UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field Operations (MS 5231)

Public Information copy of DOCD

Control # - S-07732

Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS-G15563 Block - 237 Green Canyon Area

Operator - Energy Resource Technology GOM, Inc.

Drill, Complete Well K

DP Semisubmersible

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.

Tonya Jez
Plan Coordinator

G15563/GC/237 788 FNL, 5965 FEL G15563/GC/237 WELL/K Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk Site Type/Name Description -

Rig Type - Subject: From: March 16, 2015

## P ublic Information Copy
January 22, 2015



## SUPPLEMENTAL DEVELOPMENT OPERATIONS

COORDINATION DOCUMENT

Lease Number: OCS

- G 15563

Area/Block : Green Canyon Block 237

Prospect Name: Motormouth II Prospect

Offshore: Louisiana

Submit ted by: Energy Resource Technology GOM, Inc.


### 500 Dal las Street

Suite 2000 Houston, Texas 77002

M andy Phythi an ( 713) 3 80

- 4930

m phythian@talosenergyllc.com

Estim ated startup date : June 1, 2015

Authori zed Representative: No. Copies Being Submitted: Cathy Thornton Proprietary: 1 Copy & CD J. Connor Consulting, Inc. Public Info: 1 Copy & CD 16225 Park Ten Place, Suite 700 Houston, Texas 77084 ( 713 ) 705

- 8020 cathy.thornton@jccteam.com For BOEM : Plan No. S-7732 Assigned to: Tonya JezENERGY RESOURCE TECHNOLGY GOM, INC.

S UPPLEMENTAL DEVELOPMENT OPERATIONS COORDINATION DOCUMENT

LEAS E OCS

- G 15563

G REEN CANYON BLOCK 237

A PPENDIX A Plan Contents

A PPENDIX B General Information

A PPENDIX C Geological, Geophysical Information

A PPENDIX D H2S Information

A PPENDIX E Mineral Resource Conservation Information

A PPENDIX F Biological, Physical and Socioeconomic Information

A PPENDIX G Wastes and Discharge Information

A PPENDIX H Air Emissions Information

A PPENDIX I Oil Spill s Inf ormation

A PPENDIX J Environmental Monitoring Information

A PPENDIX K Lease Stipulations Information

A PPENDIX L Environmental Mitigation Measures Information

A PPENDIX M Related Facilities and Operations Information

A PPENDIX N Support Vessels and Aircraft Information

A PPENDIX O Onshore Support Facilities Information

A PPENDIX P Coastal Zone Management Act (CZMA) Information

A PPENDIX Q Environmental Impact Analysis

A PPENDIX R Administrative InformationRecord of Changes

Date Appendix Revision

01/27/2015 B In cluded the Blowout Scenario from the previously approved WCD

for GC237 Plan Control No. R

- 5300

03/02/2015 A Corrected the Sand 2 Name from A

- 0 to A

- 1 on Page 3 of 4 of the

OCS Plan Information Form

### A PPENDIX A

PLAN CONTENTS

(A) P LAN INFORMATION FORM Under this Plan, ERT proposes to drill, complete and produce Lease OCS

- G 15563 Well Location K ( Motormouth II Prospect) located in Green Canyon Block 237. The well is located in a water depth of approximately 21 30 ’ and will be drilled and completed with a DP

semisubmersible r ig. The Motormouth II well will connect back to the proposed GC237 Expansion Manifold.

S ee attached OCS Plan Information Form – Form BOEM -137 included in Attachment A

.

(B) L OCATION

Included in Attachment A is a Well Location Plat depicting the proposed surface and bottom

location of the proposed well. Also included is a Bathymetry Plat depicting the water depth at the proposed location.

(C) S AFETY AND POLLUTION PREVENTION FEATURES ERT will drill the well with a DP semisubmersible rig which is equipped with a Subsea BOP. Once a rig is contracted, BOP information and schematics will be included as a part of the Application for Permit to Drill.

T he rig will be equipped with safety and fire

- fighting equipment required to comply with United States Coast Guard (USCG) regulations. Appropriate life saving equipment such as life rafts, life jackets, ring buoys, etc. as prescribed by the USCG, will be maintaine d on the rig at all times. Safety features on the drilling unit will include well control, pollution prevention, and blowout prevention equipment as described in BSEE regulations 30 CFR 250 C, D, E, O, Q and S; and as further clarified by BSEE Notices to Lessees, and current policy making invoked by the BSEE, Environmental Protection Agency and the U.S. Coast Guard (USCG).

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

(D) S TORAGE TANKS AND/OR PRODUCTION VESSELS All facility tanks of 25 barrels or more.

Type of Storage Tank Type of Facility Tank Capacity (bbls) Number

of Tanks Total Capacity

(bbls) Fluid Gravity (API)

Fuel Oil (Marine Diesel) DP MODU 5000 6 30,000 32.4

Energy Resources Technology GOM, Inc. Page A-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563 )(E) P OLLUTION PREVENTION MEASURES (F LORIDA ONLY) Pollution prevention measures information is not required by BOEM to be included in this P lan.

(F) A DDITIONAL MEASURES

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

(G ) C OST RECOVERY FEE

Included in Attachment A is a P ay G ov receipt in the amount of $ 4238 to cover operations proposed in this plan.

Energy Resources Technology GOM, Inc. Page A-2 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563 )

### APPENDIX B

GENERAL INFORMATION

( A) A PPLICATIONS AND PERMITS

Listed in the table below are additional permits/applications to be filed before operations can

commence under this Plan :

Application/Permit Issuing Agency Status Application for Permit to Drill B SEE Pending Supplemental Deepwater Operations Plan BSEE Pending

Lease Term Pipeline Application BSEE Pending Surface Commingling Application BSEE Pending

(B) DRI LLING FLUIDS

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

Water

- based (Seawater, freshwater, barite) 10,000

Oil

- based (diesel, minerals, oil) 0

Synthetic

- based (internal olefin, ester) 6,000

(C ) P RODUCTION Anticipated Production:

Type Average Production Rate Peak Production Rate Life of Reservoir

Oil

Gas

(D) OIL CHARACTERISTICS

The oil characteristics for the B

- 2 target sand in the Motormouth II prospect are based on the analogue PVT data in the B

- 2 reservoir that was competed in the GC 237 OCS G15563 #001

ST01 well. The # 00 1 ST 0 1 well perforated the B

- 2 sand from 15,408'

– 15,488’ TVD and produced as an undersaturated, flowing oil well with a bubble point pressure of 5400 psia. The original reservoir pressure and temperature in the B

- 2 sand were 11,580 psia and 180 deg

. F respectively. The PVT data for the B

- 2 sand exhibits a bubble point pressure of 5400 psia, a viscosity of 0.53 cp. (@ reservoir pressure), 36.9 deg. API gravity (although subsequent well test data showed 30.0 deg. API gravity oil), and a solution GOR of 1547 scf/bbl. The anticipated, current reservoir pressure and temperature in the B

- 2 sand are 9649 psia and 175 deg. F

resp ectively based on MDT data extracted from the Motormouth I well. The current reservoir pressure indicates that the B

- 2 is still an undersaturated oil with properties similar to the initial

PVT results from the B -2 sand in GC 237 #00 1 ST 01.

Energy Resource Technology GOM, Inc. Page B-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)( 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 and facilities proposed in this DOCD 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 256.53(d) and National NTL No. 2003

- N06, “Supplemen tal Bond

Procedures.”

( G ) OIL SPILL FINANCIAL RESPONSIBILITY (OSFR) ERT, BOEM company number 02899

, has demonstrated oil spill financial responsibility for the facilities proposed in this DOCD according to 30 CFR Part 253; and NTL No. 2008

- N0 5

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

( H

) DEEPWATER WELL CONTROL STATEMENT ERT (BOEM company number 02899) has the financial capability to drill a relief well and conduct other emergency well control operations.

( I) SUSPENSION OF PRODUCTION Green Canyon Block 237 is currently held by ongoing production.

( J

) B LOWOUT SCENARIO The Blowout Scenario was for the WCD well in Green Canyon Block 237 was submitted and found acceptable under the Revised DOCD (R

- 5300) providing for Well No. 005 and was approved under the R

- OSRP as the > 10 mile WCD well. Well No. 005 was drilled and completed and is currently on production. The Blowout Scenario below is from the Revised DOCD (R

- 5300).

The blowout scenario assumes the rig has sunk and is displaced from the wellhead. The well is flowing uncontrolled at the mud line.

A 11

- 7/8" liner has been set at ~15,600' TVD. Open hole is present from 15,600'

– 18,200 TVD (2,600’ of open hole). No drill pipe is in the wellbore.

Worst Case Discharge

The uncontrolled flow rate is 212,891 BOPD and 239 MMS CFD . Seismic and offset well interpret ation indicates the target reservoir is the only producible reservoir in the open hole section. No water sands or other hydrocarbon bearing sands are anticipated in the hole section.

Duration of Uncontrolled Flow

– Base Case

The duration of uncontrolled flow during the blow out scenario is 4 days with a total discharge volume of 851,564 bbls of oil.

Energy Resource Technology GOM, Inc. Page B

- 2 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )The duration assumes the BOP’s can be closed with an ROV at the subsea ROV intervention panel on the BOP stack . This assumes th e initial site assessment indicates an ROV vessel can operate close enough to the well to remotely close the BOP.

Surface Intervention In the Event of a Blowout

Energy Resource Technology GOM, Inc. will immediately initiate and mobilize the Helix Well

Co ntainment Group’s vessels and equipment to be utilized to shut

- in and contain the well. Equipment to be mobilized includes vessels to remotely close the blind shear rams, vessels to begin subsea dispersant operations, and vessels to initiate debris remov al / salvage operations. The Helix Q

- 4000 will also be immediately mobilized to assist in the response.

In the event the blind shear ram cannot be remotely closed with the ROV, the LMRP will be removed from the BOP, and the HWCG 13

- 5/8” 10K capping stack will be deployed by the Q

4000 or other suitable vessel and installed on the BOP. The blind rams in the capping stack

would then be closed to contain the well.

A top kill operation would then be initiated to kill and control the well. The proposed well design will be able to withstand the anticipated shut in pressure at the BOP, as well as additional pressure exerted on the casing during the top kill operation. The estimated shut in pressure of the well at the BOP is 9,100 psi, and the burst rating of t he 13

- 5/8” casing is 10,030 psi. In addition, ERT would employ the expertise of Wild Well Control, Inc., to assist with any early intervention options.

The estimated duration for surface intervention that would require the deployment of the capping

stack is 15 days. The contingency case assumes the H WCG vessels and equipment w ill be

utilized to shut

- in and contain the well. Energy Resource Technology GOM, Inc. is a member of the Clean Gulf Associates / Helix Well Containment Group and is guaranteed this eq uipment in

the event of a blow out.

Potential of Open Hole to Bridge Over

Due to the slight geopressured nature of the reservoir (14.0 ppg), the age of the reservoir (Pliocene), and the depth below the mud line where the reservoir exists (+/

- 15,400’ TVD) , it is highly likely that the sandstone is somewhat unconsolidated and friable. Because the blow out scenario creates ~8,500 psi of drawdown at the reservoir face, considerable sand production is anticipated. In addition, the shale sequences in the open h ole will likely experience tensile failure at 8,500 psi drawdown. It is reasonable to assume that the sandstones and shale intervals in the open hole will experience tensile failure and will collapse. It is safe to assume that the sand and shale sequences will experience tensile failure if 8,500 psi drawdown is achieved.

