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, 2014
Records of Changes – PUBLIC COPY 

S7702, Supplemental EP, Deep Gulf Energy II, LLC, (OCS-G 24060, Mississippi Canyon Block 2

Date Section Page Remarks 

09/04/14 All All Plan received by BOEM. 09/19/14 E Attachment E-1 Rescanned Water Depth & Seafloor Features Map 09/26/14 F Page 7 and Attachment F-1 Removed reference to waste table in R-6113 and pr

table. 

 09/30/14 L Page 11 and Attachment L-1 

Removed reference to waste table in R-6113 and prtable. 
 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.com
TOC Pg 1 of 2 

TABLE OF CONTENTS 

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

A.1 PLAN INFORMATION ........................................................................................... 1

A.2 LOCATION ............................................................................................................ 1

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

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

SECTION B GENERAL INFORMATION ....................................................................... 4

B.1 APPLICATIONS AND PERMITS ........................................................................... 4

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

B.3 BONDING STATEMENT ....................................................................................... 4

B.4 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR) ............................................... 4

B.5 DEEPWATER WELL CONTROL STATEMENT .................................................... 4

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

SECTION C GEOLOGICAL AND GEOPHYSICAL INFORMATION .............................. 5

C.1 GEOLOGICAL DESCRIPTION ............................................................................. 5

C.2 STRUCTURE CONTOUR MAP ............................................................................ 5

C.3 INTERPRETED SEISMIC LINE(S) ........................................................................ 5

C.4 GEOLOGICAL STRUCTURE CROSS-SECTIONS ............................................... 5

C.5 SHALLOW HAZARDS REPORT ........................................................................... 5

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

C.7 HIGH-RESOLUTION SEISMIC LINES .................................................................. 5

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

C.9 TIME VERSUS DEPTH TABLES .......................................................................... 5

SECTION E BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION ..... 6

E.1 DEEPWATER BENTHIC COMMUNITIES ............................................................. 6

SECTION F WASTES AND DISCHARGES INFORMATION ........................................ 7

F.1 PROJECTED GENERATED WASTES .................................................................. 7

SECTION G AIR EMISSIONS INFORMATION ............................................................. 8
TOC Pg 2 of 2 

G.1 EMISSIONS WORKSHEETS AND SCREENING QUESTIONS ........................... 8

G.2 SUMMARY INFORMATION .................................................................................. 8

SECTION H OIL SPILL INFORMATION ....................................................................... 9

H.1 OIL SPILL RESPONSE PLANNING ...................................................................... 9

H.2 SPILL RESPONSE SITES .................................................................................... 9

H.3 OSRO INFORMATION .......................................................................................... 9

H.4 WORST CASE SCENARIO DETERMINATION .................................................... 9

H.5 OIL SPILL RESPONSE DISCUSSION ................................................................ 10

SECTION L SUPPORT VESSELS AND AIRCRAFT INFORMATION ........................ 11

L.1 GENERAL ............................................................................................................ 11

L.2 DIESEL OIL SUPPLY VESSELS ......................................................................... 11

L.3 DRILLING FLUID TRANSPORTATION ............................................................... 11

L.4 SOLID AND LIQUID WASTE TRANSPORTATION ............................................. 11

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

SECTION M ONSHORE SUPPORT FACILITIES INFORMATION ............................. 12

M.1 GENERAL ........................................................................................................... 12

M.2 SUPPORT BASE CONSTRUCTION OR EXPANSION ...................................... 12

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

M.4 WASTE DISPOSAL ............................................................................................ 12

SECTION N COASTAL ZONE MANAGEMENT ACT (CZMA) INFORMATION ......... 13

SECTION O ENVIRONMENTAL IMPACT ANALYSIS................................................ 16

SECTION P ADMINISTRATIVE INFORMATION ........................................................ 23

P.1 EXEMPTED INFORMATION DESCRIPTION ..................................................... 23

P.2 BIBLIOGRAPHY .................................................................................................. 23
 Attachments 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, Geophysical Information 

 C-1 Shallow Hazards Assessment 

Section E Biological, Physical and Socioeconomic Information 

 E-1 Biologically Sensitive 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 Spill Response Discussion 

Section L Support Vessels and Aircraft Information 

 L-1 Waste You Will Transport and/or Dispose Onshore 

Section N Coastal Zone Management Act (CZMA) Information 

 N-1 Coastal Zone Consistency Certification (Alabama) 

Section O Environmental Impact Analysis (EIA) 

 O-1 Environmental 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”) submitted an Initial Exploration 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 Exploration 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 Unit 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 complete Well Location B within 500 feet of the 

surface location as approved in Plan Control N-9735, provide new Worst Case 

Discharge Calculations and a Dynamically Positioned Semisubmersible Drilling Unit and 

amend the estimated startup date to January 31, 2015. The Revised Exploration Plan 

was approved on August 27, 2014. To date, drilling 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 included to provide an alternate well site should 

complications occur while drilling the planned B Location). DGE II will utilize an Ensco 

8500 Series (or equivalent) Dynamically Positioned Semisubmersible Drilling Unit. 

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

A.2 LOCATION 

A Well Location Plat depicting the proposed surface and bottomhole location of the 

proposed wells is included as Attachment A-2.

No anchors are associated with the proposed activities in this plan.

A Bathymetry Map depicting the proposed surface 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 well with an Ensco 8500 Series (or equivalent) Dynamically 

Positioned Semisubmersible with Subsea BOP’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 States Coast Guard (USCG) regulations. 

Appropriate life saving equipment such as life rafts, life jackets, ring buoys, etc. as 

prescribed by the USCG, will be maintained on the rig at all times. 

Safety features on the Ensco 8500 Series drilling units include well control, pollution 

prevention, and blowout prevention equipment as described in BSEE regulations 30 

CFR 250 C, D, E, O, Q and S; and as further clarified by BSEE Notices to Lessees, and 

current policy making invoked by the BSEE, Environmental Protection Agency and the 

U.S. Coast Guard (USCG). 

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

drains on drilling deck areas to collect all contaminants and debris. Compliance will be 

maintained with the EPA NPDES Permit which 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 representative 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/A 
Deep 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 which the State of Florida is an affected 

state. 

A.6 ADDITIONAL MEASURES 

DGE II does not propose any additional safety, pollution prevention, 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 information to verify the calculations and assumptions for your WCD? X Yes X No 

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

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

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

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

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

Proposed Activity Start Date End Date No. of Days 

Drill and Complete Well Location B 11/01/2014 02/13/2015 105 

Drill and Complete Well Location C (Alternate 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 previous editions of this form which may not be used.) Page 1 of 4 

General Information 

Type of OCS Plan: X Exploration Plan (EP) Development 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: 12/31/14 
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): 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 floating 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): 

Anchor Radius (if applicable) in feet: N/A TVD (Feet): 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

Form BOEM- 0137 (December 2011 – Supersedes all previous editions of this form which may not be used.) Page 2 of 4 
OCS PLAN INFORMATION FORM (CONTINUED) 

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

Proposed Well/Structure Location 

Well or Structure Name/Number (If renaming well or 

structure, reference previous name): 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 floating 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): 

Anchor Radius (if applicable) in feet: N/A TVD (Feet): 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

 X: Y: 

Form BOEM- 0137 (December 2011 – Supersedes all previous editions of this form which may not be used.) Page 2 of 4 
MC_215

C

B

Deep Gulf Energy II, LLC

MC 215

Well Surface Location Map

0 6000 ft 2000 4000

Scale = 1:24000

3,670’

Y = 10,454,400’

Y = 10,438,560’

X

= 1,314,720’

X

= 1,298,880’

7,302’

Surface Location

OCSͲG 24060 WellB

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’md17,000’tvd

Water Depth 6,008’

7,302’

3,470’

Surface Location

OCSͲG 24060 WellC

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’md17,000’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

6 4 5

4

3

6

2 7

2

1

5 0

0

6

5

9

2

7

0

6

3

6

2

6 7

1

5

6

6

5

5

5

2

5

5

2 5 6

0

0

9 7

5

9

6

7

5

5

5

0 2

6

0

6

5

6 1

1

0

0

2

6

6 0

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’
Receipt

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

Transaction 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 emailed to:

holtinc@msn.com

mphinney@deepgulfenergy.com

Print Receipt
Deep 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 other 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 appropriate BSEE District. 

