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

WELL/K G15563/GC/237 788 FNL, 5965 FEL G15563/GC/237

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

Description -

Rig Type -

Subject:

From:

March 16, 2015
Public 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

Submitted by: Energy Resource Technology GOM, Inc.

500 Dallas Street

Suite 2000

Houston, Texas 77002

Mandy Phythian

(713) 380-4930

mphythian@talosenergyllc.com

Estimated startup date: June 1, 2015

Authorized 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 Jez
ENERGY RESOURCE TECHNOLGY GOM, INC.

SUPPLEMENTAL DEVELOPMENT OPERATIONS COORDINATION DOCUMENT

LEASE OCS-G 15563 

GREEN CANYON BLOCK 237 

APPENDIX A Plan Contents 

APPENDIX B General Information

APPENDIX C Geological, Geophysical Information

APPENDIX D H2S Information 

APPENDIX E Mineral Resource Conservation Information 

APPENDIX F Biological, Physical and Socioeconomic Information

APPENDIX G Wastes and Discharge Information 

APPENDIX H Air Emissions Information

APPENDIX I Oil Spills Information

APPENDIX J Environmental Monitoring Information 

APPENDIX K Lease Stipulations Information 

APPENDIX L Environmental Mitigation Measures Information 

APPENDIX M Related Facilities and Operations Information 

APPENDIX N Support Vessels and Aircraft Information 

APPENDIX O Onshore Support Facilities Information 

APPENDIX P Coastal Zone Management Act (CZMA) Information 

APPENDIX Q Environmental Impact Analysis

APPENDIX R Administrative Information 
Record of Changes

Date Appendix Revision

01/27/2015 B Included 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 
APPENDIX A

PLAN CONTENTS

(A) PLAN 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 2130’ and will be drilled and completed with a DP 

semisubmersible rig. The Motormouth II well will connect back to the proposed GC237 

Expansion Manifold. 

See attached OCS Plan Information Form – Form BOEM-137 included in Attachment A. 

(B) LOCATION 

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) SAFETY 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.

The rig will be equipped with safety and fire-fighting equipment required to comply with United 

States Coast Guard (USCG) regulations. Appropriate life saving equipment such as life rafts, life 

jackets, ring buoys, etc. as prescribed by the USCG, will be maintained on the rig at all times. 

Safety features on the drilling unit will include well control, pollution prevention, and blowout 

prevention equipment as described in BSEE regulations 30 CFR 250 C, D, E, O, Q and S; and as 

further clarified by BSEE Notices to Lessees, and current policy making invoked by the BSEE, 

Environmental Protection Agency and the U.S. Coast Guard (USCG). 

Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on 

drilling deck areas to collect all contaminants and debris. Compliance will be maintained with 

the EPA NPDES Permit. The rig will be monitored daily and any waste or fuel resulting in 

pollution of the Gulf waters will be reported to the representative in charge for immediate 

isolation and correction of the problem. Any spill will be reported to the appropriate 

governmental agencies. . 

(D) STORAGE 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) POLLUTION PREVENTION MEASURES (FLORIDA ONLY)

Pollution prevention measures information is not required by BOEM to be included in this Plan.

(F) ADDITIONAL MEASURES

ERT does not propose additional safety, pollution prevention, or early spill detection measures 

beyond those required by 30 CFR 250. 

(G) COST RECOVERY FEE

Included in Attachment A is a PayGov 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) APPLICATIONS 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 BSEE Pending

Supplemental Deepwater Operations Plan BSEE Pending

Lease Term Pipeline Application BSEE Pending

Surface Commingling Application BSEE Pending

(B) DRILLING FLUIDS

Type 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) PRODUCTION 

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 #001 ST01 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 

respectively 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 #001 ST01. 

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, 

subpart 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, “Supplemental Bond 

Procedures.”

(G) OIL SPILL FINANCIAL RESPONSIBILITY (OSFR)

ERT, BOEM company number 02899, has demonstrated oil spill financial responsibility for the 

facilities proposed in this DOCD according to 30 CFR Part 253; and NTL No. 2008-N05, 

"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) BLOWOUT 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 MMSCFD. Seismic and offset well 

interpretation 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 the 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 

Containment 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 removal / 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 Q4000 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 the 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 HWCG vessels and equipment will 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 equipment 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 hole 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 must 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 operations, 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 all 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 intervention 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 mobilize 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 operations 

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 

surface 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

GEOLOGICAL AND GEOPHYSICAL INFORMATION

(A) GEOLOGICAL DESCRIPTION 

Proprietary Information 

(B) STRUCTURE CONTOUR MAPS 

Current structure contour maps drawn on the top of each prospective hydrocarbon sand, showing 

the entire lease block, the location of the proposed wells, and the locations of geological crosssections are included in Attachment C.

(C) INTERPRETED SEISMIC LINES 

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) GEOLOGICAL STRUCTURE CROSS-SECTIONS

Interpreted geological structure cross-sections showing the location and depth of the proposed 

well and at least one key horizon and the objective sands 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) overlain 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) CONCENTRATION

ERT does not anticipate encountering any H2S during the proposed operations. 

(B) CLASSIFICATION

In accordance with Title 30 CFR 250.490(c), ERT hereby requests that Green Canyon Block 237

be classified by the BOEM as H2S absent. 

The basis for this determination is the evaluation of the drilling and production of the Green 

Canyon Block 237 Well No. 001 ST01 which was drilled to the stratigraphic equivalent of the B2 sand as proposed in this DOCD. 

. 

(C) H2S CONTINGENCY PLAN 

Not Applicable.