Availability of Rig to Begin Drilling Relief Well

In the event a relief well is required, a deepwater rig currently located in the GOM would be contracted to drill the relief well. Energy Resource Technology GOM, In. has worked with the major drilling contractors that provide MODU’s. The rig required to drill a relief well will

Energy Resource Technology GOM, Inc. Page B

- 3 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )either a dynamically positioned semi

- submersible or drillship. As of September 2011, there are 27 rigs in the GOM capable of drilling the relief well.

Relief Well Rig Package Constraints

Of the 27 rigs in the GOM capable of drilling the relief well, none of the rigs have constraints that would prevent the successful drilling of a relief well. All of the rigs have >10,000 psi BOP’s and suitable hook load requirements.

Estimated Time to Drill a Relief Well

The estimated time to drill a relief well is summarized in the below table:

Description Planned Days Cumulative Days

Site Assessment 3 3 Contract/Mobilize Rig to Location 14 17

Jet 36” 2.5 19.5 Drill and set 20” casing 3 22.5

Run BOP 3.5 26 Drill and set 16” casing 5.5 31.5

Drill and set 13

- 5/8” casing 10 41.5

Drill and set 11

- 7/8” liner 9.5 51

Drill and set 9

- 5/8” liner 11.5 62.5 Intercept well 8 70.5

Drilling a Relief Well from a Nearby Platform

No platforms are close enough to the proposed exploration well to drill a relief well.

Measures to Prevent or Reduce the Likelihood of a Blowout Energy Resource Technology GOM, Inc. employs the following measures to enhance our ability to prevent and reduce the likelihood of a blowout.

Management and Direct Supervision

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

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 Lessees.

• The working pressure and temperature rating of the BOPE and wellhead equipment will exceed the maximum anticipated pressure and temperature.

Energy Resource Technology GOM, Inc. Page B

- 4 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )• Accumulator controls will always be left in the power position. (i.e. open/closed; not neutral)

• Rams m ust be installed to fit all sizes of drill pipe and tubing in use.

• A pressure tested full opening safety valve (FOSV) and opening/closing wrench with appropriate threads or crossover 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 completion 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 employed for all hole sections with returns to

surface.

Drilling Practices

• Volume measurements relative to the well will be monitored at all times.

• All critical pressure test charts (i.e. casing test, LOT, FIT) will be reviewed by Drilling Engineer/Drilling Supervisor prior to continuing with operations.

• During drilling operation s, slow circulating rates (SCR) should be obtained and recorded for each pump at least after BHA or mud weight changes and 500’ 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 time when anomalous pit volume readings are reserved. Minimum flow check duration shall be 5

minutes.

• Drilling BOP space

- out and tool joint space

- out diagrams shall be posted on the rig floor

at a ll times.

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

Measures to Conduct Effective and Early Intervention in the Event of a Blowout Energy Resource Technology GOM, Inc. employs the following measures to conduct effective

and early intervention in the event of a blowout:

• ERT’s Regional Oil Spill Response Plan will be activated.

• A blowout specialty company will be deployed to conduct an immediate site assessment. The team will analyze the blowout situation and devise an interve ntion strategy.

• Site assessment will be used to assist in determining relief well locations so that planning

can be initiated.

• A suitable rig for a relief well will be sourced and preparations made for the suspension

of current activities in order to mobil ize to relief well site.

Additional Prevention and Mitigation Techniques Energy Resource Technology GOM, Inc. employs the following additional measures to prevent a

blowout:

Energy Resource Technology GOM, Inc. Page B

- 5 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )• Pursuant to wellbore cementing and zonal isolation techniques, all cementing opera tions will be modeled and designed under guidelines set forth in API RP 65 Part I & II.

• RP 53 for Blowout Prevention Equipment Systems for Drilling Wells and RP 16Q for Marine Drilling Risers will be used for installation, testing, and maintenance of the

s urface and subsea marine risers and BOP systems.

Energy Resource Technology GOM, Inc. Page B

- 6 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )

### APPENDIX C

G EOLOGICAL AND GEOPHYSICAL INFORMATION

(A) GE OLOGICAL D ESCRIPTION Proprietary Information

(B ) S TRUCTURE CONTOUR MAP S

C urrent structure contour maps drawn on the top of each pr ospective hydrocarbon sand, showing

the entire lease block

, the location of the proposed well s, and the locations of geological cross

sections are included in Attachment C.

(C ) I NTERPRETED S EISMIC LINE S Interpreted seismic lines are included in Attachment C. These lines are migrated, annotated with depth scale, and are within 500’ of the surface location of the proposed well.

(D ) G EOLOGICAL STRUCTURE CROSS

- SECTIONS

I nterpreted geological structure cross

- sections showing the location and depth of the proposed well and at least one key horizon and the objective sand s labeled using standard biostratigrahic

terms are included in Attachment C.

(E ) SHALLOW HAZARDS REPORT ERT contracted C & C Technologies, Inc. conduct a shallow hazards survey across a portion of Green Canyon Block 237. The report was previously submitted (Control No. N-9771).

(F) SHALLOW HAZARDS ASSESSMENT Utilizing the 3D seismic exploration data, C & C Technologies prepared a well site clearance

letter for the proposed surface location, and is included in Attachment C

.

(G ) HIGH

- RESOLUTION SEISMIC LINES

Included in Attachment C is 3- D survey data including swath bathymetry/seafloor rendering/edge detection (fault scarp trends) overl ain with the seafloor amplitude.

Energy Resource Technology GOM, Inc. Page C-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)(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.

Energy Resource Technology GOM, Inc. Page C-2 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)

### APPENDIX D

HYDROGEN SULFIDE INFORMATION

(A) C ONCENTRATION

ERT does not anticipate encountering any H 2 S during the proposed operations.

(B) C LASSIFICATION In accordance with Title 30 CFR 250.490(c)

, ERT hereby requests that Green Canyon Block 237 be classified by the BOEM as H 2 S absent

.

T he basis for this determination is the evaluation of the drilling and production o f t he Green Canyon Block 237 Well No. 001 ST01 which w as drilled to the stratigraphic equivalent of the B

2 sand as proposed in this DOCD.

. (C) H2S C ONTINGENCY PLAN Not Applicable.

(D ) M ODE LING REPORT Not Applicable.

Energy Resource Technology GOM, Inc. Page D-1 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 ( OCS -G 15563)

### APPENDIX E

MINERAL RESOURCE CONSERVATION INFORMATION

( A ) T E CHNOLOGY

& RES ERVOIR ENGINEERI NG PRACTIC

ES AND PROCEDURES

Pro prietary Information

( B ) T E CHNOLOGY AND RECOVERY P RACTICES A ND PROCE DURE S

Pro prietary Information

( C ) RESERVOIR DEVELOPMENT

Pro prietary Information

Energy Resource Technology GOM, Inc. Page E-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)AP PENDIX F

BIOLOGICAL

, PHYSICAL AND SOCIOECONOMIC INFORMATION

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

"D eepwater Benthic Communities", is provided below. ERT will avoid all high

- density deepwater benthic communities by 2000 feet from each proposed mud and cuttings discharge

location and 250 feet from the location of all other seafloor disturbances.

E RT wou ld like to retain the option of moving the proposed location less than 500 feet without having to submit a revised plan. Accordingly, based on the complete report prepared by C&C Technologies (including the Seafloor Amplitude and Seafloor Features Maps), “No high negative or high positive amplitude seafloor anomalies associated with fluid expulsion or mounded carbonates representing potential chemosynthetic or coral communities were noted within 2000 feet surrounding the proposed site”(p.2). In terms of shallow gas potential, “No high amplitude subsurface amplitude anomalies are noted at the location of the proposed wellbore (p.3).

M APS

Attached to this DOCD are maps prepared using 3

- D seismic data depicting seafloor and shallow geological features and ar eas, and the surface locations of the proposed wells with a radius circle

of 2000 feet around the well.

ANAL YSIS Using 3

- D seismic information, all seafloor features and areas that could be disturbed by the activities proposed in this plan have been identified. The likelihood of these proposed activities disturbing these seafloor and shallow geologic features is discussed in the following summary:

F eatures or areas that could support high

- density deepwater benthic communities are not located

within 2000 feet of any proposed muds and cuttings discharge location.

(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 BOTTOMS (PINNACLE TREND) MAP Green Canyon Block 237 is not located within 61 meters (200 feet) of any pinnacle trend feature; therefore a separate bathymetric map is not required.

Energy Resource Technology GOM, Inc. Page F-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)(E) LIVE BOTTOMS (LOW RELIEF) STIPULATION Green Canyon Block 237 is 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 Green Canyon Block 237 is 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, ERT will not be conducting any ROV surveys either pre

- spud or post

- drill operations per NTL No. 2008 -G06, “Remotely Operated Vehicle Surveys in Deepwater,” (Extended by NTL No. 2014 -N01, “Elimination of Expiration Dates on Certain Notices to Lessees and Opera tors Pending Review and Reissuance”).

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

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

Species Scientific Name Status Potential Presence Critical Habitat Designated in the

Gulf of Mexico Lease

Area Coastal

Sea Turtles Loggerhead Carettsa caretta T X X None

Green Chelonia mydas T,E X X None

Leatherback Dermochelys

corlacea E X X None

Hawksbill Eretmochelys

imbricata E X X None

Kemp’s Ridley Lepidochelys kempli E X X None

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

.

Energy Resource Technology GOM, Inc. Page F-2 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)Species Scientific Name Status Potential Presence Critical

Habitat Designated in

the Gulf of

Mexico Lease

Area Coastal

Marine Mammals Sperm Whale Physeter macrocephalus E X

-- None

West Indian

Manatee Trichechus manatus

latirostris E

-- X Florida

Blue Whale Balaenoptera

masculus E X

-- None

Fin Whale Balaenoptera physalus E X

-- None Humpback Whale Megaptera novaeangliae E X

-- None

North Atlantic Right Whale Eubalaena glacialis E X

-- None

Sei Whale Balaenopiera borealis E X

-- None

T here is one (1) species of fish that NOAA fisheries currently list as threatened (T) that may be found in the Gulf of Mexico. The Gulf sturgeon, also known as the Gulf of Mexico sturgeon, is an anadromous (breeding in freshwater after migrating up river s from marine and estuarine environments) fish overwintering in estuaries, bays, and the Gulf of Mexico (see table below).

Species Scientific Name Status Potential Presence Critical

Habitat Designated in

the Gulf of

Mexico Lease

Area Coastal

Fish Gulf Sturgeon Acipenser oxyrinchus (=oxyrhynchus)

desotoi T X X None

(I

) A RCHAEOLOGICAL REPORT Green Canyon Block 237 is not located in an area determined to have any historic or prehistoric

cultural resources.

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

- G04, “Information requirements for Exploration Plans and Development Operations Coordination Documents” (Extended by NTL No. BOEM 2014

- G05, “Extension of Prior

N otices to Lessees”).

Energy Resource Technology GOM, Inc. Page F-3 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)( K) SOCIOECONOMIC INFORMATION Socioeconomic Information is not required to be included in this plan per NTL No. 2008 -G04, “Information Requirements for Exploration Plans and Development Operations Coordination Documents” (Extended by NTL No. BOEM 2014

- G05, “Extension of Prior Notices to Lessees.”)

.

