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

Site Type/Name Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk

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 H2S 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 25 450

Production Platform 1300 1 1300 230

Fuel Oil (Marine 

Diesel)

SemiSubmersible 18,000 4 70,000 450

(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 Distance 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 Conservation Information Document to accompany this plan? Yes x No

Do you propose to use new or unusual technology to conduct your activities? Yes x No

Do you propose any facility that will serve as a host facility for deepwater subsea development? Yes x No

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

Have all of the surface locations of your proposed activities been 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: 280 09' 37.216" 

Longitude: 890 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 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEM collects this information as part of an Walter Oil & Gas Corporation’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 currently 

valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this 

form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We 

estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 hours 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 structure, 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: 280 09' 37.216" 

Longitude: 890 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 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEM collects this information as part of an Walter Oil & Gas Corporation’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 currently 

valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this 

form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We 

estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 hours 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 structure, reference previous name): A002 Subsea Completion 

Anchor Radius (if applicable) in feet: 4,600' May be drilled with either a semi-submersible 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: 280

 09' 37.218" 

Longitude: 890 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 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEM collects this information as part of an Walter Oil & Gas Corporation’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 currently 

valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this 

form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We 

estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 hours 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 structure, reference previous 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: 280

 09' 37.152" 

Longitude: 890 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 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEM collects this information as part of an Walter Oil & Gas Corporation’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 currently 

valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this 

form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We 

estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 hours 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 structure, 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: 280

 09' 37.289" 

Longitude: 890 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 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEM collects this information as part of an Walter Oil & Gas Corporation’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 currently 

valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this 

form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We 

estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 hours 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 structure, 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: 280

 09' 37.158" 

Longitude: 890 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 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEM collects this information as part of an Walter Oil & Gas Corporation’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 currently 

valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this 

form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We 

estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 hours 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 structure, reference previous 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: 280

 09' 37.087" 

Longitude: 890 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 (44 U.S.C. Chapter 35) requires us to 

inform you that BOEM collects this information as part of an Walter Oil & Gas Corporation’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 currently 

valid Office of Management and Budget Control Number. The use of this form is voluntary. The public reporting burden for this 

form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We 

estimate that burden to average 600 hours per response, or 640 with an acWaltering EP (1,000 hours 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.
Attachment A-2

Attachment 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 weight 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. 

Attachment B-1
Page Two 

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 

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 and 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 company 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. 
Attachment 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 H2S during the proposed 

operations.

(B) CLASSIFICATION 

Walter requests BSEE classify the Ewing Bank Blocks 790 and 834 and Mississippi Canyon 

Block 793 as H2S 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 relief 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. 
®33

33

EWING BANK BLOCK 834 (OCS-G27982)

2,000ft Radius

4 6, 00ft Max mi um Anchor Radius

1

,000ft Buffer Zone

EWING BANK BLOCK 790 (OCS-G33140)

, 1

00

' 0

02

, 1

'

0

Proposed EW790-A002 Well

EW834-2

EW834-1

EW789-1

2,610,000

2,615,000

2,620,000

2,625,000

2,630,000

2,635,000

10,240,00010,235,00010,230,00010,225,000

89°55'0"W

89°56'0"W

89°57'0"W

89°58'0"W

89°59'0"W

28°11'0"N

28°10'0"N

28°9'0"N28°8'0"N

Lund

Lloyd Ridge

Green Canyon Atwater Valley Garden Banks

De Soto Canyon

Henderson

Destin Dome

Mississippi Canyon

Walker Ridge

East Breaks

Keathley Canyon

Louisiana Texas Florida

Study Area

LEGEND

Chart scale 1" = 1,000'

3D GEOHAZARD ASSESSMENT

GULF OF MEXICO

EWING BANK

BLOCK 834

GEODETIC INFORMATION

SEABED DEPTH - ANCHOR RADIUS (PROPOSED EW790-A002)

CHART 1

0 1,000 2,000 3,000 500 Feet0 300 600 900 150 Meters

Proposed EW 790- A002 well location2,623,629 ft E/10,231,477 ft N

®3333

Seabed Depth (Feet)

REV DATE REMARKS AUTHOR DRAWN CHECKED

SURVEY DATE N/A REPORT REF 7071 CHART NO 7071.01

0 JANUARY 10, 2013 FINAL JR VC ARH

Not to scale

Block boundaries

±

Prepared by: Gardline Surveys, Inc. 1500 Bingle Road, Houston, Texas, 77055. Telephone: 713.481.4630

Notes

Depth in feet below sea surface to seabed, contoured at 25 ft intervals.

