UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field Operations (MS 5231)

Public Information copy of DOCD

Control # - S-07734

Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS-G04940 Block - 18 Green Canyon Area OCS-G05809 Block - 988 Ewing Bank Area

Operator - Whistler Energy II, LLC

Well No. A-23 ST1

Not Found

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

should be addressed in an Environmental Assessment.

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

Chiquita Hill

Plan Coordinator

G05809/EW/988 7914 FSL, 4395 FEL G04940/GC/18 WELL/A-23 Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk Site Type/Name Description -

Rig Type - Subject: From: March 30, 2015Record of Changes

– P ublic Information Copy Supplemental DOCD Control No. S

- 7734 Ewing Bank 988 / OCS

- G 05809 Whistler Energy II, LLC

Date Section Page Remarks

02/17/15 2 2

- 6 Amended Blowout Scenario

03/10/15 7 Attachment

7

- A Removed discharges from Well Treatment Fluids

### PUBLIC INFORMATION COPY February 2, 2015



## SUPPLEMENTAL DEVELOPMENT OPERATIONS

COORDINATION DOCUMENT

Ewing Bank Block 988
OCS-G 05809

Affected States: Louisiana

Estimated Startup Date: May 1, 2015

SUBMITTED BY: Whistler Energy II, LLC 3200 SW Freeway, Suite 2050 Houston, TX 77027

Robert Wichert

713 -333-3664 rwichert@whistlerenergy.com

AUTHORIZED REPRESENTATIVE:

Suzy Younger J. Connor Consulting, Inc. 16225 Park Ten Place, Suite 700 Houston, Texas 77084

281 -698-8520 suzy.younger@jccteam.comTOC Pg 1 of 3 TABLE OF CONTENTS
SECTION 1 PLAN CONTENTS

................................................................................................ . 1

1.1 PLAN INFORMATION

...................................................................................................... 1

1.2 LOCATION

....................................................................................................................... 1

1.3 SAFETY AND POLLUTION PREVENTION FEATURES

.................................................. 1

1.4 STORAGE TANKS AND PRODUCTION VESSELS

......................................................... 2

1.5 POLLUTION PREVENTION MEASURES

........................................................................ 2

1.6 ADDITIONAL MEASURES

............................................................................................... 2

SECTION 2 GENERAL INFORMATION

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

2.1 APPLICATIONS AND PERMITS

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

2.2 DRILLING FLUIDS

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

2.3 PRODUCTION

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

2.4 OIL CHARACTERISTICS

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

2.5 NEW OR UNUSUAL TECHNOLOGY

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

2.6 BONDING STATEMENT

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

2.7 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR)

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

2.8 DEEPWATER WELL CONTROL STATEMENT

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

2.9 SUSPENSION OF PRODUCTION

................................................................................... 4

2.10 BLOWOUT SCENARIO

.................................................................................................. 4

SECTION 3 GEOLOGICAL AND GEOPHYSICAL INFORMATION

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

3.1 GEOLOGICAL DESCRIPTION

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

3.2 STRUCTURE CONTOUR MAPS

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

3.3 INTERPRETED 3-D SEISMIC LINES

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

3.4 GEOLOGICAL STRUCTURE CROSS-SECTION

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

3.5 SHALLOW HAZARDS REPORT

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

3.6 SHALLOW HAZARDS ASSESSMENT

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

3.7 HIGH-RESOLUTION SEISMIC LINES

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

3.8 STRATIGRAPHIC COLUMN

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

3.9 TIME VS DEPTH TABLES

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

SECTION 4 HYDROGEN SULFIDE INFORMATION

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

4.1 CONCENTRATION

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

4.2 CLASSIFICATION

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

SECTION 5 MINERAL RESOURCE CONSERVATION INFORMATION

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

5.1 TECHNOLOGY & RESERVOIR ENGINEERING PRACTICES AND PROCEDURES

...... 8

5.2 TECHNOLOGY AND RECOVERY PRACTICES AND PROCEDURES

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

5.3 RESERVOIR DEVELOPMENT

......................................................................................... 8TOC Pg 2 of 3

SECTION 6 BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

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

6.1 DEEPWATER BENTHIC COMMUNITIES

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

6.2 TOPOGRAPHIC FEATURES (BANKS)

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

6.3 TOPOGRAPHIC FEATURES STATEMENT (SHUNTING)

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

6.4 LIVE-BOTTOMS (PINNACLE TREND FEATURES)

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

6.5 LIVE BOTTOMS (LOW RELIEF)

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

6.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES

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

6.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS

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

6.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND MARINE
MAMMAL INFORMATION

.............................................................................................. 10

6.9 ARCHAEOLOGICAL REPORT

........................................................................................ 11

6.11 SOCIOECONOMIC INFORMATION

.............................................................................. 11

SECTION 7 WASTES AND DISCHARGES INFORMATION

................................................... 12

7.1 PROJECTED GENERATED WASTES

............................................................................ 12

7.2 MODELING REPORT

...................................................................................................... 12

SECTION 8

............................................................................................................................... 13

8.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS

...................................... 13

8.2 SUMMARY INFORMATION

............................................................................................ 13

SECTION 9 OIL SPILL INFORMATION

.................................................................................. 14

9.1 OIL SPILL RESPONSE PLANNING

................................................................................ 14

9.2 SPILL RESPONSE SITES

............................................................................................... 14

9.3 OSRO INFORMATION

.................................................................................................... 14

9.4 WORST-CASE DISCHARGE SCENARIO DETERMINATION

......................................... 14

9.5 OIL SPILL RESPONSE DISCUSSION

............................................................................ 15

SECTION 10 ENVIRONMENTAL MONITORING INFORMATION

.......................................... 16

10.1 MONITORING SYSTEMS

............................................................................................. 16

10.2 INCIDENTAL TAKES

..................................................................................................... 16

10.3 FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY

.................................. 16

SECTION 11 LEASE STIPULATIONS INFORMATION

.......................................................... 17

11.1 MARINE PROTECTED SPECIES

................................................................................. 17

SECTION 12 ENVIRONMENTAL MITIGATION MEASURES INFORMATION

....................... 19

12.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS

...................... 19

12.2 INCIDENTAL TAKES

..................................................................................................... 19

SECTION 13 RELATED FACILITIES AND OPERATIONS INFORMATION

........................... 20

13.1 RELATED OCS FACILITIES AND OPERATIONS

......................................................... 20

13.2 TRANSPORTATION SYSTEM

...................................................................................... 20

13.3 PRODUCED LIQUID HYDROCARBONS TRANSPORTATION VESSELS

................... 20TOC Pg 3 of 3

SECTION 14 SUPPORT VESSELS AND AIRCRAFT INFORMATION

................................... 21

14.1 GENERAL

..................................................................................................................... 21

14.2 DIESEL OIL SUPPLY VESSELS

................................................................................... 21

14.3 DRILLING FLUID TRANSPORTATION

......................................................................... 21

SECTION 15 ONSHORE SUPPORT FACILITIES INFORMATION

......................................... 22

15.1 GENERAL

..................................................................................................................... 22

15.2 SUPPORT BASE CONSTRUCTION OR EXPANSION

................................................. 22

15.4 WASTE DISPOSAL

....................................................................................................... 22

SECTION 16 COASTAL ZONE MANAGEMENT (CZM) INFORMATION

................................ 23

SECTION 17 ENVIRONMENTAL IMPACT ANALYSIS (EIA)

.................................................. 24

SECTION 18 ADMINISTRATIVE INFORMATION

.................................................................... 25

18.1 EXEMPTED INFORMATION DESCRIPTION

................................................................ 25

18.2 BIBLIOGRAPHY

............................................................................................................ 25Attachment

– Pg. 1 of 1 SECTION ATTACHMENTS

Section 1 Plan Contents

1

- A OCS Plan Information Form

1

- B Well Location Plat

Section 7 Was tes and Discharges Information

7

- A Waste You Will Generate, Treat and Downhole Dispose or Discharge to

the GOM

Section 8 Air Emissions Information

8

- A Emissions Worksheets

Section 9 Oil Spill Information

9

- A Oil Spill Response Discussion

Section 14 S upport Vessels and Aircraft Information

14

- A Waste You Will Transport and/or Dispose Onshore Table

14

- B Vicinity Map

Section 17 Environmental Impact Analysis (EIA)

17

- A Environmental Impact Analysis (EIA)Whistler Energy II, LLC Section 1

– Pg. 1 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 1
PLAN CONTENTS

1.1 PLAN INFORMATION

Under a previous plan (Control No. S- 2880)

, Mobil developed Lease G-05809, Ewing Bank Block 988. Whistler Energy II, LLC was designated operator of the lease in July 2013. All of the Ewing Bank Block 988 wells are drilled from Green Canyon Block 18 A, which is a 30 -slo t, 4 -pile platform installed in 760’ of water

.

Under this Supplemental Development Operations Coordination Document

, Whistler Energy II,
LLC (Whistler) proposes to re -enter Green Canyon Block 18 (current bottomhole location) Well

No. A- 23 (API No. 60 -811- 40191

- 00 ) and sidetrack to a new bottomhole location in Ewing Bank

Block 988. These development operations are in approximately 760 feet of water. The well will

be re -entered and drilled with a platform rig (Noble MODS 201). No rig ht

- of -way or lease term pipelines will be installed.

The OCS Plan Information Form BOEM-137 is included as Attachment 1- A.

1.2 LOCATION A Well Location Plat depicting the proposed surface and bottomhole location of the proposed well, measured depth/true vertical depth and water depth is included as Attachment 1-B

.

No anchors are associated with the proposed activities in this plan.