(D) MODELING 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) TECHNOLOGY & RESERVOIR ENGINEERING PRACTICES AND PROCEDURES

Proprietary Information

(B) TECHNOLOGY AND RECOVERY PRACTICES AND PROCEDURES

Proprietary Information 

(C) RESERVOIR DEVELOPMENT

Proprietary Information

Energy Resource Technology GOM, Inc. Page E-1 

Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS-G 15563)
APPENDIX F 

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

(A) DEEPWATER BENTHIC COMMUNITIES 

Activities proposed in this DOCD will disturb seafloor areas in water depths greater than 300 

meters (984 feet); therefore, information as outlined in Attachment A of NTL No. 2009-G40, 

"Deepwater Benthic Communities", is provided below. 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.

ERT would 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). 

MAPS

Attached to this DOCD are maps prepared using 3-D seismic data depicting seafloor and shallow 

geological features and areas, and the surface locations of the proposed wells with a radius circle 

of 2000 feet around the well. 

ANALYSIS

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: 

Features 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) TOPOGRAPHIC FEATURES MAP 

Activities proposed in this DOCD do not fall within 305 meters (1000 feet) of a topographic “no 

activity zone”.

(C) TOPOGRAPHIC FEATURES STATEMENT (SHUNTING)

All activities proposed under this DOCD will be conducted outside all Topographic Feature 

Protective Zones, therefore shunting of drill cuttings and drilling fluids is not required 

(D) LIVE BOTTOMS (PINNACLE TREND) MAP

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 within 30 meters (100 feet) of potentially sensitive 

biological features; therefore, biologically sensitive area maps are not required.

(G) REMOTELY OPERATED VEHICLE (ROV) 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 Operators 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

In addition, there are 28 species of marine mammals that may be found in the Gulf of Mexico. 

The table provided below identifies the seven (7) species of marine mammals that are listed as 

endangered or threatened. Currently, there are no designated critical habitats for the listed 

species in the Gulf of Mexico Outer Continental Shelf; however, it is possible that one or more 

of these species could be seen in the area during operations

.

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

There 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 rivers 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) ARCHAEOLOGICAL 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 

Notices 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 

AIR EMISSIONS INFORMATION

(A) EMISSIONS 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 = 3400D2/3 for CO, and CT = 33.3D for the other air pollutants 

(where D = distance to shore in miles)?

X

Do your emission calculations include any emission reduction measures or modified 

emission factors?

X

Are your proposed exploration activities located east of 87.5° W longitude? X

Do you expect to encounter H2S at concentrations greater than 20 parts per million (ppm)? X

Do you propose to flare or vent natural gas for more than 48 continuous hours from any 

proposed well?

X

Do you propose to burn produced hydrocarbon liquids? X

There 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 

Amounts1

(tons) 

Calculated 

Exemption 

Amounts2

(tons) 

Calculated 

Complex Total 

Emission 

Amounts3

(tons)

Carbon Monoxide (CO) 1125.11 3030.30 1125.11

Particular matter (PM) 63.74 3030.30 63.74

Sulphur dioxide (SO2) 292.48 3030.30 292.48

Nitrogen oxides (NOx) 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 SPILLS INFORMATION

All the proposed activities and facilities in this 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 RESPONSE SITES

Primary Response Equipment Location Preplanned Staging Location

Houma, LA

Harvey, LA

Leeville, LA

Houma, LA

Harvey, LA

Leeville, LA

Fourchon, LA

(C) OSRO INFORMATION

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) WORST-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 GC237 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

Storage tanks & flowlines

Lease term pipelines

Uncontrolled blowout

Total Volume (bbls)

212,891

212,891

212,891

212,891

43,280

43,280

225 

12,450

12,675

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)
* The 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 appropriate 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 worstcase 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 available 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 beaches, 

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 practicable. 

A description of the response equipment under contract to contain and recover the Worst Case 

Discharge is shown in Figure 2.

Using the estimated chemical and physical characteristics of crude oil, an ADIOS weathering 

model was run on a similar product from the ADIOS oil database. The results indicate 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)
Spill 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 estimates 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-situ 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 aircraft would provide a 

daily dispersant capability of 7,540 barrels. If the conditions are favorable for in-situ burning, the 

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

may be attempted. 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 

associated 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 barges, an 

80,000 barrel storage barge, and an 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/skimming attempts. 

If the spill went unabated, shoreline impact in Cameron Parish, Louisiana would depend upon 

existing environmental conditions. Shoreline protection would include the use of CGA’s near 

shore and shallow water skimmers with a totaled derated skimming capacity of 54,753 barrels. 

Temporary storage associated with skimming equipment equals 1,761 barrels. If additional 

storage is needed, three 20,000 barrel storage barges may be mobilized and centrally located to 

provide temporary storage allowing the skimmers to stay in the area of operations as much as 

possible. Onshore response may include the deployment of shoreline boom on beach areas, or 

protection and sorbent boom on vegetated areas. A 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 potential 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 strategies for this area, and it describes necessary action to keep the oil spill 

from entering Louisiana’s coastal wetlands, based on the assumption that removal of the released 

oil will be much easier and less damaging to fragile coastal ecosystems if done in the open 

waters of the Gulf of Mexico. Supervisory personnel have the option to modify the deployment 

and operation of equipment allowing a more effective response to site-specific circumstances.

ERT’s contract Spill Management Team holds a copy of the State of Louisiana Initial Oil Spill 

Response Plan.

Based on the anticipated worst case discharge scenario, ERT can be onsite with contracted oil 

spill recovery equipment with adequate response capacity to contain and recover surface 

hydrocarbons, and prevent land impact, to the maximum extent practicable, within an estimated 

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). 