-1310

6 Existing Well

Pipelines 

Pipelines 

Pipelines 

Safety fairways 

Study area boundary

Coordinate System: NAD 1927 UTM Zone 15NProjection: Transverse MercatorDatum: North American 1927 Units: Foot US

False Easting: 1,640,416.6667False Northing: 0.0000Central Meridian: -93.0000Scale Factor: 0.9996Latitude Of Origin: 0.0000

Attachment F-1
®33

33

EWING BANK BLOCK 834 (OCS-G27982)

2,000ft Radius

4 6, 00ft Max mi um Anchor Radius

1

,000ft Buffer Zone

EWING BANK BLOCK 790 (OCS-G33140)

Proposed EW790-A002 Well

EW834-2

EW834-1

EW789-1

2,610,000

2,615,000

2,620,000

2,625,000

2,630,000

2,635,000

10,240,00010,235,00010,230,00010,225,000

89°55'0"W

89°56'0"W

89°57'0"W

89°58'0"W

89°59'0"W

28°11'0"N

28°10'0"N

28°9'0"N28°8'0"N

Lund

Lloyd Ridge

Green Canyon Atwater Valley Garden Banks

De Soto Canyon

Henderson

Destin Dome

Mississippi Canyon

Walker Ridge

East Breaks

Keathley Canyon

Louisiana Texas Florida

Study Area

LEGEND

Chart scale 1" = 1,000'

3D GEOHAZARD ASSESSMENT

GULF OF MEXICO

EWING BANK

BLOCK 834

GEODETIC INFORMATION

SEABED MORPHOLOGY - ANCHOR RADIUS (PROPOSED EW790-A002)

CHART 2

0 1,000 2,000 3,000 500 Feet0 300 600 900 150 Meters

Proposed EW 790- A002 well location2,623,629 ft E/10,231,477 ft N

®3333

Illumintated from the northeast at 45° above horizontal

REV DATE REMARKS AUTHOR DRAWN CHECKED

SURVEY DATE N/A REPORT REF 7071 CHART NO 7071.02

0 JANUARY 10, 2013 FINAL JR VC ARH

Not to scale

Block boundaries

±

Prepared by: Gardline Surveys, Inc. 1500 Bingle Road, Houston, Texas, 77055. Telephone: 713.481.4630

Notes

6 Existing Well

Pipelines 

Pipelines 

Pipelines 

Safety fairways 

Study area boundary

Seabed faults, ticks denote down throw side

Coordinate System: NAD 1927 UTM Zone 15NProjection: Transverse MercatorDatum: North American 1927 Units: Foot US

False Easting: 1,640,416.6667False Northing: 0.0000Central Meridian: -93.0000Scale Factor: 0.9996Latitude Of Origin: 0.0000
®33

33

EWING BANK BLOCK 834 (OCS-G27982)

2,000ft Radius

4 6, 00ft Max mi um Anchor Radius

1

,000ft Buffer Zone

EWING BANK BLOCK 790 (OCS-G33140)

Proposed EW790-A002 Well

EW834-2

EW834-1

EW789-1

2,610,000

2,615,000

2,620,000

2,625,000

2,630,000

2,635,000

10,240,00010,235,00010,230,00010,225,000

89°55'0"W

89°56'0"W

89°57'0"W

89°58'0"W

89°59'0"W

28°11'0"N

28°10'0"N

28°9'0"N28°8'0"N

Lund

Lloyd Ridge Green Canyon Atwater Valley Garden Banks

De Soto Canyon

Henderson

Destin Dome

Mississippi Canyon

Walker Ridge Keathley Canyon

East Breaks

Louisiana Texas Florida

Study Area

LEGEND

Chart scale 1" = 1,000'

3D GEOHAZARD ASSESSMENT

GULF OF MEXICO

EWING BANK

BLOCK 834

GEODETIC INFORMATION

SEABED AMPLITUDE - ANCHOR RADIUS (PROPOSED EW790-A002)