1.3 SAFETY AND POLLUTION PREVENTION FEATURES A description of the drilling unit which complies with all relevant regulations is included on the OCS Plan Information Form. Rig specifications will be made part of each Application for Permit

to Drill.

The rig will be equipped with safety and fire-fighting equipment required to comply with United States Coast Guard (USCG) regulations. Appropriate life saving equipment such as life rafts, life jackets, ring buoys, etc. as prescribed by the USCG, will be maintained on the rig at all times.

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, Q and S; and as further clarified by BSEE Notices to Lessees, and current policy making invoked by the BSEE, EPA and the USCG.

Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on drilling deck areas to collect all contaminants and debris. Compliance will be maintained with the EPA NPDES Permit. The rig will be monitored daily and any waste or fuel resulting in pollution of the Gulf waters will be reported to the representative in charge for immediate isolation and correction of the problem. Any spill will be reported to the appropriate governmental agencies.Whistler Energy II, LLC Section 1

– Pg. 2 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 1.4 STORAGE TANKS AND PRODUCTION VESSELS The table below provides storage tanks with capacity of 25 barrels or more that will store fuels,

oil and lubricants. Type of Storage

Tank Type of

Facility Tank

Capacity (bbls) Number

of Tanks Total

Capacity (bbls) Fluid Gravity

(API)

Production Platform 600 1 600 29°

Production Platform 850 1 850 29°

Production Platform 210 1 210 29°

Production Platform 100 1 100 29°

1.5 POLLUTION PREVENTION MEASURES These operations do not propose activities for which the State of Florida is an affected state.

1.6 ADDITIONAL MEASURES

Whistler does not propose any additional safety, pollution prevention, or early spill detection measures beyond those required by 30 CFR Part 250.U.S. Department of the Interior Bureau of Ocean Energy Management

Have you previously provided information to verify the calculations and assumptions for your WCD? X Yes No

If so, provide the Control Number of the EP or DOCD with which this information was provided R

- 6208

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

Do you propose to use a vessel with anchors to install or modify a structure? Yes X No

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

Description of Proposed Activities and Tentative Schedule (Mark all that apply)

Proposed Activity Start Date End Date No. of Days

Recover slot, drill, complete & produce EW 988 Well No. A

- 23 (current BHL GC 18) 05/ 01 /2015 0 7/11 /2015 72

Description of Drilling Rig Description of Structure

Jackup Drillship Caisson Tension leg platform

Gorilla Jackup X Platform rig (Noble 201) Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed tower

DP Semisubmersible Other (Attach description) Floating production

system Other (Attach description) Drilling Rig Name (If known):

Description of Lease Term Pipelines

From (Facility/Area/Block) To (Facility/Area/Block) Diameter (Inches) Length (Feet)

N/A

Form BOEM- 0137 (December 2011

– Supersedes all previous editions of this form which may not be used.) Page 1

Attachment 1-A General Information

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

Company Name: Whistler Energy II, LLC BOEM Operator Number: 03269

Address: 3200 SW Freeway, Suite 2050 Contact Person: Suzy Younger

Houston, Texas 770 27 Phone Number: 281

- 698

- 8520

E

- Mail Address: suzy.younger @jccteam.com

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $4238 Receipt No. 25JJOKEF

Project and Worst Case Discharge (WCD) Information

Leases: OCS

- G 05809 Area: Ewing Bank Blocks : 988 Project Name (If Applicable): N/A

Objective(s) X Oil X Gas Sulphur Salt Onshore Support Base: Fourchon, LA

Platform / Well Name: Platform A Total Volume of WCD: 132554 bbls API Gravity: 29°

Distance to Closest Land (Miles): 76 miles Volume from uncontrolled blowout: 130222 

### OCS PLAN INFORMATION FORM OMB Control Number: 1010

- 0151 OMB Approval Expires: 12/31/14OCS 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): EW 988 #A

- 23 (well is currently GC 18 #A

- 23) Previously reviewed under an approved EP or DOCD? X Yes No

Is this an existing well or

structure? X Yes No If this is an existing well or structure, list the Complex ID

or API No. 608114019100

Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes X No

WCD Info For wells, volume of uncontrolled

blowout (Bbls/Day): 54605 For structures, volume of all storage and pipelines (Bbls): 2332 API Gravity of fluid 29°

Surface Location Bottom

- Hole Location (For Wells) Completion (For multiple completions, enter separate lines)

Lease No. OCS

- G 04940 OCS

- G 05809 OCS

OCS

Area Name GC EW

Block No. 18 988

Blockline Departures (in feet) N/S Departure 7914’ FSL N/S Departure N/S Departure F __ L

N/S Departure F __ L N/S Departure F __ L

E/W Departure 439 5 ’ FEL E/W Departure E/W Departure F __ L

E/W Departure F __ L E/W Departure F __ L

Lambert X

- Y

coordinates X: 2,276,564.65’ X: X:

X:

X:

Y: 10,145,514.32 ’ Y: Y:

Y:

Y:

Latitude/ Longitude Latitude 27° 56’ 37.371” N Latitude Latitude

Latitude

Latitude

Longitude 91° 01’ 45.179” W Longitude Longitude Longitude Longitude

Water Depth (Feet): 760’ MD (Feet): TVD (Feet): MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet): Anchor Radius (if applicable) in feet: N/A

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:

Form BOEM- 0137 (December 2011

– Supersedes all previous editions of this form which may not be used.) Page 2Whistler Energy II, LLC Section 2

– Pg. 3 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 2

GENERAL INFORMATION

2.1 APPLICATIONS AND PERMITS The table below provides the additional applications to be filed covering op erations proposed in
this DOCD.

Application/Permit Issuing Agency Status Application for Plugback to Sidetrack BSEE Pending Application for Permit to Sidetrack BSEE Pending Application for Permit to Modify BSEE Pending

2.2 DRILLING FLUIDS The table below provides the types and estimated volumes of the drilling fluids Whistler plans t o use to drill the proposed well.

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be Used per Well (bbls)

Water

- based (seawater, fre shwater, barite) 5000 bbls

Oil

- based (diesel, mineral oil ) N/A Synthetic

- based (internal olefin, ester) N/A

2.3 PRODUCTION Proprietary Information

2.4 OIL CHARACTERISTICS Oil characteristics are not required to be submitted with this plan.

2.5 NEW OR UNUSUAL TECHNOLOGY

No new or unusual technology is proposed in this DOCD as defined by 30 CFR 550.200.

2.6 BONDING STATEMENT The bond requirements for the activities and facilities proposed in this DOCD are satisfied by an area-wide bond, furnished and maintained according to 30 CFR 556, Subpart I; NTL No. 2000

- G16, "Guidelines for General Lease Surety Bonds"; and additional security under 30 CFR 556.53(d) and National NTL No. 2008 -N07 , “Supplemental Bond Procedures” as required by
BOEM.

2.7 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR ) Whistler Energy II, LLC, Operator No. 03269 , has demonstrated 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" prior to conducting operations covered in this DOCD.

2.8 DEEPWATER WELL CONTROL STATEMENT Operations proposed in this plan are located in water depths less than 300 meters (984 feet) ; therefore, a deepwater well control statement is not provided.PUBLIC INFORMATION COPY

Whistler Energy II, LLC Section 2

– Pg. 4 of 26 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 2.8 DEEPWATER WELL CONTROL STATEMENT Operations proposed in this plan are located in water depths less than 300 meters (984 feet); therefore, a deepwater well control statement is not provided.

2.9 SUSPENSION OF PRODUCTION Whistler does not anticipate filing any requests for Suspension of Production to hold the leases

addressed in this DOCD in active status.

2.10 BLOWOUT SCENARIO The Worst Case Discharge in this DOCD is for Ewing Bank Block 988, Well No. A-13 (GC 18 A surface location) accepted in Control No. R-06208 approved by the Bureau of Ocean Energy Management on January 21, 2015.

Estimated Flow Rate - Drilling

– Calculated ‘Worst Case Drilling Discharge’ estimate for the

section for the A- 13 well, is 130,222 Bbls per day of oil and 127 MMCF per day of gas (based on 972 scf/stb (GOR).

Total Volume - Drilling

– Total volume based on a ‘Worst Case Drilling Discharge’ estimate of 130,222 Bbls per day of oil and 127 MMCF per day of gas and a ‘Maximum duration of the

po tential blowout’ of 45 days = 130222 x 45 = 5,859,990 bbls and 5.7 BCF

.

Estimated Flow Rate - Production

– The production based WCD estimate is based on a gravel packed completion with 2- 7/8” tubing in the hole. The tubing has the smallest well restriction (2.323”).

Calculated ‘Worst Case Production Discharge’ estimate for the completed well with 2

- 7/8” production tubing is 7159 Bbls per day of oil and 6.95MMCF per day of gas (based on 972 scf/stb (GOR).

Maximum duration of the potential blowout

– Maximum duration will be the time to drill the relief well and kill (45 days), assuming the reservoir does not bridge over.

Intervention, relief well plans and time required to kill the well: The potential for the well to bridge over

– The target zone is commonly known to produce sand at normal production drawdown pressures, and is routinely gravel packed in completions. The drawdown pressure and flow rate during an uncontrolled blowout, without sand control would cause sand face failure and lead to large amounts of sand production. However, it is impossible to determine if a sand bridge capable of stopping the blowout will form in the casing, and it is assumed that the blowout will continue until it can be mechanically stopped by an

intervention.

