/S Departure: 1162.98 FNL

E/W Departure: 5802.93 FEL

Lambert X-Y coordinates X: 2,623,637.07

Y: 10,231,477.02

Latitude/ Longitude Latitude: 28 0 09' 37.216"

Longitude: 89 0 56' 54.036"

TVD (Feet): MD (Feet): Water Depth (Feet): 1,183' Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor
X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y = 

### Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (4 4 U.S.C. Chapter 35) requires us to inform you that BOEM collects this informati on as part of an Walter Oil & Gas Corpora tion’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a curren tly valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 ho urs in AKOCSR), or 690 (1,700 in AKOCSR) with an acWaltering DPP or DOCD including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170.

### 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 structu re, reference prev ious name): A002 Subsea Completion

Anchor Radius (if applicable) in feet: 4,600' May be drilled with either a semi-s ubmersible or platform rig. Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 27982

Area Name EW

Block No. 834

Blockline Departures (in feet) N/S Departure: 1163.00' FNL

E/W Departure: 5810.50' FEL

Lambert X-Y coordinates X: 2,623,629.50

Y: 10,231,477.00

Latitude/ Longitude Latitude: 28 0 09' 37.218"

Longitude: 89 0 56' 54.120"

TVD (Feet): MD (Feet): Water Depth (Feet): 1,183' Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y = 

### Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (4 4 U.S.C. Chapter 35) requires us to inform you that BOEM collects this informati on as part of an Walter Oil & Gas Corpora tion’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a curren tly valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 ho urs in AKOCSR), or 690 (1,700 in AKOCSR) with an acWaltering DPP or DOCD including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170.

### 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 structu re, reference prev ious name): A003 Subsea Completion

Anchor Radius (if applicable) in feet: Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 27982

Area Name EW

Block No. 834

Blockline Departures (in feet) N/S Departure: 1169.50'' FNL

E/W Departure: 5806.75' FEL

Lambert X-Y coordinates X: 2,623,633.25

Y: 10,231,470.50

Latitude/ Longitude Latitude: 28 0 09' 37.152"

Longitude: 89 0 56' 54.080"

TVD (Feet): MD (Feet): Water Depth (Feet): 1,183' Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor
X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y = 

### Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (4 4 U.S.C. Chapter 35) requires us to inform you that BOEM collects this informati on as part of an Walter Oil & Gas Corpora tion’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a curren tly valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 ho urs in AKOCSR), or 690 (1,700 in AKOCSR) with an acWaltering DPP or DOCD including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170.

### 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 struct ure, reference previous name): A004 Subsea Completion

Anchor Radius (if applicable) in feet: Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 27982

Area Name EW

Block No. 834

Blockline Departures (in feet) N/S Departure: 1155.50'' FNL

E/W Departure: 5797.51' FEL

Lambert X-Y coordinates X: 2,623,642.49

Y: 10,231,484.50

Latitude/ Longitude Latitude: 28 0 09' 37.289"

Longitude: 89 0 56' 53.973"

TVD (Feet): MD (Feet): Water Depth (Feet): 1,183' Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y = 

### Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (4 4 U.S.C. Chapter 35) requires us to inform you that BOEM collects this informati on as part of an Walter Oil & Gas Corpora tion’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a curren tly valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 ho urs in AKOCSR), or 690 (1,700 in AKOCSR) with an acWaltering DPP or DOCD including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170.

### 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 struct ure, reference previous name): A005 Subsea Completion

Anchor Radius (if applicable) in feet: Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 27982

Area Name EW

Block No. 834

Blockline Departures (in feet) N/S Departure: 1168.5'' FNL

E/W Departure: 5790.00' FEL

Lambert X-Y coordinates X: 2,623,650.00

Y: 10,231,471.50

Latitude/ Longitude Latitude: 28 0 09' 37.158"

Longitude: 89 0 56' 53.893"

TVD (Feet): MD (Feet): Water Depth (Feet): 1,183' Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y = 

### Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (4 4 U.S.C. Chapter 35) requires us to inform you that BOEM collects this informati on as part of an Walter Oil & Gas Corpora tion’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a curren tly valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 ho urs in AKOCSR), or 690 (1,700 in AKOCSR) with an acWaltering DPP or DOCD including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170.

### 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 structu re, reference prev ious name): A006 Subsea Completion

Anchor Radius (if applicable) in feet: Yes No

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS-G 27982

Area Name EW

Block No. 834

Blockline Departures (in feet) N/S Departure: 1176.00'' FNL

E/W Departure: 5803.00' FEL

Lambert X-Y coordinates X: 2,623,637.00

Y: 10,231,464.00

Latitude/ Longitude Latitude: 28 0 09' 37.087"

Longitude: 89 0 56' 54.040"

TVD (Feet): MD (Feet): Water Depth (Feet): 1,183' Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary) Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor
X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y = 

### Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (4 4 U.S.C. Chapter 35) requires us to inform you that BOEM collects this informati on as part of an Walter Oil & Gas Corpora tion’s Exploration Plan or Development Operations Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a curren tly valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 ho urs in AKOCSR), or 690 (1,700 in AKOCSR) with an acWaltering DPP or DOCD including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170.

### A ttachment A-2

### A ttachment A-4

### Walter Oil & Gas Corporation Page B

- 1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX B GENERAL INFORMATION

(A) APPLICATIONS AND PERMITS Following is a table of the additional applications/permits which will require approval prior to conducting the operations as proposed in this plan.

Application/Permit Issuing Agency Status APD BSEE To be submitted Surface Commingling Application BSEE To be submitted Deepwater Operations Plan BSEE To be submitted ROW Pipeline Application BSEE To be submitted

(B) DRILLING FLUIDS The table below provides information on the types (including chemical constituents) and amounts of the drilling fluids Walter plans to use to drill the proposed wells.

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be Used per Well Water-based (seawater, freshwater, barite) 6,000 bbls. Oil-based (diesel, minerals, oil) 0 Synthetic-based (internal olefin, ester) 1,277 bbls

(C) PRODUCTION Anticipated Production:

Type Average Production Rate Peak Production Rate Life of Reservoir

Oil Gas

(D) OIL CHARACTERISTICS

Characteristics Analytical Methodologies Should Be Compatible With: 1) Gravity (API) 2) Flash Point (°C) 3) Pour Point (°C) 4) Viscosity (Centipoise @ 25° C) 5) Wax Content (wt %) 6) Asphaltene Content (wt %) 7) Resin Content (wt %)

### Walter Oil & Gas Corporation Page B

- 2 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 8) Boiling point distribution including for each fraction, the percent volume or weight and the boiling point range in °C 9) Sulphur (wt %)



### (E) NEW OR UNUSUAL TECHNOLOGY Walter does not propose to use any new or unusual technology to carry out the proposed development activities.

(F) BONDING STATEMENT The bond requirements for the activities and facilities proposed in this DOCD are satisfied by $3,000,000.00 areawide development bond, furnished and maintained according to 30 CFR 556 Subpart I; NTL No. 2000-G16, "Guidelines for General Lease Surety Bonds”.

(G) OIL SPILL FINANCIAL RESPONSIBILITY (OSFR) Walter Oil & Gas Corporation, BOEM Company number 0730 has demonstrated or will demonstrate oil spill financial responsibility for the facilities proposed in this DOCD according to 30 CFR Part 553; and NTL No. 2008-N05, "Guidelines for Oil Spill Financial Responsibility for Covered Facilities".

(H) DEEPWATER WELL CONTROL STATEMENT Walter Oil & Gas Corporation, BOEM Company number 0730 has or will have the financial capability to drill a relief well and conduct other emergency well control operations.

(I) SUSPENSION OF PRODUCTION Walter does not anticipate requesting a Suspension of Production for these leases.

(J) BLOWOUT SCENARIO The blowout scenario and worst-case discharge calculations are included as Attachment B-1.Initial Joint DOCD

OCS-G 27982, Ewing Bank Block 834 (A001 (previously 002ST00BP00), A003, A005 & A006), OCSG 33140, Ewing Bank Block 790 (A002) & OCS-G 33177 Mississippi Canyon Block793 (A004)

BLOWOUT SCENARIO DATA SUBMITTAL NTL 2010-N06

There are currently three moored semi-submersible drilling rigs with 15,000 psi subsea blowout preventers with derrick capacity and horsepower available for relief-well drilling in case the platform rig has a blowout. It is estimated that a contract could be administered and additional equipment procured to drill the relief well in one hundred twenty one (121) days. Availability and safety record will be predominant factor for selecting the rig for the relief well. (2 days to acquire rig, 14 days to move on location and set anchors, 105 days to drill.)

Measure to prevent Blowout: These wells are development wells to be drill with a platform rig. The pressures, mud weights and casing points were determined from the data acquire drilling the discovery well. The discovery well was a straight hole drilled to total depth of _____ and temporary abandoned.

Additional precautions and safety procedures:

1. Complete detailed well design program for drilling operations including mud program and cement program. Safety meeting will be conducted every tour to communicate importance of operations.

2. Maintain mud properties consistent with offset wells.

3. Flow monitoring equipment for the rigs mud return system with real time data provided to supervisory personnel.

4. Real-time gas monitoring for the purpose of measuring gas units contained in the mud system for supervisory personnel.

5. Drilling breaks monitored and check for flow. In the event of flow, mud weig ht will be increased to control the well.

6. Monitoring of trip volumes both pulling in and out of the hole. Proper fill up volumes will be measured.

7. Control surge and swab pressures.

8. Circulate bottoms up before trips to insure the well is stable and free of gas.

9. Testing of BOP’s at a minimum of every two weeks when rams are changed or BOP’s repaired. 

### A ttac h ment B-1Page Two Initial Joint DOCD OCS-G 27982, Ewing Bank Block 834 (A001 (pre viously 002ST00BP00), A003, A005 & A006), OCSG 33140, Ewing Bank Block 790 (A002) & OCS-G 33177 Mississippi Canyon Block793 (A004)

Blowout Scenario Data Submittal NTL 2010-N06

Measures to reduce the likelihood of a blowout:

1. Contractor personnel (driller and tool pusher) have the authority to shut well(s) in should a well flow be encountered. Company personnel will be informed of the situation.

2. Company personnel will go to the floor immediately to assist Contractor personnel in industry-best practices kill procedure.

3. Proper API casing design and cementing practices using centralizers as recommended by simulation to insure centralized casing a nd 360 degree annular fill up of cement.

4. Production casing will have two barriers (float collar and float shoe).

5. Upon bumping the plug in cement operations, floats will be checked. In the event the floats do not hold, pressure will be maintained for 6-8 hours, and then shoe tract will be rechecked. Remedial cementing or setting of bridge plug will be taken if necessary to isolate the shoe tract.

6. Run cement bond log to verify cement quality before displacing well with completion fluid.

Arrangements for drilling relief wells: 1. Review shallow hazards survey to determine positioning of relief well.

2. Contract and mobilize relief well rig.

3. Contract relief well directional drilling co mpany and relief well drilling experts.

4. Prepare drilling program based on optimum rig position relative to targeted wellbore to optimize intervention.Joint Initial DOCD

OCS-G 27982, Ewing Bank Block 834 (A001 (previously 002ST00BP00), A003, A005 & A006), OCS-G 33140, Ewing Bank Block 790 (A002) & OCS-G 33177 Mississippi Canyon Block793 (A004)

(j) Blowout Scenario

Discussion of potential for well to bridge over. Need statement

Walter does not have sufficient information to anticipate that this well would likely bridge over; therefore, discussion of the likelihood of the well to bridge over is not included in this plan.

Randy’s statement Walter does not have any empirical data.

Discussion of likelihood for surface intervention to stop blowout. Need statement

An ongoing operation for surface intervention will work in parallel to the relief well operations. “Well Control” experts will board the rig, provide there is sufficient safety, to review the possibility of surface containment; or coordinate with relief well operations to contain the blowout. Firefighting boats and derrick barges will be employed to control the heat/fire and strip away surface equipment that prohibit successful surface intervention. A capping stack/diverter arrangement could potentially be used provided wellbore/casing integrity is verified during the operation.

Relief Well

Rig package constraints (if none, a statement to that affect). Need statement

No constraints.

Estimated time to drill relief well, including: (need to break down the days)

Estimated 121 days

Time to acquire a rig (days) : 2 days

Time to move rig onsite (days) : 14 days

Drilling time (days) : 105 days to drill relief well

Statement whether the possibility of using a nearby platform was considered, if feasible.

No nearby platform.

Measures to enhance ability to conduct effective and early intervention in the event of a blow out. Need statement.

Walter Oil & Gas Corporation is a member of Helix Well Control Group and the equipment is on standby in case of an incident.

### Walter Oil & Gas Corporation Page C

- 1 Joint Initial DOCD January, 2013 Ewing Bank Block 790 & 834, Mississippi Canyon Block 793 

## APPENDIX C GEOLOGICAL AND GEOPHYSICAL INFORMATION

(A) GEOLOGICAL DESCRIPTION PROPRIETARY INFORMATION

(B) STRUCTURE CONTOUR MAPS Current structure contour maps drawn on the top of each productive hydrocarbon sand, showing the entire lease blocks, the locations of the proposed and existing wells, and the locations of geological cross-sections are/is included as Attachment C-1.