B.2 DRILLING FLUIDS 

The table below provides the types and estimated 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, freshwater, barite) 50,000 bbls/well 

Oil-based (diesel, mineral oil) N/A 

Synthetic-based (internal olefin, ester) 13,500 bbls/well 

B.3 BONDING STATEMENT 

The bond requirements for the activities and facilities proposed in this EP are satisfied 

by a lease-specific development bond, furnished and maintained according to 30 CFR 

556, Subpart I; NTL No. 2000-G16, "Guidelines for General Lease Surety Bonds"; and 

additional security under 30 CFR 556.53(d) and National NTL No. 2008-N07, 

“Supplemental Bond Procedures” as required by BOEM. 

B.4 OIL SPILL FINANCIAL RESPONSIBILITY (OSFR) 

Deep Gulf Energy II, LLC, Operator Number 02985, has demonstrated oil spill financial 

responsibility for the facilities proposed in this EP according to 30 CFR 553; and NTL 

No. 2008-N05, "Guidelines for Oil Spill Financial Responsibility for Covered Facilities" 

prior to conducting operations covered in this EP. 

B.5 DEEPWATER WELL CONTROL STATEMENT 

Deep Gulf Energy II, LLC, Operator number 02985 has the financial capability to drill a 

relief well and conduct other emergency well control operations. 

B.6 BLOWOUT SCENARIO AND WORST 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 blowout will be a function of the well 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 uncontrolled 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 operational 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 bridge over during a blowout 

There is potential for the wellbore to bridge over during the WCD blowout. Bridging may 

occur due to the drawdown calculated between 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 flowing pressures, based upon reservoir 

properties and flow rates. The calculated delta 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 the risk of wellbore collapse and sand/fines 

migration into a well. There is a potential 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 wellbore collapse and 

bridging, 

Surface intervention to stop the blowout 

In the event of a blowout and assuming the blowout 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 either abandon or return to normal operations. Surface 

intervention would be the first line of defense after a blowout occurs. The specific 

intervention technique chosen will depend on actual conditions and ability to access the 

existing well. 

In the event that the subsea BOP is inoperable, the surface intervention would employ 

the Helix Well Containment Group (HWCG) containment system to achieve successful 

containment of the well. The system will be employed, while simultaneously initiating 

relief well planning and operations. Specifics will be submitted within the Well 

Containment Plan. 

Typically blowouts can be controlled with surface intervention, with a good likelihood of 

success and in a relatively short time frame, 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 access 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 uncontrolled blowout and the MODU has sunk 

with displacement from the wellhead. Additionally, it assumes that debris removal will be 

required to gain access to the subsea BOP system. The ROV has been deployed and 

was unsuccessful in shutting in the well, using 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 estimated 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 parallel. The entire 

operation is estimated to take 15 days from start of site assessment until the capping 

stack has been deployed and the well shut in. 
Duration of a well capping operation 

Operation Incremental 

Duration 

(days) 

Cumulative Time Since 

Event Start 

(days) 

Assess wellbore conditions for 

surface intervention requirements. 

Conduct notifications to the 

regulatory agencies and primary 

contractors. 

2 2 

Site Preparation which includes 

mobilizing and deployment 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 availability. 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 seabed 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 cleared-of-hazards surface location 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 Drill Ship Contracted 

GOM 

Relief well package constraints 

The proposed rigs for relief well operations have suitable drilling packages with 

sufficient capabilities to work in the subject water depths and drill to the required relief 

well depth. The BOP systems have met the BSEE certification requirements and will be 

re-inspected in transit, prior to drilling a relief well to the required true vertical depth. 

Relief well rig contract and mobilization timing 

A suitable rig could be selected and a contract finalized in 48 hours after undertaking 

the decision to begin relief well operations. Backup tubulars and wellhead systems are 

maintained in stock for each well. Mobilization of equipment and services to the rig for 

the relief well could be completed while operations required to suspend the rig’s current 

activity were taking place. The time required 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 install 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 operating 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 other required BSEE testing 

requirements, 

 Current Well Control Certification for 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 during each tour and posting the same on the rig floor, 

 Maintain a current BOP to RKB spaceout Chart, 

 Monitoring wellbore fill-ups and displacements during trips, by the Well Site 

Supervisor, 

 Maintain the necessary circulating swages, TIW Valves and IBOP on the rig 

floor at all times during operations and function test these valves during each 

tour. 

The utilization of Pre-Job Safety meetings will continue to be implemented prior to each 

operation with all of the rig crews. These are intended to create a behavior based safety 

program and promote an atmosphere within the and rig crew interface, such that a 
“Stop the Job” mentality is promoted across the rig contractor’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 surface, 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 compromised, then debris removal will be initiated 

to obtain clear access to the BOP. A Capping Stack will be employed to achieve 

successful containment of the well. Once containment is established and wellbore 

pressure testing and assessment is completed by DGE II and Well Control Specialist, 

well kill operations can be initiated through the existing wellbore. 

Well control engineering services 

DGE II will have service agreements in place with Wild Well Control and Boots and 

Coots International Well Control 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 control and/or relief well operations. 

Additional prevention & mitigation techniques 

Pursuant to wellbore cementing and zonal isolation techniques, all cementing 

operations will be modeled and designed under the guidelines set forth in API 

Recommended Practice 65 Part 1 & 2. Operations will be dictated by the rules and 

requirements set forth in Federal Regulations, under the wellbore cementing 

requirements. 

API Standard 53 Blowout Prevention Equipment 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 testing of blowout prevention systems has 

contracted for floating marine drilling rigs. 

The goal of using these recommended practices is to assist DGE II operations in 

promoting personnel safety, public safety, and integrity of the drilling equipment and 

preservation of the environment for floating marine drilling operations. These 

recommended practices help to facilitate the broad availability of proven, sound 

engineering and operating practices. 

These practices are considered acceptable for accomplishing BOP and Marine Riser 

associated operations. However, equivalent alternative installations and practices may 

be utilized to accomplish the same objectives. When using these recommended 

practices or other alternatives, DGE II will 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 GEOPHYSICAL 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 Canyon Block 215 was previously submitted. 

