UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - N-09824

Type - Initial Exploration Plan

Lease(s) - OCS-G34441 Block - 521 Mississippi Canyon Area

Operator - Deep Gulf Energy II, LLC

Wells A and D

Not Found

Attached is a copy of the subject plan for public comments on issues that should be addressed in an Environmental Assessment.

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

Michelle Griffitt
Plan Coordinator Description -

Rig Type - Subject: From: October 1, 2014PUBLIC COPY July, 2014



## INITIAL EXPLORATION PLAN

Mississippi Canyon Block 521 OCS-G 34441 Barataria Prospect Affected State(s): Alab ama, Louisiana, Texas

Estimated Startup Date: January, 2015

SUBMITTED BY: Deep Gulf Energy II, LLC

738 Highway 6 South Suite 800 Houston, Texas 77079

Thomas E. Young

(281) 596-0933 tyoung@deepgulfenergy.com

AUTHORIZED REPRESENTATIVE: Kelley Pisciola J. Connor Consulting, Inc. 16225 Park Ten Place, Suite 700 Houston, Texas 77084 (281) 698-8519 kelley.pisciola@jccteam.comRecords of Changes – PUBLIC COPYN-9824, Initial EP, Deep Gulf Energy II, LLC, (OCS-G 34441, Mississippi Canyon Block 521)Date Section PageRemarks07/24/14 All All Plan received by BOEM.08/14/14 1 (1.4) Page 2 Updated Discrepancy on Storage Tanks and Production Vessels09/11/14 8 Pages 14-15 Updated to reflect review and acceptance of WCD calculations, and toreflect submittal of revision to Regional OSRP and update comparisontable.TOC Pg 1 of 3 TABLE OF CONTENTS

SECTION 1 PLAN CONTENTS ..................................................................................... 1

1.1 PLAN INFORMATION ............................................................................................ 1

1.2 LOCATION ............................................................................................................. 1

1.3 SAFETY AND POLLUTION PR EVENTION F EATURES ....................................... 1

1.4 STORAGE TANKS AND PRODUCTION VESSELS .............................................. 2

1.5 POLLUTION PREVEN TION MEASU RES ............................................................. 3

1.6 ADDITIONAL MEASURES .................................................................................... 3

1.7 COST RECO VERY FEE ........................................................................................ 3

SECTION 2 GENERAL INFORMATION ........................................................................ 4

2.1 APPLICATIONS A ND PERMIT S ........................................................................... 4

2.2 DRILLING FLUIDS ................................................................................................. 4

2.3 NEW OR UNUSUAL TECHNOLOGY .................................................................... 4

2.4 BONDING STATEMENT ........................................................................................ 4

2.5 OIL SPILL FINANCIAL RESP ONSIBILITY (OSFR) ............................................... 4

2.6 DEEPWATER WELL CO NTROL STAT EMENT .................................................... 5

2.7 BLOWOUT SCENARIO AND WORST CA SE DISCHARGE CALCULATIONS ..... 5

SECTION 3 GEOLOGICAL AND GEOPHYSICAL IN FORMATION ............................. 6

3.1 GEOLOGICAL D ESCRIPTION .............................................................................. 6

3.2 STRUCTURE CONTOUR MAP [PROPRIE TARY] ................................................ 6

3.3 INTERPRETED SEISMIC LI NE(S) [PROPR IETARY] ............................................ 6

3.4 GEOLOGICAL STRUCTURE CROSS- SECTIONS [PROPR IETARY] ................... 6

3.5 SHALLOW HAZA RDS REPO RT ........................................................................... 6

3.6 SHALLOW HAZARDS ASSESSM ENT .................................................................. 6

3.7 HIGH-RESOLUTION SEISMIC LINES [PROPR IETARY] ...................................... 6

3.8 STRATIGRAPHIC COLU MN [PROPRIE TARY] ..................................................... 6

3.9 TIME VERSUS DEPTH TABLES [PROPR IETARY] .............................................. 6

SECTION 4 HYDROGEN SU LFIDE INFORM ATION .................................................... 7TOC Pg 2 of 3 4.1 CONCENTRA TION ................................................................................................ 7

4.2 CLASSIFIC ATION ................................................................................................. 7

SECTION 5 BIOLOGICAL, PHYSICAL AN D SOCIOECONOMIC INFORMATION ...... 8

5.1 DEEPWATER BENTHI C COMMUNITI ES ............................................................. 8

5.2 TOPOGRAPHIC F EATURES (BAN KS) ................................................................. 8

5.3 TOPOGRAPHIC FEATURES ST ATEMENT (SHU NTING) .................................... 8
5.4 LIVE BOTTOMS (PINNACL E TREND FEAT URES) .............................................. 8
5.5 LIVE BOTTOMS (L OW RELIEF) ........................................................................... 8

5.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP ................................ 8

5.7 REMOTELY OPERATED VE HICLE (ROV) SURVEYS ......................................... 9

5.8 THREATENED AND ENDANGERED S PECIES, CRITICAL H ABITAT, AND
MARINE MAMMAL IN FORMATION ...................................................................... 9

5.9 ARCHAEOLOGICA L REPORT ............................................................................ 11

5.10 AIR AND WATER QUAL ITY INFORM ATION .................................................... 11

SECTION 6 WASTES AND DIS CHARGES INFO RMATION ...................................... 12

6.1 PROJECTED GENE RATED WAST ES ................................................................ 12

6.2 MODELING REPORT .......................................................................................... 12

SECTION 7 AIR EMISS IONS INFORM ATION ............................................................ 13

7.1 EMISSIONS WORKSHEETS A ND SCREENING QUESTIONS .......................... 13

7.2 SUMMARY IN FORMATION ................................................................................. 13

SECTION 8 OIL SPI LL INFORMAT ION ...................................................................... 14

8.1 OIL SPILL RESPON SE PLANNI NG .................................................................... 14

8.2 SPILL RESPON SE SITES ................................................................................... 14

8.3 OSRO INFO RMATION ........................................................................................ 14

8.4 WORST CASE SCENAR IO DETERMIN ATION ................................................... 14

8.5 OIL SPILL RESPON SE DISCUSS ION ................................................................ 15

SECTION 9 ENVIRONMENTAL MO NITORING INFO RMATION ................................ 16

9.1 MONITORING SYSTEMS .................................................................................... 16

9.2 INCIDENTAL TAKES ........................................................................................... 16

9.3 FLOWER GARDEN BANKS NAT IONAL MARINE SANCTUARY ....................... 16

SECTION 10 LEASE STIPUL ATIONS INFORM ATION .............................................. 17TOC Pg 3 of 3 10.1 MARINE PROTEC TED SPEC IES ..................................................................... 17

SECTION 11 ENVIRONMENTAL MITIGA TION MEASURES IN FORMATION ........... 19

11.1 MEASURES TAKEN TO AVOID, MI NIMIZE, AND MITIGATE IMPACTS .......... 19

11.2 INCIDENTAL TAKES ......................................................................................... 19

SECTION 12 SUPPORT VESSELS AN D AIRCRAFT INFO RMATION ...................... 20

12.1 GENE RAL .......................................................................................................... 20

12.2 DIESEL OIL SU PPLY VES SELS ....................................................................... 20

12.3 DRILLING FLUID TR ANSPORTAT ION ............................................................. 20

12.4 SOLID AND LIQUID W ASTE TRANSPOR TATION ........................................... 20

12.5 VICINITY MAP ................................................................................................... 20

SECTION 13 ONSHORE SUPPORT FACILITIES INFO RMATION ............................ 21

13.1 GENE RAL .......................................................................................................... 21

13.2 SUPPORT BASE CONSTRUCT ION OR EXPAN SION ..................................... 21

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE ................ 21

13.4 WASTE DI SPOSAL ........................................................................................... 21

SECTION 14 COASTAL ZONE MANAGEM ENT ACT (CZMA) INFORMATION ........ 22

SECTION 15 ENVIRONMEN TAL IMPACT ANALYSIS .............................................. 30

SECTION 16 ADMINISTRAT IVE INFORM ATION ....................................................... 31

16.1 EXEMPTED INFORMAT ION DESCRI PTION .................................................... 31

16.2 BIBLIOGR APHY ................................................................................................ 31Attachments Pg 1 of 1 SECTION ATTACHMENTS

Section 1 Plan Contents 1-A OCS Plan Information Form 1-B Well Location Plat 1-C Bathymetry Map 1-D Pay.gov Receipt Section 2 General Information 2-A Blowout Scenario Section 3 Geological, Geoph ysical Information 3-A Structure Contour Maps (Proprietary Copy Only) 3-B Interpreted Seismic Lines (Proprietary Copy Only) 3-C Geological Structure Cross Sections (Proprietary Copy Only) 3-D Shallow Hazard Assessment 3-E Stratigraphic Column (Proprietary Copy Only) 3-F Time Versus Depth Table (Proprietary Copy Only) Section 5 Biological, Physical and Socioeconomic Information 5-A Biologically Sens itive Underwater Feat ures and Areas Map Section 6 Wastes and Discharges Information 6-A Wastes You Will Gener ate, Treat and Downhole Dispose or Discharge to the GOM Section 7 Air Emissions Information 7-A Emissions Worksheets Section 8 Oil Spill Information 8-A Oil Spil l Response Discussion Section 12 Support Vessels an d Aircraft Information 12-A Waste You Will Tr ansport and/or Dispose Onshore 12-B Vicinity Map Section 14 Coastal Zone Management Act Information 14-A Coastal Zone Consistency Certification - Louisiana 14-B Coastal Zone Cons istency Certification - Texas 14-C Coastal Zone Consistency - Alabama Section 15 Environmental Impact Analysis (EIA) 15-A Environmental Impact Analysis (EIA)Deep Gulf Energy II, LLC Section 1 – Pg. 1 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 1
PLAN CONTENTS

1.1 PLAN INFORMATION Under this Exploration Plan, Deep Gulf E nergy II, LLC (“DGE II”) proposes to drill and complete one well, Location A (Location D is a mirror location of the A well and is included to provide an alternate well site should complications occur while drilling the planned A Location). The wells will be drill ed with a dynamically positioned semisubmersible drilling unit or a dynamically positioned dril lship, and are located in approximately 6,772 f eet of water.

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

.

1.2 LOCATION A Well Location Plat depicting the proposed surface and bottomhole locations of the proposed wells, measured depth/tr ue vertical depth and water depth for each location is
included as Attachment 1-B

.
No anchors are associated with the pr oposed activities in this plan.

A Bathymetry Map depicting the proposed su rface locations and water depth of each proposed well is included as Attachment 1-C

.

1.3 SAFETY AND POLLUTION PREVENTION FEATURES DGE II proposes to drill the wells with a dynamically positioned semi-submersible drilling unit or a dynamica lly positioned drillship which will be equipped with a Subsea BOP. Once a rig is cont racted, BOP information and sc hematics 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 (U SCG) 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 drilli ng unit will include we ll control, pollution prevention, and blowout prevention equi pment as described in BSEE regul ations 30 CFR 250 C, D, E, O, Q and S; and as further cl arified by BSEE Notices to Lessees, and current policy making invoked by the BSEE, Environmental Protection Agency and the U.S. Coast Guard (USCG).Deep Gulf Energy II, LLC Section 1 – Pg. 2 of 32 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) Pollution prevention measures include installation of curb s, 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 r eported to the representative in charge for immediate isolation and correcti on of the problem. An y spill will be reported to the appropriate governmental agencies.

1.4 STORAGE TANKS AND PRODUCTION VESSELS DP Semisubmersible and DP Drillship Type of Storage Tank Type of Facility Tank Capacity (bbls) Number of Tanks Total Capacity (bbls) Fluid Gravity (API) Fuel Oil (day/settling tanks) DP Semisubmersible 360/256/161 3 777 No.2 Diesel

Emergency Generator Fuel Oil DP Semisubmersible 31 1 31 No. 2 Diesel

Fuel Oil (port) DP Semisubmersible 4541/3396 2 7937 No. 2 Diesel Fuel Oil (stb) DP Semisubmersible 4541/3396 2 7937 No. 2 Diesel

Lube Oil DP Semisubmersible 116 1 116 26°

Waste Oil DP Semisubmersible 38/28 2 66 26°
Oily Water (port) DP Semisubmersible 186/178 2 364 N/A
Oily Water (stb) DP Semisubmersible 186/178 2 364 N/A

Fuel Oil (Marine Diesel) DP Drillship 901 4 3,604 0.35

Fuel Oil (Marine Diesel) DP Drillship 19,386. 8 2 38,773.6 0.35

Fuel Oil (Marine Diesel) DP Drillship 988 2 1,976 0.35

Fuel Oil (Marine Diesel) DP Drillship 4,400 1 4,400 0.35

Fuel Oil (Marine DP Drillship 1.26 4 5.04 0.35Deep Gulf Energy II, LLC Section 1 – Pg. 3 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) Diesel)

Fuel Oil (Marine Diesel) DP Drillship 1.58 1 1.58 0.35

Fuel Oil (Marine Diesel) DP Drillship 4.76 1 4.76 0.35

Fuel Oil (Marine Diesel) DP Drillship 225 2 450 0.35

Liquid Mud DP Dril lship 51.3 1 51.3 --

Drill Water DP Drillship 559 1 559 --

Potable Water DP Drillship 199.6 1 199.6 --

1.5 POLLUTION PREVENTION MEASURES These operations do not propose activities for wh ich the State of Florida is an affected

state.

1.6 ADDITIONAL MEASURES DGE II does not propose any additional safety, pollution pr evention, or early spill detection measures beyond those required by 30 CFR 250.

1.7 COST RECOVERY FEE Documentation of the $3, 673.00 cost recovery fee payment is included as Attachment 1-DU.S. Department of the Interior Bureau of Ocean Energy Management

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

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

Do you propose to use new or unusual technol ogy 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 f acility 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

Drill and Complete Well Location A 01/01/2015 04/30//2015 120

Drill and Complete Well Location D (Altern ate Well Location) 05/01/2015 08/28/2015 120

Description of Drilling Rig Description of Structure

Jackup X 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)

Form BOEM- 0137 (December 2011 – Supersedes all previ ous editions of this form which may not be used.) Page 1 of 4 General Information

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

Company Name: Deep Gulf Energy II, LLC BOEM Operator Number: 02985

Address: 738 Highway 6 South, Suite 800 Contact Person: Kelley Pisciola

Houston, Texas 77079 Phone Number: 281.698.8519

E-Mail Address: kelleypisciola@jccteam.com

If a service fee is required under 30 CFR 550.125(a), provide the Amount paid $3,673.00 Receipt No. Project and Worst Case Discharge (WCD) Information

Lease(s): G-34441 Area: Mississippi Cany on Block(s) 521 Project Name: Barataria

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

Platform / Well Name: A and D Total Volume of WCD: 2,336,430 bbls API Gravity: 29°

Distance to Closest Land (Miles): 65 Volume from uncontrolled blowout: 155,762 bbls/day OCS PLAN INFORMATION FORM OMB Control Number: 1010-0151 OMB Approval Expires: 12/31/14OCS PLAN INFORMATION FORM (CONTINUED) Include one copy of this page for each proposed well/structure
Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name): Location A 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 floa ting facility to conduct your proposed activities? X Yes No

WCD Info For wells, volume of uncontrolled blowout (Bbls/Day): 155,762 bbls/day For structures, volume of all storage and pipelines (Bbls): API Gravity of fluid 29°

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

Lease No. OCS-G 34441 OCS
OCS

Area Name Mississippi Canyon

Block No. 521

Blockline Departures (in feet) N/S Departure 7,193’ FSL N/S Departure F __ L N/S Departure F __ L N/S Departure F __ L

E/W Departure 3,620’ FWL E/W Departure F __ L E/W Departure F __ L E/W Departure F __ L

Lambert X-Y coordinates X: 1,270,820’ X:
X:
X:

Y: 10,334,873’ Y:
Y:
Y:

Latitude/ Longitude Latitude 28° 28’ 26.3452” Latitude
Latitude
Latitude

Longitude 88° 09’ 2.7459” Longitude Longitude Longitude

Water Depth (Feet): 6,768’ MD (Feet): TVD (Feet) MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet): Anchor Radius (if applicable) in feet: N/A
Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name or No. Area Block X Coordinate Y C oordinate Length of Anch or 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 previ ous editions of this form which may not be used.) Page 2 of 4OCS PLAN INFORMATION FORM (CONTINUED) Include one copy of this page for each proposed well/structure
Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name): D 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 floa ting facility to conduct your proposed activities? X Yes No

