PUBLIC COPY 

RECORD OF CHANGES

Operator: Apache Deepwater LLC 

Lease: OCS-G 34468 

Area/Block: Mississippi Canyon 983 

Plan Type: Initial Exploration Plan 

Plan Control No.: N-9678 

Complete Copy Submitted: April 23, 2013 

BOEM Coordinator: Tonya Jez 

Date Appendix Page/Attachment Revision 

1/3/13 A BOEM-0137 Revised Location B 

 B B-4 Advised BOEM to refer to this section 

for the statement “whether the 

possibility of using a nearby platform 

was considered. 

 E E-1 Refer to Section C, Attachment C-4 for 

the Site Clearance Letters for the 

locations for 

 G All Advise if the spreadsheets are feasible. 

 H All Attach the nodal analysis files. Provide 

the WCD once it has been verified. 

 K Update NTL 

1/4/13 G Attachment Attach the calculation spreadsheets 

 K All Update all NTLs in this section 

2/5/13 A BOEM-0137 Revise the Anchor radius 

 C C-4 Revise anchor radius on the Site 

Clearance Letters 

2/12/13 F & L F-1 & L-1 Revise the Waste & Discharge tables 

with the ones provided on the BOEM 

website. Revise the data to reflect. 

2/20/13 F & L F-1 & L-1 Revise the Waste & Discharge tables to 

be in compliance with BOEM 

3/18/13 H H-1 OSRP Approval 4/18/13 

 
INITIAL EXPLORATION PLAN 

PUBLIC COPY 

April 23, 2013 

Area/Block: Mississippi Canyon Block 983 

Lease Number(s): OCS-G 34468 

Prospect Name: San Marcos 

Offshore: Louisiana 

Prepared By: 

Ms. Terri Young 

Apache Deepwater LLC 

2000 W. Sam Houston Pkwy. S., Suite 1600 

Houston, Texas 77042 

(713) 296-7456 

Terri.young@apachecorp.com

Plan No.: N-9678 

Assigned to: Tonya Jez 

Date of Submittal: April 23, 2013 

Estimated Start-up Date: August 17, 2013 
INITIAL EXPLORATION PLAN DOCUMENT 

LEASE OCS-G 34468 

MISSISSIPPI CANYON BLOCK 983 

TABLE OF CONTENTS 

SECTION A Plan Contents

SECTION B General Information

SECTION C Geological, Geophysical Information

SECTION D H2S Information

SECTION E Biological, Physical and Socioeconomic Information

SECTION F Wastes and Discharge Information

SECTION G Air Emissions Information

SECTION H Oil Spills Information

SECTION I Environmental Monitoring Information

SECTION J Lease Stipulations Information

SECTION K Environmental Mitigation Measures Information

SECTION L Support Vessels and Aircraft Information

SECTION M Onshore Support Facilities Information

SECTION N Coastal Zone Management Act (CZMA) Information

SECTION O Environmental Impact Analysis

SECTION P Administrative Information
LIST OF ATTACHMENTS 

A-1 OCS Plan Information Form 

A-2 Well Location Plat 

A-3 Bathymetry Map 

A-4 Pay.Gov Receipt 

C-4 Shallow Hazard Assessment 

F-1 Projected Generated Wastes 

H-1 Spill Response Discussion for NEPA Analysis 

L-1 Solid and Liquid Waste Transportation 

L-2 Vicinity Map 

N-1 Coastal Zone Management Consistency Certification 

O-1 Environmental Impact Analysis 
Apache Deepwater LLC	 	 Page A‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION A 

PLAN CONTENTS 

(30 CFR 550.211 and 550.241) 

A. PLAN INFORMATION FORM

Apache Deepwater LLC submits this Exploration Plan to propose the drill and completion of 

three (3) well locations, Mississippi Canyon Block 983. Tentative schedules from start to finish 

of the drilling and completion activities and information regarding the proposed locations are 

included on the OCS Plan Information Form BOEM-0137, included as Attachment A-1.

B. LOCATION 

A Well Location Map depicting the proposed surface locations for the proposed wells is included 

as Attachment A-2. A Bathymetry Map showing the water depths across the lease block is 

included as Attachment A-3. These attachments are in accordance with the Notice to Lessees 

(NTL) 2008-G04. 

C. SAFETY AND POLLUTION PREVENTION FEATURES 

A description of the drilling unit is included on the OCS Plan Information Form. Rig 

specifications will be made part of each Application for Permit to Drill (APD). 

Safety features on the drilling unit will include well control, pollution prevention and blowout 

prevention equipment as described in Title 30 CFR Part 550, Subparts C, D, E and F; and as 

further clarified by BOEM Notices to Lessees and current policy making invoked by the BOEM 

Environmental Protection Agency and the U.S. Coast Guard. 

Appropriate life rafts, life jackets, ring buoys, etc., will be maintained on the facility at all times 

as mandated by the U.S. Coast Guard regulations contained in Title 33 CFR. 

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

drilling deck areas to collect all contaminants and debris. 
Apache Deepwater LLC	 	 Page A‐2

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

D. STORAGE TANKS AND/OR PRODUCTION VESSELS 

The Mississippi Canyon Block 983 wells will be drilled with a Semisubmersible or DP 

Semisubmersible unit. All facility tanks of 25 barrels or more. 

Type of 

Storage Tank 

Type of 

Facility (Rig) 

Tank 

Capacity 

(bbls) 

Number 

of 

Tanks 

Total 

Capacity 

(bbls) 

Fluid 

Gravity 

(APIDegree) 

Fuel Oil (Marine Diesel) Semisubmersible 104.7 1 104.7 35o

Fuel Oil Day Semisubmersible 97.6 1 97.6 35o

Emergency Generator Semisubmersible 5.5 1 5.5 35o

Forward Hull – Fuel Oil Semisubmersible 3416 1 3416 35o

Lower AFT Hull – Fuel Oil Semisubmersible 3416 1 3416 35o

Lube Oil Services Semisubmersible 61.3 7 429.1 26o

Dirty Lube Oil Semisubmersible 30.1 1 30.1 26o

Dirty Bilge Semisubmersible N/A N/A N/A N/A 

Fuel Oil (Marine Diesel) DP Semisubmersible 164 1 164 35o

Fuel Oil Day DP Semisubmersible 262 1 262 35o

Emergency Generator DP Semisubmersible 30.76 1 30.76 35o

Forward Hull – Fuel Oil DP Semisubmersible 4540.9 2 9081.8 35o

Lower AFT Hull – Fuel Oil DP Semisubmersible 6790 2 13,580 35o

Lube Oil Services DP Semisubmersible 115 1 115 26o

Dirty Lube Oil DP Semisubmersible 38/28 2 66 26o

Dirty Bilge DP Semisubmersible 30.7 4 123 N/A 

E. ADDITIONAL MEASURES 

Apache Deepwater does not propose additional safety, pollution prevention or early spill 

detection measures beyond those required by 30 CFR 550. 

F. COST RECOVERY FEE 

A Pay.Gov receipt in the amount of $10,326.00 for the cost recover fees associated with this plan 

is included as Attachment A-4.




983

15

984

16

MISSISSIPPI CANYON

ATWATER VALLEY

Surface

Location Map

10/22/12 1" = 4000'

APACHE DEEPWATER, LLC

“San Marcos” Prospect

Mississippi Canyon 983

OCS-G 34468 

X = 918,720.00'

Y = 10,169,280.00'

Y = 10,153,440.00'

Y = 10,137,600.00'

X = 934,560.00'

X = 950,400.00'

Shell

#1ST2

APC

#1

APC

#1 BP2 APC

#1 BP1

Apache Loc. MC 983 B

Surface Location

Apache Loc. MC 983 C

Surface Location

2,766’ FSL & 3,351’ FEL of MC 983

X = 931,209'

Y = 10,156,206'

Lat. = 27.9696868

 27 58'10.872"

Long. = -89.1975888

 -89 11'51.320"

2,107’ FSL & 5,056’ FEL of MC 983

X = 929,504'

Y = 10,155,547'

Lat. = 27.9677903

 27 58'04.045"

Long. = -89.2028320

 -89 12'10.195"

3,351' FEL (B)

5,056' FEL (C)

Prop.

Loc. B Prop.

Loc. C Prop.

Loc. A

2,107'

FSL (C)

2,766'

FSL (B)

SL

SL

SL

Apache Loc. MC 983 A

Surface Location

1,590’ FSL & 1,360’ FEL of MC 983

X = 933,200'

Y = 10,155,030'

Lat. = 27.9665516

 27 57'59.586"

Long. = -89.1913577

 -89 11'28.888"

1,360' FEL (A)

1,590'

FSL (A)
983

15

984

16

MISSISSIPPI CANYON

ATWATER VALLEY

Bathymetry Plat

1" = 4000'

APACHE DEEPWATER, LLC

“San Marcos” Prospect

Mississippi Canyon 983

OCS-G 34468 

X = 918,720.00'

Y = 10,169,280.00'

Y = 10,153,440.00'

Y = 10,137,600.00'

X = 934,560.00'

X = 950,400.00'

Shell

#1ST2

APC

#1

APC

#1 BP2 APC

#1 BP1

Prop. Loc. B

Prop. Loc. C Prop. Loc. A

SL

SL

SL

-4,300'

-4,300'

-4,200'

-4,100'

-4,000'

-4,400'

-4,400'

-4,500'

-4,500'

-4,600'

-4,600'

-4,400'

-4,400'

C.I. = 25'

10/22/12
Online Payment

Step 3: Confirm Payment 1 | 2 | 3

Thank you. 

Your transaction has been successfully completed. 

Pay.gov Tracking Information

Application Name: BOEM Exploration Plan - BF

Pay.gov Tracking ID: 258UU7KA

Agency Tracking ID: 74389069451

Transaction Date and Time: 12/17/2012 15:46 EST

Payment Summary

Address Information

Account 

Holder Name: Mariner Energy, Inc. 

Billing 

Address:

2000 W. Sam 

Houston Pkwy, S., 

Suite 1600 

Billing 

Address 2:

City: Houston 

State / 

Province: TX 

Zip / Postal 

Code: 77042 

Country: USA 

Account Information

Card Type: American Express 

Card 

Number: ************4008 

Region: Gulf of Mexico 

Contact: 

Terri Young 713-296-

7456 

Company 

Name/No: 

Apache Deepwater 

LLC, 03165 

Lease 

Number(s): 34468, , , , 

Area-Block: 

Mississippi Canyon 

MC, 983: , : , : , : , 

Surface 

Locations: 3 

Payment Information

Payment Amount: $10,326.00

Transaction Date 

and Time:

12/17/2012 

15:46 EST

Pay.gov - Online Payment Page 1 of 1

https://www.pay.gov/paygov/payments/authorizePlasticCardPayment.html 12/17/2012
Apache Deepwater LLC	 	 Page B‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION B 

GENERAL INFORMATION 

(30 CFR 550.213 and 550.243) 

A. APPLICATIONS AND PERMITS

The table below lists the additional permits/applications to be filed before operations can 

commence under this EP: 

Application/Permit Issuing Agency Status 

Application for Permit to Drill (APD) BSEE To be submitted 

 

B. DRILLING FLUIDS 

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

Used per Well 

Water-based (seawater, freshwater, barite) 40,000 bbl / well total 

Oil-based (diesel, minerals, oil) 0 bbl / well total 

M-I Bar 6,424,708 lbs / well total 

Synthetic B 825,665 gal / well total 

Suremul 16,330 gal / well total 

Surewet 8,250 gal / well total 

Rheflat 2,560 gal / well total 

Rhethik 2,006 gal / well total 

Lime 76,440 lbs / well total 

Calcium Chloride 247,366 lbs / well total 

Synthetic-based (internal olefin, ester) 14,000 bbls / well total 

C. NEW OR UNUSUAL TECHNOLOGY 

Apache Deepwater does not propose to use any new or unusual technology to carry out the 

proposed exploration activities. 

D. BONDING STATEMENT 

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

$3,000,000.00 areawide development bond, furnished and maintained according to 30 CFR 256 

subpart I; NTL No. 2000-G16 - “Guidelines for General Lease Surety Bonds”; and additional 

security under 30 CFR 256.53(d) and National NTL No. 2008-N07 - “Supplemental Bond 

Procedures”. 

E. OIL SPILL FINANCE RESPONSIBILITY (OSFR) 

Apache Deepwater LLC, (company number 03165) has demonstrated oil spill financial 

responsibility for this EP according to 30 CFR Part 253 and NTL No. 2008-N05 - “Guidelines 

for Oil Spill Financial Responsibility for Covered Facilities”. 
Apache Deepwater LLC	 	 Page B‐2

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

F. DEEPWATER WELL CONTROL STATEMENT 

Apache Deepwater LLC, (company number 03165) has the financial capability to drill a relief 

well and conduct other emergency well control operations. 

G. 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 

475,731 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 99 Days. 

Maximum discharge volume 

The following table is a linear estimate of the maximum discharge volume for each of the 

aforementioned operational outcomes. 

Operational 

Outcome 

Maximum 

Discharge Rate 

(bbl/day) 

Discharge 

Duration 

(days) 

Maximum 

Discharge 

Volume (bbl) 

Bridging Over 475,731 2 951,462

Surface 

Intervention 

475,731 15 7,135,965

Relief Well 475,731 99 47,097,369 

Potential of wellbore to bridge over during a blowout 

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

is likely to occur due to the extreme 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 reservoir pressure is 21,111 psi. The reservoir 

model estimates bottom hole flowing pressures, based upon reservoir properties and flow rates. 

The calculated drawdown is modeled to be 9,306 psi. 
Apache Deepwater LLC	 	 Page B‐3

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

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. 

We limit the drawdown to less than 1,000 psi by reducing the rates the wells produce and by 

completing each well with a cased hole, frac-pack completion. 

There is a strong likelihood of wellbore bridging over: 

 Drawdown is estimated to be 9.3 times or greater than our operating practices, 

 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, 

 Wellbore collapse and bridge-over, under the conditions cited are estimated not to 

exceed 2 days. 

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 Marine 

Well Containment Company (MWCC) 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 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. 
Apache Deepwater LLC	 	 Page B‐4

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

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. 

5 5 

Debris removal including mobilization 

of ROV boat and construction support 

vessel and execution of debris removal 

plan. 

7 7 

Well capping and/or cap and flow 

operations which include mobilization, 

deployment, and installation of the 

well containment system. 

15 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 vicinity, therefore it is not 

feasible to consider as a relief well location. 

Relief well location and drilling strategy 

Proprietary Information 
Apache Deepwater LLC	 	 Page B‐5

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

Relief well rig availability 

The rigs listed below 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 8502 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

Discoverer Americas Transocean 12,000’ DP Drill Ship 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 95 

days and is summarized below. The MC 983 Location B relief well was used for this example. 
Apache Deepwater LLC	 	 Page B‐6

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

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 8 24 

Spud and drill to the top of the zone of interest 

and set casing. 65 89

Mag-Range relief well into intersecting position. 5 94 

R/U pumping equipment and kill well. 5 99 

R/D Pumping Equipment, PA Wellbore, Pull 

Riser, and Demobilize 15 114 

Blowout Prevention and Intervention 

Summary of prevention measures 

Apache 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 Apache 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. 
Apache Deepwater LLC	 	 Page B‐7

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

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 Apache and Well Control Specialist, well kill operations can be initiated through 

the existing wellbore. 

Well control engineering services 

Apache 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 RP 53 Recommended Practices for 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 Apache has contracted for 

floating marine drilling rigs. 

The goal of using these recommended practices is to assist Apache 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, 

Apache will insure that operations comply with requirements of Federal Regulations.
Apache Deepwater LLC	 	 Page C‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION C 

GEOLOGICAL AND GEOPHYSICAL INFORMATION 

(30 CFR 550.214 and 550.244) 

A. GEOLOGICAL DESCRIPTION 

Proprietary Information 

B. STRUCTURE CONTOUR MAPS 

Proprietary Information

C. INTERPRETED 3-D SEISMIC LINE 

Proprietary Information 

D. GEOLOGICAL STRUCTURE CROSS SECTIONS 

Proprietary Information 

E. SHALLOW HAZARDS 

A Shallow Hazard Survey was conducted over Mississippi Canyon Block 983 by Geoscience 

Earth & Marine Services, Inc. (GEMS). The Shallow Hazard Report is being submitted to the 

BOEM in conjunction with this plan. 

F. SITE-SPECIFIC SHALLOW HAZARDS ASSESSMENT 

A Shallow Hazards Assessment was prepared for the proposed surface locations utilizing the 3-D 

seismic exploration data and is located in Appendix B as part of the Archaeological Assessment. 

The Site Clearance Letters are included as Attachment C-4.

G. HIGH-RESOLUTION SEISMIC LINES

Proprietary Information 

H. STRATIGRAPHIC COLUMN

Proprietary Information

I. TIME VS DEPTH TABLES

Proprietary Information 
10615 Shadow Wood Drive, Suite 200 

Houston, Texas 77043

713.468.1410[o] 713.468.1438 [f] 

www.gemsinc.com 

January 28, 2013 Project No. 0712-2115b 

Apache Deepwater LLC 

2000 W. Sam Houston Parkway South 

Suite 1600 

Houston, TX 77042

Attention: Mr. John Worthen 

Site Clearance Letter for 

San Marcos Site A Well Location 

Block 983 (OCS-G-34468) 

Mississippi Canyon Area 

Gulf of Mexico 

Apache Deepwater LLC (Apache) contracted Geoscience Earth & Marine Services, Inc.®, (GEMS) to 

prepare a Site Clearance Letter for the proposed well location in Block 983 (OCS G-34468), Mississippi 

Canyon (MC) Area. This letter addresses specific seafloor and subsurface geologic conditions around 

the proposed location to the limit of investigation, 5,193 ft below the mudline (bml). Federal lease Block 

MC 983 is approximately 98 miles southeast of Port Fourchon, Louisiana. 

