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

WELL/E G26664/GB/506 7275 FSL, 7433 FWL G26664/GB/506

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

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

738 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 Submitted:

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 Griffitt

Record Change

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 Data
04-21-2011 Entire Plan All

04-27-2011 Entire Plan All

05-03-2011 Cover Page All Record Change

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 INFORMATION FORM 

GENERAL INFORMATION 

Type of OCS Plan: Exploration Plan (EP) X Development 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 activities 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 Garden 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-1























































































Attachment 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” uncontrolled 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 hydrocarbon bearing sands are anticipated in the hole 

section. 

Duration of Uncontrolled Flow – Base Case

The duration of uncontrolled flow during the blow out scenario is 4 days. 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 indicates an ROV vessel can operate close 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-in and contain the well. Deep Gulf Energy is a 

member of the Clean Gulf Associates / Helix Fast 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 3,740,000 
Estimated 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 Containment Plan”. Equipment mobilized includes 

vessels to remotely close the blind shear rams, vessels to begin subsea dispersant operations, and 

vessels to initiate debris removal / salvage operations. The Helix Q-4000 will also be 

immediately mobilized to assist in the response. In the event the blind shear ram cannot be 

remotely closed with the ROV, the LMRP will be removed from the BOP, and the Helix 

“WellCap” will be installed on the BOP. The blind rams in the WellCap 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 withstand the anticipated shut in pressure 

at the BOP, as well as additional pressure exerted on the casing during the top kill operation. The 

estimated shut in pressure of the well at the BOP is 6,032 psi, and the burst rating of the 13-5/8” 

casing is 10,030 psi. In addition, Deep Gulf Energy would employ the expertise of Boots and 

Coots International Well Control Inc., to assist 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 required, a suitable rig may be available 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 begin 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 Offshore, etc.) to supply Deep Gulf Energy 

with a rig suitable to drill a relief well. 

Relief Well Rig Package Constraints
No rig package constraints are anticipated for the rig which would drill the relief well. All 3rd, 

4th, and 5th generation rigs in the Gulf of Mexico would 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 work to intercept the 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 nature of the reservoir, the age of the reservoir, and the depth 

below the mud line where the reservoir exists, it is highly likely that the sandstone is somewhat 

unconsolidated and friable. Considerable sand production is anticipated. 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 minimal. However, if the 

rig is still attached to the well and is not on fire, 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 close 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 using the Q-4000 360 ton crane. Once the well is 

capped, a “top kill” operation would be performed 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 Number 02815) Regional Oil Spill Response Plan 

(OSRP) was approved on September 8, 2009. The next biennial update 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 covered by the Regional OSRP in accordance with 

30 CFR 254. OSRP Certification and vendor verification documents were submitted April 27, 

2011. A copy is included in this Section as Attachment I-1. 

(B) SPILL RESPONSE SITES 

Primary Response Equipment Location Preplanned Staging Locations 

Houma, LA Houma and Cameron, LA 

(C) OSRO INFORMATION 

Deep Gulf’s primary equipment provider is Clean Gulf Associates (CGA). The Marine Spill 

Response Corporation’s (MSRC) STARS network will provide closest 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