CHART 3

0 1,000 2,000 3,000 500 Feet0 300 600 900 150 Meters

Proposed EW 790- A002 well location2,623,629 ft E/10,231,477 ft N ®33

33

Relative Seabed Amplitude

REV DATE REMARKS AUTHOR DRAWN CHECKED

SURVEY DATE N/A REPORT REF 7071 CHART NO 7071.03

0 JANUARY 10, 2013 FINAL JR VC ARH

Not to scale

Block boundaries

±

Prepared by: Gardline Surveys, Inc. 1500 Bingle Road, Houston, Texas, 77055. Telephone: 713.481.4630

Notes

6 Existing Well

Pipelines 

Pipelines 

Pipelines 

Safety fairways 

Study area boundary

Coordinate System: NAD 1927 UTM Zone 15NProjection: Transverse MercatorDatum: North American 1927 Units: Foot US

False 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 amount

Projected generated waste Projected ocean discharges 

Type of Waste Composition Projected Amount Discharge rate Discharge Method Answer yes or no

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

EXAMPLE: Cuttings wetted with synthetic

based fluid 

Cuttings generated while

using synthetic based X bbl/well X bbl/day/well discharge overboard No

Water-based drilling fluid

Water based drilling fluids 30,000 bbls/total 500 bbls/per well/hour Discharge overboard No

Cuttings wetted with water-based fluid

Cuttings generated while 

using water based drilling

fluids 20,000 bbs/total

12 bbls/hr/well including drilling fluid Discharge overboard No

Synthetic based drilling fluids

Synthetic based drilling fluids adhering to drillcuttings from synthetic based hole intervals intervals 5175 bbls/total 12 bbls/day/well

Treated cuttings will be discharged overoard while drilling SBM interval. Cuttings will pass through cuttings dryer to reduce ROC percentage in compliance with EPA and then shunt through downpipe below water line. NO

Drill cuttings generated while using synthetic based drilling fluids

Cuttings generated while susing synthetic based drilling fluids 13,330bbls total 30 bbls/day/well

Treated cuttings will be discharged overoard while drilling SBM interval. Cuttings will pass through cuttings dryer to reduce ROC percentage in compliance with EPA and then shunt through downpipe below water line. No

Will humans be there? If yes, expect conventional waste

EXAMPLE: Sanitary waste water

Sanitary waste from living quarters X bbl/well X bbl/hr/well chlorinate and discharge overboard No

ATTACHMENT G-1

WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM

Projected 

Downhole 

Disposal

Domestic waste Gray Water 8,000 bbls/total 10 bbls/hr/well

Prcessed through DNV Class approved 

treatment tank and discharged

Sanitary waste

Human body treat waste discharged from toilets 2,500 bbls total 3 bbls/hr/well chlorinate and discharge overboard No

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

Deck Drainage Rain water and rig wash 28,000 bbls total

15 bbls/hr /dependent on rainfall

Oily water is treated in one of four (4) separators 

and discharged through Port-side caisson (cuttings chute) below sea level No

Will you conduct well treatment, completion, or workover? 

Well treatment fluids

Viscous and csg wash 

spacers using HEC and 

small amounts sodium 200 bbls/well 50 bbls/day/well discharge overboard No

Well completion fluids Calcium Chloride 3000 bbls total 50 bbls/day/well discharge overboard NoWorkover fluids NA NA NA NA No

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

Desalinization unit discharge NA NA NA NA No

Blowout prevent fluid NA NA NA NA No

Ballast water NA NA NA NA No

Bilge water NA NA NA NA No

Excess cement at seafloor Cement Slurry NA NA Discharged at mudline NoFire water NA NA NA NA No

Cooling water NA NA NA NA No

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

Produced water NA NA NA NA NA

Will you be covered by an individual or general NPDES permit ? General

NOTE: 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 = 3400D2/3 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 H2S 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.com
DOCD AIR QUALITY SCREENING CHECKLIST OMB Control No. 1010-0151

OMB Approval Expires: 12/31/14

COMPANY Walter Oil & GasAREA EW, MC

BLOCK 790, 834, 793LEASE 33140, 27982, 33177PLATFORM A

WELL 6 wellsCOMPANY CONTACT Judy DavidsonTELEPHONE NO. 281-578-3388REMARKS Platform RigLEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

20122013201420152016201720182019

202020212022

FORM BOEM-0139 (December 2011- Supersedes all previous versions of this form which may not be used). Page 1 of 8

Attachment H-1
AIR EMISSIONS CUMPUTATION FACTORS

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

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

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

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

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

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 2 of 8
AIR EMISSIONS CALCULATIONS - FIRST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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 0.00BURNER 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 0.00