This letter provides details specific to Site A. For a regional assessment of the area see GEMS report 

“Geohazard Assessment, San Marcos Prospect, Block 983 (OCS-G-34468), Mississippi Canyon Area, 

Gulf of Mexico” (GEMS, 2012). The proposed Site A surface location lies in southeastern MC 983. 

Apache provided the following coordinates: 

Proposed Site A Well Location

Spheroid & Datum: Clarke 1866, NAD27

Projection: UTM Zone 16 North Line Reference Block Calls(MC 983)

X: 933,200 ft Latitude: 27o 57’ 59.5858” N Inline 7851 1,360 ft FEL

Y: 10,155,030 ft Longitude: 89o 11’ 28.8877” W Crossline 17161 1,590 ft FSL

Apache will drill Site A with a semi-submersible or dynamically positioned semi submersible. The maximum 

anchor radius is displayed on the maps as a 9,750 ft circle surrounding the proposed location to satisfy 

seabed disturbance guidelines (Map No. A-1 through A-4). 

Apache provided exploration 3-D seismic time data covering an approximate 81 square-mile "Survey 

Area" centered on MC 983, which includes all of Federal lease blocks MC 938-940, 982-984, and Atwater 

Valley (AT) Area Blocks 14-16 (Figure A-1). The primary area of investigation, the MC 983 Study Area, is 

located on the upper to middle continental slope in the southern portion of the Mississippi Canyon 

Protraction Area. Apache also provided high-resolution AUV (Autonomous Underwater Vehicle) data in 

MC 983 and portions of the surrounding blocks (Figure A-1) with subbottom profiler, side-scan sonar, and 

multibeam bathymetry and backscatter data. 
Proposed Well Site A Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 2

FORUM ENERGY TECHNOLOGIES, INC.

Attachments

The page-size maps, figures, and illustrations accompanying this letter have been extracted from the 3-D 

seismic volume supplied by Apache for the geohazard site assessment. These attachments are centered 

on and identify the proposed well location, Site A, in the San Marcos MC 983 Prospect.

Map No. A-1: Bathymetry Map

Map No. A-2: Seafloor Features Map

Map No. A-3: Side-Scan Sonar Mosaic

Map No. A-4: Geologic Features Map

Figure A-1: Regional Rendering of Mississippi Canyon/Atwater Valley Survey Area

Figure A-2: Power Spectrum Analysis Curve, Proposed Site A Well Location 

Illustration A-1: Portions of Inline 7851 and Crossline 17161 Showing Conditions Beneath 

Proposed Site A Well Location

Illustration A-2: Tophole Prognosis Chart, Proposed Site A Well Location, Mississippi Canyon, 

Block 983

Illustration A-3: Portion of SBP Line 119 Showing Conditions Near Proposed Well A

Figure A-1. Regional Rendering of Mississippi Canyon/Atwater Valley Survey Area

MC 937 MC 938 MC 939 MC 940 MC 941

MC 893 MC 894 MC 895 MC 896 MC 897

MC 981 MC 982 MC 983 MC 984 MC 985

AT 13 AT 14 AT 15 AT 16 AT 17

AT 57 AT 58 AT 59 AT 60 AT 61

C

B

A

Proposed Well Locations

Existing Well Locations

Existing Platform Location

Survey Area

Study Area

Existing Pipeline Locations

Mirage/ Titan

AUV Area
Proposed Well Site A Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 3

FORUM ENERGY TECHNOLOGIES, INC.

NTL Requirements

The following report complies with the Bureau of Ocean Energy Management (BOEM; formerly the MMS) 

Notice to Lessees (NTL’s) 2008-G04, 2008-G05, 2009-G40 (MMS, 2008a, b, and 2010) for geohazard 

assessments. The proposed wellsite must follow NTL 2008-G06 with respect to pre- and post-spud ROV 

surveys because MC 983 lies within environmental assessment grid 14, which has inadequate ROV 

survey coverage (MMS, 2008c).

NTL 2011-JOINT-G07 lists Federal lease Block MC 983 as an archaeologically significant block (BOEM, 

2011); therefore, survey requirements for archaeological assessments as set forth in NTL 2005-G07 

(MMS, 2005) and NTL 2011-JOINT-G07 are necessary. GEMS completed an archaeological assessment 

for the San Marcos survey area (GEMS, 2012).

Power Spectrum. As specified in NTL 2008-G05 (MMS, 2008b), GEMS extracted the power spectrum 

diagram (Figure A-2) from the 3-D seismic data cube provided by Apache at the proposed wellsite. The 

extraction was generated within a 500-ft radius of the intersection of the inline and crossline at the 

proposed wellsite, over a time interval from the seafloor to approximately one-second below the mudline 

(Illustration A-1). We converted the amplitude vs. frequency spectrum, generated by the SMT software, 

to power vs. frequency by squaring the amplitude values as described by J. A. Coffeen, 1978.

Figure A-2. Power Spectrum Analysis Curve, Proposed Site A Well Location

Man-Made Features

MC 984 #1, the nearest existing well to the proposed location, lies approximately three miles northeast of 

Site A (BOEM, 2012a), see Figure A-1.

The nearest platform, ATP Oil & Gas Corporation’s Titan floating platform, and associated pipelines are 

greater than seven miles to the northeast (Figure A-1).

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

0 10 20 30 40 50 60 70 80 90 100

Power (Amp2

)

Frequency (Hz)

POWER SPECTRUM
Proposed Well Site A Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 4

FORUM ENERGY TECHNOLOGIES, INC.

Table 1 lists the side-scan sonar contacts located within the 9,750 ft anchor radius of the proposed location. 

All twelve contacts are interpreted to be modern debris from shipping, lease, ordnance, or storm activities. 

None of these contacts, or any other contact in the San Marcos AUV area, are recommended for 

archaeological avoidance or investigation (GEMS, 2012). Care should be taken near these contacts as the 

Survey Area is just southeast of a discontinued military dumping area.

Side-Scan Sonar Contact No. 38 lies approximately 823 ft northwest of the proposed location. The other 

eleven other contacts (No’s. 33, 34, 35, 36, 37, 39, 40, 41, 43, 44, and 46) lie within the 9,750 ft anchor 

radius (Map No. A-4).

Table 1. Sonar Contacts Located Within the 9,750 ft Anchor Radius

No. Block Area Length 

(Feet)

Width 

(Feet)

Height 

(Feet) Shape

X

NAD27

(Feet)

Y

NAD27

(Feet)

33 984 MC 16.09 3.01 0.00 Linear 937124.64 10163272.80

34 983 MC 22.09 7.02 0.00 Irregular 925094.25 10159926.31

35 983 MC 8.03 5.04 0.00 Irregular 930038.28 10157676.04

36 984 MC 12.59 3.01 0.00 Linear 936887.60 10157246.16

37 984 MC 24.16 1.00 0.00 Linear 936244.43 10156707.26

38 983 MC 13.56 2.51 0.00 Linear 932735.03 10155709.25

39 984 MC 16.94 2.56 0.00 Linear 939907.62 10154940.65

40 984 MC 52.19 19.32 0.00 Irregular 939530.76 10154208.30

41 983 MC 23.09 8.66 0.00 Irregular 924281.73 10153443.95

43 16 AT 12.05 9.53 0.00 Irregular 936828.27 10152017.60

44 16 AT 17.69 3.51 0.00 Linear 941942.44 10151930.35

46 16 AT 11.59 7.59 0.00 Irregular 938846.74 10149175.45

Wellsite Conditions

The proposed surface location is clear of any constraining geologic conditions as defined by the 3-D 

seismic volume.

Water Depth and Seafloor Conditions. Seafloor conditions are favorable at the proposed well location. 

The water depth at the proposed surface location is approximately -4,326 ft and the seafloor slopes 

southwest at about 1.1° (Map No. A-1). The proposed well location lies along a gently sloping ramp dipping 

to the southwest (Maps No. A-1 and A-2). A surficial drape of normally consolidated very soft clays likely 

covers the seafloor at the location (Illustration A-3).

Deepwater Benthic Communities. The side-scan sonar mosaic shows a homogenous seabed in the 

vicinity of the proposed location, suggesting normal Gulf of Mexico surficial sediments (Map No. A-3). 

There is no evidence of highly reflective seabed or potential hardgrounds within 2,000 ft of the proposed 

location; therefore, the potential for high-density benthic communities is negligible within 2,000 ft of the 

proposed location.

Stratigraphy. Stratigraphic conditions are shown on Illustrations A-1 and A-2. Inline 7851 and Crossline 

17161 are the closest seismic lines to the proposed location (Illustration A-1). The Tophole Prognosis 

Chart (Illustration A-2) shows a portion of Inline 7851, annotated with calculated depths to the various 

horizons and predicted sequence lithology, along with their shallow water flow and shallow gas potential.

The seafloor and near surface sediments at the proposed well location are expected to be a thin 5 ft

pelagic clay drape overlying a thick unit of clay-rich mass-transport deposits (Illustration A-3). The 

stratigraphy in the upper 245 ft bml, above Horizon 10, is dominated by a drape-type facies interbedded 

with fine-grained mass-transport deposits (Illustrations A-2 and A-3).
Proposed Well Site A Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 5

FORUM ENERGY TECHNOLOGIES, INC.

The interval between Horizon 10 and Horizon 20 (245 ft to 1,039 ft bml) contains interlayered sediments 

that are likely hemipelagic clays and silts, mud rich turbidites, and clay and silt rich mass-transport 

deposits. Thick, continuous sand layers are not expected.

The Horizon 20 to Horizon 30 interval (1,039 ft to 2,393 ft bml) consists of a thin unit of layered deposits 

overlying a thick chaotic unit, which overlies another sequence of layered deposits (Illustrations A-1 and 

A-2). The transition from layered to chaotic is located along a prominent peak reflector at 1,182 ft bml. 

Beneath the peak reflector, rotated beds are likely and may be sand-prone. The base of the chaotic zone 

occurs at 2,066 ft bml. Thin sand-prone layers may be encountered below 2,066 ft bml to Horizon 30 at 

2,393 ft bml.

The reflectors between Horizon 30 (2,393 ft bml) and 2,507 ft bml are well layered and have slightly 

elevated amplitudes (Illustration A-2). Sand-prone turbidites may be encountered in this unit. A thick unit 

of mass-transport deposits containing clays, silts, and sands occurs between 2,507 ft and 3,118 ft bml. A 

thick package of possible sand-prone turbidites is located between 3,118 ft bml and Horizon 40 (3,431 ft 

bml). Continuous sand layers may be encountered in this interval.

The sediments between Horizon 40 (3,431 ft bml) and the limit of investigation (5,193 ft bml) consist of a 

thick package of mass-transport deposits overlying layered, continuous to semi-continuous beds 

(Illustration A-2). Rotated beds are apparent within the mass-transport deposits in the upper portion of 

the unit. Thin, continuous sand layers may be encountered in the lower portion of the unit.

Faults. The nearest seafloor fault is located approximately 1,222 ft east-southeast of the proposed 

location (Map Nos. A-2 and A-4). There are several near-surface faults located approximately 350 ft 

south and 590 ft east of the proposed location (Map No. A-2). These faults are buried by about 5 ft of 

normally deposited sediment suggesting the faults have been inactive in the recent geologic past.

A vertical borehole at the proposed location is not interpreted to intersect any seafloor or buried faults in 

the upper 5,193 ft bml (Illustrations A-1 through A-3).

Shallow Gas and Shallow Water Flow. There is negligible to moderate potential for shallow gas and 

shallow water flow at this well location (Illustration A-2).

Shallow Gas. There are no direct hydrocarbon indicators or apparent subsurface 

high-amplitude anomalies directly below the proposed location (Map No. A-4). The nearest amplitude 

anomaly is located approximately 600 ft southeast between Horizon 20 (1,039 ft bml) and Horizon 30

(2,393 ft bml). We rate the sand-prone intervals from 1,182 ft to 2,066 ft bml, 2,393 ft to 2,507 ft bml, and 

3,118 ft to 3,431 ft bml as having moderate potential for shallow gas (Illustration A-2). These intervals 

are sand prone and may contain biogenic gas at pressures greater than hydrostatic.

A low potential for shallow gas accumulation occurs from 2,066 ft to 2,393 ft bml, 2,507 ft to 3,118 ft bml,

and from 3,431 ft bml to the limit of investigation at 5,193 ft bml (Illustration A-2). Thin sands may be 

encountered in these units. The potential for shallow gas accumulation is considered negligible in the 

clay-rich sediments between the seafloor and 1,182 ft bml.

Shallow Water Flow. The potential for encountering shallow water flow at this well location is 

negligible to moderate (Illustration A-2). The following table lists nearby wells that have and have not had 

shallow water flow issues (BOEM, 2012b).

Table 2. Shallow Water Flow in Nearby Wells

Well Block Flow 

Strength

Depth 

bml (ft)

Well 

Integrity

Distance / Direction from 

Proposed Location

#1 MC 984 No SWF N/A N/A 3.0 miles northeast

#1 MC 940 No SWF N/A N/A 3.4 miles northeast

#1 MC 941 Low 991 Yes 6.8 miles northeast

#1 MC 937 Strong 2,424 Lost 8.0 miles northwest
Proposed Well Site A Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 6

FORUM ENERGY TECHNOLOGIES, INC.

The sand-prone sediments from 1,182 ft to 2,066 ft bml, 2,393 ft to 2,507 ft bml, and 3,118 ft to 3,431 ft 

bml have moderate potential for shallow water flow (Illustration A-2). Continuous, overpressured sand 

layers may be encountered within these units. As a result of numerous mass-wasting events in the 

region’s geologic past, it is likely these sand-prone sediments were rapidly buried and sealed by clay-rich 

overburden. The intervals from 2,066 ft to 2,393 ft bml, 2,507 ft to 3,118 ft bml, and 3,431 ft bml to the 

limit of investigation (5,193 ft bml) have low potential for shallow water flow. Thin sands may be 

encountered in these units. The remaining clay-rich section between the seafloor and 1,182 ft bml has 

negligible potential for shallow water flow.

Anchoring Considerations

The 9,750-ft radius outlined on Map Nos. A-1 through A-4 represents the area of potential effect for 

anchoring. The radius is the basis for clearance of seafloor conditions related to anchoring 

considerations. An additional 1,000-ft buffer zone is also included.

Water depths within the potential mooring area range from about -4,145 ft to -4,605 ft (Map No. A-1). The 

shallowest water depths are located along the northeastern portion of the mooring radius. The deepest 

water depths occur within the southeastern portion of the mooring radius. In general, the seafloor slopes 

southwest within the anchor radius.

Gradients are generally less than 5° within the mooring radius (GEMS, 2012). Steep gradients, up to 77°, 

occur locally along faults in the eastern and southeastern portions of the mooring radius. Gradients up to 

10° to 15° are evident within an area hummocky seafloor in the western and southern portions of the 

mooring radius.

The seabed topography is generally smooth in the northern and northeastern portions of the mooring 

radius (Map No. A-2). The seabed is hummocky in the western to southern portions of the anchor circle. 

Numerous seafloor faults are evident within the southeastern quadrant of the mooring radius (Map Nos. 

A-2 and A-4).

There are no areas of highly reflective seafloor identified on the side-scan sonar data within the 9,750 ft 

mooring radius, suggesting the potential for encountering hardgrounds and high-density benthic 

communities is negligible (Map No. A-3). There are areas of possible hardground interpreted to have a 

low potential for supporting high-density benthic communities along a fault in the eastern portion of the 

mooring radius and at the extreme southern margin of the radius (Map No. A-3). The 3-D seismic data 

show areas of elevated seabed amplitude in the western portion of the anchor circle (Map No. A-4). 

There is no evidence of fluid migration on the 3-D seismic data associated with these amplitudes. The 

subbottom profiler data along similar nearby features suggest intact sediment blocks within the shallow 

mass-transport deposits are creating the amplitude increase in the 3-D seismic data. The sonar data 

show no evidence of hardgrounds associated with the features. There is negligible potential for 

encountering high-density benthic communities associated with these amplitude anomalies, as the sonar 

data show there is no hard substrate for any such communities to attach (Map No. A-3 and Illustration A3).
Proposed Well Site A Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 7

FORUM ENERGY TECHNOLOGIES, INC.

Closing

The proposed Site A well location in Mississippi Canyon Block 983 appears suitable for drilling 

operations. We advise using caution while drilling through the sand-prone intervals from 1,182 ft to 

2,066 ft bml, 2,393 ft to 2,507 ft bml, and 3,118 ft to 3,431 ft bml, as overpressures may occur within 

coarse-grain sediments within these intervals.

Care should be taken near the sonar contacts within the mooring radius as the Survey Area is just 

southeast of a discontinued military dumping area.

We appreciate the opportunity to be of service to Apache Deepwater LLC and look forward to working 

with Apache on future projects.

Sincerely,

GEOSCIENCE EARTH & MARINE

SERVICES, INC.®

Christopher Madere Daniel Lanier

Senior Geoscientist Vice President-Geosciences

Kimberly L. Faulk

Senior Marine Geologist

Attachments (4 Maps and 3 Illustrations)

Distribution:

Mr. John Worthen, Apache Deepwater LLC (5 copies)
Proposed Well Site A Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 8

FORUM ENERGY TECHNOLOGIES, INC.

REFERENCES

Bureau of Ocean Energy Management, 2012, ASCII Data Files, published on the BOEM Gulf of Mexico Region Homepage, 

<http://www.boem.gov/uploadedFiles/BOEM/Oil_and_Gas_Energy_Program/Mapping_and_Data/visual1.pdf>, Accessed 

September, 2012.