Energy Resource Technology GOM, Inc. Page F-4 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)

### APPENDIX G

WASTES AND DISCHARGES INFORMATION

( A) PROJECTED GENERATED WASTES

. please specify if the amount reported is a total or per well amount

Projected generated waste Projected ocean discharges

Type of Waste Composition Projected

Amount (BBLS/Well) Discharge

Rate (BBLS/Day) Discharge Method Answer yes or

no Will drilling occur ? If yes, you should list muds and cuttings Water-based drilling fluid Water -based drilling fluids 10,000 5,000 Seafloor before installation of marine riser No

Cuttings wetted with water-based fluid Cuttings generated while using water-based drilling

fluids 2,000 1,000 Seafloor before installation of marine riser No

Cuttings wetted with synthetic-based fluid Synthetic based drilling fluids adhering to drill cuttings from synthetic-based hole intervals 3,600 250 Treated cuttings will be discharged overboard while drilling SBM interval. Cuttings will pass through cuttings dryer to reduce ROC percentage in compliance with EPA and will then be shunt through downpipe below water line No

Will humans be there? If yes, expect conventional waste

Domestic waste Gray water from galleys, sinks, showers, and laundry 3,360 48 USCG approved MSD with chlorination and discharged No

Sanitary waste Human body treated waste discharged from toilets 2,240 32 USCG approved MSD with chlorination and discharged No

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

Deck Drainage Rain water and rig wash 8,750 125 Deck drainage is gravity separated, tested and discharged overboard No

Will you conduct well treatment, completion, or workover?

Well treatment fluids Frac fluid (gel) 100 100 Discharged overboard through shunt line
Well completion fluids Calcium Bromide 100 15 Discharged overboard through shunt line

Workover fluids N/A
Miscellaneous discharges. If yes, only fill in those associated with your activity. Desalinization unit discharge N/A
Blowout prevent fluid Transaqua DW 28 0.55 Discharged from vent ports on BOP stack No

Ballast water Uncontaminated seawater 20,000 400 Per MARPOL regulations No Bilge water N/A

Excess cement at seafloor N/A

Fire water N/A Cooling water N/A

Excess food Misc. food 75 1.5 Discharged overboard No
Will you produce hydrocarbons? If yes fill in for produced water.

Produced water 450,000 500 Processed through production train then discharged in sump pile No Will you be covered by an individual or general NPDES permit ? General NOTE: If you will not have a type of waste, enter NA in the row. TABLE 1. WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE GOM (GC 237 Loc "J")

Projected

Downhole Disposal

Energy Resource Technology GOM, Inc. Page G-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)

### APPENDIX H

AI R EMISSIONS INFORMATION

(A ) E MISSIONS WORKSHEETS AND SCREENING QUESTIONS

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

Do your emission calculations include any emission reduction measures or modified

emission factors? X

Are your proposed exploration activities located east of 87.5° W longitude? X Do you expect to encounter H 2 S at concentrations greater than 20 parts per million (ppm)? X Do you propose to flare or vent natural gas for more than 48 continuous hours from any proposed well? X

Do you propose to burn produced hydrocarbon liquids? X

T here are no existing facilities or activities co

- located with the currently proposed activities, therefore the Complex Total Emissions are the same as the Plan Emissions and are provided in

the table below.

Air Pollutant Plan

Emission

Amounts 1
(tons) Calculated Exemption

Amounts 2
(tons) Calculated Complex Total

Emission

Amounts 3
(tons) Carbon Monoxide (CO) 1125.11 3030.30 1125.11 Particular matter (PM) 63.74 3030.30 63.74 Sulphur dioxide (SO 2 ) 292.48 3030.30 292.48 Nitrogen oxides (NO

x ) 2943.13 3030.30 2943.13 Volatile organic compounds (VOC) 76.26 68787.02 76.26

1 For activities proposed in your EP, list the projected emissions calculated from the worksheets.

2 List the exemption amounts for your proposed activities calculated by using the formulas in 30 CFR 250.303(d).

3 List the complex total emissions associated with your proposed activities calculated from the worksheets.

This information was calculated by: Cathy Thornton (713 ) 705-8020 cathy.thornton @jccteam.com

Energy Resource Technology GOM, Inc. Page H-1 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 ( OCS -G 15563)

### APPENDIX I
OIL SPILL S INFORMATION

A ll the proposed activities and facilities in th is Plan will be covered by ERT’s (GOM No. 02899) Oil Spill Response Plan (OSRP) revision submitted January 18, 2011 and approved February 16, 2012 and the latest revision submitted in April, 2012 and last approved modification to that Plan dated July 26, 2013. The last Biennial Oil Spill Response Plan was submitted on April 29, 2014.

OSRP Control No. O-647.

(B ) SPILL RES PONSE SITES

Primary Response Equipment Location Preplanned Staging Location

Houma, LA Harvey, LA

Leeville , LA Houma, LA Harvey, LA

Leeville , LA Fourchon, LA

(C ) OSRO I NFORMATION ERT’s primary equipment provider is Clean Gulf Associates (CGA). Clean Gulf Associates Services, LLC (CGAS) will provide closest available personnel, as well as a CGAS supervisor to operate the equipment.

(D) W ORST

- CASE SCENARIO COMPARISON

Category Drilling Production

Regional

OSRP
WCD DOCD
WCD Regional
OSRP
WCD DOCD
WCD

Type of Activity > mile Drilling > mile Drilling >10 mile
Production >10 mile
Production
Facility Location (Area/Block) GC237 GC23 7 GC 282 GC237

Facility Designation SSWell No. 005 SSWell No. 005 * SS Well No. 1 (ST03BP01) Well K

Distance to Nearest Shoreline (miles) 91 91 91 91

Volume

S torage tanks & flowlines Lease term pipelines
Uncontrolled blowout Total Volume (bbls) 212,891 212,891 212,891 212,891 43,280 43,280 2 25 12, 450

1 2 ,6 7 5 Type of Oil(s) (crude , condensate, diesel) Crude Crude Crude Crude

API Gravity 33° 33° 32° 30°

Energy Resource Technology GOM, Inc. Page I-1 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS-G 15563)* T he Calculations and Assumptions were submitted and found acceptable under the Revised DOCD (R

- 5300) and was approved under the R

- OSRP as the > 10 mile WCD well.

ERT has determined that the worst

- case scenario from the activities proposed in this DOCD does

not supersede the worst

- case scenario from our approved regional OSRP (for far

- shore drilling activities).

Since ERT has the capability to respond to the appro priate worst

- case spill scenario included in its regional OSRP approved on July 26, 2013, and since the worst

- case scenario determined for our DOCD does not replace the appropriate 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) SPILL RESPONSE DISCUSSION For the purpose of NEPA and Coastal Zone Management Act analysis, the largest spill volume originating from the proposed activity would be a well blowout during drilling operations,

estimated to be 212,891 barrels of crude oil with an API gravity of 33 °.

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

Western Gulf of Mexico avail able on the BOEM website

. The results are shown in Figure 1. The

BOEM OSRAM identifies a 7 % probability of impact to the shorelines of Cameron Parish,

Louisiana within 30 days. Cameron Parish includes the east side of Sabine Lake, Sabine National

Wildlife Refuge, Calcasieu Lake, Lacassine National Wildlife Refuge (inland) and Grand Lake. Cameron Parish also includes the area along the coastline from Sabine Pass to Big Constance Lake in Rockefeller Wildlife Refuge. This region is composed of open public be aches, marshlands and swamps. It serves as a habitat for numerous birds, finfish and other animals, including several rare, threatened and endangered species

.

Response

ERT will make every effort to respond to the Worst Case Discharge as effectively as pr acticable. A description of the response equipment under contract to contain and recover the Worst Case Discharge is shown in Figure 2.

Using the estimated chemical and physical characteristics of crude oil , an ADIOS weathering model was run on a similar product from the ADIOS oil database. The results indicate 18 % or approximately 20,280 barrels of crude oil would be evaporated/dispersed within 24 hours, with approximately 174,571 barrels remaining.

Energy Resource Technology GOM, Inc. Page I

- 2 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)Spil l Response GC 237, SS Well No. 005 Barrels of Oil

WCD Volume 212,891

Less 18 % natural evaporation/dispersion 38,320
Remaining volume 174,571
Daily dispersant capability 7,540
Oil addressed by in

- situ burning 8,728

Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary storage equipment available to respond to a spill of 174,571 barrels. The volume accounts for the amount remaining after evaporation/dispersion at 24 hours

. The list estimat es individual times needed for procurement, load out, travel 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

- si tu burn. Strategies will be decided by Unified Command based on size of the spill, weather and potential impacts. If aerial dispersants are utilized, 8 sorties (9,600 gallons) from

two of the DC

- 3 aircrafts and 4 sorties (8,000 gallons) from the Basler ai rcraft would provide a daily dispersant capability of 7,540 barrels . If the conditions are favorable for in

- situ burning, the proper approvals have been obtained and the proper planning is in place, in

- situ burning of oil may be attempted. Using estimates based on the Deepwater Horizon spill of 2010, up to 5% or approximately 6,786 barrels of the total daily Worst Case Discharge volume could be burned. Slick containment boom would be immediately called out and on

- scene as soon as possible. Offshore response strategies may include attempting to skim utilizing the HOSS barge, nine Fast Response Units, eleven sets of Koseq skimming arms, and two Aqua Guard Triton RBS

skimmers , with a total derated skimming capacity of 318,609 barrels. Temporary storage

associat ed with skimming equipment equals 31,700 barrels. If additional storage is needed, a 47,000 barrel storage barge

, a 25,000 barrel storage barge , three 23,000 barrel storage barge s, an 80,000 barrel storage barge, and a n 83,937 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 first priority. Air monitoring will be accomplished and operations deemed safe prior to any containment/sk imming attempts.

If the spill went unabated, shoreline impact in Cameron Parish, Louisiana would depend upon existing environmental conditions. Shoreline protection would include the use of CGA’s near

shore and shallow water skimmers with a totaled dera ted skimming capacity of 54,753 barrels. Temporary storage associated with skimming equipment equals 1,761 b arrels. If additional storage is needed, three 20,000 barrel storage barge s may be mobilized and centrally located to provide temporary storage allo wing the skimmers to stay in the area of operations as much as possible. Onshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. A Letter of Intent from Oil Mop will ensure

access to 30,000 feet of 18” shoreline protection boom. Figure 2 outlines individual times needed for procurement, load out, travel time to the site and deployment. Strategies would be based upon surveillance and real time trajectories that depict areas of potentia l impact given actual sea and weather conditions. The State of Louisiana Initial Oil Spill Response Plan for

Energy Resource Technology GOM, Inc. Page I

- 3 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)Cameron Parish and Unified Command would be consulted to ensure that environmental and special economic resources would be correctly identified and prioritized to ensure optimal protection. Shoreline protection strategies depict the protection response modes applicable for oil spill clean

- up operations. The State of Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection stra tegies for this area, and it describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands, based on the assumption that removal of the released oil will be much easier and less damaging to fragile coastal ecosystems if done i n the open waters of the Gulf of Mexico. Supervisory personnel have the option to modify the deployment

and operation of equipment allowing a more effective response to site

- specific circumstances.

ERT’s contract Spill Management Team holds a copy of the S tate of Louisiana Initial Oil Spill Response Plan.