(C) INTERPRETED 2-D AND/OR 3-D SEISMIC LINE(S) Interpreted 3-D seismic lines were submitted with Plan Control Number S-7359.

(D) GEOLOGICAL STRUCTURE CROSS-SECTIONS Interpreted geological structure cross-sections showing the locations and depths of each proposed well and at least one key horizon and the objective sands labeled using standard biostratigraphic terms are included as Attachment C-2.

(E) SHALLOW HAZARDS REPORT The proposed new wells will be drilled from an existing surface location; therefore, a Shallow Hazards Report is not required.

(F) SHALLOW HAZARDS ASSESSMENT Utilizing 3D seismic exploration data, a shallow hazards assessment was prepared for the proposed surface location and is included as Attachment C-3.

(G) HIGH-RESOLUTION SEISMIC LINES High resolution survey lines were included in Plan Control No. S-7359.

(H) STRATIGRAPHIC COLUMN A generalized biostratigraphic/lithostratigraphic column depicting each well from the seafloor to the total depth is not required for the operations provided for in this DOCD.

(I) TIME VS DEPTH TABLES Sufficient well control data for the target areas proposed in this DOCD exists; therefore, seismic time versus depth tables for the proposed well locations are not required.

### A ttachment C-3

### Walter Oil & Gas Corporation Page D-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX D HYDROGEN SULFIDE INFORMATION

(A) CONCENTRATION Walter Oil & Gas Corporation does not anticipate encountering any H 2 

### S during the proposed operations.

(B) CLASSIFICATION Walter requests BSEE classify the Ewing Bank Blocks 790 and 834 and Mississippi Canyon Block 793 as H 2 

### S absent.

### Walter Oil & Gas Corporation Page E-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX E MINERAL RESOURCE CONSERVATION INFORMATION

(A) TECHNOLOGY & RESERVOIR ENGINEERING PRACTICES AND PROCEDURES PROPRIETARY INFORMATION

(B) TECHNOLOGY AND RECOVERY PRACTICES AND PROCEDURES PROPRIETARY INFORMATION

(C) RESERVOIR DEVELOPMENT

PROPRIETARY INFORMATION

### Walter Oil & Gas Corporation Page F-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, and Mississippi Canyon Block 793 APPENDIX F BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

(A) DEEPWATER BENTHIC COMMUNITIES Activities proposed in this DOCD will disturb seafloor areas in water depths greater than 300 meters (984 feet); therefore, information as outlined in Attachment A of NTL No. 2009-G40, "Deepwater Benthic Communities" is provided below.

Wells proposed in this DOCD will be drilled from a common surface location, Platform A. The surface location for this platform was approved in Control Number S-7359. No deepwater benthic communities are in located within 2,000 feet from the mud and cuttings discharge location or 250 feet from the location of all other seafloor disturbances.

Included as Attachment F-1 are three charts prepared using 3-D seismic data depicting seafloor and shallow geological features and areas, and the surface location of the proposed wells with a radius circle of 2000 feet around the well. Also included on the charts is the maximum anchor radius for the Ewing Bank Block 790 well, plus the additional 1,000 foot buffer area beyond the proposed maximum anchor radius.

(B) TOPOGRAPHIC FEATURES MAP Activities proposed in this DOCD do not fall within 305 meters (1000 feet) of a topographic “no activity zone”.

(C) TOPOGRAPHIC FEATURES STATEMENT (SHUNTING) All activities proposed under this DOCD will be conducted outside all Topographic Feature Protective Zones; therefore, shunting of drill cuttings and drilling fluids is not required

(D) LIVE BOTTOMS (PINNACLE TREND) MAP Ewing Bank Block 790 & 834, and Mississippi Canyon Block 793 are not located within 61 meters (200 feet) of any pinnacle trend feature; therefore, a separate bathymetric map is not required.

(E) LIVE BOTTOMS (LOW RELIEF) STIPULATION Ewing Bank Block 790 & 834, and Mississippi Canyon Block 793 are not located within 100 feet of any pinnacle trend feature with vertical r elief equal to or greater than 8 feet; therefore, live bottom (low relief) maps are not required.

(F) POTENTIALLY SENSITIVE BIOLOGICAL FEATURES Ewing Bank Block 790 & 834, and Mississippi Canyon Block 793 are not located within 30 meters (100 feet) of potentially sensitive biological features; therefore, biologically sensitive area maps are not required.

(G) REMOTELY OPERATED VEHICLE (ROV) SURVEYS

### Walter Oil & Gas Corporation Page F-2 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, and Mississippi Canyon Block 793 BOEM has determined there is enough data gathered in Grid Area 12 therefore, we will not be conducting any ROV surveys either pre-spudding or post-drilling operations.

(H) THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND MARINE MAMMAL INFORMATION Under Section 7 of the Endangered Species Act (ESA) all federal agencies must ensure that any actions they authorize, fund, or carry out are not likely to jeopardize the continued existence of a listed species, or destroy or adversely modify its designated critical habitat.

In accordance with the 30 CFR 550, Subpart B, and further outlined in Notice to Lessees (NTL) 2012-JOINT-G01, lessees/operators are required to address site-specific information on the presence of federally listed threatened or endangered species and critical habitat designated under the ESA and marine mammals protected under the Marine Mammal Protection Act (MMPA) in the area of proposes activities under this plan.

There are five species of sea turtles that may be found in the Gulf of Mexico (see table below). NOAA fisheries currently lists all five of these turtles as endangered (E) or threatened (T).

Species Scientific Name Status Potential Presence

Critical Habitat Designated in the Gulf of Mexico Lease Area Coastal Sea Turtles Loggerhead Turtle CarettsaCaretta T X X None Green Turtle Cheloniamydas T,E X X None Leatherback Turtle Dermochelyscorlacea E X X None Hawksbill Turtle Eretmochelysimbricata E X X None Kemp’s Ridley Turtle Lepidochelyskempli E X X None



### In addition, there are 28 species of marine mammals that may be found in the Gulf of Mexico. The table provided below identifies the seven (7) species of marine mammals that are listed as endangered or threatened. Currently, there are no designated critical habitats for the listed species in the Gulf of Mexico Outer Continental Shelf; however, it is possible that one or more of these species could be seen in the area during operations.

Species Scientific Name Status Potential Presence Critical Habitat Designated in the Gulf of Mexico Lease Area Coastal

Marine Mammals Sperm Whale Physetermacrocephalus E X -- None Florida Manatee Trichechusmanatuslatirostris E -- X Florida (Peninsular) Blue Whale Balaenopteramasculus E X -- None Fin Whale Balaenopteraphysalus E X -- None Humpback Whale Megapteranovaeangliae E X -- None North Atlantic Right Whale Eubalaenaglacialis E X -- None Sei Whale Balaenopiera borealis E X -- None

### Walter Oil & Gas Corporation Page F-3 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, and Mississippi Canyon Block 793 (I) ARCHAEOLOGICAL REPORT Ewing Bank Blocks 790 & 834 and Mississippi Canyon Block 793 have been determined to have a high potential for containing archaeological properties; therefore, an Archaeological Survey Report was prepared in accordance with NTL 2005-G07 "Archaeological Surveys and Reports" and submitted to BOEM with Plan Control N-9234.

(J) AIR AND WATER QUALITY INFORMATION Air and water quality information is not required by BOEM to be included in this plan.® 3 333EWING BANK BLOCK 834 (OCS-G27982) 2 , 0 0 0 f t R a d i u s 4 , 6 0 0 f t Ma x i m u m A n c h o r R a d i u s

1 , 0 0 0 f t B u f f e r Z o n eEWING BANK BLOCK 790 (OCS-G33140)

1 , 0 0 0 ' 1 , 2 0 0 'Proposed EW790-A002 WellEW834-2EW834-1EW789-1

2,610,000 2,615,000 2,620,000 2,625,000 2,630,000 2,635,00010,225,00010,230,00010,235,00010,240,000 89°55'0"W

89°56'0"W

89°57'0"W

89°58'0"W

89°59'0"W28°11'0"N28°10'0"N28°9'0"N28°8'0"NLundLloyd RidgeGreen CanyonAtwater ValleyGarden BanksDe Soto CanyonHendersonDestin DomeMississippi CanyonWalker RidgeEast BreaksKeathley CanyonLouisianaTexasFloridaStudy AreaLEGENDChart scale 1" = 1,000'3D GEOHAZARD ASSESSMENTGULF OF MEXICOEWING BANKBLOCK 834GEODETIC INFORMATIONSEABED DEPTH - ANCHOR RADIUS (PROPOSED EW790-A002)CHART 10 1,000 2,000 3,000500 Feet0 300 600 900150 MetersProposed EW 790- A002 well location2,623,629 ft E/10,231,477 ft N® 3 333Seabed Depth (Feet)REV DATE REMARKS AUTHOR DRAWN CHECKEDSURVEY DATE N/A REPORT REF 7071 CHART NO 7071.010 JANUARY 10, 2013 FINAL JR VC ARHNot to scaleBlock boundaries±Prepared by: Gardline Surveys, Inc. 1500 Bingle Road, Houston, Texas, 77055. Telephone: 713.481.4630NotesDepth in feet belowsea surface to seabed,contoured at 25 ft intervals.-13106Existing WellPipelinesPipelinesPipelinesStudy area boundarySafety fairwaysCoordinate System: NAD 1927 UTM Zone 15NProjection: Transverse MercatorDatum: North American 1927Units: Foot USFalse Easting: 1,640,416.6667False Northing: 0.0000Central Meridian: -93.0000Scale Factor: 0.9996Latitude Of Origin: 0.0000Attachment F-1® 3 333EWING BANK BLOCK 834 (OCS-G27982) 2 , 0 0 0 f t R a d i u s 4 , 6 0 0 f t Ma x i m u m A n c h o r R a d i u s

1 , 0 0 0 f t B u f f e r Z o n eEWING BANK BLOCK 790 (OCS-G33140)Proposed EW790-A002 WellEW834-2EW834-1EW789-1

2,610,000 2,615,000 2,620,000 2,625,000 2,630,000 2,635,00010,225,00010,230,00010,235,00010,240,000 89°55'0"W

89°56'0"W

89°57'0"W

89°58'0"W

89°59'0"W28°11'0"N28°10'0"N28°9'0"N28°8'0"NLundLloyd RidgeGreen CanyonAtwater ValleyGarden BanksDe Soto CanyonHendersonDestin DomeMississippi CanyonWalker RidgeEast BreaksKeathley CanyonLouisianaTexasFloridaStudy AreaLEGENDChart scale 1" = 1,000'3D GEOHAZARD ASSESSMENTGULF OF MEXICOEWING BANKBLOCK 834GEODETIC INFORMATIONSEABED MORPHOLOGY - ANCHOR RADIUS (PROPOSED EW790-A002)CHART 20 1,000 2,000 3,000500 Feet0 300 600 900150 MetersProposed EW 790- A002 well location2,623,629 ft E/10,231,477 ft N® 3 333Illumintated from the northeast at 45° above horizontalREV DATE REMARKS AUTHOR DRAWN CHECKEDSURVEY DATE N/A REPORT REF 7071 CHART NO 7071.020 JANUARY 10, 2013 FINAL JR VC ARHNot to scaleBlock boundaries±Prepared by: Gardline Surveys, Inc. 1500 Bingle Road, Houston, Texas, 77055. Telephone: 713.481.4630Notes6Existing WellPipelinesPipelinesPipelinesStudy area boundarySafety fairwaysSeabed faults, ticks denotedown throw sideCoordinate System: NAD 1927 UTM Zone 15NProjection: Transverse MercatorDatum: North American 1927Units: Foot USFalse Easting: 1,640,416.6667False Northing: 0.0000Central Meridian: -93.0000Scale Factor: 0.9996Latitude Of Origin: 0.0000® 3 333EWING BANK BLOCK 834 (OCS-G27982) 2 , 0 0 0 f t R a d i u s 4 , 6 0 0 f t Ma x i m u m A n c h o r R a d i u s

1 , 0 0 0 f t B u f f e r Z o n eEWING BANK BLOCK 790 (OCS-G33140)Proposed EW790-A002 WellEW834-2EW834-1EW789-1

