UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)
Plans Section, Office of Field Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - S-07702

Type - Supplemental Exploration Plan

Lease(s) - OCS-G24060 Block - 215 Mississippi Canyon Area

Operator - Deep Gulf Energy II, LLC

Wells B and C

%14FNJTVCNFSTJCMF

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

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

Chiquita Hill
Plan Coordinator Description -

Rig Type - Subject: From: October 9, 2014Records of Changes – PUBLIC COPYS7702, Supplemental EP, Deep Gulf Energy II,LLC, (OCS-G 24060, Mississippi Canyon Block 260)Date Section PageRemarks09/04/14 All All Plan received by BOEM.09/19/14 E Attachment E-1 Rescanned Water Depth & Seafloor Features Map09/26/14 F Page 7 and Attachment F-1 Removed reference to waste table in R-6113 and provided new wastetable.09/30/14 L Page 11 and Attachment L-1Removed reference to waste table in R-6113 and provided new wastetable.DEEP GULF ENERGY II, LLC 738 Highway 6 South Suite 800 Houston, Texas 77079 Phone: 281.596.0933 Facsimile: 281.596.0939

September 2, 2014

Mr. Kent Randall Regional Supervisor Office of Leasing and Plans Bureau of Ocean Energy Management 1201 Elmwood Park Boulevard, New Orleans, Louisiana 70123-2394

Attn: Ms. Michelle Uli MS GM1053C

RE: Supplemental Exploration Plan – Request for Expedited Review Mississippi Canyon Block 214 Unit, Unit Contract No. 754313006 Lease OCS-G 24060, Mississippi Canyon Block 215 OCS Federal Waters, Gulf of Mexico Region, Offshore, Louisiana

Ms. Uli:

In accordance with the provisions of Title CFR 550, Subpart B, and those certain Notice to Lessees (NTL) 2008-G04, 2009-G27 and 2010-N06, Deep Gulf Energy II, LLC (“DGE II”) hereby submits this Supplemental Exploration Plan for Lease OCS-G 24060, Mississippi Canyon Block 215.

By letter dated December 20, 2013, the Bureau of Ocean and Energy Management approved Eni US Operating Co. Inc.’s (“Eni”) Initial Exploration Plan (N-9735) for the drilling and completion of well locations A and B. Further, DGE II as designated operator submitted a Revised Exploration Plan (R-6113) to provide operator information, drill and complete well location B within 500 feet of the surface location as approved in N-9735, provide new Worst Case Discharge Calculations and amend the estimated startup date to January 31, 2015. The Revised Exploration Plan (R-6113) was approved on August 27, 2014.

DGE II hereby submits this Supplemental Exploration Plan to amend the estimated startup date to November 1, 2014 and add an alternate well site, Location C. Location C is a mirror location of the B Location as provided for in R-6113, and is included to provide an alternate well site should complications occur while drilling the planned B Location.

DGE II has the Ensco 8505 Dynamically Positioned Semisubmersible Drilling Unit under contract and estimates commencing operations on or about November 1. 2014. Therefore; DGE II respectfully requests an expedited review of the enclosed Supplemental Exploration Plan.PUBLIC COPY August, 2014



## SUPPLEMENTAL EXPLORATION PLAN

Mississippi Canyon Block 215 OCS-G 24060 Odd Job Prospect

Estimated Startup Date: November, 2014

SUBMITTED BY: Deep Gulf Energy II, LLC

738 Highway 6 South Suite 800 Houston, Texas 77079

Bill Fisher (281) 596-0933 bfisher@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.comTOC Pg 1 of 2 TABLE OF CONTENTS

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

A.1 PLAN INFO RMATION ........................................................................................... 1

A.2 LOCAT ION ............................................................................................................ 1

A.3 SAFETY AND POLLUTION PREVENTION FEATURES ....................................... 2

A.4 STORAGE TANKS AND PRODUCTION VESSELS ............................................. 2

SECTION B GENERA L INFORMAT ION ....................................................................... 4

B.1 APPLICATIONS A ND PERMIT S ........................................................................... 4

B.2 DRILLING FLUIDS ................................................................................................ 4

B.3 BONDING ST ATEMENT ....................................................................................... 4

B.4 OIL SPILL FINANCIAL RE SPONSIBILITY (OSFR) ............................................... 4

B.5 DEEPWATER WELL CO NTROL STAT EMENT .................................................... 4

B.6 BLOWOUT SCENARIO AND WORST CASE DISCHARGE CALCULATIONS ..... 4

SECTION C GEOLOGICAL AND GE OPHYSICAL INFO RMATION .............................. 5

C.1 GEOLOGICAL D ESCRIPTION ............................................................................. 5

C.2 STRUCTURE CO NTOUR M AP ............................................................................ 5

C.3 INTERPRETED SE ISMIC LINE (S) ........................................................................ 5

C.4 GEOLOGICAL STRUCTU RE CROSS-SEC TIONS ............................................... 5

C.5 SHALLOW HAZA RDS REPO RT ........................................................................... 5

C.6 SHALLOW HAZARDS ASSESSMENT ................................................................. 5

C.7 HIGH-RESOLUTION SEISMIC LI NES .................................................................. 5

C.8 STRATIGRAPHIC COLUMN ................................................................................. 5

C.9 TIME VERSUS D EPTH TABL ES .......................................................................... 5

SECTION E BIOLOGICAL, PHYSICAL A ND SOCIOECONOMIC INFORMATION ..... 6

E.1 DEEPWATER BENTHI C COMMUNITI ES ............................................................. 6

SECTION F WASTES AND DIS CHARGES INFO RMATION ........................................ 7

F.1 PROJECTED GENE RATED WAST ES .................................................................. 7

SECTION G AIR EMISS IONS INFORM ATION ............................................................. 8TOC Pg 2 of 2 G.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS ........................... 8

G.2 SUMMARY IN FORMATION .................................................................................. 8

SECTION H OIL SPI LL INFORMAT ION ....................................................................... 9

H.1 OIL SPILL RESP ONSE PLANNI NG ...................................................................... 9

H.2 SPILL RESPON SE SITES .................................................................................... 9

H.3 OSRO INFO RMATION .......................................................................................... 9

H.4 WORST CASE SCENAR IO DETERMIN ATION .................................................... 9

H.5 OIL SPILL RESPON SE DISCUSS ION ................................................................ 10

SECTION L SUPPORT VESSELS AND AIRCRAFT INFO RMATION ........................ 11

L.1 GENE RAL ............................................................................................................ 11

