UNITED STATES GOVERNMENT MEMORANDUM

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

Public Information copy of DOCD
Control # - S-07464
Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS-G26664 Block - 506 Garden Banks Area
Operator - Deep Gulf Energy LP

Subsea Well E

SEMISUBMERSIBLE

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

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

Michelle Griffitt Plan Coordinator

G26664/GB/506 7275 FSL, 7433 FWL G26664/GB/506 WELL/E Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk Site Type/Name Description -
Rig Type - Subject: From: June 9, 2011

## PUBLIC INFORMATION January 25, 2011 Amended May 12 , 2011



## SUPPLEMENTAL DEVELOPMENT OPERATIONS

COORDINATION DOCUMENT

Lease Number(s): OCS

- G 26664 Area/Block: Garden Banks 506 Prospect Name: Kathleen Offshore: Louisiana

Submitted by: Deep Gulf Energy LP 7 38 Highway 6 South Suite 350 Houston, Texas 77079

Bill Fisher (281) 596

- 0933 bfisher@deepgulfenergy.com

Estimated start up date: June 30, 2011

Authorized Representative: No. Copies Being Submitt ed: Jodie Connor Proprietary: 1 HC + 1CD J. Connor Consulting, Inc. Public Info: 1 HC + 1CD 16225 Park Ten Place, Suite 700 Houston, Texas 77084 For MMS: (281) 578

- 3388 Plan No. S

- 7464 jodie.connor@jccteam.com Assigned to: Mimi Griffit t

Record Ch ange Date Section Page Revision 01

- 25

- 2011 Entire Plan All Initial Submittal
02

- 21

- 2011 A All Diagram of subsea tree, and installation method.

G All Plans for treating, storing or downhole disposal of
wastes. H All Amend drilling days in the AQR

03

- 01

- 2011 I All Attachment I

- 1 Worst Case Discharge Information, Well Test Data, Nodal Analysis 03

- 10

- 2011 I All Attachment I

- 1 Additional Nodal Analysis Data04

- 21

- 2011 Entire Plan All

04

- 27

- 2011 Entire Plan All

05

- 03

- 2011 Cover Page All Record Chang e
05

- 12

- 2011 Cover Page All Revise Estimated Start Up Date and Record Change

A Attachment A

- 1 Revise Activity Schedule

I Page I

- 1 Revise Oil Spill Response Planning

– Plan dates

B Attachment B

- 2 Revise Blowout Scenario amending Worst Case Discharge barrels of oil per day.U.S. Department of the Interior OMB Control Number: 1010-0151 Minerals Management Service OMB Approval Expires: July 31, 2008 

### OCS PLAN INFO RMATION FORM
GENERAL INFORMATION Type of OCS Plan: Exploration Plan (EP) X Deve lopment Operations Coordination Document (DOCD) Company Name: Deep Gulf Energy LP MMS Operator Number: 02815 Address: 738 Highway 6 South Contact Person: Jodie Connor
Suite 350 Phone Number: 281-578-3388 Houston, Texas 77079 Email Address: Jodie.connor@jccteam.com
Lease(s): OCS-G 26664 Area: Garden Banks Block(s) : 506 Project Name (If Applicable): Kathleen
Objective(s): Oil Gas Sulphur Salt Onshore Base: Fourchon, LA Distance to Closest Land (Miles): 149 Description of Proposed Activities (Mark all that apply) Exploration drilling Development drilling Well completion Installation of production platform Well test flaring (for more than 48 hours) Installation of production facilities Installation of caisson or platform as well protection structure Installation of satellite structure
Installation of subsea wellheads and/or manifolds Commence production Installation of lease term pipelines Other (Specify and describe) Have you submitted or do you plan to submit a Conservation Information Document to accompany this plan? X Yes No Do you propose to use new or unusual technology to conduct your activities? Yes X No Do you propose any facility that will serve as a host facility for deepwater subsea development? Yes X No Do you propose any activities that may disturb an MMS-designated high-probability archaeological area? Yes X No Have all of the surface locations of your proposed activ ities been previously reviewed and approved by MMS? Yes X No Tentative Schedule of Proposed Activities