C.6 SHALLOW HAZARDS ASSESSMENT 

In accordance with NTL 2008-G05, “Shallow Hazards Program” (Extended by NTL 

BOEM 2013-G02, “Extension of Prior Notices to Lessees”), a 3-D seismic shallow 

hazards assessment has been prepared for the proposed alternate surface location, 

evaluating seafloor and subsurface geological and manmade features and conditions 

that may adversely affect drilling operations. The Shallow Hazards Survey and 

Archaeological Assessment is included as Attachment 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 SOCIOECONOMIC INFORMATION 

E.1 DEEPWATER BENTHIC COMMUNITIES 

The seafloor disturbing activities proposed in this plan are in water depths greater than 

300 meters (984’). Fugro Geoconsulting, Inc. (“Fugro”) was contracted to provide an 

assessment of the shallow conditions at the proposed alternate 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, “Deepwater Benthic Communities,” a map 

showing the 2,000 foot radius around 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 DISCHARGES INFORMATION 

F.1 PROJECTED GENERATED WASTES 

“Wastes You Will Generate, Treat and Downhole 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 chute
Deep 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 (CT) Emission amount (tons) associated 

with your proposed exploration activities more than 90% of the amounts 

calculated using the following formulas: CT = 3400D2/3 for CO, and CT = 

33.3D for the other air pollutants (where D = distance to shore in miles)? 

 X 

Do your emission calculations include any emission reduction measures or 

modified emission factors? 

X 

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

Do you expect to encounter H2S at concentrations greater than 20 parts 

per million (ppm)? 

 X 

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

hours from any proposed well? X 

Do you propose to burn produced hydrocarbon liquids? X 

G.2 SUMMARY INFORMATION 

There are no co-existing facilities or activities co-located with the currently proposed 

activities; therefore, the Complex Total Emissions are the same as the Plan Emissions. 

Air Emissions Worksheets which show the emission 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.com 
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB 

COMPANY Deep Gulf Energy II, LLC (DGE II)

AREA Mississippi Canyon BLOCK 215LEASE OCS-G 24060PLATFORM N/A

WELL B and C (Location C is provided as an alternate location should 

complications arise during drilling).

COMPANY CONTACT Kelley PisciolaTELEPHONE NO. 281.698.8519

Drill and Complete Well Location B (Location C is provided as an alternatwell location should complications arise during drilling) with an Ensco 850DP Semi (AQR for DP Semi calculated using Ensco 8500 Series Specific 

REMARKS Horsepower).

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 1 of 8
EMISSIONS FACTORS

Fuel Usage Conversion Factors Natural Gas Turbines Natural Gas Engines Diesel Recip. Engine RE

SCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483 AP42 

Equipment/Emission Factors units PM SOx NOx VOC CO RENG Turbines gms/hp-hr 0.00247 1.3 0.01 0.83 AP42 3.2-NG 2-cycle lean gms/hp-hr 0.00185 10.9 0.43 1.5 AP42 NG 4-cycle lean gms/hp-hr 0.00185 11.8 0.72 1.6 AP42 NG 4-cycle rich gms/hp-hr 0.00185 10 0.14 8.6 AP42 Diesel Recip. < 600 hp. gms/hp-hr 1 1.468 14 1.12 3.03 AP42 Diesel Recip. > 600 hp. gms/hp-hr 0.32 1.468 11 0.33 2.4 AP42 Diesel Boiler lbs/bbl 0.084 2.42 0.84 0.008 0.21 AP42 1.3NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84 P42 1.4-1, 1NG Flares lbs/mmscf 0.593 71.4 60.3 388.5 AP42 1Liquid Flaring lbs/bbl 0.42 6.83 2 0.01 0.21 AP42 1.3-Tank Vapors lbs/bbl 0.03 E&P FFugitives lbs/hr/comp. 0.0005 API SGlycol Dehydrator Vent lbs/mmscf 6.6 La. DGas Venting lbs/scf 0.0034

Sulphur Content Source Value Units

Fuel Gas 3.33 ppm

Diesel Fuel 0.4 % weight

Produced Gas( Flares) 3.33 ppm

Produced Oil (Liquid Flaring) 1 % weight

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 2 of 8
EMISSIONS CALCULATIONS 1ST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Deep Gulf Energy II, LLC Mississippi Canyon 215 OCS-G 24060 N/A B and C (Location C is provided as an alternKelley Pisciola 281.698.8519 

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR 

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21739 1049.9937 25199.85 24 60 15.32 70.29 526.72 15.80 114.92 11.03 

DP Semisubmersible PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 17 1.46 6.68 50.03 1.50 10.92 0.10 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 17 3.10 14.23 106.61 3.20 23.26 0.26 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

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

MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 

2014 YEAR TOTAL 19.88 91.20 683.36 20.50 149.10 11.39 

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2147.85 

64.5

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 3 of 8
EMISSIONS CALCULATIONS 1ST YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

Deep Gulf Energy II, LLC Mississippi Canyon 215 OCS-G 24060 N/A B and C (Location C is provided as an alternKelley Pisciola 281.698.8519 

OPERATIONS EQUIPMENT RATING MAX. FUEL ACT. FUEL RUN TIME MAXIMUM POUNDS PER HOUR 

Diesel Engines HP GAL/HR GAL/D

Nat. Gas Engines HP SCF/HR SCF/D

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

DRILLING PRIME MOVER>600hp diesel 21739 1049.9937 25199.85 24 150 15.32 70.29 526.72 15.80 114.92 27.58 

DP Semisubmersible PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 8 43 1.46 6.68 50.03 1.50 10.92 0.25 VESSELS>600hp diesel(supply) 4400 212.52 5100.48 10 43 3.10 14.23 106.61 3.20 23.26 0.67 VESSELS>600hp diesel(tugs) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

FACILITY DERRICK BARGE diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 INSTALLATION MATERIAL TUG diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 

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

MISC. BPD SCF/HR COUNTTANK- 0 0 0 0.00 

DRILLING OIL BURN 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 

2015 YEAR TOTAL 19.88 91.20 683.36 20.50 149.10 28.50 

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2147.85 

64.5

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 3 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELLDeep Gulf EnergMississippi Canyon 215 OCS-G 24060 N/A B and C (Location 

Emitted Substance

Year

 PM SOx NOx VOC CO

2014 11.39 52.27 391.70 11.75 85.462015 28.50 130.73 979.61 29.39 213.73

Allowable 2147.85 2147.85 2147.85 2147.85 54682.97

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 8 of 8
ACTUAL 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 Rigs 256106.0 235.83 bbl/day

21.15 1 Std. Deviation

63.5 3 std. deviation

299.28 bbls/day, Mean + 3 std. 

deviations (99.73%)

0.0483 gal/hp-hr (diesel recip. 

Factor, AQE)

10843.47 HP

21686.94 HP x 2

21739.00 HP used in AQE 

reporting

600.00 bbl/day used in AQE 

reporting

257.47

257.03

230.49

242.49

202.11

225.36

Daily Fuel Consumption 8500 series January 1, 2013 to July 1, 2013 (181 days)
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 (OSRP) filed by Deep Gulf Energy 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 provider is Clean Gulf Associates (CGA). Clean Gulf 

Associates Services, LLC (CGAS) will provide the closest personnel, as well as the 

CGAS supervisor to operate 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 154,347 154,347 
Deep 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 for 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 regional 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 that DGE II has the capability to respond, to 

the maximum extent practicable, to a worst-case discharge, or a substantial threat of 

such a discharge, resulting from the activities proposed in our 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 Management Act analysis, the largest spill volume 

originating from the proposed activity would be a well blowout 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 BOEM 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 islands 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. Sandy and muddy tidal flats are also abundant. 