L.2 DIESEL OIL SU PPLY VESS ELS ......................................................................... 11

L.3 DRILLING FLUID TRANSPORTAT ION ............................................................... 11

L.4 SOLID AND LIQUID W ASTE TRANSPORT ATION ............................................. 11

L.5 VICINITY MAP ..................................................................................................... 11

SECTION M ONSHORE SUPPORT FACILITIES INFO RMATIO N ............................. 12

M.1 GENE RAL ........................................................................................................... 12

M.2 SUPPORT BASE CONSTRUCT ION OR EXPAN SION ...................................... 12

M.3 SUPPORT BASE CONSTRUCTION OR EXPANSION TIMETABLE ................. 12

M.4 WASTE DI SPOSAL ............................................................................................ 12

SECTION N COASTAL ZONE MANAGEM ENT ACT (CZMA) INFORMATION ......... 13

SECTION O ENVIRONMEN TAL IMPACT ANALYSIS................................................ 16

SECTION P ADMINISTRAT IVE INFORM ATION ........................................................ 23

P.1 EXEMPTED INFORMAT ION DESCRI PTION ..................................................... 23

P.2 BIBLIO GRAPHY .................................................................................................. 23Attachments Pg 1 of 1 SECTION ATTACHMENTS

Section A Plan Contents A-1 OCS Plan Information Form
A-2 Well Location Plat A-3 Bathymetry Map A-4 Pay Gov Receipt Section B General Information
B-1 Blowout Scenario Section C Geological, Geoph ysical Information C-1 Shallow Hazards Assessment Section E Biological, Physical and Socioeconomic Information
E-1 Biologically Sensitiv e Underwater Features and Areas Map Section F Wastes and Discharges Information F-1 Waste You Will Generate, Treat and Downhole Dispose or Discharge to the GOM Section G Air Emissions Information G-1 Emissions Worksheets Section H Oil Spill Information
H-1 Oil Spil l Response Discussion Section L Support Vessels an d Aircraft Information L-1 Waste You Will Transport and/or Dispose Onshore Section N Coastal Zone Manage ment Act (CZMA) Information N-1 Coastal Zone Consis tency Certification (Alabama) Section O Environmental Impact Analysis (EIA) O-1 Environmen tal Impact Analysis (EIA)Deep Gulf Energy II, LLC Section A – Pg. 1 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION A
PLAN CONTENTS

A.1 PLAN INFORMATION Eni US Operating Co. Inc. (“Eni”) submitt ed an Initial Explorati on Plan (Plan Control N9735) for Mississippi Canyon Block 215 on July 17, 2013 which proposed the drilling and completion of two (2) Well Locations, A and B. The Initial Ex ploration Plan (Plan Control N-9735) was approved on December 20, 2013. To date, drilling and completion operations have not commenced.

Deep Gulf Energy II, LLC (“DGE II”) was Designated Operator of Mississippi Canyon Block 215 on March 27, 2014. On May 30 , 2013, BSEE approved Un it Contract No. 754313006 (MC 214 Unit), which consists of all of Lease OCS-G 24059, Mississippi Canyon Block 214 and an aliquot portion, W/2 and W/2 W/2 E/ 2 of Lease OCS-G 24060, Mississippi Canyon Block 215. DGE II’ s request for Designation of Successor Unit Operator is pending BSEE approval.

DGE II as designated operator submitted a Revised Exploration Plan (Plan Control R6113) to cancel well location A, drill and comple te Well Location B wit hin 500 feet of the surface location as approved in Plan C ontrol N-9735, provi de new Worst Case Discharge Calculations and a Dynamically Posi tioned Semisubmersible Drilling Unit and amend the estimated startup date to Januar y 31, 2015. The Revi sed Exploration Plan was approved on August 27, 2014. To date, dr illing and completion operations have not
commenced.

Under this Supplemental Exploration Plan, DGE II proposes to amend the estimated startup date to November 1, 2014 and add an alternate well site, Location C (Location C
is a mirror location of the B well and is includ ed to provide an alternate well site should complications occur while drilling the pl anned B Location). DGE II will utilize an Ensco 8500 Series (or equivalent) Dynamically Po sitioned Semisubmersible Drilling Unit.

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

.

A.2 LOCATION A Well Location Plat depicti ng the proposed surface and bottomhole location of the proposed wells is included as Attachment A-2

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

A Bathymetry Map depicting the proposed su rface location and water depth of the proposed wells is included as Attachment A-3

.Deep Gulf Energy II, LLC Section A – Pg. 2 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) A.3 SAFETY AND POLLUTION PREVENTION FEATURES DGE II proposes to drill the we ll with an Ensco 8500 Series (or equivalent) Dynamically
Positioned Semisubmersible with Subsea BO P’s. The BOP information and schematics will be included as a part of the Application for Permit to Drill.

The Ensco 8500 Series drilling units are equipped with safety and fire-fighting equipment required to comply with United St ates Coast Guard (USCG) regulations. Appropriate life saving equipment such as lif e rafts, life jackets, ring buoys, etc. as prescribed by the USCG, will be mainta ined on the rig at all times.

Safety features on the Ensco 8500 Series dr illing units include well control, pollution prevention, and blowout prev ention equipment as descri bed in BSEE regulations 30 CFR 250 C, D, E, O, Q and S; and as further clarified by BSEE Notices to Lessees, and current policy making invoked by the BSEE, Environmental Protection Agency and the U.S. Coast Guard (USCG).

Pollution prevention measures include installation of cu rbs, gutters, drip pans, and drains on drilling deck areas to collect al l contaminants and debris. Compliance will be maintained with the EPA NPDES Permit whic h covers the lease. The rig will be monitored daily and any waste or fuel resulting in pollution of the Gulf waters will be reported to the repres entative in charge for immediate isolation and correction of the problem. Any spill will be reported to the appropriate governmental agencies.

A.4 STORAGE TANKS AND PRODUCTION VESSELS All facility tanks with a capacity of 25 bbls or more.

Ensco 8500 Series DP Semisubmersible (or equivalent) 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/ADeep Gulf Energy II, LLC Section A – Pg. 3 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) Oily Water (stb) DP Semisubmersible 186/178 2 364 N/A

A.5 POLLUTION PREVENTION MEASURES These operations do not propose activities for wh ich the State of Florida is an affected

state.

A.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.