B ased on the anticipated worst case discharge scenario, ERT can be onsite with contracted oil spill recovery equipment with adequate response capacity to contain and recover surface hydrocarbons, and prev ent land impact, to the maximum extent practicable , within an estimated

41 hours (based on the equipment’s Effective Daily Recovery Capacity (EDRC)). ERT will

continue to commit additional on

- water mechanical recovery resources as well as apply dispersants and in

- situ burning needed and as approved, under the supervision of the USCG Captain of the Port (COTP) and the Regional Response Team (RRT).

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

be limited to:

• Weather

• Equipment and materials availability

• Ocean currents and tides

• Location of the spill

• Product spilled

• Amount s pilled

• Environmental risk assessments

• Trajectory and product analysis

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

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

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

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

• Information will be confirmed

• An assessment will be made and initial objectives set

• OSROs and appropriate agencies will be notified

• ICS 201, Initial Report Form completed

Energy Resource Technology GOM, Inc. Page I-4 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS-G 15563)• Initial Safety plan will be written and published

• Unified Command will be established

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

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

site

o On

- site command and control established

Offshore Response Actions

Equipment Deployment

Surveillance

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

• Provide trained observ er to provide on site status reports

• Provide command and control platform at the site if needed

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

and visual confirmation

• Continual monitoring of vessel assets using vessel monitoring systems

Dispersant application assets

• Put ASI on standby

• With the FOSC, conduct analysis to determine appropriateness of dispersant application

• Gain FOSC approval for use of dispersants on the surface

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

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

• Confirm dispersant availability for current and long range operations

• Start ordering dispersant stocks required for expected operations

Containment boom

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

• Ensure boom handling and mooring equipment is deployed with boom

• Provide continuing 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 hig hest concentration of oil

• Assets deployed at safe distance from aerial dispersant and in

- situ burn operations

CGA HOSS Barge

• Use in areas with heaviest oil concentrations

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

Energy Resource Technology GOM, Inc. Page I

- 5 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)C GA FRUs

• To the area of the thickest oil

• Use as far off

- shore as allowed

T&T Koseq Skimming Systems

• To the area of the thickest oil

• Use as far off

- shore as allowed

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

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 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

In

- situ Burn assets

• Determine appropriateness of in

- situ burn operation in coordination wi th the FOSC and

affected SOSC

• Determine availability of fire boom and selected ignition systems

• Start ordering fire boom stocks required for expected operations

• Contact boom manufacturer to provide training if required

• Determine assets to perform on water operation

• Build operations into safety plan

• Conduct operations in accordance with an approved plan

Near Shore Response Actions

Timing

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

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

• Outfitting of VOOs for specific missions

• Deployment of assets based on actual movement of oil

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- 6 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)Considerations

• Water depth, vessel draft

• Shorelin e 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

an d visual confirmation

• Continual monitoring 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 Deploymen t Dedicated Near Shore skimming systems

• FRVs

• Egmopol and Marco SWS

• Operate with aerial spotter directing systems to observed oil slicks

VOO

• Use ERT ’s contracted resources as applicable

• Industry vessels 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

• Operate 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 avai lability

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- 7 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)• 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 boom 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 movement

o Boom, manpower and vessel (shallow draft) availability

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

Beach Preparation

Considerations and Actions

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

• Shoreli ne Cleanup and Assessment Team Reports and recommendations

• Determination of Archeological sites and gaining authority to enter

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

• Pre cleaning of beaches by moving waste above high time lines to minimize waste

• Staging of equipment and housing of response personnel as close to the job site as possible to maximize on

- site work time

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

• Constant awareness o f weather and oil movement for resource redeployment as necessary

• In

- situ burn may be considered when marshes have been impacted

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

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

inland areas

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 wa ter 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 op erations. This practice is routinely used for oil spill

recovery.

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- 8 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)CGA Equipment Limitations The capability for any spill response equipment, whether a dedicated or portable system, to operate in differing weather conditions will be directly in relation to the capabilities of the vessel the system in placed on. Most importantly, however, the decision to operate will be based on the judgment of the Unified Command and/or the Captain of the vessel, who will ultimately have the final say in terminating operat ions. Skimming equipment listed below may have operational limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil spill response, vessel skimming operations ceased when seas reached 5

- 6 feet and vessels were

often recal led to port when those conditions were exceeded. Systems below are some of the
most up

- to

- date systems available and were employed during the DWH spill.

Energy Resource Technology GOM, Inc. Page I

- 9 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)Boom 3 foot seas, 20 knot winds Dispersants Winds more than 25 knots Visibility less than 3 nautical miles Ceiling less than 1,000 feet.

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

OSRV 4 foot seas

Environmental Conditions in the GOM

Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences westerly winds during the winter and easterly winds in the summer. Average wind speed is generally 14

- 15 mph along the coast. Wave heights average 4 and 5 feet. However, during hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, flooding is prominent.

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

The Atlantic and Gulf of Mexico hurricane season is officially from 1 June to 30 November. 97% of all tropical activity occurs within this window. The Atlantic basin shows a very peaked season from August through October, with 78% of the tropical storm days, 87% of the minor (Saffir

- Simpson Scale categories 1 and 2) hurricane days, and 96% of the major (Saffir

- Simpson categories 3, 4 and 5) hurrican e 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 n month.

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- 10 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)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 BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BOEM website using 30 day impact. The results are tabulated below.

Area/Block OCS

- G Launch

Area Land Segment and/or

Resourc e Conditional Probability (%)

within 30 days

Green Canyon 237,

SS Well No. 005

91 miles from shore G15563 C43 Matagorda County, TX Brazoria County, TX Galveston County, TX Jefferson County, TX Cameron Parish, LA Vermilion Parish, LA

Iberia Parish, LA Terrebonne Parish, LA Lafourche Parish, LA Plaquemines Parish, LA 2

1

3

2

7

3

1

3

1

2

Energy Resource Technology GOM, Inc. Page I

- 11 Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS

- G 15563)WCD Scenario

– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (91 miles from shore) 174,571 bbls of crude oil (volume considering natural weathering) API Gravity 33 ° FIGURE 2

– Equipment Response Time to GC 237, SS Well No. 005 Dispersants/Surveillance

Dispersant/Surveillance Dispersant Capacity (gal) Storage Capacity Persons Req. From Hrs to Procure Hrs to

Loadout Travel to

site Total Hrs

CGA

Basler 67T 2000 NA 2 Houma 1 1 0.7 2.7

ASI

DC 3 1200 NA 2 Houma 1 1 0.9 2.9

DC 3 1200 NA 2 Houma 1 1 0.9 2.9

Aero Commander NA NA 2 Houma 1 1 0.7 2.7

Offshore Response

Offshore Equipment No Staging EDRC Storage Capacity VOO Persons Required From Hrs to

Procure Hrs to

Loadout Hrs to
GOM Travel to Spill Site Hrs to Deploy Total

Hrs

CGA

HOSS Barge 43000 4000 3 Tugs 8 H arvey 7 0 5 11.3 1 24.3
T&T Marine Services LLC (available through contract with CGA)

Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 4 12 2 9.2 2 29.2
Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 4 12 2 10.8 2 30.8
Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 4 12 2 9.2 2 29.2
Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 4 12 2 20.8 2 40.8

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

Procure Hrs to

Loadout Hrs to

GOM Travel to Spill Site Hrs to Deploy Total

Hrs
Enterprise Marine Services LLC (available through contract with CGA)

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

K

- Sea Operating (available through contract with CGA)

PACIFIC 996165 NA 80000 1 Tug 6 Houma 4 12 4 11.25 1 32.25

DBL 76 1212984 NA 83937 1 Tug 6 Houma 4 12 4 11.25 1 32.25

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- 13 Initial/Supplemental DOCD January 22, 2015 Green Canyon Blocks 236/237 (OCS

- G 34971/15563)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

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Belle Chasse 1 2 2.5 9.2 1 15.7

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Galveston 1 2 7 9.2 1 20.2

FRU (3) + 100 bbl Tank (5) 11310 500 1 Utility 6 Houma 1 2 1 9.2 1 14.2

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Ingleside 1 2 9.5 9.2 1 22.7

FRU (1) + 100 bbl Tank (2) 3770 200 1 Utility 6 Lake Charles 1 2 4 9.2 1 17.2

FRU (2) + 100 bbl Tank (4) 7540 400 1 Utility 6 Venice 1 2 4 9.2 1 17.2

T&T Marine Services LLC (available through contract with CGA)

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 7 9.2 2 34.2

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

C GA

42” Auto Boom (5000’) NA NA 10 Crew 20 Belle Chasse 1 2 2.5 9.2 1 15.7

42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 7 9.2 1 20.2

42” Auto Boom (5000’) NA NA 10 Crew 20 Houma 1 2 1 9.2 1 14.2

42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 9.5 9.2 1 22.7

42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 4 9.2 1 17.2

42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 9.2 1 17.2

1000’ Hydro

- Fire Boom NA NA 8 Utility 20 Harvey 1 4 2.5 9.2 6 22.7

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- 14 Initial/Supplemental DOCD January 22, 2015 Green Canyon Blocks 236/237 (OCS

- G 34971/15563)Nearshore Response

Nearshore Equipment No Staging EDRC Storage Capacity VOO Persons Required From Hrs to

Procure Hrs to

Loadout Hrs to
GOM Travel to Spill Site Hrs to Deploy Total

Hrs

CGA

46’ FRV 5000 65 NA 4 Galveston 1 0 0 3.2 0 4.2

46’ F RV 5000 65 NA 4 Houma 1 0 2 6 0 9

46’ FRV 5000 65 NA 4 Lake Charles 1 0 1 2 0 4

46’ F RV 5000 65 NA 4 Venice 1 0 1 9 0 11

Trinity SWS 21500 249 NA 4 Morgan City 1 2 2 4.4 1 10.4

Enter prise Marine Services LLC (available through contract with CGA)

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 13.75 1 34.75

Stagi ng Area: Cameron

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

Procure Hrs to

Load
Out Travel to Staging Travel to Deployment
Site Hrs to Deploy Total

Hrs

CGA

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

SWS Egmopol 3000 100 NA 3 Houma 1 2 4 2 0 9

SWS Marco 3588 34 NA 3 Houma 1 2 4 2 0 9

SWS Marco 3588 20 NA 3 Lake Charles 1 2 1 2 0 6

Rope Mop 77 2 0 3 Belle Chasse 1 2 4.5 2 0 9.5

RO Storage Barge NA 249 Towed 0 Galveston 1 2 3.5 2 0 8.5

RO Storage Barge NA 249 Towed 0 Houma 1 2 4 2 0 9

RO Storage Barge NA 249 Towed 0 Lake Charles 1 2 1 2 0 6

RO Storage Barge NA 249 Towed 0 Venice 1 2 6.5 2 0 11.5

Energy Resource Technology GOM, Inc. Page I

- 15 Initial/Supplemental DOCD January 22, 2015 Green Canyon Blocks 236/237 (OCS

- G 34971/15563)Staging Area: Cameron Shoreline Protection

Shoreline

Protection Boom VOO Persons Req. Storage/Warehouse

Location Hrs to

Procure Hrs to

Loadout Travel to Staging Travel to Deployment Site Hrs to Deploy Total Hrs

Oil Mop (available through Letter of Intent)

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 1 2 3 8

10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 4 2 3 11

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

Beach Boom EDRC Storage Capacity VOO Persons Req. From Hrs to

Procure Hrs to

Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total

Hrs

CGA

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

Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 6 1 2 12

Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 5.5 1 2 11.5

Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to

Procure Hrs to

Loadout Travel to Staging Travel to Deployment Hrs to Deploy Total

Hrs

CGA

Wildlife Support Trailer NA NA NA 2 Houma 1 2 4 1 2 10

Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 4.5 1 2 10.5

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

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

Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 6 1 2 12

Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 1 1 2 7

Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 5.5 1 2 11.5

Response Asset Total

Offshore EDRC 318,609

Offshore Recovered Oil Storage 336,637

Nearshore / Shallow Water EDRC 54,753

Nearshore / Shallow Water Recovered Oil Storage 61,761

Energy Resource Technology GOM, Inc. Page I

- 16 Initial/Supplemental DOCD January 22, 2015 Green Canyon Blocks 236/237 (OCS

- G 34971/15563)

### APPENDIX J

ENVIRONMENTAL MONITORING INFORMATION

( A ) M ONITORING 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.