Initial Response Considerations

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

be limited to:

• Weather

• Equipment and materials availability

• Ocean currents and tides

• Location of the spill

• Product spilled

• Amount spilled

• Environmental risk assessments

• Trajectory and product analysis

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

ERT will take action to provide a safe, aggressive response to contain and recover as much of the 

spilled oil as quickly as it is safe to do so. In an effort to protect the environment, response 

actions will be designed to provide an “in-depth” protection strategy meant to recover as much 

oil as possible as far from environmentally sensitive areas as possible. Safety will take 

precedence over all other considerations during these operations. 

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

• 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 observer to provide on site status reports

• Provide command and control platform at the site if needed

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

and visual confirmation 

• Continual monitoring of vessel assets using vessel monitoring systems 

Dispersant application assets

• Put ASI on standby

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

• 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 highest concentration of oil

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

CGA HOSS Barge

• Use in areas with heaviest oil concentrations

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

Energy Resource Technology GOM, Inc. Page I-5

Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS-G 15563)
CGA 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 with the FOSC and 

affected SOSC

• Determine availability of fire boom and selected ignition systems

• Start ordering fire boom stocks required for expected operations

• Contact boom manufacturer to provide training if required

• Determine assets to perform on water operation

• Build operations into safety plan

• Conduct operations in accordance with an approved plan

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 

Energy Resource Technology GOM, Inc. Page I-6

Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS-G 15563)
Considerations

• Water depth, vessel draft

• Shoreline gradient

• State of the oil 

• Use of VOOs

• Distance of surf zone from shoreline 

Equipment Deployment

Surveillance

• Provide trained observer to direct skimming operations

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

and visual confirmation 

• Continual 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 Deployment

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 availability

Energy Resource Technology GOM, Inc. Page I-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

• Shoreline Cleanup and Assessment Team Reports and recommendations

• Determination of Archeological sites and gaining authority to enter 

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

• Pre cleaning of beaches by moving waste above high 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 of weather and oil movement for resource redeployment as necessary 

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

• Passive clean up of marshes should considered and appropriate stocks of sorbent boom 

and/or sweep obtained

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

inland areas 

Decanting Strategy

Recovered oil and water mixtures will typically separate into distinct phases when left in a 

quiescent state. When separation occurs, the relatively clean water phase can be siphoned or 

decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases 

the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval 

will be requested prior to decanting operations. This practice is routinely used for oil spill 

recovery.

Energy Resource Technology GOM, Inc. Page I-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 operations. Skimming equipment listed below may have operational 

limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil 

spill response, vessel skimming operations ceased when seas reached 5-6 feet and vessels were 

often recalled to port when those conditions were exceeded. Systems below are some of the 

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

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) hurricane days occurring then. Maximum activity is in early to mid 

September. Once in a few years there may be a hurricane occurring "out of season" - primarily in

May or December. Globally, September is the most active month and May is the least active n

month.

Energy Resource Technology GOM, Inc. Page I-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 

Resource

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 Harvey 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

Energy Resource Technology GOM, Inc. Page I-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

CGA

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

Energy Resource Technology GOM, Inc. Page I-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’ FRV 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’ FRV 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

Enterprise 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

Staging Area: Cameron

Nearshore and Inland 

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

Hrs to 

Load 

Out

Travel to 

Staging

Travel to 

Deployment 

Site

Hrs to 

Deploy

Total 

Hrs

CGA

SWS Egmopol 3000 100 NA 3 Galveston 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) MONITORING SYSTEMS

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

activities.

(B) INCIDENTAL TAKES

There is no reason to believe that any of the endangered species or marine mammals as listed in 

the ESA will be “taken” as a result of the operations proposed under this plan. 

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 the 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 Measures 

and Protected Species Observer Program”

(C) FLOWER 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

Development activities are subject to the following stipulation(s) attached to Lease OCS-G 

15563, Green Canyon Block 237. 

. 

Marine Protected Species

Lease 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 prominent places on all vessels and platforms used as a result of activities 

related to exploration, development, and production of this lease detailing the reasons (legal and 

ecological) why release of debris must be eliminated; 

(c) observe for marine mammals and sea turtles while on vessels, reduce vessel speed to 10 knots 

or less when assemblages of cetaceans are observed, and maintain a distance of 90 meters or 

greater from whales, and a distance of 45 meters or greater from small cetaceans and sea turtles; 

(d) employ mitigation measures prescribed by BOEM/BSEE or the National Marine Fisheries 

Service (NMFS) for all seismic surveys, including the use of an “exclusion zone” based upon the 

appropriate water depth, ramp-up and shutdown procedures, visual monitoring, and reporting; 

(e) identify important habitats, including designated critical habitat, used by listed species (e.g., 

sea turtle nesting beaches, piping plover critical habitat), in oil spill contingency planning and 

require the strategic placement of spill cleanup equipment to be used only by personnel trained in 

less-intrusive cleanup techniques on beaches and bay shores; and 

(f) immediately report all sightings and locations of injured or dead protected species (e.g., 

marine mammals and sea turtles) to the appropriate stranding network. If oil and gas industry 

activity is responsible for the injured or dead animal (e.g., because of a vessel strike), the 

responsible parties should remain available to assist the stranding network. If the injury or death 

was caused by a collision with the lessee’s vessel, the lessee must notify BOEM within 24 hours 

of the strike. 