A.7 COST RECOVERY FEE Documentation of the $3, 673.00 cost recovery fee payment is included as Attachment A-4.U.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? X Yes X No

If so, provide the Control Number of the EP or DOC D with which this information was provided R-6113

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 B 11/01/2014 02/13/2015 105

Drill and Complete Well Location C (Altern ate Well Location) 02/14/2015 05/30/2015 105

Description of Drilling Rig Description of Structure

Jackup Drillship Caisson Tension leg platform

Gorilla Jackup Platform rig Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed tower

X DP Semisubmersible Other (Attach description) Floating production system Other (Attach description) Drilling Rig Name (If known): Ensco 8500 Series DP Semi-Submersible Description of Lease Term Pipelines

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

N/A N/A

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: kelley.pisciola@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-24060 Area: Mississippi Canyon Block(s) 215 Project Name: Odd Job

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

Platform / Well Name: B and C Total Volume of WCD: 12,502,107 bbls API Gravity: 33°

Distance to Closest Land (Miles): 64.5 Volume from uncontrolled blowout: 154,347 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 B Previously reviewed under an approved EP or DOCD? X Yes 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): 154,347.00 bbls/day For structures, volume of all storage and pipelines (Bbls): API Gravity of fluid 33°

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

Lease No. OCS-G 24060 OCS-G OCS OCS

Area Name Mississippi Canyon

Block No. 215

Blockline Departures (in feet) N/S Departure 3,670.00’ FNL N/S Departure N/S Departure F __ L N/S Departure F __ L N/S Departure F __ L

E/W Departure 7,302.00’ FWL E/W Departure E/W Departure F __ L E/W Departure F __ L E/W Departure F __ L

Lambert X-Y coordinates X: 1,306,182.00’ X: X:
X:
X:

Y: 10,450,730.00’ Y: Y:
Y:
Y:

Latitude/ Longitude Latitude 28° 47’ 36.906” Latitude Latitude Latitude Latitude

Longitude 88° 02’ 37.773” Longitude Longitude Longitude Longitude

Water Depth (Feet): 6,008.00’ 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): C 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): 154,347 bbls/day For structures, volume of all storage and pipelines (Bbls): API Gravity of fluid 33°

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

Lease No. OCS-G 24060 OCS-G OCS OCS-G

Area Name Mississippi Canyon

Block No. 215

Blockline Departures (in feet) N/S Departure 3,470.00’ FNL N/S Departure N/S Departure F __ L N/S Departure F __ L N/S Departure F __ L

E/W Departure 7,302.00’ FWL E/W Departure E/W Departure F __ L E/W Departure F __ L E/W Departure F __ L

Lambert X-Y coordinates X: 1,306,182.00’ X: X:
X:
X:

Y: 10,450,930.00’ Y: Y:
Y:
Y:

Latitude/ Longitude Latitude 28° 47’ 38.8865” Latitude Latitude Latitude Latitude

Longitude 88° 02’ 37.7925” Longitude Longitude Longitude Longitude

Water Depth (Feet): 5,990’ 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 4MC_215 C B



### Deep Gulf Energy II, LLC

MC 215


### Well Surface Location Map

0 6000 ft 2000 4000

Scale = 1:240003,670’ Y = 10,454,400’

Y = 10,438,560’X=1,314,720’X=1,298,880’ 7,302’

Surface Location
OCS

Ͳ G 24060 Well B
X = 1,,306,182.00’

Y = 10,450,730.00’ 7,302’ FWL of MC 215 3,670’ FNL of MC 215
Lat: N 28 ° 47’ 36.906” Long: W 88 ° 2’ 37.773”

PTD: 17,177’md 17,000’tvd

Water Depth 6,008’ 7,302’3,470’

Surface Location
OCS

Ͳ G 24060 Well C
X = 1,,306,182.00’

Y = 10,450,930.00’ 7,302’ FWL of MC 215 3,470’ FNL of MC 215
Lat: N 28 ° 47’ 38.8865” Long: W 88 ° 2’ 37.7925”

PTD: 17,000’md 17,000’tvd

Water Depth 5,990’6 2

4 0 5 6 0 0

6 5 0

2 4 0 6 0 2 6 0

5 3

6 3 3 1 7 5

0 5 5 5 0 6 0

5 6

7 6 1

5 4 6 4 3 6 7 2 2 1 0 5 0

6 5 9 2

7 0

6 3 6 2 7 6 1 5

6 6

5 5 5

2 5 5 5 2 6 0

0 7 9 5 9

6 7

5 5 5 0 2 6 0

6

5 1 6

1 0 0 2

6 0 6 0

0 5 9 9

0 9

5

0 3 0 3 6

6

6 2 6 0 0

0 0

5 5 5 5

6 5 0

7 6 0

2 5 1

1 2 0

6

0 5 5

7

4 2 5 6

2 6 2 0 7 1 6

0 6 5 1 6 0 6 5 5 7

9 0 5

5 2

8 5

5 0 6 6 0 0

1 0 0

6

5 7 0

9 9

5

5 0 0 2 6 2

5 7 5 2 6 5

0 0 5

0 3

6 3

6 0 5 5

5 1 0 6

5 5
0 0

2 3 6

5 0 9 5

5 7

0 6 5

2 2 6 2

0 0 MC_215 C B



### Deep Gulf Energy II, LLC

MC 215


### Bathymetry Map

0 6000 ft 2000 4000

Scale = 1:24000 Surface Location
OCS

‐ G 24060 Well C
X = 1,,306,182.00’

Y = 10,450,930.00’ 7,302’ FWL of MC 215 3,470’ FNL of MC 215
Lat: N 28 ° 47’ 38.8865” Long: W 88 ° 2’ 37.7925”

PTD: 17,000’md 17,000’tvd

Water Depth 5,990’ Surface Location
OCS

‐ G 24060 Well B
X = 1,,306,182.00’

Y = 10,450,730.00’ 7,302’ FWL of MC 215 3,670’ FNL of MC 215
Lat: N 28 ° 47’ 36.906” Long: W 88 ° 2’ 37.773”

PTD: 17,177’md 17,000’tvd

Water Depth 6,008’

## Rece ipt

Your payment is complete Pay.gov Tracking ID: 25H7R0F8 Agency Tracking ID: 74666857477
Form Name: BOEM Exploration Plan Application Name: BOEM Exploration Plan

- BF 

### Payment Information Payment Type: Bank account (ACH) Payment Amount: $3673.00
Tra nsaction Date: 08/21/2014 05:19:06 PM EDT Payment Date: 08/22/2014 Region: Gulf of Mexico
Contact: Kelley Pisciola 281

- 698

- 8519 Company Name/No: Deep Gulf Energy II, LLC, 02985 Lease Number(s): 24060, , , ,
Area

- Block: Mississippi Canyon MC, 215: , : , : , : , Surface Locations: 1 

### Account Information

Account Holder Name: Deep Gulf Energy II, LLC Routing Number: 121000248 Account Number: ************3536 

### Email Confirmation Receipt Confirmation Receipts have been emai led to:

holtinc@msn.com mphinney@deepgulfenergy.com

Print ReceiptDeep Gulf Energy II, LLC Section B – Pg. 4 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION B
GENERAL INFORMATION

B.1 APPLICATIONS AND PERMITS No additional applications or permits from ot her agencies are required at this time to be submitted and approved other than an Application for Permit to Drill (APD) and an Application for Permit to Modify (APM) to the appropr iate BSEE District.