The availability of a rig to drill a relief well and rig package constraints Each planned well will be drilled from the Green Canyon Block 18 platform location in 760 ’ of water. There are currently a combined number of 58 floating MODU in the GOM that are capable of drilling a relief well in this water depth. Attached in report listing of rigs and their

current location.PUBLIC INFORMATION COPY

Whistler Energy II, LLC Section 2

– Pg. 5 of 26 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 Specify as accurately as possible the time it would take to contract for a rig, move it onsite, and drill a relief well, including the possibility of drilling a relief well from a neighboring platform or an onshore location The well locations are located too far away from the nearest structure in order to drill a relief well from a neighboring platform, therefore two scenarios have been defined; the first being; a rig being immediately available, and the second being; a rig not being immediately available, and suspension of operations is required prior to mobilization.

The actual hole and casing sizes may vary with final relief well design dependent upon actual conditions at the time; this is for estimating time only. There are currently no plans or need to drill a relief well from any neighboring structures.

The first scenario assumes that a rig is available to mobilize to location and commence drilling a relief well. The mobilization time is based on utilizing an available rig and the drilling performance is based on offset wells to equivalent depth.

OPERATION TIME (DAYS) Move Rig on Location 3 Drive 30” Pipe to 1355 TVD/MD 2
Drill 26” Conductor Hole to ~2400’ TVD/MD & Run & Cement 18

- 5/8” Casing. 3

Drill 17 1/2” Surface Hole, Run & Cement 13 3/8” Casing (TVD & MD will be dependent upon surface location) ±7600’ TVD 10

Drill 12 1⁄4” Hole & Run & Cement 9 5/8” Intermediate Casing (TVD & MD will be dependent upon surface location) ±10,000 TVD (just above well intersect) 15

Drill 8

- 1/2” relief hole to intersect with reservoir section or produ ction casing 14,500 TVD / 17,500 MD (TVD & MD will be dependent upon surface location) 12

TOTAL ESTIMATED DAYS to DRILL RELIEF WELL 45 DAYS

The second scenario assumes that a rig is not immediately available to mobilize to location and commence drilling a relief well. The estimated mobilization time incorporates the suspension of activities by an operator before the rig can be released for relief well operations. The drilling performance is based on offset wells to equivalent depth.

OPERATION T IME (DAYS) Suspension of current operations 10 Move Rig on Location 3 Drive 30” Pipe to 1355’ TVD/MD 2

Drill 26” Conductor Hole to ~2400’ TVD/MD & Run & Cement 18

- 5/8” Casing. 3

Drill 17 1/2” Surface Hole, Run & Cement 13 3/8” Casing (TVD &

MD will be dependent upon surface location) ±7600’ TVD 10

Drill 12 1⁄4” Hole & Run & Cement 9 5/8” Intermediate Casing (TVD & MD will be dependent upon surface location) ±10,000’ TVD (just above well intersect) 15PUBLIC INFORMATION COPY

Whistler Energy II, LLC Section 2

– Pg. 6 of 26 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 Drill 8

- 1/2” relief hole to intersect with reservo ir section or production casing 14,500 TVD / approx. 17,500 MD (TVD & MD will be dependent upon surface location) 12

TOTAL ESTIMATED DAYS to DRILL RELIEF WELL 55 DAYS

Blowout Prevention Measures Describe the measures you propose that would enhance your ability to prevent a blowout, to reduce the likelihood of a blowout, and conduct effective and early intervention in the event of a blowout, including your arrangements for drilling relief wells, and any other measures you propose

Whistler would adhere and conduct strict compliance with all regulations, including those listed in latest Drilling Safety Rule.

This well is planned in a well-known area and has been designed to control any anticipate d pressures that might be encountered.

Liners/Production casings are planned to have two independent floats to prevent any possible internal flow back, and are equipped with an annular packer.

Sufficient cement of appropriate density with anti-gas migration additives will be used to isolate any hydrocarbon bearing zones.

All drill strings are planned to have at least one float valve installed in the BHA as close to the bit as practical.

It is planned that drilling fluids of sufficient density to control all exposed formations will be maintained at all times during drilling operations.Whistler Energy II, LLC Section 3

– Pg. 6 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 3

GEOLOGICAL AND GEOPHYSICAL INFORMATION

3.1 GEOLOGICAL DESCRIPTION Proprietary Information

3.2 STRUCTURE CONTOUR MAPS Proprietary Information

3.3 INTERPRETED 3-D SEISMIC LINES Proprietary Information

3.4 GEOLOGICAL STRUCTURE CROSS-SECTION Proprietary Information

3.5 SHALLOW HAZARDS REPORT The proposed operations will be conducted from previously approved surface location as provided for in DOCD (Control No. S- 2880 ); therefore, in accordance with NTL No. 2008 -G05,
“Shallow Hazards Program”, a shallow hazards report is not provided.

3.6 SHALLOW HAZARDS ASSESSMENT The proposed operations will be conducted from previously approved surface location as provided for in DOCD (Control No. S- 2880 ); therefore, in accordance with NTL NO. 2008 -G05, Shallow Hazards Program”

, a shallow hazards assessment is not provided.

3.7 HIGH-RESOLUTION SEISMIC LINES Proprietary Information

3.8 STRATIGRAPHIC COLUMN Proprietary Information

3.9 TIME VS DEPTH TABLES Proprietary InformationWhistler Energy II, LLC Section 4

– Pg. 7 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 4

HYDROGEN SULFIDE INFORMATION

4.1 CONCENTRATION Whistler anticipates encountering 0 ppm H 2 S during the proposed operations.

4.2 CLASSIFICATION In accordance with Title 30 CFR 250.490(c), Whistler requests that the area of proposed operations be classified by the BOEM as H 2 S absent.Whistler Energy II, LLC Section 5

– Pg. 8 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 5
MINERAL RESOURCE CONSERVATION INFORMATION

5.1 TECHNOLOGY & RESERVOIR ENGINEERING PRACTICES AND PROCEDURES Proprietary Information

5.2 TECHNOLOGY AND RECOVERY PRACTICES AND PROCEDURES Proprietary Information

5.3 RESERVOIR DEVELOPMENT Proprietary InformationWhistler Energy II, LLC Section 6

– Pg. 9 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 6 BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

6.1 DEEPWATER BENTHIC COMMUNITIES Activities proposed in this DOCD are in water depths less than 300 meters (984 feet); therefore,

information as outlined in Attachment A of NTL No. 2009

- G40, “Deepwater Benthic Communities,” is not provided.

6.2 TOPOGRAPHIC FEATURES (BANKS) Activities proposed in this DOCD do not fall within 305 meters (1000 feet) of a topographic “No Activity Z one ;” ther efore, no map is required per NTL No. 2009

- G39, “Biologically Sensitive
Underwater Features and Areas.”

6.3 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 per NTL

No. 2009

- G39, “Biologically Sensitive Underwater Features and Areas.”

6.4 LIVE-BOTTOMS (PINNACLE TREND FEATURES) Green Canyon Block 18 is not located within 61 meters (200 feet) of any pinnacle trend feature; therefore, a separate bathymetric map is not required per NTL No. 2009- G39, “Biologically
Sensitive Underwater Features and Areas.”

6.5 LIVE BOTTOMS (LOW RELIEF) Green Canyon Block 18 is not located within 30 meters (100 feet) of any live bottom (low relief) feature with vertical relief equal to or greater than 8 feet; therefore, live bottom (low relief) maps are not required per NTL No. 2009

- G39, “Biologically Sensitive Underwater Features and

Areas.”

6.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES Green Canyon Block 18 is not located within 30 meters (100 feet) of potentially sensitive biological features; therefore, biologically sensitive area maps are not required.

6.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS Operations proposed in this plan are located in water depths less than 400 meters (1312 feet); therefore, remotely operated vehicle (ROV) surveys for the purpose of biological and physical observations are not required per NTL No. 2008

- G06, “Remotely Operated Vehic le Surveys in Deepwater”.Whistler Energy II, LLC Section 6

– Pg. 10 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 6.8 THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND MARINE

MAMMAL INFORMATION The federally listed endangered and threatened species potentially occurring in the lease area and along the Gulf Coast are provided in the table below.
Species Scientific Name Status Potential Presence Critical Habitat Designated in the Gulf

of Mexico Lease

Area Coastal

Marine Mammals

Manatee, West

Indian Trichechus manatus latirostris E

-- X Florida (peninsular)

Whale, Blue Balaeno ptera masculus E X *

-- None

Whale, Finback Balaenoptera physalus E X *

-- None

Whale,
Humpback Megaptera novaeangliae E X *

-- None

Whale, North
Atlantic Right Eubalaena glacialis E X *

-- None

Whale, Sei Balaenopiera borealis E X *

-- None
Whale, Sperm P

hyseter catodon (=macrocephalus) E X

-- None

Terrestrial Mammals

Mouse, Beach (Alabama,
Choctawatchee, Perdido Key, St. Andrew) Peromyscus polionotus E

- X Alabama, Florida (panhandle) beaches

Birds
Plover, Piping Charadrius melodus T

- X Coastal Tex as, Louisiana,
Mississippi, Alabama and Florida (panhandle)
Crane, Whooping Grus Americana E

- X Coastal Texas
Reptiles

Sea Turtle,

Green Chelonia mydas T,E ** X X None

Sea Turtle,

Hawksbill Eretmochelys imbricata E X X None

Sea Turtle, Kemp’s Ridle y Lepidochelys kempli E X X None

Sea Turtle,

Leatherback Dermochelys coriacea E X X None

Sea Turtle,
Loggerhead Caretta caretta T X X Texas, Louisiana,
Mississippi, Alabama,

Florida

Fish
Sturgeon, Gulf Acipenser oxyrinchus

(=oxyrhynchus) desotoi T X X Coastal Louisiana,

Miss issippi, Alabama and Florida (p anhandle)

Corals

Coral, Elkhorn Acopora palmate T

- X Florida Keys and Dry
TortugasWhistler Energy II, LLC Section 6

– Pg. 11 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 Coral, Staghorn Acopora cervicornis T

- X Florida
Abbreviations: E = Endangered; T = Threatened

* The Blue Fin, Humpback, North Atlantic Right, and Sei Whales are rare or extralimital in the Gulf of Mexico and are unlikely to be present in the lease area.