Proposed Activity Start Date End Date No. of Days

Drill Well Location E 06/30/11 08/10/11 41
Test Well Location E 08/11/11 08/30/11 19 Install Lease Term Pipeline 08/31/11 09/7/11 7
Commence Production from Well Location E 09/07/11 Description of Drilling Rig Description of Production Platform Jackup Drillship Caisson Tension leg platform Gorilla Jackup Platform rig Well protector Compliant tower
Semisubmersible Submersible Fixed platform Guyed tower
DP Semisubmersible Other (Attach Description) Subsea manifold Floating production system Drilling Rig Name (If Known): Spar Other (Attach description) Description of Lease Term Pipelines From (Facility/Area/Block) To (Facility/Area /Block) Diameter (inches) Length (Feet) Garden Banks 506, Subsea Well E Ga rden Banks 506, #2 PLET 6.625 100 MMS Form MMS-137 (July 2005 – Supersedes all previous editions of form MMS-137, which may not be used.) 

## Attachment A-1Attachment B-2 

## GB 506 #4 Drilling Blowout Scenario

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

No drill pipe is in the wellbore.

Estimated Theoretical Uncontrolled Flow Rate The “theoretical” uncontr olled flow rate is 68,000 BOPD, 162,000 MCFD, and 0 BWPD

. Seismic interpretation indicates the target reservoir is they only producible reservoir in the open hole section. No water sands or other hydrocar bon bearing sands are anticipated in the hole section.

Duration of Uncontrolled Flow – Base Case The duration of uncontrolled flow during the blow out scenario is 4 days. This assumes the BOP’s can be closed with an ROV at the subsea ROV panel on the BOP . This assumes the initial site assessment in dicates an ROV vessel can operate clos e enough to the well to remotely close the BOP.

Duration of Uncontrolled Flow – Contingency Case A contingency plan is in place if the ROV is unsuccessful closing the BOP’s. The duration of uncontrolled flow in the contingency case is 15 days. The contingency case assumes the Helix Fast Response System will be utilized to shut-i n and contain the well. Deep Gulf Energy is a member of the Clean Gulf Associates / Helix Fa st Response Consortium, and is guaranteed this equipment in the event of a blow out.

Estimated Total Volume (barrels)(flow rate x duration) – based on original Submittal

Estimated Flow Rate – Crude (BBLS) 68,000 Base Case

4 days 272,000
Contingency Case 15 days 1,020,000

Relief Well

55 days 3,740,000Estimated Total Volume (barrels)(flow rate x duration) – amended to address the higher number generated by BOEMRE’s analysis of WCD potential

Estimated Flow Rate – Crude (BBLS) 127,878 Base Case

4 days 511,512
Contingency Case 15 days 1,918,170

Relief Well

55 days 7,033,290

Early Intervention In the Event of a Blowout Deep Gulf Energy will immediately initiate and mobilize the Helix Fast Response System equipment outlined in the attached “Well Cont ainment Plan”. Equipment mobilized includes vessels to remotely close the blind shear rams, ve ssels to begin subsea di spersant operations, and vessels to initiate debris removal / salv age operations. The Helix Q-4000 will also be immediately mobilized to assist in the respons e. In the event the bl ind shear ram cannot be remotely closed with the ROV, the LMRP w ill be removed from the BOP, and the Helix “WellCap” will be installed on th e BOP. The blind rams in the We llCap would then be closed to contain the well.

A top kill operation would then be initiated to kill and control the well. The proposed 13-5/8” 88.2# HCQ-125 casing in the proposed well design can w ithstand the anticipated shut in pressure at the BOP, as well as additional pressure exer ted on the casing during the top kill operation. The estimated shut in pressure of the well at the BOP is 6,032 psi, and the burst rating of the 13-5/8” casing is 10,030 psi. In addition, Deep Gulf En ergy would employ the expertise of Boots and Coots International Well Control Inc., to a ssist with any early intervention options.

Availability of Rig to Begin Drilling Relief Well The estimated time to begin drilling a relief well is 2 weeks. This assumes the rig is operating on another project for another operator. The two week window to receive the rig is based on contacting the operator (if require d, a suitable rig may be ava ilable immediately), giving them adequate time to temporarily abandon their well, and adequate time to mobilize wellhead equipment and large diameter tubulars to the relief well location. Initiation of relief well operations would be gin immediately.