B.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 well.

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be Used per Well (bbls) Water-based (seawater, freshw ater, barite) 50, 000 bbls/well Oil-based (diesel, mineral oil) N/A Synthetic-based (internal olef in, ester) 13,500 bbls/well

B.3 BONDING STATEMENT The bond requirements for the activities and fa cilities proposed in this EP are satisfied by a lease-specific development bond, furn ished 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 Nati onal NTL No. 2008-N07, “Supplemental Bond Procedures” as required by BOEM.

B.4 OIL SPILL FINANCIAL RE SPONSIBILITY (OSFR) Deep Gulf Energy II, LLC, Oper ator Number 02985, has demonstrated o il 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.

B.5 DEEPWATER WELL CONTROL STATEMENT Deep Gulf Energy II, LLC, Oper ator number 02985 has the financial capability to drill a relief well and conduct other emergency well control operations.

B.6 BLOWOUT SCENARIO AND WORS T CASE DISCHARGE CALCULATIONS The Worst Case Discharge Assumptions and Calculations were provided for and accepted in Revised Exploration Plan (R-6113) . The Blowout Scenario is included as
Attachment B-1

.

### ATTACHMENT B-1

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 154,347 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 81 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 154,347 2 308,694

Surface Intervention 154,347 15 2,315,205

Relief Well 154,347 81 12,502,107

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 9,223 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 3,302 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 time and are performed in par allel. 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 215 Well No. 001 (drilled from Well Site B surface location) could be drilled from an appropriately clea red-of-hazards surface locati on to the south-southeast of the Well Site B location.

A relief well for MC 215 Well No. 001 would be designed to intersect the blowout well below the 16” casing point. Once the well is intersected, kill pumping 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 81 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. 48 70

Mag-Range relief well into intersecting position. 6 76

R/U pumping equipment and kill well. 5 81
R/D Pumping Equipment, PA Wellbore, Pull Riser, and Demobilize 12 93

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 measurements during all open hole 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 al ternative 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 C – Pg. 5 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION C
GEOLOGICAL AND GEOP HYSICAL INFORMATION

C.1 GEOLOGICAL DESCRIPTION Proprietary Information.

C.2 STRUCTURE CONTOUR MAP Proprietary Information.

C.3 INTERPRETED SEISMIC LINE(S) Proprietary Information.

C.4 GEOLOGICAL STRUCTURE CROSS-SECTIONS Proprietary Information.

C.5 SHALLOW HAZARDS REPORT A shallow hazards report for Mississippi Ca nyon Block 215 was previously submitted.

C.6 SHALLOW HAZARDS ASSESSMENT In accordance with NTL 2008-G05, “Shal low Hazards Program” (Extended by NTL BOEM 2013-G02, “Extens ion of Prior Notices to Lessees”), a 3-D seismic shallow hazards assessment has been prepared for the proposed alternate surface location, evaluating seafloor and s ubsurface geological and manm ade features and conditions that may adversely affect drilling operations. The S hallow Hazards Survey and Archaeological Assessment is included as Attachment C-1

.
C.7 HIGH-RESOLUTION SEISMIC LINES Proprietary Information.

C.8 STRATIGRAPHIC COLUMN Proprietary Information.

C.9 TIME VERSUS DEPTH TABLES Proprietary Information.Deep Gulf Energy II, LLC Section E – Pg. 6 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

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

E.1 DEEPWATER BENTHIC COMMUNITIES The seafloor disturbing activi ties proposed in this plan are in water depths greater than 300 meters (984’). Fugro Geoconsulting, Inc. (“Fugro”) was contra cted to provide an
assessment of the sha llow conditions at the proposed al ternate surface location. The purpose of the assessment was to address seafloor conditions that may impact exploratory drilling operations within 2,000 feet of the proposed well site. 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 E-1

.Deep Gulf Energy II, LLC Section F – Pg. 7 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION F
WASTES AND DISCHARG ES INFORMATION

F.1 PROJECTED GENERATED WASTES “Wastes You Will Generate, Treat and Downho le Dispose or Discharge to the Gulf of
Mexico” is included as Attachment F-1

.Waste you will generate, treat and downhole dispose or discharge to the GOM Projected Generated Waste Projected Ocean Discharges

Will drilling occur? If yes, you should list muds and cuttings Type of Waste Composition Projected Amount Discharge Rate Discharge Method

Cuttings wetted with water-based fluid Cuttings coated with water based drilling mud 1,445 bbl/well 361 bbl/day/well Water-based Drilling Fluids Water based drilling fluid 50,000/bbl/well 12,500 bbl/day/well Discharged at mudline prior to BOP and riser
installation

Discharged at mudline prior to BOP and riser
installation

Will humans be there? If yes, expect conventional waste Synthetic-based Drilling Fluids Synthetic based drilling fluid - retained on cuttings 981 bbl/well 36/bbl/day/well Discharged thru shunt pipe to 25' below water's
surface

Cuttings wetted with synthetic-based fluid Cuttings coated with synthetic based drilling fluid 4,196 bbl/well 155 bbl/day/well Treated using solids control equipment and discharged thru shunt pipe 25' below water's
surface.

Is there a deck? If yes, there will be Deck Drainage Deck Drainage Platform washings and 105 bbl/well 0.1 bbl/hr/well Oily water is treated in Oily Water Separator Domestic waste Gray water (laundry, galley, lavatory) 4,930 bbl/well 5 bbl/hr/well Discharged overboard. Any associated food waste will be processed using an approved grinder

Sanitary waste Treated human body waste
from toilets 4,930 bbl/well 5 bbl/hr/well USCG approved MSD

333 bbl/well/day Overboard upon samples passing the Static Sheen Test per Region 6 GOM GMG 290000 regulations. Well completion fluids Brines, NaCl, KCl, CaBr2, CaCl2 2000/well 333 bbl/well/day Overboard upon samples passing the Static Sheen Test per Region 6 GOM GMG 290000 regulations. Will you conduct well treatment, completion or workover? If yes, only fill in those associated with your activity

Well treatment fluids Brines, NaCl, KCl, CaBr2, CaCl2 2000/well 333 bbl/well/day Overboard upon samples passing the Static Sheen Test per Region 6 GOM GMG 290000 regulations.

