UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field Operations (MS 5231)

Public Information copy of DOCD

Control # - S-07643

Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS- 00599 Block - 63 South Timbalier Area

OCS- 00605 Block - 86 South Timbalier Area

Operator - Energy Resource Technology GOM, Inc.

Wells E006, E007, E008, E009, Install Platform M and Wells
M001, M002, and M003

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.

Michelle Griffitt

Plan Coordinator

00605/ST/86

00599/ST/63

00605/ST/86

00599/ST/63

00599/ST/63

00605/ST/86

00605/ST/86 24 FNL, 2798 FWL

1968 FNL, 7795 FEL

1999 FNL, 7789 FEL

1965 FNL, 7779 FEL

1959 FNL, 7783 FEL

24 FNL, 2798 FWL

24 FNL, 2798 FEL

24 FNL, 2798 FEL 00605/ST/86

00605/ST/86

00605/ST/86

00605/ST/86

00605/ST/86

00605/ST/86

00605/ST/86

00605/ST/86 FIXED/M

WELL/E006

WELL/E007

WELL/E008

WELL/E009

WELL/M001

WELL/M002

WELL/M003 Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk Site Type/Name Description -

Rig Type - Subject: From: May 5, 2014

## P UBLIC INFORMATION COPY

November 20, 2013



## SUPPLEMENTAL DEVELOPMENT OPERATIONS

COORDINATION DOCUMENT

Lease Number: OCS-G 00599/00605

Area/Block: South Timbalier Blocks 63/86

Prospect Name: NA

Offshore: Louisiana

Submitted by: Energy Resource Technology GOM, Inc. 500 Dallas St., Suite 2000 Houston, TX 77002-4800



### Melissa Logan (713 ) 328-3016 Mlogan@talosenergyllc.com

Estimated start-up date: July 1, 2014

Authorized Representative: No . Copies Being Submitted:
Cathy Thornton Proprietary: 1 + 1 CD J. Connor Consulting, Inc. Public Info: 1 + 1 CD 16225 Park Ten Place, Suite 700 Houston, Texas 77084 For BOEM : (281) 705

- 8020 Plan No. cathy.thornton @jccteam.com Assigned to:Rec ord of Changes

Date Appendix Revision

12/19/2013 A Amended to include discussion for the installation of Platform M

12/19/2013 A Amended the Form BOEM

- 0138 Plan Information Form for the proposed wells to remove the anchor radius

12/19/2013 A Include d a Form BOEM

- 0138 providing for the installation of

Platform M

12/19/2013 G Added Table 1 Wastes and Discharges Information

12/19/2013 N Amended Solid and Waste Transportation section to include reference that the wastes and discharges information was i ncluded in Appendix O

12/28/2013 A Amended the Form BOEM

- 0138 to correct the TD depth of Well

Location B

01/16/2014 G Amended Table 1 Wastes and Discharges Information to remove cuttings from synthetic

- based fluids and to provide estimated discharge rat es for well treatment and completion fluids

02/06/2014 G Recalculated discharges and amended Table 1 Wastes and Discharges Information

03/17/2014 D A mended Appendix D regarding H2S determination. This has been

amended to reflect that the H2S is confine d to the E platform.

04/14/2014 A Amended the Form BOEM

- 0138 Plan Information Form to update the Activity Schedule with a estimated start date of 07/01/ 2014U.S. Department of the Interior OMB Control Number: 1010- 0151

Bureau of Ocean Energy Management OMB Approval Expires: 12/31/14

OCS PLAN INFORMATION FORM

General Information

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

Company Name: Energy Resource Technology GOM, Inc. BOEM Operator Number: 02899

Address: 500 Dallas Street, Suite 2000 Contact Person: Cathy Thornton

Houston, Texas 77002 Phone Number: 713

- 705

- 8020

Email Address: cathy.thornton@jccteam.com

If a service fee is required under 3 0 CFR 550.125(a), provide the Amount paid $29,666.00 Receipt No. 25D7IUEP

Project and Worst Case Discharge (WCD)Information

Lease(s): OCS 00599/00650 Area: ST Block(s): 63/86 Project Name (if applicable):

Objective(s): X Oil X Gas Sulphur Salt Onsh ore Support Base(s):

Platform/Well Name: E

- Aux/M Total Volume of WCD: 6 705 API Gravity: 37°

Distance to Close s t Land (Miles): 19.4 Volume from uncontrolled blowout: 4270

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

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

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

Do you propose to use a vessel with ancho rs 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 S tart Date End Date No. of Days

D&C Loc A & B; D&TA Loc E 07/01/2014 09/2 8 /2014 90

D&C Loc F; Complete Loc E 0 3 /01/201 5 05/11/2015 72

D&C Loc C & D 03/01/2016 04/29/2016 60

D&C Loc G 03/01/2017 04/23/201 7 54

Installation or modification of structure 0 6 /01 /201 5 0 6 /05/201 5 5
Installation of production facilities 06/ 06/201 5 09/1 1 /201 5 5

Installation of subsea wellheads and/or manifolds

Installation of lease term pipelines 0 6 /20/201 5 09/30/201 5 10
Commence production 07 / 01 /2014
Other (Specify and attach description)

Description of Drilling Rig Description of Structure

X Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform Rig X Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed tower

DP Semisu

bmersible 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)

ST86 M platform ST63 A platform 6

- inches 10,500’

ST63 A platform ST86 M platform 3

- inches 10,500’

FORM BOEM- 0137 (December 2011 - Supersedes all previous editions of this form which may not be used. Page 1 of 4

## P ublic Information Copy

November 20, 2013



## SUPPLEMENTAL DEVELOPMENT OPERATIONS

COORDINATION DOCUMENT

Lease Number: OCS-G 00599/00605

Area/Block: South Timbalier Blocks 63/86

Prospect Name: NA

Offshore: Louisiana

Submitted by: Energy Resource Technology GOM, Inc.
500 Dallas St., Suite 2000
Houston, TX 77002-4800



### Melissa Logan (713 ) 328-3016 Mlogan@talosenergyllc.com

Estimated start-up date: April 1, 2014

Authorized Representative: No . Copies Being Submitted:
Cathy Thornton Proprietary: 1 + 1 CD J. Connor Consulting, Inc. Public Info: 1 + 1 CD
16225 Park Ten Place, Suite 700
Houston, Texas 77084 For BOEM : (281) 705

- 8020 Plan No. cathy.thornton @jccteam.com Assigned to:Rec ord of Changes

Date Appendix Revision

12/19/2013 A Amended to include discussion for the installation of Platform M

12/19/2013 A Amended the Form BOEM

- 0138 Plan Information Form for the proposed wells to remove the anchor radius

12/19/2013 A Include d a Form BOEM

- 0138 providing for the installation of

Platform M

12/19/2013 G Added Table 1 Wastes and Discharges Information

12/19/2013 N Amended Solid and Waste Transportation section to include reference that the wastes and discharges information was i ncluded in Appendix O

12/28/2013 A Amended the Form BOEM

- 0138 to correct the TD depth of Well

Location B

01/16/2014 G Amended Table 1 Wastes and Discharges Information to remove cuttings from synthetic

- based fluids and to provide estimated discharge rat es for well treatment and completion fluids

02/06/2014 G Recalculated discharges and amended Table 1 Wastes and Discharges Information

03/17/2014 D A mended Appendix D regarding H2S determination. This has been amended to reflect that the H2S is confined to the E platform.ENERGY RESOURCE TECHNOLOGY GOM, INC.

SUPPLEMENTAL

DEVELOPMENT OPERATIONS COORDINATON DOCUMENT

LEASE S OCS

- G 00 599/00605

SOUTH TIMBALIER BLOCK S 63/86

APPENDIX A Plan Contents

APPENDIX B General Information

APPENDIX C Geological, Geophysical Information

APPENDIX D H2S Information

APPENDIX E Mineral Resources Conservation Information

APPENDIX F Biological

, P hysical and Socioeconomic Information

APPENDIX G Wastes and Discharge Information

APPENDIX H Air Emissions Information

APPENDIX I Oil Spill s Inf ormation

APPENDIX J Environmental Monitoring Information

APPENDIX K Lease Stipulations Information

APPENDI X L Environmental Mitigation Measures Information

APPENDIX M Related Facilities and Operations Information

APPENDIX N Support Vessels and Aircraft Information

APPENDIX O Onshore Support Facilities Information

APPENDIX P Coastal Zone Management Act (CZM A) Information

APPENDIX Q Environmental Impact Analysis

APPENDIX R Administrative InformationEnergy Resource Technology GOM, Inc. Page A

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 

### APPENDIX A

PLAN CONTENTS

( A ) PLAN INFORMATION FORM Under this DOCD, ERT proposes to drill, complete and produce Well Locations A, B , C and D

from the South Timbalier Block 86 E

- Aux platform ( to be designated Lease OCS 00605 Well Nos. E006 through E00 9 ) , drill and complete Well Locations E (OCS 00599 Well No. 25)

, and F

and G (Lease OCS 00650 Well Nos. 30 and 31), install proposed 4

- pile 4

- slot M platform over the surface location of Well Locations E, F and G (to be renamed Well Nos. M 001 through

M 003), and install a proposed 6

- inch bulk gas lease term pipeline to be installed from the M

p latform t o the South Timbalier Block 63 A platform and a proposed 3

- inch supply lease term pipeline from South Timbalier Block 63 A p latform t o the proposed M p latform

. These development operations are located in approximately 90

- 100 feet of water. The wells will be

drilled with a jack

- up rig

.

Platform s E /E

- Aux were instal led in 19 94 and 2011, respectively. Well Nos. E001 thr ough E005 were drilled, completed and produced from the E /E

- Aux platform s under previously approved

Plans.

See attached OCS Plan I nformation Form (s)

– Form BOEM

- 137 , included in Attachment A

.

( B ) LOCATION

Included in Attachment A are location plats depicting the existing and proposed surface

location s and water depth of each proposed well.

The existing E /E

- Aux platforms are 4

- pile bridge connected structure s. Each platform has 3

decks a nd 6 slots. The proposed M platform will be a tripod structure which will be installed utilizing a derrick barge

. Included in Attachme nt A is a schematic of the proposed M p latform.

( C ) SAFETY AND POLLUTION PREVENTION FEATURES A description of the drilling unit is included on the OCS Plan Information Form. Rig specifications will be made part of each Application for Permit to Drill

. There are no new pipelines or construction proposed under this Plan.

Safety features on the drilling unit will incl ude well control, pollution prevention, and blowout prevention equipment as described in Title 30 CFR Part 250, Subparts C, D, E, and F ; and as further clarified by BOEM Notices to Lessees, and current policy making invoked by the BOEM

, Environmental Prote ction Agency and the U.S. Coast Guard. Appropriate life rafts, life jackets, ring buoys, etc., will be maintained on the facility at all times.

Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on drilling deck a reas to collect all contaminants and debris.Energy Resource Technology GOM, Inc. Page A

- 2

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) ( D ) STORAGE TANKS AND PRODUCTION VESSELS All facility t anks with a capacity of 25 bbls or more.

Type of Storage Tank Type of

Facility Tank Capacity

(bbls) Number

of Tanks Total Capacity

(bbls) Fluid Gravit y

(API) Fuel Oil (Marine Diesel) MODU 600 4 2800 3 8°

Production PF E 300 1 300 3 7°

( E ) ADDITIONAL MEASURES

ERT does not propose additional safety, pollution prevention, or early spill detection measures beyond those required by 30 CFR 250.

( F ) C OST RE COVERY FEE

Included in Attachment A is a pay.gov receipt in the amount of $ 2 9, 666 .00 to cover o perations proposed in this plan.Energy Resource Technology GOM, Inc. Page B

- 1

Supplemental DOCD November 20, 2013 South Timbalier Blocks 63/86 (OCS-G 00599/00605) 

### APPENDIX B

GENERAL INFORMATION

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

Application/Permit Issuing Agency Status

APD B SEE Pending Surface Commingling and Measurement Application BSEE Pending Lease Term Pipeline Application BSEE Pending

(B) DRILLING FLUIDS Wells A, B, C & D from E-Aux Platform

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

Water

- based (Seawater, freshwater, barite) 9000

Oil

- based (diesel, minerals, oil) 0
Synthetic

- based (internal o lefin, ester) 0

Wells E, F, G from open water location

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

Water

- based (Seawater, freshwater, barite) 2500

Oil

- based (diesel, minerals, oil) 0
Synthetic

- based (internal o lefin, ester) 0

(C ) PRODUCTION Anticipated Production:

Type Average Production Rate Peak Production Rate Life of Reservoir

Oil

Gas

(D ) OIL CHARACTERISTICS Oil characteristics are not required to be submitted with this plan.Energy Resource Technology GOM, Inc. Page B

- 2

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) ( E ) NEW OR UNUSUAL TECHNOLOGY

ERT does not propose to use any new or unusual technology to carry out the proposed development activities.

( F ) BONDING STATEMENT

The bond requirements for the activities an d facilities proposed in this EP are satisfied by a $3,000,000.00 areawide development bond, furnished and maintained according to 30 CFR 256,

s ubpart I; NTL No. 2000

- G16, "Guidelines for General Lease Surety Bonds ; " and additional security under 30 CFR 25 6.53(d) and National NTL No. 2008

- N07, “Supplemental Bond

Procedures.”

( G ) OIL SPILL FINANCIAL RESPONSIBILITY (OSFR)

ERT

, BOEM company number 02899 has demonstrated oil spill financial responsibility for the facilities proposed in th is DOCD according to 30 CFR Part 253; and NTL No. 99

- N01, "Guidelines for Oil Spill Financial Responsibility for Covered Facilities".