BOEM and BSEE issue Notices to Lessees (NTLs), which more fully describe measures 

implemented in support of the above-mentioned implementing statutes and regulations, as well 

as measures identified by the U.S. Fish and Wildlife Service and NMFS arising from, among 

others, conservation recommendations, rulemakings pursuant to the MMPA, or consultation. The 

lessee and its operators, personnel, and subcontractors, while undertaking activities authorized 

under this lease, must implement and comply with the specific mitigation measures outlined in 

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

Reporting;” NTL No. 2012-JOINT-G02, “Implementation of Seismic Survey Mitigation 

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 this paragraph. The lessee and its operators, 

personnel, and subcontractors will be required to comply with the mitigation measures, identified 

in the above referenced NTLs, and additional measures in the conditions of approvals for their 

plans or permits.

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-G01, “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 GOM, Inc. Page L-1

Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS-G 15563)
APPENDIX M

RELATED FACILITIES AND 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 connection at the manifold. The 4.5" bulk 

oil pipeline will be approximately 9500ft in length. The well PLET will connect to the tree with 

a 6.625” x .864” X65 rigid M shaped jumper. The 6.625" jumper will be approximately 80ft in 

length. The design capacity of the pipelines is 10,000 BPD. The SITP is approximately 8000

psig. The shut-in time for the pipelines 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) TRANSPORTATION 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 207 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 proposed 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

There 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) SOLID 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 traveling 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)
APPENDIX O

ONSHORE SUPPORT FACILITIES INFORMATION

(A) GENERAL

Name of Shorebase Location Existing/New/Modified

Martin Terminal North Fourchon, LA Existing

(B) SUPPORT BASE CONSTRUCTION OR EXPANSION

There will be no new construction of an onshore support base, nor will we expand the existing 

shorebase as a result of the operations proposed in this Exploration Plan.

(C) SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE

There will be no new construction of an onshore support base, nor will we expand the existing 

shorebase as a result of the operations proposed in this Exploration Plan.

(D) WASTE 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 

COASTAL ZONE MANAGEMENT (CZMA) INFORMATION

Relevant 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) IMPACT PRODUCING FACTORS

ENVIRONMENTAL IMPACT ANALYSIS WORKSHEET

Environment

Resources

Impact Producing Factors (IPFs)

Categories and Examples

Refer to recent GOM OCS Lease Sale EIS for a more complete list of IPFs

Emissions 

(air, noise, 

light, etc.)

Effluents 

(muds, 

cutting, other 

discharges to 

the water 

column or 

seafloor)

Physical 

disturbances to the 

seafloor (rig or 

anchor 

emplacements, 

etc.)

Wastes sent 

to shore for 

treatment 

or disposal

Accidents 

(e.g., oil 

spills, 

chemical 

spills, H2S 

releases)

Discarded

Trash &

Debris

Site-specific at Offshore 

Location

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

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

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

Benthic communities (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 Stetson Bank;

o 1000-m, 1-mile or 3-mile zone of any topographic feature (submarine bank) protected by the 

Topographic Features Stipulation attached to an OCS lease;

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

o Proximity of any submarine bank (500 ft. buffer zone) with relief greater than 2 meters that is not 

protected by the Topographic Features Stipulation attached to an OCS lease.

2) Activities with any bottom disturbance within an OCS lease block protected through the Live Bottom 

(Pinnacle Trend) Stipulation attached to an OCS lease.

3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom 

(Low-Relief) Stipulation attached to an OCS lease.

4) Activities on blocks designated by the BOEM as being in water depths 300 meters or greater.

5) Exploration or production activities where H2S concentrations greater than 500 ppm might be encountered.

6) All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that you 

determine would impact these environmental resources. If the proposed action is located a sufficient 

distance from a resource that no impact would occur, the EIA can note that in a sentence or two.

7) All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block 

designated by the BOEM as having high-probability for the occurrence of shipwrecks or prehistoric sites, 

including such blocks that will be affected that are adjacent to the lease block in which your planned activity 

will occur. If the proposed activities are located a sufficient distance from a shipwreck or a prehistoric site 

that no impact would occur, the EIA can note that in a sentence or two.

8) All activities that you determine might have an adverse effect on endangered or threatened marine mammals 

or sea turtles or their critical habitats.

9) Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges.

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 effluents, and accidents. 

Effluents: Green Canyon Block 237 is 164 miles from the closest designated Topographic Features 

Stipulation Block (Ewing-1 Bank); therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed 

activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to benthic organisms 

only if the oil contacts the organisms. Oil from a surface spill can be driven into the water column; 

measurable amounts have been documented down to a 10 m depth. At this depth, the oil is found only 

at concentrations several orders of magnitude lower than the amount shown to have an effect on corals. 

Because the crests of topographic features in the Northern Gulf of Mexico are found below 10 m, no 

oil from a surface spill could reach their sessile biota. Oil from a subsurface spill is not applicable due 

to the distance of these blocks from a topographic area. The activities proposed in this plan will be 

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

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

shore for disposal) from the proposed activities, which could impact topographic features. 

2. Pinnacle Trend Area Live Bottoms

Potential IPFs on pinnacle trend area live bottoms include effluents and accidents. 

Effluents: Green Canyon Block 237 is 189 miles from the closest live bottom (pinnacle trend) area; 

therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed 

activities (refer to statistics in Item 5, Water Quality). Oil spills have the potential to foul benthic 

communities and cause lethal and sublethal effects on live bottom organisms. Oil from a surface spill 

can be driven into the water column; measurable amounts have been documented down to a 10 m 

depth. At this depth, the oil is found only at concentrations several orders of magnitude lower than the 

amount shown to have an effect on marine organisms. Oil from a subsurface spill is not applicable due 

to the distance of these blocks from a live bottom (pinnacle trend) area. The activities proposed in this 

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

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

shore for disposal) from the proposed activities which could 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; therefore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the proposed 

activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to live bottom 

organisms only if the oil contacts the organisms. Oil from a surface spill can be driven into the water 

column; measurable amounts have been documented down to a 10 m depth. At this depth, the oil is 

found only at concentrations several orders of magnitude lower than the amount shown to have an 

effect on marine invertebrates. Oil from a subsurface spill is not applicable due to the distance of these 

blocks from a live bottom area. The activities proposed in this plan will be covered by ERT’s Regional 

OSRP (refer to information submitted in Appendix I). 