Workover fluids Brines, NaCl, KCl, CaBr2, CaCl2 2000/well

Excess cement at seafloor Cement slurry 900 bbl/well 19 bbl/hr Discharged at the mudline during cementing conductor casing Ballast water Uncontaminated seawater used to maintain proper draft 21,000 bbl/well 9 bbl/hr Discharged overboard

Bilge Water Bilge water 99/bbl/well 0.1 bbl/hr Discharged overboard

Cooling water Seawater with no addition of
chemicals 165,000 bbl/well 1,667 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 produce hydrocarbons? If yes, fill in for produced water
Produced water N/A N/A N/A N/A Blowout prevent fluid Stackmagic 200/0/5% glycol
based on 2% mixture with potable water 180 bbl/well 12/bbl/ per week
with funtion 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 123,390 bbl/well 57 bbl/hr Cuttings chuteDeep Gulf Energy II, LLC Section G – Pg. 8 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION G
AIR EMISSIONS INFORMATION

G.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

G.2 SUMMARY INFORMATION There are no co-existing facilities or acti vities co-located with the currently proposed activities; therefore, the Co mplex Total Emissions are the same as the Plan Emissions.
Air Emissions Worksheets which show the em ission calculations with related support
vessel information is included as Attachment G-1

. This information was calculated by: Kelley Pisciola (281) 698-8519 kelley.pisciola@jccteam.comEXPLORATION PLAN (EP)AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/14COMPANYDeep Gulf Energy II, LLC (DGE II)AREAMississippi CanyonBLOCK215LEASEOCS-G 24060PLATFORMN/AWELLB and C (Location C is provided as an alternate location shouldcomplications arise during drilling).COMPANY CONTACTKelley PisciolaTELEPHONE NO.281.698.8519Drill and Complete Well Location B (Location C is provided as an alternatewell location should complications arise during drilling) with an Ensco 8500DP Semi (AQR for DP Semi calculated using Ensco 8500 Series SpecificHorsepower).REMARKSFORM BOEM-0138(December 2011 - Supersedes all previous versions of this form which may not be used).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 lean gms/hp-hr 0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84P42 1.4-1, 14-2, & 147/98NG Flares lbs/mmscf 0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vapors lbs/bbl 0.03E&P Forum 1/93Fugitives lbs/hr/comp. 0.0005API Study 12/93Glycol Dehydrator Vent lbs/mmscf 6.6La. DEQ 1991Gas Venting lbs/scf 0.0034Sulphur Content Source Value UnitsFuel Gas 3.33 ppmDiesel Fuel 0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring) 1 % weightFORM BOEM-0138(December 2011 - Supersedes all previous versions of this form which may not be used).Page 2 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSDeep Gulf Energy II, LLC Mississippi Canyon 215 OCS-G 24060 N/A B and C (Location C is provided as an alternKelley Pisciola 281.698.8519OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 21739 1049.9937 25199.85 24 60 15.32 70.29 526.72 15.80 114.92 11.03 50.61 379.24 11.38 82.74DP SemisubmersiblePRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 17 1.46 6.68 50.03 1.50 10.92 0.10 0.45 3.40 0.10 0.74VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 17 3.10 14.23 106.61 3.20 23.26 0.26 1.21 9.06 0.27 1.98VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002014 YEAR TOTAL19.88 91.20 683.36 20.50 149.10 11.39 52.27 391.70 11.75 85.46EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2147.85 2147.85 2147.85 2147.85 54682.9764.5FORM BOEM-0138(December 2011 - Supersedes all previous versions of this form which may not be used).Page 3 of 8EMISSIONS CALCULATIONS 1ST YEARCOMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKSDeep Gulf Energy II, LLC Mississippi Canyon 215 OCS-G 24060 N/A B and C (Location C is provided as an alternKelley Pisciola 281.698.8519OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR ESTIMATED TONSDiesel Engines HP GAL/HR GAL/DNat. Gas Engines HP SCF/HR SCF/DBurners MMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel 21739 1049.9937 25199.85 24 150 15.32 70.29 526.72 15.80 114.92 27.58 126.53 948.09 28.44 206.86DP SemisubmersiblePRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 43 1.46 6.68 50.03 1.50 10.92 0.25 1.15 8.61 0.26 1.88VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 43 3.10 14.23 106.61 3.20 23.26 0.67 3.06 22.92 0.69 5.00VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 0.00DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL19.88 91.20 683.36 20.50 149.10 28.50 130.73 979.61 29.39 213.73EXEMPTIONCALCULATIONDISTANCE FROM LAND INMILES2147.85 2147.85 2147.85 2147.85 54682.9764.5FORM BOEM-0138(December 2011 - Supersedes all previous versions of this form which may not be used).Page 3 of 8SUMMARYCOMPANY AREA BLOCK LEASE PLATFORM WELLDeep Gulf EnergMississippi Canyon 215 OCS-G 24060 N/A B and C (Location C isEmitted SubstanceYearPM SOx NOx VOC CO2014 11.39 52.27 391.70 11.75 85.462015 28.50 130.73 979.61 29.39 213.73Allowable2147.85 2147.85 2147.85 2147.85 54682.97FORM BOEM-0138(December 2011 - Supersedes all previous versions of this form which may not be used).Page 8 of 8ACTUAL FUEL USAGE FACTORS ASSUMED FOR AQR EMISSION CALCULATIONS

Rig 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/day

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 Ri g s 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)Deep Gulf Energy II, LLC Section H – Pg. 9 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION H
OIL SPILL INFORMATION

H.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, last approved June 24, 2014 (OSRP Control Number O-978).

H.2 SPILL RESPONSE SITES Primary Response Equipment Location Preplanned Staging Location

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

H.3 OSRO INFORMATION DGE II’s primary equipment prov ider is Clean Gulf Associat es (CGA). Clean Gulf Associates Services, LLC (CGAS) will provi de the closest personnel, as well as the CGAS supervisor to o perate the equipment.

H.4 WORST CASE SCENARIO DETERMINATION

Category Regional OSRP WCD - Drilling EP WCD - Drilling
Type of Activity Drilling Drilling
Facility Location (Area/Block) MC 215 MC 215

Facility Designation Well Location B Well Location B

Distance to Nearest Shoreline (miles) 64.5 64.5

Volume

 Storage Tanks (Total)

 Uncontrolled blowout Total Volume 154,347 154,347Deep Gulf Energy II, LLC Section H – Pg. 10 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) Type of Oil(s) (crude, condensate, diesel) Oil Oil

API Gravity 33° 33°

The WCD calculations and assumptions fo r the Regional OSRP WCD, MC215 Well Location B (154,347) were previously reviewed under Plan Control No. R-6113.