( H ) DEEPWATER WELL CONTROL STATEMENT Operations proposed in this plan are located in water depths less than 300 meters (984 feet).

( I ) SU SPENSION OF PRODUCTION

South Timbalier Blocks 63/86 are currently held by production.

( J ) BLOWOUT SCENARIO

Blowout Scenario: The proposed well has drilled the production hole interval with all potential producible hydrocarbon sands (PPHS) exposed. A blowout occurs. As per NTL 2010 N06, the BOP is not connected to the wellhead and the wellbore is free of drill pipe, logging tools, or other similar equipment resulting in an unrestricted and uncontrolled blowout thru the borehole and wellbore.

A wellbo re schematic with the required data, plats and directional survey are included in this information package.

Worst Case Discharge : The calculated worst case discharge (WCD) rate for the scenario described above would be from 3 PPHS in the production hole interval. The calculated WCD from the exposed PPHS would be 4270 BOPD, 199 MMCFGPD and 0 BWPD. The WCD is based on nodal analysis using field analog reservoir data.

Maximum duration of the potential blowout: The maximum duration of an uncontrolled

blo wout depends on the time it takes for either the well to bridge over or killed by surface intervention or relief well intervention. Each scenario is described in the subsequent paragraphs below. The table below summarizes the maximum duration of a potent ial blowout for each

scenario.Energy Resource Technology GOM, Inc. Page B

- 3

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) Scenario Blowout Duration Oil Discharge*

Well Bridges Over 48 to 72 hrs 8540 bbls to 12,810 bbls

Surface Intervention 9 to 13 days 38,430 bbls to 55,510 bbls

Drill Relief Well 31 days 132,370 bbls
*Assumes no declining oil cut

Potential of well to bridge over: History has shown that most “open hole” blowouts bridge

over in 48 to 72 hrs. BOE M reported that 49% of all blowout events during 1992

– 2006 stopped flowing in 24 hrs or less, 41% lasted between 1 to 7 days an d the longest blowout lasted 11 days. Over 50% of blowouts were controlled by surface intervention, 36% of the blowouts bridged over and the rest depleted. Two relief wells were initiated but both blowouts were controlled by other means prior to completi ng the relief well. Shallow gas was associated with 49% of the blowouts. 16 of 20 shallow gas blowouts were successfully diverted until the well bridged over.

T he PPHS in the ST 63 “B” well are normally pressured, unconsolidated and friable, therefore

m aking “ bridging ” likely in a blowout event. The targeted unconsolidated sands are at a shallow depth on top of a salt dome cap rock feature. These unconsolidated PPHS have been

encountered in other wells in the field , which is the primary motivation for drilling th e well. The estimated bottom hole pressure of the 3700’ A Sand is 2074 psi, the 3700’ B Sand is 2136 psi and the 3800’ Sand is 2155 psi. The open hole interval with the hydrocarbon bearing sands will

be drilled at 46.99 o inclination. The obje ctive sands are normally pressured with depletion and partial water drives as noted in the nodal analysis and require sand control completions to prevent them from sanding up. These PPHS characteristics facilitate formation collapse and bridging if an unc ontrolled blowout event occurred

Likelihood of surface intervention: A blowout specialty company/well control team would be mobilized immediately. Well control specialists would conduct a “fly by” in a helicopter within

12 hrs to assess conditions at th e well site. Equipment and well control personnel would be mobilized to the rig site on boat and barge within 24 to 36 hrs after a blowout has been reported. After arriving on location, the well control team typically needs 2 to 3 days to analyze the

blo wout situation, devise an intervention strategy and mobilize additional service company specialists, supplies and equipment. A field support base or command center will be identified, set up and communications established.

Surface intervention would be v ery likely if the wellbore is intact and above the water. The intervention could include snuffing out the fire, installing specialized BOPE and performing a top kill. Many wells bridge over during this time and subsequently, BOPE equipment is installed

t o secure the well. If the well does not bridge over and continues to blowout, well control companies estimate an additional 7 to 10 days are typical to contain the flow and kill the well. Therefore, the estimated time to kill a blowout with surface inte rvention is 9 to 13 days.Energy Resource Technology GOM, Inc. Page B

- 4

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) ERT GOM has Master Service Contracts in place with Cudd Pressure Control, Wild Well Control and Boots & Coots, which are diversified well control services companies offering full general contracting services with strong engineer ing component resources.

Relief well : In the event of an uncontrolled blowout, relief well planning and rig availability inquiries would commence immediately. The SHL of the ST 63 “B” well is on the ST 86 “E

Aux” platform in 98’ WD. There are 32 rigs in the GOM which are working and capable of drilling a relief well with an open water location in ST 86. ERT GOM has alliances with diversified engineering consulting firms which would provide ERT GOM relief well operations, engineering, logistical, mater ials management, QA/QC and well

- site supervision support. Rig contracts are in place with all GOM jack

- up rig contractors.

There are no known rig package constraints for a relief well. Therefore, the rig choice would be first available, quickest to mob ilize and move into position offsetting the blow out well. Typical GOM relief well rig open water location will be about 1500’ south or southeast of the blow out well. The final rig location will be influenced by operator, contractor and BSEE to

insure s afety of all personnel and equipment involved in the relief well effort.

There are no suitable platforms in the area which would provide an advantage for drilling

the relief well. A relief well could not be drilled from an onshore location.

The estimate d time to drill a relief is summarized in the table below:

Description Estimated Days Cumulative Days

Conduct site assessment 3 3 Secure rig and Mobilize 6 9

Drive 30”. Install diverter. 3 12 Drill 26” hole to 800’ and set 20” conductor casing. 2 14

Drill surface hole and set 13

- 3/8” surface casing. 7 21 Drill to within 50’ MD of intercept and set 9

- 5/8” casing 5 26

Drill to intercept point of blowout well 2 28 R/U pumping equipment and kill well 3 31

Proposed m easures to enhance the ability to prevent a blowout and reduce the likelihood of

a blowout : Preventing a blowout starts with preventing a well control incident or “kick”. In order to prevent a “kick”, a thorough understanding of the geology, reservoir characteristics and field/area produ ction history is needed. Key offset wells are identified and drilling records of these wells are studied in great detail and used in well planning. Specifically, this information is used for lithology correlation, abnormal pressure formation prediction, mud weight schedule, casing design, and other potential geological risk identification such as depleted or weak zones, ballooning formations, sloughing shale, gumbo and hole instability. This research reduces the

risk of a well control incident.Energy Resource Technology GOM, Inc. Page B

- 5

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) Hydrosta tic control of the well will be maintained by utilizing a drilling fluid (mud) which exerts sufficient hydrostatic pressure to prevent the unintended flow of wellbore fluids or “kick” during drilling operations. All Drilling Fluid Requirements per 30 CFR 250 Subpart D 250.455 thru 250.458 will be implemented while drilling ST 63 “B” location

.

The ST 63 “B” well will be drilled using mud weights as per the well plan’s mud weight schedule. Mud weight adjustments will be made based on observed drilling para meters including rate of penetration, cuttings quantity and appearance, chloride contamination and gas monitoring. In the event drilling parameters indicate a potential for a “kick”, the drilling operations will cease and a flow check will be performed. Penetration rate will be controlled while drilling thru any hydrocarbon sand. Two mud engineers will work 12 hr shifts providing 24 hr mud engineering support during drilling operations. Two “shaker” men working 12 hr shifts continuously monitor mud weig ht and returns at the shakers. Electronic PVT equipment will be utilized throughout all drilling operations.

Mud properties including viscosity and gel strengths will be adequately maintained in an effort to reduce the possibility of swab and surge duri ng tripping operations. Displacement volumes will be monitored and recorded during all tripping operations. A heavy slug will be pumped when possible before trips so that the pipe can be pulled dry and the hole more accurately monitored.
As a minimum, a volume equal to the annular volume will be circulated before pulling out of the hole. Pipe trip speeds will also be adjusted as such not to cause swab or surge pressures.

Adequate mud and chemicals will be kept on board the rig to ensure well control a t all times. Sea water will be available and ready to pump down hole if a high volume loss circulation zone

is encountered. This will enable immediate stabilization of the well until additional mud can be

mixed . If lost circulation occurs and well condi tions allow, pipe may be p ulled up into the casing shoe.

Short trips and wiper trips will be performed as the hole conditions dictate or periodically during prolonged drilling intervals to monitor and assess any change in hole conditions. These trips als o help reduce the risk of swab and surge related problems.

Gas

- detecting equipment will monitor all drilling fluid returns. Mudlogging services will commence below 2500’ and will be used to monitor wellbore conditions. Mudlogging service

will include monitoring mud weights (in and out), drill gas, background gas, connection gas, trip gas, bottoms up gas and lithology description. This information will be used to assess any relative changes in hole conditions and aid in making mud weight adjustments.

LWD (GR/Res)/MWD services will also be utilized below 2500’ TVD. LWD will provide real

time directional surveying well, formation evaluation, reservoir fluid type, and formation pressures including abnormal pressure detection. LWD will enable the drillin g team with real

time identification of unexpected and potential drilling hazards.Energy Resource Technology GOM, Inc. Page B

- 6

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) All efforts will be made to avoid a loss returns event. This includes but not limited to identification of depleted zones and faults, high quality casing seats, controlled penetration rates, controlling trip in hole speeds, staging up pumps, cement placement models, controlling casing surge pressures and solids control.

Cement programs will be designed to prevent gas influx during cement setting. All casing strings wil l be centralized across hydrocarbon bearing zones. Prior to cementing casing, the annulus will be circulated a minimum of 1.5 times its volume as long as mud returns are maintained. After cementing casing, the annulus will be monitored while the cement s ets.

Diverter and BOP System Requirements as per 30 CFR 250 Subpart D 250.430 thru 250.451 will be in effect while drilling ST 63 “B”. The diverter equipment will be installed and tested prior to drilling conductor and surface holes. BOP equipment will be installed and tested while conducting operations below surface pipe. All BOPE will be tested every 14 days using water. Annular and ram BOP’s will be function tested every 7 days between pressure tests. BOP’s will

include at least one set of blind/sh ear rams capable of shearing the drill pipe under MASP

conditions.

A minimum of two (2) offshore supervisors will be on the rig at all times to ensure 24 hour supervision of all drilling activities conducted on the ST 63 “B” well. These onsite superviso rs will witness and review all BOP tests, casing tests and formation integrity tests. Formation integrity tests must be approved by the ERT GOM drilling superintendent, manager or drilling engineer prior to drilling ahead. ERT GOM also requires the contr actor provide two toolpushers to ensure 24 hr supervision of the rig crew.

ERT GOM conducts rig safety and well control system audits on every rig contracted. These audits are conducted after the rig arrives on location and commences work. Each rig cr ew practices well control drills daily. These well control drills include pit drill, kick drill and trip drill. Each drill will emphasize “kick” recognition, confirmation, shut

- in procedures and personnel assignments.

Additional measures to enhance ERT ’s ability to prevent and reduce the likelihood of a blowout

are:

Management and Direct Supervision Processes:

 Drilling Supervisors, Completion Supervisors, MODU OIM’s, Drillers, and Tool Pushers, (including all personnel that may be acting in these capac ities) must hold a valid well control certificate from an accredited IWCF or WellCAP organization.

 Compliance with all federal rules and regulations: CFRs, NTLs, and Final Rules

 Pursuant to wellbore cementing and zonal isolation techniques, all cementing o perations will be modeled and designed under the guidelines set forth in API RP 65 Part I & II.Energy Resource Technology GOM, Inc. Page B

- 7

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 )  RP 53 for Blowout Prevention Equipment Systems for Drilling Wells will be used for
installation, testing and maintenance of the surface BOP systems.

 Utilizati on of ERT management systems: SEMS and MOC

 Adherence to Contractors Safety Management Systems

 Ensure proper physical barriers are in place to prevent uncontrolled flow

 Professionally certified and peer reviewed well design (casing and cementing)

 Contracto r engagement meeting to gain alignment on well plan

 Specific procedures to execute well plan

Well and rig equipment:

 All rigs will meet all applicable rules and regulations per 30 CFR 250 and 550, as well as

all Notice to Leases.

 Certified BOP equipment t hat is fit for purpose

 Utilize rig and equipment that is fit for purpose

 The working pressure and temperature rating of the BOPE and wellhead will exceed the maximum anticipated surface pressure and temperature.

 Accumulator controls will always be left in the power position (i.e. opened/closed; not neutral).

 Rams installed & tested to fit all sizes of drill pipe, casing , and tubing to be used.

 A pressure tested fully opening safety valve (FOSV) and opening/closing wrench with appropriate threads or crosso ver subs for all connections will be available on the rig floor

at all times.

 A drill string float valve (ported acceptable) will be installed in all drilling bottom hole

assemblies (BHA’s). Similar valves will be considered for well intervention and

com pletion operations when reverse circulating is not required.

 MWD/LWD/PWD tools will be used accordingly to obtain real

- time data on subsurface

zones

 Circulating trip tanks are required for all drilling operations.

 PVT and gas detection equipment will be em ployed for all hole sections.

Drilling Practices:

 Volume measurements relative to the well will be monitored at all times.Energy Resource Technology GOM, Inc. Page B

- 8

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 )  All critical pressure test charts (i.e. negative tests, casing tests, FIT/LOT) will be reviewed by Drilling Engineer/Drilling Su pervisor prior to continuing with operations.