Arrangements for Drilling Relief Wells In the event Deep Gulf Energy requires a rig to drill a relief well, we have arrangements with major drilling contractors (Transocean, Diamond O ffshore, etc.) to suppl y Deep Gulf Energy with a rig suitable to drill a relief well.

Relief Well Rig Package ConstraintsNo rig package constraints are anticipated for the rig which would drill the relief well. All 3 rd

, 4 th , and 5 th generation rigs in the Gulf of Mexico w ould be suitable to drill the relief well. Hook loads are minimal, and 10,000 psi BOP’s are required.

Estimated Time to Drill a Relief Well The estimated time to drill a relief well is 55 days. The estimated time to drill the proposed exploration well is 41 days. An additional 14 days is required to drill the relief well due to the critical nature of the directional wo rk to intercept th e uncontrolled well.

Drilling a Relief Well from a Nearby Platform No platforms are close enough to the proposed exploration well to drill a relief well.

Potential of Open Hole to “Bridge Over” Due to the slight geopressured na ture of the reservoir, the age of the reservoir, and the depth below the mud line where the reservoir exists, it is highly likely that th e sandstone is somewhat unconsolidated and friable. Cons iderable sand production is anti cipated. It is reasonable to assume that the sandstones and shale intervals in the open hole will experience tensile failure and will collapse. However, determining if the open hole will “bridge over” is difficult if not impossible to model and predict. However, it is likely safe to assume that the sand and shale sequences will experience tensile failure if 6,000 psi drawdown is achieved.

Likelihood for Surface Intervention to Stop Blowout Because the proposed MODU to drill the well is a floating rig with the blowout preventor on the seafloor, the likelihood of a surface intervention to stop the blowout is mi nimal. However, if the rig is still attached to the well and is not on fi re, a well control contractor would be employed to man the rig and attempt to shut in the well.

The best option to stop the blowout is to cl ose the blind/shear ram remotely using an ROV vessel. If that is unsuccessful, the best option to stop the blowout is to disconnect the LMRP from the BOP and install the Helix “WellCap” on top of the BOP. The Helix Q-4000 would be the vessel of choice to perform this work. The Helix “fast response” system would be employed to install their 13-5/8” BOP in open water us ing the Q-4000 360 ton crane. Once the well is capped, a “top kill” operation would be performe d by bullheading into the well. Deep Gulf Energy is a member of the Helix “Fast Response” consortium.

### APPENDIX I OIL SPILLS INFORMATION

(A) OIL SPILL RESPONSE PLANNING Deep Gulf Energy LP’s (MMS Operator Nu mber 02815) Regional Oil Spill Response Plan (OSRP) was approved on September 8, 2009. The next biennial updat e is due May 31, 2012. The latest revision to the OSRP was submitted April 28, 2011 and is pending approval. The activities proposed in this DOCD will be cove red by the Regional OSRP in accordance with 30 CFR 254. OSRP Certification and vendor ve rification documents were submitted April 27, 2011. A copy is included in this Section as Attachment I-1.

(B) SPILL RESPONSE SITES Primary Response Equipment Locati on Preplanned Staging Locations Houma, LA Houma and Cameron, LA

(C) OSRO INFORMATION Deep Gulf’s primary equipment provider is Clea n Gulf Associates (CGA). The Marine Spill Response Corporation’s (MSRC) STARS network will provide cl osest available personnel, as well as an MSRC supervisor to operate the equipment.

(D) WORST-CASE DISCHARGE (WCD ) SCENARIO DETERMINATION

Category Drilling Pro duction

Regional OSRP WCD DOCD WCD Regional OSRP WCD DOCD WCD

Type of Activity Drilling Drilling >10 mile Production >10 mile Production Facility Location (Area/Block) GB 506 GB 506 GC 448 GB 506

Facility Designation Well E Well E SS001 Well E

Distance to Nearest Shoreline (miles) 149 149 113 149

Volume Storage tanks & flowlines (total) Lease term pipelines (total) Uncontrolled blowout Total Volume (bbls) 68,000 68,000 127,878 127,878 14,600 14,600 127,878 127,878 Type of Oil(s) (crude, condensate, diesel) Crude Crude Crude Crude

API Gravity 40.6 40.6 30.8° 40.6°
Deep Gulf Energy LP Supplemental DOCD GB 506 OCS-G 26664 I-1