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

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

• NTL No. 2012

- JOINT

- G01, “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”

• NTL No. 2012

- JOINT

- G02, “Implementation of Seismic Survey Mitigation Measur es and Protected Species Observer Program”

( C ) F LOWER GARDEN BANKS NATIONAL MARINE SANCTUARY Green Canyon Block 237 is not located in the Flower Garden Banks National Marine Sanctuary; therefore, the requested information is not required in this Plan

.

Energy Resource Technology GOM, Inc. Page J

- 1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )

### APPENDIX K
LEASE STIPULATIONS INFORMATION

Developm ent activities are subject to the following stipulation (s) attached to Lease OCS

- G 15563, Green Canyon Block 237.

. Marine Protected Species

L ease Stipulation No. 8 is meant to reduce the potential taking of marine protected species. In accordance with the Federal Endangered Species Act and the Marine Mammal Protection Act,

ERT will:

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

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

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

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

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

less

- intrusive cleanup techniques on beaches and bay shores; and

(f

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

of the strike.

B OEM and BSEE issue Notices to Lessees (NTLs), which more fully describe measures implemented in support of the above

- mentioned implementing statutes and regulations, as well as measures identified by the U.S. Fish and Wildlife Service and NMFS arising from, among others, conservation recommendations, rulemakings pursuant to the MMPA, or consultation. The

les see and its operators, personnel, and subcontractors, while undertaking activities authorized under this lease, must implement and comply with the specific mitigation measures outlined in

NTL No. 2012

- JOINT

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

- JOINT

- G02, “Implementation of Seismic Survey Mitigation

Energy Resource Technology GOM, Inc. Page K-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)Measures and Protected Species Observer Program;” and NTL No. 2012

- BSEE

- G01, “Marine Trash and Debris Awareness and Elimination.” At the lessee’s option, the lessee, its operators, personnel, and contractors may comply with the most current measures to protect species in place at the time an activity is undertaken under this lease, including but not limited to new or updated versions of the NTLs identified in t his paragraph. The lessee and its operators, personnel, and subcontractors will be required to comply with the mitigation measures, identified in the above referenced NTLs, and additional measures in the conditions of approvals for their plans or permits.

Energy Resource Technology GOM, Inc. Page K

- 2 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )APPENDIX L
ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(A) MITIGATION MEASURES TAKEN TO MINIMIZE IMPACT TO MARINE AND

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

for this EP.

(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

- JOINT

- G0 1 , “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting

• NTL 2012

- JOINT

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

• NTL 2012

- JOINT

- G02, “Implementation of Seismic Survey Mitigation Measures and Protected Species Observer Program”

Energy Resource Technology G OM, Inc. Page L

- 1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )A PPENDIX M
RELATED FACILITIES AN D OPERATIONS INFORMATION

(A) RELATED OCS FACILITIES AND OPERATIONS

The Motormouth II well will connect back to the proposed GC237 Expansion Manifold. The

infield bulk oil pipeline will be 4.5” x .586” X65 initiating with a dual hub PLET at the well end and termination in a 200ft flexible jumper/gooseneck conne ction at the manifold. The 4.5" bulk oil pipeline will be approximately 9500 ft in length. The well PLET will connect to the tree with a 6.625” x .864” X65 rigid M shaped jumper. T he 6.625" jumper will be approximately 80 ft in length. The design capacity of the pipelines is 10,000 BPD. The SITP is approximately 8000 psig. The shut

- in time for the pi p elines is approximately 5 minutes.

The well will be controlled via a 3

- inch infield electrohydraulic control umbilical. This umbilical will connect to the SUDA of the proposed U1 umbilical riser and terminate near the

well with a UTA. The Motormouth II well will be controlled from the UTA via a hydraulic flying lead and 2 electrical flying leads.

( B

) T RANSPORTATION SYSTEM The measured gas production will depart the Green Canyon Block 237 HP1 platform via the existing 08

- 12 pipeline (Segment No. 16124) to a subsea tie

- in point on the Enterprise

- operated

18

- 20

- inch pipeline (Segment No. 12749) to the Ship Shoal Block 2 07 DWPF platform into the Manta Ray/Nautilus/Anacondo System (Operations System No. H00).

The liquid hydrocarbons from the Green Canyon Block 237 HP1 platform will be transported to

the Shell

- operated Green Canyon Block 19 A Boxer platform via the propo sed 8

- inch oil pipeline (Segment No. 16123) where it will enter into the Phoenix Field dedicated LACT unit meter skid and be measured, for sales and royalty purposes. The measured liquid hydrocarbons will depart the Green Canyon Block 19 A Boxer platform via the existing 12

- inch, 16

- inch or 20

- inch pipelines (Segment Nos. 11472, 7867 or 10610, respectively) for ultimate delivery to shore via Operations System No. 29.5 and/or Operations System No. 36.5.

No new nearshore or onshore pipelines or facilities will be constructed.

( 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 M

- 1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )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 100,000 gallons 3 2 trips/wk

Anchor Handling Boat NA NA NA

Crew Boat 27,000 gallons 1 Daily

Supply Boat 159,000 gallons 1 Daily

Helicopter 380 gallons 1 Daily

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 GC237 then

back to shorebase.

( 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 M

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 and the primary route(s) of the support vessels and aircraft that will be used when travelin g between the onshore support facilities and the platform.

Energy Resource Technology GOM, Inc. Page N

- 1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )APPEN DIX O

ONSHORE SUPPORT FACILITIES INFORMATION

( A ) G ENERAL

Name of Shorebase Location Existing/New/Modified

Martin Terminal North Fourchon , LA Existing

( B

) S UPPORT 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 Exploration Plan.

( C ) S UPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE

There will be no new constructio n of an onshore support base, nor will we expand the existing shorebase as a result of the operations proposed in this Exploration Plan.

( D

) W ASTE DISPOSAL

please specify whether the amount reported is a total or per well Projected generated waste Solid and Liquid Wastes transportation

Type of Waste Composition Transport Method Name/Location of Facility Amount (BBLS/Well) Disposal Method

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

Oil-based drilling fluid or mud N/A

Synthetic-based drilling fluid or mud Synthetic based drilling

fluids USCG approved 25 bbls cutting boxes on deck of transport vessel R360 Environmental

Solutions
Fourchon, La. 400 Injected down hole or recycled at waste disposal facility in Bourg, La.

Cuttings wetted with Water-based fluid N/A

Cuttings wetted with Synthetic-based fluid Spent synthetic based drilling fluids and cuttings USCG approved 25 bbls cutting boxes on deck of transport vessel R360 Environmental

Solutions
Fourchon, La. 400 Injected down hole or recycled at waste disposal facility in Bourg, La.

Cuttings wetted with oil-based fluids N/A

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

Produced sand N/A

Trash and debris Domestic trash Storage bins on deck of transport

vessel River Birch Landfill
Avondale, La. 220 Recycled or disposed per

classification

Used oil Used oil, filters, and rags Storage drums on deck of transport

vessel Martin Energy
Fourchon, La. 3 Recycled

Wash water N/A

Chemical product wastes N/A

NOTE: If you will not have a type of waste, enter NA in the row. TABLE 2. WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHORE (GC 237 Loc "J")

Waste Disposal

Will you have additional wastes that are not permitted for discharge? If yes, fill in the appropriate rows.

Energy Resource Technology GOM, Inc. Page O

- 1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )APPENDIX P

CO ASTAL ZONE MANAGEMENT (CZMA) INFORMATION

R elevant enforceable policies were considered in certifying consistency for Louisiana. The operations proposed in this Plan do not require Coastal Zone Management Consistency for the

state of Louisiana.

Energy Resource Technology GOM, Inc. Page P-1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)APPENDIX Q ENVIRONMENTAL IMPACT 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 (air, noise, light, etc.) Effluents (muds, cutting, other discharges to

the water

column or

s eafloor) Physical

disturbances to the

seafloor (rig or

anchor emplacements, etc.) Wastes sent

to shore for

treatment or disposal Accidents (e.g., oil spills,

chemical spills, H 2 S releases) Discarded

Trash &

Debris

Site

- specific at Offshore

Location

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

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

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

Benthic communities (4)

Water quality X X

Fisheries 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 (7)

Vicinity of Offshore Location

Essential fish habitat X X(6)

Marine and pelagic birds X X

Public health and safety (5)

Coastal and Onshore

Beaches X(6) X

Wetlands X(6)

Shore birds and coastal nesting

birds X6)

Coastal wildlife refuges

Wilderness areas

Energy Resource Technology GOM, Inc. Page Q

- 1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )Footnotes for Environmental Impact Analysis Matrix

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

o 4

- mile zone of the Flower Garden Banks, or the 3

- mile zone of Stets on Bank;

o 1000

- m, 1

- mile or 3

- mile zone of any topographic feature (submarine bank) protected by the Topographic Features Stipulation attached to an OCS lease;

o Essential Fish Habitat (EFH) criteria of 500 ft. from any no

- activity zone; or

o Proximity of any submarine bank (500 ft. buffer zone) with relief greater than 2 meters that is not protected by the Topographic Features Stipulation attached to an OCS lease.

2) Activities with any bottom disturbance within an OCS lease block protected through the Live Botto m (Pinnacle Trend) Stipulation attached to an OCS lease. 3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (Low

- Relief) Stipulation attached to an OCS lease. 4) Activities on blocks designated by the BOEM as being in water depths 300 meters or greater. 5) Exploration or production activities where H2S concentrations greater than 500 ppm might be encountered. 6) All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel th at you determine would impact these environmental resources. If the proposed action is located a sufficient distance from a resource that no impact would occur, the EIA can note that in a sentence or two. 7) All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block designated by the BOEM as having high

- probability for the occurrence of shipwrecks or prehistoric sites, including such blocks that will be affected that are adjacent to the lease block in which your planned activity will occur. If the proposed activities are located a sufficient distance from a shipwreck or a prehistoric site that no impact would occur, the EIA can note that in a sentence or two. 8) All activities that you determine might have an adverse effect on endangered or threatened marine mammals

or sea turtles or their critical habitats. 9) Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges.

Energy Resource Technology GOM, Inc. Page Q

- 2 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )(B) ANALYSIS

Site -Specific at Green Canyon Block 237 Proposed operations consist of the drilling, completion, and production of Well Location J. The operations will be conducted with a dynamically positioned semisubmersible.

1. Designated Topographic Features Potential IPFs on topographic features include e ffluents, and accidents.

E ffluents: Green Canyon Block 237 is 164 miles from the closest designated Topographic Features Stipulation Block (Ewing

- 1 Bank); therefore, no adverse impacts are expected.