** Green Sea turtle is threatened, except for the Florida breeding population, which is listed as endangered.

6.9 ARCHAEOLOGICAL REPORT The proposed operations will be conducted from previously approved surface location as provided for in the DOCD (Control S- 2880 ); therefore, in accordance with NTL No. 2005 -G07, “Archaeological Surveys and Reports,” and NTL No. 2011 -JOINT- G01, “Revisions to the List of OCS Lease Blocks Requiring Archaeological Resource Surveys and Reports,” an archaeological survey report is not provided.

6.10 AIR AND WATER QUALITY INFORMATION Air and water quality information is not required to be included in this plan per NTL No. 2008

- G04, “Information R equirements for Exploration Plans and Development Operations
Coordination Documents”.

6.11 SOCIOECONOMIC INFORMATION Socioeconomic Information is not required to be included in this plan pe r NTL No. 2008 -G04, “Information Requirements for Exploration Plans and Development Op erations Coordination

Documents ”

.Whistler Energy II, LLC Section 7

– Pg. 12 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 7

WASTES AND DISCHARGES INFORMATION

7.1 PROJECTED GENERATED WASTES

“ Wastes You Will Generate, Treat and Downhole Dispose or Discharge to the Gulf of Mexico ” is

included as Attachment 7-A.

7.2 MODELING REPORT Modeling reports are not required for the activities proposed in this plan.Projected generated waste Projected ocean discharges

Type of Waste Composition Projected Amount (bbl/well) Discharge rate (bbl/day/well) Discharge Method Answer yes or no

Water-based drilling fluid Water based drilling fluid 7430 106 Discharge overboard No Cuttings wetted with water-based fluid Water based cuttings 5430 78 Discharge overboard No

Cuttings wetted with synthetic-based fluid N/A N/A N/A N/A No

Domestic waste (kitchen water, shower water) Domestic water: kitchen, shower water @ 65 USG/Man Day 9208 132 Chlorination and discharge overboard No

Sanitary waste (toilet water) Black Water (Toilet Water @ 10USG/Man Day) 85 Men max 1417 20 Red Fox then chlorination and discharge

overboard No

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

Deck Drainage Rainwater @ 8"/mo 128770 1840 Drill sump then overboard No

Will you conduct well treatment, completion, or workover?

Well treatment fluids N/A N/A N/A N/A No

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

Desalinization unit discharge Concentrated seawater 21600 309 Discharge overboard No

Blowout prevent fluid N/A N/A N/A N/A No

Ballast water N/A N/A N/A N/A No

Bilge water N/A N/A N/A N/A No

Excess cement at seafloor N/A N/A N/A N/A No

Fire water N/A N/A N/A N/A No

Cooling water N/A N/A N/A N/A No

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

Produced water Produced water 30,000 BWPD 30,000 BWPD Discharge overboard No

Will you be covered by an individual or general NPDES permit ? Yes GMG 290538 

### TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM

Projected

Downhole Disposal

Attachment 7-AWhistler Energy II, LLC Section 8

– Pg. 13 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 8

8.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS

Screen Questions for DOCD’s Yes No Is any calculated Complex Total (CT) Emission amount (tons) associated with your proposed development activities more than 90% of the amounts calculated using the following formulas: CT = 3400D 2/3 for CO, and CT = 33.3D for the other air pollutants (w here D = distance to shore in miles)? X

Do your emission calculations include any emission reduction measures or
modified emission factors? X

Does or will the facility complex associated with your proposed development and production activities process production from eight or more wells? X

Do you expect to encounter H 2 S at concentrations greater than 20 parts per million (ppm)? X

Do you propose to flare or vent natural gas in excess of the criteria set forth under 250.1105(a)(2) and (3)? X

Do you propose to burn produced hydrocarbon liquids? X Are your proposed development and production activities located within 25 miles (40 kilometers) from shore? X

Are your proposed development and production activities located within 124 miles (200 kilomete rs) of the Breton Wilderness Area? X

8.2 SUMMARY INFORMATION

Included as Attachment 8-A are Air Emission Worksheets which show the emissions calculations for the Plan emissions and a set of worksheets showing the emissions calculations for the Complex Total emissions.

This information was calculated by: Suzy Younger

281

- 698

- 8520 suzy.younger@jccteam.comWhistler Energy II, LLC Section 9

– Pg. 14 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 9
OIL SPILL INFORMATION

9.1 OIL SPILL RESPONSE PLANNING All the proposed activities and facilities in this DOCD will be covered by the Oil Spill Response Plan (OSRP) filed by Whistler (Operator N o. 03269 ) dated November 18, 2014 and last approved on December 18, 2014 (OSRP Control N o. 0- 707 ).

9.2 SPILL RESPONSE SITES Primary Respons e Equipment Location Preplanned Staging Location

Houma, LA Harvey, LA Leeville, LA Houma, LA Harvey, LA Fourchon, LA

9.3 OSRO INFORMATION

Whistler ’s primary equipment provider is Clean Gulf Associates (CGA). Clean Gulf Associates Services, LLC (CGAS) wi ll provide closest available personnel, as well as a supervisor to operate the equipment.

9.4 WORST-CASE DISCHARGE SCENARIO DETERMINATION

Category Drilling Production

Regional
OSRP
WCD DOCD

WCD Regional

OSRP
WCD DOCD

WCD

Type of Activity Drilling Dr illing >10 M ile s Production >10 M ile s

Production

Facility Location (Area/Block) GC18 SL is GC 18

BHL is EW

988 GC 18 GC 18

Facility Designation A A

- 13 ST A A

Distance to Nearest Shoreline (miles) 79 76 79 76

Volume

 Storage tanks &
flowlines

 Lease term pipelines

 Uncontrolled

blowout Total Volume (bbls) 2332

0

130222

132554 2332

0

130222

132554 2332

0

7159

9491 2332

0

7159

9491 Type of Oil(s) (crude, condensate, diesel) Crude Crude Crude Crude

API Gravity 30 30 30 30Whistler Energy II, LLC Section 9

– Pg. 15 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 The DOCD drilling WCD calculations and production WCD volume were submitted under Plan
Control No. R- 06208 approved on January 21, 2015.

Whistler 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.

9.5 OIL SPILL RESPONSE DISCUSSION The Oil Spill Response Discussion is included as Attachment 9- A.

### Attachment 9-A Page 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 132,554 barrels of crude oil wi th an API gravity of 29°.

Land Segment and Resource Identification

Trajectories of a spill and the probability of it impacting a land segment have been projected utilizing information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and

Western Gulf of Mexico available on the BOEM website. The results are shown in Fi gure 1.

The BOEM OSRAM identifies a 7% probability of impact to the shoreline in 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; along the Gulf beach 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

Whistler 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 11 % or approximately 14,581 barrels of crude oil would be evaporated/dispersed within 24 hours, with approximately 117,973 barrels remaining.

Spill Response GC 18 A Barrels of Oil

WCD Volume 132,55 4

Less 11 % natural evaporation/dispersion 14,581

Remaining volume 117,973



### Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary storage equipment available to respond to the worst case discharge. 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.

Whistler ’s Oil Sp ill Response Plan includes alternative response technologies such as dispersants and in-situ burn. Strategies will be decided by Unified Command based on an operations safety analysis, the size of the spill, weather and potential impacts. If aerial dispersants are utilized, 8

### Attachment 9-A Page 2

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 CGA spill response equipment, with a total derated skimming capacity of 359,964 barrels. Temporary storage associated with skimming equipment equals 32,447 barrels.

If additional storage is needed, various tank barges with a total of 332,000+ barrels of storagecapacity may be mobilized and centrally located to provide temporary storage and minimize offloading time

. 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 97,839 barrels. Temporary storage associated with skimming equipment equals 1,718 barrels. If additional storage is needed, an 80,000+ barrel storage barge and three 23,000 barrel storage barges may be mobilized and centrally located to provide temporary storage and minimize off-loading time. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. A Letter of Intent from OMI Environmental will ensure access to 30,000 feet o f 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 give n actual sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan, applicable Area Contingency and Geographical Response Plans 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. Whistler ’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, Whistler 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

69 hours (based on the equipment’s Effective Daily Recovery Capacity (EDRC)).

### Attachment 9-A Page 3

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

be limited to:

 Weather

 Equipment and materials availability

 Ocean currents and tides

 Location of the spill

 Product spilled

 Amount spilled

 Environmental risk assessments

 Trajectory and product analysis

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

Whistler 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, res ponse 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.

Coordination of response assets will normally be supervised by the Operations Section as necessary for close quarter vessel response activities. A Simultaneous Operations (SIMOPS) unit may be established in the Source Control Section to control operations if events require a significant number of large vessels to operate independently, but in coordination with each other. This unit would normally monitor the subsurface activities of each vessel (ROV, dispersant application, well control support, etc.), as well.

In addition, these activities will be monitored by the spill management team (SMT) and Unified Command via a structured Common Operating Picture (COP) established to track resource and

slick movement in real time.