Since DGE II has the capability to respond to the appropriate worst-case spill scenario included in its region al OSRP approved on June 24, 2014, and since the worst-case scenario determined for our EP does not replace the appropriate worst-case scenario in our regional OSRP, DGE II hereby certifies t hat DGE II has the capability to respond, to the maximum extent practicable, to a worst- case discharge, or a s ubstantial threat of such a discharge, resulting from t he activities proposed in our EP.

H.5 OIL SPILL RESPONSE DISCUSSION The Oil Spill Response Discussion is included as Attachment H-1.

## ATTACHMENT H-1

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 154,347 barrels of crude oil with an API gravity of 33°.

Land Segment and Resource Identification

Trajectories of a spill and the probability of it impacting a land segment have been projected utilizing information in the BOEM Oil Spill Risk Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the 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 20% or approximately 30,869 barrels of crude oil would be evaporated/dispersed w ithin 24 hours, with approximately 123,478 barrels remaining.

Spill Response MC Barrels of Oil

WCD Volume 154,347

Less 20% natural evaporation/dispersion 30,869 Remaining volume 123,478

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 a

## ATTACHMENT H-1

daily 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 will 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)).

## ATTACHMENT H-1

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) established to track resource and slick movement in real time.

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

 Information will be confirmed

 An assessment will be made and initial objectives set

 OSROs and appropriate 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 established

## ATTACHMENT H-1

Decanting 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 operations

## ATTACHMENT H-1

CGA 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 inspections

## ATTACHMENT H-1

In-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.

## ATTACHMENT H-1

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 patches

## ATTACHMENT H-1

Shoreline 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 areas

## ATTACHMENT H-1

Decanting 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 seas

## ATTACHMENT H-1

Environmental 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.

## ATTACHMENT H-1

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 215, Well Location B 64.5 miles from shore G24060 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
1ATTACHMENT H-1WCD Scenario– BASED ON WELLBLOWOUT DURING DRILLING OPERATIONS (64.5 miles from shore)123,478 bbls of crude oil (Volume considering natural weathering)API Gravity 33°FIGURE 2 – Equipment ResponseTime to MC 215, Well Location BDispersants/SurveillanceDispersant/SurveillanceDispersantCapacity (gal)StorageCapacityPersons Req.FromHrs toProcureHrs toLoadoutTravel tositeTotal HrsASIBasler 67T 2000 NA 2 Houma 1 1 0.9 2.9DC 3 1200 NA 2 Houma 1 1 1.1 3.1DC 3 1200 NA 2 Houma 1 1 1.1 3.1Aero Commander NA NA2 Houma 1 1 0.9 2.9Offshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGAHOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 10.6 1 23.695’ FRV 12342 249 NA 4 Leeville 1 0 2 5.2 0 8.295’ FRV 12342 249 NA 4 Venice 1 0 1 3.4 0 5.4Boom Barge (CGA-300)42” Auto Boom (25000’)NA NA1 Tug50 Crew4 (Barge)2 (PerCrew)Leeville 4 0 6 18.6 1.5 30.1T&T Marine (available through contract with CGA)Koseq Skimming Arms (4) 71316 8000 4 Utility 24 Galliano 24 24 16.6 10.8 2 77.4Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey 24 24 15.8 7.1 2 72.9Recovered 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 47.25ATTACHMENT H-1Staging Area: VeniceOffshore Equipment WithStagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toSiteHrs toDeployTotalHrsCGAFRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 1 2 12.7 7.1 1 23.8FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 1 2 2.1 7.1 1 13.2FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 1 2 17.7 7.1 1 28.8FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 8 7.1 1 19.1FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 4.4 7.1 1 15.5FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 4.9 7.1 1 16.0FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 7.1 1 11.1Hydro-Fire Boom NA NA 8 Utility 40 Harvey 1 4 2.1 7.1 6 20.2T&T Marine (available through contract with CGA)Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 12.7 7.1 1 36.8ATTACHMENT H-1Nearshore ResponseNearshore Equipment NoStagingEDRCStorageCapacityVOOPersonsRequiredFromHrs toProcureHrs toLoadoutHrs toGOMTravel toSpill SiteHrs toDeployTotalHrsCGA46’ FRV 5000 65 NA 4 Morgan City 1 0 2 4.8 0 7.846’ FRV 5000 65 NA 4 Venice 1 0 1 2.0 0 4.0Trinity SWS 21500 249 NA 4 Venice 1 2 2 2.0 0 7.0Enterprise Marine Services LLC (available through contract with CGA)CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 15.00 1 36.00CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 15.00 1 36.00CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 15.00 1 36.00Staging Area: VeniceNearshore and InlandSkimmers With StagingEDRCStorageCapacityVOOPersonsReq.FromHrs toProcureHrs toLoadoutTravel toStagingTravel toDeploymentHrs toDeployTotal HrsCGASWS Egmopol 3000 100 NA 3 Morgan City 1 2 4.9 2 0 9.9SWS Marco 3588 20 NA 3 Lake Charles 1 2 8 2 0 13SWS Marco 3588 34 NA 3 Leeville 1 2 4.4 2 0 9.4SWS Marco 3588 34 NA 3 Venice 1 2 0 2 0 5ATTACHMENT H-1Shoreline 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 1 2 2.1 1 2 8.1Bird Scare Guns (48) NA NANA 2 Harvey 1 2 2.1 1 2 8.1Bird Scare Guns (12) NA NANA 2 Galveston 1 2 12.7 1 2 18.7Bird Scare Guns (12) NA NA NA2 Aransas Pass 1 2 17.7 1 2 23.7Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 8 1 2 14Bird Scare Guns (24) NA NA NA 2 Leeville 1 2 4.4 1 2 10.4Response 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 L – Pg. 11 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION L
SUPPORT VESSELS AND AIRCRAFT INFORMATION

L.1 GENERAL The most practical, direct route from the shore base as permitted by weather and traffic
conditions will be utilized.

Ensco 8505 Type Maximum Fuel Tank Capacity Maximum Number in Area at Any Time Trip Frequency or Duration

Crew Boat 1500 bbls 1 2 per week
Supply Boat 2500 bbls 2 2 per week

Helicopter 600 gals 1 6 per week

L.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

L.3 DRILLING FLUID TRANSPORTATION Drilling fluid transportation information is not required to be submitted with this plan.

L.4 SOLID AND LIQUID WASTE TRANSPORTATION A table, “Wastes You Will Transpor t and/or Dispose of Onshore,” is included as
Attachment L-1

.