WCD Info For wells, volume of uncontrolled blowout (Bbls/Day): 155,762 bbls/day For structures, volume of all storage and pipelines (Bbls): API Gravity of fluid 29°

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

Lease No. OCS-G 34441 OCS
OCS

Area Name Mississippi Canyon

Block No. 521

Blockline Departures (in feet) N/S Departure 7,193’ FSL N/S Departure F __ L N/S Departure F __ L N/S Departure F __ L

E/W Departure 3,820’ FWL E/W Departure F __ L E/W Departure F __ L E/W Departure F __ L

Lambert X-Y coordinates X: 1,271,020’ X:
X:
X:

Y: 10,334,873’ Y:
Y:
Y:

Latitude/ Longitude Latitude 28° 28’ 26.3642” Latitude
Latitude
Latitude

Longitude 88° 09’ 00.5045” Longitude Longitude Longitude

Water Depth (Feet): 6,772’ MD (Feet): TVD (Feet): MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet): Anchor Radius (if applicable) in feet: N/A
Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name or No. Area Block X Coordinate Y C oordinate Length of Anch or 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 previ ous editions of this form which may not be used.) Page 2 of 4MC0521 Loc_A Loc_D

1267700 1272700 1277700 1282700 1033050 0 1033550 0 1034050 0

Deep Gulf Energy II, LLC

Barataria MC 521

Well Surface Locations

Base Map 0 6000 ft 2000 4000

Scale = 1:24000 1267700 1272700 1277700 1282700 X/Y: Feet

10330500 10335500 10340500 Y = 10,343,520.00

Y = 10,327,680.00X=1,283,040.00X=1,267,200.00 Surface Location
OCS

‐ G 34441 Location A

X = 1,270,820

Y = 10,334,873
Lat: 28° 28’ 26.345237’’ Long: ‐ 88° 9’ 2.745893’’
3620’ FWL of MC 521
7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD
Water Depth: 6768’

Surface Location
OCS

‐ G 34441 Location D

X = 1,271,020

Y = 10,334,873
Lat: 28° 28’ 26.3642’’ Long: ‐ 88° 9’ 00.5045’’
3820’ FWL of MC 521
7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD
Water Depth: 6772’0

0 0 6 8 0

9 0

6 7

0 9 6 6

6

7

0 0

0 0 0 09 6

MC0521 Loc_A Loc_D

1267700 1272700 1277700 1282700 1033050 0 1033550 0 1034050 0

Deep Gulf Energy II, LLC

Barataria MC 521

Bathymetry Map

Contour: waterbottom_Justice_WAZ_Bara_RTM (mike) (Black), Data Type: Depth, Version: 7.5 0 6000 ft 2000 4000

Scale = 1:24000 1267700 1272700 1277700 1282700 X/Y: Feet

10330500 10335500 10340500 Surface Location
OCS

‐ G 34441 Location A

X = 1,270,820

Y = 10,334,873
Lat: 28° 28’ 26.345237’’ Long: ‐ 88° 9’ 2.745893’’
3620’ FWL of MC 521
7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD
Water Depth: 6768’ Y = 10,343,520.00

Y = 10,327,680.00X=1,283,040.00X=1,267,200.00 Surface Location
OCS

‐ G 34441 Location D

X = 1,271,020

Y = 10,334,873
Lat: 28° 28’ 26.3642’’ Long: ‐ 88° 9’ 00.5045’’
3820’ FWL of MC 521
7193’ FSL of MC521

PTD: 17,000’ MD 17,000’ TVD
Water Depth: 6772’Deep Gulf Energy II, LLC Section 2 – Pg. 4 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 2
GENERAL INFORMATION

2.1 APPLICATIONS AND PERMITS
Listed in the table below are all additional applications to be filed covering operations proposed in this EP.

Application/Permit Issu ing Agency Status

Application for Permit to Drill BSEE To Be Submitted Emergency Evacuation Plan USCG To Be Submitted

2.2 DRILLING FLUIDS The table below provides the types and estima ted volumes of the drilling fluids DGE II plans to use to drill the proposed wells.

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be Used per Well (bbls) Water-based (seawater, fr eshwater, barite) 35,000 Oil-based (diesel, mineral oil) N/A Synthetic-based (internal olefin, ester) 20,000

2.3 NEW OR UNUSUAL TECHNOLOGY No new or unusual technology is proposed to carry out activities in this Initial Exploration Plan as defined by 30 CFR 550.200.

2.4 BONDING STATEMENT The bond requirements for the activities and fa cilities proposed in this EP are satisfied by a lease bond, furnished and maintained according to 30 CFR 556, Subpart I; NTL No. 2000-G16, "Guidelines for General Lease Surety Bonds"; and additional security under 30 CFR 556.53(d) and National NTL No. 2008-N07, “Supplemental Bond Procedures” as required by BOEM.

2.5 OIL SPILL FINANCIAL RE SPONSIBILITY (OSFR) Deep Gulf Energy II, LLC Oper ator Number 02985, will demonstrate oil spill financial responsibility for the facilities proposed in this EP according to 30 CFR 553; and NTL No. 2008-N05, "Guidelines for Oil Spill Financia l Responsibility for Covered Facilities" prior to conducting operations covered in this EP.Deep Gulf Energy II, LLC Section 2 – Pg. 5 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 2.6 DEEPWATER WELL CONTROL STATEMENT Deep Gulf Energy II, LLC, Oper ator number 02985 has the financ ial capability to drill a relief well and conduct other emergency well control operations.

2.7 BLOWOUT SCENARIO AND WORS T CASE DISCHARGE CALCULATIONS The calculated Worst Case Discharge estima te for Mississippi C anyon Well Location A is 155,762 bbls of oil.

In accordance with NTL No. 2010-N06, “Information Re quirements for Exploration Plans, Development and Produc tion Plans, and Development Operations Coordination Documents on the OCS,” the Blow out Scenario is included as Attachment 2-A . The Worst Case Discharge Volume calculatio ns and assumptions were provided in the Proprietary copy of this plan.

### ATTACHMENT 2-A

Blowout Scenario

Estimated maximum flow rate

The estimated maximum flow rate would occur in the objective section, if a kick were taken and the well blew out. The maximum Worst Case Discharge (WCD) modeled for this scenario is 155,762 BOPD.

Maximum duration of blowout (days)

The duration of the bl owout will be a function of the we ll bridging over, the ability of surface intervention to shut or contain the well or, as a last resort, drilling a relief well to kill the blowout. The expected maximum time frames for uncont rolled flow in each of the different operational outcomes would be as follows:

 Bridging Over in 2 Days,

 Surface Intervention in 15 Days,

 A Relief Well in 71 Days.

Maximum discharge volume The following table is a linear estimate of the maximum discharge volume for each of the aforementioned operati onal outcomes assuming no reservoir depletion.
Operational

Outcome Maximum Discharge Rate (bbl/day) Discharge Duration

(days) Maximum Discharge Volume (bbl)

Bridging Over 155,762 2 311,524

Surface Intervention 155,762 15 2,336,430

Relief Well 155,762 71 11,059,102

Potential of wellbore to br idge over during a blowout
There is potential for the we llbore to bridge over during t he WCD blowout. Bridging may occur due to the drawdown calculated betwe en the formation and the open hole section. A Merlin reservoir simulation model was used to investigate the well conditions during the WCD blowout scenario. The estimated initial reservoir pressure is 9,438 psi. The reservoir model estimates bottom hole fl owing pressures, based upon reservoir properties and flow rates. The calculated del ta reservoir pressure (initial reservoir pressure minus flowing BHP at Day 1 WCD rate) is modeled to be 4,470 psi.In our experience in the deepwater GOM, we strive to limit the estimated total drawdown on a producing interval to reduce t he risk of wellbore collapse and sand/fines migration into a well. There is a pot ential for the wellbore bridging over as:

 Drawdown is estimated to be above 3,300 psi;

 The blowout occurs in a long open hole section of the well, with no benefit of casing or a frac-pack completion,

 If any water zones are exposed this will accelerate we llbore collapse and bridging,

Surface intervention to stop the blowout
In the event of a blowout and assuming the bl owout prevention equipment is still intact; the subsea BOP will be used for successful shut -in of the well. The well would then be killed and re-entered to eit her abandon or return to norma l operations. Surface intervention would be the first line of defens e after a blowout occurs. The specific intervention technique chosen will depend on ac tual conditions and ability to access the existing well.
In the event that the subsea BOP is inoperabl e, the surface intervention would employ the Helix Well Contai nment Group (HWCG) containment system to achieve successful containment of the well. T he system will be empl oyed, while simultaneously initiating relief well planning and operat ions. Specifics will be submitted within the Well Containment Plan.
Typically blowouts can be controlled with surf ace intervention, with a good likelihood of success and in a relatively short time fram e, as long as, the subsea casing, wellhead and BOP’s are not damaged beyond use. The intervention technique chosen will depend on actual conditions and ability to a ccess the existing well. There can be simple solutions such as rig up and bullhead kill mud or more complex solutions, but the solution will depend on wellbore conditions.

Surface intervention time estimate
The assumption is that the well has an unc ontrolled blowout and the MODU has sunk with displacement from the well head. Additionally, it assumes that debris removal will be required to gain access to the subsea BO P system. The ROV has been deployed and was unsuccessful in shutting in the well, us ing the existing subsea BOP control panel. The scenario employs one of the aforementioned containment system’s capping BOP.
The table on the next page describes the estima ted time required to shut in and secure the well using the containment system or capping stack. Note that these operations all basically start at the same point in ti me and are performed in parallel. The entire operation is estimated to take 15 days from start of site assessment until the capping stack has been deployed and the well shut in.

Duration of a well capping operation
Operation Incremental Duration

(days) Cumulative Time Since Event Start (days)Assess wellbore conditions for surface intervention requirements. Conduct notifications to the regulatory agencies and primary
contractors. 2 2

Site Preparation which includes mobilizing and deploy ment of the IWOCS system and Dispersant system. 3 5

Debris removal including mobilization of ROV boat and construction support vessel and execution of debris removal plan. 2 7

Well capping and/or cap and flow operations which include mobilization, deployment, and installation of the well containment system. 8 15

Relief Well
It is preferred to drill relief wells from an open water location, rather than a platform location. Open water locations provide the best option on designing a simpler intercept well and allow a greater choice on rig avail ability. There are not any platforms in the immediate vicinity, therefore it is not feasible to consider as a relief well location.

Relief well location and drilling strategy
The surface location for a relief well(s) is a function of s eabed bottom and shallow hazard conditions, current, wind direction and wellbore access. The relief well surface location for the MC 521 Well No. 001 (drilled from Well Site A surface location) could be drilled from an appropriately clea red-of-hazards surface locati on to the south-southeast of the Well Site A location.

A relief well for MC 521 Well No. 001 would be designed to intersect the blowout well below the16” casing point. Once the well is intersected, kill pum ping operations would be initiated to kill the blowout well.

Relief well rig availability
As of the date of this EP submittal, the rigs listed below have Gulf of Mexico area of operations, and could be available for relief well operations:Rig Name Contractor Rated Water Depth MODU Type Rig Status

Ensco 8500 Ensco 8,500’ DP Semisubmersible Contracted GOM Ensco 8501 Ensco 8,500’ DP Semisubmersible Contracted GOM Ensco 8505 Ensco 8,500’ DP Semisubmersible Contracted GOM West Sirius Seadrill 10,000’ DP Semisubmersible Contracted GOM Maersk Developer Maersk 10,000’ DP Semisubmersible Contracted GOM Danny Adkins Noble 12,000’ DP Semisubmersible Contracted GOM C.R. Luigs Transocean 10,000’ DP Drill Ship Contracted GOM Discoverer Deep Seas Transocean 10,000’ DP Dr ill Ship Contracted GOM

Relief well package constraints
The proposed rigs for relief well operati ons have suitable drilling packages with sufficient capabilities to work in the subjec t water depths and drill to the required relief well depth. The BOP systems have met the BSE E certification requirements and will be re-inspected in transit, prior to drilling a reli ef well to the required true vertical depth.

Relief well rig contract and mobilization timing
A suitable rig could be sele cted and a contract finalized in 48 hours after undertaking the decision to begin relief well operations. Backup tubular s and wellhead systems are maintained in stock for each well. Mobilizat ion of equipment and services to the rig for the relief well could be completed while opera tions required to suspend the rig’s current activity were taking place. The time requir ed to contract, mobilize, drill a relief well and kill the blowout well is estimated at 71 days and is summarized on the next page.Duration of relief well
Description Days Cumulative Days
Well Control Assessment. Identify suitable MODU for relief well operations 2 2

MODU suspends operations from current well. Contract to be executed and Well Spud Equipment is mobilized 14 16

Mobilize Rig and instal l 36” Structural Casing 6 22

Spud and drill to the top of the zone of interest and set casing. 38 60

Mag-Range relief well into intersecting position. 6 66

R/U pumping equipment and kill well. 5 71
R/D Pumping Equipment, PA Wellbore, Pull Riser, and Demobilize 12 83

Blowout Prevention and Intervention
Summary of prevention measures

DGE II has maintained a safe track record of prudent operations in the GOM deepwater environment. It will continue to implement its safe operati ng practices to enhance its operating risk reduction program. In addition to the safe operating practices, the following measures will be implemented into well design, drilling and completion operations.

 BOP Certification, BOP Drills, Pit Drill’s and all ot her required BSEE testing requirements,

 Current Well Control Certification fo r all Drilling and Completion Rig Site Supervisors,

 Taking Slow Pump Rate measurement s during all open hol e operations and critical cased hole operations,

 Updating Kill Sheets duri ng each tour and posting the same on the rig floor,

 Maintain a current BOP to RKB spaceout Chart,

 Monitoring wellbore fill-ups and displace ments during trips, by the Well Site Supervisor,

 Maintain the necessary circulating sw ages, TIW Valves and IBOP on the rig floor at all times during operations and f unction test these valves during each
tour.

The utilization of Pre-Job Sa fety meetings will continue to be implemented prior to each operation with all of the rig cr ews. These are intended to create a behavior based safety program and promote an at mosphere within the and rig cr ew interface, such that a“Stop the Job” mentality is promoted across the rig contract or’s crew, empowering every crew member to question the safety of each operation.

Early well control intervention

In the event of a blowout situation, due to failed BOP equipment and uncontrolled flow at the seafloor or at surfac e, assuming all other surface controlled actuation measures have failed or are inaccessible, a ROV will fly into position at the BOP subsea actuation panel and actuate the shear ram or pipe rams to establish containment.
If the riser system and rig have been compromis ed, then debris removal will be initiated to obtain clear access to the BOP. A C apping Stack will be employed to achieve successful containment of the well. Once containment is es tablished and wellbore pressure testing and assessment is comple ted by DGE II and Well Control Specialist, well kill operations can be initiate d through the existing wellbore.

Well control engineering services
DGE II will have service agreements in pl ace with Wild Well Control and Boots and Coots International Well Contro l prior to commencement of well operations. In the event of a blowout situation, these companies will be contacted to assist in the detailed design and implementation of well contro l and/or relief well operations.

Additional prevention & mitigation techniques
Pursuant to wellbore cementing and zonal isolation techniques, all cementing operations will be modeled a nd designed under the guideli nes set forth in API Recommended Practice 65 Part 1 & 2. Operations will be dictated by the rules and requirements set forth in Federal Regu lations, under the wellbore cementing requirements.
API Standard 53 Blowout Prevention Equi pment Systems for Drilling Wells and Recommended Practice 16Q for Marine Drilling Risers will be used as the guidelines for installation, testing and maintenance of the surface and subsea Marine Risers and BOP systems. The purpose of these recommended practices is to provide information that can serve as a guide for installation and te sting of blowout prevention systems has contracted for floating marine drilling rigs.
The goal of using these re commended practices is to assi st DGE II operations in promoting personnel safety, public safety, and integrity of the drilling equipment and preservation of the environment for float ing marine drilling operations. These recommended practices help to facilitate the broad availability of proven, sound engineering and operati ng practices.
These practices are considered acceptab le for accomplishing BOP and Marine Riser associated operations. However, equivalent alternative installations and practices may be utilized to accomplish the same obj ectives. When using these recommended practices or other alternatives, DGE II wi ll insure that operations comply with requirements of Federal Regulations.Deep Gulf Energy II, LLC Section 3 – Pg. 6 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 3
GEOLOGICAL AND GEOP HYSICAL INFORMATION

3.1 GEOLOGICAL DESCRIPTION Proprietary Information.

3.2 STRUCTURE CONTOUR MAP Proprietary Information.

3.3 INTERPRETED SEISMIC LINE(S) Proprietary Information.

3.4 GEOLOGICAL STRUCTURE CROSS-SECTIONS Proprietary Information.

3.5 SHALLOW HAZARDS REPORT A shallow hazards survey was conducted over Mississippi Canyon Block 521.

In accordance with NTL No. 2008-G05, “S hallow Hazards Progra m” (Extended by NTL NTL No. 2014-G03, “Extension of Prior Notices to Lessees”), a shallow hazards survey evaluating seafloor and s ubsurface geological and manm ade features and conditions that may adversely affect drilling operatio ns, was conducted by Geoscience Earth & Marine Services (GEMS). The shallow ha zards report is provided with this plan.