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

shore for disposal) from the proposed activities which could impact an Eastern Gulf live bottom area. 

4. Benthic Communities 

There are no IPFs (including emissions, physical disturbances to the seafloor, wastes sent to shore for 

disposal, or accidents) from the proposed activities that could cause impacts to benthic communities.

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 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 effects. Operational discharges 

are not expected to cause significant adverse impacts to water quality.

Accidents: Oil spills have the potential to alter offshore water quality; however, it is unlikely that an 

accidental surface or subsurface spill would occur from the proposed activities. Between 1980 and 

2000, OCS operations produced 4.7 billion barrels of oil and spilled only 0.001 percent of this oil, or 1 

bbl for every 81,000 bbl produced. The spill risk related to a diesel spill from drilling operations is 

even less. Between 1976 and 1985, (years for which data were collected), there were 80 reported 

diesel spills greater than one barrel associated with drilling activities. Considering that there were 

11,944 wells drilled, this is a 0.7 percent probability of an occurrence. If a spill were to occur, the 

water quality of marine waters would be temporarily affected by the dissolved components and small 

oil droplets. Dispersion by currents and microbial degradation would remove the oil from the water 

column and dilute the constituents to background levels. Historically, changes in offshore water quality 

from oil spills have only been detected during the life of the spill and up to several months afterwards. 

Most of the components of oil are insoluble in water and therefore float. The activities proposed in this 

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).

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

shore for disposal) from the proposed activities which could cause impacts to water quality. 

6. Fisheries

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

Block 237 include effluents and accidents. 

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

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

and the water column can occur out to several hundred meters down-current from the discharge point. 

Offshore discharges are expected to disperse and dilute to very near background levels in the water 

column or on the seafloor within 3,000 m of the discharge point, and are expected to have negligible 

effect on fisheries.

Accidents: An accidental oil spill has the potential to cause some detrimental effects on fisheries; 

however, it is unlikely that such an event would occur from the proposed activities (refer to Item 5, 

Water Quality). The effects of oil on mobile adult finfish or shellfish would likely be sublethal and the 

extent of damage would be reduced to the capacity of adult fish and shellfish to avoid the spill, to 

metabolize hydrocarbons, and to excrete both metabolites and parent compounds. The activities 

proposed in this plan will be covered by ERT’s Regional OSRP (refer to information submitted in 

Appendix I). 

There are no IPFs from emissions, physical disturbances to the seafloor or wastes sent to shore for 

disposal from the proposed activities which could cause impacts to fisheries.

7. Marine Mammals

GulfCet II studies revealed that cetaceans of the continental shelf and shelf-edge were almost 

exclusively bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and pygmy 

killer whale, Risso’s dolphin, rough-toothed dolphin, and Cuvier’s beaked whale, occurred most 

frequently along the upper slope in areas outside of anticyclones. IPFs that could cause impacts to 

marine mammals as a result of the proposed operations in Green Canyon Block 237 include emissions, 

effluents, discarded trash and debris, and accidents. 

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

from marine mammals. This reaction may lead to disruption of marine mammals’ normal activities. 

Stress may make them more vulnerable to parasites, disease, environmental contaminants, and/or 

predation (Majors and Myrick, 1990). There is little conclusive evidence for long-term displacements 

and population trends for marine mammals relative to noise. 

Effluents: Drilling fluids and cuttings discharges contain components which may be detrimental to 

marine mammals. Most operational discharges are diluted and dispersed upon release. Any potential 

impact from drilling fluids would be indirect, either as a result of impacts on prey items or possibly 

through ingestion in the food chain (API, 1989). 

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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 have caused the death or 

serious injury of marine mammals (Laist, 1997; MMC, 1999). The limited amount of marine debris, if 

any, resulting from the proposed activities is not expected to substantially harm marine mammals. 

Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and 

the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies 

including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA).

ERT will operate in accordance with the regulations and also avoid accidental loss of solid waste items 

by maintaining waste management plans, manifesting trash sent to shore, and using special precautions 

such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be 

exercised when handling and disposing of small items and packaging materials, particularly those 

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

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

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from ERT management 

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

in accordance with NTL No. 2012-G01.

Accidents: Collisions between support vessels and cetaceans would be unusual events, however 

should one occur, death or injury to marine mammals is possible. Contract vessel operators can avoid 

marine mammals and reduce potential deaths by maintaining a vigilant watch for marine mammals and 

maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to help 

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

encountered in the Gulf of Mexico OCS. Vessel crews must report sightings of any injured or dead 

protected marine mammal species immediately, regardless of whether the injury or death is caused by 

their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS 

Southeast Regional Office at (727) 824-5312, or the Marine Mammal Stranding Network at (305) 862-

2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM 

must be notified within 24 hours of the strike by email to protectedspecies@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 the area, 

which could add to changes in cetacean behavior and/or distribution, thereby causing additional stress 

to the animals. The effect of oil dispersants on cetaceans is not known. The acute toxicity of oil 

dispersant chemicals included in 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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There are no other IPFs (including physical disturbances to the seafloor) from the proposed activities 

which could impact marine mammals.