Bureau of Ocean Energy Management, 2012b, Safety performance review – shallow water flows can pose significant 

hazards to deepwater drilling, published on the BOEM Gulf of Mexico Region website, 

<www.boem.gov/uploadeFiles/BOEM/Oil_and_Gas_Energy_Program_Resource_Evaluation/Geological_and_Geophysical_

Reviews/SWF2011.pdf>, Accessed October, 2012.

BOEM (Bureau of Ocean Energy Management), 2011, Notice to lessees and operators (NTL) of federal oil and gas leases 

and pipeline right-of-way (ROW) holders on the outer continental shelf (OCS), Revisions to the list of OCS lease blocks 

requiring archaeological resource surveys and reports: U. S. Department of the Interior, Bureau of Ocean Energy 

Management, Bureau of Safety and Environmental Enforcement Gulf of Mexico Region (GOMR), NTL 2011-JOINT-G01. 

Effective Date December 29, 2011.

Coffeen, J. A., 1978, Seismic Exploration Fundamentals: Tulsa, the Petroleum Publishing Co., p. 125.

Geoscience Earth & Marine Services, Inc.®(GEMS), 2012, Geohazard assessment, San Marcos Prospect, block 983 (OCSG-34468), Mississippi Canyon Area, Gulf of Mexico, Project No. 0712-2115b.

Minerals Management Service, 2005, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, Archaeological resource surveys and reports: 

U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2005-G07.

Minerals Management Service, 2008a, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, information requirements for exploration plans 

and development operations coordination documents: U. S. Department of the Interior, Minerals Management Service, Gulf 

of Mexico, NTL 2008-G04.

Minerals Management Service, 2008b, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, shallow hazards requirements: U. S. 

Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G05.

Minerals Management Service, 2008c, Notice to lessees and operators of federal oil, gas, and sulphur leases in the outer 

continental shelf, Gulf of Mexico OCS region; remotely operated vehicle surveys in deepwater, U. S. Department of the 

Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G06.

Minerals Management Service, 2010, Notice to lessees and operators of federal oil and gas leases in the outer continental 

shelf, Gulf of Mexico OCS region, deepwater benthic communities: U. S. Department of the Interior, Minerals Management 

Service, Gulf of Mexico, NTL 2009-G40. Effective Date January 27, 2010.




30000 35000 40000

1.600

1.700

1.800

1.900

2.000

2.100

2.200

2.300

2.400

2.500

2.600

2.700

2.800

2.900

3.000

3.100

3.200

3.300

40000 45000 50000

1.700

1.800

1.900

2.000

2.100

2.200

2.300

2.400

2.500

2.600

2.700

2.800

2.900

3.000

3.100

3.200

3.300

3.400

MC

983

AT

15

STUDY AREA

MC

984

NORTHWEST SOUTHEAST

Project No. 0712-2115b Filename: 122115b_Illustration_A-1.cdr

Illustration A-1. Portions of Inline 7851 and Crossline 17161 Showing Conditions Beneath Proposed Site A Well Location

INLINE 7851

SOUTHWEST NORTHEAST PROPOSED WELLSITE A TWO-WAY TRAVEL TIME (SEC) TWO-WAY TRAVEL TIME (SEC)

PROPOSED WELLSITE A

Horizontal

Distance (ft):

Horizontal

Distance (ft):

CROSSLINE 17161

Seafloor

CHAOTIC ZONE

Horizon 1 Horizon 10

Horizon 2 Horizon 20

Horizon 3 Horizon 30

Horizon 4 Horizon 40

Seafloor

Horizon 1 Horizon 10

Horizon 3 Horizon 30

Horizon 4 Horizon 40

Horizon 20

CHAOTIC ZONE

RELATIVE AMPLITUDE

Peak

Trough

MC

983

AT

16 MC

984

CHAOTIC ZONE

STUDY AREA

CHAOTIC ZONE
MC

983

AT

15

STUDY AREA

40000 45000

1.700

1.8001.9002.0002.1002.2002.3002.4002.5002.6002.7002.8002.9003.0003.1003.2003.3003.400

WATER

FLOW AND

GAS

POTENTIAL

Shallow Water Flow and Gas Potential

HIGH

0 1 2 3

0 = NEGLIGIBLE

1 = LOW2 = MODERATE

3 = HIGH

NEGLIGIBLE

Horizon Lithology/Stratigraphy

Illustration A-2. Tophole Prognosis Chart, Proposed Site A Well Location, Mississippi 

Project No. 0712-2115b 

Water

Flow

Gas

3-D Seismic Section Through

Proposed Wellsite A

X = 933,200 ft

Y = 10,155,030 ft

NW SE

Horizon

TWT

(sec, bsl)

Depth

(ft, bml)

Depth

(ft, bsl)*

INLINE 7851

TWO-WAY TIME TRAVEL (SEC)

3.458

2.938

Proposed

Wellsite A

Distance (ft):

Horizontal

Low po

SEAFLOOR -4,326

Negligi

2.610 -6,719 2,393

HORIZON 10HORIZON 20INTERFACEINTERFACEHORIZON 40HORIZON 30

LIMIT OF

INVESTIGATION

1.839

2.1442.1962.352

1.744

-4,571

-5,365

-5,508

-5,950

-7,757

-9,519

245

1,039

1,182

1,624

3,431

5,193

Pelagic clay drape overlying bedded hemipelagic clay andfine grained muddy turbidites or mud flows.

Layered hemipelagic clays and silts and mud rich turbiditesinterbedded with clay and silt rich mass-transport deposits.Clay and silt-rich mass-transport deposits between 417 ftand 560 ft below mudline.Layered hemipelagic clay-rich section.Bedded hemipelagic clay-rich interval with fine grainedturbidite and mass-transport deposits at base of unit. Thinsands possible.Interface marks top of sand-prone unit. Beds in middle ofsection appear slightly rotated.Chaotic and discontinuous hemipelagic clay interval withmuddy turbidites interbedded with clay, silt, and sand masstransport deposits.

Modera

INTERFACE 2.841 -7,444 3,118

Low poModera

Interface marks top of elevated amplitude reflectors,suggesting an increase in sand content.Thick package of elevated amplitude reflectors, suggestingbedded, sand-prone turbidites.Clay, silt, and sand prone mass-transport deposits. Rotatedbeds appear probable.Generally clay-rich, layered deposits with some thin sandseams possible.

INTERFACE 2.502 -6,392 2,066INTERFACE 2.647 -6,833 2,507 Package of slightly elevated amplitude reflectors, suggesting

bedded, sand-prone turbidites.

ModeraLow po
16000 17000 18000 19000 20000 21000

1.750

1.760

1.770

1.780

1.790

1.800

1.810

1.820

Illustration A-3. Portion of SBP Line 119 Showing Conditions Near Proposed Well A

Project No. 0712-2115b Filename: 122115b_Illustration_A_3.cdr

PORTION OF SBP LINE 119

WEST EAST

TWO-WAY TRAVEL TIME (SEC)

PROPOSED WELLSITE A

(~260 FT TO NORTH) MC

983

WELL B

WELL A

WELL C

3-D SEABED

ANOMALY

SIDE-SCAN SONAR DATA SHOW NO

EVIDENCE OF HARDGROUNDS WITHIN

2,000 FT OF THE PROPOSED LOCATION

MTD

SEAFLOOR

MASS-TRANSPORT DEPOSITS APPEAR

CLAY-RICH NEAR PROPOSED WELLSITE

MC

983

N

SBP LINE 119

0 FT 500 FT 1,000 FT 1,500 FT

PORTION OF SIDE-SCAN SONAR MOSAIC

MTD

~25 FT

AT

16

MC

984

AT

15

MISSISSIPPI CANYON AREA

ATWATER VALLEY AREA
10615 Shadow Wood Drive, Suite 200 

Houston, Texas 77043

713.468.1410[o] 713.468.1438 [f] 

www.gemsinc.com 

January 28, 2013 Project No. 0712-2115b 

Apache Deepwater LLC 

2000 W. Sam Houston Parkway South 

Suite 1600 

Houston, TX 77042

Attention: Mr. John Worthen 

Site Clearance Letter for 

San Marcos Site B Well Location 

Block 983 (OCS-G-34468) 

Mississippi Canyon Area 

Gulf of Mexico 

Apache Deepwater LLC (Apache) contracted Geoscience Earth & Marine Services, Inc.®, (GEMS) to 

prepare a Site Clearance Letter for the proposed well location in Block 983 (OCS G-34468), Mississippi 

Canyon (MC) Area. This letter addresses specific seafloor and subsurface geologic conditions around 

the proposed location to the limit of investigation, 5,231 ft below the mudline (bml). Federal lease Block 

MC 983 is approximately 98 miles southeast of Port Fourchon, Louisiana. 

This letter provides details specific to Site B. For a regional assessment of the area see GEMS report 

“Geohazard Assessment, San Marcos Prospect, Block 983 (OCS-G-34468), Mississippi Canyon Area, 

Gulf of Mexico” (GEMS, 2012). The proposed Site B surface location lies in southeastern MC 983. 

Apache provided the following coordinates: 

Proposed Site B Well Location

Spheroid & Datum: Clarke 1866, NAD27

Projection: UTM Zone 16 North Line Reference Block Calls(MC 983)

X: 931,209 ft Latitude: 27o 58’ 10.8724” N Inline 7845 3,351 ft FEL

Y: 10,156,206 ft Longitude: 89o 11’ 51.3196” W Crossline 17269 2,766 ft FSL

Apache will drill Site B with a semi-submersible or dynamically positioned semi submersible. The maximum 

anchor radius is displayed on the maps as a 9,750 ft circle surrounding the proposed location to satisfy 

seabed disturbance guidelines (Map No. B-1 through B-4). 

Apache provided exploration 3-D seismic time data covering an approximate 81 square-mile "Survey 

Area" centered on MC 983, which includes all of Federal lease blocks MC 938-940, 982-984, and Atwater 

Valley (AT) Area Blocks 14-16 (Figure B-1). The primary area of investigation, the MC 983 Study Area, is 

located on the upper to middle continental slope in the southern portion of the Mississippi Canyon 

Protraction Area. Apache also provided high-resolution AUV (Autonomous Underwater Vehicle) data 

covering MC 983 and portions of the surrounding blocks (Figure B-1) with subbottom profiler, side-scan 

sonar, and multibeam bathymetry and backscatter data. 

Attachments 

The page-size maps, figures, and illustrations accompanying this letter have been extracted from the 3-D 

seismic volume supplied by Apache for the geohazard site assessment. These attachments are centered 

on and identify the proposed well location, Site B, in the San Marcos MC 983 Prospect. 

Map No. B-1: Bathymetry Map 

 Map No. B-2: Seafloor Features Map 
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 2

FORUM ENERGY TECHNOLOGIES, INC.

Map No. B-3: Side-Scan Sonar Mosaic

Map No. B-4: Geologic Features Map

Figure B-1: Regional Rendering of Mississippi Canyon/Atwater Valley Survey Area

Figure B-2: Power Spectrum Analysis Curve, Proposed Site B Well Location 

Illustration B-1: Portions of Inline 7845 and Crossline 17269 Showing Conditions Beneath 

Proposed Site B Well Location

Illustration B-2: Tophole Prognosis Chart, Proposed Site B Well Location, Mississippi Canyon, 

Block 983

Illustration B-3: Portion of SBP Line 121 Showing Conditions Near Proposed Well B

Figure B-1. Regional Rendering of Mississippi Canyon/Atwater Valley Survey Area

NTL Requirements

The following report complies with the Bureau of Ocean Energy Management (BOEM; formerly the MMS) 

Notice to Lessees (NTL’s) 2008-G04, 2008-G05, 2009-G40 (MMS, 2008a, b, and 2010) for geohazard 

assessments. The proposed wellsite must follow NTL 2008-G06 with respect to pre- and post-spud ROV 

surveys because MC 983 lies within environmental assessment grid 14, which has inadequate ROV 

survey coverage (MMS, 2008c).

MC 937 MC 938 MC 939 MC 940 MC 941

MC 893 MC 894 MC 895 MC 896 MC 897

MC 981 MC 982 MC 983 MC 984 MC 985

AT 13 AT 14 AT 15 AT 16 AT 17

AT 57 AT 58 AT 59 AT 60 AT 61

C

B

A

Proposed Well Locations

Existing Well Locations

Existing Platform Location

Survey Area

Study Area

Existing Pipeline Locations

Mirage/ Titan

AUV Area
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 3

FORUM ENERGY TECHNOLOGIES, INC.

NTL 2011-JOINT-G07 lists Federal lease Block MC 983 as an archaeologically significant block (BOEM, 

2011); therefore, survey requirements for archaeological assessments as set forth in NTL 2005-G07 

(MMS, 2005) and NTL 2011-JOINT-G07 are necessary. GEMS completed an archaeological assessment 

for the San Marcos survey area (GEMS, 2012).

Power Spectrum. As specified in NTL 2008-G05 (MMS, 2008b), GEMS extracted the power spectrum 

diagram (Figure B-2) from the 3-D seismic data cube provided by Apache at the proposed wellsite. The 

extraction was generated within a 500-ft radius of the intersection of the inline and crossline at the 

proposed wellsite, over a time interval from the seafloor to approximately one-second below the mudline 

(Illustration B-1). We converted the amplitude vs. frequency spectrum, generated by the SMT software, 

to power vs. frequency by squaring the amplitude values as described by J. A. Coffeen, 1978.

Figure B-2. Power Spectrum Analysis Curve, Proposed Site B Well Location

Man-Made Features

MC 984 #1, the nearest existing well to the proposed location, lies approximately three miles northeast of 

Site B (BOEM, 2012a), see Figure B-1.

The nearest platform, ATP Oil & Gas Corporation’s Titan floating platform, and associated pipelines are 

greater than seven miles to the northeast (Figure B-1).

Table 1 lists the side-scan sonar contacts located within the 9,750 ft anchor radius of the proposed location. 

All eleven contacts are interpreted to be modern debris from shipping, lease, ordnance, or storm activities. 

None of these contacts, or any other contact in the San Marcos AUV area, are recommended for 

archaeological avoidance or investigation (GEMS, 2012). Care should be taken near these contacts as the 

Survey Area is just southeast of a discontinued military dumping area.

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

0 10 20 30 40 50 60 70 80 90 100

Power (Amp2

)

Frequency (Hz)

POWER SPECTRUM
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 4

FORUM ENERGY TECHNOLOGIES, INC.

Side-Scan Sonar Contact No’s. 35 and 38 lie approximately 1,879 ft northwest and 1,605 ft east-southeast 

of the proposed location, respectively. The other nine contacts (No.’s 33, 34, 36, 37, 39, 40, 41, 43, and 46) 

lie within the 9,750 ft anchor radius (Map No. B-4).

Table 1. Sonar Contacts Located Within the 9,750 ft Anchor Radius

No. Block Area Length 

(Feet)

Width 

(Feet)

Height 

(Feet) Shape

X

NAD27

(Feet)

Y

NAD27

(Feet)

33 984 MC 16.09 3.01 0.00 Irregular 937124.64 10163272.80

34 983 MC 22.09 7.02 0.00 Irregular 925094.25 10159926.31

35 983 MC 8.03 5.04 0.00 Irregular 930038.28 10157676.04

36 984 MC 12.59 3.01 0.00 Linear 936887.60 10157246.16

37 984 MC 24.16 1.00 0.00 Linear 936244.43 10156707.26

38 983 MC 13.56 2.51 0.00 Linear 932735.03 10155709.25

39 984 MC 16.94 2.56 0.00 Linear 939907.62 10154940.65

41 983 MC 23.09 8.66 0.00 Irregular 924281.73 10153443.95

40 984 MC 52.9 19.32 0.00 Irregular 939530.76 10154208.30

43 16 AT 12.05 9.53 0.00 Irregular 936828.27 10152017.60

46 16 AT 11.59 7.59 0.00 Irregular 938846.74 10149175.45

Wellsite Conditions

The proposed surface location is clear of any constraining geologic conditions as defined by the 3-D 

seismic volume and the supplemental AUV data.

Water Depth and Seafloor Conditions. Seafloor conditions are favorable at the proposed well location. 

The water depth at the proposed surface location is approximately -4,342 ft and the seafloor slopes 

southwest at about 0.8° (Map No. B-1). The proposed well location lies along a gently sloping ramp dipping 

to the southwest (Maps No. B-1 and B-2). A surficial drape of normally consolidated very soft clays likely 

covers the seafloor at the location (Illustration B-3).

Deepwater Benthic Communities. The side-scan sonar mosaic shows a homogenous seabed in the 

vicinity of the proposed location, suggestive of normal Gulf of Mexico surficial sediments (Map No. B-3). 

There is no evidence of highly reflective seabed or potential hardgrounds within 2,000 ft of the proposed 

location; therefore, the potential for high-density benthic communities is negligible within 2,000 ft of the 

proposed location.

The 3-D seismic data show an isolated area of elevated seabed amplitude along the southwestern 

portion of the 2,000 ft circle surrounding the proposed location (Map No. B-4). There is no evidence of 

fluid migration on the 3-D seismic data associated with this amplitude. The subbottom profiler data along 

similar nearby features suggest intact blocks of sediment within the shallow mass-transport deposits are 

creating the amplitude increase in the 3-D seismic data (Illustration B-3). The sonar data show no 

evidence of hardgrounds associated with the feature. There is a negligible potential for encountering 

high-density benthic communities associated with this amplitude anomaly, as the sonar data show there 

is no hard substrate for any such communities to attach.

Stratigraphy. Stratigraphic conditions are shown on Illustrations B-1 and B-2. Inline 7845 and Crossline 

17269 are the closest seismic lines to the proposed location (Illustration B-1). The Tophole Prognosis 

Chart (Illustration B-2) shows a portion of Inline 7845, annotated with calculated depths to the various 

horizons and predicted sequence lithology, along with their shallow water flow and shallow gas potential.