 During drilling operations, slow circulating rates (SCR) will be taken and recorded for each mud pump at least after BHA or mud weight changes and 500 feet of formation

drilled.

 Flow checks shall be conducted after drilling breaks, prior to tripping, after or during lost circulation events, pumping out, prior to nippling down BOP’s, and any other time when anomalous pit volume readings are observed. Minimum flow check duration shall be 5

minutes.

 Drilling BOP s pace

- out and tool joint space

- out diagrams shall be posted on the rig floor

at all times.

 Kill sheets will be updated during each tour and posted on the rig floor.

 PVT and gas detection equipment will be employed for all hole sections.

E ffective and ear ly blowout intervention : In the event of a blowout, the ERT GOM OSRP will be activated. The first priority will be to quickly organize a focused team of operational and technical professionals including a blowout specialty company (BSC). The BSC will be immediately mobilized to the blowout site. The BSC will analyze the blowout situation and devise an intervention strategy. Site assessment will be used to assist in determining the relief well location options so that planning can be initiated.

Historic al perspective of blowout occurrence and intervention: MMS Article written by David Izon, E.P. Danenberger and Melinda Mayes for IADC presentation Aug 2007 states that 19 blowouts occurred during the drilling of 8722 wells in OCS water depths <200’ during years 1992

– 2006. The authors further say that 1 fatality and 2 injuries resulted and environmental impacts were negligible during this same period in all OCS water depths. The total spillage of all blowouts during this period was 341 bbls oil/condensat e and 982 bbls of synthetic

- based mud. MMS article “OCS Oil Spill Facts”, September 2002, states that blowouts from drilling exploratory wells accounted for only 2 spills that were greater

than 5 bbls

– a 100

- bbl spill in 1992 and a 200

- bbl spill in 2000.

The study further states that 49% of all blowout events during 1992

– 2006 stopped flowing in 24 hrs or less, 41% lasted between 1 to 7 days and the longest blowout lasted 11 days. Over 50% were controlled by surface intervention, 36% of the blowouts br idged over and the rest depleted. Two relief wells were initiated but both blowouts were controlled by other means prior to completing the relief well. Shallow gas was associated with 49% of the blowouts. 16 of 20 shallow gas blowouts were successfully diverted until the well bridged over.

The DOI published Increased Safety Measures For Energy Development on the Outer Continental Shelf, May 27, 2010, states that oil spilled from OCS rigs and platforms over the past 30 years is about 27,000 bbls. The st udy documents 6 events from 1964 to 2009 whichEnergy Resource Technology GOM, Inc. Page B

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) blowouts exceeding 1000 bbls. Of the six, three were associated with drilling. Further noted is the last event over 1000 bbls occurred in 1970. In the past 40 years (since 1971), a total of 1800 bbls was sp illed on the Federal OCS as a result of blowout events.

These are all noteworthy statistics when providing and justifying WCD scenarios and blowout intervention while drilling in OCS water depths <200’. The BP Oil Spill illustrates the significant cha llenges in intervention and containment of a blowout in deepwater using subsea BOPE as compared to intervention and containment in water depths <200’ using a jack up rig
and surface BOPE. Since 1947, more than 50,000 wells have been drilled in Federal Gul f of

Mexico. Until the BP Oil Spill, research did not find a single blowout in Federal Gulf of Mexico

waters which required a relief well to kill the blowout.

Included in Attachment B is the NTL 2010

- N06 Worst Case Discharge Analysis.Energy Resource Technology GOM, Inc. Page C

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Supplemental DOCD November 20, 2013 South Timbalier Blocks 63/86 (OCS-G 00599/00605) 

### APPENDIX C

GEOLOGICAL AND GEOPHYSICAL INFORMATION

NOTE: Two separate discussions were done. One for the H2S shallow A,B,C,D wells and one for the deep E,F,G sweet wells.

PROPOSED WELL LOCATIONS A, B, C and D

(A ) GEOLOGICAL DESCRIPTION

(B) STRUCTURE CONTOUR MAP(S) Structure contour maps on the 3700, 3700B, and 3800 sands are included in Attachment C for locations A,B,C,D, These maps are at a scale of 1”=2000’ and have the proposed wellbore paths shown. They have been generated by using the offset well control and 3-D seismic time data.

(C ) INTERPRETED 2-D A ND / OR 3-D SEISMIC LINE(S) The seismic data used to interpret structure is a Western Geophysical Merge W/TauP Filter &Gain volume. Arbitrary seismic lines labeled A,B,C,D are included. They show the bottomhole locations of the proposed wells and portions. A time/depth curve for the Odeco ST86 #16 well (API:177154028300) was used to convert target time to depth and is included in

Attachment C

.

(D ) GEOLOGICAL STRUCTURE CROSS-SECTIONS An interpreted geological structure cross-section showing the location and depth of the proposed wells and key horizons and the objective sands is included. The geologic age of the targeted sands is shown in biostratigraphic terms are included in Attachment C.

(E ) SHALLOW HAZARDS REPORT The proposed new wells will be drilled from an existing surface location (Platform E-Aux)

, therefore, a Shallow Hazards Report is not required.Energy Resource Technology GOM, Inc. Page C

- 2

Supplemental DOCD November 20, 2013 South Timbalier Blocks 63/86 (OCS-G 00599/00605) (F ) SHALLOW HAZARDS ASSESSMENT The proposed new wells (Well Locations A, B, C and D) will be drilled from an existing surface location (Platform E-Aux), therefore, a Shallow Hazards Assessment is not required.

(G ) HIGH-RESOLUTION SEISMIC LINES The proposed new wells (Well Locations A, B, C and D) will be from an existing surface location (Platform E-Aux), therefore High Resolution Seismic Lines are not required.

(H ) STRATIGRAPHIC COLUMN A generalized biostratigraphic/lithostratigraphic column depicting each well from the seafloor to total depth, with each objective horizon labeled, is included in Attachment C.

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

PROPOSED WELL LOCATIONS E, F and G

(A ) GEOLOGICAL DESCRIPTION

(B) STRUCTURE CONTOUR MAP(S) Structure contour maps on the “S” and “T” sands are included in Attachment C for locations E,F,G. These maps are at a scale of 1”=2000’ and have the proposed wellbore paths shown. They have been generated by using the offset well control and 3-D seismic time data.

(C) INTERPRETED 2-D AND/OR 3-D SEISMIC LINE(S) The seismic data used to interpret structure is a Western Geophysical Merge W/TauP Filter & Gain volume. Arbitrary seismic lines labeled E,F,G are included. They show the bottom- hole locations of the proposed wells and portions. A time/depth curve for the Odeco ST86 #16 well (API:177154028300) was used to convert target time to depth and is included in Attachment C

.Energy Resource Technology GOM, Inc. Page C

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) (D) GEOLOGICAL STRUCTURE CROSS

- SECTIONS An interpreted geological structure cross

- section showing the location and depth of the proposed wells and key ho rizons and the objective sands is included. The geologic age of the targeted sands is shown in biostratigraphic terms are included in Attachment C.

(E) SHALLOW HAZARDS REPORT

ERT contracted Tesla Offshore LLC to conduct a shallow hazards survey across a portion of

South Timbalier Blocks 63/86

. T hree copies of this report are being submitted on this date under

separate cover.

(F) SHALLOW HAZARDS ASSESSMENT A shallow hazards assessment has been prepared for the proposed surface location (Well

Locatio ns E, F and G) , evaluating seafloor and subsurface geologic al and manmade features and conditions that may adversely affect drilling operations, and is included in Attachment C

.

( G ) HIGH

- RESOLUTION SEISMIC LINES

Included in Attachment C are annotated hi gh

- resolution s urvey lines closest to each of the proposed well locations.

(H) STRATIGRAPHIC COLUMN A generalized biostratigraphic/lithostratigraphic column depicting each well from the seafloor to total depth , with each objective horizon labeled, is in cluded in Attachment C

.

(I) TIME VS DEPTH TABLES Sufficient well control data for the target areas proposed in this DOCD exists; therefore, seismic time versus depth tables for the proposed well locations are not required.Energy Resource Technology GOM, Inc. Page D-1

Supplemental DOCD November 20, 2013 South Timbalier Blocks 63/86 (OCS-G 00599/00605) 

### APPENDIX D

HYDROGEN SULFIDE INFORMATION

(A) CONCENTRATION Hydrogen sulfide is expected in Well Locations A, B, C and D, drilled from the existing Platform E. A test on the E-4 well from a gas sample taken 10/12/2013 indicated 4500 ppm and 0.4500 mole% hydrogen sulfide. A Sensidyne pump was used for the analytical method. Flowline vapor pressure was 435 psi @ a temp of 78 degrees. Gas rate for this well was 6718 mcfpd.

ERT will submit to the appropriate BOEM district office an H 2 S Contingency Plan prepared according to 30 CFR 250.490(f) before conducting the proposed development and production

activities.

Please note that the H2S is confined to the E platform. This is the platform that handles all of the shallow production that has H2S, and it’s the only platform with H2S handling equipment and associated safety equipment. The H2S concentration on the E platform is approximately 4500 ppm. There is no H2S anywhere else.

(B) CLASSIFICATION In accordance with Title 30 CFR 550.490(c ), ERT requests that the South Timbalier Blocks 63/86 Well Locations E, F, and G (drilled from the proposed South Timbalier Block 63 Platform

H be classified by the BOEM as H 2 S absent.Energy Resource Technology GOM, Inc. Page E-1

Supplemental DOCD November 20, 2013 South Timbalier Blocks 63/86 (OCS-G 00599/00605) 

### APPENDIX E

MINERAL RESOURCE CONSERVATION INFORMATION

(A ) TECHNOLOGY & RESERVOIR ENGINEERING PRACTICES AND PROCEDURES

(B) TECHNOLOGY AND RECOVERY PRACTICES AND PROCEDURES

(C) RESERVOIR DEVELOPMENTEnergy Resource Technology GOM, Inc. Page F

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) APPENDIX F BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

( A ) DEEPWATER BENTHIC COMMUNITIES

A ctivities proposed in this DOCD will not disturb seafloor areas in water depths of 300 meters (984 feet) or greater; there fore, information as outlined in Attachment A of NTL No. 2009

- G40, "Deepwater Benthic Communities", is not provided..

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

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

(D) LIVE BOTTO MS (PINNACLE TREND) MAP

South Timbalier Blocks 63/86 are not located within 61 meters (200 feet) of any pinnacle trend feature; therefore a separate bathymetric map is not required.

(E) LIVE BOTTOMS (LOW RELIEF) STIPULATION

South Timbalier Blocks 63/86 are not located within 100 feet of any pinnacle trend feature with vertical relief equal to or greater than 8 feet; therefore, live bottom (low relief) maps are not required.

( F ) POTENTIALLY SENSITIVE BIOLOGICAL FEATURES

South Timbalier Blocks 63/86 ar e not located with in 30 meters ( 1 00 feet) of potentially sensitive biological features; therefore, biologically sensi tive area maps are not required.

(G) REMOTELY OPERATED VEHICLE (R OV ) SURVEYS BOEM has determined there is enough data gathered in this grid area, therefore, we will not be conducting any ROV surveys either pre

- spudding or post

- drilling operations.

(H)THREATENED AND ENDANGERED SPECIES , CRITICAL HABITAT, AND MARINE

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

In accordance with the 30 CFR 250, S ubpart B, effective May 14, 2007, and further outlined in Notice to Lessees (NTL) 2008

- G04 (extended by NTL 2013

- G02) , lessees/operators are required

to address site

- specific information on the presence of federally listed threatened or endangered species and critical habitat designated under the ESA and marine mammals protected under the Marine Mammal Protection Act (MMPA) in the area of proposes activities under this plan.Energy Resource Technology GOM, Inc. Page F

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) NOAA Fisheries currently lists the Sperm Whale, Leatherback Turtle, Green Turtle, Hawksbill Turtle, and the Kemp’s Ridley Turtle as endangered and the Loggerhead Turtle and Gulf Sturgeon as threatened. Currently there are no designated critical habitats for the listed species in the Gulf of Mexico Outer Continental Shelf, however, it i s possible that one or more of these species could be seen in the area of our operations.

(I) ARCHAEOLOGICAL REPORT South Timbalier Blocks 63/86 have been determined as potentially containing prehistoric archaeological properties. Therefore, an Archaeo logical Survey Report has been prepared in

accordance with NTL 2005

- G07 "Archaeological Surveys and Reports" and is being submitted under separate cover.

(J) AIR AND WATER QUALITY INFORMATION Air and water quality information is not required by BOEM to b e included in this plan.

(K) SOCIOECONOMIC INFORMATION Socioeconomic information is not required by BOEM to be included in this plan.Energy Resource Technology GOM, Inc. Page G

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 

### APPENDIX G

W ASTES AND DISCHARGES INFORMATION

(A) PROJECTED GENERATED WASTESEnergy Resource Technology GOM, Inc. Page H

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Sup plemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 

### APPENDIX H

AI R EMISSIONS INFORMATION

( A ) EMISSIONS WORKSHEETS AND SCREENING QUESTIONS

( 1 ) Screening Questions

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

Do your emission calculations include any emission reduction measures or modified

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

Do you expect to encounter H 2 S at concentrations greater than 20 parts per million (ppm)? X Do you pro pose to flare or vent natural gas in excess or criteria set for the 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) f

rom shore? X

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

E nclosed in Attachment H are Air Emission Worksheets showing the emissions calculations for

the Plan Emiss ions, and if different, a set of worksheets showing the emissions calculations for the Complex Total emissions.