PIPELINE 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 0.00

PIPELINE 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 0.00

FACILITY 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 12.85

VESSELS>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 0.07

PRODUCTION 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 0.00

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 0.00SUPPORT 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 0.00

RECIP.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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2015 YEAR TOTAL 11.73 53.79 403.05 12.09 87.94 4.30 19.71 147.71 4.43 32.23

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 3 of 8
AIR EMISSIONS CALCULATIONS - SECOND YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 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 16.49 119.96

PRIME 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 0.00

PIPELINE 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 0.00

PIPELINE 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 0.00

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

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

PRODUCTION Crane 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 0.06

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 0.00TURBINE 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 0.00

Compressor 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 9.47

Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 350 0.00 14.10 0.20 12.12 0.01 59.21 0.83 50.92 Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 350 0.00 14.10 0.20 12.12 0.01 59.21 0.83 50.92Generator 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 0.04

BURNER 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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2016 YEAR TOTAL 10.16 43.38 431.47 12.80 148.44 16.30 74.86 893.11 24.76 357.75

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 4 of 8
AIR EMISSIONS CALCULATIONS - THIRD YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 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 54.72

PRIME 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 0.00

PIPELINE 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 0.00

PIPELINE 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 0.00

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

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

PRODUCTION Crane 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 0.06

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 0.00TURBINE 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 0.00

Compressor RECIP 4 cycle lean nat gas 640 4571 52 109716 48 24 365 0 00 16 63 1 01 2 26 0 01 72 86 4 45 9 88 Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 365 0.00 16.63 1.01 2.26 0.01 72.86 4.45 9.88Compressor 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 0.04

BURNER 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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2017 YEAR TOTAL 10.16 43.38 431.47 12.80 148.44 7.45 34.23 602.90 15.96 301.41

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 5 of 8
AIR EMISSIONS CALCULATIONS - FOURTH YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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 0.00BURNER 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 0.00

PIPELINE 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 0.00

PIPELINE 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 0.00

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

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

PRODUCTION Crane 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 0.06

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 0.00TURBINE 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 0.00

Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 365 0.00 16.63 1.01 2.26 0.01 72.86 4.45 9.88 Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 365 0.00 16.63 1.01 2.26 0.01 72.86 4.45 9.88Compressor 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 0.04

BURNER 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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2018 YEAR TOTAL 1.61 4.14 137.45 3.98 84.29 0.01 0.10 347.20 8.29 245.62

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 6 of 8
AIR EMISSIONS CALCULATIONS

COMPANY AREA BLOCK LEASE PLATFORM WELLWalter Oil & GasEW, MC 790, 834, 793 33140, 27982, 33177 A 6 wells

Emitted Substance

Year

 PM SOx NOx VOC CO

2015 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 15.96 301.41

2018-2035 0.01 0.10 347.20 8.29 245.62

Allowable 2064.60 2064.60 2064.60 2064.60 53260.68

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 8 of 8
DOCD AIR QUALITY SCREENING CHECKLIST OMB Control No. 1010-0151

OMB Approval Expires: 12/31/14

COMPANY Walter Oil & GasAREA EW, MC

BLOCK 790, 834, 793LEASE 33140, 27982, 33177PLATFORM A

WELL 6 wellsCOMPANY CONTACT Judy DavidsonTELEPHONE NO. 281-578-3388REMARKS The A-2 well in EW 790 maybe drilled with a semi-submersible rig, and is 

included in this AQR as such.

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

20122013201420152016201720182019

202020212022

FORM BOEM-0139 (December 2011- Supersedes all previous versions of this form which may not be used). Page 1 of 8

Attachment H-2
AIR EMISSIONS CUMPUTATION FACTORS

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

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

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

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

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

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 2 of 8
AIR EMISSIONS CALCULATIONS - FIRST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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 0.00BURNER 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 0.00

PIPELINE 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 0.00

PIPELINE 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 0.00

FACILITY 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 12.85

VESSELS>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 0.07

PRODUCTION 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 0.00

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 0.00SUPPORT 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 0.00

RECIP.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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2015 YEAR TOTAL 11.73 53.79 403.05 12.09 87.94 4.30 19.71 147.71 4.43 32.23

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 3 of 8
AIR EMISSIONS CALCULATIONS - SECOND YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 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 82.08

PRIME 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 1.14

PIPELINE 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 0.00

PIPELINE 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 0.00

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

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

PRODUCTION Crane 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 0.06

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 0.00TURBINE 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 0.00