2,610,000 2,615,000 2,620,000 2,625,000 2,630,000 2,635,00010,225,00010,230,00010,235,00010,240,000 89°55'0"W

89°56'0"W

89°57'0"W

89°58'0"W

89°59'0"W28°11'0"N28°10'0"N28°9'0"N28°8'0"NLundLloyd RidgeGreen CanyonAtwater ValleyGarden BanksDe Soto CanyonHendersonDestin DomeMississippi CanyonWalker RidgeKeathley CanyonEast BreaksLouisianaTexasFloridaStudy AreaLEGENDChart scale 1" = 1,000'3D GEOHAZARD ASSESSMENTGULF OF MEXICOEWING BANKBLOCK 834GEODETIC INFORMATIONSEABED AMPLITUDE - ANCHOR RADIUS (PROPOSED EW790-A002)CHART 30 1,000 2,000 3,000500 Feet0 300 600 900150 MetersProposed EW 790- A002 well location2,623,629 ft E/10,231,477 ft N® 3 333Relative Seabed AmplitudeREV DATE REMARKS AUTHOR DRAWN CHECKEDSURVEY DATE N/A REPORT REF 7071 CHART NO 7071.030 JANUARY 10, 2013 FINAL JR VC ARHNot to scaleBlock boundaries±Prepared by: Gardline Surveys, Inc. 1500 Bingle Road, Houston, Texas, 77055. Telephone: 713.481.4630Notes6Existing WellPipelinesPipelinesPipelinesStudy area boundarySafety fairwaysCoordinate System: NAD 1927 UTM Zone 15NProjection: Transverse MercatorDatum: North American 1927Units: Foot USFalse Easting: 1,640,416.6667False Northing: 0.0000Central Meridian: -93.0000Scale Factor: 0.9996Latitude Of Origin: 0.0000

### Walter Oil & Gas Corporation Page G-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX G WASTES AND DISCHARGES INFORMATION

(A) PROJECTED GENERATED WASTES Table 1, “ Wastes You Will Generate, Treat and Downhole Dispose or Discharge to the GOM” is included in this section as Attachment G-1.please 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 wettedwithsyntheticbased fluidCuttings generatedwhileusing synthetic based X bbl/well X bbl/day/well discharge overboard NoWater-based drilling fluidWater based drillingfluids 30,000 bbls/total 500 bbls/per well/hour Discharge overboard NoCuttings wetted with water-based fluidCuttings generated whileusingwater based drillingfluids 20,000 bbs/total12 bbls/hr/well includingdrilling fluid Discharge overboard NoSynthetic based drilling fluidsSynthetic based drillingfluids adhering to drillcuttings from syntheticbased hole intervalsintervals5175 bbls/total 12 bbls/day/wellTreated cuttings will be discharged overoard whiledrilling SBM interval. Cuttings will pass throughcuttings dryer to reduce ROC percentage incompliance with EPA and then shunt throughdownpipe below water line.NODrill cuttingsgenerated while using syntheticbased drilling fluidsCuttings generated whilesusing synthetic baseddrilling fluids 13,330bbls total 30 bbls/day/wellTreated cuttings will be discharged overoard whiledrilling SBM interval. Cuttings will pass throughcuttings dryer to reduce ROC percentage incompliance with EPA and then shunt throughdownpipe below water line.NoWill humans be there? Ifyes, expect conventional wasteEXAMPLE: Sanitary waste waterSanitary waste fromliving quarters X bbl/well X bbl/hr/well chlorinate and discharge overboard NoATTACHMENT G-1WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOMProjectedDownholeDisposalDomestic waste Gray Water 8,000 bbls/total 10 bbls/hr/wellPrcessed through DNV Class approvedtreatment tank and dischargedSanitary wasteHuman body treat wastedischarged from toilets 2,500 bbls total 3 bbls/hr/well chlorinate and discharge overboard NoIs there a deck? If yes, there will be Deck DrainageDeck Drainage Rain water and rig wash 28,000 bbls total15 bbls/hr /dependent onrainfallOilywater is treated in one of four(4)separatorsand discharged through Port-side caisson(cuttings chute) below sea level NoWill you conduct well treatment, completion, or workover?Well treatment fluidsViscous and csgwashspacers using HEC andsmall amounts sodium 200 bbls/well 50 bbls/day/well discharge overboard NoWell completion fluids Calcium Chloride 3000 bbls total 50 bbls/day/well discharge overboard NoWorkover fluids NA NA NA NA NoMiscellaneous discharges. If yes, only fill in thoseassociated with your activity.Desalinization unit dischargeNA NA NA NANoBlowout prevent fluidNA NA NA NANoBallast waterNA NA NA NANoBilge waterNA NA NA NANoExcess cement at seafloor Cement Slurry NA NA Discharged at mudlineNoFire waterNA NA NA NANoCooling water NA NANA NANoWill you produce hydrocarbons? Ifyes fill in for produced water.Produced water NA NANANANAWill 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.

### Walter Oil & Gas Corporation Page H-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX H AIR EMISSIONS INFORMATION

(A) EMISSIONS WORKSHEETS AND SCREENING QUESTIONS Screen Procedures for DOCD’s Yes No Is any calculated Complex Total (CT) Emission amount (tons) associated with your proposed development activities more than 90% of the amounts calculated using the following formulas: CT = 3400D 2/3 

### for CO, and CT = 33.3D for the other air pollutants (where D = distance to shore in miles)? x

Do your emission calculations include any emission reduction measures or modified emission factors? x Does or will the facility complex associated with your proposed development and production activities process production from eight or more wells? x Do you expect to encounter H 2 

### S at concentrations greater than 20 parts per million (ppm)? x Do you propose to flare or vent natural gas in excess of the criteria set forth under 250.1105(a)(2) and (3)? x Do you propose to burn produced hydrocarbon liquids? x Are your proposed development and production activities located within 25 miles (40 kilometers) from shore? x Are your proposed development and production activities located within 124 miles (200 kilometers) of the Breton Wilderness Area? x



### An Air Emission Spreadsheet utilizing a platform rig for all wells is included as Attachment H1. Attachment H-2 is an Air Emission Spreadsheet utilizing a platform rig for five wells, and a semi-submersible rig for one well.

This information was calculated by: Judy Davidson (281) 578-3388 judy.davidson@jccteam.comDOCD AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/14COMPANYWalter Oil & GasAREAEW, MCBLOCK790, 834, 793LEASE33140, 27982, 33177PLATFORMAWELL6 wellsCOMPANY CONTACTJudy DavidsonTELEPHONE NO.281-578-3388REMARKSPlatform RigLEASE TERM PIPELINE CONSTRUCTION INFORMATION:YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYSPIPELINES20122013201420152016201720182019202020212022FORM BOEM-0139(December 2011- Supersedes all previous versions of this form which may not be used).Page 1 of 8Attachment H-1AIR EMISSIONS CUMPUTATION FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6La. DEQ 1991Gas Venting lbs/scf 0.0034Sulphur Content Source Value UnitsFuel Gas 3.33 ppmDiesel Fuel 0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightFORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 2 of 8AIR EMISSIONS CALCULATIONS - FIRST YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982,3A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>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 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 6635 320.4705 7691.29 24 45 4.68 21.45 160.76 4.82 35.07 2.53 11.59 86.81 2.60 18.94INSTALLATION MATERIAL TUG diesel 4500 217.35 5216.40 24 45 3.17 14.55 109.03 3.27 23.79 1.71 7.86 58.88 1.77 12.85VESSELS>600hp diesel(crew) 2500 120.75 2898.00 8 7 1.76 8.08 60.57 1.82 13.22 0.05 0.23 1.70 0.05 0.37VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 2 2.11 9.70 72.69 2.18 15.86 0.01 0.04 0.33 0.01 0.07PRODUCTION RECIP.<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 0.00RECIP.>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 0.00SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL11.73 53.79 403.05 12.09 87.94 4.30 19.71 147.71 4.43 32.23EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 3 of 8AIR EMISSIONS CALCULATIONS - SECOND YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982, 3 A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 6635 320.4705 7691.29 24.00 285.00 4.68 21.45 160.76 4.82 35.07 15.99 73.37 549.80 16.49 119.96PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2500 120.75 2898.00 6.00 41.00 1.76 8.08 60.57 1.82 13.22 0.22 0.99 7.45 0.22 1.63VESSELS>600hp diesel(supply) 3000 144.9 3477.60 8.00 10.00 2.11 9.70 72.69 2.18 15.86 0.08 0.39 2.91 0.09 0.63VESSELS>600hp diesel(tugs) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONCrane RECIP.<600hp diesel 475 22.9425 550.62 1 2 1.05 1.54 14.65 1.17 3.17 0.00 0.00 0.01 0.00 0.00Crane RECIP.>600hp diesel 800 38.64 927.36 10 3 0.56 2.59 19.38 0.58 4.23 0.01 0.04 0.29 0.01 0.06SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 350 0.00 16.63 1.01 2.26 0.01 69.86 4.26 9.47CompressorRECIP.4 cycle rich nat gas6404571.52109716.48243500.0014.100.2012.120.0159.210.8350.92CompressorRECIP.4 cycle rich nat gas6404571.52109716.48243500.0014.100.2012.120.0159.210.8350.92Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 350 0.00 24.23 0.34 20.84 0.02 101.76 1.42 87.52Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 350 0.00 24.23 0.34 20.84 0.02 101.76 1.42 87.52Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 2 2 0.00 24.23 0.34 20.84 0.00 0.05 0.00 0.04BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002016 YEAR TOTAL10.16 43.38 431.47 12.80 148.44 16.30 74.86 893.11 24.76 357.75EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 4 of 8AIR EMISSIONS CALCULATIONS - THIRD YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982, 3 A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 6635 320.4705 7691.29 24.00 130.00 4.68 21.45 160.76 4.82 35.07 7.30 33.47 250.79 7.52 54.72PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2500 120.75 2898.00 6.00 19.00 1.76 8.08 60.57 1.82 13.22 0.10 0.46 3.45 0.10 0.75VESSELS>600hp diesel(supply) 3000 144.9 3477.60 8.00 5.00 2.11 9.70 72.69 2.18 15.86 0.04 0.19 1.45 0.04 0.32VESSELS>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 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONCrane RECIP.<600hp diesel 475 22.9425 550.62 1 2 1.05 1.54 14.65 1.17 3.17 0.00 0.00 0.01 0.00 0.00Crane RECIP.>600hp diesel 800 38.64 927.36 10 3 0.56 2.59 19.38 0.58 4.23 0.01 0.04 0.29 0.01 0.06SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00CompressorRECIP 4 cycle lean nat gas6404571 52109716 48243650 0016 631 012 260 0172 864 459 88CompressorRECIP.4 cycle lean nat gas6404571.52109716.48243650.0016.631.012.260.0172.864.459.88Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 365 0.00 14.10 0.20 12.12 0.01 61.74 0.86 53.10Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 2 2 0.00 24.23 0.34 20.84 0.00 0.05 0.00 0.04BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002017 YEAR TOTAL10.16 43.38 431.47 12.80 148.44 7.45 34.23 602.90 15.96 301.41EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 5 of 8AIR EMISSIONS CALCULATIONS - FOURTH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982, 3 A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>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 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONCrane RECIP.<600hp diesel 475 22.9425 550.62 1 2 1.05 1.54 14.65 1.17 3.17 0.00 0.00 0.01 0.00 0.00Crane RECIP.>600hp diesel 800 38.64 927.36 10 3 0.56 2.59 19.38 0.58 4.23 0.01 0.04 0.29 0.01 0.06SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00CompressorRECIP.4 cycle lean nat gas6404571.52109716.48243650.0016.631.012.260.0172.864.459.88CompressorRECIP.4 cycle lean nat gas6404571.52109716.48243650.0016.631.012.260.0172.864.459.88Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 365 0.00 14.10 0.20 12.12 0.01 61.74 0.86 53.10Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 2 2 0.00 24.23 0.34 20.84 0.00 0.05 0.00 0.04BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002018 YEAR TOTAL1.61 4.14 137.45 3.98 84.29 0.01 0.10 347.20 8.29 245.62EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 6 of 8AIR EMISSIONS CALCULATIONSCOMPANY AREA BLOCK LEASE PLATFORM WELLWalter Oil & GasEW, MC 790, 834, 793 33140, 27982, 33177 A 6 wellsEmitted SubstanceYearPM SOx NOx VOC CO2015 4.30 19.71 147.71 4.43 32.232016 16.30 74.86 893.11 24.76 357.752017 7.45 34.23 602.90 15.96 301.412018-2035 0.01 0.10 347.20 8.29 245.62Allowable2064.60 2064.60 2064.60 2064.60 53260.68FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 8 of 8DOCD AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/14COMPANYWalter Oil & GasAREAEW, MCBLOCK790, 834, 793LEASE33140, 27982, 33177PLATFORMAWELL6 wellsCOMPANY CONTACTJudy DavidsonTELEPHONE NO.281-578-3388REMARKSThe A-2 well in EW 790 maybe drilled with a semi-submersible rig, and isincluded in this AQR as such.LEASE TERM PIPELINE CONSTRUCTION INFORMATION:YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYSPIPELINES20122013201420152016201720182019202020212022FORM BOEM-0139(December 2011- Supersedes all previous versions of this form which may not be used).Page 1 of 8Attachment H-2AIR EMISSIONS CUMPUTATION FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6La. DEQ 1991Gas Venting lbs/scf 0.0034Sulphur Content Source Value UnitsFuel Gas 3.33 ppmDiesel Fuel 0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightFORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 2 of 8AIR EMISSIONS CALCULATIONS - FIRST YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982,3A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>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 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 6635 320.4705 7691.29 24 45 4.68 21.45 160.76 4.82 35.07 2.53 11.59 86.81 2.60 18.94INSTALLATION MATERIAL TUG diesel 4500 217.35 5216.40 24 45 3.17 14.55 109.03 3.27 23.79 1.71 7.86 58.88 1.77 12.85VESSELS>600hp diesel(crew) 2500 120.75 2898.00 8 7 1.76 8.08 60.57 1.82 13.22 0.05 0.23 1.70 0.05 0.37VESSELS>600hp diesel(supply) 3000 144.9 3477.60 6 2 2.11 9.70 72.69 2.18 15.86 0.01 0.04 0.33 0.01 0.07PRODUCTION RECIP.<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 0.00RECIP.>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 0.00SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle rich nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL11.73 53.79 403.05 12.09 87.94 4.30 19.71 147.71 4.43 32.23EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 3 of 8AIR EMISSIONS CALCULATIONS - SECOND YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982, 3 A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 6635 320.4705 7691.29 24.00 195.00 4.68 21.45 160.76 4.82 35.07 10.94 50.20 376.18 11.29 82.08PRIME MOVER>600hp diesel 26,400 1275.12 30602.88 24.00 90.00 18.61 85.36 639.65 19.19 139.56 20.10 92.19 690.82 20.72 150.72PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2500 120.75 2898.00 6.00 41.00 1.76 8.08 60.57 1.82 13.22 0.22 0.99 7.45 0.22 1.63VESSELS>600hp diesel(supply) 3000 144.9 3477.60 8.00 10.00 2.11 9.70 72.69 2.18 15.86 0.08 0.39 2.91 0.09 0.63VESSELS>600hp diesel(tugs) 4500 217.35 5216.40 24.00 4.00 3.17 14.55 109.03 3.27 23.79 0.15 0.70 5.23 0.16 1.14PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONCrane RECIP.<600hp diesel 475 22.9425 550.62 1 2 1.05 1.54 14.65 1.17 3.17 0.00 0.00 0.01 0.00 0.00Crane RECIP.>600hp diesel 800 38.64 927.36 10 3 0.56 2.59 19.38 0.58 4.23 0.01 0.04 0.29 0.01 0.06SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 350 0.00 16.63 1.01 2.26 0.01 69.86 4.26 9.47CompressorRECIP.4 cycle rich nat gas6404571.52109716.48243500.0014.100.2012.120.0159.210.8350.92CompressorRECIP.4 cycle rich nat gas6404571.52109716.48243500.0014.100.2012.120.0159.210.8350.92Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 350 0.00 24.23 0.34 20.84 0.02 101.76 1.42 87.52Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 350 0.00 24.23 0.34 20.84 0.02 101.76 1.42 87.52Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 2 2 0.00 24.23 0.34 20.84 0.00 0.05 0.00 0.04BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002016 YEAR TOTAL31.94 143.29 1180.15 35.26 311.79 31.50 144.58 1415.54 40.43 471.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 4 of 8AIR EMISSIONS CALCULATIONS - THIRD YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982, 3 A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 6635 320.4705 7691.29 24.00 130.00 4.68 21.45 160.76 4.82 35.07 7.30 33.47 250.79 7.52 54.72PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2500 120.75 2898.00 6.00 19.00 1.76 8.08 60.57 1.82 13.22 0.10 0.46 3.45 0.10 0.75VESSELS>600hp diesel(supply) 3000 144.9 3477.60 8.00 5.00 2.11 9.70 72.69 2.18 15.86 0.04 0.19 1.45 0.04 0.32VESSELS>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 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONCrane RECIP.<600hp diesel 475 22.9425 550.62 1 2 1.05 1.54 14.65 1.17 3.17 0.00 0.00 0.01 0.00 0.00Crane RECIP.>600hp diesel 800 38.64 927.36 10 3 0.56 2.59 19.38 0.58 4.23 0.01 0.04 0.29 0.01 0.06SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00CompressorRECIP 4 cycle lean nat gas6404571 52109716 48243650 0016 631 012 260 0172 864 459 88CompressorRECIP.4 cycle lean nat gas6404571.52109716.48243650.0016.631.012.260.0172.864.459.88Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 365 0.00 14.10 0.20 12.12 0.01 61.74 0.86 53.10Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 2 2 0.00 24.23 0.34 20.84 0.00 0.05 0.00 0.04BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002017 YEAR TOTAL10.16 43.38 431.47 12.80 148.44 7.45 34.23 602.90 15.96 301.41EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 5 of 8AIR EMISSIONS CALCULATIONS - FOURTH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSWalter Oil & Gas EW, MC 790, 834, 793 33140, 27982, 3 A 6 wells Judy Davidson 281-578-3388 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00PRIME MOVER>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 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>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 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL 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 0.00PIPELINE BURY 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 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONCrane RECIP.<600hp diesel 475 22.9425 550.62 1 2 1.05 1.54 14.65 1.17 3.17 0.00 0.00 0.01 0.00 0.00Crane RECIP.>600hp diesel 800 38.64 927.36 10 3 0.56 2.59 19.38 0.58 4.23 0.01 0.04 0.29 0.01 0.06SUPPORT VESSEL 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 0.00TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00CompressorRECIP.4 cycle lean nat gas6404571.52109716.48243650.0016.631.012.260.0172.864.459.88CompressorRECIP.4 cycle lean nat gas6404571.52109716.48243650.0016.631.012.260.0172.864.459.88Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 365 0.00 14.10 0.20 12.12 0.01 61.74 0.86 53.10Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 24 365 0.00 24.23 0.34 20.84 0.02 106.12 1.49 91.27Generator RECIP.4 cycle rich nat gas 1100 7857.3 188575.20 2 2 0.00 24.23 0.34 20.84 0.00 0.05 0.00 0.04BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 0.0 0 0.00 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002018 YEAR TOTAL1.61 4.14 137.45 3.98 84.29 0.01 0.10 347.20 8.29 245.62EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2064.60 2064.60 2064.60 2064.60 53260.6862.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 6 of 8AIR EMISSIONS CALCULATIONSCOMPANY AREA BLOCK LEASE PLATFORM WELLWalter Oil & GasEW, MC 790, 834, 793 33140, 27982, 33177 A 6 wellsEmitted SubstanceYearPM SOx NOx VOC CO2015 4.30 19.71 147.71 4.43 32.232016 31.50 144.58 1415.54 40.43 471.732017 7.45 34.23 602.90 15.96 301.412018-2035 0.01 0.10 347.20 8.29 245.62Allowable2064.60 2064.60 2064.60 2064.60 53260.68FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 8 of 8