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

 Information will be confirmed

 An assessment will be made and initial objectives set

 OSROs and appropriate agencies will be notified

 ICS 201, Initial Report Form completed

 Initial Safety plan will be written and published

 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

### Attachment 9-A Page 4

Offshore Response Actions

Equipment Deployment

Surveillance

 Surveillance Aircraft: within two hours of QI notification, or at first light

 Provide trained observer to provide on site status reports

 Provide command and control platform at the site if needed

 Continual surveillance of oil movement by remote sensing systems, aerial photography

and visual confirmation

 Continual monitoring of vessel assets using vessel monitoring systems

Dispersant application assets

 Put ASI on standby

 With the FOSC, conduct analysis to determine appropriateness of dispersant application (refer to Section 18)

 Gain FOSC approval for use of dispersants on the surface

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

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

 Confirm dispersant availability for current and long range operations

 Start ordering dispersant stocks required for expected operations

Containment boom

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

 Ensure boom handling and mooring equipment is deployed with boom

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

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

Oceangoing Boom Barge

 Containment at the source

 Increased/enhanced skimmer encounter rate

 Protection booming

In -situ Burn assets

 Determine appropriateness of in-situ burn operation in coordination with the FOSC and

affected SOSC

 Determine availability of fire boom and selected ignition systems

 Start ordering fire boom stocks required for expected operations

 Contact boom manufacturer to provide training if required

 Determine assets to perform on water operation

 Build operations into safety plan

 Conduct operations in accordance with an approved plan

### Attachment 9-A Page 5

Dedicated off-shore skimming systems

General

 Deployed to the highest concentration of oil

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

CGA HOSS Barge

 Use in areas with heaviest oil concentrations

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

CGA 95’ Fast Response Vessels (FRVs)

 Designed to be a first vessel on scene

 Capable of maintaining the initial Command and Control function for on water recovery operations

 24 hour oil spill detection capability

 Highly mobile and efficient skimming capability

 Use as far off-shore as safely possible

CGA FRUs

 To the area of the thickest oil

 Use as far off-shore as allowed

 VOOs 100 ’ minimum in length

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

 VOOs in shallow water should have a draft of <10 feet when fully loaded

T&T Koseq Skimming Systems

 To the area of the thickest oil

 Use as far off-shore as allowed

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

 VOOs at least 200’ in length

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

 VOOs for shallow water should be deck barges with a draft of <10 feet when fully loaded

Storage Vessels

 Establish availability of CGA contracted assets (See Appendix E)

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

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

systems

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

Vessels of Opportunity (VOO)

 Use Whistler ’s contracted resources as applicable

 Industry vessels are ideal for deployment of Vessel of Opportunity Skimming Systems (VOSS)

### Attachment 9-A Page 6

 Acquire additional resources as needed

 Consider use of local assets, i.e. fishing and pleasure craft for ISB operations or boom tending

 Expect mission specific and safety training to be required

 Plan with the US Coast Guard for vessel inspections

 

### Place VOOs in Division or Groups as needed

 

### Use organic on-board storage if appropriate

 

### Maximize non-organic storage appropriate to vessel limitations

 

### Decant as appropriate after approval to do so has been granted

 

### Assign bulk storage barges to each Division/Group

 

### Position bulk storage barges as close to skimming units as possible

 

### Utilize large skimming vessel (e.g. barges) storage for smaller vessel offloading

 

### Maximize skimming area (swath) to the optimum width given sea conditions and available equipment

 

### Maximize use of oleophilic skimmers in all operations, but especially offshore

 

### Nearshore, use shallow water barges and shuttle to skimming units to minimize offloading time

 

### Plan and equip to use all offloading capabilities of the storage vessel to minimize offloading time

Adverse Weather Operations:

In adverse weather, when seas are > 3 feet, the use of larger recovery and storage vessels, oleophilic skimmers, and large offshore boom will be maximized. KOSEQ Arm systems are built for rough conditions, and they should be used until th eir operational limit (9.8’ seas) is met. Safety will be the overriding factor in all operations and will cease at the order of the Unified Command, vessel captain, or in an emergency, ”stop work” may be directed by any crew

member.

Surface Oil Recovery Considerations and Tactics (Offshore and Near-shore Operations)

Maximization of skimmer-oil encounter rate

 Place barges in skimming task forces, groups, etc., to reduce recovered oil offloading

time

 Place barges alongside skimming systems for immediate offloading of recovered oil when practicable

 Use two vessels, each with heavy sea boom, in an open- ended “V” configuration to funnel surface oil into a trailing skimming unit’s organic, V -shaped boom and skimmer (see page 7, CGA Equipment Guide Book and Tactic Manual (CGATM)

 Use secondary vessels and heavy sea boom to widen boom swath beyond normal skimming system limits (see page 15, CGATM)

 Consider night-time operations, first considering safety issues

### Attachment 9-A Page 7

 Utilize all available advanced technology systems ( IR, X-Band Radar, etc.) to determine the location of, and move to, recoverable oil

 Confirm the presence of recoverable oil prior to moving to a new location

Maximize skimmer system efficiency

 Place weir skimming systems in areas of calm seas and thick oil

 Maximize the use of oleophilic skimming systems in heavier seas

 Place less mobile, high EDRC skimming systems (e.g. HOSS Barge) in the largest pockets of the heaviest oil

 Maximize onboard recovered oil storage for vessels.

 Obtain authorization for decanting of recovered water as soon as possible

 Use smaller, more agile skimming systems to recover streamers of oil normally found farther from the source. Place recovered oil barges nearby

Recovered Oil Storage

 Smaller barges in larger quantities will increase flexibility for multi-location skimming operations

 Place barges in skimming task forces, groups, etc., to reduce recovered oil offloading

time

 Procure and deploy the maximum number of portable tanks to support Vessel of Opportunity Skimming Systems if onboard storage is not available

 Maximize use of the organic recovered oil storage capacity of the skimming vessel

Command, Control, and Communications (C 3 

### )

 Publish, implement, and fully test an appropriate communications plan

 Design an operational scheme, maintaining a manageable span of control

 Designate and mark C 3 

### vessels for easy aerial identification

 Designate and employ C 3 

### aircraft for task forces, groups, etc.

 Use reconnaissance air craft and Rapid Response Teams (RAT) to confirm the presence

of recoverable oil

### Attachment 9-A Page 8

On Water Recovery Group When the first skimming vessel arrives on scene, a complete site assessment will be conducted before recovery operations begin. Once it is confirmed that the air monitoring readings for O2, LEL, H2S, CO, VOC, and Benzene are all within the permissible limits, oil recovery operations may begin.

As skimming vessels arrive, they will be organized to work in areas that allow for the most efficient vessel operation and free vessel movement in the recovery of oil. Vessel groups will vary in structure as determined by the Operations Section of the Unified Command, but will generally consist, at a minimum, of the following dedicated assets:

 3 to 5

–

Offshore skimming vessels (recovery)

 1

– Tank barge (temporary storage)

 1

– Air asset (tactical direction)

 2

– Support vessels (crew/utility for supply)

 6 to 10

–

Boom vessels (enhanced booming )

Example (

Note: Actual organization of TFs will be dependent on several factors including, asset availability, weather, spilled oil migration, currents, etc.)

The 95’ FRV Breton Island out of Venice arrives on scene and conducts an initial site assessment. Air monitoring levels are acceptable and no other visual threats have been observed. The area is cleared for safe skimming operations. The Breton Island assumes command and control (CoC) of on-water recovery operations until a dedicated non-skimming vessel arrives to

relieve it of those duties.

A second 95’ FRV arrives and begins recovery operations alongside the Breton Island. Several more vessels begin to arrive, including a third 95’ FRV out of Galveston, the HOSS Barge (High Volume Open Sea Skimming System) out of Harvey, a boom barge (CGA 300) with 25,000’ of 42” auto boom out of Leeville, and 9 Fast Response Units (FRUs) f rom the load-out location at

C-Port in Port Fourchon.

As these vessels set up and begin skimming, they are grouped into task forces (TFs) as directed by the Operations Section of the Unified Command located at the command post.

Initial set-up and potential actions:

 A 1,000 meter safety zone has been established around the incident location for vessels

involved in Source Control

 The HOSS Barge is positioned facing the incident location just outside of this safety zone or at the point where the freshest oil is reaching the surface

 The HOSS Barge engages its Oil Spill Detection (OSD) system to locate the heaviest oil and maintains that ability for 24-hour operations

### Attachment 9-A Page 9

 The HOSS Barge deploys 1,320’ of 67” Sea Sentry boom on each side, creating a swath

w idth of 800’

 The Breton Island and H.I. Rich skim nearby, utilizing the same OSD systems as the HOSS Barge to locate and recover oil

 Two FRUs join this group and it becomes TF1

 The remaining 7 FRUs are split into a 2 and 3 vessel task force numbered TF2 and TF3

 A 95’ FRV is placed in each TF

 The boom barge (CGA 300) is positioned nearby and begins deploying auto boom in sections between two utility vessels (1,000’ to 3,000’ of boom, depending on conditions) with chain-link gates in the middle to funnel oil to the skimmers

 The initial boom support vessels position in front of TF2 and TF3

 A 100,000+ barrel offshore tank barge is placed with each task force as necessary to facilitate the immediate offload of skimming vessels

The initial task forces (36 hours in) may be structured as follows:

TF 1

 1

– 95’ FRV

 1

– HOSS Barge with 3 tugs

 2

– FRUs

 1

– 100,000+ barrel tank barge and associated tug(s)

 1

– Dedicated air asset for tactical direction

 8

– 500’ sections of auto boom with gates

 8

– Boom-towing vessel s

 2

– Support vessels (crew/utility)

TF 2

 1

– 95’ FRV

 4

– FRUs

 1

– 100,000+ barrel tank barge and associated tug(s)

 1

– Dedicated air asset for tactical direction

 10

– 500’ sections of auto boom with gates

 10

– Boom-towing vessels

 2

– Support vessels (crew/utility)

TF 3

 1

– 95’ FRV

 3

– FRUs

 1

– 100,000+ barrel tank barge and associated tug(s)

 1

– Dedicated air asset for tactical direction

 8

– 500’ sections of auto boom with gates

 8

– Boom-towing vessels

 2

– Support vessels (crew/utility)

### Attachment 9-A Page 10

Offshore skimming equipment continues to arrive in accordance with the ETA data listed in figure H.3a; this equipment includes 2 AquaGuard skimmers and 11 sets of Koseq Rigid Skimming Arms. These high volume heavy weather capable systems will be divided into functional groups and assigned to specific areas by the Operations Section of the Unified

Command.