Response 

DGE II will make every effort to respond to the Worst Case Discharge as effectively as 

practicable. A description of the response equipment under contract to contain and recover the 

Worst Case Discharge is shown in Figure 2.

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

model was run on a similar product from the ADIOS oil database. The results indicate 20% or 

approximately 30,869 barrels of crude oil would be evaporated/dispersed within 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, travel 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 utilized, 8 sorties (9,600 gallons) from 

two of the DC-3 aircrafts and 4 sorties (8,000 gallons) from the Basler aircraft would provide a 
 ATTACHMENT H-1 

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

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

may be attempted. Slick containment boom would be immediately called out and on-scene as 

soon as possible. Offshore response strategies may include attempting to skim utilizing CGA’s 

spill response equipment, with a total derated skimming capacity of 258,477 barrels. Temporary 

storage associated with skimming equipment equals 22,198 barrels. If additional storage is 

needed, a 107,285 barrel storage barge, a 47,000 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. Shoreline protection would include the use of CGA’s 

near shore and shallow water skimmers with a totaled derated skimming capacity of 45,264 

barrels. Temporary storage associated with skimming 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 deployment of shoreline boom 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 feet of 18” shoreline protection boom. Figure 2

outlines individual times needed for procurement, load out, travel time to the site and 

deployment. Strategies would be based upon surveillance and real time trajectories that depict 

areas of potential impact given actual sea and weather conditions. The State of Louisiana Initial 

Oil Spill Response Plan for Plaquemines Parish and Unified Command would be consulted to 

ensure that environmental and special economic resources would be correctly identified and 

prioritized to ensure optimal protection. Shoreline protection strategies depict the protection 

response modes applicable for oil spill clean-up operations. The State of Louisiana Initial Oil 

Spill Response Plan provides detailed shoreline protection strategies for this area, and it 

describes necessary action to keep the oil spill from entering Louisiana’s coastal wetlands, based 

on the assumption that removal of the released oil will be much easier and less damaging to 

fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. Supervisory 

personnel have the option to modify the deployment and operation of equipment allowing a more 

effective response to site-specific circumstances. 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 scenario, 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 Effective 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, aggressive response to contain and recover as much of 

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

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

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

precedence over all other considerations during these operations. 

Coordination of response assets will be supervised by the designation of a SIMOPS group as 

necessary for close quarter vessel response activities. Most often, this group will be used during 

source control events that require a significant number of large vessels operating independently, 

but in coordination to complete a common objective, in a small area and in close coordination 

and support of each other. This group must also monitor the subsurface activities of each vessel 

(ROV, dispersant application, well control support, etc.). The SIMOPS group leader reports to 

the Source Control Section Chief. 

In addition, these activities will be monitored by the spill management 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 agencies will be notified 

 ICS 201, Initial Report Form will be completed 

 Initial Safety plan will be written and published 

 Unified Command will be established 

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

objectives 

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

site 

o On-site command and control established 
 ATTACHMENT H-1 

Decanting Strategy 

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

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

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

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

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

recovery. 

Offshore Response Actions 

Equipment Deployment

Surveillance 

 Surveillance Aircraft will be deployed within two hours of Qualified Individual (QI) 

notification, or at first light

 Provide trained observer to provide on site status reports 

 Provide command and control platform at the site if needed 

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

and visual confirmation 

 Continual monitoring of vessel assets using vessel monitoring systems 

Dispersant application assets 

 Put Airborne Support Inc. (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, aircraft, and support equipment and personnel 

 Confirm dispersant availability for current and long range operations 

 Start ordering dispersant stocks required for expected operations 

Containment boom 

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

 Ensure boom handling and mooring equipment is deployed with boom 

 Provide continuing reports to vessels to expedite their arrival at sites that will provide for 

their most effective containment 

 Use Vessels of Opportunity (VOO) to deploy and maintain boom 

Dedicated off-shore skimming systems 

General 

 Deployed to the highest concentration of oil 

 Assets deployed at safe distance from aerial dispersant and in-situ burn operations 
 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 draft 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 with a draft of <10 feet when fully loaded 

Storage Vessels 

 Establish availability of CGA contracted assets 

 Early call out (to allow for tug boat acquisition and deployment speeds) 

 Phase mobilization to allow storage vessels to arrive at the same time as skimming 

systems 

 Position as closely as possible to skimming assets to minimize offloading time 

Vessels of Opportunity (VOO) 

 Use DGE II’s contracted resources as applicable 

 Industry vessels are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS) 

 Acquire additional resources as needed 

 Consider use of local assets, i.e. fishing and pleasure craft 

 Expect mission specific and safety training to be required 

 Plan with the US Coast Guard for vessel inspections 
 ATTACHMENT H-1 

In-situ Burn assets 

 Determine appropriateness of in-situ burn operation in coordination with the FOSC and 

affected State On-Scene Coordinator (SOSC) 

 Determine availability of fire boom and selected ignition 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, the use of larger recovery and storage vessels, 

oleophilic skimmers, and large offshore boom will be maximized. Safety will be the overriding 

factor in all operations and will cease at the order of the Unified Command, vessel 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 deploy in accordance with planning based on the 

actual situation, actual trajectories and oil budgets 

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

 Outfitting of VOOs for specific missions 

 Deployment of assets based on actual movement of oil 

Considerations 

 Water depth, vessel draft 

 Shoreline gradient 

 State of the oil 

 Use of VOOs 

 Distance of surf zone from shoreline 

Equipment Deployment 

Surveillance 

 Provide trained observer to direct skimming operations 

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

and visual confirmation 

 Continual monitoring of vessel assets 

Dispersant Use 

 Generally will not be approved within 3 miles of shore or with less than 10 meters of 

water depth 

 Approval would be at Regional Response Team level (Region 6) 

Vessel Deployment 

Dedicated Near Shore skimming systems 

 Fast Response Vessels (FRV) 

 Egmopol and Marco Shallow Water Skimmer (SWS) 

 Operate with aerial spotter directing systems to observed oil slicks 

VOO 

 Use DGE II’s contracted resources as applicable 

 Industry vessels are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS) 

 Acquire additional resources as needed 

 Consider use of local assets, i.e. fishing and pleasure craft 

 Expect mission specific and safety training to be required 

 Plan with the US Coast Guard for vessel inspections 

 Operate with aerial spotter directing systems to oil patches 
 ATTACHMENT H-1 

Shoreline Protection Operations 

Response Planning Considerations 

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

 Time to acquire personnel and equipment and their availability 

 Previous contingency planning contained in the appropriate Area Contingency Plan, and 

currently for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep 

Water Horizon, dated 2 May 2010 

Actions 

Placement of boom 

 Position boom in accordance with the ERA based on the actual situation or the 

appropriate ACP 

 Assess timing of booming operations to ensure it is where it needs to be at time of 

impact. Consider: 

o Trajectories 

o Weather forecast 

o Oil Impact forecast 

o Verified spill movement 

o Boom, manpower and vessel (shallow draft) availability 

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

Beach Preparation 

Considerations and Actions 

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

 Shoreline Cleanup and Assessment Team Reports and recommendations 

 Determination of Archeological sites and gaining authority to enter 

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

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

 Staging of equipment and housing of response personnel as close to the job site as 

possible to maximize on-site work time 

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

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

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

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

and/or sweep obtained 

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

inland areas 
 ATTACHMENT H-1 

Decanting Strategy 

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

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

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

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

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

recovery. 