3.6 SHALLOW HAZARDS ASSESSMENT In accordance with NTL No. 2008-G05, “Shallow Hazards Progr am,” (Extended by NTL No. 2014-G03, “Extension of Prior Notices to Lessees”), a shallow hazards assessment has been prepared for the proposed surface locations evaluating seafloor and subsurface geological and manmade features and conditions that may adversely affect drilling operations. The shallow hazards survey and archaeological assessment is included as Attachment 3-D

.
3.7 HIGH-RESOLUTION SEISMIC LINES Proprietary Information.

3.8 STRATIGRAPHIC COLUMN Proprietary Information.

3.9 TIME VERSUS DEPTH TABLES Proprietary Information.10344 Sam Houston Park Drive HOUSTON, TEXAS 77043 Phone: (713) 351-7900

www.gemsinc.com

Geoscience Earth & Marine Services // 1 FORUM ENERGY TECHNOLOGIES, INC. July 2, 2014 Project No. 0613-2255b
Deep Gulf Energy Companies 738 Highway 6 South Houston, TX 77079

Attention: Mr. Ri chard Brainard

Site Clearance Letter Proposed Wellsites A and D

Block 521 (OCS-G-34441) Mississippi Canyon Area Gulf of Mexico

Deep Gulf Energy Companies, (DGE) contracted Geo science Earth & Marine Serv ices, (GEMS) to provide an assessment of the shallow geologic conditions and to determine the favorability of drilling operations for the Proposed Wellsites A and D in Block 521 (OCS-G -34441), Mississippi Canyon Area (MC), Gulf of Mexico. This letter addresses specific seafloor and su bsurface geologic conditions to the Top of Salt at approximately 1,551 ft below the mudline (bml) at the proposed locations.
This letter is based on findings provided within the main body of the geohazard report “Geologic, Stratigraphic, and Archaeological Assessment Block 521 (OCS-G-34441), Mississippi Canyon Area, Gulf of Mexico” (GEMS Report No. 0613-2255bc). The text, maps, and figures included in the geohazard report provide detail on the regional geology of the MC 521 Survey Area. This letter is intended to supplement that report with details pertaining directly to the proposed wellsites.
The following sections provide details specific to t he well location, including: available data, Notice to Lessees (NTL) requirements, obstructions, ar chaeological assessment, and wellsite conditions.

Proposed Well Locations

The surface locations for the Proposed Wellsites A and D are in the west-central portion of Block 521, Mississippi Canyon Area, Gulf of Mexico. DGE plans to drill this well using a dy namically positioned drilling vessel. This assessment addresses the seafloor conditions within a 2,000 ft radius around the proposed wellsite locations. DGE provided the following coordinates:

Proposed Wellsite A Spheroid & Datum: Clarke 1866, NAD27 Projection: UTM Zone 16 North Line Reference Block Calls MC 521 X: 1,270,820 ft Latitude: 28 ° 28' 26.3452" N Inline 12045 3,620 ft FWL Y: 10,334,873 ft Longitude: 88 ° 09' 02.7459" W Crossline 11308 7,193 ft FSL

Proposed Wellsite D Spheroid & Datum: Clarke 1866, NAD27 Projection: UTM Zone 16 North Line Reference Block Calls MC 521 X: 1,271,020 ft Latitude: 28 ° 28' 26.3642" N Inline 12048 3,820 ft FWL Y: 10,334,873 ft Longitude: 88 ° 09' 00.5045" W Crossline 11305 7,193 ft FSLProject N o Deep Gul f

Geoscience FORUM EN Availabl

DGE pro v includes B for the g Technolo g (Illustrati o

assessm e from the h

Illustrati o

Attach m
The pag e data volu m

M M M M M F

F

F

o . 0613-225 5 f Energy Com

Earth & Marine S ERGY TECHN O e Data

v ided an ex p B locks MC 5 2

e ohazard an
g ies, Inc. (C

o n 1). GEM

e nt over MC 5 h igh-resolutio

o n 1. Seaflo o

m ents

e -size maps a

m es and illus t

M ap No. 1: M ap No. 2: M ap No. 3: M ap No. 4: M ap No. 5:

igure 1:

igure 2:

igure 3: 5 b panies

S ervices O LOGIES, INC. p loration 3-D 2 1, 565, and 6 alysis. A h & C) over B l S used the
5 21. The pa g n and 3-D d a

o r Renderin g

a nd figures a c t rate the sea f

Bathymetr y Seafloor F e Side-Scan Seafloor A m Geologic F e Subbottom Wellsite Portions of Propos e Tophole P r Block 5 2 seismic dat a 6 09. GEMS u igh-resolutio n l ock MC 521

,

C & C sur v g e-size map s

a ta volumes a

g of the Sur v

c companying f loor and shal

y Map

e atures Map Sonar Mosai c

m plitude Ren d

e atures Map Profiler Line

s A and D in Inline 12045

e d Wellsites A

r ognosis Cha r 2 1 a set coverin g

u sed a porti o

n AUV surv e

, including a n

v ey data to

s and figures nd centered o

v ey Area.

this letter w e low geologic

c d ering

116 Showin g Mississippi C and Crosslin A and D

r t, Proposed W g an approxi m

o n of the 27 s q

e y was cond u

n approxima t

complete a accompanyi n

o n the propo s

e re extracted conditions a t

g Shallow Str a C anyon Block

e 11308 Sho

W ellsites A a Propos e

m ate 27 squ a quare-mile a r

u cted in Au g t e 1,600 ft h a

geohazard

n g this letter

s ed well loca t

from the hig
t the Propose

a tigraphy at P 521 wing Conditi o

nd D, Missis s e d Wellsites A // July

a re-mile are a

r ea covering
g ust 2013 b y

a lo around t h

and archa e have been e x t ion.

h-resolution a d Wellsites A

P roposed

o ns Beneath

s ippi Canyon, A and D 2, 2014

// 2 a , which MC 521
y C & C h e block

e ological

x tracted

a nd 3-D A and D:Project No. 0613-2255b Proposed Wellsites A and D Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 3 FORUM ENERGY TECHNOLOGIES, INC. NTL Requirements

The following report complies with the Bureau of Ocean Energy Management (BOEM, formerly MMS) Notice to Lessees (NTL’s) 2008-G04, 2008-G05, and 2009-G40 (MMS, 2008a, b, and 2010). BOEM’s NTL 2014-G05 (BOEM, 2014a) extends the expiration of NTL 2008-G04 and -G05. The operator will be required to follow NTL’s 2008-G04 and -G06 with respect to an ROV monitoring survey as well as pre- and post-spud ROV visual inspection surveys (MMS, 2008a and 2008c). The Federal lease Block MC 521 is considered archaeologically significant (NTL 2011- JOINT-G01, BOEM, 2011). Any seabed disturbing activities within this designated block will be s ubject to the archaeological survey and reporting requirements according to NTL 2005-G07 (MMS, 2005 ). A high-resolution geophysical survey was conducted in the area by C & C Technologies, Inc., (C & C) in August 2013 using an autonomous underwater vehicle (AUV). The data collected were analyzed by a marine archaeologist at GEMS and an archaeological assessment is included in the MC 521 geohazard report (GEMS, 2014).
Power Spectrum. According to NTL 2008-G05 (MMS, 2008b), 3-D seismic reflection data may be used for shallow hazard assessments with approval from t he BOEM, Gulf of Mexico Region. A power spectrum analysis was conducted from the 3-D seismic data cube pr ovided by DGE to illustrate the data parameters. The power spectrum curve (below) was generated within a 500-ft radius of the intersection of the inline and crossline at the proposed wellsite location. We c onverted the amplitude vs. frequency spectrum, generated by the SMT software, to power vs. frequency by s quaring the amplitude values as described by J. A. Coffeen, 1978.

Illustration 2. Power Spectrum Analysis Curv e, MC 521, Proposed Wellsites A and D

Obstructions

There are no existing exploration or development well s within MC 521. Several existing pipelines and umbilicals are present near the proposed well locations in MC 521 (BOEM, 2014b, Table 1). These pipelines are associated with BP’s Na Kika platform located in MC 474, about 9.0 miles northwest of the proposed wellsite. Table 1 provides a summary of the pipelines and umbilicals located within MC 521. 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9

1

0 10 20 30 40 50 60 70 80 90 100Power (Amp2)

Frequency (Hz) POWER SPECTRUMProject No. 0613-2255b Proposed Wellsites A and D Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 4 FORUM ENERGY TECHNOLOGIES, INC. Table 1: Existing Pipelines Within MC 521

Operator Pipeline Type Origin Destination Distance/ Direction to Proposed Wellsite A

BP Exploration & Production Inc.* 8-inch Bulk Oil MC 522 SLED MC 474 Na Kika Platform 3,279 ft/S

BP Exploration & Production Inc.* 8-inch Bulk Oil MC 522 SLED MC 520 SLED 4,072 ft/S

BP Exploration & Production Inc.* 8-inch Bulk Ga s MC 522 SLED MC 474 Na Kika Platform 1,380 ft/S

BP Exploration & Production Inc.* 5-inch Umbilical MC 474 Na Kika Platform MC 522 #F5, #F6 1,638 ft/S

Shell Offshore Inc.* 1-inch Umbilical MC 474 Na Kika Platform MC 522 #F3, #F4 2,558 ft/S

*Illustrated on Maps 1 through 5

Archaeological Assessment

High-resolution digital side-scan so nar, subbottom profiler, multibeam ba thymetry, and mult ibeam backscatter data were collected in 2013 over the primary survey area using C & C’s C-Surveyor III Hugin 4500 AUV.
An Edgetech Dual Frequency Side-Scan Sonar syst em was used on all survey lines at 200-m (656 ft) range. The AUV collected 230 kHz side-scan sonar data at 200-m (656 ft) line spacing on the primary lines ensuring 200% coverage on all lines. The AUV survey lines also collected 1.5-4.5 kHz Chirp subbottom profiler data, 3-m (9.8 ft) bin multibeam bathymetry da ta, and 1-m (3.28 ft) bin multibeam backscatter data.
The 2014 GEMS assessment delineated a total of eight unidentified side-scan sonar contacts in the AUV data within the Survey Area. An unidentified side -scan sonar contact was discovered within 610 m (2,000 ft) of the proposed wells (Illustration 3). Sonar Contact 8, an unknown object interpreted to represent modern debris from shipping, storm, fishing, or exploration activities, is located approximately 206 m (676 ft) southeast of Proposed Wellsite A and 157 m (516 ft) southeast of Proposed Wellsite D. According to the sonar data, the object is irregular in s hape and measures approximately 7.3 m (23.9 ft) long and 1.8 m (5.8 ft) wide.

No potential submerged cultural resources were identi fied in the subbottom, bathymetry, or backscatter data sets.

Illustration 3. Side-Scan Sonar Contact No. 8

Archaeological Avoidance. No archaeological avoidances exist within the area of potential effect for the Proposed Wellsites A and D. No known shipwrecks lie within the area of potential effect. A 30.5-m (100 ft) geohazard avoidance is recommended for Sonar Contact 8.Project No. 0613-2255b Proposed Wellsites A and D Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 5 FORUM ENERGY TECHNOLOGIES, INC. Wellsite Conditions

A gas pipeline and an umbilical exist within 2,000 ft of the proposed well locations (Map 1). The shallow stratigraphy at the proposed well reflects alternatin g deposition of mass-transport, turbidite, and slope-fan deposits interbedded with pelagic and hemipelagic clay s and silts. Overpressured sands and minor amounts of shallow gas are possible within the sand-prone sequences. Precautions should be made when drilling through potentially ov erpressured intervals.
Water Depth, Gradient, and Seabed Sediments. The water depth is about -6,767 ft below sea level (bsl) at Proposed Wellsite A and about -6,771 ft bsl at Proposed Wellsite D (Map 1). The seafloor slopes to the southeast at about 0.9° at Proposed Wellsite A and 1.8° at Proposed Wellsite D. The proposed wellsites are situated along the southern flank of a shallow salt dome in the west-central portion of MC 521 (Illustration 1). Slightly irregular seafloor conditions associated with shallow mass-transport deposits are expected at the proposed sites (Map 2). A surficial dr ape of soft, high-water content silty clays covers the seafloor surrounding the proposed wellsites (Figure 1).
Deepwater Benthic Communities. There is no evidence of hydroc arbon seepage, authigenic carbonates, or hardbottom conditions that could support high-density, deepwater chemosynthetic or coral communities near the proposed surface locations. The Side-Sc an Sonar Mosaic and Seafloor Amplitude Rendering (Maps 3 and 4) shows low reflective and normal or am bient amplitudes along the seafloor at the proposed wellsites. The potential for high-density chemosyn thetic or other deepwater benthic communities is negligible.
Stratigraphy

Stratigraphic conditions are shown on Figures 1, 2, and 3. The surficial interval from the seafloor to about 125 ft bml (upper portion of Unit 1), likely consis ts of very soft surficial clays (<15 ft) overlying stratified, normally consolidated hemipelagic clays and silty clays (Figure 1). Shallow mass-transport deposits are expected below about 125 ft bml. These amalgamated sediments likely represent dewatered clays and could be stiffer than a normal or standard sediment profile.

The seismic character of the interval between 125 ft and 242 ft bml (lower portion of Unit 1) consists of interlayered chaotic, low-amplitude reflectors and continuous, low to moderate-amplitude reflectors (Figures 1 through 3). The overall sequence likely represents interlayered mud-rich, mass-transport deposits with bedded pelagic and hemipelagic clays and silty clays. Mass-transport deposits within the lower portion of Unit 1 are expected to range between 35 ft to 55 ft thick.
Unit 2 (242 ft to 462 ft bml) consists of bedded, low to high-amplitude reflectors interlayered with chaotic, transparent to low-amplitude zones (Figures 2 and 3). This sequence is identified as the “MC Blue Unit” basin floor fan. The Blue Unit interval is a sand-rich, slope-fan complex with hemipelagic muds and mud-rich, mass-transport deposits. The transpar ent to low-amplitude zones within the unit likely represent hemipelagic muds and mass-transport deposit s. The moderate to high-amplitude reflectors within this interval represent sand-rich, slope-fan deposits.
Unit 3 (462 ft to 659 ft bml) consists of low-am plitude, continuous to semi-continuous reflectors interbedded with low-amplitude, chaotic reflectors (F igures 2 and 3). This sequence likely represents stratified, clay-dominated turbidites interlayered with thin mass-transport deposits. Thin sand seams are possible within the turbidite and mass-transport deposits in this unit.
Unit 4 (659 ft to 1,092 ft bml) consists of chaot ic, amorphous, low-amplitude reflectors overlying, continuous to discontinuous moderate to high-amplitude reflectors (Figures 2 and 3) . This interval likely corresponds to interbedded clay-prone turbidites an d sand-rich, slope-fan deposits overlain by clay-rich, mass-transport deposits. Potentially thick sand layers are possible within the lower portion of the unit.
Unit 5 (1,092 ft to 1,551 ft bml) consists of amor phous, low-amplitude reflectors interlayered with semi-continuous, moderate to high-amplitude reflectors (F igures 2 and 3). This interval likely represents clay-dominated turbidite and mass-transport deposits interbedded with sand-prone, slope-fan sediments. Potential sand layers may be encountered within slump deposits in the mid portion of the unit.Project No. 0613-2255b Proposed Wellsites A and D Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 6 FORUM ENERGY TECHNOLOGIES, INC. Faults

A vertical well bore at the proposed wellsites is not ex pected to intersect any seafloor or buried faults in the shallow section to the Top of Salt (1,551 ft bml), Map 5 and Figures 1 through 3. Various buried faults exist near the proposed well location within Unit 5 (1,092 ft to 1,551 ft bml), Map 5 and Figure 2. These faults are normal adjustment faults mostly confined to Unit 5 and the lower portion of Unit 4. The faults generally trend northwest-southeast and are downthrown to the southwest toward the wellsite, but do not appear to be intersected by the proposed wellsite and are not expected to impact drilling operations. The closest buried fault is about 3,600 ft northeast of the proposed wellsite.