At this point of the response, the additional TFs may assume the following configurations:

TF 4

 2

– Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs

 1

– AquaGuard Skimmer

 1

– 100,000+ barrel tank barge and associated tug(s)

 1

– Dedicated air asset for tactical direction

 2

– Support vessels (crew/utility)

 6

– 500’ sections of auto boom with gates

 6

– Boom-towing vessels

TF 5

 3

– Sets of Koseq Rigid Sk imming Arms w/ associated 200’+ PIDVs

 1

– AquaGuard Skimmer

 1

– 100,000+ barrel tank barge and associated tug(s)

 1

– Dedicated air asset for tactical direction

 2

– Support vessels (crew/utility)

 8

– 500’ sections of auto boom with gates

 8

– Boom-towing vessels

TF 6

 3

– Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs

 1

– 100,000+ barrel tank barge and associated tug(s)

 1

– Dedicated air asset for tactical direction

 2

– Support vessels (crew/utility)

 6

– 500’ sections of auto boom with gates

 6

– Boom-towing vessels

TF 7

 3

– Sets of Koseq Rigid Skimming Arms w/ associated 200’+ PIDVs

 1

– 100,000+ barrel tank barge and associated tug(s)

 1

– Dedicated air asset for tactical direction

 2

– Support vessels (crew/utility)

 6

– 500’ sections of auto b oom with gates

 6

– Boom-towing vessels

### Attachment 9-A Page 11

Near Shore Response Actions

Timing

 Put near shore assets on standby and deployment in accordance with planning based on the actual situation, actual trajectories and oil budgets

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

 Outfitting of VOOs for specific missions

 Deployment of assets based on actual movement of oil

Considerations

 Water depth, vessel draft

 Shoreline gradient

 State of the oil

 Use of VOOs

 Distance of surf zone from shoreline

 Sea state

 Tides

 Currents

Surveillance

 Provide trained observer to direct skimming operations

 Continual surveillance of oil movement by remote sensing systems, aerial photography

and visual confirmation

 Continual monitoring of vessel assets

Dispersant Use

 Dispersants are pre-approved with FOSC approval outside of 3 miles and the 10 meter depth curve and requires RRT VI approval inside 3 mile and/or 10 meter curve

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

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

Dedicated Near Shore skimming systems

 FRVs

 56’ shallow water skimmers

 Egmopol and Marco SWS (protected waters)

 Operate with aerial spotter directing systems to observed oil slicks

VOO

 Use Whistler ’s contracted resources as applicable

 Industry vessels are usually best for deployment of VOSS

 Acquire additional resources as needed

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

 Expect mission specific and safety training to be required

 Plan with the US Coast Guard for vessel inspections

 Operate with aerial spotter directing systems to oil patches

### Attachment 9-A Page 12

Shoreline Protection Operations

Response Planning Considerations

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

 Shoreline Cleanup Assessment Team (SCAT) assessments

 Time to acquire personnel and equipment and their availability

 Previous contingency planning contained in the appropriate ACP, Geographic Response Plan (GRP), and currently for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep Water Horizon, dated 2 May 2010

Actions

Placement of boom

 Position boom in accordance with the ERA based on the actual situation or the appropriate ACP or GRP.

 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

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

 Shoreline Cleanup and Assessment Team Reports and recommendations

 Determination of Archeological sites and gaining authority to enter

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

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

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

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

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

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

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

 Earthen berms and shoreline protection boom may be considered to protect sensitive

inland areas

### Attachment 9-A Page 13

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

### Attachment 9-A Page 14

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.

### Attachment 9-A Page 15 FIGURE 1

TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it impacting a land segment have been projected utilizing Whistler ’s WCD and information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BOEM website using 30 day impact. The results are tabulated below.

Area/Block OCS

- G Launch

Area Land Segment and/or

Resource Conditional

Probability (%)

within 30 days

Re

- enter 7 existing wells (Surface

Location GC 18 A platform) and

sidetrack to new

bottom hole locations

GC 18 A

76 miles from shore G04940 C43 Matagorda, TX Brazoria, TX Galveston, TX Jefferson, TX Cameron, LA Vermilion, LA Iberia, LA Terrebonne, LA Lafourche, LA Plaquemines, LA 2

1

3

2

7

3

1

3

1

2

### Attachment 9-A Page 16

WCD Scenario

–

BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (76 miles from shore) 117,973 bbls of crude oil (Volume considering natural weathering) API Gravity 29°

FIGURE 2

– Equipment Response Time to GC 18 A

Dispersants/Surveillance

Dispersant/Surveillance Dis persant Capacity (gal) Storage

Capacity Persons Req. From Hrs to

Procure Hrs to

Loadout Travel to

site Total Hrs

ASI

Basler 67T 2000 NA 2 Houma 2 2 0.6 4.6

DC 3 1200 NA 2 Houma 2 2 0.8 4.8

DC 3 1200 NA 2 Houma 2 2 0.8 4.8

Aero Commander NA NA 2 Houma 2 2 0.6 4.6

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 5 Harvey 7 0 8 9.4 1 25. 4

95’ FRV 12342 249 NA 4 Galveston 2 0 2 11 0 15

95’ FRV 12342 249 NA 4 Leeville 2 0 2 4 0 8

95’ FRV 12342 249 NA 4 Venice 2 0 3 5.5 0 10.5

Boom Barge (CGA

- 300) 42” Auto Boom (25000’) NA NA 1 Tug

50 Crew 4 (Barge)

2 (Per Crew) Leeville 12 0 6 12.9 2 32 .9

Recovered Oil Storage 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
Kirby Offshore Marine (available through CGA contract)

RO Barge NA 100000+ 1 Tug 6 Venice 45 0 2 13 0 60

RO Barge NA 100000+ 1 Tug 6 Venice 45 0 2 13 0 60

Enterprise Marine Services LLC (available through contract with CGA)

CTCo 2603 NA 25000 1 Tug 6 Amelia 46 0 2 12 0 60

CTCo 2604 NA 20000 1 Tug 6 Amelia 46 0 2 12 0 60

CTCo 2605 NA 20000 1 Tug 6 Amelia 46 0 2 12 0 60

CTCo 2606 NA 20000 1 Tug 6 Amelia 46 0 2 12 0 60

CTCo 5001 NA 47000 1 Tug 6 Amelia 46 0 2 12 0 60

### Attachment 9-A Page 17

### Attachment 9-A Page 18

Staging Area: Fourchon
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

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 11.4 7.5 1 35.9

Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 24 24 11.4 7.5 2 68.9

Koseq Skimming Arms (4) 71316 8000 4 Utility 24 Galliano 24 24 0.5 7.5 2 58

Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey 24 24 2.7 7.5 2 60.2

CGA

FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 2 2 11.4 7.5 1 23.9

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 2 2 2.7 7.5 1 15.2

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 16.5 7.5 1 29

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 2 6.8 7.5 1 19.3

FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Lee ville 2 2 0.4 7.5 1 12.9

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 2 2.7 7.5 1 15.2

FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 2 2 4.7 7.5 1 17.2

Hydro

- Fire Boom NA NA 8 Utility 40 Harvey 2 4 2.7 7.5 6 22.2

### Attachment 9-A Page 19 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

CGA

46’ FRV 5000 65 NA 4 Aransas Pass 2 0 2 11.5 0 15.5

46’ FRV 5000 65 NA 4 L ake Charles 2 0 3 3 0 8

46’ FRV 5000 65 NA 4 Morgan City 2 0 3 6 0 11

46’ FRV 5000 65 NA 4 Venice 2 0 3 12 0 17

Trinity SWS 21500 249 NA 4 Galveston 2 6 N/A 48 1 57

Trinity SWS 21500 249 NA 4 Morgan City 2 6 N/A 48 1 57

Kirby Offshore Marine (availabl e through CGA contract)

RO Barge NA 80000+ 1 Tug 6 Venice 23 0 2 35 0 60

Enterprise Marine Services LLC (available through contract with CGA)

CTCo 2607 NA 23000 1 Tug 6 Amelia 44 0 2 14 0 60

CTCo 2608 NA 23000 1 Tug 6 Amelia 44 0 2 14 0 60

CTCo 2609 N A 23000 1 Tug 6 Amelia 44 0 2 14 0 60

Staging Area: Cameron

Nearshore and Inland Skimmers

With Staging EDRC Storage Capacity VOO Persons Req. From Hrs to

Procure Hrs to

Load Out Travel to

Staging Travel to

Deployment Site Hrs to

Deploy Total

Hrs

CGA

SWS Egmopol 3000 100 NA 3 Galveston 2 2 3.6 2 1 10.6

SWS Egmopol 3000 100 NA 3 Morgan City 2 2 5.3 2 1 12.3

SWS Marco 3588 20 NA 3 Lake Charles 2 2 1.5 2 1 8.5

SWS Marco 3588 34 NA 3 Leeville 2 2 6.8 2 1 13.8

SWS Marco 3588 34 NA 3 Venice 2 2 9.2 2 1 1 6.2

Rope Mop 77 2 0 3 Harvey 2 2 7 2 1 14

Foilex Skim Package (TDS 150) 1131 45 NA 3 Lake Charles 2 2 1.5 2 1 8.5

Foilex Skim Package (TDS 150) 1131 45 NA 3 Galveston 2 2 3.6 2 1 10.6

Foilex Skim Package (TDS 150) 1131 45 NA 3 Harvey 2 2 7 2 1 14

3 We ir Skimmers (TDS 250) 12753 135 NA 9 Harvey 2 2 7 2 1 14

4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 2 2 1.5 2 1 8.5

4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 2 2 7 2 1 14

2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Lake Charles 2 2 1.5 2 1 8.5