This information was calculated by: Cathy Thornton (713) 705

- 8020 cathy.thornton@jccte am.comEnergy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 

### APPENDIX I

OIL SPILL S INFORMATION

( A ) OIL SPILL RESPONSE PLANNING Energy Resource Technology GOM, Inc. ’s (MMS Operator Number 0 2899 ) Regional Oil Spill Response Plan (OSRP) was submitted in April, 20 1 2 with the latest modification of the Reg ional OSRP approved on July 26, 2013 . The next Biennial Oil Spill Response Plan is due by April 30,

201 4 . The a ctivities proposed in this DOCD will be covered by the Regional OSRP in

accordance with 30 CFR 254

.

(B) SPILL RESPONSE SITES Primary Respons e Equipment Location Preplanned Staging Location

Houma, LA Harvey, LA Venice, LA Houma, LA Harvey, LA Venice, LA

( C) OSRO INFORMATION

ERT ’s primary equipment provider is Clean Gulf Associates (CGA). The Marine Spill Response Corporation’s (MSRC) STARS network will provide closest available personnel, as well as an MSRC supervisor to operate the equipment.

(D) WORST

- CASE SCENARIO DETERMINATION

Category Drilling Production

Regional
OSRP

WCD DOCD

WCD Regional

OSRP

WCD DOCD

WCD

Type of Activity Dri l ling Drilling >10 mile

Production >10 mile

Production

Facility Location (Area/Block) GC237 S T 86 GC 282 SM130

Facility Designation Well No. 005 Well No. E0 07 (Well Loc. B) SS Well No. 1

(ST03BP01) PF E

Distance to Nearest Shoreline (miles) 91 2 0 91 20

Volume
S torage tanks & flowlines Lease term pipelines

Uncontrolled blowout

Total Volume (bbls) 2 12,891 212,891 4270

4270 43,280

43,280 300

275

1860

2 435 Type of Oil(s) (crude, condensate, diesel) C rude Crude Crude Crude

API Gravity 33 ° 3 7 ° 32° 37°Energy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) ERT has determined that the worst

- case scenario from the activities proposed in this DOCD do es not super s ede the worst

- case scenario from our approved regional OSRP for far

- shore activities.

Since ERT has the capabili ty to respond to the worst

- case spill scenario included in our regional

OSRP currently pending approval , and since the worst

- case scenario determined for our DOCD does not replace the worst

- case scenario in our regional OSRP, I hereby certify that ERT has the capability to respond, to the maximum extent practicable, to a worst

- case discharge, or a substantial threat of such a discharge, resulting from the activities proposed in our DOCD

.

( E ) OIL SPILL RESPONSE DISCUSSION For the purpose of NEPA and Coasta l Zone Management Act analysis, the largest spill volume originating from the proposed activity would be a well blowout during drilling operations, estimated to be 4270 barrels of crude oil with an API gravity of 37 °.

Land Segment and Resource Identificat ion

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

Western Gulf of Mexico available on the BSEE website. The resul ts are shown in Figure 1. The BSEE OSRAM identifies a 10% probability of impact to the shorelines of Cameron and/or Terrebonne Parish, Louisiana within 30 days. Cameron Parish includes the east side of Sabine Lake, Sabine National Wildlife Refuge, Calcasie u Lake, Lacassine National Wildlife Refuge (inland) and Grand Lake. Cameron Parish also includes the area along the coastline from Sabine Pass to Big Constance Lake in Rockefeller Wildlife Refuge. This region is composed of open public beaches, marshland s and swamps. It serves as a habitat for numerous birds, finfish and other animals, including several rare, threatened and endangered species. Terrebonne Parish includes the eastern portion of Atchafalaya National Wildlife Refuge across to Timbalier Bay. The Terrebonne parish also includes the area along the Gulf Coast including Caillou Bay, Isles Dernieres and Terrebonne Bay. The entire parish is classified as an EPA National Estuary. This area is primarily marshland, broken up by numerous small bays and freshwater lakes.

Response

ERT 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.

Usi ng 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 45 % or approximately 1922 barrels of crude oil would be evaporated/dispersed withi n 24 hours, with approximately 2348 barrels remaining.Energy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 )

Spill Response ST 86, Well E007 Barrels of Oil

WCD Volume 4270

Less 45 % natural evaporation/dispersion 1922

Remaining volume 2348

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, t ravel time to the site and deployment

. Figure 2 also indicates how operations will be supported.

ERT ’s Oil Spill Response Plan includes alternative response technologies such as dispersants

and in

- situ burn. Strategies will be decided by Unified Command based on the size of the spill, weather and potential impacts. If aerial dispersants are utilized, 8 sorties (9600 gallons) from two

of the DC

- 3 aircrafts and 4 sorties (8000 gallons) from the Basler aircraft would provide a daily dispersant capability of 7540 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. S lick containment boom would be immediately called out and on

- scene as soon as possible. Offshore response strategies may include attempting to skim utilizing the HOSS Barge and the R/V Grand Bay , with a total derated skimming capacity of 48,000 barrels. Temporary storage associated with skimming equipment equals 4065 barrel s. If additional storage is needed, a 25,000 barrel storage barge and a 20,000 barrel storage barge may be

mobilized and centrally located to provide temporary storage allowing the skimmers to stay in the area of operations as much as possible

. Safety is f irst 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 and/or Terrebonne Parish, Louisiana would depend upon existing environment al conditions. Shoreline protection would include the use of CGA’s near shore and shallow water skimmers with a totaled derated skimming capacity

of 7,176 barrels. Temporary storage associated with skimming equipment equals 54 barrels. If additional storag e is needed, a 20,000 barrel storage barge may be mobilized and centrally located to provide temporary storage allowing the skimmers to stay in the area of operations as much as possible. Onshore response may include the deployment of shoreline boom on bea ch areas, or protection and sorbent boom on vegetated areas. A Letter of Intent from OMI Environmental will ensure access to 85,000 feet of 18” shoreline protection boom. Figure 2 outlines individual times needed for procurement, load out, travel time to t he site and deployment. Strategies would be based upon surveillance and real time trajectories that depict areas of potential impact given actual sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan for Cameron and Terrebonne Parish and Unified Command would be consulted to ensure that environmental and special economic resources would be correctly identified and prioritized to ensure optimal protection. Shoreline protection strategies depict the protection response modes appl icable for oil spill clean

- up operations. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection strategies for this area, andEnergy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) it describes necessary action to keep the oil spill from entering Louisiana’s coastal wetl ands, 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 operatio n of equipment allowing a more effective response to site

- specific circumstances. ERT’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, ERT can be onsite with contrac ted 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

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

Initial Response Considerations Actual actions taken during an oil spill response will be based on many factors which include but

are not limited to:

 Weather

 Equipment and materials availability

 Ocean currents and tides

 L ocation of the spill

 Product spilled

 Amount spilled

 Environmental risk assessments

 Trajectory and product analysis

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

ERT will take action to provide a safe, aggressive response to contain and recover as muc h of the spilled oil as quickly as it is safe to do so. In an effort to protect the environment, response actions will be designed to provide an “in

- depth” protection strategy meant to recover as much oil as possible as far from environmentally sensitive a reas as possible. Safety will take precedence over all other considerations during these operations.

Coordination of response assets will be supervised by the designation of a SIMOPS group as necessary for close quarter vessel response activities. Most o ften, this group will be used during source control events that require a significant number of large vessels operating independently, but in coordination to complete a common objective, in a small area and in close coordination and support of each other. This group must also monitor the subsurface activities of each vessel (ROV, dispersant application, well control support, etc.). The SIMOPS group leader reports to

the Source Control Section Chief.

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

slick movement in real time.Energy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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 will be completed

 Initial Safety plan will be written and published

 Unified Command will be established

o Overall safety pla n 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

Decanting Strategy

Recovered oil and water mixture s 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 e ffective 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.

Offshore Response Actions

Equipment Deployment

Surveillance

 Su rveillance Aircraft will be deployed within two hours of Q ualified I ndividual (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 A irborne S upport I nc. (ASI) on standby

 With the Federal On

- Sce ne Coordinator ( FOSC ) , conduct analysis to determine appropriateness of dispersant application

 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 dis persants, aircraft, and support equipment and personnel

 Confirm dispersant availability for current and long range operations

 Start ordering dispersant stocks required for expected operationsEnergy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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 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

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

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

CGA FRUs

 To the area of the thickest oil

 Use as far off

- shore as allowed

 VOOs 140’

– 180’ in length

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

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

Storage Vessels

 Establish availability of CGA contracted assets

 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 ERT ’s contracted resources as applicable

 Industry vessels are usually best for deployment of Vessel of Opport unity Skimming Systems (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

In

- situ Burn assets

 Determine appropriateness of in

- situ burn operation in coordination with the FOSC and

affected State On

- Scene Coordinator (SOSC)

 Determine availability of fire boom and selected ignition systemsEnergy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 )  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

Adverse Weather Operations: In adverse weather, w hen seas are > 3 feet, the use of larger recovery and storage vessels, oleophilic skimmers, and large offshore boom will be maximized. Safety will be the overriding factor in all operations and will cease at the order of the Unified Command, vessel captai n, or in an emergency, ”stop work” may be directed by any crew member.

Near Shore Response Actions

Timing

 P lace near shore assets on standby and deploy in accordance with planning based on the actual situation, actual trajectories and oil budgets

 VOO ide ntification 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

Equipment Deployment

Surveillance

 Provide trained observer to direct skimming operations

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

and visual confirmation

 Continual mon itoring of vessel assets

Dispersant Use

 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)

Vessel Deployment Dedicated Near Shore skimming syst ems

 F ast R esponse V essel s (FRV)

 Egmopol and Marco S hallow Water Skimmer (SWS)Energy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 )  Operate with aerial spotter directing systems to observed oil slicks

VOO

 Use ERT ’s contracted resources as applicable

 Industry vessel s are usually best for deployment of Vessel of Opportunity Skimming Systems (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

 Oper ate with aerial spotter directing systems to oil patches

Shoreline Protection Operations

Response Planning Considerations

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

 Time to acquire personnel and equipment and their a vailability

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

Actions

Placement of boom

 Position boo m in accordance with the ERA based on the actual situation or the appropriate ACP

 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 movem ent

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 a nd 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 ti d e lines to min imize wasteEnergy Resource Technology GOM, Inc. Page I

- 9

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 )  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 an d oil movement for resource redeployment as necessary

 In

- situ burn may be considered when marshes have been impacted

 Passive clean up of marshes should be 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

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 capa bilities 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. Ski mming 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 po rt 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

C eiling less than 1,000 feet.

FRU 8 foot seas HOSS Barge/OSRB 8 foot seas Koseq Arms 8 foot seas

OSRV 4 foot seasEnergy Resource Technology GOM, Inc. Page I

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) Environmental Conditions in the GOM Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences

west erly 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 hi gh 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 At lantic 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.Energy Resource Technology GOM, Inc. Page I

- 11

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) FIGURE 1

TRAJECTORY BY LAND SEGMENT

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

Area/Block OCS

- G Launch

Area Land Segment and/or

Resource Conditional

Probability (%)

within 30 days

D rill, complete and produce 7 wells (4

from PF E and 3 from proposed PF M), and install one tripod

structure and 2 lease term pipelines.

ST 86, Well E007

20 miles from shore 00 605 C39 Matagorda, TX Brazoria, TX Galveston, TX Jefferson, TX Cameron, LA Vermilion, LA Iberia, La Terrebonne, LA Lafourche, LA Jefferson, LA

Pl aquemines, LA 2

1

2

3

10

4

1

10

5

2

8Energy Resource Technology GOM, Inc. Page I

- 12 Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) WCD Scenario

– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS ( 20 miles from shore)
2,348 bbls of crude oil (Volume considering natural weathering) API Gravity 37 °

FIGURE 2

– Equipment Response Time to ST 86, Well E007

Dispersants/Surveillance

Dispersant/Surveillance Dispersant 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 1 1 0.3 2.3

DC 3 1200 NA 2 Houma 1 1 0.4 2.4

DC 3 1200 NA 2 Houma 1 1 0.4 2.4

Aero Commander NA NA 2 Houma 1 1 0.3 2.3

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 5 4.4 1 17.4

46’ FRV 5000 65 NA 4 Venice 1 0 1 2 0 4

Boom Barge (CGA

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

50 Crew 4 (Barge)

2 (Per Crew) Leeville 4 0 6 3.6 1.5 15.1

Recovered Oil Storage No Staging EDR C Storage Capacity VOO Persons Required From Hrs to

Procure Hrs to

Loadout Hrs to

GOM Travel to

Spill Site Hrs to

Deploy Total

Hrs

Enterprise Marine Services LLC (available through contract with CGA)

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 10 1 31

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 10 1 31

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

Hydro

- Fire Boom NA NA 8 Utility 40 Harvey 1 4 2 2.1 6 15.1Energy Resource Technology GOM, Inc. Page I

- 13 Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) Nearshore Response

Nearshore Equipment No Staging EDRC Storage Capacity VOO Persons

Required From Hrs to

Procure Hrs to

Loadout Hrs to

GOM Travel to

Spill Site Hrs to

Deploy Total

Hrs

Enterprise Marine Servic es LLC (available through contract with CGA)

CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 12.5 1 33.5

Staging Area: Fourchon

Nearshore and Inland Skimmers With Staging EDRC Storage Capacity VOO Persons Req. From Hrs to

Procure Hrs to

Loadout Travel to

Sta ging Travel to

Deployment Hrs to

Deploy Total Hrs

CGA

SWS Marco 3588 20 NA 3 Lake Charles 1 2 4 2 0 9

SWS Marco 3588 34 NA 3 Leeville 1 2 0.25 2 0 5.25Energy Resource Technology GOM, Inc. Page I

- 14 Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) Shoreline Protection Staging Area: Fourchon

Shoreline Protection

Boom VOO Persons Req. Storage/War ehouse

Location Hrs to

Procure Hrs to

Loadout Travel to

Staging Travel to

Deployment 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 3.5 2 3 10.5

10,000’ 18” Boom 4 Crew 1 0 Houston, TX 1 1 7 2 3 14

10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 5.75 2 3 12.75

20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 3 2 6 13

10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 3.5 2 3 10.5

10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 2 2 3 9

15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.75 2 4 12.75

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 Tra iler NA NA NA 2 Harvey 1 2 2 1 2 8

Bird Scare Guns (48) NA NA NA 2 Harvey 1 2 2 1 2 8

Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 7 1 2 13

Bird Scare Guns (12) NA NA NA 2 Aransas Pass 1 2 9.5 1 2 15.5

Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 4 1 2 10

Bird Scare Guns (24) NA NA NA 2 Venice 1 2 4 1 2 10

Response Asset Total

Offshore EDRC 48,000

Offshore Recovered Oil Storage 49,065

Nearshore / Shallow Water EDRC 7,176

Nearshore / Shallow Water Recovered Oil Storage 20,054Energy Resource Technology GOM, Inc. Page J

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 

### APPENDIX J

EN VIRONMENTAL MONITORING INFORMATION

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

activities.