Shallow Gas

The well path will not penetrate any in terpreted high-amplitude events from the seafloor to the Top of Salt (1,551 ft bml), Map 5 and Figures 2 and 3. There is a low potential for encountering shallow gas below Horizon 10 (242 ft bml) to the Top of Salt (1,551 ft bml). Moderate-amplitude reflectors within the turbidite and slope-fan deposits may indicate coarse grai ned sediments within the predominantly clay-rich intervals. Minor amounts of biogenic gas may be encountered within isolated sands. A negligible potential for encountering shallow gas exists within the clay-prone units between the seafloor and Horizon 10 (242 ft bml) and from Horizon 20 (462 ft bml) to 976 ft bml.

Shallow Water Flow

There is a moderate potential for shallow water flow within the MC Blue Unit slope-fan complex from Horizon 10 to Horizon 20 (242 ft to 462 ft bml, Unit 2). The Blue Unit contains sand-rich intervals and has sourced shallow water flow problems in the Missi ssippi Canyon region (BOEM, 2014c). Three incidents of low severity water flow are reported from wells within a 10-mile radius of the proposed locations. Reported depths below the mudline to the flows vary from 448 ft to 2,371 ft. Potential sands within this unit may be thick and continuous; however, the Blue Un it is relatively shallow with thin sediment overburden at the proposed well location. Any sand layers encountered within this shallow section may not be significantly overpressured.
There is a moderate potential for enco untering shallow water flow within the lower portion of Unit 4 (976 ft to 1,092 ft bml), Figure 3. Potentially thick and cont inuous sand deposits may exist within the turbidite and slope-fan deposits within this interval.
A low potential for water flow exists in the upper portion of Unit 4 from Horizon 30 (659 ft bml) to 976 ft bml and within Unit 5 from Horizon 40 to the Top of Salt (1,092 ft to 1,551 ft bml), Figure 3. Any sands encountered within the turbidite and mass-transport deposits within these intervals are expected to be thin seams and not likely to produce sustained fl ows. There is a negligible potential for encountering shallow water flow within Unit 1 from the seafloor to Horizon 10 (242 ft bml) and within Unit 3 from Horizon 20 to Horizon 30 (462 ft to 659 ft bml).

Closing

No potential submerged cultural resources were found in the area of potential effect (GEMS, 2014). Sonar Contact No. 8 is the closest unidentified sonar contact and is located approximately 206 m (676 ft) southeast of Proposed Wellsite A and 157 m (516 ft) southeast of Proposed Wellsite D. This contact likely represents modern debris. Contact No. 8 is not recommended for archaeological avoidance or investigation; however, a 100 ft geohazard avoidance of all sonar contacts is recommended to avoid damage to equipment and infrastructure. Should any potentially historic materials such as textiles, wood, ceramics, or other items be uncovered during operations in the area, all operations must cease and BOEM be notified within 48 hours.

An active pipeline and umbilical exist within 2, 000 ft of the proposed wells ites. The subsurface interpretation concluded a moderate potential for sha llow water flow within the MC Blue Unit slope-fan complex (242 ft to 462 ft bml) and within the turbidite and slope-fan interval in the lower portion of Unit 4 (976 ft to 1,092 ft bml). These units are associat ed with shallow water flow events throughout the Mississippi Canyon Area. We advis e using caution while drilling thro ugh the potentially overpressured sands within these units, some of which may contain minor amounts of biogenic gas. ShallowProject No. 0613-2255b Proposed Wellsites A and D Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 7 FORUM ENERGY TECHNOLOGIES, INC. mass-transport deposits are expected below about 125 ft bml. Drillers should be aware that the deposits are anticipated to vary between 35 ft and 55 ft thick, and variable soil conditions are likely.
We appreciate the opportunity to be of service to Deep Gulf Energy Companies, and look forward to working with DGE on future projects.
Sincerely,

GEOSCIENCE EARTH & MARINE SERVICES

Carla Cleveland George Schwarz, Ph.D. Geoscientist Marine Archaeologist

Erin Williams Janes Daniel Lanier Project Manager - Senior Geoscientist Director - GEMS

Attachments (4 Maps, 3 Figures) Distribution: Mr. Richard Brainard , DGE, Houston, TX. (10 Copies)

References:

Bureau of Ocean Energy Management, 2011, Notice to less ees and operators of federal oil and gas leases and pipeline right-of-way holders on the outer continental shelf, revisions to the list of OCS lease blocks requiring archaeological resource surveys and reports: U. S. Department of the Interior, Bureau of Ocean Energy Management, Bureau of Safety and Environmental Enfo rcement, Gulf of Mexico OCS Region, NTL 2011-JOINTG01.

Bureau of Ocean Energy Management, 2014a, Notice to less ees and operators of federal oil, gas, and sulphur leases in the outer continental shelf, Gulf of Mexico OCS regi on: Extension of prior notice to lessees, NTL 2014-G05.

Bureau of Ocean Energy Management, 2014b, ASCII data file s, published on the BOEM Gulf of Mexico Region homepage, <http://www.gomr.boemre.gov/homepg/pubinf o/freeasci/freedesc.html>, accessed July, 2014.

Bureau of Ocean Energy Management, 2014c, Safety perfo rmance review - shallow waterflows can pose significant hazards to deepwater drilling, http://www.gomr/boemre.g ov/homepg/offshore/sftey/watrflow.html website accessed July, 2014.

Coffeen, J. A., 1978, Seismic exploration fundamen tals: Tulsa, the Petroleum Publishing Co., p. 125.

GEMS, 2014, Geologic, stratigraphic, and archaeological assessment, block 521, Mississippi Canyon Area, Gulf of Mexico: GEMS Report No. 0613-2255bc.

Minerals Management Service, 2005, Noti ce to lessees and operators of feder al oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, Archaeological resource surveys and reports: U. S. Department of the Interior, Mi nerals Management Service, Gulf of Mexico, NTL 2005-G07. Effective Date July 1, 2005.

Minerals Management Service, 2008a, Notice to lessees and oper ators of federal oil, gas, and sulphur leases in the outer continental shelf, Gulf of Mexico OCS region, info rmation requirements for exploration plans and development operations coordination documents: U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G04. Effective Date May 1, 2008.

Minerals Management Service, 2008b, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline right-of-way holders in the outer continental shel f, Gulf of Mexico OCS region, shallow hazards requirements: U. S. Department of the Interior, Minerals Mana gement Service, Gulf of Mexico, NTL 2008-G05.Project No. 0613-2255b Proposed Wellsites A and D Deep Gulf Energy Companies // July 2, 2014

Geoscience Earth & Marine Services // 8 FORUM ENERGY TECHNOLOGIES, INC. Minerals Management Service, 2008c, Notice to lessees and op erators of federal oil, gas, and sulphur leases in the outer continental shelf, Gulf of Mexico OCS region; re motely operated vehicle surveys in deepwater, U. S. Department of the Interior, Minerals Managem ent Service, Gulf of Mexico, NTL 2008-G06.

Minerals Management Service, 2010, Notice to lessees a nd operators of federal oil and gas leases in the outer continental shelf, Gulf of Mexico OCS region, deepwater benthic communities: U. S. Department of the Interior, Minerals Management Service, Gu lf of Mexico, NTL 2009-G40.Deep Gulf Energy II, LLC Section 4 – Pg. 7 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 4
HYDROGEN SULFIDE INFORMATION

4.1 CONCENTRATION DGE II anticipates encountering zero H 2 S during the proposed operations.

4.2 CLASSIFICATION In accordance with Title 30 CFR 250.490(c), DGE II requests that the area of proposed operations be classified by the BOEM as H 2 S absent.Deep Gulf Energy II, LLC Section 5 – Pg. 8 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 5 BIOLOGICAL, PHYSICAL AND SO CIOECONOMIC INFORMATION

5.1 DEEPWATER BENTHIC COMMUNITIES The seafloor disturbing activi ties proposed in this plan are in water depths greater than 300 meters (984’). Geoscience Earth & Marine Services (GEMS) was contracted to provide an assessment of t he shallow conditions at the proposed surface locations. The purpose of the assessment was to address seafloor conditions that may impact exploratory drilling operations within 2,000 feet of the proposed well sites. DGE II will avoid all high-density deepwater benthic communities by 2,000 feet from each proposed mud and cuttings discharge location and 250 feet from the location of all other seafloor disturbances. As per NTL No. 2009-G40, “D eepwater Benthic Communities,” a map showing the 2,000 foot radius aro und the well sites is included as Attachment 5-A

.

5.2 TOPOGRAPHIC FE ATURES (BANKS) Activities proposed in this EP do not fall within 305 mete rs (1000 feet) of a topographic “No Activity Zone;” therefore, no map is required per NTL No. 2009-G39, “Biologically
Sensitive Underwater Features and Areas.”

5.3 TOPOGRAPHIC FEATURES STATEMENT (SHUNTING) All activities proposed under this EP will be conducted outsi de all Topographic Feature Protective Zones; therefore shunt ing of drill cuttings and drilling fluids is not required per NTL No. 2009-G39, “Biologically Sens itive Underwater Features and Areas.”

5.4 LIVE BOTTOMS (PINNACLE TREND FEATURES) Mississippi Canyon Block 521 is not located within 61 meters (200 feet) of any pinnacle trend feature; ther efore, a separate bathymetric map is not required per NTL No. 2009- G39, “Biologically Sensitive U nderwater Features and Areas.”

5.5 LIVE BOTTOMS (LOW RELIEF) Mississippi Canyon Block 521 is not locate d within 30 meters (100 feet) of any live bottom (low relief) feature with vertical relief equal to or greater t han 8 feet; therefore, live bottom (low relief) maps are not requ ired per NTL No. 2009- G39, “Biologically
Sensitive Underwater Features and Areas.”

5.6 POTENTIALLY SENSITIVE BIOLOGICAL FEATURES MAP Mississippi Canyon Block 521 is not located wit hin 30 meters (100 feet) of potentially sensitive biological features ; therefore, biologically s ensitive area maps are not required.Deep Gulf Energy II, LLC Section 5 – Pg. 9 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 5.7 REMOTELY OPERATED VEHICLE (ROV) SURVEYS Pursuant to NTL No. 2008-G06, “Remotely O perated Vehicle Surveys in Deepwater” (Extended by NTL No. 2014-N01, “Elimination of Expiration Da tes on Certain Notices to Lessees and Operators Pending Review an d Reissuance”), operators may be required to conduct remotely operated vehicle (R OV) surveys during pre-spudding and postdrilling operations for the purpose of biological and physical observations.

If required, surveys will be conducted immediately prior and upon completion of drilling operations. A rig-based ROV equipped with video imagi ng capabilities will be used. The survey pattern will consist of six transects centered on the well location with tracks extending approximately 100 meters away from the well on bearings of 30 degrees, 90 degrees, 150 degrees, 210 degrees, 270 degrees and 330 degrees. The seafloor will be videotaped continuously along each track.

Biological and physical observations as de scribed in the subject NTL and Form BOEM0141 will be made prior to co mmencing drilling operati ons and also following the completion of drilling operations, but prio r to moving the rig off location. The
observations will be document ed using Form BOEM-0141 or a facsimile and submitted to the BOEM within 60 days after t he second survey is completed.

5.8 THREATENED AND ENDANGERED S PECIES, CRITICAL HABITAT, AND
MARINE MAMMAL INFORMATION There are five (5) species of sea turtles t hat may be found in the Gu lf of Mexico (see table below). NOAA fisheries cu rrently 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 coriacea E x x None Hawksbill Eretmochelys imbricata E x x None

Kemp’s Ridley Lepidochelys kempli E x x NoneDeep Gulf Energy II, LLC Section 5 – Pg. 10 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 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 enda ngered or threatened. Cu rrently, there are no designated critical habitats for the listed species in the Gulf of Mexico Outer Continen tal Shelf; however, it is possible that one or more of these species could be seen in the area during operations.

Species Scientific Name Status Potential Presence Critical Habitat Designated in

the Gulf of Mexico Lease
Area Coastal

Marine Mammals Sperm Whale 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

NorthAtlantic 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 Gu lf 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 es tuaries, 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

FishDeep Gulf Energy II, LLC Section 5 – Pg. 11 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441)

Gulf Sturgeon Acipenser oxyrinchus (=oxyrhynchus)
desotoi T X X None

5.9 ARCHAEOLOGICAL REPORT Mississippi Canyon Block 521 has been det ermined to have a high potential for containing archaeological properties. In accordance with NTL No. 2005-G07 “Archaeological Surveys and Reports,” and NT L No. 2011-JOINT-G01, “Revisions to the List of OCS Lease Blocks Requiring Archaeological Resource Surveys and Reports”, an Archaeological Survey Report is provided with this plan.

5.10 AIR AND WATER QUALITY INFORMATION Air and water quality information is not required to be included in this plan per NTL No. 2008-G04, “Information requ irements for Explorati on Plans and Development Operations Coordination Documents” (Extended by NTL No. BOEM 2014-G03, “Extension of Prior Notices to Lessees”).

5.11 SOCIOECONOMIC INFORMATION Socioeconomic Information is not required to be included in this pl an per NTL No. 2008- G04, “Information Requirements for Explor ation Plans and Development Operations
Coordination Documents.”Deep Gulf Energy II, LLC Section 6 – Pg. 12 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 6
WASTES AND DISCHARG ES INFORMATION

6.1 PROJECTED GENERATED WASTES “Wastes You Will Generate, Treat and Downho le Dispose or Discharge to the Gulf of
Mexico” is included as Attachment 6-A

.

6.2 MODELING REPORT Modeling reports are not r equired for the activities proposed in this plan.ATTACHMENT 6

‐ A

Domestic waste Gray water (laundry, galley, lavatory) 12,000 bbl/well 5 bbl/hr/well Discharged overboard. Asso ciated food waste will be processed using an approved grinder Will humans be there? If yes, expect conventional waste Drill Cuttings wetted with synthetic-based fluid Cuttings coated with synthetic based drilling mud 2459 bbl/well 137 bbl/day/well Drill cuttings from the wellbore are processed using solids control equipment (shakers, cuttings dryer) which substantially reduces ROC percentage, and processed cuttings are discharged through shunt pipe to 25' below
water's surface. Will drilling occur? If yes, you should list muds and cuttings

Drill Cuttings wetted with water-based fluid Cuttings coated with water based drilling mud 1999 bbl/well 222 bbl/day/well Discharged at mudline prior to BOP & riser installation

Well treatment fluids KCL/HCL/NaCL/NaBr 2,000 bbls/well 10 bbl/min/well Oily water is treated in Oily Water Separator Water-based Drilling Fluids Water based drilling fluid 35,000 bbl/well 7,778 bbl/ day/well Discharged at mudline prior to BOP & rise r installation Waste you will generate, treat and downhole dispose or discharge to the GO M Projected Generated Waste Projected Ocean Discharges

Type of Waste Composition Projected Amount Discharge Rate Discharge Method

Treated human body waste from
toilets 12,000 bbl/well 5 bbl/hr/well USCG approved MSD

Will you conduct well treatment, completion or workover? If yes, only fill in those associated with your activity Is there a deck? If yes, there will be Deck Drainage
Deck Drainage Platform washings and rainwater 163.2 bbl/well 0.1 bbl/hr/well Oily water is treated in Oily Water Separator Sanitary waste

Blowout prevent fluid Stackmagic 200/0/5% glycol
based on 2% mixture with potable water 132 bbl/well 12 bbl/week with
function test Discharged from BOP near mudline Miscellaneous discharges? If yes, only fill in those associated with your activity

Desalinization unit discharge Rejected water from water
maker unit 136,800 bbl/well 57 bbl/hr Cuttings chute

Bilge Water Bilge water 240 bbl/well 0.1 bbl/hr Discharged overboard Ballast water Uncontaminated seawater used to maintain proper draft 21,000 bbl/well 9 bbl/hr Discharged overboard

Discharged overboard Wash water Wash water, sink drainage, etc 12,000 bbl/well 5 bbl/hr

Excess cement at seafloor Cement slurry 912 bbl/well 19 bbl/hr Discharged at the mudline during cementing conductor

Cooling water Seawater with no addition of 4,000,800 bbl/well 1667 bbl/hr Discharged overboard Firewater Seawater with no addition of
chemicals N/A N/A Discharged overboard

Will you be covered by an individual or general NPDES permit: General - NPDES ID GMG290356

NOTE: IF YOU WILL NOT HAVE A TYPE OF WASTE, ENTER “NA” IN THE ROW. Will you pr oduce hydrocarbons? If yes, f ill in for pr oduced water Produced water N/A N/A N/A N/ADeep Gulf Energy II, LLC Section 7 – Pg. 13 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 7
AIR EMISSIONS INFORMATION

7.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS Screen Questions for EP’s Yes No Is any calculated Complex Total (C T) Emission amount (tons) associated with your proposed exploration activi ties more than 90% of the amounts calculated using the following formulas: CT = 3400D 2/3 for CO, and CT = 33.3D for the other air pollutants (wher e D = distance to shore in miles)? X

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

Are your proposed exploration activities located east of 87.5° W longitude? X Do you expect to encounter H 2 S at concentrations greater than 20 parts per million (ppm)? X

Do you propose to flare or vent na tural gas for more than 48 continuous hours from any proposed well? X
Do you propose to burn produced hydrocarbon liquids? X

7.2 SUMMARY INFORMATION There are no existing facilities or activi ties co-located with the currently proposed activities; therefore, the Comp lex Total Emissions are the same as t he Plan Emissions.
Air Emissions Worksheets which show the emission calculations for each of the proposed rig types, DP Semisubmersible Drilling Unit and DP Drillship , with related support vessel information are included as Attachment 7-A

.