### Walter Oil & Gas Corporation Page I-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX I OIL SPILLS INFORMATION

(A) OIL SPILL RESPONSE PLANNING All the proposed activities and facilities in the DOCD will be covered by Walter Oil & Gas Corporation's (BOEM Operator No.0730) last approved Oil Spill Response Plan (OSRP) submitted July, 2011 and approved August 3, 2012.

(B) SPILL RESPONSE SITES

Primary Response Equipment Location Preplanned Staging Location Houma, LA. Houma, LA Harvey, LA. Harvey, LA. Venice, LA. Venice, LA.

(C) OSRO INFORMATION Walter’s primary equipment provider is Clean Gulf Associates (CGA, and it will provide the closest available personnel, as well as supervisor to operate the equipment.

(D) WORST-CASE DISCHARGE SCENARIO DETERMINATION

Category Drilling Production

Regional

OSRP WCD DOCD WCD Regional OSRP WCD DOCD WCD

Type of Activity Drilling Drilling Production Production
Facility Location (Area/Block) EW 834 EW 834 WD 107 EW 834

Facility Designation Well No. 2 Platform A A-7 Platform A

Distance to Nearest Shoreline (miles) 64 63 20 63

Volume Storage tanks & flowlines Lease term pipelines Uncontrolled blowout Total Volume (bbls) 169,488 bbls. 169,488 bbls. 1350 bbls.

96,574 bbls. 97,924 bbls. 850 bbls.

26,029 bbls. 26,879 bbls. 1,350 bbls.

20,000 bbls. 21,350 bbls. Type of Oil(s) (crude, condensate, diesel) Crude Crude Condensate Crude

API Gravity 24 23.7 45 23.7

### Walter Oil & Gas Corporation Page I-2 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 Walter has determined that the worst-case scenario from the activities proposed in this DOCD does not supersede the worst-case scenario from our approved regional OSRP.

Since Walter has the capability to respond to the worst-case spill scenario included in our regional OSRP approved on August 3, 2012,, and since the worst-case scenario determined for our DOCD does not replace the worst-case scenario in our regional OSRP, Walter herebycertifies that Walter has the capability to respond, to the maximum extent practicable, to a worstcase discharge, or a substantial threat of such a discharge, resulting from the activities proposed in our DOCD.

(E) OIL SPILL RESPONSE DISCUSSION Included as Attachment I-1 is Walter's Spill Response Discussion.

### ATTACHMENT I-1 SPILL RESPONSE DISCUSSION

For the purpose of NEPA and Coastal Zone Management Act analysis, the largest spill volume originating from the proposed activity would be a well blowout during drilling operations, estimated to be 97,924 barrels of crude oil with an API gravity of 23.7°.

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 BSEE Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BSEE website. The results are shown in Figure 1. The BSEE OSRAM identifies a 7% probability of impact to the shorelines of Cameron Parish, Louisiana within 30 days. Cameron Parish includes the east side of Sabine Lake, Sabine National Wildlife Refuge, Calcasieu Lake, Lacassine National Wildlife Refuge (inland) and Grand Lake. Cameron Parish also includes the area along the coastline from Sabine Pass to Big Constance Lake in Rockefeller Wildlife Refuge. This region is composed of open public beaches, marshlands and swamps. It serves as a habitat for numerous birds, finfish and other animals, including several rare, threatened and endangered species.

Response

Walter will make every effort to respond to the Worst Case Discharge as effectively as practicable. A description of the response equipment under contract 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 6% or approximately 5,875 barrels of crude oil would be evaporated/dispersed within 24 hours, with approximately 92,049 barrels remaining.

Spill Response EW 834, Platform A Barrels of Oil
WCD Volume 97,924

Less 6% natural evaporation/dispersion 5,875 Remaining volume 92,049 Daily dispersant capability 7,540



### Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary storage equipment available to respond to a spill of approximately 92,049 barrels. The volume accounts for the amount remaining after evaporation/dispersion at 24 hours. The list estimates individual times needed for procurement, load out, travel time to the site and deployment. Figure 2 also indicates how operations will be supported.

### Walter’s Oil Spill Response Plan includes alternative response technologies such as dispersants and in-situ burn. Strategies will be decided by Unified Command based on the size of the spill, weather and potential impacts. If aerial dispersants are utilized, 8 sorties (9,600 gallons) from two of the DC-3 aircrafts and 4 sorties (8,000 gallons) from the Basler aircraft would provide a daily dispersant capability of 7,540 barrels. 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. Slick containment boom would be immediately called out and on-scene as soon as possible. Offshore response strategies may include attempting to skim utilizing the HOSS Barge, nine Fast Response Units (FRUs), four sets of Koseq skimming arms, and two Aqua Guard Triton RBS skimmers, with a total derated skimming capacity of 198,135 barrels. Temporary storage associated with skimming equipment equals 17,700 barrels. If additional storage is needed, an 80,000 barrel storage barge, a 25,000 barrel storage barge, a 47,000 barrel storage barge, and three 23,000 barrel storage barges may be mobilized and centrally located to provide temporary storage allowing the skimmers to stay in the area of operations as much as possible. 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 Cameron Parish, Louisiana would depend upon existing environmental conditions. Shoreline protection would include the use of CGA’s near shore and shallow water skimmers with a totaled derated skimming capacity of 54,753 barrels. Temporary storage associated with skimming equipment equals 765 barrels. If additional storage is needed, three 20,000 barrel storage barges may be mobilized and centrally located to provide temporary storage allowing the skimmers to stay in the area of operations as much as possible. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. A Master Service Agreement with OMI Environmental will ensure access to 30,000 feet of 18” shoreline protection boom. Figure 2 outlines individual times needed for procurement, load out, travel time to the site and deployment. Strategies would be based upon surveillance and real time trajectories that depict areas of potential impact given actual sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan for Cameron Parish and Unified Command would be consulted to ensure that environmental and special economic resources would be correctly identified and prioritized to ensure optimal protection. Shoreline protection strategies depict the protection response modes applicable for oil spill clean-up operations. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection strategies for this area, and it describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands, based on the assumption that removal of the released oil will be much easier and less damaging to fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. Supervisory personnel have the option to modify the deployment and operation of equipment allowing a more effective response to site-specific circumstances. Walter’s contract Spill Management Team holds a copy of the State of Louisiana Initial Oil Spill Response Plan.

Based on the anticipated worst case discharge scenario, Walter can be onsite with contracted oil spill recovery equipment with adequate response capacity to contain and recover surface hydrocarbons, and prevent land impact, to the maximum extent practicable, within an estimated 62 hours (based on the equipment’s Effective Daily Recovery Capacity (EDRC)).