The seafloor and near surface sediments at the proposed well location are expected to be a thin 5 ft 

pelagic clay drape overlying a thick unit of clay-rich mass-transport deposits (Illustration B-3). The 
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 5

FORUM ENERGY TECHNOLOGIES, INC.

stratigraphy in the upper 240 ft bml, above Horizon 10, is dominated by a drape-type facies interbedded

with fine-grained mass-transport deposits (Illustrations B-2 and B-3).

The interval between Horizon 10 and Horizon 20 (240 ft to 1,099 ft bml) contains interlayered sediments 

that are likely hemipelagic clays and silts, mud rich turbidites, and clay and silt rich mass-transport 

deposits. Thick, continuous sand layers are not expected.

The Horizon 20 to Horizon 30 interval (1,099 ft to 2,378 ft bml) consists of a thin unit of layered deposits 

overlying a thick chaotic unit, which overlies another sequence of layered deposits (Illustrations B-1 and 

B-2). The transition from layered to chaotic is located along a prominent peak reflector at 1,260 ft bml. 

Beneath the peak reflector, rotated beds are likely and may be sand-prone. The base of the chaotic zone 

occurs at 1,952 ft bml. Thin sand-prone layers may be encountered below 1,952 ft bml to Horizon 30 at 

2,378 ft bml.

The reflectors between Horizon 30 (2,378 ft bml) and 2,588 ft bml are well layered and have slightly 

elevated amplitudes (Illustration B-2). Sand-prone turbidites may be encountered in this unit. A thick unit 

of mass-transport deposits containing clays, silts, and sands occurs between 2,588 ft and 3,153 ft bml. A 

thick package of possible sand-prone turbidites is located between 3,153 ft bml and Horizon 40 (3,519 ft 

bml). Continuous sand layers may be encountered in this interval.

The sediments between Horizon 40 (3,519 ft bml) and the limit of investigation (5,231 ft bml) consist of a 

thick package of mass-transport deposits overlying layered, continuous to semi-continuous beds 

(Illustration B-2). Rotated beds are apparent within the mass-transport deposits in the upper portion of 

the unit. Thin, continuous sand layers may be encountered in the lower portion of the unit.

Faults. The nearest seafloor fault is located approximately 3,500 ft southeast of the proposed location 

(Map Nos. B-2 and B-4). There are several near-surface faults located approximately 2,235 ft southeast 

of the proposed location (Map No. B-2). These faults are buried by about 5 ft of normally deposited 

sediment suggesting the faults have been inactive in the recent geologic past.

A vertical borehole at the proposed location is not interpreted to intersect any seafloor or buried faults in 

the upper 5,231 ft bml (Illustrations B-1 through B-3).

Shallow Gas and Shallow Water Flow. There is negligible to moderate potential for shallow gas and 

shallow water flow at this well location (Illustration B-2).

Shallow Gas. There are no direct hydrocarbon indicators or apparent subsurface 

high-amplitude anomalies directly below the proposed location (Map No. B-4). The nearest amplitude 

anomaly is located approximately 600 ft southwest between Horizon 20 (1,099 ft bml) and Horizon 30

(2,378 ft bml). We rate the sand-prone intervals from 1,260 ft to 1,952 ft bml, 2,378 ft to 2,588 ft bml, and 

3,153 ft to 3,519 ft bml as having moderate potential for shallow gas (Illustration B-2). These intervals 

are sand prone may contain biogenic gas at pressures greater than hydrostatic.

A low potential for shallow gas accumulation occurs from 1,952 ft to 2,378 ft bml, 2,588 ft to 3,153 ft bml,

and from 3,519 ft bml to the limit of investigation at 5,231 ft bml (Illustration B-2). Thin sands may be 

encountered in these units. The potential for shallow gas accumulation is considered negligible in the 

clay-rich sediments between the seafloor and 1,260 ft bml.

Shallow Water Flow. The potential for encountering shallow water flow at this well location is 

negligible to moderate (Illustration B-2). The following table lists nearby wells that have and have not had 

shallow water flow issues (BOEM, 2012b).

Table 2. Shallow Water Flow in Nearby Wells

Well Block Flow 

Strength

Depth 

bml (ft)

Well 

Integrity

Distance / Direction from 

Proposed Location

#1 MC 984 No SWF N/A N/A 3.0 miles northeast

#1 MC 940 No SWF N/A N/A 3.4 miles northeast

#1 MC 941 Low 991 Yes 6.9 miles northeast
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 6

FORUM ENERGY TECHNOLOGIES, INC.

Well Block Flow 

Strength

Depth 

bml (ft)

Well 

Integrity

Distance / Direction from 

Proposed Location

#1 MC 937 Strong 2,424 Lost 7.6 miles northwest
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 7

FORUM ENERGY TECHNOLOGIES, INC.

The sand-prone sediments from 1,260 ft to 1,952 ft bml, 2,378 ft to 2,588 ft bml, and 3,153 ft to 3,519 ft 

bml have moderate potential for shallow water flow (Illustration B-2). Continuous, overpressured sand 

layers may be encountered within these units. As a result of numerous mass-wasting events in the 

region’s geologic past, it is likely these sand-prone sediments were rapidly buried and sealed by clay-rich 

overburden. The intervals from 1,952 ft to 2,378 ft bml, 2,588 ft to 3,153 ft bml, and 3,519 ft bml to the 

limit of investigation (5,231 ft bml) have low potential for shallow water flow. Thin sands may be 

encountered in these units. The remaining clay-rich section between the seafloor and 1,260 ft bml has 

negligible potential for shallow water flow.

Anchoring Considerations

The 9,750-ft radius outlined on Map Nos. B-1 through B-4 represents the area of potential effect for 

anchoring. The radius is the basis for clearance of seafloor conditions related to anchoring 

considerations. An additional 1,000-ft buffer zone is also included.

Water depths within the potential mooring area range from about -4,150 ft to -4,530 ft (Map No. B-1). The 

shallowest water depths are located along the northeastern portion of the mooring radius. The deepest 

water depths occur within the southern portion of the mooring radius. In general, the seafloor slopes 

southwest within the anchor radius.

Gradients are generally less than 5° within the mooring radius (GEMS, 2012). Steep gradients, up to 15°, 

occur locally along faults in the eastern and southeastern portions of the mooring radius. Gradients up to 

10° to 15° are evident locally along the flanks of hummocks within the mooring radius.

The seabed topography is generally smooth in the northeastern quadrant of the mooring radius (Map 

No. B-2). The seabed is hummocky in the northern, northwestern, western, southwestern, and southern 

portions of the anchor circle. Numerous seafloor faults are evident within the southeastern portion of the 

mooring radius (Map Nos. B-2 and B-4).

There are no areas of highly reflective seafloor identified on the side-scan sonar data, suggesting the 

potential for encountering hardgrounds and high-density benthic communities is negligible (Map No. B-3). 

The 3-D seismic data show areas of elevated seabed amplitude in the western portion of the anchor circle 

(Map No. B-4). There is no evidence of fluid migration on the 3-D seismic data associated with these 

amplitudes. The subbottom profiler data along similar nearby features suggest intact sediment blocks 

within the shallow mass-transport deposits are creating the amplitude increase in the 3-D seismic data

(Illustration B-3). The sonar data show no evidence of hardgrounds associated with the features. There 

is negligible potential for encountering high-density benthic communities associated with these amplitude 

anomalies, as the sonar data show there is no hard substrate for any such communities to attach. 

Patches with low-potential of supporting communities exist at the eastern and southern limits of the 1,000 

ft buffer zone (Map No. B-3 and Illustration B-3).
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 8

FORUM ENERGY TECHNOLOGIES, INC.

Closing

The proposed Site B well location in Mississippi Canyon Block 983 appears suitable for drilling 

operations. We advise using caution while drilling through the sand-prone intervals from 1,260 ft to 

1,952 ft bml, 2,378 ft 2,588 ft bml, and 3,153 ft to 3,519 ft bml, as overpressures may occur within coarsegrain sediments within these intervals.

Care should be taken near the sonar contacts within the mooring radius as the Survey Area is just 

southeast of a discontinued military dumping area.

We appreciate the opportunity to be of service to Apache Deepwater LLC and look forward to working 

with Apache on future projects.

Sincerely,

GEOSCIENCE EARTH & MARINE

SERVICES, INC.®

Christopher Madere Daniel Lanier

Senior Geoscientist Vice President-Geosciences

Attachments (4 Maps and 3 Illustrations)

Distribution:

Mr. John Worthen, Apache Deepwater LLC (5 copies)
Proposed Well Site B Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 9

FORUM ENERGY TECHNOLOGIES, INC.

REFERENCES

Bureau of Ocean Energy Management, 2012a, ASCII data files, published on the BOEM Gulf of Mexico Region website, 

<www.data.boem.gov/homepg/data_center/mapping/geographic_mapping.asp>, Accessed September, 2012.

Bureau of Ocean Energy Management, 2012b, Safety performance review – shallow water flows can pose significant 

hazards to deepwater drilling, published on the BOEM Gulf of Mexico Region website, 

<www.boem.gov/uploadeFiles/BOEM/Oil_and_Gas_Energy_Program_Resource_Evaluation/Geological_and_Geophysical_

Reviews/SWF2011.pdf>, Accessed October, 2012.

BOEM (Bureau of Ocean Energy Management), 2011, Notice to lessees and operators (NTL) of federal oil and gas leases 

and pipeline right-of-way (ROW) holders on the outer continental shelf (OCS), Revisions to the list of OCS lease blocks 

requiring archaeological resource surveys and reports: U. S. Department of the Interior, Bureau of Ocean Energy 

Management, Bureau of Safety and Environmental Enforcement Gulf of Mexico Region (GOMR), NTL 2011-JOINT-G01. 

Effective Date December 29, 2011.

Coffeen, J. A., 1978, Seismic Exploration Fundamentals: Tulsa, the Petroleum Publishing Co., p. 125.

Geoscience Earth & Marine Services, Inc.®(GEMS), 2012, Geohazard assessment, San Marcos Prospect, block 983 (OCSG-34468), Mississippi Canyon Area, Gulf of Mexico, Project No. 0712-2115b.

Minerals Management Service, 2005, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, Archaeological resource surveys and reports: 

U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2005-G07.

Minerals Management Service, 2008a, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, information requirements for exploration plans 

and development operations coordination documents: U. S. Department of the Interior, Minerals Management Service, Gulf 

of Mexico, NTL 2008-G04.

Minerals Management Service, 2008b, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, shallow hazards requirements: U. S. 

Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G05.

Minerals Management Service, 2008c, Notice to lessees and operators of federal oil, gas, and sulphur leases in the outer 

continental shelf, Gulf of Mexico OCS region; remotely operated vehicle surveys in deepwater, U. S. Department of the 

Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G06.

Minerals Management Service, 2010, Notice to lessees and operators of federal oil and gas leases in the outer continental 

shelf, Gulf of Mexico OCS region, deepwater benthic communities: U. S. Department of the Interior, Minerals Management 

Service, Gulf of Mexico, NTL 2009-G40. Effective Date January 27, 2010.




MC

983

AT

15

STUDY AREA

MC

984

30000 35000 40000

1.600

1.700

1.800

1.900

2.000

2.100

2.200

2.300

2.400

2.500

2.600

2.700

2.800

2.900

3.000

3.100

3.200

3.300

35000 40000 45000

1.700

1.800

1.900

2.000

2.100

2.200

2.300

2.400

2.500

2.600

2.700

2.800

2.900

3.000

3.100

3.200

3.300

3.400

NORTHWEST SOUTHEAST

Project No. 0712-2115b Filename: 122115b_Illustration_B-1.cdr

Illustration B-1. Portions of Inline 7845 and Crossline 17269 Showing Conditions Beneath Proposed Site B Well Location

INLINE 7845

SOUTHWEST NORTHEAST PROPOSED WELLSITE B TWO-WAY TRAVEL TIME (SEC) TWO-WAY TRAVEL TIME (SEC)

PROPOSED WELLSITE B

Horizontal

Distance (ft):

Horizontal

Distance (ft):

CROSSLINE 17269

Seafloor

CHAOTIC ZONE

Horizon 10

Horizon 2 Horizon 20

Horizon 3 Horizon 30

Horizon 4 Horizon 40

Seafloor

Horizon 1 Horizon 10

Horizon 3 Horizon 30

Horizon 40

Horizon 20

CHAOTIC ZONE

RELATIVE AMPLITUDE

Peak

Trough

MC

983

AT

16

AT

15

CHAOTIC ZONE

STUDY AREA

CHAOTIC ZONE
MC

983

STUDY AREA

40000

1.7001.8001.9002.0002.1002.2002.3002.4002.5002.6002.7002.8002.9003.0003.1003.2003.3003.400

42500

WATER

FLOW AND

GAS

POTENTIAL

Shallow Water Flow and Gas Potential

HIGH

0 1 2 3

NEGLIGIBLE

Horizon Lithology/Stratigraphy

Illustration B-2. Tophole Prognosis Chart, Proposed Site B Well Location, Mississippi 

Project No. 0712-2115b 

Water

Flow

Gas

3-D Seismic Section Through

Proposed Wellsite B

X = 931,209 ft

Y = 10,156,206 ft

NW SE

Horizon

TWT

(sec, bsl)

Depth

(ft, bml)

INLINE 7845

TWO-WAY TIME TRAVEL (SEC)

3.475

2.971

Proposed

Wellsite B

Distance (ft):

Horizontal

Low po

SEAFLOOR -4,342

Negligi

2.611 -6,720 2,378

HORIZON 10HORIZON 20INTERFACEINTERFACEHORIZON 40HORIZON 30

LIMIT OF

INVESTIGATION

1.843

2.1722.2302.470

1.750

-4,582

-5,441

-5,602

-6,294

-7,861

-9,573

240

1,099

1,260

1,952

3,5195,231

Pelagic clay drape overlying bedded hemipelagic clay andfine grained muddy turbidites or mud flows.

Layered hemipelagic clay-rich section.Bedded hemipelagic clay-rich interval with fine grainedturbidite and mass-transport deposits at base of unit. Thinsands possible.Interface marks top of sand-prone unit. Beds in middle ofsection appear slightly rotated.Chaotic and discontinuous hemipelagic clay interval withmuddy turbidites interbedded with clay, silt, and sand masstransport deposits.

Modera

INTERFACE 2.858 -7,495 3,153

Low poModera

Thick package of elevated amplitude reflectors, suggesting bedded, sand-prone turbidites.Clay, silt, and sand prone mass-transport deposits. Rotatedbeds appear probable.Generally clay-rich, layered deposits with some thin sandseams possible.

0 = NEGLIGIBLE

1 = LOW2 = MODERATE

3 = HIGH

Depth

(ft, bsl)*

INTERFACE 2.679 -6,930 2,588

Package of slightly elevated amplitude reflectors, suggestingbedded, sand-prone turbidites. Modera

Low po

Layered hemipelagic clays and silts and mud rich turbiditesinterbedded with clay and silt rich mass-transport deposits.Clay and silt-rich mass-transport deposits between 407 ftand 535 ft below mudline.
Distance (ft): 13000 14000 15000 16000 17000 18000

1.760

1.770

1.780

1.790

1.800

1.810

1.820

1.830

Illustration B-3. Portion of SBP Line 121 Showing Conditions Near Proposed Well B

Project No. 0712-2115b Filename: 122115b_Illustration_B_3.cdr

PORTION OF SBP LINE 121

WEST EAST

TWO-WAY TRAVEL TIME (SEC)

PROPOSED WELLSITE B

(~120 FT TO NORTH) MC

983

WELL B

WELL A

WELL C

3-D SEABED

ANOMALY

SIDE-SCAN SONAR DATA SHOW NO

EVIDENCE OF HARDGROUNDS WITHIN

2,000 FT OF THE PROPOSED LOCATION

MTD

SEAFLOOR

INTACT BLOCKS

ALIGN WITH 3-D

SEABED ANOMALIES

{ { } }

MASS-TRANSPORT DEPOSITS APPEAR

CLAY-RICH NEAR PROPOSED WELLSITE

MC

983

N

SBP LINE 121

0 FT 500 FT 1,000 FT 1,500 FT

PORTION OF SIDE-SCAN SONAR MOSAIC

MTD

~25 FT MTD
10615 Shadow Wood Drive, Suite 200 

Houston, Texas 77043

713.468.1410[o] 713.468.1438 [f] 

www.gemsinc.com 

January 28, 2013 Project No. 0712-2115b 

Apache Deepwater LLC 

2000 W. Sam Houston Parkway South 

Suite 1600 

Houston, TX 77042

Attention: Mr. John Worthen 

Site Clearance Letter for 

San Marcos Site C Well Location 

Block 983 (OCS-G-34468) 

Mississippi Canyon Area 

Gulf of Mexico 

Apache Deepwater LLC (Apache) contracted Geoscience Earth & Marine Services, Inc.®, (GEMS) to 

prepare a Site Clearance Letter for the proposed well location in Block 983 (OCS G-34468), Mississippi 

Canyon (MC) Area. This letter addresses specific seafloor and subsurface geologic conditions around 

the proposed location to the limit of investigation, 5,042 ft below the mudline (bml). Federal lease Block 

MC 983 is approximately 98 miles southeast of Port Fourchon, Louisiana. 

This letter provides details specific to Site C. For a regional assessment of the area see GEMS report 

“Geohazard Assessment, San Marcos Prospect, Block 983 (OCS-G-34468), Mississippi Canyon Area, 

Gulf of Mexico” (GEMS, 2012). The proposed Site C surface location lies in southeastern MC 983. 