2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Harvey 2 2 7 2 1 14

### Attachment 9-A Page 20 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

Deplo yment Site Hrs to Deploy Total Hrs

OMI Environmental (available through Letter of Intent)

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 3 11

10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 3.8 2 3 10.7

10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 1.4 2 3 8.4

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 Harvey 2 2 7 1 2 14

Bird Scare Guns (48) NA NA NA 2 Harvey 2 2 7 1 2 14

Bird Scare Guns (12) NA NA NA 2 Galveston 2 2 3.6 1 2 10.6

Bird Scare Guns (12) NA NA NA 2 Aransas Pass 2 2 9.9 1 2 16.9

Bird Scare Guns (24) NA NA NA 2 Lake Charles 2 2 1.5 1 2 8.5

Bird Scare Guns (24) NA NA NA 2 Leeville 2 2 6.8 1 2 13.8

Response Asset Total

Offshore EDRC 359,964

Offshore Recovered Oil Storage 364,447 +

Nearshore / Shallow Water EDRC 97,839

Nearshore / Shallow Water Recovered Oil Storage 150,718+Whistler Energy II, LLC Section 10

– Pg. 16 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 10

ENVIRONMENTAL MONITORING INFORMATION

10.1 MONITORING SYSTEMS There are no environmental monitoring systems currently in place or planned for the proposed

activities.

10.2 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 operati ons 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.

Whistler 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 Endangered Species Act (ESA) as a result of the operations conducted herein:

NTL No. 2012- BSEE

- G01, “Marine Trash and Debris Awareness and Elimination”

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

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

10.3 FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY Green Canyon Block 18 is not located in the Flower Garden Banks National Marine Sanctuary; therefore, relevant information is not required in this DOCD.Whistler Energy II, LLC Section 11

– Pg. 17 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 11

LEASE STIPULATIONS INFORMATION

Development activities are subject to the following stipulations attached to Lease OCS- G 04940

, (surface location) Green Canyon Block 18.

11. 1 MARINE PROTECTED SPECIES In accordance with the Federal Endangered Species Act and the Marine Mammal Protection Act, Whistler will:

(a) collect and remove flotsam resulting from activities related to exploration, development, and production of this lease;

(b) post signs in prominent places on all vessels and platforms used as a result of activities related to exploration, development, and production of this lease detailing the reasons (legal and ecological) why release of debris must be eliminated;

(c) observe for marine mammals and sea turtles while on vessels, reduce vessel speed to 10 knots or less when assemblages of cetaceans are observed, and maintain a distance of 90 meters or greater from whales, and a distance of 45 meters or greater from small cetaceans and sea turtles;

(d) employ mitigation measures prescribed by BOEM/BSEE or the National Marine Fisheries Service (NMFS) for all seismic surveys, including the use of an “exclusion zone” based upon the appropriate water depth, ramp-up and shutdown procedures, visual monitoring, and reporting;

(e) identify important habitats, including designated critical habitat, used by listed species (e.g., sea turtle nesting beaches, piping plover critical habitat), in oil spill contingency planning and require the strategic placement of spill cleanup equipment to be used only by personnel trained in less-intrusive cleanup techniques on beaches and bay shores; and

(f) immediately report all sightings and locations of injured or dead protected species (e.g., marine mammals and sea turtles) to the appropriate stranding network. If oil and gas industry activity is responsible for the injured or dead animal (e.g., because of a vessel strike), the responsible parties should remain available to assist the stranding network. If the injury or death was caused by a collision with the lessee’s vessel, the lessee must notify BOEM within 24 hours

of the strike.

BOEM and BSEE issue Notices to Lessees (NTLs), which more fully describe measures implemented in support of the above-mentioned implementing statutes and regulations, as well as measures identified by the U.S. Fish and Wildlife Service and NMFS arising from, among others, conservation recommendations, rulemakings pursuant to the MMPA, or consultation. The lessee and its operators, personnel, and subcontractors, while undertaking activities authorized under this lease, must implement and comply with the specific mitigation measures
outlined in NTL No. 2012-JOINT- G01, “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting;” NTL No. 2012 -JOINT- G02, “Implementation of Seismic Survey Mitigation Measures and Protected Species Observer Program;” and NTL No. 2012- BSEE

- G01, “ Marine Trash and Debris Awareness and Elimination.” At the lessee’s option, the lessee, its operators,Whistler Energy II, LLC Section 11

– Pg. 18 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 personnel, and contractors may comply with the most current measures to protect species in place at the time an activity is undertaken under this lease, including but not limited to new or updated versions of the NTLs identified in this paragraph. The lessee and its operators, personnel, and subcontractors will be required to comply with the mitigation measures, identified in the above referenced NTLs, and additional measures in the conditions of approvals for their plans or permits.Whistler Energy II, LLC Section 12

– Pg. 19 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 12
ENVIRONMENTAL MITIGATION MEASURES INFORMATION

12.1 MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS Green Canyon Block 18 (surface location) is not located within Florida; therefore, mitigation information is not required for the activities proposed in this plan.

12.2 INCIDENTAL TAKES Whistler 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 Endangered Species Act (ESA) as a result of the operations conducted herein:

 NTL No. 2012

- BSEE

- G01, “Marine Trash and Debris Awareness and Elimination”

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

 NTL No. 2012 -JOINT- G02, “Implementation of Seismic Survey Mitigation Measures and Protected Species Observer Program”Whistler Energy II, LLC Section 13

– Pg. 20 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
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## SECTION 13
RELATED FACILITIES AND OPERATIONS INFORMATION

13.1 RELATED OCS FACILITIES AND OPERATIONS

Whist ler’s t wo wells in Green Canyon Block 60 flow via existing 6-inch bulk oil pipeline Segments 10999 and 18229 (approximately 7.6 miles in length) to the Green Canyon Block 18 A platform. The platform is a 30 -slot 4 pile platform and processes production from platform wells with bottom holes in Green Canyon Block 18 and Ewing Bank 988. Separated and measured gas production is transported via existing 10 -inch right- of -way gas pipeline Segment 8411 (approximately 7.06 miles in length) to a 16-inch subsea tie-in located in Ewing Bank Block 990 for ultimate delivery into Operations Systems No. 26.5 and 24.0. Separated and measured liquid hydrocarbons are transported via existing 10-inch oil right- of -way pipeline Segment 7905 (approximately 3.05 miles in length) to a 16-inch subsea tie-in located in Ewing Bank Block 989 for ultimate delivery into Operations System No. 29.5. The flowlines will have a

shut-in time of 45 seconds.

13.2 TRANSPORTATION SYSTEM Produced hydrocarbons will be transported as described above.

13.3 PRODUCED LIQUID HYDROCARBONS TRANSPORTATION VESSELS There will not be any transfers of liquid hydrocarbons other than via pipeline.Whistler Energy II, LLC Section 14

– Pg. 21 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 14

SUPPORT VESSELS AND AIRCRAFT INFORMATION

14.1 GENERAL The most practical, direct route from the shorebase as permitted by weather and traffic

conditions will be utilized.

Type Maximum Fuel

Tank Capacity Maximum Number in Area at Any
Time Trip Frequency

or Duration

Tug Boat N/A N/A N/A

Anchor Handling Boat N/A N/A N/A

Crew Boat 500 gals 

### 1 7

Supply Boat 5 00 gals 

### 1 7

Helicopter 560 gals 

### As required

14.2 DIESEL OIL SUPPLY VESSELS Size of Fuel Supply

Vessel Capacity of Fuel

Supply Vessel Frequency of Fuel
Transfers Route Fuel Supply

Vessel Will Take

180’ 1500 1 X weekly Shortest route from
Shorebase to bl ock

14.3 DRILLING FLUID TRANSPORTATION Drilling fluid transportation information is not required to be submitted with this plan.

14.4 SOLID AND LIQUID WASTE TRANSPORTATION A table, “ Wastes You Will Transport and/or Dispose of Onshore, ” is included as Attachment 14

- A.

14.5 VICINITY MAP 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 routes of the support vessels and aircraft that will be used when traveling between the onshore support facilities and the platform is included as Attachment 14 -B.Projected generated

waste Solid and Liquid Wastes transportation

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

bbl/well Disposal Method
Oil-based drilling fluid or mud N/A N/A N/A N/A N/A

Synthetic-based drilling fluid or mud N/A N/A N/A N/A N/A

Cuttings wetted with Water-based fluid N/A N/A N/A N/A N/A

Cuttings wetted with Synthetic-based fluid N/A N/A N/A N/A N/A

Cuttings wetted with oil-based fluids N/A N/A N/A 50 Approved onshore disposal

Well treatment fluids Acid blends Deck level holding tanks on offshore support velles Galliano Waste, Galliano, LA 1500 Recycled

Well completion fluids Weighted brines Deck level holding tanks on offshore support velles Galliano Waste, Galliano, LA 1500 Recycled

Produced sand Produced sand Cuttings boxes Galliano Waste, Galliano, LA 25 Landfill

trash and debris (Non-Recyclables) Plastic, paper, aluminum Trash basket Galliano Waste, Galliano, LA 10500 Landfill

used oil Used oil 550 tote tank on supply boat Martin Energy, Fouchon, LA 10 Recycled

wash water N/A N/A N/A NA N/A

Oily rags, absorbent pads Rags and oil DOT drums Martin Energy, Fourchon, LA 5 Approved Disposal
trash and debris (Recyclables) Trash and recycleables Trash basket Galliano Waste, Galliano, LA 10 Recycled

Chemical product wastes Chemicals Disposal tanks - 25bbl American Recovery, Houma, LA 100 Recycled

Batteries Batteries Battery basket American Recovery, Houma, LA 0.1 Recycled Waste Disposal 

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

Attachment 14-AWhistler Energy II, LLC Section 15

– Pg. 22 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
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## SECTION 15

ONSHORE SUPPORT FACILITIES INFORMATION

15.1 GENERAL

Name Location Existing/New/Modified Newpark Base Port Fourchon, Louisia na Existing

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

15.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE A support base construction or expansion timetable is not required for the activities proposed in this plan

.