### Initial Response Considerations Actual actions taken during an oil spill response will be based on many factors which include but are not limited to:

x Weather

x Equipment and materials availability

x Ocean currents and tides

x Location of the spill

x Product spilled

x Amount spilled

x Environmental risk assessments

x Trajectory and product analysis

x Well status, i.e., shut in or continual release

Walter will take action to provide a safe, aggressive response to contain and recover as much of the spilled oil as quickly as it is safe to do so. In an effort to protect the environment, response actions will be designed to provide an “in-depth” protection strategy meant to recover as much oil as possible as far from environmentally sensitive areas as possible. Safety will take precedence over all other considerations during these operations.

Upon notification of a spill, the following actions will be taken:

x Information will be confirmed

x An assessment will be made and initial objectives set

x OSROs and appropriate agencies will be notified

x ICS 201, Initial Report Form will be completed

x Initial Safety plan will be written and published

x Unified Command will be established

o Overall safety plan developed to reflect the operational situation and coordinated objectives

o Areas of responsibility established for Source Control and each surface operational site

o On-site command and control established

Offshore Response Actions

Equipment Deployment Surveillance

x Surveillance Aircraft will be deployed within two hours of Qualified Individual (QI) notification, or at first light

x Provide trained observer to provide on site status reports

x Provide command and control platform at the site if needed

x Continual surveillance of oil movement by remote sensing systems, aerial photography and visual confirmation

x Continual monitoring of vessel assets using vessel monitoring systems

### Dispersant application assets

x Put Airborne Support Inc. (ASI) on standby

x With the Federal On-Scene Coordinator (FOSC), conduct analysis to determine appropriateness of dispersant application

x Gain FOSC approval for use of dispersants on the surface

x Deploy aircraft in accordance with a plan developed for the actual situation

x Coordinate movement of dispersants, aircraft, and support equipment and personnel

x Confirm dispersant availability for current and long range operations

x Start ordering dispersant stocks required for expected operations

Containment boom

x Call out early and expedite deployment to be on scene ASAP

x Ensure boom handling and mooring equipment is deployed with boom

x Provide continuing reports to vessels to expedite their arrival at sites that will provide for their most effective containment

x Use Vessels of Opportunity (VOO) to deploy and maintain boom

Dedicated off-shore skimming systems General

x Deployed to the highest concentration of oil

x Assets deployed at safe distance from aerial dispersant and in-situ burn operations

CGA HOSS Barge

x Use in areas with heaviest oil concentrations

x Consider for use in areas of known debris (seaweed, and other floating materials)

CGA FRUs

x To the area of the thickest oil

x Use as far off-shore as allowed

x VOOs 140’ – 180’ in length

x VOOs with minimum of 18’ x 38’ or 23’ x 50’ of optimum deck space

T&T Koseq Skimming Systems

x To the area of the thickest oil

x Use as far off-shore as allowed

x VOOs with a minimum of 2,000 bbls storage capacity

x VOOs at least 200’ in length

x VOOs with deck space of 100’ x 40’ to provide space for arms, tanks, and crane

### Storage Vessels

x Establish availability of CGA contracted assets

x Early call out (to allow for tug boat acquisition and deployment speeds)

x Phase mobilization to allow storage vessels to arrive at the same time as skimming systems

x Position as closely as possible to skimming assets to minimize offloading time

Vessels of Opportunity (VOO)

x Use Walter’s contracted resources as applicable

x Industry vessels are usually best for deployment of Vessel of Opportunity Skimming Systems (VOSS)

x Acquire additional resources as needed

x Consider use of local assets, i.e. fishing and pleasure craft

x Expect mission specific and safety training to be required

x Plan with the US Coast Guard for vessel inspections

In-situ Burn assets

x Determine appropriateness of in-situ burn operation in coordination with the FOSC and affected State On-Scene Coordinator (SOSC)

x Determine availability of fire boom and selected ignition systems

x Start ordering fire boom stocks required for expected operations

x Contact boom manufacturer to provide training if required

x Determine assets to perform on water operation

x Build operations into safety plan

x Conduct operations in accordance with an approved plan

### Near Shore Response Actions

Timing

x Place near shore assets on standby and deploy in accordance with planning based on the actual situation, actual trajectories and oil budgets

x VOO identification and training in advance of spill nearing shoreline if possible

x Outfitting of VOOs for specific missions

x Deployment of assets based on actual movement of oil

Considerations

x Water depth, vessel draft

x Shoreline gradient

x State of the oil

x Use of VOOs

x Distance of surf zone from shoreline

Equipment Deployment Surveillance

x Provide trained observer to direct skimming operations

x Continual surveillance of oil movement by remote sensing systems, aerial photography and visual confirmation

x Continual monitoring of vessel assets

Dispersant Use

x Generally will not be approved within 3 miles of shore or with less than 10 meters of water depth

x Approval would be at Regional Response Team level (Region 6)

Vessel Deployment Dedicated Near Shore skimming systems

x Fast Response Vessels (FRV)

x Egmopol and Marco Shallow Water Skimmer (SWS)

x Operate with aerial spotter directing systems to observed oil slicks

VOO

x Use Walter’s contracted resources as applicable

x Industry vessels are usually best for deployment of Vessel of Opportunity Skimming Systems (VOSS)

x Acquire additional resources as needed

x Consider use of local assets, i.e. fishing and pleasure craft

x Expect mission specific and safety training to be required

x Plan with the US Coast Guard for vessel inspections

x Operate with aerial spotter directing systems to oil patches

### Shoreline Protection Operations

Response Planning Considerations

x Environmental risk assessments (ERA) to determine priorities for area protection

x Time to acquire personnel and equipment and their availability

x Previous contingency planning contained in the appropriate Area Contingency Plan, and currently for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep Water Horizon, dated 2 May 2010

Actions

Placement of boom

x Position boom in accordance with the ERA based on the actual situation or the appropriate ACP

x Assess timing of booming operations to ensure it is where it needs to be at time of impact. Consider:

o Trajectories

o Weather forecast

o Oil Impact forecast

o Verified spill movement

o Boom, manpower and vessel (shallow draft) availability

o Near shore boom and support material, (stakes, anchors, line)

Beach Preparation

Considerations and Actions

x Use of a 10 mile go/no go line to determine timing of beach cleaning

x Shoreline Cleanup and Assessment Team Reports and recommendations

x Determination of Archeological sites and gaining authority to enter

x Monitoring of tide tables and weather to determine extent of high tides

x Pre cleaning of beaches by moving waste above high tide lines to minimize waste

x Staging of equipment and housing of response personnel as close to the job site as possible to maximize on-site work time

x Boom tending, repair, replacement and security (use of local assets may be advantageous)

x Constant awareness of weather and oil movement for resource redeployment as necessary

x In-situ burn may be considered when marshes have been impacted

x Passive clean up of marshes should be considered and appropriate stocks of sorbent boom and/or sweep obtained

x Earthen berms and shoreline protection boom may be considered to protect sensitive inland areas

### Decanting Strategy Recovered oil and water mixtures will typically se parate into distinct phases when left in a quiescent state. When separation occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill
recovery.

CGA Equipment Limitations The capability for any spill response equipment, whether a dedicated or portable system, to operate in differing weather conditions will be dir ectly in relation to the capabilities of the vessel the system in placed on. Most importantly, however, the decision to operate will be based on the judgment of the Unified Command and/or the Captain of the vessel, who will ultimately have the final say in terminating operations. Skimming equipment listed below may have operational limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil spill response, vessel skimming operations ceased when seas reached 5-6 feet and vessels were often recalled to port when those conditions were exceeded. Systems below are some of the most up-to-date systems available and were employed during the DWH spill.

Boom 3 foot seas, 20 knot winds Dispersants Winds more than 25 knots Visibility less than 3 nautical miles Ceiling less than 1,000 feet. FRU 8 foot seas HOSS Barge/OSRB 8 foot seas Koseq Arms 8 foot seas OSRV 4 foot seas

### Environmental Conditions in the GOM Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences westerly winds during the winter and easterly winds in the summer. Average wind speed is generally 14-15 mph along the coast. Wave heights average 4 and 5 feet. However, during hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, flooding is prominent.

Surface water temperature ranges between 70 and 80  ̊ F during the summer months. During the winter, the average temperature will range from 50 and 60  ̊ F.

The Atlantic and Gulf of Mexico hurricane season is officially from 1 June to 30 November. 97% of all tropical activity occurs within this window. The Atlantic basin shows a very peaked season from August through October, with 78% of the tropical storm days, 87% of the minor (Saffir-Simpson Scale categories 1 and 2) hurricane days, and 96% of the major (Saffir-Simpson categories 3, 4 and 5) hurricane days occurring then. Maximum activity is in early to mid September. Once in a few years there may be a h urricane occurring "out of season" - primarily in May or December. Globally, September is the most active month and May is the least active month.

### FIGURE 1 TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it impacting a land segment have been projected utilizing Walter’s WCD and information in the BSEE Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BSEE 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

Install Platform A and

2 10" right-of-way pipelines. Drill and

complete 6 wells.

EW 834, Platform A

63 miles from shore G27982 C42 Matagorda, TX Galveston, TX Jefferson, TX Cameron, LA Vermilion, LA Iberia, LA Terrebonne, LA Lafourche, LA Jefferson, LA Plaquemines, LA 1 2 2 7 3 1 3 2 1 5WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS(63 miles from shore)92,049 bbls of crude oil (Volume considering natural weathering)API Gravity 23.7°FIGURE 2 – Equipment Response Time to EW 834, Platform ADispersants / SurveillanceDispersant/SurveillanceDispersantCapacity (gal)StorageCapacityPersonsReq.From Hrs to ProcureHrs toLoadoutTravel to site Total HrsCGABasler 67T 2000 NA 2 Houma 1 1 0.6 2.6ASIDC 3 1200 NA 2 Houma 1 1 0.8 2.8DC 3 1200 NA 2 Houma 1 1 0.8 2.8Aero Commander NA NA 2 Houma 1 1 0.6 2.6Offshore ResponseOffshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge 43000 4000 3 Tugs 8 Harvey 7 0 5 15 1 28T&T Marine (available through contract with CGA)Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Leeville 24 24 2 10 2 62Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 24 24 2 5 2 57Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 24 24 1 10 2 61K-Sea Operating (available through contract with CGA)PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 2 7.75 1 26.75Enterprise Marine Services LLC (available through contract with CGA)CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 15 1 36Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGAFRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 3 5 1 12FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 1 2 1.5 5 1 10.5FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 8 5 1 17FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Ingleside 1 2 11 5 1 20FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 5.5 5 1 14.5FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 5 1 9FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Leeville 1 2 3.5 5 1 12.5T&T Marine (available through contract with CGA)Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 8 5 2 31Offshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGA42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 5 1 1742” Auto Boom (10000’) NA NA 10 Crew 20 Harvey 1 2 1.5 5 1 10.542” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 5 1 2042” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 5 1 14.542” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 5 1 131000’ Hydro-Fire Boom NA NA 8 Utility 40 Harvey 1 4 1.5 5 6 17.5Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs to GOMTravel toSpill SiteHrs toDeployTotalHrsEnterprise Marine Services LLC (available through contract with CGA)CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36CGA46’ FRV 5000 65 NA 4 Venice 1 0 1 2.4 0 4.446’ FRV 5000 65 NA 4 Leeville 1 0 2 3.8 0 6.846’ FRV 5000 65 NA 4 Galveston 1 0 0 13.8 0 14.846’ FRV 5000 65 NA 4 Lake Charles 1 0 1 10.2 0 12.2Trinity SWS 21500 249 NA 4 Morgan City 1 2 2 4.6 1 10.6Staging Area: CameronNearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGASWS Egmopol 3000 100 NA 3 Galveston 1 2 3.5 2 0 8.5SWS Egmopol 3000 100 NA 3 Houma 1 2 4 2 0 9SWS Marco 3588 34 NA 3 Houma 1 2 4 2 0 9SWS Marco 3588 20 NA 3 Lake Charles 1 2 1 2 0 6Rope Mop 77 2 0 3 Belle Chasse 1 2 4.5 2 0 9.5Shoreline ProtectionStaging Area: CameronShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeployment SiteHrs toDeployTotal HrsOMI Environmental (available through MSA)10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 2.5 2 3 9.510,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 2.5 2 3 9.510,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 1.25 2 3 8.25Beach Boom EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGABeach Boom (2000’) NA NA NA 6 Galveston 1 2 3.5 1 2 9.5Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 6 1 2 12Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 5.5 1 2 11.5Wildlife Response EDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotalHrsCGAWildlife Support Trailer NA NA NA 2 Houma 1 2 4 1 2 10Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 4.5 1 2 10.5Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 3.5 1 2 9.5Bird Scare Guns (24) NA NA NA 2 Houma 1 2 4 1 2 10Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 6 1 2 12Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 1 1 2 7Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 5.5 1 2 11.5Response Asset TotalOffshore EDRC 198,135Offshore Recovered Oil Storage 238,700Nearshore / Shallow Water EDRC 54,753Nearshore / Shallow Water Recovered Oil Storage 60,765

### Walter Oil & Gas Corporation Page J-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX J ENVIRONMENTAL MONITORING INFORMATION

(A) MONITORING SYSTEMS Anemometer, thermometer and barometer will be installed on Platform A. Daily and special updates from Wilken's Weather Service and Horizon Marine Eddie Watch for loop current information.