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

To date, it has been documented that the use of explosives and/or seismic devices can affect marine life. Operations proposed in this pla n will not be utilizing either of these devices.

(C ) FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY

South Timbalier Blocks 63/86 are not located in the Flower Garden Banks National Marine Sanctuary; therefore, the requested information is not required in this DO CD.Energy Resource Technology GOM, Inc. Page K

- 1 Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 

### APPENDIX K

LEASE STIPULATIONS INFORMATION

The BOEM did not invoke lease stipulations for Lease s OCS

- G 00599/00605

, South Timbalier

Blocks 63/86

.Energy Resource Technology GOM, Inc. Page L

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) APPENDIX L

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

( A ) MITIGATION MEASURES TAKEN TO MINIMIZ E IMPACT TO MARINE AND

COASTAL ENVIRONMENT Mitigation measures taken to minimize impact to marine and coastal environment is not required

for this DOCD.

( B ) INCIDENTAL TAKES

ERT will adhere to the requirements as set forth in the following documents, as applicable, to avoid or minimize impacts to any of the species listed in the ESA as a result of the operations

conducted herein:

 NTL 2012

- G02

- JOINT, “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting

 NTL 2012

- G01, “Marine Trash and Deb ris Awareness and Elimination”

 NTL 2012

- G02

- JOINT, “Implementation of Seismic Survey Mitigation Measures and Protected Species Observer Program”Energy Resource Technology GOM, Inc. Page M

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) A PPENDIX M

RELATED FACILITIES AN D OPERATIONS INFORMATION

(A) RELATED OCS FACILITIES AND OPERATIONS

Well Lo cations A, B, C and D will be drilled and produced from the existing South Timbalier

Block 86 Platform E

- Aux. Well Locations E, F and G will be drilled and will be produced from the proposed M p latform

. A 6

- inch bulk gas lease term pipeline approximately 10,500 feet in length will be installed to transport produced bulk gas to the South Timbalier Block 63 A

p latform for processing. Additionally, a 3

- i nch lease term supply pipeline approximately 10,500 feet in length will be installed from the South Timba lier Block 63 A p latform to the proposed South Timbalier Block 86 M platform

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

( B ) T RANSPORTATION SYSTEM

Fu ll well stream production from the proposed South Timbalier Block 86 M p latform will flow

to the South Timbalier Block 63 A p latform for processing. Separated gas production will depart the South Timbalier Block 63 A platform via Trunkline’s existing 12

- i nch pipeline (Segment No. 01655) to the Trunkline

- operated South Timbalier Block 63 Manifold platform (ROW No. OCS

G 01693) prior to delivery into Operations System No. 25.0/XE0. Separated liquid hydrocarbon production will depart the South Timbalier Bl ock 63 A / Aux platform via Energy XXI Pipeline, LLC's existing 10

- inch pipeline (Segment No. 04305) for ultimate delivery to shore via Operations System No. 36.0.

( C) PRODUCED LIQUID HYDROCARBONS TRANSPORTATION VESSELS

T here will not be any transfers of liquid hydrocarbons other than via pipeline.Energy Resource Technology GOM, Inc. Page N

- 1 Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) APPENDIX N

SUPPORT VESSELS AND AIRCRAFT INFORMATION

( A ) GENERAL

Type Maximum Fuel

Tank Capacity Maximum

Number in Area at Any Time Trip

Frequency or

Duration

Tug Boats 3000 bbls 2 2 days

Anchor Handling Boat 1500 bbls 2 NA

Crew Boat 500 bbls 1 Daily

Supply Boat 500 bbls 1 Three times per

week
Helicopter 800 l bs

100

- 120 gallons 1 T wo trips daily

average

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

conditions will be utilized.

( B ) DIESEL OIL SUPPLY VESSELS Size of Fuel Supply

Vessel Capacity of Fuel

Supply Vessel Frequency of Fuel Transfers Route Fuel Supply

Vessel Will Take

180 feet 1500 bbls Weekly From shorebase in

Fourchon to ST63/86

then back to shoreba se.

( C ) DRILLING FLUID TRANSPORTATION Drilling fluid transportation information is not required by BOEM to be included in this plan.

( D ) S OLID AND LIQUID WASTE TRANSPORTATION For solid and liquid waste transportation refer to Table 2 under Waste Disposal in Appendix O

Section D of this Plan.

( E ) VICINITY MAP

Enclosed in Attachment N is a vicinity map showing the location of the activities proposed herein relative to the shoreline with the distance of the proposed activities from the shoreline a nd the primary route(s) of the support vessels and aircraft that will be used when traveling between the onshore support facilities and the platform.Energy Resource Technology GOM, Inc. Page O

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OC S

- G 00599/00605 ) APPENDIX O

ONSHORE SUPPORT FACILITIES INFORMATION

( A ) GENERAL

Name Location Existing/New/Modified

Martin Terminal North F ourchon

, LA Existing

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

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

(D) WASTE DISPOSALEnergy Resource Technology GOM, Inc. Page P

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) APPENDIX P

CO ASTAL ZONE MA NAGEMENT (CZMA) INFORMATION

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

.Energy Resource Technolo gy GOM, Inc. Page Q

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) APPENDIX Q

ENVIRONMENTAL IM PACT ANALYSIS (EIA)

(A) I MPACT PRODUCING FACT ORS

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 (ai r, noise, light, etc.) Effluents

(muds, cutting, other discharges to

the water

column or seafloor) Physical

disturbances to the seafloor (rig or

anchor emplacements, etc.) Wastes sent

to shore for

treatment or disposal Accidents

(e.g., oil spills,

chemical spills, H 2 S releases) Discarded

Trash &

Debris

Site

- specific at Offshore

Location

Designated topographic features (1) (1) (1)

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

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

Benthic communitie s (4)

Water quality X X X

Fisheries X X X

Marine Mammals X(8) X X(8) X

Sea Turtles X(8) X X(8) X

Air quality X(9)

Shipwreck sites (known or potential) (7)

Prehistoric archaeological sites X(7)

Vicinity of Offsh ore 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

Coast al wildlife refuges X

Wilderness areas XEnergy Resource Technolo gy GOM, Inc. Page Q

- 2

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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 t he 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 Essent ial 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) Activit ies with any bottom disturbance within an OCS lease block protected through the Live Bottom (Pinnacle Trend) Stipulation attached to an OCS lease. 3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (Low

- Re lief) Stipulation attached to an OCS lease. 4) Activities on blocks designated by the BOEM as being in water depths 300 meters or greater. 5) Exploration or production activities where H2S concentrations greater than 500 ppm might be encountered. 6) All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that you determine would impact these environmental resources. If the proposed action is located a sufficient distance from a resource that no impact would occur, the E IA 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 suc h 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 u sing shuttle tankers or barges.Energy Resource Technolo gy GOM, Inc. Page Q

- 3

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) (B) ANALYSIS

Site

- Specific at South Timbalier Block 63 and South Timbalier Block 86

Proposed operations consist of the drilling, completion and commencement of production from Well locations A, B, C and D from the South Tim balier Block 86 E

- Aux platform (to be designated Well Nos. E006 through E009, under OCS

- G 00605); the drilling and com pletion of Well Locations E ( to be designated Well No. 25, under OCS

- G 00599 ), F and G (to be designated Well Nos. 30 and 31, under

OCS

- G 00605); the installation of propose d 4

- pile 4

- slot M platform over the surface location of Well Locations E, F and G (to be renamed Well Nos. M001 through M003); and the installation of a proposed 6

- inch bulk gas lease term pipeline to be installed from th e M platform to the South Timbalier Block 63 A platform and a proposed 3

- inch supply lease term pipeline from South Timbalier Block 63 A platform to the proposed M platform.

Operations will be conducted with a Jack

- up Rig.

1. Designated Topographic Featur es Potential IPFs on topographic features include physical disturbances to the seafloor, effluents, and

accidents.

Physical disturbances to the seafloor: South Timbalier Block 63 and South Timbalier Block 86 are approximately 40 miles from the closest d esignated Topographic Features Stipulation Block (Sackett Bank); therefore, no adverse impacts are expected.

Effluents: South Timbalier Block 63 and South Timbalier Block 86 are approximately miles from the closest designated Topographic Features Stipu lation Block (Sackett Bank); therefore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed activities (refer to statistics in Item 5 , Water Quality). Oil spills cause damage to benthic organisms only if the oil contacts the organisms. Oil from a surface spill can be driven into the water column; measurable amounts have been documented down to a 10 m depth. At this depth, the oil is found only

at concentrations several orders of magnitude lower than the amount shown to have an effect on corals. Because the crests of topographic features in the Northern Gulf of Mexico are found below 10 m, no oil from a surface spill could reach their sessile biota. Oil from a subsurface spill is not applicable due to the distance of these blocks from a topographic area. The activities proposed in this plan will be covered by ERT’s Regional OSRP (refer to information submitted in Section 9 ).

There are no other IPFs (including emissions a nd wastes sent to shore for disposal) from the proposed activities, which could impact topographic features.Energy Resource Technolo gy GOM, Inc. Page Q

- 4

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 2. Pinnacle Trend Area Live Bottoms
Potential IPFs on pinnacle trend area live bottoms include physical disturbances to the seafloor, effluents, a nd accidents.

Physical disturbances to the seafloor: South Timbalier Block 63 and South Timbalier Block 86 are approximately 108 miles from the closest live bottom (pinnacle trend) area; therefore, no adverse impacts are expected.

Effluents: South T imbalier Block 63 and South Timbalier Block 86 are approximately 108 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 oc cur 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 wate r 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 no t 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 ERT’s Regional OSRP (refer to information submitted in Section 9 ).

There are no other IPFs (including emiss ions 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, efflu ents, and

accidents.

Physical disturbances to the seafloor: South Timbalier Block 63 and South Timbalier Block 86 are not located in an area characterized by the existence of live bottoms, and this lease does not contain a

Live

- Bottom Stipulation requiri ng a photo documentation survey and survey report.

Effluents: South Timbalier Block 63 and South Timbalier Block 86 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 sp ill 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 theseEnergy Resource Technolo gy GOM, Inc. Page Q

- 5

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) blocks from a live bottom area. The activities proposed in this plan will be covered by ERT’s Regional OSRP (refer to information submitted in Section 9 ).

There are no other IPF s (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 ranging from 94 feet to 100 feet. High

- density benthic communities are found only in water depths greater than 984 feet (300 meters); therefore, ERT’s proposed operations in South Timbalier Block 63 and South Timbalier Block 86 would not cause impacts to benthic communities.

5. Water Quality

IPFs that could result in water quality deg radation from the proposed operations in South Timbalier Block 63 and South Timbalier Block 86 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 w ater quality conditions in the immediate vicinity of the emplacement operations.

Effluents: Levels of contaminants in drilling muds and cuttings and produced water discharges, discharge

- rate restrictions and monitoring and toxicity testing are regulated by the EPA NPDES permit, thereby eliminating many significant biological or ecological effects. Operational discharges are not expected to cause significant adverse impacts to water quality.

Accidents: Oil spills have the potential to alter offshore wate r 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 s pill and up to several months afterwards.Energy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) Most of the components of oil are insoluble in water and therefore float. The activities proposed in this plan will be covered by ERT’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 fisherie s as a result of the proposed operations in South Timbalier Block 63 and South Timbalier Block 86 include physical disturbances to the seafloor, effluents and

accidents.

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

Effluents: Effluents such as drilling fluids and cuttings discharges contain components and properties

which are detrimental to fishery resources. Moderate petroleum and metal contamination of sediments

and the water column can occur out to several hundred meters down

- current from the discharge point. Offshore discharges are expected to disperse and dilute to v ery 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 fi sheries; 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 th e 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 ERT’s Regional OSRP (refer to information submitted in

Sect ion 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, occurred mostEnergy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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 South Timbalier Block 63 and South Timbalier Block 86 include emissions, effluents, discarded trash and debris, and accidents.