15.4 WASTE DISPOSAL A table, “ Wastes You Will Transport and/or Dispose of Onshore, ” is included as Attachment 14-

A

.Whistler Energy II, LLC Section 16

– Pg. 23 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 16 COASTAL ZONE MANAGEMENT (CZM) INFORMATION

Coastal Zone Management Information is not required for the activities proposed in this plan.Whistler Energy II, LLC Section 17

– Pg. 24 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SECTION 17

ENVIRONMENTAL IMPACT ANALYSIS (EIA)

The Environmental Impact Analysis is included as Attachment 17- A.

### Attachment 17-A Page 1



# Whistler Energy II, LLC (Whistler)

Revised Development Operations Coordination Document Green Canyon Block 18 and Ewing Bank Block 988

OCS- G 04940 and 05809

(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

disturbance s to the seafloor (rig or

anchor emplacements, etc.) Wastes sent

to shore for

treatment or disposal Accidents

(e.g., oil spills,

chemical spills, H 2 S releases) Discarded

Trash &

Debris

Site

- specific at Offshore

Location

Designated topograph ic features (1) (1) (1)

Pinnacle Trend area live bottoms (2) (2) (2)

Eastern Gulf live bottoms (3) (3) (3)

Benthic communities (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

Ai r quality X(9)

Shipwreck sites (known or potential) X (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

### Attachment 17-A Page 2

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:

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 (LowRelief) Stipulation attached to an OCS lease. 4) Activities on blocks designated by th e 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.

### Attachment 17-A Page 3



## (B) ANALYSIS

Site-Specific at Green Canyon Block 18 and Ewing Bank Block 988

Proposed operations consist of the re -entry into GC 18 (current bottomhole location) #A-23 and drill to a new target in EW 988 (new bottomhole location) from the existing GC 18 “A” platform.

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: Green Canyon Block 18 and Ewing Bank Block 988 are 8 miles from the closest designated Topographic Features Stipulation Block (Ewing-1 Bank); therefore, no adverse impacts are expected.

Effluents: Green Canyon Block 18 and Ewing Bank Block 988 are 8 miles from the closest designated Topographic Features Stipulation Block (Ewing-1 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 Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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.

### Attachment 17-A Page 4

Physical disturbances to the seafloor: Green Canyon Block 18 and Ewing Bank Block 988 are 151 miles from the closest live bottom (pinnacle trend) area; therefore, no adverse impacts are expected.

Effluents: Green Canyon Block 18 and Ewing Bank Block 988 a re 151 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 Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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: Green Canyon Block 18 and Ewing Bank Block 988 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: Green Canyon Block 18 and Ewing Bank Block 988 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 Whistler’s Regional OSRP (refer to information submitted in

Section 9 ).

### Attachment 17-A Page 5

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
There are no IPFs (including emissions, physical disturbances to the seafloor, wastes sent to shore for disposal, or accidents) from the proposed activities that could cause impacts to benthic

communities.

Operations proposed in this plan are in water depths of 750 feet. High-density benthic communities are found only in water depths greater than 984 feet (300 meters); therefore,

Whistler’s proposed operations in Green Canyon Block 18 and Ewing Bank Block 988 would not cause impacts to benthic communities.

5. Water Quality

IPFs that could result in water quality degradation from the proposed operations in Green Canyon Block 18 and Ewing Bank Block 988 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: Le vels 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 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

### Attachment 17-A Page 6

covered by Whistler’s Regional Oil Spill Response Plan (refer to information submitted in

Section 9 ).

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 Green Canyon Block 18 and Ewing Bank Block 988 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 Fisher men’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 downcurrent 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 Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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,

### Attachment 17-A Page 7

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 Green Canyon Block 18 and Ewing Bank Block 988 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).

Whistler 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 Whistler management or the designated lease operator management that emphasizes their commitment to waste management in accordance

with NTL No. 2012-G01.

### Attachment 17-A Page 8

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

ma mmals 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 Whistler’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 Whistler’s OSRP (refer to

information submitted in accordance with Section 9 ).

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.

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).

### Attachment 17-A Page 9

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). Whistler 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 Whistler 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 vesse l 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. 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 Whistler’s Regional Oil Spill Response Plan (refer to

information submitted in accordance with Section 9 ).

### Attachment 17-A Page 10

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

9. Air Quality

The projected air emissions identified in Section 8 are not expected to affect the OCS air quality primarily due to distance to the shore or to any Prevention of Significant Deterioration Class I air quality area such as the Breton Wilderness Area. Green Canyon Block 18 and Ewing Bank Block 988 are beyond the 200 kilometer (124 mile) buffer for the Breton Wilderness Area and are 76 miles from the coastline. Therefore, no special mitigation, monitoring, or reporting requirements apply with respect to air emissions.

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 distance of Green Canyon Block 18 and Ewing Bank Block 988 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 could impact air quality.

10. Shipwreck Sites (known or potential)
IPFs that could cause impacts to known or unknown shipwreck sites as a result of the proposed operations in Green Canyon Block 18 and Ewing Bank Block 988 are disturbances to the

seafloor.

Physical Disturbances to the seafloor: Ewing Bank Block 988 is located within the area designated by BOEM as high-probability for occurrence of shipwrecks. Whistler will report to BOEM the discovery of any evidence of a shipwreck 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 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 Whistler’s Regional Oil Spill Response Plan (refer to

information submitted in accordance with Section 9 ).

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 Green Canyon Block 18 and Ewing Bank Block 988 are physical disturbances to the seafloor and accidents (oil spills).

### Attachment 17-A Page 11

Physical Disturbances to the seafloor: Green Canyon Block 18 and Ewing Bank Block 988 are located inside the Archaeological Prehistoric high probability lines. Wh istler 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 Whistler’s Regional Oil Spill Response Plan (refer to information submitted in accordance with Section 9 ).

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

1. Essential Fish Habitat (EFH)

IPFs that could cause impacts to EFH as a result of the proposed operations in Green Canyon Block 18 and Ewing Bank Block 988 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 live-bottom 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 W histler’s Regional OSRP (refer to information

submitted in Section 9 ).

### Attachment 17-A Page 12

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 be affected to that extent. The activities proposed in this plan will be covered by

Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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 anddeath. Operators are prohibited from deliberately discharging debris as mandated by MARPOLAnnex 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). Whistler 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

ac cidental 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 Whistler 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.

### Attachment 17-A Page 13

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 Section 4 to justify our request that our proposed activities be classified by BSEE as H 2 

### S absent.

Coastal and Onshore

1. Beaches

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

Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches and associated resources. Due to the distance from shore (76 mi les) and the response capabilities that would be implemented, no significant adverse impacts are expected. The activities proposed in this plan will be covered by Whistler’s Regional OSRP (refer to information submitted in

Section 9 ).

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). Whistler 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 Whistler management or the designated lease operator management that emphasizes their commitment to waste management in accordance

with NTL No. 2012-G01.

### Attachment 17-A Page 14

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

sp ills) 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 (76 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be covered by Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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 regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Whistler 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 Whistler 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 (76 miles) and the response capabilities that would be

### Attachment 17-A Page 15

implemented, no impacts are expected. The activities proposed in this plan will be covered by

Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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). Whistler 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 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 Whistler ma nagement 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 (76 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be covered by Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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). Whistler 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

### Attachment 17-A Page 16

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 sl eeping 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 Whistler 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 (178 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 Whistler’s Regional OSRP (refer to information submitted in Section 9 ).

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). Whistler 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 whenhandling 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 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 Whistler management or the designated lease operator management that emphasizes their commitment to waste management in accordance

with NTL No. 2012-G01.

### Attachment 17-A Page 17

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

condition s.

(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 location in the gulf, Gr een Canyon Block 18 and Ewing Bank Block 988 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.

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 wit h 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.

### Attachment 17-A Page 18

(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

(I ) REFERENCES

Authors:

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

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

Tech. Memo. NOAA- TM -NMFS-SWFC-54. Pp 387-429.

Bu rke, 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.

### Attachment 17-A Page 19

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. BLMYK

- 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:

 Hazard Surveys

 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.Whistler Energy II, LLC Section 18

– Pg. 25 of 25 Supplemental DOCD February 2, 2015 Ewing Bank Block 988
OCS-G 05809 

## SEC TION 18

ADMINISTRATIVE INFORMATION

18.1 EXEMPTED INFORMATION DESCRIPTION The proposed bottomhole location of the planned well has been removed from the Public Information copy of the DOCD as well as any discussions of the target objectives, geologic or

ge ophysical data, and any interpreted geology.

18.2 BIBLIOGRAPHY

1. Supplemental DOCD (Control No. S-2880); approved December 23, 1992.

2. Revised DOCD (Control No. R-06208); approved January 21, 2015