(B) INCIDENTAL TAKES There is no reason to believe that any of the endangered species or marine mammals as listed in the ESA will be “taken” as a result of the operations proposed under this plan.

It has been documented that the use of explosives and/or seismic devices can affect marine life. Operations proposed in this plan will not be utilizing either of these devices.

(C) FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY Ewing Bank Blocks 790 & 834 and Mississippi Canyon Block 793 are not located in the Flower Garden Banks National Marine Sanctuary; therefore, relevant information is not required in this DOCD.

### Walter Oil & Gas Corporation Page K-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 

## APPENDIX K

LEASE STIPULATIONS INFORMATION

Marine Protected Species The Marine Protected Species Stipulation is meant to reduce the potential taking of marine protected species. Walter will operate in accordance with JOINT NTL No. 2012-G01 to minimize the risk of vessel strikes to protected species and report observations of injured or dead protected species, and the prevention of intentional and/or accidental introduction of debris into the marine environment.

### Walter Oil & Gas Corporation Page L-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 APPENDIX L

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(A) MITIGATION MEASURES TAKEN TO MINIMIZE IMPACT TO MARINE AND COASTAL ENVIRONMENT Not required to be submitted with this DOCD.

(B) INCIDENTAL TAKES Walter will adhere to the requirements as set forth in the following documents, as applicable, to avoid or minimize impacts to any of the species listed in the ESA as a result of the operations conducted herein:

x JOINT NTL No. 2012-G01, “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”

x BSEE NTL No. 2012-G01, “Marine Trash and Debris Awareness and Elimination”

x JOINT NTL No. 2012-G02, “Implementation of Seismic Survey Mitigation Measures and Protected Species Observer Program”

### Walter Oil & Gas Corporation Page M-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 APPENDIX M RELATED FACILITIES AND OPERATIONS INFORMATION

(A) RELATED OCS FACILITIES AND OPERATIONS Walter proposes to install a 10" oil sales right-of-way pipeline approximately 63,000' in length to Shell's existing 12" Amberjack pipeline side valve assembly in Grand Isle Block 115. Walter also proposes to install a 10" gas sales right-of-way pipeline approximately 60,000' in length to Discovery Gas Transmissions 20" pipeline side valve assembly in Grand Isle Block 115. The maximum flow rates are 30,000 BOPD and 20 MMCFD. Shut-in times are 45 seconds.

All hydrocarbon handling equipment installed for testing and production operations will be designed, installed and operated to prevent pollution.

(B) TRANSPORTATION SYSTEM The oil production will be transported to shore to LOOP in Clovelly, Louisiana, and gas production will travel to the Discovery Plant at LaRose, Louisiana. No new nearshore or onshore pipelines or facilities will be constructed.

(C) PRODUCED LIQUID HYDROCARBONS TRANSPORTATION VESSELS There will not be any transfers of liquid hydrocarbons other than via pipeline.

### Walter Oil & Gas Corporation Page N-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 APPENDIX N SUPPORT VESSELS AND AIRCRAFT INFORMATION

(A) GENERAL Type Maximum Fuel Tank Capacity Maximum Number in Area at Any Time Trip Frequency or Duration Crew Boat 18,000 gallons 1 1 trip/week

Supply Boat 200,000 gallons 1 1 trip/month

Utility Boat 50,000 gallons 1 1 trip/month
Helicopter 265 gallons 1 1/day

The most practical, direct route from the shore base as permitted by weather and traffic conditions will be utilized.

(B) DIESEL OIL SUPPLY VESSELS Size of Fuel Supply Vessel Capacity of Fuel Supply Vessel Frequency of Fuel Transfers Route Fuel Supply Vessel Will Take 120 feet 50,000 gallons 1 per month Closest route from shorebase to block.

(C) DRILLING FLUID TRANSPORTATION Drilling fluid transportation is not required to be submitted with this DOCD.

(D) SOLID AND LIQUID WASTE TRANSPORTATION

“ Wastes You Will Transport and/or Dispose of Onshore” is included in this section as Attachment N-1.

(E) VICINITY MAP Enclosed as Attachment N-2 is a vicinity map showing the location of the activities proposed herein relative to the shoreline with the distan ce of the proposed activities from the shoreline and the primary route of the support vessels and aircraft that will be used when traveling between the onshore support facilities and Platform A

.please specify whether the amount reported is a total or per wellProjected generatedwasteSolid and LiquidWastes transportationType of Waste Composition Transport MethodName/Location ofFacility Amount Disposal MethodWill drilling occur ? If yes, fill in the muds and cuttings.EXAMPLE: Synthetic-based drilling fluid ormudinternal olefin, esterBelow deck storage tanks onoffshore support vesselsUS Liquids orNewparkFourchon,LouisianaX bbl/well RecycledOil-based drilling fluid or mud NA NA NA NA NASynthetic-based drilling fluid or mudSynthetic based drillingfluidsadhering to drill cuttingsfrom synthetic based holeintervals NA NA 5175 bbls/total GOMCuttings wetted with Water-based fluidCuttings generated while usingwater based drilling fluids NA NA 20,000 bbls/total GOMCuttings wetted with Synthetic-based fluidCuttings generated whileusuing synthetic based drillingfluids NA NA 13,330 bbls/total GOMCuttings wetted with oil-based fluids NA NA NA NA NAWaste DisposalATTACHMENT N-1WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHOREgSynthetic-based drilling fluid or mudSpent synthetic based drillingfluids and cuttingsTransport to shore base in cuttingsboxes on supply vesselNewparkEnvironmental,Cameron, LA. 5200/bbls totalreconditioned atmud plantWill you produce hydrocarbons? If yes fill in for produced sand.Produced sandNA NA NA NA NAEXAMPLE: trash and debris (recylables) Plastic, paper, aluminum barged in a storage binARC, New Iberia, LAXlb/well RecycledTrash and debrisWhile drilling Paper & PlasticGarbage bags on Supply or CrewBoatHOS Port, Fourchon,LA57 Bags at 40 cuft perbagLandfillUsed oilOily rags/absorbent pads,used oil filters 19 DOT Drums on Supply boatUS Liquids, Fourchon, LA7 DrumsIncinerationWash waterNA NA NA NA NAChemical product wastesWhile Drilling-Paint, solvents,light bulbsStorage Bins on Supply or CrewBoatNewparkEnvironmental,Cameron, LA 200 lb./yr Hazardous WasteBatteries5 gallon DrumNewparkEnvironmental,Cameron, LA10 gal/yr RecycledWill you have additional wastes that are not permitted for discharge? If yes,fill in the appropriate rows.

### Walter Oil & Gas Corporation Page O-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 APPENDIX O ONSHORE SUPPORT FACILITIES INFORMATION

(A) GENERAL Name Location Existing/New/Modified US Liquids or Newpark Port Fourchon, Louisiana Existing HOS Port EPS Port Fourchon, Louisiana Existing GIS Facility Port Fourchon, Louisiana Existing

(B) SUPPORT BASE CONSTRUCTION OR EXPANSION There will be no new construction of an onshore support base, nor will we expand the existing shorebase as a result of the operations proposed in this DOCD.

(C) SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE Not applicable.

(D) WASTE DISPOSAL “Wastes You Will Transport and/or Dispose of Onshore” is included in Appendix N as Attachment N-1.

### Walter Oil & Gas Corporation Page P-1 Joint Initial DOCD January, 2013 Ewing Bank Blocks 790 & 834, Mississippi Canyon Block 793 APPENDIX P COASTAL ZONE MANAGEMENT (CZMA) INFORMATION

Relevant enforceable policies were considered in certifying consistency for Louisiana. A certificate of Coastal Zone Management Consistency for the state of Louisiana is enclosed as Attachment P-1

.

### Walter Oil & Gas Corporation Page Q

- 1 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 APPENDIX Q ENVIRONMENTAL IMPACT ANALYSIS (EIA)

(A) IMPACT PRODUCING FACTORS ENVIRONMENTAL IMPACT ANALYSIS WORKSHEET

Environment

Resources Impact Producing Factors (IPFs) Categories and Examples Refer to recent GOM OCS Lease Sale EIS for a more complete list of IPFs

Emissions (air, noise, light, etc.) Effluents (muds, cutting, other discharges to

the water column or seafloor) Physical disturbances to the

seafloor (rig or anchor emplacements, etc.) Wastes sent to shore for treatment or disposal Accidents (e.g., oil spills, chemical spills, H 2 S releases) Discarded Trash & Debris

Site-specific at Offshore Location Designated topographic features (1) (1) (1)

Pinnacle Trend area live bottoms (2) (2) (2)
Eastern Gulf live bottoms (3) (3) (3)

Benthic communities X(4) Water quality X X X

Fisheries X X X
Marine Mammals X(8) X X(8) X
Sea Turtles X(8) X X(8) X Air quality X(9) Shipwreck sites (known or potential) (7)

Prehistoric archaeological sites X(7)

Vicinity of Offshore Location Essential fish habitat X X X(6) Marine and pelagic birds X X X Public health and safety (5)

Coastal and Onshore

Beaches X(6) X

Wetlands X(6) Shore birds and coastal nesting birds X(6) X

Coastal wildlife refuges X

Wilderness areas X

Footnotes for Environmental Impact Analysis Matrix

1) Activities that may affect a marine sanctuary or topographic feature. Specifically, if the well or platform site or any anchors will be on the seafloor within the:

### Walter Oil & Gas Corporation Page Q

- 2 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 o 4-mile zone of the Flower Garden Banks, or the 3-mile zone of Stetson Bank;

o 1000-m, 1-mile or 3-mile zone of any topographic fe ature (submarine bank) protected by the Topographic Features Stipulation attached to an OCS lease;

o Essential Fish Habitat (EFH) criteria of 50 0 ft. from any no-activity zone; or

o Proximity of any submarine bank (500 ft. buffer zone) with relief greater than 2 meters th at is not protected by the Topographic Features Stipulation attached to an OCS lease. 2) Activities with any bottom disturbance within an OCS lease block protected through the Live Bottom (Pinnacle Trend) Stipulation attached to an OCS lease. 3) Activities within any Eastern Gulf OCS block where seaf loor habitats are protected by the Live Bottom (Low-Relief) Stipulation attached to an OCS lease. 4) Activities on blocks designated by the BOEM as being in water depths 300 meters or greater. 5) Exploration or production activities wh ere H2S concentrations greater than 500 ppm might be encountered. 6) All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that you determine would impact these environmental resour ces. If the proposed action is located a sufficient distance from a resource that no impact would occur, the EIA can note that in a sentence or two. 7) All activities that involve seafloor disturbances, including an chor emplacements, in any OC S block designa ted by the BOEM as having high-probability for the o ccurrence of shipwrecks or prehistoric s ites, including such blocks that will be affected that are adjacent to the lease block in which your planned acti vity will occur. If th e proposed activities are located a sufficient distance from a shipwreck or a prehistoric site that no impact would occur, the EIA can note that in
a sentence or two. 8) All activities that you determine might have an adverse ef fect on endangered or threatened marine mammals or sea turtles or their critical habitats. 9) Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges.

### Walter Oil & Gas Corporation Page Q

- 3 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 (B) ANALYSIS

Site-Specific at Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 Proposed operations consist of the installation of Platform A and two (2) 10-inch right-of-way pipelines and the drilling and completion of six (6) wells. Operations will be conducted with a Platform Rig.

1. Designated Topographic Features 

### Potential IPFs on topographic features include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbances to the seafloor: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are approximately 38 miles from the closest designated Topographic Features Stipulation Block (Sackett Bank); therefore, no adverse impacts are expected.

Effluents: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are approximately 38 miles from the closest designated Topographic Features Stipulation Block (Sackett Bank); therefore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed activities (refer to statistics in Item 5 , Water Quality). Oil spills cause damage to benthic organisms only if the oil contacts the organisms. Oil from a surface spill can be driven into the water column; measurable amounts have been documented down to a 10 m depth. At this depth, the oil is found only at concentrations several orders of magnitude lower than the amount shown to have an effect on corals. Because the crests of topographic features in the Northern Gulf of Mexico are found below 10 m, no oil from a surface spill could reach their sessile biota. Oil from a subsurface spill is not applicable due to the distance of these blocks from a topographic area. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

There are no other IPFs (including emissions and wastes sent to shore for disposal) from the proposed activities, which could impact topographic features.

2. Pinnacle Trend Area Live Bottoms 

### Potential IPFs on pinnacle trend area live bottoms include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbances to the seafloor: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are approximately 114 miles from the closest live bottom (pinnacle trend) area; therefore, no adverse impacts are expected.