Compressor 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 9.47

Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 350 0.00 14.10 0.20 12.12 0.01 59.21 0.83 50.92 Compressor RECIP.4 cycle rich nat gas 640 4571.52 109716.48 24 350 0.00 14.10 0.20 12.12 0.01 59.21 0.83 50.92Generator 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 0.04

BURNER 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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2016 YEAR TOTAL 31.94 143.29 1180.15 35.26 311.79 31.50 144.58 1415.54 40.43 471.73

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 4 of 8
AIR EMISSIONS CALCULATIONS - THIRD YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 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 54.72

PRIME 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 0.00

PIPELINE 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 0.00

PIPELINE 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 0.00

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

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

PRODUCTION Crane 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 0.06

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 0.00TURBINE 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 0.00

Compressor RECIP 4 cycle lean nat gas 640 4571 52 109716 48 24 365 0 00 16 63 1 01 2 26 0 01 72 86 4 45 9 88 Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 365 0.00 16.63 1.01 2.26 0.01 72.86 4.45 9.88Compressor 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 0.04

BURNER 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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2017 YEAR TOTAL 10.16 43.38 431.47 12.80 148.44 7.45 34.23 602.90 15.96 301.41

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 5 of 8
AIR EMISSIONS CALCULATIONS - FOURTH YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Walter 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 TONS

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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 0.00BURNER 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 0.00

PIPELINE 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 0.00

PIPELINE 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 0.00

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

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

PRODUCTION Crane 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 0.06

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 0.00TURBINE 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 0.00

Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 365 0.00 16.63 1.01 2.26 0.01 72.86 4.45 9.88 Compressor RECIP.4 cycle lean nat gas 640 4571.52 109716.48 24 365 0.00 16.63 1.01 2.26 0.01 72.86 4.45 9.88Compressor 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 0.04

BURNER 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 0.00 FLARE- 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 0.00 FUGITIVES- 0.0 0 0.00 0.00 GLYCOL STILL VENT- 0 0 0 0.00 0.00

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2018 YEAR TOTAL 1.61 4.14 137.45 3.98 84.29 0.01 0.10 347.20 8.29 245.62

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2064.60 2064.60 2064.60 2064.60 53260.68

62.0

FORM BOEM-0139 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 6 of 8
AIR EMISSIONS CALCULATIONS

COMPANY AREA BLOCK LEASE PLATFORM WELLWalter Oil & GasEW, MC 790, 834, 793 33140, 27982, 33177 A 6 wells

Emitted Substance

Year

 PM SOx NOx VOC CO

2015 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 15.96 301.41

2018-2035 0.01 0.10 347.20 8.29 245.62

Allowable 2064.60 2064.60 2064.60 2064.60 53260.68

FORM 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 hereby 

certifies 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 separate 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 directly 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 hurricane 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

5
WCD 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 A 

Dispersants / Surveillance 

Dispersant/Surveillance Dispersant Capacity (gal) Storage Capacity Persons Req. From Hrs to Procure Hrs to Loadout Travel to site Total Hrs 

CGA

Basler 67T 2000 NA 2 Houma 1 1 0.6 2.6 

ASI 

DC 3 1200 NA 2 Houma 1 1 0.8 2.8 DC 3 1200 NA 2 Houma 1 1 0.8 2.8 Aero Commander NA NA 2 Houma 1 1 0.6 2.6 

Offshore Response 

Offshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM Travel to Spill Site Hrs to Deploy Total Hrs

CGA

HOSS Barge 43000 4000 3 Tugs 8 Harvey 7 0 5 15 1 28

T&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 61

K-Sea Operating (available through contract with CGA) 

PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 2 7.75 1 26.75 

Enterprise 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 36
Staging Area: Venice 

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Travel to Site Hrs to Deploy Total Hrs

CGA

FRU (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 10.5 FRU (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 14.5 FRU (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 12.5 

T&T Marine (available through contract with CGA) 

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 8 5 2 31

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Travel to Site Hrs to Deploy Total Hrs

CGA

42” 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 10.5 42” 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 14.5 42” 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 17.5 
Nearshore Response 

Nearshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM Travel to Spill Site Hrs to Deploy Total Hrs