CGA Equipment Limitations 

The capability for any spill response equipment, whether a dedicated or portable system, to 

operate in differing weather conditions will be directly in relation to the capabilities of the vessel 

the system in placed on. Most importantly, however, the decision to operate will be based on the 

judgment of the Unified Command and/or the Captain of the vessel, who will ultimately have the 

final say in terminating operations. Skimming equipment listed below may have operational 

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

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

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

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

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 winter and easterly winds in the summer. Average wind speed is 

generally 14-15 mph along the coast. Wave heights average 4 and 5 feet. However, during 

hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and 

winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, 

flooding is prominent. 

Surface water temperature ranges between 70 and 80 ̊F during the summer months. During the 

winter, the average temperature will range from 50 and 60 ̊F. 

The Atlantic and Gulf of Mexico hurricane season is officially from 1 June to 30 November. 

97% of all tropical activity occurs within this window. The Atlantic basin shows a very peaked 

season from August through October, with 78% of the tropical storm days, 87% of the minor 

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

categories 3, 4 and 5) hurricane days occurring then. Maximum activity is in early to mid 

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

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

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 

1 
ATTACHMENT H-1 

WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (64.5 miles from s123,478 bbls of crude oil (Volume considering natural weathering) API Gravity 33° 

FIGURE 2 – Equipment Response Time to MC 215, Well Location B 

Dispersants/Surveillance

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

si

ASI 

Basler 67T 2000 NA 2 Houma 1 1 0DC 3 1200 NA 2 Houma 1 1 1DC 3 1200 NA 2 Houma 1 1 1Aero Commander NA NA 2 Houma 1 1 0

Offshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

CGA 

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 95’ FRV 12342 249 NA 4 Leeville 1 0 2 95’ FRV 12342 249 NA 4 Venice 1 0 1 Boom Barge (CGA-300) 42” Auto Boom (25000’) NA NA 1 Tug 50 Crew 4 (Barge) 2 (Per Crew) Leeville 4 0 6 

T&T Marine (available through contract with CGA) 

Koseq Skimming Arms (4) 71316 8000 4 Utility 24 Galliano 24 24 16.6 Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Harvey 24 24 15.8 

Recovered Oil Storage No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

K-Sea Operating (available through contract with CGA) 

DBL 101 1119760 NA 107285 1 Tug 6 Venice 4 12 4 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 
ATTACHMENT H-1 

Staging Area: Venice

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging 

CGA 

FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Galveston 1 2 12.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Harvey 1 2 2.1 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Aransas Pass 1 2 17.7 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 8 FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 4.4 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 4.9 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 Hydro-Fire Boom NA NA 8 Utility 40 Harvey 1 4 2.1 

T&T Marine (available through contract with CGA) 

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 12.7 
ATTACHMENT H-1 

Nearshore Response

Nearshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM 

CGA 

46’ FRV 5000 65 NA 4 Morgan City 1 0 2 46’ FRV 5000 65 NA 4 Venice 1 0 1 Trinity SWS 21500 249 NA 4 Venice 1 2 2 

Enterprise Marine Services LLC (available through contract with CGA) 

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 

Staging Area: Venice

Nearshore and Inland 

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

Deplo

CGA 

SWS Egmopol 3000 100 NA 3 Morgan City 1 2 4.9 SWS Marco 3588 20 NA 3 Lake Charles 1 2 8 SWS Marco 3588 34 NA 3 Leeville 1 2 4.4 SWS Marco 3588 34 NA 3 Venice 1 2 0 
ATTACHMENT H-1 

Shoreline Protection 

Staging Area: Venice 

Shoreline Protection 

Boom VOO Persons Req. Storage/Warehouse Location Hrs to Procure Hrs to Loadout Travel to Staging Travel to Deployment Site 

AMPOL (available through MSA) 

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 6 2 20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2.2 2 

OMI Environmental (available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 6 2 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 12.1 2 10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 9.7 2 20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.9 2 10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 4.5 2 10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.8 2 15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2.1 2 

Wildlife Response EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Loadout Travel to Staging Trav

Deplo

CGA 

Wildlife Support Trailer NA NA NA 2 Harvey 1 2 2.1 Bird Scare Guns (48) NA NA NA 2 Harvey 1 2 2.1 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 12.7 Bird Scare Guns (12) NA NA NA 2 Aransas Pass 1 2 17.7 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 8 Bird Scare Guns (24) NA NA NA 2 Leeville 1 2 4.4 

Response Asset Total 

Offshore EDRC 258,477 

Offshore Recovered Oil Storage 270,483 

Nearshore / Shallow Water EDRC 45,264 

Nearshore / Shallow Water Recovered Oil Storage 60,567 
Deep 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 Transport 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 aircraft 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). 
ATTACHMENT L‐1

1000 lbs / well 

CaCI2 / CaBr2 / KCI / NaCI Below deck storage tanks on offshore support vessels

Newport 

Environmental 

Services, Inc., 

Ingleside Texas

1000 lbs / well 

Well Completion Fluids

Well Treatment Fluids

CaCI2 / CaBr2 / KCI / NaCI Below deck storage tanks on offshore support vessels

Newport 

Environmental 

Services, Inc., 

Ingleside Texas

Synthetic Based Cuttings Internal Olefin 

Below deck storage tanks on offshore support vessels

Newport 

Environmental 

Services Inc., 

Ingleside, TX

1000 bbls/well

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

SUPPORT VESSELS AND AIRCRAFT INFORMATION (30 CFR 250.224 & 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 Disposal

Type of Waste Composition Transport Method Name/Location of Facility Amount

NOTE: IF YOU WILL NOT HAVE A TYPE OF WASTE, ENTER “NA” IN THE ROW.

Synthetic Base Mud Internal Olefin Below deck storage tanks on offshore support vessels M-I Swaco Port Fourchon, La. 13500 bbls/well 

Will you have additional wastes that are not permitted for discharge?

Trash and debris

Used oil

Chemical product wastes

Wash water

Non-hazardous trash & debris 

(non-recyclables)

Transport in DOT containers on supply vessels to 

shorebase

Progressive Waste 

Solutions of LA, 

Houma, LA

700 lbs / well 

420 gal / well 

(10 bbls well)

N/A

130 lbs / well

Used oil and glycol

N/A

Paints, solvents, unused 

chemicals, etc.

Safety Kleen 

System, Baton 

Rouge, LA

N/A

Safety Kleen 

System, Baton 

Rouge, LA

Transport in DOT containers on supply vessels to 

shorebase

N/A

Transport in DOT containers on supply vessels to 

shorebase
Deep 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 Fourchon, Louisiana Existing 

M.2 SUPPORT BASE CONSTRUCTION OR EXPANSION 

There will be no new construction of an onshore support 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 timetable is not required for the activities 

proposed in this plan. 

M.4 WASTE DISPOSAL 

The Table, “Wastes You Will Transport 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 Consistency for the state of Alabama is 

included as Attachment N-1. 

A certificate of Coastal Zone Management Consistency for the state of Louisiana is not 

required for the operations proposed in this plan. 