8. Sea Turtles

IPFs that could cause impacts to sea turtles as a result of the proposed operations include emissions, 

effluents, discarded trash and debris, and accidents. GulfCet II studies sighted most loggerhead, 

Kemp’s ridley and leatherback sea turtles over shelf waters. Historically these species have been 

sighted up to the shelf’s edge. They appear to be more abundant east of the Mississippi River than 

they are west of the river (Fritts et al., 1983b; Lohoefener et al., 1990). Deep waters may be used by all 

species as a transitory habitat.

Emissions: Noise from drilling activities, support vessels, and helicopters may elicit a startle reaction 

from sea turtles, but this is a temporary disturbance.

Effluents: Drilling fluids and cuttings discharges are not known to be lethal to sea turtles. Most 

operational discharges are diluted and dispersed upon release. Any potential impact from drilling 

fluids would be indirect, either as a result of impacts on prey items or possibly through ingestion in the 

food chain (API, 1989). 

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

serious injury of sea turtles (Balazs, 1985). The limited amount of marine debris, if any, resulting from 

the proposed activities is not expected to substantially harm sea turtles. Operators are prohibited from 

deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution 

Research and Control Act, and regulations imposed by various agencies including the United States 

Coast Guard (USCG) and the Environmental Protection Agency (EPA). ERT will operate in 

accordance with the regulations and also avoid accidental loss of solid waste items by maintaining 

waste management plans, manifesting trash sent to shore, and using special precautions such as 

covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised 

when handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass.

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

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from ERT management 

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

in accordance with NTL No. 2012-G01. 

Accidents: Collisions between support vessels and sea turtles would be unusual events, however 

should one occur, death or injury to sea turtles is possible. Contract vessel operators can avoid sea 

turtles and reduce potential deaths by 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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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. 

All sea turtle species and their life stages are vulnerable to the harmful effects of oil through direct 

contact or by fouling of their food. Exposure to oil can be fatal, particularly to juveniles and hatchlings. 

However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to 

Item 5, Water Quality). Oil spill response activities may increase vessel traffic in the area, which could 

add to the possibility of collisions with sea turtles. The activities proposed in this plan will be covered 

by ERT’s Regional Oil Spill Response Plan (refer to information submitted in accordance with 

Appendix I).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed activities 

which could impact sea turtles.

9. Air Quality

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 mile) 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. 

Accidents and blowouts can release hydrocarbons or chemicals, which could cause the emission of air 

pollutants. However, these releases would not impact onshore air quality because of the prevailing 

atmospheric conditions, emission height, emission rates, and the distance of Green Canyon Block 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. 

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 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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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 marine 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 will contact the BOEM immediately and make every reasonable effort to preserve 

and protect that cultural resource.

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or disposal, 

or accidents) from the proposed activities 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 the 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 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 

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 resources. Copies of the certifications and a circle radius plat of the 

survey area will be submitted to the BOEM. Should a resource be encountered, 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 treatment or disposal, 

or accidents) from the proposed activities which could impact prehistoric archeological sites.

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Green Canyon Block 237 (OCS-G 15563)
Vicinity of Offshore Location

1. Essential Fish Habitat (EFH)

IPFs that could cause impacts to EFH as a result of the proposed operations in Green Canyon Block 

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

Gulf of Mexico. 

Effluents: The Live Bottom Low Relief Stipulation, the Live Bottom (Pinnacle Trend) Stipulation, 

and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential impacts on livebottom communities and EFH from operational waste discharges. Levels of contaminants in drilling 

muds and cuttings and produced-water discharges, discharge-rate restrictions, and monitoring and 

toxicity testing are regulated by the EPA NPDES permit, thereby eliminating many significant 

biological or ecological effects. Operational discharges are not expected to cause significant adverse 

impacts to EFH.

Accidents: An accidental oil spill has the potential to cause some detrimental effects on EFH. Oil 

spills that contact coastal bays and estuaries, as well as OCS waters when pelagic eggs and larvae are 

present, have the greatest potential to affect fisheries. However, it is unlikely that an oil spill would 

occur from the proposed activities (refer to Item 5, Water Quality). The activities proposed in this plan 

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

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

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

2. Marine and Pelagic Birds

IPFs that could impact marine birds as a result of the proposed activities include air emissions, 

accidental oil spills, and discarded trash and debris from vessels and the facilities.

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

concentrations which could harm coastal and marine birds. 

Accidents: An oil spill would cause localized, low-level petroleum hydrocarbon contamination. 

However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, 

Water Quality). Marine and pelagic birds feeding at the spill location may experience chronic, 

nonfatal, physiological stress. It is expected that few, if any, coastal and marine birds would actually 

be affected to that extent. The activities proposed in this plan will be covered by ERT’s Regional 

OSRP (refer to information submitted in Appendix I).

Discarded trash and debris: Marine and pelagic birds could become entangled and snared in 

discarded trash and debris, or ingest small plastic debris, which can cause permanent injuries and 

death. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex 

V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various 

agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency 

(EPA). 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 

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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. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as plastic or 

glass. Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 

from ERT management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01. Debris, if any, from these 

proposed activities will seldom interact with marine and pelagic birds; therefore, the effects will be 

negligible.

There are no other IPFs (including effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities which could impact marine and pelagic 

birds.

3. Public Health and Safety Due to Accidents.

There are no IPFs (emissions, effluents, physical disturbances to the seafloor, wastes sent to shore for 

treatment or disposal or accidents, including an accidental H2S 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 activities be classified by BSEE as H2S absent. 