Apache provided the following coordinates: 

Proposed Site C Well Location

Spheroid & Datum: Clarke 1866, NAD27

Projection: UTM Zone 16 North Line Reference Block Calls(MC 983)

X: 929,504 ft Latitude: 27o 58’ 4.0451” N Inline 7828 5,056 ft FEL

Y: 10,155,547 ft Longitude: 89o 12’ 10.1951” W Crossline 17305 2,107 ft FSL

Apache will drill Site C with a semi-submersible or dynamically positioned semi submersible. The maximum 

anchor radius is displayed on the maps as a 9,750 ft circle surrounding the proposed location to satisfy 

seabed disturbance guidelines (Map No. C-1 through C-4). 

Apache provided exploration 3-D seismic time data covering an approximate 81 square-mile "Survey 

Area" centered on MC 983, which includes all of Federal lease blocks MC 938-940, 982-984, and Atwater 

Valley (AT) Area Blocks 14-16 (Figure C-1). The primary area of investigation, the MC 983 Study Area, is 

located on the upper to middle continental slope in the southern portion of the Mississippi Canyon 

Protraction Area. Apache also provided high-resolution AUV (Autonomous Underwater Vehicle) data 

covering MC 983 and portions of the surrounding blocks (Figure C-1) with subbottom profiler, side-scan 

sonar, and multibeam bathymetry and backscatter data. 
Proposed Well Site C Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 2

FORUM ENERGY TECHNOLOGIES, INC.

Attachments

The page-size maps, figures, and illustrations accompanying this letter have been extracted from the 3-D 

seismic volume supplied by Apache for the geohazard site assessment. These attachments are centered 

on and identify the proposed well location, Site C, in the San Marcos MC 983 Prospect.

Map No. C-1: Bathymetry Map

Map No. C-2: Seafloor Features Map

Map No. C-3: Side-Scan Sonar Mosaic

Map No. C-4: Geologic Features Map

Figure C-1: Regional Rendering of Mississippi Canyon/Atwater Valley Survey Area

Figure C-2: Power Spectrum Analysis Curve, Proposed Site C Well Location

Illustration C-1: Portions of Inline 7828 and Crossline 17305 Showing Conditions Beneath 

Proposed Site C Well Location

Illustration C-2: Tophole Prognosis Chart, Proposed Site C Well Location, Mississippi Canyon, 

Block 983

Illustration C-3: Portion of SBP Lines 120 and 121 Showing Conditions Near Proposed Well C

Figure C-1. Regional Rendering of Mississippi Canyon/Atwater Valley Survey Area

MC 937 MC 938 MC 939 MC 940 MC 941

MC 893 MC 894 MC 895 MC 896 MC 897

MC 981 MC 982 MC 983 MC 984 MC 985

AT 13 AT 14 AT 15 AT 16 AT 17

AT 57 AT 58 AT 59 AT 60 AT 61

C

B

A

Proposed Well Locations

Existing Well Locations

Existing Platform Location

Survey Area

Study Area

Existing Pipeline Locations

Mirage/ Titan

AUV Area
Proposed Well Site C Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 3

FORUM ENERGY TECHNOLOGIES, INC.

NTL Requirements

The following report complies with the Bureau of Ocean Energy Management (BOEM; formerly the MMS) 

Notice to Lessees (NTL’s) 2008-G04, 2008-G05, 2009-G40 (MMS, 2008a, b, and 2010) for geohazard 

assessments. The proposed wellsite must follow NTL 2008-G06 with respect to pre- and post-spud ROV 

surveys because MC 983 lies within environmental assessment grid 14, which has inadequate ROV 

survey coverage (MMS, 2008c).

NTL 2011-JOINT-G07 lists Federal lease Block MC 983 as an archaeologically significant block (BOEM, 

2011); therefore, survey requirements for archaeological assessments as set forth in NTL 2005-G07 

(MMS, 2005) and NTL 2011-JOINT-G07 are necessary. GEMS completed an archaeological assessment 

for the San Marcos survey area (GEMS, 2012).

Power Spectrum. As specified in NTL 2008-G05 (MMS, 2008b), GEMS extracted the power spectrum 

diagram (Figure C-2) from the 3-D seismic data cube provided by Apache at the proposed wellsite. The 

extraction was generated within a 500-ft radius of the intersection of the inline and crossline at the 

proposed wellsite, over a time interval from the seafloor to approximately one-second below the mudline 

(Illustration C-1). We converted the amplitude vs. frequency spectrum, generated by the SMT software, 

to power vs. frequency by squaring the amplitude values as described by J. A. Coffeen, 1978.

Figure C-2. Power Spectrum Analysis Curve, Proposed Site C Well Location

Man-Made Features

MC 984 #1, the nearest existing well to the proposed location, lies approximately 3.4 miles northeast of 

Site C (BOEM, 2012a), see Figure C-1.

The nearest platform, ATP Oil & Gas Corporation’s Titan floating platform, and associated pipelines are 

greater than seven miles to the northeast (Figure C-1).

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

0 10 20 30 40 50 60 70 80 90 100

Power (Amp2

)

Frequency (Hz)

POWER SPECTRUM
Proposed Well Site C Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 4

FORUM ENERGY TECHNOLOGIES, INC.

Table 1 lists the side-scan sonar contacts located within the 9,750 ft anchor radius of the proposed location. 

All eight contacts are interpreted to be modern debris from shipping, lease, ordnance, or storm activities. 

None of these contacts, or any other contact in the San Marcos AUV area, are recommended for 

archaeological avoidance or investigation (GEMS, 2012). Care should be taken near these contacts as the 

Survey Area is just southeast of a discontinued military dumping area.

No side-scan sonar contacts lie within 2,000 ft of the proposed location. Eight Side-Scan Sonar Contacts 

(No’s. 34, 35, 36, 37, 38, 41, 43, and 45) lie within the 9,750 ft anchor radius (Map No. C-4).

Table 1. Sonar Contacts Located Within the 9,750 ft Anchor Radius

No. Block Area Length 

(Feet)

Width 

(Feet)

Height 

(Feet) Shape

X

NAD27

(Feet)

Y

NAD27

(Feet)

34 983 MC 22.09 7.02 0.00 Irregular 925094.25 10159926.31

35 983 MC 8.03 5.04 0.00 Irregular 930038.28 10157676.04

36 984 MC 12.59 3.01 0.00 Linear 936887.60 10157246.16

37 984 MC 24.16 1.00 0.00 Linear 936244.43 10156707.26

38 983 MC 13.56 2.51 0.00 Linear 932735.03 10155709.25

41 983 MC 23.09 8.66 0.00 Irregular 924281.73 10153443.95

43 16 AT 12..05 9.53 0.00 Irregular 936828.27 10152017.60

45 15 AT 26.23 10.03 0.00 Irregular 922498.29 10149452.70

Wellsite Conditions

The proposed surface location is clear of any constraining geologic conditions as defined by the 3-D 

seismic volume and the supplemental AUV data.

Water Depth and Seafloor Conditions. Seafloor conditions are favorable at the proposed well location. 

The water depth at the proposed surface location is approximately -4,366 ft and the seafloor slopes 

southwest at about 0.5° (Map No. C-1). The proposed well location lies along a gently sloping ramp dipping 

to the southwest (Maps No. C-1 and C-2). A surficial drape of normally consolidated very soft clays likely 

covers the seafloor at the location (Illustration C-3).

Deepwater Benthic Communities. The side-scan sonar mosaic shows a homogenous seabed in the 

eastern half of a 2,000 ft benthic avoidance radius around the proposed wellsite, suggesting normal Gulf 

of Mexico surficial sediments (Map No. C-3). The western half of the 2,000 ft avoidance radius appears 

slightly hummocky in the sonar and multibeam data, indicative of buried mass-transport deposits. There 

is no evidence of highly reflective seabed or potential hardgrounds within 2,000 ft of the proposed 

location making the potential for high-density benthic communities negligible.

The 3-D seismic data show elevated seabed amplitudes 726 ft northwest of and 395 ft south of the 

proposed location (Map No. C-4). 3-D seismic data show no evidence of fluid migration associated with 

these amplitudes. The subbottom profiler data along similar nearby features suggest intact sediment 

blocks within the shallow mass-transport deposits are creating the 3-D seismic amplitude increase 

(Illustration C-3). The sonar data show no evidence of hardgrounds associated with the elevated 

amplitudes. There is negligible potential for encountering high-density benthic communities associated 

with the 3-D amplitude anomalies, as the sonar data show no substrate for such communities to attach.

Stratigraphy. Stratigraphic conditions are shown on Illustrations C-1 and C-2. Inline 7828 and Crossline 

17305 are the closest seismic lines to the proposed location (Illustration C-1). The Tophole Prognosis 

Chart (Illustration C-2) shows a portion of Inline 7828, annotated with calculated depths to the various 

horizons and predicted sequence lithology, along with their shallow water flow and shallow gas potential.

The seafloor and near surface sediments at the proposed well location are expected to be a thin 5 ft 

pelagic clay drape overlying a thick unit of clay-rich mass-transport deposits (Illustration C-3). The 
Proposed Well Site C Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 5

FORUM ENERGY TECHNOLOGIES, INC.

stratigraphy in the upper 287 ft bml, above Horizon 10, is dominated by a drape-type facies interbedded 

with fine-grained mass-transport deposits (Illustrations C-2 and C-3).

The interval between Horizon 10 and Horizon 20 (287 ft to 1,093 ft bml) contains interlayered sediments 

that are likely hemipelagic clays and silts, mud rich turbidites, and clay and silt rich mass-transport 

deposits. Thick, continuous sand layers are not expected.

The Horizon 20 to Horizon 30 interval (1,093 ft to 2,362 ft bml) consists of a thin unit of layered deposits 

overlying a thick chaotic unit, which overlies another sequence of layered deposits (Illustrations C-1 and 

C-2). The transition from layered to chaotic is located along a prominent peak reflector at 1,207 ft bml. 

Beneath the peak reflector, rotated beds are likely and may be sand-prone. A prominent peak and 

underlying trough occur at 1,543 ft bml (Illustration C-2). These reflections may represent an erosional 

surface or a continuous sand-prone layer within the mass-transport deposits. The base of the chaotic 

zone occurs at 2,069 ft bml. Thin sand-prone layers may be encountered below 2,069 ft bml to Horizon 

30 at 2,362 ft bml.

The seismic character between Horizon 30 (2,362 ft bml) and 3,063 ft bml consists of well layered 

reflections overlying a thick unit of mass-transport deposits (Illustration C-2). Sand-prone turbidites may 

be encountered in the upper portion of this unit. A thick package of possible sand-prone turbidites is 

located between 3,063 ft bml and Horizon 40 (3,493 ft bml). Continuous sand layers may be encountered 

in this interval.

The sediments between Horizon 40 (3,493 ft bml) and the limit of investigation (5,042 ft bml) consist of a 

thick package of mass-transport deposits overlying layered, continuous to semi-continuous beds 

(Illustration C-2). Rotated beds are apparent within the mass-transport deposits in the upper portion of 

the unit. Thin, continuous sand layers may be encountered in the lower portion of the unit.

Faults. The nearest seafloor fault is located approximately 4,945 ft southeast of the proposed location 

(Map Nos. C-2 and C-4). There are several near-surface faults located approximately 3,200 ft southeast 

of the proposed location (Map No. C-2). These faults are buried by about 5 ft of normally deposited 

sediment suggesting the faults have been inactive in the recent geologic past.

A vertical borehole at the proposed location is not interpreted to intersect any seafloor or buried faults in 

the upper 5,042 ft bml (Illustrations C-1 through C-3).

Shallow Gas and Shallow Water Flow. There is negligible to moderate potential for shallow gas and 

shallow water flow at this well location (Illustration C-2).

Shallow Gas. There are no direct hydrocarbon indicators or apparent subsurface 

high-amplitude anomalies directly below the proposed location (Map No. C-4). The nearest amplitude 

anomaly is located approximately 200 ft south between Horizon 20 (1,093 ft bml) and Horizon 30

(2,362 ft bml). We rate the sand-prone intervals from 1,207 ft to 2,069 ft bml, 2,362 ft to 2,553 ft bml, and 

3,063 ft to 3,493 ft bml as having moderate potential for shallow gas (Illustration C-2). These intervals 

are sand prone and may contain biogenic gas at pressures greater than hydrostatic.

A low potential for shallow gas accumulation occurs from 2,069 ft to 2,362 ft bml, 2,553 ft to 3,063 ft bml,

and from 3,493 ft bml to the limit of investigation at 5,042 ft bml (Illustration C-2). Thin sands may be 

encountered in these units. The potential for shallow gas accumulation is considered negligible in the 

clay-rich sediments between the seafloor and 1,207 ft bml.

Shallow Water Flow. The potential for encountering shallow water flow at this well location is 

negligible to moderate (Illustration C-2). The following table lists nearby wells that have and have not had 

shallow water flow issues (BOEM, 2012b).
Proposed Well Site C Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 6

FORUM ENERGY TECHNOLOGIES, INC.

Table 2. Shallow Water Flow in Nearby Wells

Well Block Flow 

Strength

Depth 

bml (ft)

Well 

Integrity

Distance / Direction from 

Proposed Location

#1 MC 984 No SWF N/A N/A 3.4 miles northeast

#1 MC 940 No SWF N/A N/A 3.7 miles northeast

#1 MC 941 Low 991 Yes 7.2 miles northeast

#1 MC 937 Strong 2,424 Lost 7.3 miles northwest

The sand-prone sediments from 1,207 ft to 2,069 ft bml, 2,362 ft to 2,553 ft bml, and 3,063 ft to 3,493 ft 

bml have moderate potential for shallow water flow (Illustration C-2). Continuous, overpressured sand 

layers may be encountered within these units. As a result of numerous mass-wasting events in the 

region’s geologic past, it is likely these sand-prone sediments were rapidly buried and sealed by clay-rich 

overburden. The intervals from 2,069 ft to 2,362 ft bml, 2,553 ft to 3,063 ft bml, and 3,493 ft bml to the 

limit of investigation (5,042 ft bml) have low potential for shallow water flow. Thin sands may be 

encountered in these units. The remaining clay-rich section between the seafloor and 1,207 ft bml has 

negligible potential for shallow water flow.

Anchoring Considerations

The 9,750 ft radius outlined on Map Nos. C-1 through C-4 represents the area of potential effect for 

anchoring. The radius is the basis for clearance of seafloor conditions related to anchoring 

considerations. An additional 1,000-ft buffer zone is also included.

Water depths within the potential mooring area range from about -4,170 ft to -4,530 ft (Map No. C-1). The 

shallowest water depths are located along the northeastern portion of the mooring radius. The deepest 

water depths occur within the southeastern portion of the mooring radius. In general, the seafloor slopes 

southwest within the anchor radius.

Gradients are generally less than 5° within the mooring radius (GEMS, 2012). Steep gradients, up to 15°, 

occur locally along faults in the eastern portion of the mooring radius. Gradients up to 10° to 15° are 

evident within an area hummocky seafloor in the northwestern, central, and southern portions of the 

mooring radius.

The seabed topography is generally smooth in the northeastern quadrant of the mooring radius (Map 

No. C-2). The seabed is hummocky in the northern, central, and southern portions of the anchor circle. 

Several seafloor faults are evident within the eastern portion of the mooring radius (Map Nos. C-2 and 

C-4).

There are no areas of highly reflective seafloor identified on the side-scan sonar data, suggesting the 

potential for encountering hardgrounds and high-density benthic communities is negligible (Map No. C-3). 

The 3-D seismic data show areas of elevated seabed amplitude in the western portion of the anchor circle 

(Map No. C-4). There is no evidence of fluid migration on the 3-D seismic data associated with these 

amplitudes. The subbottom profiler data along similar nearby features suggest intact sediment blocks 

within the shallow mass-transport deposits are creating the amplitude increase in the 3-D seismic data 

(Illustration C-3). The sonar data show no evidence of hardgrounds associated with the features. There 

is negligible potential for encountering high-density benthic communities associated with these amplitude 

anomalies throughout the mooring area, as the sonar data show there is no hard substrate for any such 

communities to attach. Two patches with low potential of supporting high-density communities exists at 

the southern extreme of the 1,000 ft buffer zone (Map No. C-3 and Illustration C-3).
Proposed Well Site C Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 7

FORUM ENERGY TECHNOLOGIES, INC.

Closing

The proposed Site C well location, in Mississippi Canyon Block 983, appears suitable for drilling 

operations. We advise using caution while drilling through the sand-prone intervals from 1,207 ft to 

2,069 ft bml, 2,362 ft to 2,553 ft bml, and 3,063 ft to 3,493 ft bml, as overpressures may occur within 

coarse-grain sediments within these intervals.

Care should be taken near the sonar contacts within the mooring radius as the Survey Area is just 

southeast of a discontinued military dumping area.

We appreciate the opportunity to be of service to Apache Deepwater LLC and look forward to working 

with Apache on future projects.

Sincerely,

GEOSCIENCE EARTH & MARINE

SERVICES, INC.®

Christopher Madere Daniel Lanier

Senior Geoscientist Vice President-Geosciences

Kimberly L. Faulk

Senior Marine Geologist

Attachments (4 Maps and 3 Illustrations)

Distribution:

Mr. John Worthen, Apache Deepwater LLC (5 copies)
Proposed Well Site C Clearance Letter

Apache Deepwater LLC // January 28, 2013

Geoscience Earth & Marine Services, Inc. ® // 8

FORUM ENERGY TECHNOLOGIES, INC.

REFERENCES

Bureau of Ocean Energy Management, 2012a, ASCII data files, published on the BOEM Gulf of Mexico Region website, 

<www.data.boem.gov/homepg/data_center/mapping/geographic_mapping.asp>, Accessed September, 2012.

Bureau of Ocean Energy Management, 2012b, Safety performance review – shallow water flows can pose significant 

hazards to deepwater drilling, published on the BOEM Gulf of Mexico Region website, 

<www.boem.gov/uploadeFiles/BOEM/Oil_and_Gas_Energy_Program_Resource_Evaluation/Geological_and_Geophysical_

Reviews/SWF2011.pdf>, Accessed October, 2012.