Emissions: Noises f

rom 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, environmenta l 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 fo od 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 agen cies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA).

ERT will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting t rash 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 o f 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 o ther 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 Bea ch Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from ERT management or the designated lease operator management that emphasizes their commitm ent to waste management
in accordance with NTL No. 2012

- G01.

Accidents: Collisions between support vessels and cetaceans would be unusual events, however should one occur, death or injury to marine mammals is possible. Contract vessel operators can avoi d marine mammals and reduce potential deaths by maintaining a vigilant watch for marine mammals and maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to helpEnergy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) identify the twenty

- eight species of whales and dolphin s, 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 ves sel, 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 wit h a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@ BOEM .gov . If the vessel is the responsible party, it is required to remain available to assist the resp ective 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 activitie s (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 dispersant s on cetaceans is not known. The acute toxicity of oil dispersant chemicals included in ERT’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

c overed by ERT’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 c ause 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. Historical ly 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 transitor y 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).

Discar ded 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 substantial ly harm sea turtles. Operators are prohibited fromEnergy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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). ERT 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 precaut ions 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 persiste nt 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 ERT 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 mai ntaining 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 mus t 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 Of fice 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@ BOEM .gov . If the vessel is the responsible party, it is required to remain available to assist the respective salvage and stranding network as needed.

All sea turtle species and their life stages are vulnerable to the harmful effects of oil through direct contact or by fouling of their food. Exposure to oil can be fatal, particularly to juveniles and hatchlings. 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 ERT’s Regional Oil Spill Response P lan (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 sea turtles.Energy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 9. Air Quality

South Timbalier Block 63 and South Ti mbalier Block 86 are located approximately 75 miles from the Breton Wilderness Area and 20 miles from shore. Applicable emissions data is included in Section 8

of the Plan.

There would be a limited degree of air quality degradation in the immediate vici nity of the proposed activities. Plan Emissions for the proposed activities do not exceed the annual exemption levels as set forth by BOEM. Accidents and blowouts can release hydrocarbons or chemicals, which could cause the emission of air pollutants. Ho wever, these releases would not impact onshore air quality because of the prevailing atmospheric conditions, emission height, emission rates, and the distances of South

Timbalier Block 63 and South Timbalier Block 86 from the coastline. There are no other IPFs (including effluents, physical disturbances to the seafloor, wastes sent to shore for treatment or disposal) from the proposed activities which would impact air quality.

10. Shipwreck Sites (known or potential)
IPFs that could impact known or unknow n shipwreck sites as a result of the proposed operations in

South Timbalier Block 63 and South Timbalier Block 86 include disturbances to the seafloor and accidents (oil spill). South Timbalier Block 63 and South Timbalier Block 86 are not located in or

a djacent to an OCS block designated by BOEM as having a high probability for occurrence of shipwrecks. ERT will report to BOEM the discovery of any evidence of a shipwreck and make every reasonable effort to preserve and protect that cultural resource. Ther e are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or disposal, or accidents) from the proposed activities which could impact shipwreck sites.

Accidents: An accidental oil spill has the potential to cause some detrime ntal 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 ERT ’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 im pacts to shipwreck sites.

11. Prehistoric Archaeological Sites IPFs that could cause impacts to prehistoric archaeological sites as a result of the proposed operations in South Timbalier Block 63 and South Timbalier Block 86 are physical disturbances to t he seafloor and accidents (oil spills).

Physical Disturbances to the seafloor: South Timbalier Block 63 and South Timbalier Block 86 are located inside the Archaeological Prehistoric high probability lines. ERT 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.Energy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) Accidents: An accidental oil spill has the potential to cause some detrimental effects to prehistoric archaeological sites i f 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 ERT’s Regional Oil Spill Response P lan (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 South Timbalier Block 63 and South Timbalier Block 86 include physical disturbances to the seafloor, effl uents 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 Pi nnacle 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 Bo ttom (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 pr oduced

- 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 signifi cant 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 grea test 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 ERT’s Regional OSRP (refer to information submi tted in Section 9 ).

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.Energy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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 wil l be covered by ERT’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 perma nent injuries and death. Operators are prohibited from deliberately discharging debris as mandated by MARPOL

- Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the United States Coast G uard (USCG) and the Environmental Protection Agency (EPA). ERT 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

pr ecautions 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 per sistent 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 perso nnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from ERT 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 waste s sent to shore for treatment or disposal) from the proposed activities which could impact marine and pelagic

birds.Energy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 3. Public Health and Safety Due to Accidents.

In accordance with NTL No.’s 2008

- G04, 2009

- G27, and 2009

- G31, information has been included in

Section 4 to verify the presence of H 2 S for Well Locations A

– D (to be designated Well Nos. E006 through E009, under OCS

- G 00605 and drilled from the South Timbalier Block 86 E

- Aux platform).

There are no IPFs (emissions, effluents, physical disturba nces to the seafloor, wastes sent to shore for treatment or disposal or accidents, including an accidental H2S releases) from the proposed activities

for Well Locations E

– G (Well Nos. to be designated as stated at the beginning of this Environmental Impa ct Analysis and ultimately renamed as Well Nos. M001 through M003), 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 reques t that our proposed activities for these Wells 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.

Ac cidents: Oil spills contacting beaches would have impacts on the use of recreational beaches and associated resources. Due to the response capabilities that would be implemented, no significant adverse impacts are expected. The activities proposed in th is plan will be covered by ERT’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 mar ine 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). ERT will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash s ent 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 Li tter Problem” ). Thereafter, all personnel will view the marine trash and debrisEnergy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) training video annually. Offshore personnel will also receive an explanation from ERT management or the designated lease operator management that emphasizes their commitment t o waste management
in accordance with NTL No. 2012

- G01.

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

2. W etlands Salt marshes and seagrass beds fringe the coastal areas of the Gulf of Mexico. Due to the distance from shore (20 miles), accidents (oil spills) and discarded trash and debris represent IPFs which could impact these resources.

Accidents: Lev el of impact from an oil spill will depend on oil concentrations contacting vegetation, kind of oil spilled, types of vegetation affected, season of the year, pre

- existing stress level of the vegetation, soil types, and numerous other factors. Light

- oilin g impacts will cause plant die

- back with recovery within two growing seasons without artificial replanting. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5 , Water quality). If a spill were to occur,

res ponse capabilities as outlined in ERT’s Regional OSRP (refer to information submitted in Section

9 ) would be implemented.

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

Enviro nmental Protection Agency (EPA). ERT 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 p lastic 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, v essel 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 marin e trash and debris training video annually. Offshore personnel will also receive an explanation from ERT management or the designated lease operator management that emphasizes their commitment to waste management

in accordance with NTL No. 2012

- G01.

Ther e 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 wetlands.Energy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 3. Shore Birds and Coastal Nesting Birds WMA Wisner (27 .5 miles from South Timbalier Block 63 and South Timbalier Block 86) is a highly productive habitat for wildlife. Thousands of shore birds use the refuge as a wintering area. Also, wading birds nest on the refuge. The WMA provides habitat for colonies o f nesting wading birds and seabirds as well as wintering shorebirds and waterfowl. The most abundant nesters are brown pelicans, laughing gulls, and royal, Caspian, and sandwich terns. IPFs from the proposed activities that could cause impacts to shore b irds and coastal nesting birds are accidents (oil spills) and discarded

trash and debris.

Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. The birds most vulnerable to direct effects of oiling include those species tha t spend most of their time swimming on and under the sea surface, and often aggregate in dense flocks (Piatt et al., 1990; Vauk et al., 1989). Coastal birds, including shorebirds, waders, marsh birds, and certain water fowl, may be the hardest hit

indirec tly through destruction of their feeding habitat and/or food source (Hansen, 198l; Vermeer and Vermeer, 1975). Direct oiling of coastal birds and certain seabirds is usually minor; many of these birds are merely stained as a result of their foraging behav iors. Birds can ingest oil when feeding on contaminated food items or drinking contaminated water.

Oil

- spill cleanup operations will result in additional disturbance of coastal birds after a spill. However, it is unlikely that an oil spill would occur f rom the proposed activities (refer to Item 5 , Water quality). Due to the distance from shore being 20 miles, ERT would immediately implement the response capabilities outlined in their Regional OSRP (refer to information submitted in Section 9 ).

Discarde d trash and debris: Shore birds and coastal nesting 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). ERT will operate in accordance with the regulation s 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 wil l 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 fac ility 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 wi ll 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 receiv e an explanation from ERT management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012

- G01.Energy Resource Technolo gy GOM, Inc. Page Q

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Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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 South Timbalier Block 63 and South Timbalier Block 86 are approximately 27.5 m iles from the WMA Wisner. Management goals of the WMA are waterfowl habitat management, marsh restoration, providing sanctuary for nesting and wintering seabirds, and providing sandy beach habitat for a variety of wildlife species. IPFs from the proposed activities that could cause impacts to this coastal wildlife refuge are accidents (oil spills) and discarded trash and debris.

Impacts to shore birds and coastal nesting birds and to the beach, was covered in previous sections. Other wildlife species fo und on the refuges include nutria, rabbits, raccoons, alligators, and loggerhead turtles. Impacts to loggerhead turtles were also covered under a previous section.

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

, Water quality). Response capabilities would be implemented, no impacts are expected. The activities proposed in this plan will be covered by ERT’s Regional OSRP (refer to information submitted in

Section 9 ).

Discarded trash and debris: Op erators 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

Environmenta l Protection Agency (EPA). ERT 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 outsi de 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 plas tic 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, ves sel 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 ERT 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.Energy Resource Technolo gy GOM, Inc. Page Q

- 17

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) There are no other IPFs (emissions, efflu ents, 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 act ivities 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 (75 miles) and the

respons e capabilities that would be implemented, no significant adverse impacts are expected. The activities proposed in this plan will be covered by ERT’s Regional OSRP (refer to information

submitted in Section 9).

Discarded trash and debris: Operators are p rohibited 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). ERT 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 deb ris training video annually. Offshore personnel will also receive an explanation from ERT management or the designated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012

- G01.

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

areas.

6. Other Environmental Resources Identified
There are no other environmental resources identified for this impact assessment.

(C) IMPACTS ON PROPOSED ACTIVITIES

The site

– specific environmental conditions have been taken into account for the proposed activities. No impacts are expected on the proposed activities fro m site

- specific environmental conditions.Energy Resource Technolo gy GOM, Inc. Page Q

- 18

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) (D) ENVIRONMENTAL HAZARD S 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, South Timbalier Block 63 and South Timbalier Block 86 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 with NTL No.’s 2008

- G09, 2009

- G10, and 2010

- N10.

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

Storm or Hurricane threat.

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

Hurricane threat.

(E) ALTERNATIVES

No alternatives to the proposed activities were considered to reduce environmental impacts.

(F) MITIGATION MEASURES

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

(G) CONSULTATION

No agencies or persons were consulted regarding potential impacts associated with the proposed activities. Therefore, a list of such entities has not been provided.Energy Resource Technolo gy GOM, Inc. Page Q

- 19

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) (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

Author s:

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.

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

- 43.

Daly, J.M. 1997. Controlling the discharge of synthetic

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

Hansen, D.J. 198l. The relative sensitivity of seabird populations in Alaska to oil pollution. U.S. Dept.

of the Inter ior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLM

- YK

- ES

- 81

- 006

- 1792.

Laist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris including a comprehensive list of species with entanglement and ingestion recor ds. 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.Energy Resource Technolo gy GOM, Inc. Page Q

- 20

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) 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 Surv eys

 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.Energy Resource Technology GOM, Inc. Page R

- 1

Supplemental DOCD November 20, 2013

South Timbalier Blocks 63/86 ( OCS

- G 00599/00605 ) APPENDIX R

ADMINISTRATIVE INFORMATION

( A ) EXE MPTED INFORMATION DESCRIPTION The proposed bottom

- hole locations of the planned well (s) have been removed from the public information copy of the DOCD as well as any discussions of the target objectives, geologic or geophysical data, and any interpreted g eology.

(B) BIBLIOGRAPHY Not applicable.