This information was calculated by: Kelley Pisciola (281) 698-8519 kelley.pisciola@jccteam.comEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0049OMB Approval Expires: August 31, 2006COMPANYDeep Gulf Energy II, LLCAREAMississippi CanyonBLOCK521LEASEOCS-G 34441PLATFORMWELLLocations A and D (Alternate Location)COMPANY CONTACTKelley PisciolaTELEPHONE NO.281.698.8519REMARKSDrill and Complete with a DP Semi (AQR for DP Semi calculated usingEnsco 8500 Series Specific Horsepower.)Form MMS-138 (August 2003)Page 1 of 8EMISSIONS FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle leangms/hp-hr0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle leangms/hp-hr0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle richgms/hp-hr0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp.gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boilerlbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flareslbs/mmscf0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaringlbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vaporslbs/bbl0.03E&P Forum 1/93Fugitiveslbs/hr/comp.0.0005API Study 12/93Glycol Dehydrator Ventlbs/mmscf6.6La. DEQ1991Gas Ventinglbs/scf0.0034Sulfur Content Source Value UnitsFuel Gas3.33 ppmDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightForm MMS-138 (August 2003)Page 2 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSDeep Gulf Energy II, LLC Mississippi Canyon521 OCS-G 34441 0 Locations A and D (Alternate Location) Kelley Pisciola281.698.8519OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 21739 1049.9937 25199.85 24 240 15.32 70.29 526.72 15.80 114.92 44.13 202.44 1516.94 45.51 330.97PRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 68 1.46 6.68 50.03 1.50 10.92 0.40 1.82 13.61 0.41 2.97VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 68 3.10 14.23 106.61 3.20 23.26 1.05 4.84 36.25 1.09 7.91VESSELS>600hp diesel(tugs)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK-00 00.000.00DRILLING OIL BURN00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE00 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL19.88 91.20 683.36 20.50 149.10 45.58 209.10 1566.80 47.00 341.85EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2164.50 2164.50 2164.50 2164.50 54965.2065.0Form MMS-138 (August 2003)Page 3 of 8SUMMARYCOMPANY AREABLOCKLEASEPLATFORM WELLDeep Gulf EnergMississippi Canyon 521OCS-G 34441 0Locations A and D (AlteEmittedSubstanceYearPMSOxNOxVOCCO2015 45.58209.10 1566.80 47.00341.85Allowable2164.50 2164.50 2164.50 2164.50 54965.20Form MMS-138 (August 2003)Page 8 of 8Rig 1/1/2013 Fuel On Board, Bbl 7/1/2013 Fuel On Board, Bbl Fuel Taken On, Bbl Total Fuel Used,
Bbl Daily Ave. Fuel,
Bbl
8500 6580.0 10836.0 50858.0 46602.0 257.47
8501 6870.0 9284.0 48936.0 46522.0 257.03
8503 11812.0 9295.0 39202.0 41719.0 230.49
8505 10618.0 10205.0 43477.0 43890.0 242.49

246.87 bbl/da y
12.95 1 Std. deviation 8500, 8501, 8503, 8505 reported fuel-on-board at beginning (01 Jan. 2013) and ending (01 July 2013) dates, also all fuel taken onbaord that period

8502.0 36582.0 202.11
8506.0 40791.0 225.36

213.74 (bbl/day)

16.44 1 Std. deviation 8502 and 8506 reported total fuel consumption for the period 01 Jan. - 01 July 2013

Rig Total Fuel Used, Bbl Daily Ave. Fuel, Bbl
6 x 8500 Series Rigs 256106.0 235.83 bbl/day

21.15 1 Std. Deviation

63.5 3 std. deviation

299.28 bbls/day, Mean + 3 std. deviations (99.73%)

0.0483 gal/hp-hr (diesel recip. Factor, AQE)

10843.47 HP
21686.94 HP x 2

21739.00 HP used in AQE reporting

600.00 bbl/day used in AQE reporting

257.47

257.03

230.49

242.49

202.11

225.36 Daily Fuel Consumption 8500 series January 1, 2013 to July 1, 2013 (181 days)EXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0049OMB Approval Expires: August 31, 2006COMPANYDeep Gulf Energy II, LLCAREAMississippi CanyonBLOCK521LEASEOCS-G 34441PLATFORMWELLLocations A and D (Alternate Location)COMPANY CONTACTKelley PisciolaTELEPHONE NO.281.698.8519REMARKSDrill and Complete with a DP DrillshipForm MMS-138 (August 2003)Page 1 of 8EMISSIONS FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle leangms/hp-hr0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle leangms/hp-hr0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle richgms/hp-hr0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp.gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boilerlbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flareslbs/mmscf0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaringlbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vaporslbs/bbl0.03E&P Forum 1/93Fugitiveslbs/hr/comp.0.0005API Study 12/93Glycol Dehydrator Ventlbs/mmscf6.6La. DEQ1991Gas Ventinglbs/scf0.0034Sulfur Content Source Value UnitsFuel Gas3.33 ppmDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightForm MMS-138 (August 2003)Page 2 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSDeep Gulf Energy II, LLC Mississippi Canyon521 OCS-G 34441 0 Locations A and D (Alternate Location) Kelley Pisciola281.698.8519OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 29566 1428.0378 34272.91 24 240 20.84 95.60 716.36 21.49 156.30 60.02 275.33 2063.11 61.89 450.13PRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 68 1.46 6.68 50.03 1.50 10.92 0.40 1.82 13.61 0.41 2.97VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 68 3.10 14.23 106.61 3.20 23.26 1.05 4.84 36.25 1.09 7.91VESSELS>600hp diesel(tugs)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK-00 00.000.00DRILLING OIL BURN00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE00 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL25.40 116.51 873.00 26.19 190.47 61.47 281.98 2112.96 63.39 461.01EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2164.50 2164.50 2164.50 2164.50 54965.2065.0Form MMS-138 (August 2003)Page 3 of 8SUMMARYCOMPANY AREABLOCKLEASEPLATFORM WELLDeep Gulf EnergMississippi Canyon 521OCS-G 34441 0Locations A and D (AlteEmittedSubstanceYearPMSOxNOxVOCCO2015 61.47281.98 2112.96 63.39461.01Allowable2164.50 2164.50 2164.50 2164.50 54965.20Form MMS-138 (August 2003)Page 8 of 8Deep Gulf Energy II, LLC Section 8 – Pg. 14 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 8
OIL SPILL INFORMATION

8.1 OIL SPILL RESPONSE PLANNING All the proposed activities and facilities in this EP will be covered by the Regional Oil Spill Response Plan (O SRP) filed by Deep Gulf Ener gy LP (BOEM Operator Number 02815) which includes Deep Gulf Energy II, LLC (BOEM Operator Number 02985) dated May, 2013 and last approved on June 24, 2014 (OSRP Control Number O-578).

8.2 SPILL RESPONSE SITES Primary Response Equipment Location Preplanned Staging Location

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

8.3 OSRO INFORMATION DGE II’s primary equipment prov ider is Clean Gulf Associates (CGA). Clean Gulf Associates Services, LLC (CGA S) will provide closest avai lable personnel, as well as a CGAS supervisor to o perate the equipment.

8.4 WORST CASE SCENARIO DETERMINATION

Category Regional OSRP WCD - Drilling EP WCD - Drilling

Type of Activity Drilling Drilling
Facility Location (Area/Block) MC 521 MC 521

Facility Designation A A

Distance to Nearest Shoreline (miles) 65 65

Volume

 Storage Tanks (Total)

 Uncontrolled blowout Total Volume 155,762 155,762Deep Gulf Energy II, LLC Section 8 – Pg. 15 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) Type of Oil(s) (crude, condensate, diesel) Oil Oil

API Gravity 29° 29°

The WCD calculations and assumptions for the regional OSRP WCD, MC521 Well No. 001 (155,762) were previously reviewed and accepted under Plan control No. N-9824.

DGE II has determined that the wo rst-case scenario from the activities proposed in this EP does supersede the worst-case scenario from our approved Regional OSRP. DGE II
will submit the new worst-case scenario to the BSEE GOMR for inclusion in our Regional OSRP on or bef ore September 12, 2014.

8.5 OIL SPILL RESPONSE DISCUSSION The Oil Spill Response Discussion is included as Attachment 8-A.SPILL RESPONSE DISCUSSION

For the purpose of NEPA and Coastal Zone Mana gement Act analysis, the largest spill volume originating from the proposed activity would be a well bl owout during drilling operations, estimated to be 155,762 barrels of crude oil with an API gravity of 29°.

Land Segment and Resource Identification

Trajectories of a spill and the probability of it impacting a land segment have been projected utilizing information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the BO EM website. The results are shown in Figure 1. The BOEM OSRAM identifies a 21% probability of impact to the shorelines of Plaquemines Parish, Louisiana within 30 days. Plaquemines Parish includes Barataria Bay, the Mississippi River Delta, Breton Sound and the affiliated isla nds and bays. This region is an extremely sensitive habitat and serves as a migratory, breeding, feeding and nursery habitat for numerous species of wildlife. Beaches in this area vary in grain particle size and can be classified as fine sand, shell or perched shell beaches. Sa ndy and muddy tidal flats are also abundant.

Response

DGE II will make every effort to respond to th e Worst Case Discharge as effectively as practicable. A description of the response equipment under contra ct to contain and recover the Worst Case Discharge is shown in Figure 2.

Using the estimated chemical and physical charact eristics of crude oil, an ADIOS weathering model was run on a similar product from the ADIO S oil database. The results indicate 11% or approximately 17,134 barrels of crude oil would be evaporated/dispersed w ithin 24 hours, with approximately 138,628 barrels remaining.

Spill Response MC 521, Well Location A Barrels of Oil

WCD Volume 155,762

Less 20% natural evaporation/dispersion 17,134
Remaining volume 138,628

Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary storage equipment available to respond to the worst case discharge. The volume accounts for the amount remaining after evaporation/dispersion at 24 hours. The list estimates individual times needed for procurement, load out, tr avel time to the site and deployment. Figure 2 also indicates how operations will be supported.

DGE II’s Oil Spill Response Plan includes alternative response technologies such as dispersants and in-situ burn. Strategies will be decided by Unified Command based on the size of the spill, weather and potential impacts. If aerial dispersants are utili zed, 8 sorties (9,600 gallons) from two of the DC-3 aircrafts and 4 sorties (8,000 gall ons) from the Basler ai rcraft would provide adaily dispersant capability of 7,540 barrels. If th e conditions are favorable for in-situ burning, the proper approvals have been obtained and the prope r planning is in place, in-situ burning of oil may be attempted. Slick containment boom woul d be immediately calle d out and on-scene as soon as possible. Offshore response strategies may include attempting to skim utilizing CGA’s spill response equipment, w ith a total derated skimming capac ity of 258,477 barrels. Temporary storage associated with skimming equipment e quals 22,198 barrels. If additional storage is needed, a 107,285 barrel storage barge, a 47,0 00 barrel storage barge, a 25,000 barrel storage barge, and three 23,000 barrel storage barges may be mobilized and centrally located to provide temporary storage allowing the skimmers to stay in the area of operations as much as possible. Safety is first priority. Air monitoring w ill be accomplished and operations deemed safe prior to any containment/skimming attempts.

If the spill went unabated, shoreline impact in Plaquemines Parish, Louisiana would depend upon existing environmental conditions. Shorelin e protection would include the use of CGA’s near shore and shallow water skimmers with a totaled derated sk imming capacity of 45,264 barrels. Temporary storage associated with skim ming equipment equals 567 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 de ployment of shoreline bo om on beach areas, or protection and sorbent boom on vegetated areas. Letters of Intent from AMPOL and OMI Environmental will ensure access to 147,000 f eet 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 survei llance and real time trajectories that depict areas of potential impact given actual sea and w eather conditions. The Stat e of Louisiana Initial Oil Spill Response Plan for Plaquemines Parish and Unified Command would be consulted to ensure that environmental and special economic resources would be co rrectly identified and prioritized to ensure optimal protection. Shorel ine protection strategies depict the protection response modes applicable for o il spill clean-up operati ons. 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 deploym ent and operation of equipment allowing a more effective response to site-specific circumstan ces. DGE II’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 scen ario, DGE II 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 78 hours (based on the equipment’s Effectiv e Daily Recovery Capacity (EDRC)).Initial Response Considerations Actual actions taken during an oil spill response will be based on many factors which include but
are not limited to:

 Weather

 Equipment and materials availability

 Ocean currents and tides

 Location of the spill

 Product spilled

 Amount spilled

 Environmental risk assessments

 Trajectory and product analysis

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

DGE II will take action to provide a safe, aggressi ve 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 se nsitive areas as possible. Safety will take precedence over all other considerations during these operations.

Coordination of response assets will be supe rvised by the designation of a SIMOPS group as necessary for close quarter vessel response activitie s. Most often, this gr oup will be used during source control events that require a significant nu mber of large vessels operating independently, but in coordination to complete a common objec tive, in a small area and in close coordination and support of each other. This group must also monitor the subsurface activ ities of each vessel (ROV, dispersant application, well control sup port, etc.). The SIMOPS group leader reports to the Source Control Section Chief.

In addition, these activities will be monitored by the spill mana gement team (SMT) and Unified Command via a structured Common Operating Picture (COP) esta blished to track resource and slick movement in real time.

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

 Information will be confirmed

 An assessment will be made and initial objectives set

 OSROs and appropriate agen cies will be notified

 ICS 201, Initial Report Form will be completed

 Initial Safety plan will be written and published

 Unified Command will be established

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

o Areas of responsibility esta blished for Source Control a nd each surface operational
site

o On-site command and control establishedDecanting Strategy Recovered oil and water mixtures will typically se parate into distinct phases when left in a quiescent state. When separati on occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with minima l, if any, impact. Decan ting therefore increases the effective on-site oil storage capacity a nd equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill

recovery.