A ccidents: 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 colu mn; 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 Appendix I ).

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

2. Pinnacle Trend Area Live Bottoms Potential IPFs on pinnacle trend area live bottoms include effluents and accidents.

E ffluents: Green Canyon Block 237 is 189 miles from the closest live bottom (pinnacle trend) area; therefore, no adverse impacts are expected.

A ccidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed activities (refer to statistics in Item 5 , Water Quality). Oil spills have the potential to foul benthic

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

T here are no other IPFs (including emissions, physical disturbances to the seafloor 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 effluents and accidents.

Energy Resource Technology GOM, Inc. Page Q

- 3 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)Effluents: Green Canyon Block 237 is not located in an area characterized by the existence of live bottoms; therefo re, 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 i f 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 th e amount shown to have an effect on marine invertebrates. Oil from a subsurface spill is not applicable due to the distance of these blocks from a live bottom area. The activities proposed in this plan will be covered by ERT’s Regional OSRP (refer to infor mation submitted in Appendix I ).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes sent to shore for disposal) from the proposed activities which could impact an Eastern Gulf live bottom area.

4. Benthic Com munities 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.

A Dynamically Positioned Semisubmersibl e is being used for the proposed activities; therefore, only an insignificant amount of seafloor will be disturbed. Because physical disturbances to the seafloor will be minimized by the use of a Dynamically Positioned Semisubmersible, ERT’s proposed

oper ations in Green Canyon Block 237 would not cause impacts to benthic communities.

5. Water Quality IPFs that could result in water quality degradation from the proposed operations in Green Canyon

Block 237 include effluents and accidents.

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 effec ts. Operational discharges are not expected to cause significant adverse impacts to water quality.

Accidents: Oil spills have the potential to alter offshore water quality; however, it is unlikely that an accidental surface or subsurface spill would occu r 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 probabi lity 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

colum n and dilute the constituents to background levels. Historically, changes in offshore water quality from oil spills have only been detected during the life of the spill and up to several months afterwards. Most of the components of oil are insoluble in wa ter and therefore float. The activities proposed in this

Energy Resource Technology GOM, Inc. Page Q

- 4 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )plan will be covered by ERT’s Regional Oil Spill Response Plan (refer to information submitted in Appendix I ).

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

6. Fisheries IPFs that could cause impacts to fisheries as a result of the proposed operations in Green Canyon

Block 237 include effluents and accidents.

E ffluents: Effluents such as drilling fluids and cuttings discharges contain components and properties which are detrimental to fishery resources. Moderate petroleum and metal contamination of sediments

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

- current from the discharge point. Offshore discharges are expected to disperse and dilute to very near background levels in the water column or on the seafloor within 3,000 m of the discharge point, and are expected to have neglig ible

effect on fisheries.

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

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

T here are no IPFs from emissions, physical disturbances to the seafloor or wastes sent to shore fo r disposal from the proposed activities which could cause impacts to fisheries.

7

. Marine Mammals GulfCet II studies revealed that cetaceans of the continental shelf and shelf

- edge were almost exclusively bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and pygmy killer whale, Risso’s dolphin, rough

- toothed dolphin, and Cuvier’s beaked whale, occurred most frequently along the upper slope in areas outside of anticyclones. IPFs that could cause impacts to

marine mammals as a r esult of the proposed operations in Green Canyon Block 237 include emissions, effluents, discarded trash and debris, and accidents.

E missions: Noises from drilling activities, support vessels and helicopters may elicit a startle reaction

from marine ma mmals. This reaction may lead to disruption of marine mammals’ normal activities. Stress may make them more vulnerable to parasites, disease, environmental contaminants, and/or predation (Majors and Myrick, 1990). There is little conclusive evidence for l ong- term displacements and population trends for marine mammals relative to noise.

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

Energy Resource Technology GOM, Inc. Page Q

- 5 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)Discarded trash and debris: Both entanglement in, and ingestion of debris h ave 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 delib erately 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).

E RT 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 acci dental 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) wil l 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 cetaceans would be unusual events, however should one occur, death or injury to marine mammals is possible. Contract vessel operators can avoid marine mammals and reduce potential deaths by maintaining a vigilant watch for marine mammals and maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to help identify the twenty

- eight species of whales and dolphins, and the single species of manatee that may be

encountered in the Gulf of Mexico OCS. Vessel crew s must report sightings of any injured or dead protected marine mammal species immediately, regardless of whether the injury or death is caused by their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline at (888) 404

- 3922, the NMFS Southeast Reg ional Office at (727) 824

- 5312, or the Marine Mammal Stranding Network at (305) 862

- 2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@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.

Oil spills have the potential to cause sublethal oil

- related injuries and spill

- related deaths to marine mammals. However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Oil spill response activities may increase vessel traffic in t he area, which could add to changes in cetacean behavior and/or distribution, thereby causing additional stress to the animals. The effect of oil dispersants on cetaceans is not known. The acute toxicity of oil dispersant chemicals included in 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 covered by ERT’s OSRP (refer to information submitted in accordance with Appendix I ).

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- 6 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )There are no other IPFs (including physical disturbances to the seafloor) from the proposed activities which could impact marine mammals.

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

E missions: Noise from drilling activities, support vessels, and helicopters may elici t a startle reaction from sea turtles, but this is a temporary disturbance.

E ffluents: 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 i mpact 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).

D iscarded trash and debris: Both entanglement in, and ingestion of, debris have caused the death or

ser ious injury of sea turtles (Balazs, 1985). The limited amount of marine debris, if any, resulting from the proposed activities is not expected to substantially harm sea turtles. Operators are prohibited from deliberately discharging debris as mandated by MARPOL

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

I nformational 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 rece ive 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.

A ccidents: Collisions between support vessels and sea turtles would be unusual events, however should one occur, death or injury to sea turtles is possible. Contract vessel operators can avoid sea turtles and reduce potential deaths by maintaining a vigilant watch for sea turtles and maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to help identify the five species of sea turtles that may be encountered in the Gulf of Mexico OCS. Vessel crews must report sightings of any injured or dead protected sea turtle species immediately, regardless of whether

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- 7 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)the injury or death is caused by their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline at (888) 404

- 3922, the NMFS Southeast Regional Office at (727) 824

- 5312, or the Marine Mammal Stranding Network at (305) 862-2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@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.

A ll 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 oi l 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 Plan (refer to information submitted in accordance with Appendix I ).

T here are no other IPFs (inc luding physical disturbances to the seafloor) from the proposed activities which could impact sea turtles.

9. Air Quality The projected air emissions identified in Appendix H are not expected to affect the OCS air quality primarily due to distance to the shore or to any Prevention of Significant Deterioration Class I air quality area such as the Breton Wilderness Area. Green Canyon Block 237 is beyond the 200 kilometer (124 m ile) buffer for the Breton Wilderness Area and is 91 miles from the coastline. Therefore, no special mitigation, monitoring, or reporting requirements apply with respect to air

emissions.

A ccidents and blowouts can release hydrocarbons or chemicals, which could cause the emission of air pollutants. However, these releases would not impact onshore air quality because of the prevailing atmospheric conditions, emission height, emission rates, and the distance of Green Canyon Block 237

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

10. Shipwreck Sites (known or potential)
Potential IPFs that could impact known or unknown shipwreck sites as a result of the proposed operations in Green Canyon Block 237 include disturbances to the seafloor.

P hysical disturbances to the seafloor: A Dynamically Positioned Semisubmersible is being used for the proposed activities; therefore, only an insignificant amount of seafloor will be disturbed. Because physical disturbances to the seafloor will be minimized by the use of a Dynamically Positioned Semisubmersible, ERT’s proposed operations in Green Canyon Block 237 would not cause impacts to shipwreck sites.

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- 8 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)Additionally, Green Canyon Block 237 is not located in or adjacent to an OCS block designated by BOEM as having a high probability for occurrence of shipwrecks, therefore, no adverse impacts are expected.

ERT will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning sonar within a minimum 500’ radius of the proposed well location(s) prior to or upon commencement of operations. These locations will be certified by an authorized mari ne archaeologist and by ERT to be clear of seafloor archaeological resources, including historic shipwrecks. Copies of the certifications and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be encountered, ERT wil l contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural resource.

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

11. Prehistoric Archaeological Sites Potential IPFs that could cause impacts to prehistoric archaeological sites as a result of the proposed operations in Green Canyon Block 237 include disturbances to th e seafloor.

Physical disturbances to the seafloor: A Dynamically Positioned Semisubmersible is being used for the proposed activities; therefore, only an insignificant amount of seafloor will be disturbed. Because physical disturbances to the seafloor w ill be minimized by the use of a Dynamically Positioned Semisubmersible, ERT’s proposed operations in Green Canyon Block 237 would not cause impacts to prehistoric archaeological sites.

ERT will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning sonar within a minimum 500’ radius of the proposed well location(s) prior to or upon commencement of operations. These locations will be certified by an authorized marine archaeologist and by ERT to be clear of seafloor archaeological reso urces. Copies of the certifications and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be encountered, ERT will contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural resource.

Additionally, Green Canyon Block 237 is located outside the Archaeological Prehistoric high probability line, therefore, no adverse impacts are expected.

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatmen t or disposal, or accidents) from the proposed activities which could impact prehistoric archeological sites.

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- 9 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )V icinity of Offshore Location

1. Essential Fish Habitat (EFH) IPFs that could cause impacts to EFH as a result of the proposed operations in Green Canyon Block

237 include effluents and accidents. EFH includes all estuarine and marine waters and substrates in the

Gulf of Mexico.

E ffluents: The Live Bottom Low Rel ief Stipulation, the Live Bottom (Pinnacle Trend) Stipulation, and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential impacts on live

bottom communities and EFH from operational waste discharges. Levels of contaminants in drill ing muds and cuttings and produced

- water discharges, discharge

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

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

T here are no other IPFs (including emissions, physical disturbances to the seafloor and wastes sent to

shore for treatment or disposal) from the proposed activities which could impact essential fish habitat.

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

E missions: Emissions of pollutants into the atmosphere from these activities are far below

concentrations which could harm coastal and marine birds.

A ccidents: An oil spill would cause localized, lo w- 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, phy siological stress. It is expected that few, if any, coastal and marine birds would actually be affected to that extent. The activities proposed in this plan will be covered by ERT’s Regional OSRP (refer to information submitted in Appendix I ).

D iscarded trash and debris : Marine and pelagic birds could become entangled and snared in discarded trash and debris, or ingest small plastic debris, which can cause permanent injuries and death. Operators are prohibited from deliberately discharging debris as man dated 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 wit h the regulations and also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and using special

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- 10 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)precautions such as covering outside trash bins to prevent accidental loss of solid waste. Speci al 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 vess els 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 procedur es, 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 a lso 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 m arine and pelagic birds; therefore, the effects will be negligible.

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

birds.

3. Public Health and Safety Due to Accidents. There are no IPFs (emissions, effluents, physical disturbances to the seafloor, wastes sent to shore for treatment or disposal or accidents, including an accidental H 2 S release) from the proposed activities which could cause impacts to public health and safety. In accordance with NTL No.’s 2008

- G04,

2009

- G27, and 2009

- G31, sufficient information is included in Appendix D to justify our request that our proposed activit ies be classified by BSEE as H 2 S absent.