L.5 VICINITY MAP A vicinity map showing the location of the activities proposed herein relative to the
shoreline with the distance of the proposed activities from the shoreline and the primary route(s) of the support vessels and aircra ft that will be used when traveling between the onshore support facilities and the drilling unit was provided for in Revised Exploration Plan (Control No. R-6113).ATTACHMENTL‐11000 lbs / well Disposed OnshoreCaCI2 / CaBr2 / KCI / NaCIBelow deck storage tanks on offshore supportvesselsNewportEnvironmentalServices, Inc.,Ingleside Texas1000 lbs / well Disposed OnshoreWell Completion FluidsWell Treatment FluidsCaCI2 / CaBr2 / KCI / NaCIBelow deck storage tanks on offshore supportvesselsNewportEnvironmentalServices, Inc.,Ingleside TexasRecycledSynthetic Based Cuttings Internal OlefinBelow deck storage tanks on offshore supportvesselsNewportEnvironmentalServices Inc.,Ingleside, TX1000 bbls/wellWill drilling occur? If yes, fill in the muds and cuttings.Disposal MethodSUPPORTVESSELSANDAIRCRAFTINFORMATION(30CFR250.224&257)‐Drilling(c) Wastes you will transport and/or dispose of onshore.Please specify if the amount reported is a total or per well amount.Projected Generated Waste Solid and Liquid Wastes Transportation Waste DisposalType of Waste Composition Transport MethodName/Location ofFacilityAmountNOTE: IF YOU WILL NOT HAVE A TYPE OF WASTE, ENTER“NA”IN THE ROW.Synthetic Base Mud Internal OlefinBelow deck storage tanks on offshore supportvesselsM-I SwacoPort Fourchon, La.13500 bbls/well RecycledWill you have additional wastes that are not permitted for discharge?Trash and debrisUsed oilChemical product wastesWash waterNon-hazardous trash & debris(non-recyclables)Transport in DOT containers on supply vessels toshorebaseProgressive WasteSolutions of LA,Houma, LA700 lbs / wellDisposed inLandfillRecycledN/ARecylced420 gal / well(10 bbls well)N/A130 lbs / wellUsed oil and glycolN/APaints, solvents, unusedchemicals, etc.Safety KleenSystem, BatonRouge, LAN/ASafety KleenSystem, BatonRouge, LATransport in DOT containers on supply vessels toshorebaseN/ATransport in DOT containers on supply vessels toshorebaseDeep Gulf Energy II, LLC Section M – Pg. 12 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION M
ONSHORE SUPPORT FACILITIES INFORMATION

M.1 GENERAL Name Location Existing/New/Modified

Fourchon C-Port Port Four chon, Louisiana Existing

M.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.

M.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.

M.4 WASTE DISPOSAL The Table, “Wastes You Will Trans port and/or Dispose of Onshore,” is included as
Attachment L-1

.Deep Gulf Energy II, LLC Section N – Pg. 13 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION N
COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION

A certificate of Coastal Zone Management C onsistency for the st ate of Alabama is
included as Attachment N-1.

A certificate of Coastal Zo ne Management Consistency for t he state of Louisiana is not required for the operations proposed in this plan.

A certificate of Coastal Zo ne Management Consistency for t he state of Texas is not required for the operations proposed in this plan.Deep Gulf Energy II, LLC Section N – Pg. 14 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 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 101 miles from Alabama’s coastline.

Commercial Fishing Section H

Hazard Management Section C Shallow Hazards Reports were prepared and previously submitted to BOEM under Ex ploration Plan Control N9683 and N-9735 in order to identify and assess the seafloor and shallo w geologic conditions in the block. Shoreline Erosion Section H Proposed exploration operations will take place approximately 101 miles from Alabama’s coastline. Recreation Section H Transportation Section L Natural Resource Protection Policies Biological Productivity Section O Environmental Impact Analysis

Water Quality Section O Environmental Impact Analysis Water Resources Section O Environmental Impact Analysis

Air Quality Section G Environmental Impact Analysis Wetlands and Submerged Grassbeds Section O Environmental Impact AnalysisDeep Gulf Energy II, LLC Section N – Pg. 15 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060)

Beach and Dune Protection Section O Environmental Impact Analysis

Wildlife Habitat Protection Section O Environmental Impact Analysis

Endangered Species Section O

Cultural Resources Protection Section E MC 215 is located in an area where historic shipwrecks may exist. An archaeological reports were prepared and it was determined that t here are no known historic shipwrecks located in the block. The reports were previously submitted to BOEM.

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.

A certificate of Coastal Zone Management C onsistency for the st ate of Alabama is
included as Attachment N-1

.Deep Gulf Energy II, LLC Section O – Pg. 16 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION O
ENVIRONMENTAL IMPACT ANALYSIS

The Environmental Impact Analysis is included as Attachment O-1.

## Deep Gulf Energy II, LLC

Supplemental Exploration Plan

Mississippi Canyon Block 215 OCS-G 24060

(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 concentrations 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 Missis sippi Canyon Block 215
Proposed operations consist of drilling and comp leting well Location B and C (Location C is a mirror location of the B well and is included to provide an alternate well site should complications occur while drilling the planned B Location). The operations will be conducted with an Ensco 8500 Series (or equivalent) Dynamically Positioned Semisubmersible Drilling Unit.

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

Effluents: Mississippi Canyon Block 215 is 91.7 miles fr om 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 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 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 covered by Deep Gulf Energy II, LLC’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 effluents and accidents.

Effluents: Mississippi Canyon Block 215 is 29 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 severalorders 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 Deep Gulf Energy II, LLC’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 215 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 Deep Gulf Ener gy II, LLC’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 Dynamically Positioned Semisubmersible Dr illing Unit is being used for the proposed activities; therefore, only an insignificant amount of seafloor will be disturbed. Because physical disturbances to the seafloor will be mini mized by the use of a Dynamically Positioned Semisubmersible Drilling Unit, Deep Gulf Ener gy II, LLC’s proposed opera tions in Mississippi Canyon Block 215 would not cause imp acts to benthic communities.5. Water Quality
IPFs that could result in water quality degrada tion from the proposed oper ations in Mississippi Canyon Block 215 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 impact s 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 Deep Gulf Energy II, LLC’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 215 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 and parent compounds. The activities proposed in this plan will be covered by Deep Gulf Energy II, LLC’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 215 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).