Offshore Response Actions

Equipment Deployment Surveillance

 Surveillance Aircraft will be deployed within two hours of Qu alified Individual (QI) notification, or at first light

 Provide trained observer to pr ovide on site status reports

 Provide command and control platfo rm at the site if needed

 Continual surveillance of oil movement by re mote sensing systems, aerial photography and visual confirmation

 Continual monitoring of vessel assets using vessel monitoring systems

Dispersant application assets

 Put Airborne Support In c. (ASI) on standby

 With the Federal On-Scene Coordinator (FOSC), conduct analysis to determine appropriateness of dispersant application

 Gain FOSC approval for use of dispersants on the surface

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

 Coordinate movement of dispersants, ai rcraft, and support equipment and personnel

 Confirm dispersant availability fo r current and long range operations

 Start ordering dispersa nt 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 aer ial dispersant and in-situ burn operationsCGA HOSS Barge

 Use in areas with heaviest oil concentrations

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

CGA FRUs

 To the area of the thickest oil

 Use as far off-shore as allowed

 VOOs 140’ – 180’ in length

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

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

T&T Koseq Skimming Systems

 To the area of the thickest oil

 Use as far off-shore as allowed

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

 VOOs at least 200’ in length

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

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

Storage Vessels

 Establish availability of CGA contracted assets

 Early call out (to allow for tug boa t 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 ski mming assets to minimize offloading time

Vessels of Opportunity (VOO)

 Use DGE II’s contracted resources as applicable

 Industry vessels are usually best for depl oyment 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 sa fety training to be required

 Plan with the US Coast Guard for vessel inspectionsIn-situ Burn assets

 Determine appropriateness of in-situ burn ope ration in coordination with the FOSC and affected State On-Scene Coordinator (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

Adverse Weather Operations:

In adverse weather, when seas are > 3 feet, th e use of larger recovery and storage vessels, oleophilic skimmers, and large offshore boom will be maximized. Safety will be the overriding factor in all operations and will cease at the orde r of the Unified Command, vessel captain, or in an emergency, ”stop work” may be directed by any crew member.Near Shore Response Actions

Timing

 Place near shore assets on standby and depl oy in accordance with planning based on the actual situation, actual traj ectories and oil budgets

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

 Outfitting of VOOs for specific missions

 Deployment of assets based on actual movement of oil

Considerations

 Water depth, vessel draft

 Shoreline gradient

 State of the oil

 Use of VOOs

 Distance of surf zone from shoreline

Equipment Deployment Surveillance

 Provide trained observer to direct skimming operations

 Continual surveillance of oil movement by re mote 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 Re sponse Team level (Region 6)

Vessel Deployment Dedicated Near Shore skimming systems

 Fast Response Vessels (FRV)

 Egmopol and Marco Shallow Water Skimmer (SWS)

 Operate with aerial spotter directi ng systems to observed oil slicks

VOO

 Use DGE II’s contracted resources as applicable

 Industry vessels are usually best for depl oyment 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 sa fety training to be required

 Plan with the US Coast Guard for vessel inspections

 Operate with aerial spotter directing systems to oil patchesShoreline Protection Operations

Response Planning Considerations

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

 Time to acquire personnel and eq uipment and their availability

 Previous contingency planning contained in the appropriate Area Contingency Plan, and currently for Louisiana, The State of Loui siana 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 site s and gaining authority to enter

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

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

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

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

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

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

 Passive clean up of marshes should be consider ed and appropriate stoc ks of sorbent boom and/or sweep obtained

 Earthen berms and shoreline protection boom may be considered to protect sensitive inland areasDecanting Strategy Recovered oil and water mixtures will typically se parate into distinct phases when left in a quiescent state. When separati on occurs, the relatively clean water phase can be siphoned or decanted back to the recovery point with minima l, if any, impact. Decan ting therefore increases the effective on-site oil storage capacity a nd equipment operating time. FOSC/SOSC approval will be requested prior to decanting operations. This practice is routinely used for oil spill

recovery.

CGA Equipment Limitations The capability for any spill response equipment, whether a dedicated or portable system, to operate in differing weather conditions will be directly in rela tion 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 a nd/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 opera tions ceased when seas reache d 5-6 feet and vessels were often recalled to port when those conditions were exceeded. Systems below are some of the most up-to-date systems available and were employed during the DWH spill.

Boom 3 foot seas, 20 knot winds Dispersants Winds more than 25 knots Visibility less than 3 nautical miles Ceiling less than 1,000 feet.
FRU 8 foot seas HOSS Barge/OSRB 8 foot seas Koseq Arms 8 foot seas
OSRV 4 foot seasEnvironmental Conditions in the GOM Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences westerly winds during the wint er and easterly winds in the summer. Average wind speed is generally 14-15 mph along the coast. Wave he ights 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 temperatur e will range from 50 and 60  ̊ F.

The Atlantic and Gulf of Mexico hurricane seas on is officially from 1 June to 30 November. 97% of all tropical activity occurs within this window. The Atlant ic 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 occurri ng then. Maximum activity is in early to mid September. Once in a few years there may be a hurri cane occurring "out of season" - primarily in May or December. Globally, September is the mo st active month and May is the least active
month.FIGURE 1 TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it impacting a land segment have been projected utilizing DGE II’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

Drill and Complete

Well Location B

MC 521, Well Location A 65 miles from shore G34441 C57 Cameron, LA Vermilion, LA Terrebonne, LA Lafourche, LA Plaquemines, LA

St. Bernard, LA Hancock & Harrison, MS Jackson, MS Mobile, AL Baldwin, AL Escambia, AL Okaloosa, FL

Walton, FL

Bay, FL 1
1
2
2
21
3
1
1
1
1
1
1
1
1WCD Scenario– BASED ON WELLBLOWOUT DURING DRILLING OPERATIONS (65 miles from shore)138,628 bbls of crude oil (Volume considering natural weathering)API Gravity 29°FIGURE 2 – Equipment ResponseTime to MC 521, Well Location ADispersants/SurveillanceDispersant/SurveillanceDispersantCapacity (gal)StorageCapacityPersons Req.FromHrs toProcureHrs toLoadoutTravel tositeTotal HrsASIBasler 67T 2000 NA 2 Houma 2 2 0.9 4.9DC 3 1200 NA 2 Houma 2 2 1.1 5.1DC 3 1200 NA 2 Houma 2 2 1.1 5.1Aero Commander NA NA2 Houma 2 2 0.9 4.9Offshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 10 1 2395’ FRV 12342 249 NA 4 Leeville 2 0 2 5.2 0 9.295’ FRV 12342 249 NA 4 Venice 2 0 1 3.2 0 6.2Boom Barge (CGA-300)42” Auto Boom (25000’)NA NA1 Tug50 Crew4 (Barge)2 (Per Crew)Leeville 4 0 6 18.6 1.5 30.1Recovered Oil Storage NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsK-Sea Operating (available through contract with CGA)DBL 101 1119760 NA 107285 1 Tug 6 Venice 4 12 4 11 1 32Enterprise Marine Services LLC (available through contract with CGA)CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGAFRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 2 2 12.7 6.7 1 24.4FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 2 2 2.1 6.7 1 13.8FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 2 2 17.7 6.7 1 29.4FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 2 2 8 6.7 1 19.7FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 2 2 4.4 6.7 1 16.1FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 2 2 4.9 6.7 1 16.6FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 2 2 0 6.7 1 11.7Hydro-Fire Boom NA NA 8 Utility 40 Harvey 2 4 2.1 6.7 6 20.8T&T Marine (available through contract with CGA)Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 12.7 6.7 1 36.4Koseq Skimming Arms (4) 71316 8000 4 Utility 24 Galliano 24 24 4.25 6.7 2 60.95Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey 24 24 2.1 6.7 2 58.8Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGA46’ FRV 5000 65 NA 4 Morgan City 2 0 2 4.8 0 8.846’ FRV 5000 65 NA 4 Venice 2 0 1 2.0 0 5Trinity SWS 21500 249 NA 4 Venice 2 2 2 2.0 0 8Enterprise Marine Services LLC (available through contract with CGA)CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36Staging Area: VeniceNearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGASWS Egmopol 3000 100 NA 3 Morgan City 2 2 4.9 2 0 10.9SWS Marco 3588 20 NA 3 Lake Charles 2 2 8 2 0 14SWS Marco 3588 34 NA 3 Leeville 2 2 4.4 2 0 10.4SWS Marco 3588 34 NA 3 Venice 2 2 0 2 0 6Shoreline ProtectionStaging Area: VeniceShoreline ProtectionBoomVOOPersonsReq.Storage/WarehouseLocationHrs toProcureHrs toLoadoutTravel toStagingTravel toDeployment SiteHrs toDeployTotal HrsAMPOL (available through MSA)42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 6 2 12 2420,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2.2 2 6 14.2OMI Environmental (available through MSA)10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 6 2 3 1310,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 12.1 2 3 19.110,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 9.7 2 3 16.720,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.9 2 6 11.910,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 4.5 2 3 11.510,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.8 2 3 10.815,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.1 2 4 12.1Wildlife ResponseEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGAWildlife Support Trailer NA NANA 2 Harvey 2 2 2.1 1 2 9.1Bird Scare Guns (48) NA NANA 2 Harvey 2 2 2.1 1 2 9.1Bird Scare Guns (12) NA NANA 2 Galveston 2 2 12.7 1 2 19.7Bird Scare Guns (12) NA NA NA2 Aransas Pass 2 2 17.7 1 2 24.7Bird Scare Guns (24) NA NA NA 2 Lake Charles 2 2 8 1 2 15Bird Scare Guns (24) NA NA NA 2 Leeville 2 2 4.4 1 2 11.4Response AssetTotalOffshore EDRC 258,477Offshore Recovered Oil Storage 270,483Nearshore / Shallow Water EDRC 45,264Nearshore / Shallow Water Recovered Oil Storage 60,567Deep Gulf Energy II, LLC Section 9 – Pg. 16 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 9
ENVIRONMENTAL MONITORING INFORMATION

9.1 MONITORING SYSTEMS
DGE II subscribes to Wilkens Weather Serv ice which provides access to real time weather conditions and provides periodi c updates on impending weather conditions such as tropical depressions, storms, and/or hurricanes entering the Gulf of Mexico.

DGE II also relies on the National Weat her Service to support the aforementioned
subscribed service. Duri ng impending inclement weather conditions, DGE II closely coordinates the activity with our contractor s and field personnel to ensure the safety of people for evacuation to ensure prot ection of the environment and the facility/equipment.

DGE II will monitor loop currents per the requi rements as set forth in NTL 2009-G02, “Ocean Current Monitoring.”

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

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

DGE II will adhere to the requirements as se t forth in the following documents, as applicable, to avoid or minimize impacts to any of the species listed in the Endangered Species Act (ESA) as a result of the operations conducted herein:

 NTL No. 2012-BSEE-G01, “Marine Trash and Debris Awareness and Elimination”

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

 NTL No. 2012-JOINT-G02, “Implementat ion of Seismic Survey Mitigation Measures and Protected S pecies Observer Program”

9.3 FLOWER GARDEN BANKS NAT IONAL MARINE SANCTUARY Mississippi Canyon Block 521 is not located in the Fl ower Garden Banks National Marine Sanctuary; therefore, relevant information is not required in this EP.Deep Gulf Energy II, LLC Section 10 – Pg. 17 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 10
LEASE STIPULATIONS INFORMATION

Exploration activities are subject to the foll owing stipulations attached to Lease OCS-G 34441, Mississippi Canyon Block 521.

10.1 MARINE PROTECTED SPECIES In accordance with the Federal Endang ered Species Act and the Marine Mammal Protection Act, DGE II will:

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

(b) post signs in prominent places on all ve ssels and platforms used as a result of activities related to exploration, developm ent, and production of this lease detailing the reasons (legal and ecological) why rel ease 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 whal es, 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 su rveys, including the us e of an “exclusion zone” based upon the appropriate water depth, ramp-up and shutdown procedures, visual monitoring, and reporting;

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

(f) immediately report all sightings and loca tions of injured or dead protected species (e.g., marine mammals and sea tu rtles) to the appropriate st randing network. If oil and gas industry activity is responsible for t he injured or dead animal (e.g., because of a vessel strike), the responsible parties should remain available to assist the strandingDeep Gulf Energy II, LLC Section 10 – Pg. 18 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 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 (N TLs), which more fully describe measures implemented in support of the above-menti oned implementing statutes and regulations, as well as measures identified by the U.S. Fish and Wildlife Serv ice and NMFS arising from, among others, conservation recommendat ions, rulemakings pursuant to the MMPA, or consultation. The lessee and it s 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 Protec ted Species Reporting;” NTL No. 2012- JOINT-G02, “Implementation of Seismic Survey Mitigati on Measures and Protected Species Observer Program;” and NTL No. 2012-BSEE-G01, “Marine Trash and Debris
Awareness and Elimination.” At the lessee’s option, t he lessee, its operators, personnel, and contractors may comply with t he 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 versi ons of the NTLs identified in this paragraph. The lessee and its operators, personnel, and subcontractors will be required to comply with the mitigation measures, identifie d in the above referenced NT Ls, and additi onal measures in the conditions of approvals for their plans or permits.Deep Gulf Energy II, LLC Section 11 – Pg. 19 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 11
ENVIRONMENTAL MITIGATION MEASURES INFORMATION

11.1 MEASURES TAKEN TO AVOID, MI NIMIZE, AND MITIGATE IMPACTS Mississippi Canyon Block 521 is not located within Florida; therefore, mitigation information is not required for the ac tivities proposed in this plan.

11.2 INCIDENTAL TAKES DGE II will adhere to the requirements as set forth in the following documents, as applicable, to avoid or minimize impacts to any of the species listed in the Endangered Species Act (ESA) as a result of the operations conducted herein:

 NTL No. 2012-BSEE-G01, “Marine Trash and Debris Awareness and Elimination”

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

 NTL No. 2012-JOINT-G02, “Implementat ion of Seismic Survey Mitigation Measures and Protected S pecies Observer Program”Deep Gulf Energy II, LLC Section 12 – Pg. 20 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 12
SUPPORT VESSELS AND AIRCRAFT INFORMATION

12.1 GENERAL The most practical, direct route from the shore base as permitted by weather and traffic
conditions will be utilized.

Type Maximum Fuel Tank Capacity Maximum Number in Area at Any Time Trip Frequency or Duration
Crew Boat 1500 bbls 2 2 per week

Supply Boat 1500 bbls 2 2 per week

Helicopter 600 gals 1 6 per week

12.2 DIESEL OIL SUPPLY VESSELS
Size of Fuel Supply Vessel Capacity of Fuel Supply Vessel Frequency of Fuel Transfers Route Fuel Supply Vessel Will Take 240’ 2500 bbls 1 per week Direct to Fourchon

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

12.4 SOLID AND LIQUID WASTE TRANSPORTATION A table, “Wastes You Will Transpor t and/or Dispose of Onshore,” is included as
Attachment 12-A.

12.5 VICINITY MAP A vicinity map showing the location of the activities proposed herein relative to the shoreline with the distance of the proposed ac tivities from the sh oreline and the primary route(s) of the support vessels and aircraft that will be used when traveling between the onshore support facilities and the drilling unit is included as Attachment 12-B.please specify whether the amount reported is a total or per wellSolid and Liquid WastestransportationType of WasteComposition Transport MethodName/Location ofFacilityAmountDisposal MethodWill drilling occur ? If yes, fill in the muds and cuttings.Oil-based drilling fluid or mudN/A N/A N/A N/A N/ASynthetic-based drilling fluid or mudinternal olefinBelow-deck storage tanks on offshoresupport vesselsM-I Swaco, PortFourchon, LA20,000 bbls/well RecycledCuttings wetted with Synthetic-based fluidCuttings generated using syntheticbased fluidBelow-deck storage tanks on offshoresupport vesselsNewport EnvironmentalServices Inc., Ingleside,TX1,000 bbls/well RecycledCuttings wetted with oil-based fluidsN/A N/A N/A N/A N/AWill you produce hydrocarbons? If yes fill in for produced sand.Produced sandN/A N/A N/A N/A N/AWell Completion FluidsNaCL/NaBrBelow-deck storage tanks on offshoresupport vesselsNewport EnvironmentalServices, Inc., Ingleside,TX6,000 bbls/well RecycledWorkover FluidsNaCL/NaBrBelow-deck storage tanks on offshoresupport vesselsNewport EnvironmentalServices, Inc., Ingleside,TX6,000 bbls/well RecycledTrash and debrisNon-hazardous trash & debris(nonrecyclables)Transport in DOT containers on supplyvessels to shorebaseProgressive WasteSolutions of LA, Houma,LA700 lbs/well Disposed in landfillUsed oilUsed oil and glycolTransport in DOT containers on supplyvessels to shorebaseSafety Kleen System,Baton Rouge, LA420 gal/well (10bbls/well)RecycledChemical product wastesPaints, solvents, unusedchemicals, etcTransport in DOT containers on supplyvessels to shorebaseSafety Kleen System,Baton Rouge, LA130 lbs/well RecycledNOTE: Ifyou will not have a type of waste, enter NA in the row.TABLE 12-A WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHOREWaste DisposalWill you have additional wastes that are not permitted for discharge? If yes, fill inthe appropriate rows.Projected generated waste!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!South Marsh IslandNorthTheodore, ALLundAtwater ValleyGreen CanyonGarden BanksMississippi CanyonWalker RidgeKeathley CanyonHigh IslandLloyd RidgeVermilionEast BreaksShip ShoalDeSoto CanyonMobileWest CameronHendersonMain PassViosca KnollSouth TimbalierWest DeltaEwing BankPensacolaBaton RougeLafayetteBeaumontLake CharlesPascagoulaGulfportPort ArthurPensacola4959105565110De Soto NFAngelina NFSabine NFHomochitto NFKisatchie NFBig Thicket NPRESDeep Gulf Energy II. LLCVicinity MapMississippi Canyon 521MC521

~ 1 3 1 . 9 M i l e s t o F o u r c h o n , L A S h o r e b a s e ~ 1 2 1

. 8 M i l e s t

o A l a b a m a

6 5 M i l e s t o L o u i s i a n a

~ 3 5 7 M i l e s t o T e x a sDeep Gulf Energy II, LLC Section 13 – Pg. 21 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 13
ONSHORE SUPPORT FACILITIES INFORMATION

13.1 GENERAL Name Location Existing/New/Modified

Fourchon C-Port Port Four chon, Louisiana Existing

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

13.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE A support base construction or expansion time table is not required for the activities proposed in this plan.