## Attachment AU.S. Department of the Interior OMB Control Number: 1010

- 0151

Bureau of Ocean Energy Management OMB Approval Expires: 12/31/14

OCS PLAN INFORMATION FORM

General Information

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

Company Name: Energy Resource Technology GOM, Inc. BOEM Operator Number: 02899

Address: 500 Dallas Street, Suite 2000 Contact Person: Cathy Thornton

Houston, Texas 77002 Phone Number: 713

- 705

- 8020

Email Address: cathy.thornton@jccteam.com

If a service fee is required under 3 0 CFR 550.125(a), provide the Amount paid $29,666.00 Receipt No. 25D7IUEP

Project and Worst Case Discharge (WCD)Information

Lease(s): OCS 00599/00650 Area: ST Block(s): 63/86 Project Name (if applicable):

Objective(s): X Oil X Gas Sulphur Salt Onsh ore Support Base(s):

Platform/Well Name: E

- Aux/M Total Volume of WCD: 6 705 API Gravity: 37°

Distance to Close s t Land (Miles): 19.4 Volume from uncontrolled blowout: 4270

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

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

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

Do you propose to use a vessel with ancho rs 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 S tart Date End Date No. of Days

D&C Loc A & B; D&TA Loc E 04/01/2014 06/29/2014 90

D&C Loc F; Complete Loc E 0 3 /01/201 5 05/11/2015 72

D&C Loc C & D 03/01/2016 04/29/2016 60

D&C Loc G 03/01/2017 04/23/201 7 54

Installation or modification of structure 0 6 /01 /201 5 0 6 /05/201 5 5

Installation of production facilities 06/ 06/201 5 09/1 1 /201 5 5

Installation of subsea wellheads and/or manifolds

Installation of lease term pipelines 0 6 /20/201 5 09/30/201 5 10

Commence production 07 / 01 /2014
Other (Specify and attach description)

Description of Drilling Rig Description of Structure

X Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform Rig X Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed tower

DP Semisu bmersible 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)

ST86 M platform ST63 A platform 6

- inches 10,500’

ST63 A platform ST86 M platform 3

- inches 10,500’

FORM BOEM

- 0137 ( Decem ber 2011

- Supersedes all previous editions of this form which may not be used. Page 1 of 4OCS PLAN INFORMATION FORM (CONTIN UED) 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)

E006 (Well Location A) Previously reviewed under an approved EP or DOCD? Yes X 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. 24 161

- 2

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

WCD info For wells, volume of uncontrolled

blowout (Bbls/day) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37°

Surface Location Bottom

- Hole Location (For Wells) Completion (For multiple

co mpletions, enter separate lines)

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 1967.99’ FNL

E/W Departure: 7795.34’ FEL

Lambert X

- Y

coordinates X: 2,356,339.92’

Y: 43,813.7 7’

Latitude / Longitude Latitude: 28°46’56.601”N

Longitude: 90°13’16.225”W

Water Depth (Feet):

98’ Anchor Radius (if applicable) in feet:

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied ab ove, 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 ( Decemb er 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS 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)

E00 7 (Well Location B ) Previo usly reviewed under an approved EP or

DOCD? Yes X 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. 24 161

- 2

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

WCD info For wells, volume of uncontrolled

blowout (Bbls/day) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37°

Surface Location Bottom

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

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 19 99

. 73 ’ FNL

E/W Departure: 77 89.41 ’ FEL

Lambert X

- Y

coordinates X: 2,356,33 8.85 ’

Y: 43,81 8.36 ’

Latitude / Longitude Latitude: 28°46’56.6 46 ”N

Longitude: 90°13’16. 158 ”W

Water Depth (Feet):

98’ Anchor Radius (if applicable) in feet:

Anchor Locations for Drilling Rig or Construction Ba rge (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 ( Decem b er 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS 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)

E00 8 (Well Location C ) Previ ously reviewed under an approved EP or

DOCD? Yes X 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. 24 161

- 2

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

WCD info For wells, volume of uncontrolled

blowout (Bbls/day) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37°

Surface Location Bottom

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

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 196 4

. 75 ’ FNL

E/W Departure: 77 78

. 89 ’ FEL

Lambert X

- Y

coordinates X: 2,356, 349.37 ’

Y: 43,81 7

. 01 ’

Latitude / Longitude Latitude: 28°46’56.6 32 ”N

Longitude: 90°13’16. 04 ”W

Water Depth (Feet):

98’ Anchor Radius (if applicable) in feet:

Anchor Locations for Drilling Rig or Construction Ba rge (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 ( Decem b er 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS 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)

E00 9 (Well Location D ) Prev iously reviewed under an approved EP or

DOCD? Yes X 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. 24 161

- 2

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

WCD info For wells, volume of uncontrolled

blowout (Bbls/day) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37°

Surface Location Bottom

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

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 19 58.82 ’ FNL

E/W Departure: 77 8 3.47 ’ FEL

Lambert X

- Y

coordinates X : 2,356,3 44

. 79 ’

Y: 43,8 22

. 94 ’

Latitude / Longitude Latitude: 28°46’56.6 91 ”N

Longitude: 90°13’16. 091 ”W

Water Depth (Feet):

98’ Anchor Radius (if applicable) in feet:

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 ( De cemb er 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS 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) #025 (Well Location E) Previously reviewed under an approved EP or

DOCD? Yes X No

Is this an existing well or

structure? Yes X No If this is an existing well or structure, list the Complex ID or API No. 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) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37 °

Surface Location Bottom

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

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 24’ FNL

E/W Departure: 2798’ FWL

Lambert X

- Y

coordinates X: 2,352,168.22

Y: 45,757.76

Latitude / Longitude Latitude: 28°47’16.242”N

Longitude: 90°14’02.808”W

Water Depth (Feet):

94’ Anchor Radius (if applicable) in feet:

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=

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. 2501 et seq.) requires us to inform you that BOEM collects this information as part of an applicant’s Exploration Plan or Development Operations Coordinat ion Document submitted for BOEM approval. We use the information to facilitate our review and data ent ry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor

, and a person is not required to respond to, a collection of information unless it displays a currently valid Office of Management and Budget Control Number. Responses are mandatory (43 U.S.C. 1334). The public reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations Coordination Documents. We estima te that burden to average 600 hours with an accompanying EP, or 700 hours with an accompanying DPP or DOCD, including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. Dir ect comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Oce an Energy Management, 381 Elden Street, Herndon, VA 20170.

FORM BOEM

- 0137 (December 201 1

- Supersedes all previous edi tions of this form which may not be used.) Page 2 of 4OCS 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)

#030 (Well Location F ) Previously reviewed under an approved EP or

DOCD? Yes X No

Is this an existing well or

structure? Yes X No If this is an existing well or structure, list the Complex ID or API No. 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) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37 °

Surface Location Bottom

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

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 24’ FNL

E/W Departure: 2798’ FWL

Lambert X

- Y

coordinates X: 2,352,168.22

Y: 45,757.76

Latitude / Longitude Latitude: 28°47’16.242”N

Longitude: 90°14’02.808”W

Water Depth (Feet):

94’ Anchor Radius (if applicable) in feet:

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=

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. 2501 et seq.) requires us to inform you that BOEM collects this information as part of an applicant’s Exploration Plan or Development Operations Coordinat ion Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor

, and a person is not required to respond to, a collection of information unless it displays a currently valid Office of Management and Budget Control Number. Responses are mandatory (43 U.S.C. 1334). The public reporting burden for this form is included in the burden for preparing Exploration Plans an d Development Operations Coordination Documents. We estimate that burden to average 600 hours with an accompanying EP, or 700 hours with an accompanying DPP or DOCD, including the time for reviewing instructions, gathering and maintaining data, and complet ing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Oce an Energy Management, 381 Elden Street, Herndon, VA 20170.

FORM BOEM

- 0137 (December 201 1

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS 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)

#03 1 (Well Location G ) Previously reviewed under an approved EP or

DOCD? Yes X No

Is this an existing well or

structure? Yes X No If this is an existing well or structure, list the Complex ID or API No. 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) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37 °

Surface Location Bottom

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

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 24’ FNL

E/W Departure: 2798’ FWL

Lambert X

- Y

coordinates X: 2,352,168.22

Y: 45,757.76

Latitude / Longitude Latitude: 28°47’16.242”N

Longitude: 90°14’02.808”W

Water Depth (Feet):

94’ Anchor Radius (if applicable) in feet:

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=

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. 2501 et seq.) requires us to inform you that BOEM collects this information as part of an applicant’s Exploration Plan or Development Operations Coordinat ion Document submitted for BOEM approval. We use the information to facilitate our review and data entry for OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An agency may not conduct or sponsor

, and a person is not required to respond to, a collection of information unless it displays a currently valid Office of Management and Budget Control Number. Responses are mandatory (43 U.S.C. 1334). The public reporting burden for this form is included in the burden for preparing Exploration Plans an d Development Operations Coordination Documents. We estimate that burden to average 600 hours with an accompanying EP, or 700 hours with an accompanying DPP or DOCD, including the time for reviewing instructions, gathering and maintaining data, and complet ing and reviewing the forms associated with subpart B. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Oce an Energy Management, 381 Elden Street, Herndon, VA 20170.

FORM BOEM

- 0137 (December 201 1

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4OCS PLAN INFORMATION FORM (CONTINUED) Include one copy of this page for each proposed well/structure

Proposed Well/Structure Location Well or Structure Name / Number (if renaming well or structure, reference previous name)

Platform M Previously reviewed under an approved EP or

DOCD? Yes X No

Is this an existing well or

structure? Yes X No If this is an existing well or structure, list the Complex ID or API No. 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) 4270 For structures, volume of all storage and pipelines (Bbls) 2 435 API Gravity of

fluid 37 °

Surface Location Bottom

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

Lease No. OCS 00605

Area Name ST

Block No. 86

Block Line Departures (in feet) N/S Departure: 24’ FNL

E/W Departure: 2798’ FWL

Lambert X

- Y

coordinates X: 2,352,168.22

Y: 45,757.76

Latitude / Longitude Latitude: 28°47’16.242”N

Longitude: 90°14’02.808”W

Water Depth (Feet):

94’ Anchor Radius (if applicable) in feet:

3500 ’ 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=

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FORM BOEM

- 0137 (December 201 1

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## Attachment B

## Attachment C36499 Perkins Road Prairieville, Louisiana 70769 Telephone: 225.673.2163

Fax: 225.744.3116

www.teslaoffshore.com

November 12 , 2013 Job No. 13

- 017

- 1 1

Bureau of Ocean Energy Management (MS 5230) Gulf of Mexico OCS Region

1201 Elmwood Park Blvd. New Orleans, LA 70123

- 2394

RE: Energy Resources Technology GOM, Inc. Proposed Well s E, F, and G, OCS 00605

Block 86

, South Timbalier Area Shallow Hazards and Archaeological Assessment

Energy Resources Technology GOM, Inc. (ERT) p roposes to drill Well s E, F, and G from the following common surface location :

Datum:

NAD 27 Spheroid:

Clarke 1866 Projection:

LAMBERT Zone:

LAS Central Meridian:

91° 2 0’ West

Latitude: 28° 47' 16.242 ” N Longitude: 90° 14' 02.808 ” W

X: 2,352,168.22 Y: 45,757.76

F N L: 24 ’ F W L: 2,798 ’

Tesla Offshore

, LLC conducted a high

- resolution geophysical survey covering all of Block
63 and the northern half of Block 86 with 300m extensions run in adjacent blocks to the south, east, and west , South Timbalier Area between May 6 and June 3 , 2013, using

300

- meter primary grid spacing and 900

- meter tie lines

. ERT selected Tesla Offshore, LLC to prepare this shallow hazard and archaeological assessment for the proposed drill site to comply with NTL No. 2008

- G05 and NTL No. 2005

- G07 from the Bureau of Ocean Energy Management (BOEM), Gulf of Mexico Region

. Geophysica l record copies are enclosed for the magnetometer, side scan sonar, subbottom profiler, echo sounder, and processed seismic sections from the survey line nearest the proposed common well site as required by the BOEM in NTL No. 2008

- G04

.

Water depth is slightly less than 94 feet BSL surrounding the proposed surface location. Water depths increase to the south east at an approximate rate of 6.8 feet per mile.

Seafloor sediments are reportedly silty clay ( USDI MMS Visual No. 3 , 1983 ).

Seafloor installations located within 1,000 feet of the proposed well site include the Block 63 P&A Well No. 17 located approximately 360 feet NE, the 4” ERT pipeline (Segment No. 10831) located approximately 360 feet NE at its closest point, the 4” and 6” ERT pip eline bundle (Segments No. 9633 and 9632) located approximately 360 feet NE at its closest point, the 10” Trunkline pipeline (Segment No. 7963) located approximately 500 feet east at its closest point, the Block 86 Platform ‘F’ located approximately 835 fe et to the SSW, and the 4” and 3 ” ERT pipeline bundle (Segments No. 9385 and 9441) located approximately 835 feet SSW at its closest point.TESLA OFFSHORE

Energy Resources Technology GOM, Inc. Proposed Wells E, F, and G, OCS 00605

Block 86

, South Timbalier Area Shallow Hazards and Archaeological Assessment Page 2

Magnetic anomalies are not located within 1,000 feet of the proposed surface

location due to the overwhelming magnetic signature of P&A Well No. 17 and its associated pipelines

. The closest discernable anomaly is no. 23

, located approximately 1,400 feet to the SE

. This anomaly is a 22 nT dipole wit h a 387 foot

duration and has been designated for avoidance by 195 feet as a potent ial hazard only

.

Side scan sonar verified that the seafloor immediately surrounding the proposed well site was clear of protruding obstructions. No sonar targets were observed within 1,000 feet of the proposed surface location. The nearest recorded sonar target is target no

. 1 2 , located approximately 1,025 feet to the west . This target is an irregular

feat ure measuring approximately 23 feet in length, 5 feet in width with no observed
relief above the surrounding seafloor. This target has bee n recommended for avoidance by 50 feet as a potent ial hazard only

.

Subbottom data indicates that the seafloor at the proposed well location is moderately reflecting, and overlies approximately 16 feet of moderately stratified,

para llel bedded sediments of low to moderate reflectivity

. These stratified sediments parallel the seafloor and are underlain by a zone of acoustically amorphous deposits approximately 4 feet thick, which in turn overlies an apparent migrating gas front at a depth of approximately 23 ft BML; the subbottom signal i s completely attenuated below the interpreted gas front

. Drilling engineers should be aware of the underlying gas front and take appropriate precautions to mitigate the risk of fluid expulsion. Although near

- seabed conditions are not interpreted as probl ematic based on the available data, it is not possible to determine the physical characteristics of the near

seafloor sediments (such as bearing shear strength) from the subbottom data; therefore, geotechnical testing would be required to quantify near

- sea floor sediment properties.