### Walter Oil & Gas Corporation Page Q

- 4 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 Effluents: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are approximately 114 miles from the closest live bottom (pinnacle trend) area; therefore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed activities (refer to statistics in Item 5 , Water Quality). Oil spills have the potential to foul benthic communities and cause lethal and sublethal effects on live bottom organisms. Oil from a surface spill can be driven into the water column; measurable amounts have been documented down to a 10 m depth. At this depth, the oil is found only at concentrations several orders of magnitude lower than the amount shown to have an effect on marine organisms. Oil from a subsurface spill is not applicable due to the distance of these blocks from a live bottom (pinnacle trend) area. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

There are no other IPFs (including emissions and wastes sent to shore for disposal) from the proposed activities which could impact a live bottom (pinnacle trend) area.

3. Eastern Gulf Live Bottoms 

### Potential IPFs on Eastern Gulf live bottoms include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbances to the seafloor: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are not located in an area characterized by the existence of live bottoms, and this lease does not contain a Live-Bottom Stipulation requiring a photo documentation survey and survey report.

Effluents: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are not located in an area characterized by the existence of live bottoms; therefore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed activities (refer to statistics in Item 5 , Water Quality). Oil spills cause damage to live bottom organisms only if the oil contacts the organisms. Oil from a surface spill can be driven into the water column; measurable amounts have been documented down to a 10 m depth. At this depth, the oil is found only at concentrations several orders of magnitude lower than the amount shown to have an effect on marine invertebrates. Oil from a subsurface spill is not applicable due to the distance of these blocks from a live bottom area. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

### Walter Oil & Gas Corporation Page Q

- 5 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 There are no other IPFs (including emissions and wastes sent to shore for disposal) from the proposed activities which could impact an Eastern Gulf live bottom area.

4. Benthic Communities 

### Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are located in water depths 984 feet (300 meters) or greater. IPFs that could result in impacts to benthic communities from the proposed activities include physical disturbances to the seafloor.

Physical disturbances to the seafloor: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are approximately 12 miles from a known benthic community site (BenthicEwing Bank Block 1010), listed in NTL 2009-G40. Additionally, Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are approximately 12 miles from another known benthic community site (BenthicMississippi Canyon Block 969), listed in NTL 2009-G40. This Joint Initial Development Operations Coordination Document submittal includes the required maps, analyses, and statement(s). The proposed activities will be conducted in accordance with NTL 2009- G40, which will ensure that features or areas that could support high-density benthic communities will not be impacted.

There are no other IPFs (including emissions, effluents, wastes sent to shore for disposal, or accidents) from the proposed activities which could impact benthic communities.

5. Water Quality 

### IPFs that could result in water quality degradation from the proposed operations in Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 include disturbances to the seafloor, effluents and accidents.

Physical disturbances to the seafloor: Bottom area disturbances resulting from the emplacement of drill rigs, the drilling of wells and the installation of platforms and pipelines would increase water-column turbidity and re-suspension of any accumulated pollutants, such as trace metals and excess nutrients. This would cause short-lived impacts on water quality conditions in the immediate vicinity of the emplacement operations.

Effluents: Levels of contaminants in drilling muds and cuttings and produced water discharges, discharge-rate restrictions and monitoring and toxicity testing are regulated by the EPA NPDES permit, thereby eliminating many significant biological or ecological effects. Operational discharges are not expected to cause significant adverse impacts to water quality.

Accidents: Oil spills have the potential to alter offshore water quality; however, it is unlikely that an accidental surface or subsurface spill would occur from the proposed activities. Between 1980 and 2000, OCS operations produced 4.7 billion barrels of oil and spilled only 0.001 percent of this oil, or 1

### Walter Oil & Gas Corporation Page Q

- 6 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 bbl for every 81,000 bbl produced. The spill risk related to a diesel spill from drilling operations is even less. Between 1976 and 1985, (years for which data were collected), there were 80 reported diesel spills greater than one barrel associated with drilling activities. Considering that there were 11,944 wells drilled, this is a 0.7 percent probability of an occurrence. If a spill were to occur, the water quality of marine waters would be temporarily affected by the dissolved components and small oil droplets. Dispersion by currents and microbial degradation would remove the oil from the water column and dilute the constituents to background levels. Historically, changes in offshore water quality from oil spills have only been detected during the life of the spill and up to several months afterwards. Most of the components of oil are insoluble in water and therefore float. The activities proposed in this plan will be covered by Walter’s Regional Oil Spill Response Plan (refer to information submitted in Appendix I ).

There are no other IPFs (including emissions, physical disturbances to the seafloor, and wastes sent to shore for disposal) from the proposed activities which could cause impacts to water quality.

6. Fisheries 

### IPFs that could cause impacts to fisheries as a result of the proposed operations in Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 include physical disturbances to the seafloor, effluents and accidents.

Physical disturbances to the seafloor: The emplacement of a structure or drilling rig results in minimal loss of bottom trawling area to commercial fishermen. Pipelines cause gear conflicts which result in losses of trawls and shrimp catch, business downtime and vessel damage. Most financial losses from gear conflicts are covered by the Fishermen’s Contingency Fund (FCF). The emplacement and removal of facilities are not expected to cause significant adverse impacts to fisheries.

Effluents: Effluents such as drilling fluids and cuttings discharges contain components and properties which are detrimental to fishery resources. Moderate petroleum and metal contamination of sediments and the water column can occur out to several hundred meters down-current from the discharge point. Offshore discharges are expected to disperse and dilute to very near background levels in the water column or on the seafloor within 3,000 m of the discharge point, and are expected to have negligible effect on fisheries.

Accidents: An accidental oil spill has the potential to cause some detrimental effects on fisheries; however, it is unlikely that such an event would occur from the proposed activities (refer to Item 5

, Water Quality). The effects of oil on mobile adult finfish or shellfish would likely be sublethal and the extent of damage would be reduced to the capacity of adult fish and shellfish to avoid the spill, to metabolize hydrocarbons, and to excrete both metabolites and parent compounds. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

### Walter Oil & Gas Corporation Page Q

- 7 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 There are no IPFs from emissions, or wastes sent to shore for disposal from the proposed activities which could cause impacts to fisheries.

7. Marine Mammals 

### GulfCet II studies revealed that cetaceans of the continental shelf and shelf-edge were almost exclusively bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and pygmy killer whale, Risso’s dolphin, rough-toothed dolphin, and Cuvier’s beaked whale, occurred most frequently along the upper slope in areas outside of anticyclones. IPFs that could cause impacts to marine mammals as a result of the proposed operations in Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 include emissions, effluents, discarded trash and debris, and accidents.

Emissions: Noises from drilling activities, support vessels and helicopters may elicit a startle reaction from marine mammals. This reaction may lead to disruption of marine mammals’ normal activities. Stress may make them more vulnerable to parasites, disease, environmental contaminants, and/or predation (Majors and Myrick, 1990). There is little conclusive evidence for long-term displacements and population trends for marine mammals relative to noise.

Effluents: Drilling fluids and cuttings discharges contain components which may be detrimental to marine mammals. Most operational discharges are diluted and dispersed upon release. Any potential impact from drilling fluids would be indirect, either as a result of impacts on prey items or possibly through ingestion in the food chain (API, 1989).

Discarded trash and debris: Both entanglement in, and ingestion of debris have caused the death or serious injury of marine mammals (Laist, 1997; MMC, 1999). The limited amount of marine debris, if any, resulting from the proposed activities is not expected to substantially harm marine mammals. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA).

Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handling and disposing of small items and packaging materials, particularly those made of non-biodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore personnel, including contractors and other support services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed

### Walter Oil & Gas Corporation Page Q

- 8 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

Accidents: Collisions between support vessels and cetaceans would be unusual events, however should one occur, death or injury to marine mammals is possible. Contract vessel operators can avoid marine mammals and reduce potential deaths by maintaining a vigilant watch for marine mammals and maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to help identify the twenty-eight species of whales and dolphins, and the single species of manatee that may be encountered in the Gulf of Mexico OCS. Vessel crews must report sightings of any injured or dead protected marine mammal species immediately, regardless of whether the injury or death is caused by their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional Office at (727) 824-5312, or the Marine Mammal Stranding Network at (305) 862- 2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@boemre.gov . If the vessel is the responsible party, it is required to remain available to assist the respective salvage and stranding network as needed.

Oil spills have the potential to cause sublethal o il-related injuries and spill-related deaths to marine mammals. However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Oil spill response activities may increase vessel traffic in the area, which could add to changes in cetacean behavior and/or distribution, thereby causing additional stress to the animals. The effect of oil dispersants on cetaceans is not known. The acute toxicity of oil dispersant chemicals included in Walter’s OSRP is considered to be low when compared with the constituents and fractions of crude oils and diesel products. The activities proposed in this plan will be covered by Walter’s OSRP (refer to information submitted in accordance with Appendix I ).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed activities which could impact marine mammals.

8. Sea Turtles 

### IPFs that could cause impacts to sea turtles as a result of the proposed operations include emissions, effluents, discarded trash and debris, and accidents. GulfCet II studies sighted most loggerhead, Kemp’s ridley and leatherback sea turtles over shelf waters. Historically these species have been sighted up to the shelf’s edge. They appear to be more abundant east of the Mississippi River than they are west of the river (Fritts et al., 1983b; Lohoefener et al., 1990). Deep waters may be used by all species as a transitory habitat.

Emissions: Noise from drilling activities, support vessels, and helicopters may elicit a startle reaction from sea turtles, but this is a temporary disturbance.

### Walter Oil & Gas Corporation Page Q

- 9 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 Effluents: Drilling fluids and cuttings discharges are not known to be lethal to sea turtles. Most operational discharges are diluted and dispersed upon release. Any potential impact from drilling fluids would be indirect, either as a result of impacts on prey items or possibly through ingestion in the food chain (API, 1989).

Discarded trash and debris: Both entanglement in, and ingestion of, debris have caused the death or serious injury of sea turtles (Balazs, 1985). The limited amount of marine debris, if any, resulting from the proposed activities is not expected to substantially harm sea turtles. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercisedwhen handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore personnel, including contractors and other support services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

Accidents: Collisions between support vessels and sea turtles would be unusual events, however should one occur, death or injury to sea turtles is possible. Contract vessel operators can avoid sea turtles and reduce potential deaths by maintaining a vigilant watch for sea turtles and maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to help identify the five species of sea turtles that may be encountered in the Gulf of Mexico OCS. Vessel crews must report sightings of any injured or dead protected sea turtle species immediately, regardless of whether the injury or death is caused by their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional Office at (727) 824-5312, or the Marine Mammal Stranding Network at (305) 862-2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@boemre.gov . If the vessel is the responsible part y, it is required to remain available to assist the respective salvage and stranding network as needed.

All sea turtle species and their life stages are vulnerable to the harmful effects of oil through direct contact or by fouling of their food. Exposure to oil can be fatal, particularly to juveniles and hatchlings.

### Walter Oil & Gas Corporation Page Q

- 10 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Oil spill response activities may increase vessel traffic in the area, which could add to the possibility of collisions with sea turtles. The activities proposed in this plan will be covered by Walter’s Regional Oil Spill Response Plan (refer to information submitted in accordance with Appendix I ).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed activities which could impact sea turtles.

9. Air Quality 

### Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are located approximately 99 miles from the Breton Wilderness Area and approximately 63 miles from shore. Applicable emissions data is included in Appendix H of the Plan.

There would be a limited degree of air quality degradation in the immediate vicinity of the proposed activities. Plan Emissions for the proposed activities do not exceed the annual exemption levels as set forth by BOEM. Accidents and blowouts can release hydrocarbons or chemicals, which could cause the emission of air pollutants. However, these releases would not impact onshore air quality because of the prevailing atmospheric conditions, emission height, emission rates, and the distances of Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 from the coastline. There are no other IPFs (including effluents, physical disturbances to the seafloor, wastes sent to shore for treatment or disposal) from the proposed activities which would impact air quality.

10. Shipwreck Sites (known or potential) 

### IPFs that could impact known or unknown shipwreck sites as a result of the proposed operations in Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 include disturbances to the seafloor and accidents (oil spill). Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are not located in or adjacent to OCS blocks designated by BOEM as having a high probability for occurrence of shipwrecks. Walter will report to BOEM the discovery of any evidence of a shipwreck and make every reasonable effort to preserve and protect that cultural resource. There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or disposal, or accidents) from the proposed activities which could impact shipwreck sites.

Accidents: An accidental oil spill has the potential to cause some detrimental effects to shipwreck sites if the release were to occur subsea. However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). The activities proposed in this plan will be covered by Walter’s Regional Oil Spill Response Plan (refer to information submitted in accordance with Appendix I ).

Although Ewing Bank Block 834 and Mississippi Canyon Block 793 have been surveyed in an existing Environmental Assessment grid (Deepwater Grid 12), Ewing Bank Block 790 has not yet been

### Walter Oil & Gas Corporation Page Q

- 11 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 included in such an assessment. Therefore, Walter will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning sonar within a minimum 500’ radius of the proposed well location(s) in Ewing Bank Block 790 prior to or upon commencement of operations. These locations will be certified by an authorized marine archaeo logist and by Walter to be clear of seafloor archaeological resources, including historic shipwrecks. Copies of the certifications and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be encountered, Walter will contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural

resource.