Enterprise 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 36

CGA

46’ FRV 5000 65 NA 4 Venice 1 0 1 2.4 0 4.4 46’ FRV 5000 65 NA 4 Leeville 1 0 2 3.8 0 6.8 46’ FRV 5000 65 NA 4 Galveston 1 0 0 13.8 0 14.8 46’ FRV 5000 65 NA 4 Lake Charles 1 0 1 10.2 0 12.2 Trinity SWS 21500 249 NA 4 Morgan City 1 2 2 4.6 1 10.6 

Staging Area: Cameron 

Nearshore and Inland 

Skimmers With Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total Hrs

CGA

SWS Egmopol 3000 100 NA 3 Galveston 1 2 3.5 2 0 8.5 SWS 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 9.5 
Shoreline Protection 

Staging Area: Cameron 

Shoreline Protection 

Boom VOO Persons Req. Storage/Warehouse Location Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Site Hrs to Deploy Total Hrs 

OMI Environmental (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 2.5 2 3 9.5 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 2.5 2 3 9.5 10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 1.25 2 3 8.25 

Beach Boom EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total Hrs

CGA

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 3.5 1 2 9.5 Beach 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 11.5 

Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total Hrs

CGA

Wildlife 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 10.5 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 3.5 1 2 9.5 Bird 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 11.5 

Response Asset Total

Offshore EDRC 198,135 Offshore Recovered Oil Storage 238,700 Nearshore / Shallow Water EDRC 54,753 Nearshore / 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 shorebase 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 distance 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 well

Projected generated 

waste

Solid and Liquid 

Wastes transportation 

Type of Waste Composition Transport Method

Name/Location of Facility Amount Disposal Method

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

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

Below deck storage tanks on offshore support vessels

US Liquids or NewparkFourchon, Louisiana X bbl/well Recycled

Oil-based drilling fluid or mud NA NA NA NA NASynthetic-based drilling fluid or mud 

Synthetic based drilling 

fluidsadhering to drill cuttings 

from synthetic based hole 

intervals NA NA 5175 bbls/total GOM

Cuttings wetted with Water-based fluid

Cuttings generated while using 

water based drilling fluids NA NA 20,000 bbls/total GOM

Cuttings wetted with Synthetic-based fluid 

Cuttings generated while 

usuing synthetic based drilling 

fluids NA NA 13,330 bbls/total GOM

Cuttings wetted with oil-based fluids NA NA NA NA NA

Waste Disposal

ATTACHMENT N-1

 WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHORE 

g

Synthetic-based drilling fluid or mud 

Spent synthetic based drilling fluids and cuttings 

Transport to shore base in cuttings 

boxes on supply vessel

Newpark 

Environmental, 

Cameron, LA. 5200/bbls total

reconditioned at 

mud plant

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

Produced sand NA NA NA NA NA

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

Trash and debris While drilling Paper & Plastic

Garbage bags on Supply or Crew Boat

HOS Port, Fourchon, LA

57 Bags at 40 cuft per bag Landfill

Used oil

Oily rags/absorbent pads, used oil filters 19 DOT Drums on Supply boat US Liquids, Fourchon, LA 7 Drums Incineration

Wash water NA NA NA NA NAChemical product wastes

While Drilling-Paint, solvents, light bulbs

Storage Bins on Supply or Crew Boat

Newpark Environmental, Cameron, LA 200 lb./yr Hazardous Waste

Batteries 5 gallon Drum

Newpark Environmental, Cameron, LA 10 gal/yr Recycled

Will 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, H2S

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 feature (submarine bank) protected by the Topographic 

Features Stipulation attached to an OCS lease; 

o Essential Fish Habitat (EFH) criteria of 500 ft. from any no-activity zone; or 

o Proximity of any submarine bank (500 ft. buffer zone) with relief greater than 2 meters that 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 seafloor 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 where 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 resources. 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 anchor emplacements, in any OCS block designated by the 

BOEM as having high-probability for the occurrence of shipwrecks or prehistoric sites, including such blocks that will 

be affected that are adjacent to the lease block in which your planned activity will occur. If the 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 effect 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 oil-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. 
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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 exercised 

when 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 party, 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. 
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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 
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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 archaeologist 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 archaeologist 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 
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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 pelagic 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 
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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 food 

preparation 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 H2S 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.
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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 
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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 exercised 

when 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 food 

preparation 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” 
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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 food 

preparation 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 
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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 food 

preparation 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. 
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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 
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Joint Initial DOCD January, 2013 

Ewing Bank Block 790, 834, Mississippi Canyon Block 793 

(I) REFERENCES 

Authors:

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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: sources, 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