Coastal and Onshore

1. Beaches

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

discarded trash and debris. 

Accidents: Oil spills contacting beaches would 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 

plan 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 including the United States Coast Guard (USCG) and the Environmental 

Protection Agency (EPA). ERT will operate in accordance with the regulations and also avoid 

accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to 

shore, and using special precautions such as covering outside trash bins to prevent accidental loss of 

solid waste. Special caution will be exercised when handling and disposing of small items and 

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Supplemental Development Operations Coordination Document January 22, 2015

Green Canyon Block 237 (OCS-G 15563)
packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass. 

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

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from ERT management 

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

in accordance with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities which could impact beaches. 

2. Wetlands

IPFs from the proposed activities that could cause impacts to wetlands include accidents (oil spills) and 

discarded trash and debris. 

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

Water Quality). Due to the distance from shore (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). 

Discarded trash and debris: There will only be a limited amount of marine debris, if any, resulting 

from the proposed activities. Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and the 

Environmental Protection Agency (EPA). ERT will operate in accordance with the regulations and also 

avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash 

sent to shore, and using special precautions such as covering outside trash bins to prevent accidental 

loss of solid waste. Special caution will be exercised when handling and disposing of small items and 

packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass. 

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

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from ERT management 

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

in accordance with NTL No. 2012-G01. 

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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 disposal) from the proposed activities which could impact wetlands.

3. Shore Birds and Coastal Nesting Birds

Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. However, it is 

unlikely that an oil spill would occur from the proposed activities (refer to Item 5, Water Quality). 

Given the distance from shore (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). 

Discarded trash and debris: Coastal and marine birds are highly susceptible to entanglement in 

floating, submerged, and beached marine debris: specifically plastics. Operators are prohibited from 

deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution 

Research and Control Act, and regulations imposed by various agencies including the United States 

Coast Guard (USCG) and the Environmental Protection Agency (EPA). ERT will operate in 

accordance with the regulations and also avoid accidental loss of solid waste items by maintaining 

waste management plans, manifesting trash sent to shore, and using special precautions such as 

covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised 

when handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 

from ERT management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities that could cause impacts to shore birds 

and coastal nesting birds.

4. Coastal Wildlife Refuges

Accidents: An accidental oil spill from the proposed activities could cause impacts to coastal wildlife 

refuges. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 

5, Water Quality). Due to the distance from shore (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).

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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 waste management plans, manifesting 

trash sent to shore, and using special precautions such as covering outside trash bins to prevent 

accidental loss of solid waste. Special caution will be exercised when handling and disposing of small 

items and packaging materials, particularly those made of non-biodegradable, environmentally 

persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 

from ERT management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities that could cause impacts to coastal 

wildlife refuges.

5. Wilderness Areas

Accidents: An accidental oil spill from the proposed activities could cause impacts to wilderness 

areas. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, 

Water Quality). Due to the distance from the nearest designated Wilderness Area (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 

regulations imposed by various agencies including the United States Coast Guard (USCG) and the 

Environmental Protection Agency (EPA). ERT will operate in accordance with the regulations and 

also avoid accidental loss of solid waste items by maintaining waste management plans, manifesting 

trash sent to shore, and using special precautions such as covering outside trash bins to prevent 

accidental loss of solid waste. Special caution will be exercised when handling and disposing of small 

items and packaging materials, particularly those made of non-biodegradable, environmentally 

persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

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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” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 

from ERT management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01. 

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities that could cause impacts to wilderness 

areas.

6. Other Environmental Resources Identified

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

(C) IMPACTS ON PROPOSED ACTIVITIES

The site–specific environmental conditions have been taken into account for the proposed activities. 

No impacts are expected on the proposed activities from site-specific environmental conditions. 

(D) ENVIRONMENTAL HAZARDS 

During the hurricane season, June through November, the Gulf of Mexico is impacted by an average of 

ten tropical storms (39-73 mph winds), of which six become hurricanes ( > 74 mph winds). Due to 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 (including 

hydrocarbons). Additionally, the displacement of equipment may disrupt the local benthic habitat and 

pose a threat to local species.

The following preventative measures included in this plan may be implemented to mitigate these 

impacts:

1. Drilling & completion

a. Secure well

b. Secure rig / platform

c. Evacuate personnel

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

N10. 

2. Platform / Strucure Installation

Operator will not conduct platform / structure installation operations during Tropical

Storm or Hurricane threat.

3. Pipeline Installation

Operator will not conduct pipeline installation operations during Tropical Storm or

Hurricane threat.

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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 

Houston, TX 77084 

(281) 578-3388 

Evan.connolly@jccteam.com 

(I) REFERENCES

Authors: 

American Petroleum Institute (API). 1989. Effects of offshore petroleum operations on cold water 

marine mammals: a literature review. Washington, DC: American Petroleum Institute. 385 pp. 

Balazs, G.H. 1985. Impact of ocean debris on marine turtles: entanglement and ingestion. In: Shomura, 

R.S. and H.O. Yoshida, eds. Proceedings, Workshop on the Fate and Impact of Marine Debris, 26-

29 November 1984, Honolulu, HI. U.S. Dept. of Commerce. NOAA Tech. Memo. NOAA-TMNMFS-SWFC-54. Pp 387-429. 

Burke, C.J. and J.A. Veil. 1995. Potential benefits from regulatory consideration of synthetic drilling 

muds. Environmental Assessment Division, Argonne National Laboratory, ANL/EAD/TM-43. 

Daly, J.M. 1997. Controlling the discharge of synthetic-based drilling fluid contaminated cuttings in 

waters of the United States. U.S. Environmental Protection Agency, Office of Water. Work Plan, 

June 24, 1997. 