Coastal and Onshore

1. Beaches IPFs from the proposed activities that could cause impacts to beaches include accidents (oil spills) and

discarded trash and debris.

Accidents: Oil spills contacting beaches wou ld have impacts on the use of recreational beaches and associated resources. Due to the distance from shore (91 miles) and the response capabilities that would be implemented, no significant adverse impacts are expected. The activities proposed in this

p lan will be covered by ERT’s Regional OSRP (refer to information submitted in Appendix I ).

Discarded trash and debris: Trash on the beach is recognized as a major threat to the enjoyment and use of beaches. There will only be a limited amount of marine debris, if any, resulting from the proposed activities. Operators are prohibited from deliberately discharging debris as mandated by

MARPOL

- Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies inc luding 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

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- 11 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )packaging materials, particularly those made of non -bio degradable, environmentally persistent materials such as plastic or glass.

I nformational placards will be posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore personnel, including contractors and other sup port 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 Litte r 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.

T here 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. Wetl ands IPFs from the proposed activities that could cause impacts to wetlands include accidents (oil spills) and

discarded trash and debris.

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

, Water Quali ty). Due to the distance from shore (91 miles) and the response capabilities that 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 Appendix I ).

D i scarded trash and debris: There will only be a limited amount of marine debris, if any, resulting from the proposed activities. Operators are prohibited from deliberately discharging debris as mandated by MARPOL

- Annex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). 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 o f small items and packaging materials, particularly those made of non

- biodegradable, environmentally persistent materials such as plastic or glass.

I nformational placards will be posted on all vessels and facilities having sleeping or food preparation

c apabilities. 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 pr esentation), “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 d esignated lease operator management that emphasizes their commitment to waste management

in accordance with NTL No. 2012-G01.

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- 12 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to

shore for treatment or di sposal) from the proposed activities which could impact wetlands.

3. Shore Birds and Coastal Nesting Birds Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Given the distance from shore (91 miles) and the response capabi lities that 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 Appendix I ).

Discarded trash and debris: Coastal and marine birds are highly sus ceptible 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 re gulations 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

wast e 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 m aterials, 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 p ersonnel, 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 man agement 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 ac tivities that could cause impacts to shore birds and coastal nesting birds.

4. Coastal Wildlife Refuges Accidents: An accidental oil spill from the proposed activities could cause impacts to coastal wildlife refuges. However, it is unlikely that an oil s pill would occur from the proposed activities (refer to Item 5, Water Quality). Due to the distance from shore (91 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be cove red by ERT’s Regional OSRP (refer to information submitted in Appendix I ).

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- 13 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )Discarded trash and debris: Operators are prohibited from deliberately discharging debris as mandated by MARPOL

- Annex V, the Marine Plastic Pollution Research and Control Act and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). ERT will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaining wa ste management plans, manifesting trash sent to shore, and using special precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handling and disposing of small items and packaging materials, particularly those made of non

- biodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or food preparation capabilities. All offshore personnel, including contractors and other support services

related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris training video annually. Offshore personnel will also receive an explanation from ERT management or the designated lease operator m anagement that emphasizes their commitment to waste management in accordance with NTL No. 2012

- G01.

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

5. Wilderness Areas Accidents: An accidental oil spill from the proposed activities could cause impacts to wilderness areas. However, it is unlikely that an oil spill would occur from the pr oposed activities (refer to Item 5

, Water Quality). Due to the distance from the nearest designated Wilderness Area (164 miles) and the response capabilities that would be implemented, no significant adverse impacts are expected. The activities proposed in this plan will be covered by ERT ’s Regional OSRP (refer to information

submitted in Appendix I).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as mandated by MARPOL

- Annex V, the Marine Plastic Pollution Research and Control Act and regulation s 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 manage ment 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

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- 14 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” ( previ ously “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.

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

areas.

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

(C ) IMPACTS ON PROPOSED ACTIVITIES

The site

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

(D ) ENVIRONMENTAL 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 its location in the gulf, Green Canyon Block 237 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 (i ncluding hydrocarbons). Additionally, the displacement of equipment may disrupt the local benthic habitat and pose a threat to local species.

T he following preventative measures included in this plan may be implemented to mitigate these impacts:

1. Drilli ng & 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. P latform / Strucure Installation Operator will not conduct platform / structure ins tallation operations during Tropical

Storm or Hurricane threat.

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

Hurricane threat.

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- 15 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)(E) ALTERNATIVES No alternatives to the proposed activities were considered to reduce environmental impacts.

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

(G ) CONSULTATION

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

(H) PREPARER(S) Evan Connolly J. Connor Consulting, Inc. 16225 Park Ten Place, Suite 700

Ho uston, TX 77084 (281) 578-3388 Evan.connolly@jccteam.com

(I

) REFERENCES

Authors:

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

B alazs, 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.

B urke, 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.

D aly, 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.

H ansen, D.J. 198l. The relative sensitivity of seabird populations in Alaska to oil pollution. U.S. Dept. of the Interior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLM

- YK

- ES -81-

006-1792.

L aist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris including a comprehensive list of species with entanglement and ingestion records. In: Coe, J.M. and D.B. Rogers, eds. Marine debris: sources, impacts, and solutions. New York, NY: Springer

- Verlag. Pp.

99-139.

Energy Resource Technology GOM, Inc. Page Q

- 16 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS -G 15563)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 Cong ress

– 1998.

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

- 397

Vauk , G., E. Hartwig, B. Reineking, and E. Vauk

- Hentzelt. 1989. Loss es of seabirds by oil pollution at the German North Sea coast. Topics in Marine Biology. Ros, J.D, ed. Scient. Mar. 53 (2

- 3): 749

- 754.

Vermeer, K. and R. Vermeer, 1975 Oil threat to birds on the Canadian west coast. The Canadian

Field

- Naturalist. 89:278

- 298.

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

• Hazard Surveys

• BOEM EIS’s:

o GOM Deepwater Operations and Activities. Environmental Assessment. BOEM 2000

- 001
GOM Central and Western Planning Areas Sales 166 and 168 Final Enviro nmental Impact Statement.

BOEM

Energy Resource Technology GOM, Inc. Page Q

- 17 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )APPENDIX R
ADMINISTRATIVE INFORMATION

( A) E XEMPTED INFORMATION DESCRIPTION The proposed bottom

- hole location of the planned well ha s been removed from the public information copy of the DOCD as well as any discussions of the target objectives, geologic or geophysical data,

and an y interpreted geology.

(B) B IBLIOGRAPHY Not applicable.

Energy Resource Technology GOM, Inc. Page R

- 1 Supplemental Development Operations Coordination Document January 22, 2015 Green Canyon Block 237 ( OCS

- G 15563 )

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

- 0151 Bureau of Ocean Energy Management OMB Approval Expires: 12/31/14

O CS PLAN INFORMATION FORM

General Information

Type of OCS Plan: E xploration 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

E mail Address: cathy.thornton@jccteam.com

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $4238 Receipt No. 25JE9SJ O

Project and Worst Case Discharge (WCD)Information

Lease(s): G15563 Area: GC Block(s): 237 Project Name (if applicable): Motormouth II

Objective(s): X Oil X Gas S ulphur Sa lt Onshore Support Base(s): Fourchon, LA

Platform/Well Name: Well Location K Total Volume of WCD : 212,891 API Gravity : 33°

Distance to Close s t Land (Miles): 9 1 Volume from uncontrolled blowout: 212,891

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

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

- 5300

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

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

Do you propose any facility that will serve as a host facility for deepwater subsea development? Yes X No Description of Proposed Activities and Tentative Schedule (Mark all that apply )
Proposed Activity Start Date End Date No. of Days

Exploration drilling

Development drilling and completion

Well completion 0 6 /0 1 /2015 0 8 / 09 / 201 5 7 0
Well test flaring (for more than 48

- hours)

Installation or modification of structure

In stallation of production facilities

Installation of subsea wellheads and/or manifolds 09/01/2015 09/16/2015 15
Installation of lease term pipelines

Commence production

Other (Specify and attach description) Description of Drilling Rig Desc ription of Structure

Jackup D rillship C aisson T ension leg platform

Gorilla Jackup Platform Rig Fixed platform Compliant tower

Semisubmersible S ubmersible Sp ar G uyed tower

X DP Semisubmersible O ther (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)

MM2 w ell (Well Jumper) MM2 PLET 6.625" 80' '

MM2 PLET (MM2 Flo wline) #003 well PLET 4.5" 9500'

MM2 well (Control Umbilical) Typhoon SUDA 3" 9500'

FORM BOEM

- 0137 ( Decem ber 2011 - Supersedes all previous editions of this form which may not be used. Page 1 of 4O CS PLAN INFORMATION FORM (CONTINUED)

Include on e 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)

Well Location K 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? X Yes No

WCD info F or wells, volume of uncontrolled blowout (Bbls/day) 212,891 For structures, volume of all storage and pipelines (Bbls) API Gravity of

fluid 3 3 °

Surface Location Bottom

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

Lease No. OCS

- G 15563

Area Name GC

Block No. 2 37

Block Line Departures (in feet) N/S Departure: 788 ’ F N L N/S Departu re: N/S Departure: F____L N/S Departure: F____L N/S Departure: F____L E/W Departure: 5965 ’ F E L E/W De parture: E/W Departure: F____L E/W Departure: F____L E/W Departure: F____L

Lambert X

- Y

coordinates X: 2,2 59

, 155.00 ’ X: X:

X:

X:

Y: 10,0 73

, 452.00 ’ Y: Y:

Y:

Y:

Latitude / Longitude Latitude: 27 ° 4 4 ' 46.655 "N Latitude: Latitude:

Latitude:

Latitude: Longitude: 91 ° 0 5 ' 11.791 " W Longitude: Longitude: Longitude: Longitude: Water Depth (Feet):

1935' MD (Feet): TVD (Feet): MD (Feet): MD (Feet): MD (Feet ): TVD (Feet): TVD (Feet): TVD (Feet): 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 (December 2011- Supersedes all previous editions of this form which may not be used.) Page 2 of 4Bathymetric information based on seafloor event pick from 3D data set

Contour interval = 10 feet

Zero datum = Sea Level Applied acoustic velocity using Advocate and Hood, 1993 Color shaded image

6XQD]LPXWK 

6XQHOHYDWLRQ 

DATE: REVISED: JOB No:

FILENAME: 141454 Jan. 7, 2015 PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions.



### WELL SITE CLEARANCE
COLOR SHADED BATHYMETRY Well "K" Block 237 (OCS-G-15563) Green Canyon Area Deeper Shallower Seafloor surface location of wellYour payment has been submitted to Pay.gov and the details are below. If you have any questions regarding this payment, please contact Brenda Dickerson at (703) 787 -1617 or BseeFinanceAccountsReceivable@bsee.gov

.

Application Name: BOEM Development/DOCD Plan

- BD Pay.gov Tracking ID: 25JE9SJO Agency Tracking ID: 74740726290

Transaction Type: Sale

Transaction Date: 01/21/2015 08:55:08 AM EST

Account Holder Name: Melissa Logan

Transaction Amount: $4,238.00 Billing Address: 500 Dallas Street Billing Address 2: Sui te 2000 City: Houston

State/Province: TX Zip/Postal Code: 77002 Country: USA

Card Type: MasterCard

Card Number: ************9587

Region: Gulf of Mexico Contact: Cathy Thornton 713-705-8020

Company Name/No: Energy Resource Technology GOM, Inc., 02899 Lease Number(s): 15563, , , ,

Area -Block: Green Canyon GC, 237: , : , : , : , Type-Wells: Supplemental Plan, 1

# A ttachment B

P reviously reviewed and found acceptable under Revised DOCD (R

- 5300)

# A ttachment CDATE:

REVISED: JOB No:

FILENAME: 141454 Jan. 7, 2015 PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions.