BOEM (Bureau of Ocean Energy Management), 2011, Notice to lessees and operators (NTL) of federal oil and gas leases 

and pipeline right-of-way (ROW) holders on the outer continental shelf (OCS), Revisions to the list of OCS lease blocks 

requiring archaeological resource surveys and reports: U. S. Department of the Interior, Bureau of Ocean Energy 

Management, Bureau of Safety and Environmental Enforcement Gulf of Mexico Region (GOMR), NTL 2011-JOINT-G01. 

Effective Date December 29, 2011.

Coffeen, J. A., 1978, Seismic Exploration Fundamentals: Tulsa, the Petroleum Publishing Co., p. 125.

Geoscience Earth & Marine Services, Inc.®(GEMS), 2012, Geohazard assessment, San Marcos Prospect, block 983 (OCSG-34468), Mississippi Canyon Area, Gulf of Mexico, Project No. 0712-2115b.

Minerals Management Service, 2005, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, Archaeological resource surveys and reports: 

U. S. Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2005-G07.

Minerals Management Service, 2008a, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, information requirements for exploration plans 

and development operations coordination documents: U. S. Department of the Interior, Minerals Management Service, Gulf 

of Mexico, NTL 2008-G04.

Minerals Management Service, 2008b, Notice to lessees and operators of federal oil, gas, and sulphur leases and pipeline 

right-of-way holders in the outer continental shelf, Gulf of Mexico OCS region, shallow hazards requirements: U. S. 

Department of the Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G05.

Minerals Management Service, 2008c, Notice to lessees and operators of federal oil, gas, and sulphur leases in the outer 

continental shelf, Gulf of Mexico OCS region; remotely operated vehicle surveys in deepwater, U. S. Department of the 

Interior, Minerals Management Service, Gulf of Mexico, NTL 2008-G06.

Minerals Management Service, 2010, Notice to lessees and operators of federal oil and gas leases in the outer continental 

shelf, Gulf of Mexico OCS region, deepwater benthic communities: U. S. Department of the Interior, Minerals Management 

Service, Gulf of Mexico, NTL 2009-G40. Effective Date January 27, 2010.




MC

983

AT

15

STUDY AREA

MC

984

25000 30000 35000

1.700

1.800

1.900

2.000

2.100

2.200

2.300

2.400

2.500

2.600

2.700

2.800

2.900

3.000

3.100

3.200

3.300

3.400

35000 40000 45000

1.700

1.800

1.900

2.000

2.100

2.200

2.300

2.400

2.500

2.600

2.700

2.800

2.900

3.000

3.100

3.200

3.300

3.400

NORTHWEST SOUTHEAST

Project No. 0712-2115b Filename: 122115b_Illustration_C-1.cdr

Illustration C-1. Portions of Inline 7828 and Crossline 17305 Showing Conditions Beneath Proposed Site C Well Location

INLINE 7828

SOUTHWEST NORTHEAST PROPOSED WELLSITE C TWO-WAY TRAVEL TIME (SEC) TWO-WAY TRAVEL TIME (SEC)

PROPOSED WELLSITE C

Horizontal

Distance (ft):

Horizontal

Distance (ft):

CROSSLINE 17305

Seafloor

CHAOTIC ZONE

Horizon 10

Horizon 2 Horizon 20

Horizon 3 Horizon 30

Horizon 4 Horizon 40

Seafloor

Horizon 1 Horizon 10

Horizon 30

Horizon 40

Horizon 2 Horizon 20

CHAOTIC ZONE

RELATIVE AMPLITUDE

Peak

Trough

MC

983

AT

16

AT

15

CHAOTIC ZONE

STUDY AREA

CHAOTIC ZONE
MC

983

STUDY AREA

37500 40000

1.7001.8001.9002.0002.1002.2002.3002.4002.5002.6002.7002.8002.9003.0003.1003.2003.3003.400

WATER

FLOW AND

GAS

POTENTIAL

Shallow Water Flow and Gas Potential

HIGH

0 1 2 3

NEGLIGIBLE

Horizon Lithology/Stratigraphy

Illustration C-2. Tophole Prognosis Chart, Proposed Site C Well Location, Mississipp

Project No. 0712-2115b 

Water

Flow

Gas

3-D Seismic Section Through

Proposed Wellsite C

X = 929,504 ft

Y = 10,155,547 ft

NW SE

Horizon

TWT

(sec, bsl)

Depth

(ft, bml)

INLINE 7828

TWO-WAY TIME TRAVEL (SEC)

3.430

2.972

Proposed

Wellsite C

Distance (ft):

Horizontal

Low po

SEAFLOOR -4,366

Negligi

2.615 -6,728 2,362

HORIZON 10HORIZON 20INTERFACEINTERFACEINTERFACEINTERFACEHORIZON 40HORIZON 30

LIMIT OF

INVESTIGATION

1.871

2.1792.2202.3392.5182.677

1.759

-4,653

-5,459

-5,573

-5,909-6,435-6,919

-7,859

-9,408

287

1,093

1,207

1,5432,0692,553

3,4935,042

Pelagic clay drape overlying bedded hemipelagic clay andfine grained muddy turbidites or mud flows.

Layered hemipelagic clay-rich section.Bedded hemipelagic clay-rich interval with fine grainedturbidite and mass-transport deposits at base of unit. Thinsands possible.Interface marks top of sand-prone unit. Beds in middle ofsection appear slightly rotated.Chaotic and discontinuous hemipelagic clay interval withmuddy turbidites interbedded with clay, silt, and sand masstransport deposits.

Modera

INTERFACE 2.839 -7,429 3,063

Low poModera

Interface marks top of elevated amplitude reflectors,suggesting an increase in sand content.Thick package of elevated amplitude reflectors, suggestingbedded, sand-prone turbidites.Clay, silt, and sand prone mass-transport deposits. Rotatedbeds appear probable.Generally clay-rich, layered deposits with some thin sandseams possible.

0 = NEGLIGIBLE

1 = LOW2 = MODERATE

3 = HIGH

Depth

(ft, bsl)*

Modera

Package of slightly elevated amplitude reflectors, suggesting bedded, sand-prone turbidites.Layered hemipelagic clays and silts and mud rich turbiditesinterbedded with clay and silt rich mass-transport deposits.Clay and silt-rich mass-transport deposits between 445 ftand 584 ft below mudline.
12000 13000 14000 15000 16000 17000

1.760

1.770

1.780

1.790

1.800

1.810

1.820

1.830

12000 13000 14000 15000 16000 17000

1.760

1.770

1.780

1.790

1.800

1.810

1.820

1.830

WELL B

WELL A

WELL C

3-D SEABED

ANOMALY

MC

983

N

SBP LINE 121

SBP LINE 120

0 FT 500 FT 1,000 FT 1,500 FT

MISSISSIPPI CANYON AREA

ATWATER VALLEY AREA

WEST EAST

Project No. 0712-2115b Filename: 122115b_Illustration_C-1.cdr

Illustration C-3. Portion of SBP Lines 120 and 121 Showing Conditions Near Proposed Well C

PORTION OF SBP LINE 121

WEST EAST PROPOSED WELLSITE C

(~115 FT TO SOUTH)

TWO-WAY TRAVEL TIME (SEC) TWO-WAY TRAVEL TIME (SEC)

PROPOSED WELLSITE C

(~540 FT TO NORTH)

Distance (ft):

Distance (ft):

SEAFLOOR SEAFLOOR

SEAFLOOR

RELATIVE AMPLITUDE

Peak

Trough

MC

983

MC

983

SIDE-SCAN SONAR DATA SHOW NO

EVIDENCE OF HARDGROUNDS WITHIN

2,000 FT OF THE PROPOSED LOCATION

MTD

INTACT BLOCKS

ALIGN WITH 3-D

SEABED ANOMALIES

{ { } }

MASS-TRANSPORT DEPOSITS APPEAR

CLAY-RICH NEAR PROPOSED WELLSITE

PORTION OF SIDE-SCAN SONAR MOSAIC

MTD

MTD

PORTION OF SBP LINE 120

{ }

MTD

INTACT BLOCKS

ALIGN WITH 3-D

SEABED ANOMALIES

{ }

MTD

MTD

~25 FT

~25 FT
Apache Deepwater LLC	 	 Page D‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION D 

HYDROGEN SULFIDE (H2S) INFORMATION 

(30 CFR 550.215 and 550.245) 

A. CONCENTRATION

Apache Deewpater LLC does not anticipate encountering any H2S during the proposed 

operations. 

The closest wells to the proposed locations and in the same mini-basin are the Anadarko/Shell 

OCS-G-22919 wells in MC 984 001, 001 BP01, 001 BP02 and 001 ST01 for which the surface 

location is about 3 miles from the proposed locations MC983 A, B and C. Anadarko/Shell did 

not report any occurrences of H2S. The closest known occurrence of H2S is over 12 miles to the 

north in MC 807 where Shell reported 11ppm. There have not been any reports of H2S from 

nearby closer wells nor as far south in Mississippi Canyon Block 983 and therefore Apache does 

not expect H2S at any of the proposed locations. 

B. CLASSIFICATION

In accordance with Title 30 CFR 250.490(c), Apache Deepwater requests that Mississippi 

Canyon Block 983 be classified by the BOEM as H2S absent. 
Apache Deepwater LLC	 	 Page E‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION E 

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION 

(30 CFR 550.216 and 550.247) 

A. DEEPWATER BENTHIC/CHEMOSYNTHETIC COMMUNITIES

This EP does propose activities that could disturb seafloor areas in water depths of 300 meters 

(984 feet) or greater; therefore in compliance with Attachment A of NTL No. 2009-G40, 

“Deepwater Benthic Communities”, information is included in the Site Clearance Letters and the 

Addendum to the Geologic and Stratigraphic Assessment as submitted in conjunction with this 

plan. (Reference Section C, Attachment C-4) 

Included in the Geologic and Stratigraphic Assessment submitted in conjunction with this plan, 

are Maps using 3-D seismic data depicting seafloor and shallow geological features and areas 

and an analysis regarding Mississippi Canyon Block 983 pertaining to this EP. 

B. TOPOGRAPHIC FEATURES MAP

This EP’s proposed activities do not fall within 305 meters (1,000 feet) of a topographic “no 

activity zone”. 

C. TOPOGRAPHIC FEATURES STATEMENT (SHUNTING)

All activities proposed under this EP will be conducted outside all Topographic Feature 

Protective Zones, therefore shunting of drill cuttings and drilling fluids is not required. 

D. LIVE BOTTOMS (PINNACLE TREND) MAP

Mississippi Canyon Block 983 is not located within 61 meters (200 feet) of any pinnacle trend 

feature; therefore a separate bathymetric map is not required. 

E. LIVE BOTTOMS (LOW RELIEF) STIPULATION

Mississippi Canyon Block 983 is not located within 30 meters (100 feet) of any pinnacle trend 

feature vertical relief equal to or greater than 8 feet; therefore, live bottom (low relief) maps are 

not required. 

F. POTENTIAL SENSITIVE BIOLOGICAL FEATURES

Mississippi Canyon Block 983 is not located within 30 meters (100 feet) of potentially sensitive 

biological features; therefore, biologically sensitive area maps are not required. 

G. REMOTELY OPERATED VEHICLE (ROV) SURVEYS 

Based on the data acquired in the AUV Arch survey, BOEM has determined that there is enough 

data gathered in this grid area, therefore, we are not required to run any ROV surveys either prespudding or post-drilling operations. 
Apache Deepwater LLC	 	 Page E‐2

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

H. THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT AND 

MARINE MAMMAL INFORMATION

Under Section 7 of the Endangered Species Act (ESA) all federal agencies must ensure that any 

actions they authorize, fund or carry out are not likely to jeopardize the continued existence of a 

listed species, destroy or adversely modify its designated critical habitat. 

In accordance with the 30 CFR 250, Subpart B, effective May 14, 2007, and further outlined in 

Notice to Lessees (NTL) 2008-G04, lessees/operators are required to address site-specific 

information on the presence of federally listed threatened or endangered species and critical 

habitat designated under the ESA and marine mammals protected under the Marine Mammal 

Protection Act (MMPA) in the area of proposed activities under this plan. 

NOAA Fisheries currently lists the Sperm Whale, Leatherback Turtle, Green Turtle, Hawksbill, 

Turtle and the Kemp’s Ridley Turtle as endangered and the Loggerhead Turtle and Gulf 

Sturgeon as threatened. Currently there are no designated critical habitats for the listed species 

in the Gulf of Mexico Outer Continental Shelf; however, it is possible that one or more of these 

species could be seen in the area of our operations. 

The Environmental Impact Analysis in “Section O” of this plan further discusses potential 

impacts and mitigation measures related to threatened and endangered species. 

I. ARCHAEOLOGICAL REPORT

As per NTL 2011-JOINT-G01, an Archaeological Report (AUV) is submitted to comply with 

NTL requirements. No potential submerged cultural resources were discovered in the Mississippi 

Canyon Block 983 survey area. This area does not have any historic or prehistoric cultural 

resources. 
Apache Deepwater LLC	 	 Page F‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION F 

WASTES AND DISCHARGES INFORMATION 

(30 CFR 550.217 and 550.248) 

A. PROJECTED GENERATED WASTES

Wastes you will generate, treat and downhole dispose or discharge to the GOM, are included in 

this section as Attachment F-1. 
ATTACHMENT F-1

Blowout prevent fluid

Stackmagic 200/0/5% glycol 

based on 2% mixture with 

potable water

143 bbls/well 12 bbls 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 bbls/well 57 bbl/hr/well Cuttings chute

Will you be covered by an individual or general NPDES permit:

General - NPDES ID GMG290388

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 

Cooling water Seawater with no addition of 

chemicals 3,600,000 bbls/well 1,667 bbl/hr/well Discharged overboard

Firewater Seawater with no addition of 

chemicals

N/A N/A Discharged overboard

Excess cement at seafloor Cement slurry 900 bbls/well 19 bbl/hr/well Discharged at the mudline during 

cementing conductor casing

Ballast water Uncontaminated seawater used 

to maintain proper draft 19,710 bbls/well 9 bbl/hr/well Discharged overboard

Bilge Water Bilge water 216 bbls/well 0.1 bbl/hr/well Discharged overboard

N/A N/A 

Well completion fluids N/A N/A N/A N/A 

Will you conduct well treatment, completion or workover? If yes, only fill in those associated with your activity

Well treatment fluids N/A N/A N/A N/A 

Workover fluids N/A N/A 

Is there a deck? If yes, there will be Deck Drainage

Deck Drainage Platform washings and 214 bbls/well 0.1 bbl/hr/well Oily water is treated in Oily Water 

Domestic waste Gray water (laundry, galley, 

lavatory) 10,750 bbls/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 10,750 bbls/well 5 bbl/hr/well USCG approved MSD

Will humans be there? If yes, expect conventional waste

EXAMPLE: Sanitary waste water Sanitary waste from living 

quarters

X bbl/well X bbl/hr /well Chlorinate & discharge overboard

Cuttings wetted with synthetic-based fluid Synthetic based drilling fluid 2,500 bbls/well 50 bbls/day/well Discharged thru shunt pipe to 25' below 

water's surface

Cuttings wetted with water-based fluid Cuttings coated with water 

based drilling mud 1,000 bbls/well 250 bbls/day/well

Water-based Drilling Fluids Water based drilling fluid 40,000 bbls/well 10,000 

bbls/day/well

Discharged at mudline prior to BOP and 

riser installation

Discharged at mudline prior to BOP and 

riser installation

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

EXAMPLE: Cuttings wetted with synthetic based 

fluid

Cuttings generated while 

using synthetic based drilling 

fluid

X bbl/well X bbl/day /well Discharge overboard

Type of Waste Composition Projected Amount Discharge Rate Discharge Method
Apache Deepwater LLC	 	 Page G‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION G 

AIR EMISSIONS INFORMATION 

(30 CFR 550.218 and 550.249) 

A. SCREENING QUESTIONS

Screen Procedures 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 emissions 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 

A. EMISSIONS WORKSHEETS

Air emission worksheets have been prepared using Semisubmersible and DP Semisubmersible 

drilling units. Air emission worksheets are available upon request. Per NTL No. 2008-G04, if 

an operator answers “no” to all of the above screening questions from the appropriate table, 

provide the following: 

Summary information regarding the peak year emissions that will be generated by and associated 

with your Plan Emissions and Complex Total Emissions which is compiled on the summary 

form of the two sets of worksheets or in the format below. The entire set of worksheets does not 

need to be included. 

If drilled with a Semisubmersible: 

Air Pollutant Plan Emission 

Amounts1 (tons) 

Calculated Exemption 

Amounts2 (tons) 

Carbon Monoxide (CO) 197.24 55527.51 

Particular Matter (PM) 26.30 2197.80 

Sulphur Dioxide (SO2) 120.64 2197.80 

Nitrogen Oxides (NOx) 904.00 2197.80 

Volatile Organic Compounds (VOC) 27.12 2197.80 
Apache Deepwater LLC	 	 Page G‐2

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

If drilled with a DP Semisubmersible: 

Air Pollutant Plan Emission 

Amounts1 (tons) 

Calculated Exemption 

Amounts2 (tons) 

Carbon Monoxide (CO) 453.31 55527.51 

Particular Matter (PM) 60.44 2197.80 

Sulphur Dioxide (SO2) 277.28 2197.80 

Nitrogen Oxides (NOx) 2077.69 2197.80 

Volatile Organic Compounds (VOC) 62.33 2197.80 

1

For activities proposed in your EP, list the projected emissions calculated from the worksheets. 

2

List the exemption amounts for your proposed activities calculated by using the formulas in 30 CFR 250.303(d). 