13.4 WASTE DISPOSAL The Table, “Wastes You Will Transport and/ or Dispose of Onshore, “is included as
Attachment 12-A.Deep Gulf Energy II, LLC Section 15 – Pg. 22 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 14
COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION Relevant enforceable policies were considered in certifying consistency for Louisiana. A certificate of Coastal Zone Management C onsistency for the state of Louisiana is
included as Attachment 14-A.

Relevant enforceable policies were considered in certifying consistency for Texas. A
certificate of Coastal Zone Ma nagement Consistency for the st ate of Texas is included

as Attachment 14-B.

Relevant enforceable policies were considered in certifying consistency for Alabama. A certificate of Coastal Zone Management Cons istency for the state of Alabama is
included as Attachment 14-C.Deep Gulf Energy II, LLC Section 15 – Pg. 23 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) As authorized by the Federal Coastal Zo ne Management Act (CZM A), the State of Texas developed a Coastal Management Program (CMP) to allow for the review of proposed Federal license and permit activities affecting any coastal use or resource, in
or outside of the Texas Coastal Zone.

The OCS related oil and gas exploratory and development activities having potential impact on the Texas Coastal Zone are based on the location of the proposed facilities, access to those sites, best practical techniq ues for drilling location s, drilling equipment guidelines for the prevention of adverse environmental effe cts, effective environmental protection, emergency pl ans and contingency plans.

Listed below are the policies an d corresponding sections with in this Exploration Plan identified by the State of Texas CMP as being related to OCS Plans:

Policy of the Texas Coastal Management Plan (TCMP)

(Texas Administrative C ode, Title 31, Park 16, C hapter 501, Subchapter B)

Policies EP Section Evaluation Category 2: Construction, Operation and Maintenance of Oil and Gas Exploration and Production Facilities (501.17) 1 Plan Contents
2 General The proposed activities are located approximately 357
miles from the nearest Texas coastline, No adverse impacts on Texas submerged lands, critical areas, wetlands, beaches, or
other coastal resources from
routine activities are anticipated. Category 3: Discharges of Wastewater and Disposal of Waste from Oil and Gas Exploration and Production Activities (501.18) 6 Wastes and Discharges No adverse impacts on the
Texas coastal zone are anticipated. The proposed activities do not involve any discharges to the Texas coastal zone as the project is approximately 357 miles from the nearest Texas coastline, All offshore discharges associated with the proposed activities, as summarized inDeep Gulf Energy II, LLC Section 15 – Pg. 24 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) Section 6 and evaluated in Section 15, will be conducted
in accordance with regulations implemented by
the United States
Environmental Protection Agency (USEPA), the U. S. Coast Guard (USCG), and the Bureau of Ocean Energy Management (BOEM). All wastes generated during drilling that do not meet discharge regulations will be properly transported to City, State, and disposed of as
summarized in Section 12. Category 4: Construction and Operation of Solid Waste Treatment, Storage, and Disposal Facilities (501.19) 6 Wastes and Discharges 13 Onshore Support
Facilities All solid wastes generated by the activities proposed in this plan will be treated, stored, and disposed of in State following applicable rules and regulations as described in
Section 12. Category 5: Prevention, Response, and Remediation of Oil Spills (501.20) 2 General 8 Oil Spill The proposed activities
summarized in Section 8 will comply with all applicable laws and regulations concerning oil spill prevention, response, and remediation. The proposed
activities will be covered under Deep Gulf Energy LP’s approved Regional Oil Spill Response Plan (OSRP), which includes Deep Gulf Energy II, LLC. The proposed
activities are located approximately 357 miles fromDeep Gulf Energy II, LLC Section 15 – Pg. 25 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) the nearest Texas coastline and no significant impacts on
the Texas coastal zone are expected. Category 6: Discharge of Municipal and Industrial Waste Water to Coastal Waters (501.21) 6 Wastes and Discharges No discharges to Texas coastal waters are proposed (Section 6) and no adverse impacts are expected. The proposed activities are located approximately 357
miles from the nearest Texas
coastline and will be
conducted in accordance with discharge regulations implemented by the USEPA, the USCD, and BOEM. Category 7: Non Point Source Pollution (501.22) 6 Wastes and Discharges The proposed activities do not include nonpoint sources of water pollution and no adverse impacts are expected. Category 8: Development in Critical Areas (501.23) 5 Biological, Physical
and Socioeconomic 10 Lease Stipulations
11 Environmental Mitigation Measures 13 Onshore Support
Facilities 15 Environmental Impact Analysis No activities are proposed in
critical areas and no adverse impacts on critical areas from
routine activities are expected.

Category 9: Construction of Waterfront Facilities and Other Structures on Submerge lands (501.24) 2 General
7 Air Emissions 13 Onshore Support
Facilities 15 Environmental Impact Analysis No construction of waterfront
facilities or other structures on Texas submerged lands is proposed and no adverse impacts from routine activities are expected. Category 10: Dredging and Dredged 13 Onshore Support
Facilities No dredging or dredged material disposal orDeep Gulf Energy II, LLC Section 15 – Pg. 26 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) Material Disposal and Placement (501.25) placement is proposed and no adverse impacts are expected. Category 11: Construction in the Beach / Dune System (501.26) 13 Onshore Support
Facilities No construction in the beach/dune system is proposed and no adverse impacts from routine activities are expected. Category 12: Development in Coastal Hazard Area (501.27) 13 Onshore Support
Facilities No development in coastal hazard areas is proposed and no adverse impacts are expected. Category 13: Development within Coastal Barrier Resource (501.28) 13 Onshore Support
Facilities No development within the
Texas coastal barrier resource system is proposed and no adverse impacts from
routine activities are expected. Category 14: Development in State Parks, Wildlife Management Areas or Preserves (501.29) 13 Onshore Support
Facilities No development in Texas state parks, wildlife management areas, or preserves is proposed and no adverse impacts from routine activities are expected. Category 15: Alteration of Coastal Historic Areas (501.30) 5 Biological, Physical,
and Socioeconomic 15 Environmental Impact Analysis The proposed activities do not include any development that
would alter or disturb coastal
historic areas and no adverse impacts from routine activities are expected. Category 16: Transportation Projects (501.31) 13 Onshore Support
Facilities No transportation construction or maintenance projects are proposed and no adverse impacts are expected. Category 17: Emission of Air Pollutants (501.32) 7 Air Emissions 15 Environmental Impact Analysis Air emissions associated with project activities are
summarized in Section 7. The proposed activities will beDeep Gulf Energy II, LLC Section 15 – Pg. 27 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) conducted in conformance with applicable air quality laws, standards, and regulations. No adverse impacts on onshore air quality are expected based on the emission rates, prevailing atmospheric conditions, and
the distance from the nearest
Texas coastline (approximately 357 miles) as
discussed in Section 15. Category 18: Appropriations of Water (501.33) 13 Onshore Support
Facilities No appropriations, impoundments, or diversions
of water resources are proposed and no adverse impacts are expected. Category 19: Levee and Control Projects (501.34) 13 Onshore Support
Facilities No levee or flood control projects are proposed and no adverse impacts are expected. Category 20: Marine Fishery Management 15 Environmental Impact Analysis No adverse impacts on
marine fisheries are anticipated. Category 22: Policies for Major Actions (501.15) 15 Environmental Impact Analysis The proposed activities are not a “major action” as defined by 501.15Deep Gulf Energy II, LLC Section 15 – Pg. 28 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) The OCS related oil and gas development ac tivities having potential impact on the
Alabama Coastal Zone are based on the loca tion of the proposed facilities, access to those sites, best practical techniqu e for operations and production equipment, guidelines for the prevention of adverse environmental effect s, effective environmental protection, emergency plans and contin gency plans. Alabama policies have been
addressed below or are cross referenced to the appropriate sectio ns of the plan:

Topic Cross Reference Comments

Coastal Resource Use Policies Coastal Development Dock and port facilities in Louisiana will be used. There will be no new construction, dredging, or filling in Alabama state waters. There will be no new commercial development or capital im provements in Alabama’s coastal zone, nor will there be any employment effects. Mineral Resource Exploration and Extraction Proposed exploration operat ions will take place approximately 121.8 miles from Alabama’s coastline.

Commercial Fishing Section 8

Hazard Management Section 3 A Shallow Hazard s Report has been prepared and submitted to BOEM in order to identify and assess the seafloor and shallow geologic conditions in this block. Shoreline Erosion Section 8 Proposed exploration operations will take place approximately 121.8 miles from Alabama’s coastline. Recreation Section 8 Transportation Section 12
Natural Resource Protection Policies Biological Productivity Section 8

Water Quality Section 8 Water Resources Section 8

Air Quality Section 7 Wetlands and Submerged Grassbeds Section 8Deep Gulf Energy II, LLC Section 15 – Pg. 29 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441)

Beach and Dune Protection Section 8

Wildlife Habitat Protection Section 8

Endangered Species Section 8

Cultural Resources Protection Section 5 Mississippi Canyon Block 521 is not located in an area where historic shipwrecks may exist. An archaeological report was prepared by Geos cience Earth & Marine Services, Inc. (GEMS) and it was determined that there are no known historic shipwrecks located in the block. The report is submitted with this EP.

The proposed activities described in detail in this Plan comply with Alabama’s approved Coastal Zone Management Progr ams and will be conducted in a manner consistent with such Programs.Deep Gulf Energy II, LLC Section 15 – Pg. 30 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 15
ENVIRONMENTAL IMPACT ANALYSIS

The Environmental Impact Analysis is included as Attachment 15-A.

## Deep Gulf Energy II, LLC (DGE II)

Initial Exploration Plan Mississippi Canyon Block 521 OCS-G 34441

(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, H 2 S releases) Discarded Trash & Debris

Site-specific at Offshore Location
Designated topographic features (1) (1) (1)

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

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

Benthic communities (4)
Water quality X X

Fisheries X X

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

Sea Turtles X(8) X X(8) X
Air quality X(9)
Shipwreck sites (known or potential) (7)

Prehistoric archaeological sites X(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 areasFootnotes for Environmental Impact Analysis Matrix

1) Activities that may affect a marine sanctuary or topographic feature. Specifically, if th e 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) w ith relief greater than 2 meters that is not protected by the Topographic Features Stipul ation attached to an OCS lease.
2) Activities with any bottom disturbance within an OCS l ease block protected through the Live Bottom (Pinnacle Trend) Stipulation attached to an OCS lease. 3) Activities within any Eastern Gulf OCS block where seaflo or habitats are protected by the Live Bottom (LowRelief) 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 concentr ations greater than 500 ppm might be encountered. 6) All activities that could result in an accidental spill of produced liquid hydr ocarbons or diesel fuel that you determine would impact these environmental resources. If the proposed action is lo cated 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 leas e 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 trans portation of produced fluids to shor e using shuttle tankers or barges.

### (B) Analysis

Site-Specific at Mi ssissippi Canyon 521
Proposed operations consist of the drilling an d completion of Well Lo cations A and D. The operations will be conducted with a drillshi p or dynamically positioned semisubmersible.

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

Effluents: Mississippi Canyon Block 521 is 86 miles from the closest designated Topographic Features Stipulation Block (Sackett Bank); ther efore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surf ace 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 orga nisms. 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 ma gnitude lower than the amount shown to have an effect on corals. Becau se the crests of topogr aphic features in the Northern Gulf of Mexico are found below 10 m, no oil from a surface sp ill could reach their sessile biota. Oil from a subsurface spill is not app licable due to the distance of these blocks from a topographic area. The activities proposed in this plan will be covere d by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

There are no other IPFs (includi ng emissions, physical disturbances to the seafloor and wastes sent to shore for disposal) from the proposed act ivities, which could impact topographic features.

2. Pinnacle Trend Area Live Bottoms
Potential IPFs on pinnacle trend area live bo ttoms include effluent s and accidents.

Effluents: Mississippi Canyon Block 521 is 49.5 miles from the closest live bottom (pinnacle trend) area; therefore, no adve rse impacts are expected.

Accidents: It is unlikely that an accidental surf ace or subsurface spill would occur from the proposed activities (refer to statistics in Item 5 , Water Quality). Oil spill s have the potential to foul benthic communities and cause lethal and sublethal effects on live bottom organisms. Oil from a surface spill can be dr iven 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 a pplicable due to the distance of these blocks from a live bottom(pinnacle trend) area. The activi ties proposed in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

There are no other IPFs (includi ng 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.

Effluents: Mississippi Canyon Block 521 is not located in an area characterized by the existence of live bottoms; therefor e, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surf ace 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 organi sms. 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 ma gnitude lower than the amount shown to have an effect on marine inve rtebrates. 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 DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

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

4. Benthic Communities There are no IPFs (including emissions, physical di sturbances to the seaf loor, wastes sent to shore for disposal, or a ccidents) from the proposed activities that could cause impacts to benthic
communities.

A drillship or dynamically positioned semisubmersibl e is being used for the proposed activities; therefore, only an insignificant amount of s eafloor will be disturbed. Because physical disturbances to the seafloor will be minimized by the use of a drillship or dynamically positioned semisubmersible, DGE II’s proposed operations in Mississippi Canyon Block 521 would not cause impacts to benthic communities.

5. Water Quality
IPFs that could result in water quality degrada tion from the proposed oper ations in Mississippi Canyon Block 521 include effluents and accidents.Effluents: Levels of contaminants in drilling muds and cuttings and produced water discharges, discharge-rate restrictions a nd monitoring and toxicity testin g are regulated by the EPA NPDES permit, thereby eliminating many significant bi ological or ecological effects. Operational discharges are not expected to cause si gnificant adverse impacts to water quality.

Accidents: Oil spills have the potential to alter o ffshore water quality; how ever, it is unlikely
that an accidental surface or s ubsurface spill would occur from th e 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 da ta were collected), there were 80 reported diesel spil ls greater than one barrel associ ated with drilling activities. Considering that there were 11,944 wells drille d, this is a 0.7 percen t 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 seve ral months afterwards. Most of the components of oil are insoluble in water and therefore floa t. The activities proposed in this plan will be covered by DGE II’s Regional Oil Spill Response Plan (refer to information submitted in Section 8 ).

There are no other IPFs (includi ng 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 pr oposed operations in Mississippi Canyon Block 521 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 downcurrent from the discharge point. Offshore discharges are expected to disperse and dilute to very near background levels in the water column or on the seafloor within 3,000 m of the discharge point, and are expected to have negligible effect on fisheries.

Accidents: An accidental oil spill has the potent ial 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 woul d be reduced to the cap acity of adult fish and shellfish to avoid the spill, to metabolize hydr ocarbons, and to excrete both metabolites andparent compounds. The activities pr oposed in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

There are no IPFs from emissions, physical disturba nces to the seafloor or wastes sent to shore for disposal from the proposed activities which could cause imp acts to fisheries.

7. Marine Mammals

GulfCet II studies revealed that cetaceans of the continental shelf and shelf-edge were almost exclusively bottlenose dolphin a nd Atlantic spotted dolphin. S quid eaters, including dwarf and pygmy killer whale, Risso’s dolphin, rough-toothed dolphin, a nd 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 Mississippi Canyon Block 521 include emissions, effluents, discar ded 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 vul nerable to parasites, disease, environmental contaminants, and/or predation (Majors and Myri ck, 1990). There is little conclusive evidence for long-term displacements and population tren ds for marine mammals relative to noise.

Effluents: Drilling fluids and cutti ngs discharges contain components which may be detrimental to marine mammals. Most operational discharges are diluted and dispersed upon release. Any potential impact from drilling flui ds 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 inge stion 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 act ivities 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 Polluti on Research and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA).

DGE II 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 coveri ng outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised when handlin g and disposing of small items and packaging materials, particularly those made of non-biode gradable, 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 personne l, including contract ors and other supportservices-related personnel (e.g. helicopter pilots, vessel capt ains 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 debr is training video annually. Offshore personnel will also receive an explanation from DGE II management or the designated lease operator management that emphasizes their commi tment 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 mamma l species immediately, regardless of whether the injury or death is cau sed 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 Networ k at (305) 862-2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@boemre.gov . If the vessel is the responsible party, it is required to remain available to assist the respective salvage and stranding network as needed.