A certificate of Coastal Zone Management Consistency for the 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 activities having potential impact on the 

Alabama Coastal Zone are based on the location of the proposed facilities, access to 

those sites, best practical technique for operations and production equipment, 

guidelines for the prevention of adverse environmental effects, effective environmental 

protection, emergency plans and contingency plans. Alabama policies have been 

addressed below or are cross referenced to the appropriate sections 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 improvements in Alabama’s 

coastal zone, nor will there be any employment effects. 

Mineral 

Resource 

Exploration 

and Extraction 

 Proposed exploration operations 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 Exploration Plan Control N9683 and N-9735 in order to identify and assess the 

seafloor and shallow 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 Analysis 
Deep 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 there 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 Programs and will be conducted in a manner consistent with 

such Programs. 

A certificate of Coastal Zone Management Consistency for the state 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, H2S 

releases) 

Discarded 

Trash & 

Debris 

Site-specific at Offshore 

Location 

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

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

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

Benthic communities (4) 

Water quality X X 

Fisheries X X 

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

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

Air quality X(9) 

Shipwreck sites (known or 

potential) 

 (7) 

Prehistoric archaeological sites 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 areas 
Footnotes for Environmental Impact Analysis Matrix 

1) Activities that may affect a marine sanctuary or topographic feature. Specifically, if the well or platform site or 

any anchors will be on the seafloor within the: 

o 4-mile zone of the Flower Garden Banks, or the 3-mile zone of Stetson Bank; 

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

Features Stipulation attached to an OCS lease; 

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

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

by the Topographic Features Stipulation attached to an OCS lease. 

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

Trend) Stipulation attached to an OCS lease. 

3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (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 hydrocarbons or diesel fuel that you 

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

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

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

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

blocks that will be affected that are adjacent to the lease block in which your planned activity will occur. If the 

proposed activities are located a sufficient distance from a shipwreck or a prehistoric site that no impact would 

occur, the EIA can note that in a sentence or two. 

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

sea turtles or their critical habitats. 

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

Site-Specific at Mississippi Canyon Block 215 

Proposed operations consist of drilling and completing 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 from the closest designated Topographic 

Features Stipulation Block (Sackett Bank); therefore, no adverse impacts are expected. 

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

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

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

into the water column; measurable amounts have been documented down to a 10 m depth. At 

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

amount shown to have an effect on corals. Because the crests of topographic features in the 

Northern Gulf of Mexico are found below 10 m, no oil from a surface spill could reach their 

sessile biota. Oil from a subsurface spill is not applicable due to the distance of these blocks from 

a topographic area. The activities proposed in this plan will be covered by Deep Gulf Energy II, 

LLC’s Regional OSRP (refer to information submitted in Section 8). 

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

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

2. Pinnacle Trend Area Live Bottoms 

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

Effluents: Mississippi Canyon Block 215 is 29 miles from the closest live bottom (pinnacle 

trend) area; therefore, no adverse impacts are expected. 

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

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

foul benthic communities and cause lethal and sublethal effects on live bottom organisms. Oil 

from a surface spill can be driven into the water column; measurable amounts have been 

documented down to a 10 m depth. At this depth, the oil is found only at concentrations several 
orders of magnitude lower than the amount shown to have an effect on marine organisms. Oil 

from a subsurface spill is not applicable due to the distance of these blocks from a live bottom 

(pinnacle trend) area. The activities proposed in this plan will be covered by Deep Gulf Energy 

II, LLC’s Regional OSRP (refer to information submitted in Section 8). 

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

sent to shore for disposal) from the proposed activities which could impact a live bottom 

(pinnacle trend) area. 

3. Eastern Gulf Live Bottoms 

Potential IPFs on Eastern Gulf live bottoms include effluents and accidents. 

Effluents: Mississippi Canyon Block 215 is not located in an area characterized by the 

existence of live bottoms; therefore, no adverse impacts are expected. 

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

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

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

into the water column; measurable amounts have been documented down to a 10 m depth. At 

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

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

applicable due to the distance of these blocks from a live bottom area. The activities proposed in 

this plan will be covered by Deep Gulf Energy II, LLC’s Regional OSRP (refer to information 

submitted in Section 8). 

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

sent to shore for disposal) from the proposed activities which could impact an Eastern Gulf live 

bottom area. 

4. Benthic Communities 

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

shore for disposal, or accidents) from the proposed activities that could cause impacts to benthic 

communities. 

A Dynamically Positioned Semisubmersible 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 

Semisubmersible Drilling Unit, Deep Gulf Energy II, LLC’s proposed operations in Mississippi 

Canyon Block 215 would not cause impacts to benthic communities. 
5. Water Quality 

IPFs that could result in water quality degradation from the proposed operations 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 and monitoring and toxicity testing are regulated by the EPA NPDES 

permit, thereby eliminating many significant biological or ecological effects. Operational 

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

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

that an accidental surface or subsurface spill would occur from the proposed activities. Between 

1980 and 2000, OCS operations produced 4.7 billion barrels of oil and spilled only 0.001 percent 

of this oil, or 1 bbl for every 81,000 bbl produced. The spill risk related to a diesel spill from 

drilling operations is even less. Between 1976 and 1985, (years for which data were collected), 

there were 80 reported diesel spills greater than one barrel associated with drilling activities. 

Considering that there were 11,944 wells drilled, this is a 0.7 percent probability of an 

occurrence. If a spill were to occur, the water quality of marine waters would be temporarily 

affected by the dissolved components and small oil droplets. Dispersion by currents and 

microbial degradation would remove the oil from the water column and dilute the constituents to 

background levels. Historically, changes in offshore water quality from oil spills have only been 

detected during the life of the spill and up to several months afterwards. Most of the components 

of oil are insoluble in water and therefore float. The activities proposed in this 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 (including emissions, physical disturbances to the seafloor, and wastes 

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

quality. 

6. Fisheries 

IPFs that could cause impacts to fisheries as a result of the proposed operations in 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 potential to cause some detrimental effects on 

fisheries; however, it is unlikely that such an event would occur from the proposed activities 
(refer to Item 5, Water Quality). The effects of oil on mobile adult finfish or shellfish would 

likely be sublethal and the extent of damage would be reduced to the capacity of adult fish and 

shellfish to avoid the spill, to metabolize hydrocarbons, and to excrete both metabolites and 

parent compounds. The activities proposed in this plan will be covered by Deep Gulf Energy II, 

LLC’s Regional OSRP (refer to information submitted in Section 8). 

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

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

7. Marine Mammals 

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

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

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

occurred most frequently along the upper slope in areas outside of anticyclones. IPFs that could 

cause impacts to marine mammals as a result of the proposed operations in Mississippi Canyon 

Block 215 include emissions, effluents, discarded trash and debris, and accidents. 

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

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

normal activities. Stress may make them more vulnerable to parasites, disease, environmental 

contaminants, and/or predation (Majors and Myrick, 1990). There is little conclusive evidence 

for long-term displacements and population trends for marine mammals relative to noise. 

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

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

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

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

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

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

marine debris, if any, resulting from the proposed activities is not expected to substantially harm 

marine mammals. Operators are prohibited from deliberately discharging debris as mandated by 

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

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

Environmental Protection Agency (EPA). 

Deep Gulf Energy II, LLC will operate in accordance with the regulations and also avoid 

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

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

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

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

environmentally persistent materials such as plastic or glass. 
Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from Deep Gulf Energy II, LLC management or the 

designated lease operator management that emphasizes their commitment to waste management 

in accordance with NTL No. 2012-G01. 