This information was calculated by: 

Terri Young 

EH&S Specialist II – Regulatory 

(731) 296-7456 

Terri.young@apachecorp.com
EXPLORATION PLAN (EP)

AIR QUALITY SCREENING CHECKLIST

OMB 

COMPANY APACHE DEEPWATER LLC

AREA Mississippi Canyon

BLOCK 983

LEASE OCS-G 34468PLATFORMWELL A, B & C

COMPANY CONTACT Terri YoungTELEPHONE NO. 713-296-7456

REMARKS

Type of Rig Max HP

Drillship 61,800DP Semisubmersible 61,200 Semisubmersible 26,400 Submersible 6,064Jack-up 16,975Platform/Barge 6,635

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

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

APACHE DEEPWATER LLC Mississippi Canyon 983 OCS-G 34468 A, B & C Terri Young 713-296-7456 Total Days

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 S

DRILLING PRIME MOVER>600hp diesel 26400 1275.12 30602.88 24 116 18.61 85.36 639.65 19.19 139.56 25.90 11

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 34 1.46 6.68 50.03 1.50 10.92 0.15 0VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 34 1.46 6.68 50.03 1.50 10.92 0.25 1VESSELS>600hp diesel(tugs) 0 0 0.00 18 0 0.00 0.00 0.00 0.00 0.00 0.00 0

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

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

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 0WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0

2013 YEAR TOTAL 21.52 98.72 739.71 22.19 161.39 26.30 12

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2197.80 21

66.0

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 3 of 8
EMISSIONS CALCULATIONS 2ND YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

APACHE DEEPWATER Mississippi Canyon 983 OCS-G 34468 A, B & C Terri Young 713-296-7456 Total Days

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 S

DRILLING PRIME MOVER>600hp diesel 26400 1275.12 30602.88 24.00 116.00 18.61 85.36 639.65 19.19 139.56 25.90 11

PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6.00 34.00 1.46 6.68 50.03 1.50 10.92 0.15 0VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10.00 34.00 1.46 6.68 50.03 1.50 10.92 0.25 1VESSELS>600hp diesel(tugs) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0

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

VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0MISC. 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 0WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0

2014 YEAR TOTAL 21.52 98.72 739.71 22.19 161.39 26.30 12

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2197.80 21

66.0

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 4 of 8
EMISSIONS CALCULATIONS 3RD YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

APACHE DEEPWATER Mississippi Canyon 983 OCS-G 34468 A, B & C Terri Young 713-296-7456 Total Days

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 S

DRILLING PRIME MOVER>600hp diesel 26400 1275.12 30602.88 24 116 18.61 85.36 639.65 19.19 139.56 25.90 11

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 34 1.46 6.68 50.03 1.50 10.92 0.15 0VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 34 1.46 6.68 50.03 1.50 10.92 0.25 1VESSELS>600hp diesel(tugs) 0 0 0.00 18 0 0.00 0.00 0.00 0.00 0.00 0.00 0

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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 

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

2015 YEAR TOTAL 21.52 98.72 739.71 22.19 161.39 26.30 12

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2197.80 21

66.0

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 5 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELLAPACHE DEEPWATER LLC Mississippi Canyon 983 OCS-G 34468 A, B & C

Emitted Substance

Year

 PM SOx NOx VOC C

2013 26.30 120.64 904.00 27.12 1972014 26.30 120.64 904.00 27.12 1972015 26.30 120.64 904.00 27.12 197

Allowable 2197.80 2197.80 2197.80 2197.80 5552

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

AIR QUALITY SCREENING CHECKLIST

OMB 

COMPANY APACHE DEEPWATER LLC

AREA Mississippi Canyon

BLOCK 983

LEASE OCS-G 34468PLATFORMWELL A, B & C

COMPANY CONTACT Terri YoungTELEPHONE NO. 713-296-7456

REMARKS

Type of Rig Max HP

Drillship 61,800DP Semisubmersible 61,200 Semisubmersible 26,400 Submersible 6,064Jack-up 16,975Platform/Barge 6,635

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

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

APACHE DEEPWATER LLC Mississippi Canyon 983 OCS-G 34468 A, B & C Terri Young 713-296-7456 Total Days

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 S

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24 116 43.14 197.89 1482.82 44.48 323.52 60.05 27

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 34 1.46 6.68 50.03 1.50 10.92 0.15 0VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 34 1.46 6.68 50.03 1.50 10.92 0.25 1VESSELS>600hp diesel(tugs) 0 0 0.00 18 0 0.00 0.00 0.00 0.00 0.00 0.00 0

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

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

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 0WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0

2013 YEAR TOTAL 46.05 211.24 1582.89 47.49 345.36 60.44 27

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2197.80 21

66.0

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 3 of 8
EMISSIONS CALCULATIONS 2ND YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

APACHE DEEPWATER Mississippi Canyon 983 OCS-G 34468 A, B & C Terri Young 713-296-7456 Total Days

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 S

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24.00 116.00 43.14 197.89 1482.82 44.48 323.52 60.05 27

PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6.00 34.00 1.46 6.68 50.03 1.50 10.92 0.15 0VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10.00 34.00 1.46 6.68 50.03 1.50 10.92 0.25 1VESSELS>600hp diesel(tugs) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0

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

VESSELS>600hp diesel(crew) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(supply) 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0MISC. 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 0WELL TEST GAS FLARE 0 0 0 0.00 0.00 0.00 0.00 0

2014 YEAR TOTAL 46.05 211.24 1582.89 47.49 345.36 60.44 27

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2197.80 21

66.0

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 4 of 8
EMISSIONS CALCULATIONS 3RD YEAR

COMPANY AREA BLOCK LEASE PLATFORM WELL CONTACT PHONE REMARKS

APACHE DEEPWATER Mississippi Canyon 983 OCS-G 34468 A, B & C Terri Young 713-296-7456 Total Days

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 S

DRILLING PRIME MOVER>600hp diesel 61200 2955.96 70943.04 24 116 43.14 197.89 1482.82 44.48 323.52 60.05 27

PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0PRIME MOVER>600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0BURNER diesel 0 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0AUXILIARY EQUIP<600hp diesel 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(crew) 2065 99.7395 2393.75 6 34 1.46 6.68 50.03 1.50 10.92 0.15 0VESSELS>600hp diesel(supply) 2065 99.7395 2393.75 10 34 1.46 6.68 50.03 1.50 10.92 0.25 1VESSELS>600hp diesel(tugs) 0 0 0.00 18 0 0.00 0.00 0.00 0.00 0.00 0.00 0

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

VESSELS>600hp diesel(crew) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0VESSELS>600hp diesel(supply) 0 0 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0MISC. BPD SCF/HR COUNT

TANK- 0 0 0 0.00 

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

2015 YEAR TOTAL 46.05 211.24 1582.89 47.49 345.36 60.44 27

EXEMPTION 

CALCULATION

DISTANCE FROM LAND IN 

MILES 2197.80 21

66.0

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 5 of 8
SUMMARY

COMPANY AREA BLOCK LEASE PLATFORM WELLAPACHE DEEPWATER LLC Mississippi Canyon 983 OCS-G 34468 A, B & C

Emitted Substance

Year

 PM SOx NOx VOC C

2013 60.44 277.28 2077.69 62.33 4532014 60.44 277.28 2077.69 62.33 453

2015 60.44 277.28 2077.69 62.33 453

Allowable 2197.80 2197.80 2197.80 2197.80 5552

FORM BOEM-0138 (December 2011 - Supersedes all previous versions of this form which may not be used). Page 8 of 8
Apache Deepwater LLC	 	 Page H‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION H 

OIL SPILLS INFORMATION 

(30 CFR 250.219 and 250.250) 

A. OIL SPILL RESPONSE PLANNING

All proposed activities and facilities in this Revised EP will be covered by the Regional OSRP (0-685) 

filed by Apache Deepwater LLC, (company number 03165) in accordance 30 CFR 254, NTL 2006-G21, 

NTL 2007-N04 and NTL 2008-G17 and includes information required by the Bureau of Ocean Energy 

Management (BOEM). The initial OSRP and further modifications were approved as of April 18, 2013. 

B. SPILL RESPONSE SITES

Primary Response Equipment Location Preplanned Staging Location 

Houma, Louisiana Houma, Louisiana 

Venice, Louisiana Venice, Louisiana 

C. OSRO INFORMATION

Apache Deepwater’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. 

In addition Apache Deepwater LLC has contracted with National Response Corporation (NRC), Marine 

Spill Response Corporation (MSRC) and Oil spill Response Limited (OSRL) for additional equipment 

and personnel. Apache Deepwater LLC is also a member of the Marine Well Containment Company 

(MWCC) and the Helix Well Containment Group (HWCG). These agreements allow access to the subsea 

well containment and well shut-in equipment. 

D. WORST-CASE SCENARIO COMPARISON

Category Regional OSRP - WCD EP - WCD 

Type of Activity Drilling Drilling 

Facility Location (Area/Block) MC 983 MC 983 

Facility Designation Well Location A Well Location A 

Distance to Nearest Shoreline (miles) 66 66 

Volume - Uncontrolled blowout - Total Volume 475,731 475,731 

Type of Oil(s) (crude, condensate, diesel) Crude Crude 

API Gravity 33 33 

Apache Deepwater LLC has determined that the worst-case scenario from the activities in this EP does 

not supersede the worst-case scenario from our approved Regional OSRP. Apache Deepwater LLC 

hereby certifies it 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. 

E. SPILL RESPONSE DISCUSSION FOR NEPA ANALYSIS

Spill Response Discussion is included in this section as 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 475,731 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 BSEE Oil Spill Risk Analysis Model (OSRAM) for the Central and 

Western Gulf of Mexico available on the BSEE website. The results are shown in Figure 1. The 

BSEE OSRAM identifies a 8% 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

Apache Deepwater LLC 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 14% or 

approximately 66,602 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 409,129 barrels remaining. 

Spill Response MC 983, Well Location A Barrels of Oil 

WCD Volume 475,731 

Less 14% natural evaporation/dispersion 66,602 

Remaining volume 409,129 

Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary 

storage equipment available to respond to a spill of approximately 409,129 barrels. 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. 

Apache Deepwater LLC’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 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 a variety of CGA, MSRC, and NRCC equipment, with a total derated skimming 

capacity of 935,182 barrels. Temporary storage associated with skimming equipment equals 

348,944 barrels. If additional storage is needed, an 80,000 barrel storage barge, an 83,937 barrel 

storage barge, and four 107,285 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, 

MSRC’s, and NRCC’s near shore and shallow water skimmers with a totaled derated skimming 

capacity of 230,695 barrels. Temporary storage associated with skimming equipment equals 

6,890 barrels. If additional storage is needed, an 86,948 barrel storage barge, a 25,000 barrel 

storage barge, three 20,000 barrel storage barges, 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. Onshore response may include the deployment of 

shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. Master 

Service Agreements with 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. Apache 

Deepwater LLC’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, Apache Deepwater LLC 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 83 hours (based on the equipment’s Effective Daily Recovery Capacity 

(EDRC)). 
Initial Response Considerations 

Actual actions taken during an oil spill response will be based on many factors which include but 

are not limited to: 

• Weather 

• Equipment and materials availability 

• Ocean currents and tides 

• Location of the spill 

• Product spilled 

• Amount spilled 

• Environmental risk assessments 

• Trajectory and product analysis 

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

Apache Deepwater LLC 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. 

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 

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 

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 

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 

MSRC Oil Spill Response Vessels (OSRV) 

• Use in areas with heaviest oil concentrations 

• Use as far off-shore as allowed 
MSRC Responders 

• Use in areas with heaviest oil concentrations 

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

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 Apache Deepwater LLC’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 

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 
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 Apache Deepwater LLC’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 
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 
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 
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. 
FIGURE 1 

TRAJECTORY BY LAND SEGMENT 

Trajectory of a spill and the probability of it impacting a land segment have been projected 

utilizing Apache Deepwater LLC’s WCD and information in the BSEE Oil Spill Risk 

Analysis Model (OSRAM) for the Central and Western Gulf of Mexico available on the 

BSEE 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 

Exploratory Drilling 

MC 983, 

Well Location A 

66 miles from shore 

G34468 C58 Galveston, TX 

Jefferson, TX 

Cameron, LA 

Vermilion, LA 

Iberia, LA 

Terrebonne, LA 

Lafourche, LA 

Jefferson, LA 

Plaquemines, LA 

St. Bernard, LA 

Okaloosa, FL 

1 

1 

3 

2 

1 

3 

3 

1 

8 

1 

1 
WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (66 miles from sh

409,129 bbls of crude oil (Volume considering natural weathering) API Gravity 33° 

FIGURE 2 – Equipment Response Time to MC 983, Well Location A 

Dispersants/Surveillance 

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

CGA

Basler 67T 2000 NA 2 Houma 1 1 0.8 

ASI 

DC 3 1200 NA 2 Houma 1 1 1 DC 3 1200 NA 2 Houma 1 1 1 Aero Commander NA NA 2 Houma 1 1 0.8 

Offshore Response 

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 8 Harvey 7 0 5 

T&T Marine (available through direct contract with CGA) 

Koseq Skimming Arms (5) 89145 10000 5 Utility 30 Galveston 24 24 1 Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 24 24 2 Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 24 24 2 Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 24 24 1 

Recovered Oil Storage PreDetermined Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure Hrs to Loadout Hrs to GOM T

S

K-Sea Operating (available through contract with CGA) 

PACIFIC 996165 NA 80000 1 Tug 6 Venice 4 12 2 DBL 76 1212984 NA 83937 1 Tug 6 Venice 4 12 2 DBL 101 1119760 NA 107285 1 Tug 6 Venice 4 12 2 DBL 102 1146491 NA 107285 1 Tug 6 Venice 4 12 2 DBL 103 1170633 NA 107285 1 Tug 6 Venice 4 12 2 DBL 104 1193787 NA 107285 1 Tug 6 Venice 4 12 2 
Offshore Equipment 

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

MSRC 

Louisiana Responder LFF 100 Brush + OSRV 2,640’ 44” Sea Sentry II Boom 5,280’ 67” LAMOR 

18086 4000 NA 14 Fort Jackson 2 0 1 

MSRC 452 Offshore Barge 1 Crucial Disk 88/30 1,980’ 44” Sea Sentry II Boom 660 ‘ 67” LAMOR 

11122 45000 3 Tugs 6 Fort Jackson 2 0 2 

Mississippi Responder Transrec 350 + OSRV 5,280’ 44” Sea Sentry II Boom 2,640’ 67” LAMOR 

10567 4000 NA 14 Pascagoula 2 0 1 

MSRC 402 Offshore Barge 2 Crucial Disk 88/30 660’ 44” Sea Sentry II Boom 1,980‘ 67” LAMOR 

22244 40300 3 Tugs 6 Pascagoula 2 0 2 

Deep Blue Responder LFF 100 Brush + OSRV 6,600’ 44” Sea Sentry II Boom 660’ 67” LAMOR 

18086 4000 NA 14 Fourchon 2 0 1 

PSV – HOS Centerline 1 Crucial Disk 88/30 1,320’ EFC (cont inflate) 

11122 10626 NA 14 Fourchon 12 12 1 

PSV – HOS Strongline 1 Crucial Disk 88/30 1,320’ EFC (cont inflate) 

11122 10626 NA 14 Fourchon 12 12 1 

PSV – C-Freedom 1 LFF 100 Brush 1,320’ EFC (cont inflate) 

18086 6000 NA 14 Fourchon 12 12 1 

PSV – C-Leader 1 LFF 100 Brush 1,320’ EFC (cont inflate) 

18086 6000 NA 14 Fourchon 12 12 1 

PSV – Allysa Chouest 1 LFF 100 Brush 1,320’ EFC (cont inflate) 

18086 6000 NA 14 Fourchon 12 12 1 
Offshore Equipment 

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

MSRC 

MSRC Lightning 2 LORI Brush Pack 5000 50 3 Tugs 6 Tampa 2 0 2 Gulf Coast Responder Transrec 350 + OSRV 5,280’ 44” Sea Sentry II Boom 2,640’ 67” LAMOR 

10567 4000 NA 14 Lake Charles 2 0 1 

Texas Responder Transrec 350 + OSRV 4,620’ 44” Sea Sentry II Boom 3,300’ 67” LAMOR 

10567 4000 NA 14 Galveston 2 0 1 

MSRC 570 Offshore Barge 2 Crucial Disk 88/30 2,640’ 44” Sea Sentry II Boom 

22244 56900 3 Tugs 6 Galveston 2 0 2 

Southern Responder Transrec 350 + OSRV 4,290’ 44” Sea Sentry II Boom 2,970’ 67” LAMOR 

10567 4000 NA 14 Ingleside 2 0 1 

MSRC 403 Offshore Barge 1 Crucial Disk 88/30 660’ 44” Sea Sentry II Boom 660’ 67” LAMOR 

11122 40300 3 Tugs 6 Ingleside 2 0 2 

MSRC Quick Strike 2 LORI Brush Pack 5000 50 3 Tugs 6 Ingleside 2 0 1 

NRCC 

OSRV Energy (Marco Class XI AB) 24000 300 NA 6 Morgan City 4 2 0 OSRV Admiral (Marco Class XI AB) 24000 300 NA 6 Galveston 4 2 0 OSRB Defender (Marco Class XI AB) 24000 16500 1 Tug 6 Bayou La Batre 4 2 0 OSRB Valiant (Marco Class XI AB) 24000 20892 1 Tug 6 Aransas Pass 4 2 0 OSRB Valor (Marco Class XI AB) 24000 19000 1 Tug 6 Tampa 4 2 0 
Staging Area: Venice 

Offshore Equipment With 

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

T&T Marine (available through direct contract with CGA)

Aqua Guard Triton RBS (2) 45560 4000 2 Utility 12 Galveston 4 12 7.5 

CGA

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 3 FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 1 2 2 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 8 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Ingleside 1 2 11 FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 5.5 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Leeville 1 2 3.5 FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 
Staging Area: Venice 