Oil spills have the potential to cause sublethal oil-related injuries and spill-related deaths to marine mammals. However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). Oil spill response activities may increase vessel traffic in the area, which could add to changes in cetacean behavior and/or distribution, thereby causing additional stress to the animals. The effect of oil dispersants on cetaceans is not known. The acute toxicity of oil dispersant chem icals included in DGE II’s OSRP is considered to be low when compared with the constituents and fractions of crude o ils and diesel products. The activities proposed in this plan will be covered by DGE II’s OSRP (refer to information submitted in accordance with Section 8 ).

There are no other IPFs (including physical di sturbances 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 tr ash and debris, and accidents. Gu lfCet II studies sighted most loggerhead, Kemp’s ridley and le atherback sea turtles over shel f 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 sp ecies as a transitory habitat.Emissions: Noise from drilling activi ties, support vessels, and heli copters may elicit a startle reaction from sea turtles, but th is is a temporary disturbance.

Effluents: Drilling fluids and cuttings discharges are not k nown to be lethal to sea turtles. Most operational discharges are dilu ted 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 inge stion of, debris have caused the death or serious injury of sea tu rtles (Balazs, 1985). The limited am ount of marine debris, if any, resulting from the proposed activitie s is not expected to substantially harm sea turtles. Operators are prohibited from deliberately discharging de bris as mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Ac t, and regulations imposed by various agencies including the United States Coast Guard (USC G) and the Environmental Protection Agency (EPA). DGE II will operate in acc ordance 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 outsid e 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 personne l, including contract ors and other support services-related personnel (e.g. helicopter pilots, vessel capt ains 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 debr is training video annually. Offshore personnel will also receive an explanation from DGE II management or the designated lease operator management that emphasizes their commi tment to waste management in accordance with NTL No. 2012-G01.

Accidents: Collisions between support vessels and s ea turtles would be unusual events, however should one occur, death or injury to sea turtles is possible. Cont ract vessel operators can avoid sea turtles and reduce potential deaths by main taining a vigilant watch for sea turtles and maintaining a safe distance when they are sighte d. 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 inju red or dead protecte d sea turtle species immediately, regardless of whethe r 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 th e Marine Mammal Stranding Ne twork at (305) 862-2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM must be notified within 24 hours of the strike by email to protectedspecies@boemre.gov . If the vesselis 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 vulnerab le to the harmful e ffects of oil through direct contact or by fouling of their food. Exposure to oil can be fa tal, particularly to juveniles and hatchlings. However, it is un likely that an accidental oil sp ill would occur from the proposed activities (refer to Item 5 , Water Quality). Oil sp ill response activities ma y 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 DGE II’s Regional Oil Spill Re sponse Plan (refer to information submitted in accordance with Section 8 ).

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

9. Air Quality
Mississippi Canyon Block 521 is located 93 miles from the Breton Wilderness Area and 65 miles from shore. Applicable emissions data is included in Section 7 of the Plan.

There would be a limited degree of air quality degradation in the immediate vicinity of the proposed activities. Plan Emissions for th e proposed activities do not exceed the annual exemption levels as set forth by BOEM. Acci dents and blowouts can release hydrocarbons or chemicals, which could cause the emission of air pollutants. However, th ese releases would not impact onshore air quality because of the prev ailing atmospheric cond itions, emission height, emission rates, and the distance of Mississippi Canyon Block 521 from the coastline. There are no other IPFs (including effluents, physical disturbances to the seaf loor, wastes sent to shore for treatment or disposal) from the proposed activities which would impact air quality.

10. Shipwreck Sites (known or potential)
Potential IPFs that could impact known or unknown shipwreck sites as a re sult of the proposed operations in Mississippi Canyon Block 521 in clude disturbances to the seafloor.

Physical disturbances to the seafloor: A drillship or dynamically positioned semisubmersible is being used for the proposed activities; therefor e, only an insignificant am ount of seafloor will be disturbed. Because physical disturbances to the seafloor will be minimized by the use of a drillship or dynamically positioned semisubm ersible, DGE II’s proposed operations in Mississippi Canyon Block 521 would not cau se impacts to shipwreck sites.

Additionally, Missis sippi Canyon Block 521 is not located in or adja cent to an OCS block designated by BOEM as having a hi gh probability for occurrence of shipwrecks, therefore, no adverse impacts are expected.DGE II 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 DGE II to be clear of seafl oor archaeological resour ces, including historic shipwrecks. Copies of the cert ifications and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be encountered, DGE II will contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural resource.

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

11. Prehistoric Archaeological Sites IPFs that could cause impacts to prehistoric archaeological site s as a result of the proposed operations in Mississippi Canyon Block 521 are physical disturba nces to the seafloor and accidents (oil spills).

Physical Disturbances to the seafloor: Although the operations proposed will be conducted by utilizing a drillship or dynami cally positioned semisubmersibl e, which would cause only an insignificant amount of seafloor to be distur bed, Mississippi Canyon Block 521 is located inside the Archaeological Prehistoric high probability li nes. DGE II will report to BOEM the discovery of any object of prehistoric ar chaeological significance and make every reasonable effort to preserve and protect that cultural resource.

DGE II 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 DGE II to be clear of seaf loor 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, DGE II will cont act the BOEM immediately and make every reasonable effort to preserve and protect that cultu ral resource. .

Accidents: An accidental oil spill has the potentia l to cause some detrimental effects to prehistoric archaeological sites if the release were to occur subsea. However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to Item 5 , Water Quality). The activities proposed in this plan will be covered by DGE II’s Regional Oil Spill Response Plan (refer to information submitted in accordance with Section 8 ).

There are no other IPFs (including emissions, effluents or wastes sent to shore for treatment or disposal) from the proposed activ ities which could impact prehistoric archeological sites.Vicinity of Offshore Location

1. Essential Fish Habitat (EFH)
IPFs that could cause impacts to EFH as a resu lt of the proposed oper ations in Mississippi Canyon Block 521 include effluents a nd accidents. EFH includes all estuarine and marine waters and substrates in the Gulf of Mexico.

Effluents: The Live Bottom Low Relief Stipulati on, the Live Bottom (Pinnacle Trend) Stipulation, and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential impacts on live-bottom communities and EFH from operational waste discharges. Levels of contaminants in drilling muds and cuttings a nd produced-water discha rges, discharge-rate restrictions, and monitoring a nd toxicity testing are regulated by the EPA NPDES permit, thereby eliminating many significa nt biological or ecol ogical effects. Operat ional 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 a ffect 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 DGE II’s Regional OSRP (refer to information
submitted in Section 8 ).

There are no other IPFs (includi ng emissions, physical disturbances to the seafloor and wastes sent to shore for treatment or disposal) from th e proposed activities whic h 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 a nd debris from vessel s and the facilities.

Emissions: Emissions of pollutants into the atmo sphere from these activities are far below concentrations which could harm coastal and marine birds.

Accidents: An oil spill woul d cause localized, low-level petroleum hydrocarbon contamination. However, it is unlikely that an oil spill woul d occur from the proposed activities (refer to Item 5

, Water Quality). Marine and pelagic birds feedi ng at the spill location may experience chronic, nonfatal, physiological stress. It is expected th at few, if any, coastal and marine birds would actually be affected to that extent. The activit ies proposed in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).Discarded trash and debris : Marine and pelagic birds could become entangled and snared in discarded trash and debris, or in gest small plastic debris, which can cause permanent injuries and death. Operators are prohibited from deliberat ely discharging debris as mandated by MARPOLAnnex V and the Marine Plastic Pollution Resear ch and Control Act, and regulations imposed by various agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). DGE II will operate in accordance with the regulations and also avoid accidental loss of solid waste items by maintaini ng 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 w ill be exercised when handling and disposing of small items and packaging materials, par ticularly 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 capa bilities. All offshore personnel, including contractors and other suppor t services-related pers onnel (e.g. helicopter pilots, vessel captains and boat cr ews) will be indoctrinated on wa ste 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 DGE II management or the designated lease operator ma nagement 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 pr oposed 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 H 2 S release) from the proposed activities which could cau se impacts to public health a nd safety. In accordance with NTL No.’s 2008-G04, 2009-G27, and 2009-G31, suffi cient information is included in Section 4 to justify our request that our proposed activities be classified by BSEE as H 2 S absent.

Coastal and Onshore

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

Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches
and associated resources. Due to the distance fr om shore (65 miles) and the response capabilitiesthat would be implemented, no significant adverse impacts are expected. The activities proposed in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

Discarded trash and debris: Trash on the beach is recogni zed 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 activ ities. Operators are prohibite d from deliberately discharging debris as mandated by MARPOL-Annex V and th e Marine Plastic Pollution Research and Control Act, and regulations imposed by variou s agencies including the United States Coast Guard (USCG) and the Environmental Protecti on Agency (EPA). DGE II will operate in accordance with the regulations and also avoi d accidental loss of solid waste items by maintaining waste management plans, manifes ting 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 dispos ing of small items and packaging materials, particularly those made of non- biodegradable, environmentally pe rsistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore personne l, including contract ors and other support services-related personnel (e.g. helicopter pilots, vessel capt ains 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 debr is training video annually. Offshore personnel will also receive an explanation from DGE II management or the designated lease operator management that emphasizes their commi tment to waste management in accordance with NTL No. 2012-G01.

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

2. Wetlands
IPFs from the proposed activities that could ca use impacts to wetlands include accidents (oil spills) and discarded trash and debris.

Accidents: It is unlikely that an oil spill would occu r from the proposed activities (refer to Item 5 , Water Quality). Due to the distance from shor e (65 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

Discarded trash and debris: There will only be a limited amount of marine debris, if any, resulting from the proposed activ ities. Operators are prohibite d from deliberately discharging debris as mandated by MARPOL-Annex V and th e Marine Plastic Pollution Research andControl Act, and regulations imposed by variou s agencies including the United States Coast Guard (USCG) and the Environmental Protecti on Agency (EPA). DGE II will operate in accordance with the regulations and also avoi d accidental loss of solid waste items by maintaining waste management plans, manifes ting 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 dispos ing of small items and packaging materials, particularly those made of non- biodegradable, environmentally pe rsistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation capabilities. All offshore personne l, including contract ors and other support services-related personnel (e.g. helicopter pilots, vessel capt ains 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 debr is training video annually. Offshore personnel will also receive an explanation from DGE II management or the designated lease operator management that emphasizes their commi tment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the seaflo or, or wastes sent to shore for treatment or disposal) fr om the proposed activities which could impact wetlands.

3. Shore Birds and Coastal Nesting Birds

Accidents: Oil spills could cause impacts to shore bird s 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 (65 mile s) and the response capabilities that would be implemented, no impacts are expected. The activ ities proposed in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

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 manda ted by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Ac t, and regulations imposed by va rious agencies including the United States Coast Guard (USCG) and the Envi ronmental Protection Agency (EPA). DGE II will operate in accordance with the regulations a nd also avoid accidental loss of solid waste items by maintaining waste management plans, mani festing trash sent to shore, and using special precautions such as covering outside trash bins to pr event accidental loss of solid waste. Special caution will be exercised when handling and dispos ing of small items and packaging materials, particularly those made of non- biodegradable, environmentally pe rsistent 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 personne l, including contract ors and other supportservices-related personnel (e.g. helicopter pilots, vessel capt ains 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 debr is training video annually. Offshore personnel will also receive an explanation from DGE II management or the designated lease operator management that emphasizes their commi tment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the seaflo or, or wastes sent to shore for treatment or disposal) from th e 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 di stance from shore (65 miles) and the response capabilities that would be implemented, no impacts ar e expected. The activities proposed in this plan will be covered by DGE II’s Regional OSRP (refer to information submitted in Section 8 ).

Discarded trash and debris: Operators are prohibited from de liberately discharging debris as mandated by MARPOL-Annex V, the Marine Plas tic Pollution Research and Control Act and regulations imposed by various ag encies including the United St ates Coast Guard (USCG) and the Environmental Protection Agency (EPA). DGE II will operate in accordance with the regulations and also avoid accide ntal loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and us ing 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 packagi ng 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 personne l, including contract ors and other support services-related personnel (e.g. helicopter pilots, vessel capt ains 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 debr is training video annually. Offshore personnel will also receive an explanation from DGE II management or the designated lease operator management that emphasizes their commi tment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the seaflo or, or wastes sent to shore for treatment or disposal) from th e 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 (93 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 DGE II’s Regional OSRP (refer to information submitted in Section 8).

Discarded trash and debris: Operators are prohibited from de liberately discharging debris as mandated by MARPOL-Annex V, the Marine Plas tic Pollution Research and Control Act and regulations imposed by various ag encies including the United St ates Coast Guard (USCG) and the Environmental Protection Agency (EPA). DGE II will operate in accordance with the regulations and also avoid accide ntal loss of solid waste items by maintaining waste management plans, manifesting trash sent to shore, and us ing 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 packagi ng 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 personne l, including contract ors and other support services-related personnel (e.g. helicopter pilots, vessel capt ains 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 debr is training video annually. Offshore personnel will also receive an explanation from DGE II management or the designated lease operator management that emphasizes their commi tment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the seaflo or, or wastes sent to shore for treatment or disposal) from th e 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 propos ed 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 si x become hurricanes ( > 74 mph winds). Due to its location in the gulf, Mississippi Canyon Bl ock 521 may experience hurricane and tropical storm force winds, and related sea cu rrents. These factors can adversely impact the integrity of the operations covered by this pla n. A significant storm may present physical hazards to operators and vessels, damage exploration or pr oduction equipment, or result in the release of hazardous materials (including hydrocarbons). Add itionally, the displacement of equipment may disrupt the local benthic habitat a nd 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. Structure Installation Operator will not conduct structure instal lation operations duri ng Tropical Storm or
Hurricane threat.

(E) ALTERNATIVES
No alternatives to the proposed activities were cons idered to reduce environmental impacts.

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

(G) CONSULTATION
No agencies or persons were consulted regard ing potential impacts associ ated with the proposed activities. Therefore, a list of such entities has not been provided.

(H) PREPARER(S)

Trinity Howell J. Connor Consulting, Inc. 16225 Park Ten Place, Suite 700 Houston, TX 77084 (281) 578-3388 trinity.howell@jccteam.com(I) REFERENCES

Authors:

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

Balazs, G.H. 1985. Impact of ocean debris on mari ne 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, Honolu lu, HI. U.S. Dept. of Commerce. NOAA Tech. Memo. NOAA-TM-NMFS-SWFC-54. Pp 387-429.

Burke, C.J. and J.A. Veil. 1995. Potential benef its from regulatory cons ideration of synthetic drilling muds. Environmental Assessmen t Division, Argonne Na tional 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 sens itivity of seabird populations in Al aska to oil pollution. U.S. Dept. of the Interior, Bureau of Land Mana gement, Alaska OCS Region, Anchorage. BLMYK-ES-81-006-1792.

Laist, D.W. 1997. Impacts of marine debris: en tanglement 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: s ources, impacts, and solutions. New York, NY: Springer-Verlag. Pp. 99-139.

Majors, A.P. and A.C. Myrick, Jr. 1990. Effects of noise on animals: implications for dolphins exposed to seal bombs in the eastern tropi cal Pacific purse-sein e fishery–an annotated bibliography. NOAA Admini strative Report LJ-90-06.

Marine Mammal Commission. 1999. A nnual report to Congress – 1998.

Piatt, J.F., C.J. Lensink, W. Butler, M. Ke ndziorek, 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 prepar ing this EIA:

 Hazard Surveys

 BOEM EIS’s:

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

o GOM Central and Western Planning Areas Sales 166 and 168 Final Environmental Impact Statement. BOEM 96-0058.Deep Gulf Energy II, LLC Section 16 – Pg. 31 of 31 Initial EP July, 2014 Mississippi Canyon Block 521 (OCS-G 34441) 

### SECTION 16
ADMINISTRATIVE INFORMATION

16.1 EXEMPTED INFORMATION DESCRIPTION The proposed bottom-hole locations of the planned wells have been removed from the Public Information copy of this EP as well as any discussions of the target objectives, geologic or geophysical data, and any interpreted geology.

16.2 BIBLIOGRAPHY 1. Regional Oil Spill Response Plan (Control Number O-578).

2. Geoscience Earth & Marine Services , Inc. Geologic, Stratigraphic and Archaeological Assessment, Block 521, Mi ssissippi Canyon Area Gulf of Mexico, Project No. 0613-2255b / 0613-2255c.

3. Geoscience Earth & Marine Services, Inc. Site Clearance Letter, Proposed Wellsites A and D, Block 521 (OCS-G 34441), Mississippi Canyon Area, Gulf of Mexico, Project No. 0613-2255b.