There are no other IPFs (including emissions, effluents, or wastes sent to shore for treatment or disposal) from the proposed activities that could cause impacts to shipwreck sites.

11. Prehistoric Archaeological Sites 

### IPFs that could cause impacts to prehistoric archaeological sites as a result of the proposed operations in Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are physical disturbances to the seafloor and accidents (oil spills).

Physical Disturbances to the seafloor: Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 are located inside the Archaeological Prehistoric high probability lines. Walter will report to BOEM the discovery of any object of prehistoric archaeological significance and make every reasonable effort to preserve and protect that cultural resource.

Accidents: An accidental oil spill has the potential to cause some detrimental effects to prehistoric archaeological sites if the release were to occur subsea. However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). The activities proposed in this plan will be covered by Walter’s Regional Oil Spill Response Plan (refer to information submitted in accordance with Appendix I ).

Although Ewing Bank Block 834 and Mississippi Canyon Block 793 have been surveyed in an existing Environmental Assessment grid (Deepwater Grid 12), Ewing Bank Block 790 has not yet been included in such an assessment. Therefore, Walter will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning sonar within a minimum 500’ radius of the proposed well location(s) in Ewing Bank Block 790 prior to or upon commencement of operations. These locations will be certified by an authorized marine archaeo logist and by Walter to be clear of seafloor archaeological resources. Copies of the certifications and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be encountered, Walter will contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural resource.

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or disposal) from the proposed activities that could cause impacts to prehistoric archaeological sites.

Vicinity of Offshore Location

### Walter Oil & Gas Corporation Page Q

- 12 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 1. Essential Fish Habitat (EFH) 

### IPFs that could cause impacts to EFH as a result of the proposed operations in Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 include physical disturbances to the seafloor, effluents and accidents. EFH includes all estuarine and marine waters and substrates in the Gulf of Mexico.

Physical disturbances to the seafloor: The Live Bottom Low Relief Stipulation, the Live Bottom (Pinnacle Trend) Stipulation, and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential impacts on live-bottom communities and EFH from bottom disturbing activities (e.g., anchoring, structure emplacement and removal).

Effluents: The Live Bottom Low Relief Stipulation, the Live Bottom (Pinnacle Trend) Stipulation,and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential impacts on livebottom communities and EFH from operational waste discharges. Levels of contaminants in drilling muds and cuttings and produced-water discharges, discharge-rate restrictions, and monitoring and toxicity testing are regulated by the EPA NPDES permit, thereby eliminating many significant biological or ecological effects. Operational discharges are not expected to cause significant adverse impacts to EFH.

Accidents: An accidental oil spill has the potential to cause some detrimental effects on EFH. Oil spills that contact coastal bays and estuaries, as well as OCS waters when pelagic eggs and larvae are present, have the greatest potential to affect fisheries. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

There are no other IPFs (including emissions, or wastes sent to shore for treatment or disposal) from the proposed activities which could impact essential fish habitat.

2. Marine and Pelagic Birds 

### IPFs that could impact marine birds as a result of the proposed activities include air emissions, accidental oil spills, and discarded trash and debris from vessels and the facilities.

Emissions: Emissions of pollutants into the atmosphere from these activities are far below concentrations which could harm coastal and marine birds.

Accidents: An oil spill would cause localized, low-level petroleum hydrocarbon contamination. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5

, Water Quality). Marine and pe lagic birds feeding at the spill location may experience chronic, nonfatal, physiological stress. It is expected that few, if any, coastal and marine birds would actually

### Walter Oil & Gas Corporation Page Q

- 13 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 be affected to that extent. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

Discarded trash and debris : Marine and pelagic birds could become entangled and snared in discarded trash and debris, or ingest small plastic debris, which can cause permanent injuries and death. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handling and disposing of small items and packaging materials, particularly those made of non-biodegradable, environmentally persistent materials such as plastic or glass. Informational placards will be posted on all vessels and facilities having sleeping or foodpreparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01. Debris, if any, from these proposed activities will seldom interact with marine and pelagic birds; therefore, the effects will be negligible.

There are no other IPFs (including effluents, physical disturbances to the seafloor, or wastes sent to shore for treatment or disposal) from the proposed activities which could impact marine and pelagic birds.

3. Public Health and Safety Due to Accidents. 

### There are no IPFs (emissions, effluents, physical disturbances to the seafloor, wastes sent to shore for treatment or disposal or accidents, including an accidental H2S releases) from the proposed activities which could cause impacts to public health and safety. In accordance with NTL No.’s 2008-G04, 2009-G27, and 2009-G31, sufficient information is included in Appendix D to justify our request that our proposed activities be classified by BSEE as H 2 

### S absent.

Coastal and Onshore

1. Beaches 

### IPFs from the proposed activities that could cause impacts to beaches include accidents (oil spills) and discarded trash and debris.

### Walter Oil & Gas Corporation Page Q

- 14 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches and associated resources. Due to the distance from shore (63 miles) and the response capabilities that would be implemented, no significant adverse impacts are expected. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

Discarded trash and debris: Trash on the beach is recognized as a major threat to the enjoyment and use of beaches. There will only be a limited amount of marine debris, if any, resulting from the proposed activities. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handling and disposing of small items and packaging materials, particularly those made of non-biodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore personnel, including contractors and other support services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to shore for treatment or disposal) from the proposed activities which could impact beaches.

2. Wetlands 

### IPFs from the proposed activities that could cause impacts to wetlands include accidents (oil spills) and discarded trash and debris.

Accidents: It is unlikely that an oil spill would occur from the proposed activities (refer to Item 5

, Water Quality). Due to the distance from shore (63 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

Discarded trash and debris: There will only be a limited amount of marine debris, if any, resulting from the proposed activities. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and

### Walter Oil & Gas Corporation Page Q

- 15 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handling and disposing of small items and packaging materials, particularly those made of non-biodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore personnel, including contractors and other support services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to shore for treatment or disposal) from the proposed activities which could impact wetlands.

3. Shore Birds and Coastal Nesting Birds


### Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Given the distance from shore (63 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

Discarded trash and debris: Coastal and marine birds are highly susceptible to entanglement in floating, submerged, and beached marine debris: specifically plastics. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercisedwhen handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or foodpreparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It”

### Walter Oil & Gas Corporation Page Q

- 16 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to shore for treatment or disposal) from the proposed activities that could cause impacts to shore birds and coastal nesting birds.

4. Coastal Wildlife Refuges


### Accidents: An accidental oil spill from the proposed activities could cause impacts to coastal wildlife refuges. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, Water Quality). Due to the distance from shore (63 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I ).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handling and disposing of small items and packaging materials, particularly those made of non-biodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or foodpreparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to shore for treatment or disposal) from the proposed activities that could cause impacts to coastal wildlife refuges.

5. Wilderness Areas


### Accidents: An accidental oil spill from the proposed activities could cause impacts to wilderness areas. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Due to the distance from the nearest designated Wilderness Area (99 miles) and the

### Walter Oil & Gas Corporation Page Q

- 17 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 response capabilities that would be implemented, no significant adverse impacts are expected. The activities proposed in this plan will be covered by Walter’s Regional OSRP (refer to information submitted in Appendix I).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Walter will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handling and disposing of small items and packaging materials, particularly those made of non-biodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or foodpreparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from Walter management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to shore for treatment or disposal) from the proposed activities that could cause impacts to wilderness

areas.

6. Other Environmental Resources Identified 

### There are no other environmental resources identified for this impact assessment.

(C) IMPACTS ON PROPOSED ACTIVITIES The site–specific environmental conditions have been taken into account for the proposed activities. No impacts are expected on the proposed activities from site-specific environmental conditions.

(D) ENVIRONMENTAL HAZARDS During the hurricane season, June through November, the Gulf of Mexico is impacted by an average of ten tropical storms (39-73 mph winds), of which six become hurricanes ( > 74 mph winds). Due to their locations in the gulf, Ewing Bank Block 790, Ewing Bank Block 834 and Mississippi Canyon Block 793 may experience hurricane and tropical storm force winds, and related sea currents. These factors can adversely impact the integrity of the operations covered by this plan. A significant storm may present physical hazards to operators and vessels, damage exploration or production equipment, or result in the release of hazardous materials (including hydrocarbons). Additionally, the displacement of equipment may disrupt the local benthic habitat and pose a threat to local species.

### Walter Oil & Gas Corporation Page Q

- 18 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 The following preventative measures included in this plan may be implemented to mitigate these impacts:

1. Drilling & completion a. Secure well b. Secure rig / platform c. Evacuate personnel

Drilling activities will be conducted in accordance with NTL No.’s 2008-G09, 2009-G10, and 2010- N10.

2. Platform / Structure Installation Operator will not conduct platform / structure installation operations during Tropical Storm or Hurricane threat.

3. Pipeline Installation Operator will not conduct pipeline installation operations during Tropical Storm or Hurricane threat.

(E) ALTERNATIVES No alternatives to the proposed activities were considered to reduce environmental impacts.

(F) MITIGATION MEASURES No mitigation measures other than those required by regulation will be employed to avoid, diminish, or eliminate potential impacts on environmental resources.

(G) CONSULTATION No agencies or persons were consulted regarding potential impacts associated with the proposed activities. Therefore, a list of such entities has not been provided.

(H) PREPARER(S)

Matt Harlan J. Connor Consulting, Inc. 16225 Park Ten Place, Suite 700 Houston, TX 77084 (281) 578-3388 matt.harlan@jccteam.com

### Walter Oil & Gas Corporation Page Q

- 19 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 (I) REFERENCES
Authors:

American Petroleum Institute (API). 1989. Effects of offshore petroleum operations on cold water marine mammals: a literature review. Washington, DC: American Petroleum Institute. 385 pp.

Balazs, G.H. 1985. Impact of ocean debris on marine turtles: entanglement and ingestion. In: Shomura, R.S. and H.O. Yoshida, eds. Proceedings, Workshop on the Fate and Impact of Marine Debris, 26-29 November 1984, Honolulu, HI. U.S. Dept. of Commerce. NOAA Tech. Memo. NOAA-TMNMFS-SWFC-54. Pp 387-429.

Burke, C.J. and J.A. Veil. 1995. Potential benefits from regulatory consideration of synthetic drilling muds. Environmental Assessment Division, Argonne National Laboratory, ANL/EAD/TM-43.

Daly, J.M. 1997. Controlling the discharge of synthetic-based drilling fluid contaminated cuttings in waters of the United States. U.S. Environmental Protection Agency, Office of Water. Work Plan, June 24, 1997.

Hansen, D.J. 198l. The relative sensitivity of seabird populations in Alaska to oil pollution. U.S. Dept. of the Interior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLM-YK-ES-81- 006-1792.

Laist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris including a comprehensive list of species with entanglement and ingestion records. In: Coe, J.M. and D.B. Rogers, eds. Marine debris: so urces, impacts, and solutions. New York, NY: Springer-Verlag. Pp. 99-139.

Majors, A.P. and A.C. Myrick, Jr. 1990. Effects of noise on animals: implications for dolphins exposed to seal bombs in the eastern tropical Pacific purse-seine fishery–an annotated bibliography. NOAA Administrative Report LJ-90-06.

Marine Mammal Commission. 1999. Annual report to Congress – 1998.

Piatt, J.F., C.J. Lensink, W. Butler, M. Kendziorek, and D.R. Nysewander. 1990. Immediate impact of the Exxon Valdez oil spill on marine birds. The Auk. 107 (2): 387-397.

Vauk , G., E. Hartwig, B. Reineking, and E. Vauk-Hentzelt. 1989. Losses of seabirds by oil pollution at the German North Sea coast. Topics in Marine Biology. Ros, J.D, ed. Scient. Mar. 53 (2-3): 749- 754.

Vermeer, K. and R. Vermeer, 1975 Oil threat to birds on the Canadian west coast. The Canadian Field-Naturalist. 89:278-298.

Although not cited, the following were utilized in preparing this EIA:

### Walter Oil & Gas Corporation Page Q

- 20 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 x Hazard Surveys

x BOEM EIS’s:

o GOM Deepwater Operations and Activities. Environmental Assessment. MMS 2000-001

o GOM Central and Western Planning Areas Sales 166 and 168 Final Environmental Impact Statement. MMS 96-0058.

### Walter Oil & Gas Corporation Page R -1 Joint Initial DOCD January, 2013 Ewing Bank Block 790, 834, Mississippi Canyon Block 793 APPENDIX R ADMINISTRATIVE INFORMATION

(A) EXEMPTED INFORMATION DESCRIPTION The proposed bottom-hole locations of the planned wells have been removed from the public information copy of the DOCD as well as any discussions of the target objectives, geologic or geophysical data, and any interpreted geology.

(B) BIBLIOGRAPHY 1. Initial EP for Ewing Bank Block 834, Control N-9234 2. Supplemental EP for Ewing Bank Block 834, Control S-7359