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

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

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

mammals and maintaining a safe distance when they are sighted. Vessel crews should use a 

reference guide to help identify the twenty-eight species of whales and dolphins, and the single 

species of manatee that may be encountered in the Gulf of Mexico OCS. Vessel crews must 

report sightings of any injured or dead protected marine mammal species immediately, 

regardless of whether the injury or death is caused by their vessel, to the Marine Mammal and 

Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional Office at (727) 

824-5312, or the Marine Mammal Stranding Network at (305) 862-2850. In addition, if the 

injury or death was caused by a collision with a contract vessel, the BOEM must be notified 

within 24 hours of the strike by email to protectedspecies@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 chemicals included in Deep Gulf Energy II, LLC’s 

OSRP is considered to be low when compared with the constituents and fractions of crude oils 

and diesel products. The activities proposed in this plan will be covered by Deep Gulf Energy II, 

LLC’s OSRP (refer to information submitted in accordance with Section 8). 

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

activities which could impact marine mammals. 

8. Sea Turtles 

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

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

loggerhead, Kemp’s ridley and leatherback sea turtles over shelf waters. Historically these 
species have been sighted up to the shelf’s edge. They appear to be more abundant east of the 

Mississippi River than they are west of the river (Fritts et al., 1983b; Lohoefener et al., 1990). 

Deep waters may be used by all species as a transitory habitat. 

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

reaction from sea turtles, but this is a temporary disturbance. 

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

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

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

ingestion in the food chain (API, 1989). 

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

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

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

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

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

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

(EPA). Deep Gulf Energy II, LLC will operate in accordance with the regulations and also avoid 

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

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

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

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

environmentally persistent materials such as plastic or glass. 

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

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from Deep Gulf Energy II, LLC management or the 

designated lease operator management that emphasizes their commitment to waste management 

in accordance with NTL No. 2012-G01. 

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

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

sea turtles and reduce potential deaths by maintaining a vigilant watch for sea turtles and 

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

help identify the five species of sea turtles that may be encountered in the Gulf of Mexico OCS. 

Vessel crews must report sightings of any injured or dead protected sea turtle species 

immediately, regardless of whether the injury or death is caused by their vessel, to the Marine 

Mammal and Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS Southeast Regional 
Office at (727) 824-5312, or the Marine Mammal Stranding Network at (305) 862-2850. In 

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

be notified within 24 hours of the strike by email to protectedspecies@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 vulnerable to the harmful effects of oil through 

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

and hatchlings. However, it is unlikely that an accidental oil spill would occur from the proposed 

activities (refer to Item 5, Water Quality). Oil spill response activities may increase vessel traffic 

in the area, which could add to the possibility of collisions with sea turtles. The activities 

proposed in this plan will be covered by Deep Gulf Energy II, LLC’s Regional Oil Spill 

Response Plan (refer to information submitted in accordance with Section 8). 

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

activities which could impact sea turtles. 

9. Air Quality 

Mississippi Canyon Block 215 is located 83.5 miles from the Breton 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 the proposed activities do not exceed the annual 

exemption levels as set forth by BOEM. Accidents and blowouts can release hydrocarbons or 

chemicals, which could cause the emission of air pollutants. However, these releases would not 

impact onshore air quality because of the prevailing atmospheric conditions, 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 seafloor, 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 result of the proposed 

operations in Mississippi Canyon Block 215 include 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 Semisubmersible Drilling Unit, Deep Gulf Energy II, LLC’s proposed 

operations in Mississippi Canyon Block 215 would not cause impacts to shipwreck sites. 
Additionally, Mississippi Canyon Block 215 is not located in or adjacent to an OCS block 

designated by BOEM as having a high probability for occurrence of shipwrecks, therefore, no 

adverse impacts are expected. 

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. 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. 

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

disposal, or accidents) from the proposed activities that could cause impacts to shipwreck sites. 

11. Prehistoric Archaeological Sites 

IPFs that could cause impacts to prehistoric archaeological sites as a result of the proposed 

operations in Mississippi Canyon Block 215 are physical disturbances to the seafloor and 

accidents (oil spills). 

Physical Disturbances to the seafloor: Although the operations proposed will be conducted by 

utilizing a Dynamically Positioned Semisubmersible Drilling Unit, which would cause only an 

insignificant amount of seafloor to be disturbed, Mississippi Canyon Block 215 is located inside 

the Archaeological Prehistoric high probability lines. Deep Gulf Energy II, LLC will report to 

BOEM the discovery of any object of prehistoric archaeological significance and make every 

reasonable effort to preserve and protect that cultural resource. 

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 potential 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 Gulf Energy II, LLC’s Regional Oil 

Spill Response Plan (refer to information submitted in accordance with Section 8). 
There are no other IPFs (including emissions, effluents or wastes sent to shore for treatment or 

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

Vicinity of Offshore Location 

1. Essential Fish Habitat (EFH) 

IPFs that could cause impacts to EFH as a result of the proposed operations in Mississippi 

Canyon Block 215 include effluents and accidents. EFH includes all estuarine and marine waters 

and substrates in the Gulf of Mexico. 

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

Stipulation, and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential 

impacts on live-bottom communities and EFH from operational waste discharges. Levels of 

contaminants in drilling muds and cuttings and produced-water discharges, discharge-rate 

restrictions, and monitoring and toxicity testing are regulated by the EPA NPDES permit, 

thereby eliminating many significant biological or ecological effects. Operational discharges are 

not expected to cause significant adverse impacts to EFH. 

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

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

larvae are present, have the greatest potential to affect fisheries. However, it is unlikely that an 

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

proposed in this plan will be covered by Deep Gulf Energy II, LLC’s Regional OSRP (refer to 

information submitted in Section 8). 

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

sent to shore for treatment or disposal) from the proposed activities which could impact essential 

fish habitat. 

2. Marine and Pelagic Birds 

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

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

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

concentrations which could harm coastal and marine birds. 

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

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

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

nonfatal, physiological stress. It is expected that few, if any, coastal and marine birds would 
actually be affected to that extent. The activities proposed in this plan will be covered by 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 ingest small plastic debris, which can cause permanent injuries and 

death. Operators are prohibited from deliberately discharging debris as mandated by MARPOLAnnex V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by 

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

Protection Agency (EPA). Deep Gulf Energy II, LLC will operate in accordance with the 

regulations and also avoid accidental loss of solid waste items by maintaining waste management 

plans, manifesting trash sent to shore, and using special precautions such as covering outside 

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

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

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

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

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

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

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

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

explanation from Deep Gulf Energy II, LLC management or the designated lease operator 

management that emphasizes their commitment to waste management in accordance with NTL 

No. 2012-G01. Debris, if any, from these proposed activities will seldom interact with marine 

and pelagic birds; therefore, the effects will be negligible. 

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

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

pelagic birds. 

3. Public Health and Safety Due to Accidents. 

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

shore for treatment or disposal or accidents, including an accidental H2S release) from the 

proposed activities which could cause impacts to public health and safety. In accordance with 

NTL No.’s 2008-G04, 2009-G27, and 2009-G31, sufficient information is included in Section 4

to justify our request that our proposed activities be classified by BSEE as H2S absent. 