Deep Gulf Energy II, LLC will operate in acco rdance 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 material s 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 Deep Gulf Energy II, LLC management or the designated lease operator manageme nt that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

Accidents: Collisions between support vessels and cetaceans would be unusual events, however should one occur, death or injury to marine mammals is possible. Contract vessel operators can avoid marine mammals and reduce potential deaths by maintaining a vigilant watch for marine mammals and maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to help identify the twenty-eight species of whales and dolphins, and the single species of manatee that may be encountered in the Gulf of Mexico OCS. Vessel crews must report sightings of any injured or dead protected marine 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 ch emicals included in Deep Gulf Energy II, LLC’s OSRP is considered to be low when compared w ith the constituents and fractions of crude oils and diesel products. The activities proposed in this plan will be covered by Deep Gulf Energy II, LLC’s OSRP (refer to informati on 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 thesespecies 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). Deep Gulf Energy II, LLC 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 materi als 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 Deep Gulf Energy II, LLC management or the designated lease operator manageme nt that emphasizes their commitment 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 RegionalOffice 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 vessel is the responsible party, it is required to remain available to assist the respective salvage and stranding network as needed.

All sea turtle species and their life stages are 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 D eep Gulf Energy II, LLC’s Regional Oil Spill Response Plan (refer to informa tion 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 215 is lo cated 83.5 miles from the Bret on Wilderness Area and 64.5 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 215 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 215 in clude disturbances to the seafloor.

Physical disturbances to the seafloor: A Dynamically Positioned Semisubmersible Drilling Unit is being used for the proposed activities; therefore, only an insignificant amount of seafloor will be disturbed. Because physical disturbances to the seafloor will be minimized by the use of a Dynamically Positioned Semisu bmersible Drilling Unit, Deep Gulf Energy II, LLC’s proposed operations in Mississippi Canyon Block 215 would not cause impacts to shipwreck sites.Additionally, Missis sippi Canyon Block 215 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.

Deep Gulf Energy II, LLC 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 Deep Gulf Energy II, LLC to be clear of seafloor archaeological resources, including historic shipwrecks. C opies of the certificati ons and a circle radius plat of the survey area will be submitted to the BOEM. Should a re source be encountered, Deep Gulf Energy II, LLC 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 215 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 Dynamically Positioned Semisubmersi ble Drilling Unit, which would cause only an insignificant amount of seafloor to be distur bed, Mississippi Canyon Block 215 is located inside the Archaeological Prehistoric high probability li nes. Deep Gulf Energy II, LLC will report to BOEM the discovery of any object of prehisto ric archaeological significance and make every reasonable effort to preserve a nd protect that cu ltural resource.

Deep Gulf Energy II, LLC 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 Deep Gulf Energy II, LLC to be clear of seafloor archaeological resources. Copies of the certifications and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be encountered, Deep Gulf Energy II, LLC will contact the BOEM immediately and make every reasonable effort to preserve and protect that cultural 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 Deep Gu lf Energy II, LLC’s Regional Oil Spill Response Plan (refer to inform ation 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 215 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 Deep Gulf Energy II , LLC’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 wouldactually be affected to that extent. The activitie s proposed in this plan will be covered by Deep Gulf Energy II, LLC’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). Deep Gulf Ener gy II, LLC 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 material s such as plastic or glass. Informational placards will be posted on all ve ssels and facilities having sl eeping or food preparation capabilities. All offshore pers onnel, including contractors and other support services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and will view the video (or Microsof t PowerPoint presentation), “Think About It” ( previously “All Washed Up: The Beach Litter Problem” ). Thereafter, all personnel will view the marine trash and debris trai ning video annually. Offshore pe rsonnel will also receive an explanation from Deep Gulf Energy II, LLC management or the de signated lease operator management that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01. Debris, if any, from these proposed activities will seldom interact with marine and pelagic birds; therefore, th e 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 dist ance from shore (64.5 miles) and the response capabilities that would be implemented, no si gnificant adverse impacts are expected. The activities proposed in this plan will be covered by Deep Gulf Energy II, LLC’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 Protection Agency (EPA). Deep Gu lf Energy II, LLC will operate in accordance with the regulations and also avoid 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 Deep Gulf Energy II, LLC management or the designated lease operator manageme nt that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the 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 (64.5 miles) and the response capabilities that would be implemented, no impacts are expected. The activities proposed in this plan will be covered by Deep Gulf Energy II, LLC’s Regiona l 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 and Control Act, and regulations imposed by variou s agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA). Deep Gu lf Energy II, LLC will operate in accordance with the regulations and also avoid 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 Deep Gulf Energy II, LLC management or the designated lease operator manageme nt that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the 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 (64.5 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 Deep Gulf Energy II, LLC’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). Deep Gulf Energy II, LLC will operate in accordance w ith the regulations and also avoid accidental loss of solid waste items by maintaining waste ma nagement plans, manife sting 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 exer cised when handling and disposing of small items and packaging materials, particularly those made of non-biodegradable, environmentally persistent materials such as plastic or glass.Informational placards will be posted on vessels and every facility that has sleeping or food preparation capabilities. All offshore 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 Deep Gulf Energy II, LLC management or the designated lease operator manageme nt that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the 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 distance from shore (64.5 miles) and the response capabilities that would be implemented, no impacts ar e expected. The activities proposed in this plan will be covered by Deep Gulf Energy II, LLC’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). Deep Gulf Energy II, LLC 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 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 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 Deep Gulf Energy II, LLC management or the designated lease operator manageme nt that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.There are no other IPFs (emissions , effluents, physical disturbances to the 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 th e nearest designated Wilderness Area (83.5 miles) and the response capabilities that would be implemented, no significant adverse impacts are expected. The activities propo sed in this plan will be c overed by Deep Gulf Energy II, LLC’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). Deep Gulf Energy II, LLC 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 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 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 Deep Gulf Energy II, LLC management or the designated lease operator manageme nt that emphasizes their commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions , effluents, physical disturbances to the 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 215 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 preparing 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 P – Pg. 17 of 17 Supplemental EP August, 2014 Mississippi Canyon Block 215 (OCS-G 24060) 

### SECTION P
ADMINISTRATIVE INFORMATION

P.1 EXEMPTED INFORMATION DESCRIPTION The proposed bottom-hole location of the planned well has 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.

P.2 BIBLIOGRAPHY 1. Initial Exploration Pl an (Control Number N-9735). 2. Regional Oil Spill Response Plan (Control Number O-978) 3. Revised Exploration Plan (Control Number R-6113). 4. Fugro Geoconsulting, Inc. “Wellsite Cle arance Letter, Propos ed Wellsite MC 215- C, Block 215, Mississippi Canyon Area (OCS-G-24060), 1 August 2014, Report No. 27.1401-2756”.