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

of the Interior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLM-YK-ES-81-

006-1792. 

Laist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris including a 

comprehensive list of species with entanglement and ingestion records. In: Coe, J.M. and D.B. 

Rogers, eds. Marine debris: sources, impacts, and solutions. New York, NY: Springer-Verlag. Pp. 

99-139. 

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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 Congress – 1998.

Piatt, J.F., C.J. Lensink, W. Butler, M. Kendziorek, and D.R. Nysewander. 1990. Immediate impact 

of the Exxon Valdez oil spill on marine birds. The Auk. 107 (2): 387-397

Vauk , G., E. Hartwig, B. Reineking, and E. Vauk-Hentzelt. 1989. Losses of seabirds by oil pollution 

at the German North Sea coast. Topics in Marine Biology. Ros, J.D, ed. Scient. Mar. 53 (2-

3): 749-754.

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

Field-Naturalist. 89:278-298.

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

• Hazard Surveys

• BOEM EIS’s:

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

GOM Central and Western Planning Areas Sales 166 and 168 Final Environmental 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) EXEMPTED INFORMATION DESCRIPTION

The proposed bottom-hole location of the planned well has been removed from the public information 

copy of the DOCD as well as any discussions of the target objectives, geologic or geophysical data, 

and any interpreted geology.

(B) BIBLIOGRAPHY

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)
Attachment A
U.S. Department of the Interior OMB Control Number: 1010-0151

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

OCS PLAN INFORMATION FORM

General Information

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

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

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

 Houston, Texas 77002 Phone Number: 713-705-8020 

Email Address: cathy.thornton@jccteam.com

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $4238 Receipt No. 25JE9SJO

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 Sulphur Salt Onshore Support Base(s): Fourchon, LA

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

Distance to Closest Land (Miles): 91 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 use a vessel with anchors to install or modify a structure? Yes X No

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

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

Proposed Activity Start Date End Date No. of Days

Exploration drilling

Development drilling and completion

Well completion 06/01/2015 08/09/2015 70

Well test flaring (for more than 48-hours)

Installation or modification of structure

Installation 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 Description of Structure

Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform Rig Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed tower

X DP Semisubmersible Other (attach description) Floating production

system

Other (Attach Description)

Drilling Rig Name (if known):

Description of Lease Term Pipelines

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

MM2 well (Well Jumper) MM2 PLET 6.625" 80''

MM2 PLET (MM2 Flowline) #003 well PLET 4.5" 9500'

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

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

Include one copy of this page for each proposed well/structure

Proposed Well/Structure Location

Well or Structure Name / Number (if renaming well 

or structure, reference previous name) 

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 For wells, volume of uncontrolled 

blowout (Bbls/day) 212,891

For structures, volume of all storage 

and pipelines (Bbls)

API Gravity of 

fluid 33°

Surface Location Bottom-Hole Location (For Wells) Completion (For multiple 

completions, enter separate lines)

Lease No. OCS-G 15563

Area Name GC

Block No. 237

Block Line 

Departures 

(in feet)

N/S Departure: 788’ FNL N/S Departure: N/S Departure: F____L

N/S Departure: F____L

N/S Departure: F____L

E/W Departure: 5965’ FEL E/W Departure: E/W Departure: F____L

E/W Departure: F____L

E/W Departure: F____L

Lambert X-Y 

coordinates

X: 2,259,155.00’ X: X:

X:

X:

Y: 10,073,452.00’ Y: Y:

Y:

Y:

Latitude / 

Longitude

Latitude: 27° 44'46.655"N Latitude: Latitude:

Latitude:

Latitude:

Longitude: 91° 05' 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):

Anchor Radius (if applicable) in feet: TVD (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 4

Bathymetric 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 

JOB No: REVISED: DATE:

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
Your 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: Suite 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 
Attachment B

Previously reviewed and found acceptable under 

Revised DOCD (R-5300)
Attachment C






JOB No: REVISED: DATE:

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 zone
JOB No: REVISED: DATE:

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

NUM. DESCRIPTION X COORDINATE Y COORDINATE

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 well
JOB No: REVISED: DATE:

FILENAME:

141454 Jan. 7, 2015

PLAN VIEW

NADCON version 2.1 utilized for WGS84-NAD27 conversions. 120000 115000 110000 105000 100000 95000 90000 85000 80000 75000 70000 65000 60000 55000 50000 45000 40000 35000 30000 25000 20000 15000 10000 5000 0 -5000 -10000 6.00 5.75 5.50 5.25 5.00 4.75 4.50 4.25 4.00 3.75 3.50 3.25 3.00 2.75 2.50 2.25 2.00 1.75 1.50 1.25 1.00 0.75 0.50 0.25 0.00 -0.25 -0.50 -0.75 -1.00 -1.25 

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 well CGG Data WesternGeco Data
JOB No: REVISED: DATE:

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 well
JOB No: REVISED: DATE:

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 >20_ 19 18 17 16 15 14 13 12 11 10 9 8 7 6 5 4 3 2 1 0 

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 well
Bathymetric 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 

JOB No: REVISED: DATE:

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
Attachment H
DOCD 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 15
AIR 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

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

Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 3.4-1 10/96

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 % weight
AIR 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 CONTACT PHONE 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

PIPELINE 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

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

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 RECIP.<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

GLYCOL 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

91.0
AIR 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
Attachment N
Viosca 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

--<

(")

--:::s

~.;Ld rIe'S P-l/N _.. I ~? T

"'C Area ofInterest _

Green Canyon Area

Blocrt1~67