Processed seismic data (3 .0 sec o nds) recorded approximately 2.95 seconds BM L

of usable subsurface data except where a salt dome attenuated the data within the

south

- central portion of the grid

. The seismic data display a mo derately reflecting disrupted parallel and subparallel general reflection patte rn throughout the en tire

record

. Several normal faults were observed throughout the area, the closest of

which were first observed on the seismic records approximately 3,105 feet to the

east of the proposed surface location at a depth of 442 ms BSL and 3,685 feet to the
SSW at a depth of 364 ms BSL

. The well path may intersect the fault located to the
SSW at approximately 1,650 ms BSL, although it is diff icult to determine because the possible intersection occurs near where the fault becomes attenuated adjacent to the salt. The operator will carefully assess their 3D data in the area surrounding the salt to assure adequate precautions are taken if the fault is intersected. A mplitude anomalies were observed throughout the survey area, the cl osest of which was

observed approximately 935 feet to the east of the proposed surface location at a depth of 885 ms BSL

.TESLA OFFSHORE

Energy Resources Technology GOM, Inc. Proposed Wells E, F, and G, OCS 00605

Block 86

, South Timbalier Area Shallow Hazards and Archaeological Assessment Page 3

The operator has identified the primary hazards to rig movements, any ancillary a nchor and/or mooring deployments, and drilling. The proposed surface location will be marked with DGPS during rig moves and drilling to comply with the BOEM On

- Site Requirements specified in NTL No. 2008

- G05, Section VI, Item B

- 2(a).

No sonar targets, ma g netic anomalies, or other features on the geophysical data were recorded which were interpreted as possible shipwrecks, or possible high probability areas for prehistoric habitation within 1,000 feet of the proposed well location . Pursuant
to 30 CFR 550. 194 (c), 30 CFR 550.101 (c), and NTL No. 2005

- G07 , if any archaeological or potentially historically significant materials are observed during lease development, operations will immediately cease in that area and appropriate BOEM/BSEE personnel will be not ified within 48 hours of discovery.

ERT and subcontractors will apply the safest and best available technologies during rig moves and drilling operations.

Sincerely,

John Allen Amanda Evans, PhD, RPA

M arine Geologist Senior Marine Archaeologist

## Attachment HDOCD AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/14COMPANYEnergy Resource Technology GOM, Inc.AREASouth TimbalierBLOCK86LEASEOCS 00605PLATFORME/E-Aux and MWELLWell Locations A-GCOMPANY CONTACTCathy ThorntonTELEPHONE NO.713 705 8020REMARKSLEASE TERM PIPELINE CONSTRUCTION INFORMATION:YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYSPIPELINES20132014 2 10201520162017201820192020FORM BOEM-0139(December 2011- Supersedes all previous versions of this form which may not be used).Page 1 of 8AIR EMISSIONS CUMPUTATION FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6La. DEQ 1991Gas Venting lbs/scf 0.0034Sulphur Content Source Value UnitsFuel Gas 3.33 ppmDiesel Fuel 0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightFORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 2 of 8AIR EMISSIONS CALCULATIONS - FIRST YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSEnergy Resource Techno South Timbalier 86 OCS 00605 E/E-Aux and M Well Locations A-G Cathy Thornton 713 705 8020 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOxVOC CO PM SOx NOxVOC CODRILLING PRIME MOVER>600hp diesel 16975 819.8925 19677.42 24 90 11.96 54.89 411.29 12.34 89.74 12.92 59.28 444.19 13.33 96.91PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 90 1.46 6.68 50.03 1.50 10.92 0.52 2.40 18.01 0.54 3.93VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 39 1.46 6.68 50.03 1.50 10.92 0.28 1.29 9.65 0.29 2.11VESSELS>600hp diesel(tugs) 12600 608.58 14605.92 24 2 8.88 40.74 305.29 9.16 66.61 0.21 0.98 7.33 0.22 1.60PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE BURY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTION RECIP.<600hp dieselcrane PF E150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06PF E/E-AuxRECIP.<600hp dieselcrane PFE-Aux150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06RECIP.>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL dieselshared2065 99.7395 2393.75 8 156 1.46 6.68 50.03 1.50 10.92 0.91 4.18 31.31 0.94 6.83TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle rich nat gasPF E-Aux1000 7143 171432.00 24 365 0.00 22.03 0.31 18.94 0.02 96.48 1.35 82.97BURNER nat gasPF E2.5 2380.95 57142.86 24 84 0.02 0.00 0.24 0.01 0.20 0.02 0.00 0.24 0.01 0.20MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 1250.0 365 0.63 2.74GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002014 YEAR TOTAL25.89 116.64 898.19 27.69 210.24 14.91 68.20 607.76 19.46 194.67EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES646.02 646.02 646.02 646.02 24547.8519.4FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 3 of 8AIR EMISSIONS CALCULATIONS - SECOND YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSEnergy Resource Techno South Timbalier 86 OCS 00605 E/E-Aux and M Well Locations A-G Cathy Thornton 713 705 8020 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 16975 819.8925 19677.42 24 72 11.96 54.89 411.29 12.34 89.74 10.34 47.42 355.35 10.66 77.53PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 72 1.46 6.68 50.03 1.50 10.92 0.42 1.92 14.41 0.43 3.14VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 31 1.46 6.68 50.03 1.50 10.92 0.22 1.03 7.72 0.23 1.68VESSELS>600hp diesel(tugs) 12600 608.58 14605.92 24 2 8.88 40.74 305.29 9.16 66.61 0.21 0.98 7.33 0.22 1.60PIPELINE PIPELINE LAY BARGE diesel 1500 72.45 1738.80 24 10 1.06 4.85 36.34 1.09 7.93 0.13 0.58 4.36 0.13 0.95INSTALLATION MATERIAL TUG diesel 4200 202.86 4868.64 24 10 2.96 13.58 101.76 3.05 22.20 0.36 1.63 12.21 0.37 2.66PIPELINE BURY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 2 1.46 6.68 50.03 1.50 10.92 0.01 0.07 0.50 0.02 0.11FACILITY DERRICK BARGE diesel 2500 120.75 2898.00 24 10 1.76 8.08 60.57 1.82 13.22 0.21 0.97 7.27 0.22 1.59INSTALLATION MATERIAL TUG diesel 4200 202.86 4868.64 24 10 2.96 13.58 101.76 3.05 22.20 0.36 1.63 12.21 0.37 2.66VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 2 1.46 6.68 50.03 1.50 10.92 0.01 0.07 0.50 0.02 0.11PRODUCTION RECIP.<600hp dieselcrane PF E150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06PF E/E-Aux & MRECIP.<600hp dieselcrane PFE-Aux150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06RECIP.<600hp dieselcrane PF M150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06SUPPORT VESSEL dieselshared2065 99.7395 2393.75 8 156 1.46 6.68 50.03 1.50 10.92 0.91 4.18 31.31 0.94 6.83TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle lean nat gas000.00000.000.000.000.000.000.000.000.00RECIP.4cycleleannatgasRECIP.4 cycle rich nat gasPF E-Aux1000 7143 171432.00 24 365 0.00 22.03 0.31 18.94 0.02 96.48 1.35 82.97BURNER nat gasPF E2.5 2380.95 57142.86 24 84 0.02 0.00 0.24 0.01 0.20 0.02 0.00 0.24 0.01 0.20MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 1875.0 365 0.94 4.11GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL37.87 170.57 1303.32 40.38 298.62 13.26 60.58 550.72 19.13 182.22EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES646.02 646.02 646.02 646.02 24547.8519.4FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 4 of 8AIR EMISSIONS CALCULATIONS - THIRD YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSEnergy Resource Techno South Timbalier 86 OCS 00605 E/E-Aux and M Well Locations A-G Cathy Thornton 713 705 8020 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 16975 819.8925 19677.42 24 72 11.96 54.89 411.29 12.34 89.74 10.34 47.42 355.35 10.66 77.53PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 72 1.46 6.68 50.03 1.50 10.92 0.42 1.92 14.41 0.43 3.14VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 31 1.46 6.68 50.03 1.50 10.92 0.22 1.03 7.72 0.23 1.68VESSELS>600hp diesel(tugs) 12600 608.58 14605.92 24 2 8.88 40.74 305.29 9.16 66.61 0.21 0.98 7.33 0.22 1.60PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE BURY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTION RECIP.<600hp dieselcrane PF E150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06PF E/E-Aux & MRECIP.<600hp dieselcrane PFE-Aux150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06RECIP.<600hp dieselcrane PF M150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06SUPPORT VESSEL dieselshared2065 99.7395 2393.75 8 156 1.46 6.68 50.03 1.50 10.92 0.91 4.18 31.31 0.94 6.83TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle lean nat gas000.00000.000.000.000.000.000.000.000.00RECIP.4cycleleannatgasRECIP.4 cycle rich nat gasPF E-Aux1000 7143 171432.00 24 365 0.00 22.03 0.31 18.94 0.02 96.48 1.35 82.97BURNER nat gasPF E2.5 2380.95 57142.86 24 84 0.02 0.00 0.24 0.01 0.20 0.02 0.00 0.24 0.01 0.20MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 1875.0 0 0.94 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002016 YEAR TOTAL26.22 117.12 902.82 28.37 211.24 12.18 55.64 513.66 13.91 174.14EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES0.00 0.00 0.00 0.00 0.000.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 5 of 8AIR EMISSIONS CALCULATIONS - FOURTH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSEnergy Resource Techno South Timbalier 86 OCS 00605 E/E-Aux and M Well Locations A-G Cathy Thornton 713 705 8020 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 16975 819.8925 19677.42 24 54 11.96 54.89 411.29 12.34 89.74 7.75 35.57 266.51 8.00 58.15PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 54 1.46 6.68 50.03 1.50 10.92 0.31 1.44 10.81 0.32 2.36VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 23 1.46 6.68 50.03 1.50 10.92 0.17 0.77 5.79 0.17 1.26VESSELS>600hp diesel(tugs) 12600 608.58 14605.92 24 2 8.88 40.74 305.29 9.16 66.61 0.21 0.98 7.33 0.22 1.60PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE BURY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTION RECIP.<600hp dieselcrane PF E150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06PF E/E-Aux & MRECIP.<600hp dieselcrane PFE-Aux150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06RECIP.<600hp dieselcrane PF M150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06SUPPORT VESSEL dieselshared2065 99.7395 2393.75 8 156 1.46 6.68 50.03 1.50 10.92 0.91 4.18 31.31 0.94 6.83TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle lean nat gas000.00000.000.000.000.000.000.000.000.00RECIP.4cycleleannatgasRECIP.4 cycle rich nat gasPF E-Aux1000 7143 171432.00 24 365 0.00 22.03 0.31 18.94 0.02 96.48 1.35 82.97BURNER nat gasPF E2.5 2380.95 57142.86 24 84 0.02 0.00 0.24 0.01 0.20 0.02 0.00 0.24 0.01 0.20MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 1875.0 0 0.94 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002017 YEAR TOTAL26.22 117.12 902.82 28.37 211.24 9.44 43.04 419.29 11.08 153.55EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES0.00 0.00 0.00 0.00 0.000.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 6 of 8AIR EMISSIONS CALCULATIONS - FIFTH YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSEnergy Resource Techno South Timbalier 86 OCS 00605 E/E-Aux and M Well Locations A-G Cathy Thornton 713 705 8020 #REF!OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE PIPELINE LAY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE BURY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTION RECIP.<600hp dieselcrane PF E150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06PF E/E-Aux & MRECIP.<600hp dieselcrane PFE-Aux150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06RECIP.<600hp dieselcrane PF M150 7.245 173.88 2 60 0.33 0.49 4.63 0.37 1.00 0.02 0.03 0.28 0.02 0.06SUPPORT VESSEL dieselshared2065 99.7395 2393.75 8 156 1.46 6.68 50.03 1.50 10.92 0.91 4.18 31.31 0.94 6.83TURBINE nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle lean nat gas000.00000.000.000.000.000.000.000.000.00RECIP.4cycleleannatgasRECIP.4 cycle rich nat gasPF E-Aux1000 7143 171432.00 24 365 0.00 22.03 0.31 18.94 0.02 96.48 1.35 82.97BURNER nat gasPF E2.5 2380.95 57142.86 24 84 0.02 0.00 0.24 0.01 0.20 0.02 0.00 0.24 0.01 0.20MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00FLARE- 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PROCESS VENT- 0 0 0 0.00 0.00FUGITIVES- 1875.0 0 0.94 0.00GLYCOL STILL VENT- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002018 YEAR TOTAL2.46 8.14 86.17 3.87 33.06 0.99 4.28 128.85 2.37 90.18EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES0.00 0.00 0.00 0.00 0.000.0FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 7 of 8AIR EMISSIONS CALCULATIONSCOMPANY AREA BLOCK LEASE PLATFORM WELLEnergy ResourceSouth Timbalier 86 OCS 00605 E/E-Aux and M Well Locations A-GEmitted SubstanceYearPM SOx NOx VOC CO2014 14.91 68.20 607.76 19.46 194.672015 13.26 60.58 550.72 19.13 182.222016 12.18 55.64 513.66 13.91 174.142017 9.44 43.04 419.29 11.08 153.552018 0.99 4.28 128.85 2.37 90.182019 0.99 4.28 128.85 2.37 90.182020 0.99 4.28 128.85 2.37 90.182021 0.99 4.28 128.85 2.37 90.182022 0.99 4.28 128.85 2.37 90.182023 0.99 4.28 128.85 2.37 90.18Allowable646.02 646.02 646.02 646.02 24547.85FORM BOEM-0139(December 2011 - Supersedes all previous versions of this form which may not be used).Page 8 of 8

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