### WELL SITE CLEARANCE
SUBSURFACE FEATURES MAP Well "K" Block 237 (OCS-G-15563) Green Canyon Area Navigation trackline with name and direction run, fix and fix number

Camera trackline with name and direction run, fix and fix number
CGG survey inline line number Inline spacing = 65.62' (20m) CGG survey crossline line number Crossline spacing = 82.02' (25m) WesternGeco survey inline line number Inline spacing = 65.62' (20m) WesternGeco survey crossline line number Crossline spacing = 41.01' (12.5m)
Surface fault with and seafloor displacement in feet (Hachures on downthrown side) Amplitude anomalies within Unit B (1,851' - 4,536' below sea level)

NOTE: C&C and Tesla Deeptow data was merged with CGG and WesternGeco data to provide coverage for Well "K" assessment area. -15' Normal fault with depth of burial below seafloor (Hachures on downthrown side) Fault zoneDATE:

REVISED: JOB No:

FILENAME: 141454 Jan. 7, 2015 PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions.



### WELL SITE CLEARANCE
SEAFLOOR FEATURES MAP Well "K" Block 237 (OCS-G-15563) Green Canyon Area Navigation trackline with name and direction run, fix and fix number

Camera trackline with name and direction run, fix and fix number Drag scar

Sonar contact & reference number

CGG survey inline line number Inline spacing = 65.62' (20m) CGG survey crossline line number Crossline spacing = 82.02' (25m) WesternGeco survey inline line number Inline spacing = 65.62' (20m) WesternGeco survey crossline line number Crossline spacing = 41.01' (12.5m) 2 8.1'x5.7'x0.0' 2,257,339' 10,074,062' 1 8.1'x4.0'x0.0' 2,257,401' 10,074,080' SONAR CONTACTS

DESCRIPTION X COORDINATE Y COORDINATE NUM.

Surface fault with and seafloor displacement in feet (Hachures on downthrown side)

Increased reflectivity indicating hardgrounds and potential benthic communities Depression (symbol does not reflect actual size)

NOTE: C&C and Tesla Deeptow data was merged with CGG and WesternGeco data to provide coverage for Well "K" assessment area. Seafloor surface

location of wellDATE:

REVISED: JOB No:

FILENAME: 141454 Jan. 7, 2015 PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions.-10000-500005000100001500020000250003000035000400004500050000550006000065000700007500080000850009000095000100000105000110000115000120000-1.25-1.00-0.75-0.50-0.250.000.250.500.751.001.251.501.752.002.252.502.753.003.253.503.754.004.254.504.755.005.255.505.756.00



### WELL SITE CLEARANCE
SEAFLOOR AMPLITUDE MAP Well "K" Block 237 (OCS-G-15563) Green Canyon Area CGG survey inline line number Inline spacing = 65.62' (20m) CGG survey crossline line number Crossline spacing = 82.02' (25m) WesternGeco survey inline line number Inline spacing = 65.62' (20m) WesternGeco survey crossline line number Crossline spacing = 41.01' (12.5m) Seafloor surface location of wellCGG DataWesternGecoDataDATE:

REVISED: JOB No:

FILENAME: 141454 Jan. 7, 2015 PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions. 2 8.1'x5.7'x0.0' 2,257,339' 10,074,062'

1 8.1'x4.0'x0.0' 2,257,401' 10,074,080' SONAR CONTACTS

NUM. DESCRIPTION X COORDINATE Y COORDINATE



### WELL SITE CLEARANCE
SIDE SCAN SONAR MOSAIC Well "K" Block 237 (OCS-G-15563) Green Canyon Area SONAR MOSAIC Dark returns represent higher seafloor reflectivity. Navigation trackline name and direction run

Sonar contact & reference number

Seafloor surface location of wellDATE:

REVISED: JOB No:

FILENAME: 141454 Jan. 7, 2015 PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions.



### WELL SITE CLEARANCE
SEAFLOOR GRADIENT MAP Well "K" Block 237 (OCS-G-15563) Green Canyon Area Navigation trackline name and direction run>20191817161514131211109876543210_ GRADIENT

Gradient is the first order derivative of the multibeam data. Bin size = 3 meters (9.84 feet)

SLOPE IN DEGREES Seafloor surface location of wellBathymetric information based on seafloor event pick from 3D data set

Contour interval = 10 feet

Zero datum = Sea Level Applied acoustic velocity using Advocate and Hood, 1993 Color shaded image

6XQD]LPXWK 

6XQHOHYDWLRQ 

DATE: REVISED: JOB No:

FILENAME: 141454 Jan. 7, 2015 PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions.



### WELL SITE CLEARANCE
COLOR SHADED BATHYMETRY Well "K" Block 237 (OCS-G-15563) Green Canyon Area Deeper Shallower Seafloor surface location of well

# A ttachment HDOCD AIR QUALITY SCREENING CHECKLIST OMB Control No. 1010-0151 OMB Approval Expires: 12/31/2011

MMS FORM MMS-139 (December 2008- Supersedes all previous versions of form MMS-139 which may not be used). Page 1 of 8 COMPANY Energy Resource Technology GOM, Inc.

AREA Green Canyon

BLOCK 237

LEASE OCS-G 15563

PLATFORM

WELL Location K

COMPANY CONTACT Cathy Thornton

TELEPHONE NO. 713-705-8020

REMARKS

LEASE TERM PIPELINE CONSTRUCTION INFORMATION:

YEAR NUMBER OF TOTAL NUMBER OF CONSTRUCTION DAYS

PIPELINES

2015 2 15AIR EMISSIONS CUMPUTATION FACTORS

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 2 of 8 Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATE SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 3.2-1 4/76 & 8/84

Equipment/Emission Factors units PM SOx NOx VOC CO REF. DATE

NG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-1& 3.1-1 10/96 NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 3.2-1 10/96 NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 3.2-1 10/96 NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 3.2-1 10/96

D iesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 3.3-1 10/96 Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96

Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3-12,14 9/98

NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 14-2, & 14 7/98
NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 11.5-1 9/91 Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-1 & 1.3-3 9/98 Tank Vapors lbs/bbl 0.03 E&P Forum 1/93 Fugitives lbs/hr/comp. 0.0005 API Study 12/93 Glycol Dehydrator Vent lbs/mmscf 6.6 La. DEQ 1991 Gas Venting lbs/scf 0.0034

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm
Diesel Fuel 0.4 % weight Produced Gas( Flares) 3.33 ppm Produced Oil (Liquid Flaring) 1 % weightAIR EMISSIONS CALCULATIONS - FIRST YEAR

MMS FORM MMS-139 (December 2008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 3 of 8 COMPANY AREA BLOCK LEASE PLATFORM WELL CO NTACT P HONE REMARKS

Energy Resource Techno Green Canyon 237 OCS-G 15563 0 Location K Cathy Thornton 713-705-8020 #REF!
OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONS Diesel Engines HP GAL/HR GAL/D 3.3 Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24 70 43.14 197.89 1482.82 44.48 323.52 36.23 166.23 1245.57 37.37 271.76 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 10 1.46 6.68 50.03 1.50 10.92 0.06 0.27 2.00 0.06 0.44 VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 10 1.46 6.68 50.03 1.50 10.92 0.07 0.33 2.50 0.08 0.55 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PIPEL INE PIPELINE LAY BARGE diesel 8000 386.4 9273.60 24 15 5.64 25.87 193.83 5.81 42.29 1.01 4.66 34.89 1.05 7.61

INSTALLATION SUPPORT VESSEL diesel 13600 656.88 15765.12 20 15 9.59 43.98 329.52 9.89 71.89 1.44 6.60 49.43 1.48 10.78

SUPPORT VESSEL diesel 10800 521.64 12519.36 24 15 7.61 34.92 261.67 7.85 57.09 1.37 6.29 47.10 1.41 10.28

PIPELINE BURY BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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

FACIL ITY DERRICK BARGE diesel 0 0 0.00 0 0 0 .00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

PRODUCTION R ECIP.<600hp diesel 35 1.6905 40.57 1 365 0.08 0.11 1.08 0.09 0.23 0.01 0.02 0.20 0.02 0.04 RECIP.<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 RECIP.>600hp diesel 7500 362.25 8694.00 24 365 5.29 24.25 181.72 5.45 39.65 23.15 106.22 795.93 23.88 173.66

SUPPORT VESSEL diesel 2065 99.7395 2393.75 10 52 1.46 6.68 50.03 1.50 10.92 0.38 1.74 13.01 0.39 2.84 TURBINE nat gas 0 0 0.00 0 0 0 .00 0.00 0.00 0.00 0 .00 0.00 0.00 0.00 RECIP.2 cycle lean nat gas 0 0 0.00 0 0 0 .00 0.00 0.00 0.00 0 .00 0.00 0.00 0.00 RECIP.4 cycle lean nat gas 0 0 0.00 0 0 0 .00 0.00 0.00 0.00 0 .00 0.00 0.00 0.00 RECIP.4 cycle rich nat gas 7800 55715.4 1337169.60 24 365 0 .03 171.81 2.41 147.75 0 .14 752.51 10.54 647.16 BURNER nat gas 0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 0.00

FLARE- 0 0 0 0 .00 0.00 0.00 0.00 0 .00 0.00 0.00 0.00

PROCESS VENT- 0 0 0 0 .00 0 .00

FUGITIVES- 0 .0 0 0.00 0.00

GL YCOL STILL VENT- 0 0 0 0.00 0.00

OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0 .00 0.00 0.00 0.00 0.00

DRILLING GAS FLARE 0 0 0 0 .00 0.00 0.00 0.00 0 .00 0.00 0.00 0.00

WELL TEST

YEAR TOTAL 79.04 347.08 2772.54 80.48 715.19 63.74 292.48 2943.13 76.26 1125.11

2015

EXEMPTION

CALCULATION DISTANCE FROM LAND IN

MILES 3030.30 3030.30 3030.30 3030.30 68787.02

91.0AIR EMISSIONS CALCULATIONS

MMS FORM MMS-139 (December 20008 - Supersedes all previous versions of form MMS-139 which may not be used). Page 8 of 8 COMPANY AREA BLOCK LEASE PLATFORM WELL

Energy Resource Green Canyon 237 OCS-G 15563 0 Location K

Emitted Substance

Year

PM SOx NOx VOC CO

2015 63.74 292.48 2943.13 76.26 1125.11

Allowable 3030.30 3030.30 3030.30 3030.30 68787.02

# A ttachment NViosca Knoll

Miui

.. ippi Canyon

Atwater Valley 

## Louisiana

Eugene Island Area

South Addition Eugene lJland Area SouthManb
bland Area

South M

.... h

"land Are

.. South Additiol Vermilion Area

Vermilion Area
South Addition East Cameron Area

Garden Bank

.. --" 

## Texas 

# Central GOM Regional Map



# <

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# -- :::s

# ~.;Ld 

# r

Ie'S 

# P-l/N

_ .. I

# ~? 

# T

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## Area of Interest

_ Green Canyon Area**Blocrt1~6** 

## 7