Coastal and Onshore 

1. Beaches 

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

spills) and discarded trash and debris. 
Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches 

and associated resources. Due to the distance from shore (64.5 miles) and the response 

capabilities that would be implemented, no significant adverse impacts are expected. The 

activities proposed in this plan will be covered by Deep Gulf Energy II, LLC’s Regional OSRP 

(refer to information submitted in Section 8). 

Discarded trash and debris: Trash on the beach is recognized as a major threat to the 

enjoyment and use of beaches. There will only be a limited amount of marine debris, if any, 

resulting from the proposed activities. Operators are prohibited from deliberately discharging 

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

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

Guard (USCG) and the Environmental Protection Agency (EPA). Deep Gulf Energy II, LLC will 

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

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

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

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

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

plastic or glass. 

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

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from Deep Gulf Energy II, LLC management or the 

designated lease operator management that emphasizes their commitment to waste management 

in accordance with NTL No. 2012-G01. 

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

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

2. Wetlands 

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

spills) and discarded trash and debris. 

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

5, Water Quality). Due to the distance from shore (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 Regional OSRP (refer to information submitted in 

Section 8). 
Discarded trash and debris: There will only be a limited amount of marine debris, if any, 

resulting from the proposed activities. Operators are prohibited from deliberately discharging 

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

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

Guard (USCG) and the Environmental Protection Agency (EPA). Deep Gulf Energy II, LLC will 

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

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

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

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

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

plastic or glass. 

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

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from Deep Gulf Energy II, LLC management or the 

designated lease operator management that emphasizes their commitment to waste management 

in accordance with NTL No. 2012-G01. 

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

sent to shore for treatment or disposal) from the proposed activities which could impact 

wetlands. 

3. Shore Birds and Coastal Nesting Birds 

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

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

Quality). Given the distance from shore (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 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 mandated by MARPOL-Annex V and the Marine Plastic 

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

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

Gulf Energy II, LLC will operate in accordance with the regulations and also avoid accidental 

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

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

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

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

persistent materials such as plastic or glass. 
 

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

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from Deep Gulf Energy II, LLC management or the 

designated lease operator management that emphasizes their commitment to waste management 

in accordance with NTL No. 2012-G01. 

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

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

shore birds and coastal nesting birds. 

4. Coastal Wildlife Refuges 

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

wildlife refuges. However, it is unlikely that an oil spill would occur from the proposed activities 

(refer to Item 5, Water Quality). Due to the distance from shore (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 Regional OSRP (refer to information 

submitted in Section 8). 

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

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

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

the Environmental Protection Agency (EPA). Deep Gulf Energy II, LLC will operate in 

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

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

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

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

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

plastic or glass. 

 

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

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from Deep Gulf Energy II, LLC management or the 

designated lease operator management that emphasizes their commitment to waste management 

in accordance with NTL No. 2012-G01. 
There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes 

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

coastal wildlife refuges. 

5. Wilderness Areas 

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

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

Item 5, Water Quality). Due to the distance from the nearest designated Wilderness Area (83.5 

miles) and the response capabilities that would be implemented, no significant adverse impacts 

are expected. The activities proposed in this plan will be covered by Deep Gulf Energy II, 

LLC’s Regional OSRP (refer to information submitted in Section 8).

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

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

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

the Environmental Protection Agency (EPA). Deep Gulf Energy II, LLC will operate in 

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

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

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

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

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

plastic or glass. 

 

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

preparation capabilities. All offshore personnel, including contractors and other support 

services-related personnel (e.g. helicopter pilots, vessel captains and boat crews) will be 

indoctrinated on waste procedures, and will view the video (or Microsoft PowerPoint 

presentation), “Think About It” (previously “All Washed Up: The Beach Litter Problem”). 

Thereafter, all personnel will view the marine trash and debris training video annually. Offshore 

personnel will also receive an explanation from Deep Gulf Energy II, LLC management or the 

designated lease operator management that emphasizes their commitment to waste management 

in accordance with NTL No. 2012-G01. 

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

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

wilderness areas. 

6. Other Environmental Resources Identified 

There are no other environmental resources identified for this impact assessment. 
(C) IMPACTS ON PROPOSED ACTIVITIES 

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

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

conditions. 

(D) ENVIRONMENTAL HAZARDS 

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

average of ten tropical storms (39-73 mph winds), of which six become hurricanes ( > 74 mph 

winds). Due to its location in the gulf, Mississippi Canyon Block 215 may experience hurricane 

and tropical storm force winds, and related sea currents. These factors can adversely impact the 

integrity of the operations covered by this plan. A significant storm may present physical hazards 

to operators and vessels, damage exploration or production equipment, or result in the release of 

hazardous materials (including hydrocarbons). Additionally, the displacement of equipment may 

disrupt the local benthic habitat and pose a threat to local species. 

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

impacts: 

1. Drilling & completion 

a. Secure well 

b. Secure rig / platform 

c. Evacuate personnel 

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

2010-N10. 

2. Structure Installation 

 Operator will not conduct structure installation operations during Tropical Storm or 

 Hurricane threat. 

 (E) ALTERNATIVES 

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

(F) MITIGATION MEASURES 

No mitigation measures other than those required by regulation will be employed to avoid, 

diminish, or eliminate potential impacts on environmental resources. 

(G) CONSULTATION 

No agencies or persons were consulted regarding potential impacts associated with the proposed 

activities. Therefore, a list of such entities has not been provided. 
(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. Effects of offshore petroleum operations on cold 

water marine mammals: a literature review. Washington, DC: American Petroleum 

Institute. 385 pp. 

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

Shomura, R.S. and H.O. Yoshida, eds. Proceedings, Workshop on the Fate and Impact of 

Marine Debris, 26-29 November 1984, Honolulu, HI. U.S. Dept. of Commerce. NOAA 

Tech. Memo. NOAA-TM-NMFS-SWFC-54. Pp 387-429. 

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

drilling muds. Environmental Assessment Division, Argonne National Laboratory, 

ANL/EAD/TM-43. 

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

cuttings in waters of the United States. U.S. Environmental Protection Agency, Office of 

Water. Work Plan, June 24, 1997. 

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

Dept. of the Interior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLMYK-ES-81-006-1792. 

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

including a comprehensive list of species with entanglement and ingestion records. In: Coe, 

J.M. and D.B. Rogers, eds. Marine debris: sources, impacts, and solutions. New York, NY: 

Springer-Verlag. Pp. 99-139. 

Majors, A.P. and A.C. Myrick, Jr. 1990. Effects of noise on animals: implications for dolphins 

exposed to seal bombs in the eastern tropical Pacific purse-seine fishery–an annotated 

bibliography. NOAA Administrative Report LJ-90-06. 

Marine Mammal Commission. 1999. Annual report to Congress – 1998. 
Piatt, J.F., C.J. Lensink, W. Butler, M. Kendziorek, and D.R. Nysewander. 1990. Immediate 

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

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

pollution at the German North Sea coast. Topics in Marine Biology. Ros, J.D, ed. Scient. 

Mar. 53 (2-3): 749-754. 

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

Field-Naturalist. 89:278-298. 

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

• Hazard Surveys 

• BOEM EIS’s: 

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

001 

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 Plan (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 Clearance Letter, Proposed Wellsite MC 215-

C, Block 215, Mississippi Canyon Area (OCS-G-24060), 1 August 2014, Report 

No. 27.1401-2756”.