Offshore Equipment 

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

MSRC 

WP 1 Skimmer (1) 3017 400 1 Utility 6 Ingleside 1 2 11 Stress I Skimmer (1) 15840 400 1 Utility 6 Ingleside 1 2 11 GT-185 Skimmer w Adaptor (1) 1371 400 1 Utility 6 Ingleside 1 2 11 Foilex 250 Skimmer (1) 3977 400 1 Utility 6 Ingleside 1 2 11 GT-185 Skimmer w Adaptor (2) 2742 400 2 Utility 12 Galveston 1 2 8 Walosep 4 Skimmer (1) 3017 400 1 Utility 6 Galveston 1 2 8 Queensboro Skimmer (1) 905 400 1 Utility 6 Galveston 1 2 8 Foilex 250 Skimmer (1) 3977 400 1 Utility 6 Galveston 1 2 8 Stress I Skimmer (1) 15840 400 1 Utility 6 Galveston 1 2 8 GT-185 Skimmer w Adaptor (1) 1371 400 1 Utility 6 Port Arthur 1 2 6 Queensboro Skimmer (4) 3620 400 4 Utility 24 Lake Charles 1 2 5.5 Desmi Skimmer (1) 3017 400 1 Utility 6 Lake Charles 1 2 5.5 Foilex 250 Skimmer (1) 3977 400 1 Utility 6 Lake Charles 1 2 5.5 Stress I Skimmer (1) 15840 400 1 Utility 6 Lake Charles 1 2 5.5 LFF 100 Brush Skimmer (1) 18086 400 1 Utility 6 Lake Charles 1 2 5.5 Transrec 350 Skimmer (1) 21134 400 1 Utility 6 Lake Charles 1 2 5.5 LFF 100 Brush Skimmer (2) 36172 400 2 Utility 12 Port Fourchon 1 2 4 Stress I Skimmer (1) 15840 400 1 Utility 6 Port Fourchon 1 2 4 Crucial Disk 88/30 Skimmer (1) 11122 400 1 Utility 6 Port Fourchon 1 2 4 GT-185 Skimmer w Adaptor (1) 1371 400 1 Utility 6 Fort Jackson 1 2 0.5 Walosep W4 Skimmer (1) 3017 400 1 Utility 6 Fort Jackson 1 2 0.5 Foilex 250 Skimmer (1) 3977 400 1 Utility 6 Fort Jackson 1 2 0.5 Stress I Skimmer (1) 15840 400 1 Utility 6 Fort Jackson 1 2 0.5 
Staging Area: Venice 

Offshore Equipment 

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

MSRC 

Desmi Ocean Skimmer (1) 3017 400 1 Utility 6 Fort Jackson 1 2 0.5 Queensboro Skimmer (1) 905 400 1 Utility 6 Fort Jackson 1 2 0.5 Foilex 200 Skimmer (1) 1989 400 1 Utility 6 Fort Jackson 1 2 0.5 GT-185 Skimmer w Adaptor (1) 1371 400 1 Utility 6 Baton Rouge 1 2 3 Stress I Skimmer (1) 15840 400 1 Utility 6 Pascagoula 1 2 4 GT-185 Skimmer (1) 1371 400 1 Utility 6 Pascagoula 1 2 4 AardVac Skimmer (1) 3840 400 1 Utility 6 Pascagoula 1 2 4 WP 1 Skimmer (1) 3017 400 1 Utility 6 Pascagoula 1 2 4 Queensboro Skimmer (1) 905 400 1 Utility 6 Pascagoula 1 2 4 Stress II Skimmer (1) 3017 400 1 Utility 6 Pascagoula 1 2 4 Stress I Skimmer (1) 15840 400 1 Utility 6 Tampa 1 2 11 GT-185 Skimmer w Adaptor (1) 1371 400 1 Utility 6 Tampa 1 2 11 WP 1 Skimmer (1) 3017 400 1 Utility 6 Tampa 1 2 11 
Staging Area: Venice 

Offshore Equipment Preferred 

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

CGA 

42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 42” Auto Boom (10000’) NA NA 20 Crew 40 Harvey 1 2 2 42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 1000’ Hydro-Fire Boom NA NA 8 Utility 40 Harvey 1 4 2 

MSRC 

44” Sea Sentry II Boom (2860’) NA NA 6 Crew 12 Ingleside 1 2 11 44” Sea Sentry II Boom (4290’) NA NA 10 Crew 20 Galveston 1 2 8 44” Sea Sentry II Boom (6679’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 44” Sea Sentry II Boom (1980’) NA NA 6 Crew 12 Fort Jackson 1 2 0.5 44” Sea Sentry II Boom (3190’) NA NA 10 Crew 20 Pascagoula 1 2 4 2000’ Hydro-Fire Boom NA NA 16 Utility 80 Lake Charles 1 4 5.5 

NRCC 

42” Auto Boom (200’) NA NA 3 Crew 6 Belle Chasse 1 2 1.5 42” Auto Boom (1000’) NA NA 3 Crew 6 Bayou La Batre 1 2 4 42” Auto Boom (2100’) NA NA 6 Crew 12 Morgan City 1 2 3 42” Auto Boom (2000’) NA NA 6 Crew 12 Houston 1 2 7 42” Auto Boom (2200’) NA NA 6 Crew 12 Galveston 1 2 8 42” Auto Boom (2700’) NA NA 6 Crew 12 Aransas Pass 1 2 10 42” Auto Boom (4000’) NA NA 8 Crew 16 Corpus Christi 1 2 10 1000’ Hydro-Fire Boom NA NA 8 Utility 40 Morgan City 1 4 3 
Nearshore Response 

Nearshore Equipment 

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

CGA 

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

K-Sea Operating (Available through contract with CGA) 

DBL 81 1132231 NA 86948 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 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 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 

Staging Area: Venice 

Nearshore Equipment With Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure Hrs to Load Out Travel to Staging 

CGA 

SWS Egmopol 3000 100 NA 3 Galveston 1 2 8 SWS Egmopol 3000 100 NA 3 Houma 1 2 3 SWS Marco 3588 34 NA 3 Venice 1 2 0 SWS Marco 3588 34 NA 3 Houma 1 2 3 SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 
Nearshore Equipment Preferred 

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

Stag

NRCC 

4-Band Rope Mop Skimmer 1509 100 1 Utility 3 Morgan City, LA 2 4 3 4-Band Rope Mop Skimmer 1509 100 1 Utility 3 Morgan City, LA 2 4 3 Vikoma Cascade Skimmer 5520 100 1 Utility 3 Sulphur, LA 2 4 5 VTU w/weir head skimmer 6857 24 1 Utility 3 Mobile, AL 2 4 4 VTU w/weir head skimmer 6857 24 1 Utility 3 Fort Lauderdale, FL 2 4 13.VTU w/weir head skimmer 6857 24 1 Utility 3 Fort Lauderdale, FL 2 4 13.VTU w/weir head skimmer 6857 24 1 Utility 3 Tampa, FL 2 4 11 VTU w/weir head skimmer 6857 24 1 Utility 3 Panama City Beach, FL 2 4 7 VTU w/weir head skimmer 6857 24 1 Utility 3 Morgan City, LA 2 4 3 VTU w/weir head skimmer 6857 24 1 Utility 3 Belle Chasse, LA 2 4 1.5 VTU w/weir head skimmer 6857 24 1 Utility 3 Sulphur, LA 2 4 5 VTU w/weir head skimmer 6857 24 1 Utility 3 Sulphur, LA 2 4 5 VTU w/weir head skimmer 6857 24 1 Utility 3 Southaven, MS 2 4 7 VTU w/weir head skimmer 6857 24 1 Utility 3 La Porte, TX 2 4 7 VTU w/weir head skimmer 6857 24 1 Utility 3 Port Arthur, TX 2 4 6 VTU w/weir head skimmer 6857 24 1 Utility 3 Corpus Christi, TX 2 4 10 VTU w/weir head skimmer 6857 24 1 Utility 3 Baytown, TX 2 4 6.5 
Staging Area: Venice 

Nearshore Equipment With 

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

MSRC 

GT 185 with Adaptor (1) + Storage Bladder 1371 500 1 Utility 3 Port Arthur 2 .5 6.5 GT 185 with Adaptor (1) + Storage Bladder 1371 500 1 Utility 3 Baton Rouge 2 .5 3.5 GT 185 with Adaptor (1) + Storage Bladder 1371 500 1 Utility 3 Pascagoula 2 .5 4 Foilex 250 Skimmer+ Storage Bladder 3977 500 1 Crew 3 Fort Jackson 2 .5 .5 Foilex 250 Skimmer+ Storage Bladder 3977 500 1 Crew 3 Lake Charles 2 .5 5.5 Foilex 250 Skimmer+ Storage Bladder 3977 500 1 Crew 3 Galveston 2 .5 8 Foilex 250 Skimmer+ Storage Bladder 3977 500 1 Crew 3 Ingleside 2 .5 11 WP-1 Skimmer+ Storage Bladder 3017 500 1 Utility 3 Ingleside 2 .5 11 WP-1 Skimmer+ Storage Bladder 3017 500 1 Utility 3 Pascagoula 2 .5 4 Aardvac 800 Skimmer+ Storage Bladder 3840 500 NA 3 Pascagoula 2 .5 4 
Shoreline Protection 

Staging Area: Venice 

Shoreline 

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

AMPOL (Available through MSA) 

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 4 2 20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2 2 

OMI Environmental (Available through MSA) 

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 7.5 2 10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 6.25 2 20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.75 2 10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 3.5 2 10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.5 2 15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2 2 

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

D

CGA 

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 8 Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 11 Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 
Staging Area: Venice 

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

D

CGA 

Wildlife Support Trailer NA NA NA 2 Houma 1 2 3 Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 2 Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 11 Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 

Response Asset Total 

Offshore EDRC 935,182 Offshore Recovered Oil Capacity 942,021 Nearshore / Shallow Water EDRC 230,695 Nearshore / Shallow Water Recovered Oil Capacity 247,838 
Apache Deepwater LLC	 	 Page I‐1

Initial Exploration Plan	 	 April 13, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION I 

ENVIRONMENTAL MONITORING INFORMATION 

(30 CFR 550.221 and 550.252) 

A. MONITORNING SYSTEMS

There are no environmental monitoring systems currently in place or planned for the proposed 

activities. 

B. INCIDENTAL TAKES

There is no reason to believe that any of the endangered species or marine mammals as listed in 

the ESA will be incidentally taken as a result of the operations proposed under this plan. 

To date, it has been documented that the use of explosives and/or seismic devices can affect 

marine life. Operations proposed in this plan will not be utilizing either of these devices. 

C. FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY

Mississippi Canyon Block 983 is not located in the Flower Garden Banks National Marine 

sanctuary; therefore, the requested information is not required for this EP. 
Apache Deepwater LLC	 	 Page J‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION J 

LEASE STIPULATIONS INFORMATION 

(30 CFR 550.222 and 550.253) 

The Lease Stipulations Information for the exploration activities of this EP are subject to the 

following for Mississippi Canyon Block 983. 

Military Warning Area (MWA)

Mississippi Canyon Block 983 is not located within Military Warning Area (MWA). 

Marine Protected Species

The Marine Protected Species Stipulation is meant to reduce the potential taking of marine 

protected species. Apache Deepwater will operate in accordance with NTL 2007-G04, to 

minimize the risk of vessel strikes to protected species and report observations of injured or dead 

protected species and the prevention of intentional and/or accidental introduction of debris into 

the marine environment. 
Apache Deepwater LLC	 	 Page K‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION K 

ENVIRONMENTAL MITIGATION MEASURES INFORMATION 

(30 CFR 550.213 and 550.243) 

A. MEASURES TAKEN TO AVOID, MINIMIZE AND MITIGATE IMPACTS

Not applicable for the operations proposed in this EP. 

B. INCIDENTAL TAKES

Apache Deepwater will adhere to the requirements set forth in the following documents, as 

applicable, to avoid or minimize impacts to any of the species listed in the ESA as a result of the 

operations conducted herein: 

 NTL 2012-JOINT-G01: Vessel Strike Avoidance and Injured/Dead Protected Species 

Reporting 

 NTL 2012-BSEE-G01: Marine Trash and Debris Awareness and Elimination 

 NTL 2012-JOINT-G02: Implementation of Seismic Survey Mitigation Measures and 

Protected Species Observer Program 
Apache Deepwater LLC	 	 Page L‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION L 

SUPPORT VESSELS AND AIRCRAFT INFORMATION 

(30 CFR 550.224 and 550.257) 

A. GENERAL

The most practical, direct route from the shorebase as permitted by weather and traffic 

conditions will be utilized. 

Type Maximum Fuel 

Tank Capacity 

Maximum 

Number in Area 

at Any Time 

Trip Frequency 

or Duration 

Crew Boat 27,216 gals 1 2 Per week 

Marine Supply Vessel (MSV) 379,615 gals 2 2 Per week 

Helicopters 560 gals 1 6 Per week 

B. DIESEL OIL SUPPLY VESSELS

Size of Fuel Supply Vessel Capacity of Fuel 

Supply Vessel 

Frequency of 

Fuel Transfers 

Route Fuel Supply 

Vessel Will Take 

Marine Supply Vessel (MSV) 379,615 gals 1 per week Direct to Fourchon 

*Please note the actual vessels have not yet been contracted. 

C. DRILLING FLUIDS TRANSPORTATION

N/A 

D. SOLID AND LIQUID WASTE TRANSPORTATION

“Wastes You Will Transport and/or Dispose of Onshore” is included in this section as 

Attachment L-1. 

E. VICINITY MAP

A vicinity map, included in this section as Attachment L-2, is 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. 
ATTACHMENT L-1

Discharged at mudline 

prior to BOP and riser 

installation

Cuttings wetted with Water-based 

fluid

Cuttings generated while using 

water based fluid N/A N/A 1,000 bbls/well

N/A

Cuttings wetted with Syntheticbased fluidCuttings generated while using 

synthetic based fluid N/A N/A 2,500 bbls/well

Discharged thru shunt 

pipe to 25' below water's 

surface

Cuttings wetted with oil-based 

fluids N/A N/A N/A N/A

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

Wash Water Wash water, sink drainage, 

etc.

N/A N/A 450,000 gals per well Discharged overboard

Recycled

Chemical product wastes Paint, solvents, unused 

chemicals, etc

Transport in DOT containers on supply boats to 

shorebase

Safety Kleen System 

Baton Rouge, LA 129 lbs per well Recycled

Used Oil Used oil & glycol Transport in DOT containers on supply boats to 

shorebase

Safety Kleen System 

Baton Rouge, LA 386 gals per well

Disposed in landfill

Will you produce hydrocarbons? If yes fill in for produced sand.

Produced sand N/A

Will you have additional wastes that are not permitted for discharge? If yes, fill in the appropriate rows.

EXAMPLE: Trash & debris 

(Recyclables)

Plastic, Paper, Aluminum, 

Glass Storage bins on supply boat or crew boat

Waste Management 7170 

Brannon Road, Sulphur, 

LA

X lb/well Recycled

Trash & debris (NonRecyclables)Non-hazardous trash and 

debris non- recyclables

Transport in DOT containers on supply boats to 

shorebase

Progressive Waste 

Solutions of LA, 

Houma, LA

643 lbs per well

Recycled

Oil-based drilling fluid or mud N/A N/A N/A N/A N/A

Synthetic-based drilling fluid 

or mud Internal Olefin Below deck storage tanks on offshore support vessels

M-I Swaco 

Port Fourchon, La. 14,000 bbls/well

Projected Generated Waste Solid and Liquid Wastes Transportation Waste Disposal

Type of Waste Composition Transport Method Name/Location of 

Facility Amount Disposal Method

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

EXAMPLE: Synthetic-based 

drilling fluid or mud Internal olefin, ester Below deck storage tanks on offshore support vessels

Newport Environmental 

Services Inc., Golden 

Meadow, LA

X bbl/well Recycled
Apache Deepwater, LLC Vicinity Map

Mississippi Canyon 983

~99 Miles to Fouchon, LA Shorebase

~66 Miles to Closest Shoreline

Fouchon, LA

Venice, LA

Grand Isle, LA
Apache Deepwater LLC	 	 Page M‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION M 

ONSHORE SUPPORT FACILITIES INFORMATION 

(30 CFR 550.225 and 550.258) 

A. GENERAL

Apache Deepwater will utilize the following onshore facility to provide supply and service for 

the proposed operations. 

Name of Shorebase Location Existing/New/Modified 

Martin Fuel Docks Fourchon, LA Existing 

B. SUPPORT BASE CONSTRUCTION OR EXPANSION

There will be no new construction of an onshore support base, nor will we expand the existing 

shorebase as a result of the operations proposed in this Exploration Plan. 

C. WASTE DISPOSAL

Information regarding Waste Disposal on the onshore facilities that will be used to store and 

dispose of any solid and liquid wastes generated by the proposed activities is included in 

Attachment L-1. 
Apache Deepwater LLC	 	 Page N‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION N 

COASTAL ZONE MANAGEMENT (CZM) INFORMATION 

(30 CFR 550.213 and 550.243) 

Under the direction of the Coastal Zone Management Act (CZMA), the states of Alabama, 

Florida, Louisiana, Mississippi and Texas developed Coastal Zone Management Programs 

(CZMP) to allow for the supervision of the significant land and water use activities that take 

place within or that could significantly impact their respective coastal zones. 

Any new or unusual technology will/will not be used by Apache Deepwater LLC in regards 

to spill control, cleanup, prevention, etc. 

Relevant enforceable policies were considered in certifying consistency for Louisiana. 

A certificate of Coastal Zone Management Consistency for the state of Louisiana is enclosed as 

Attachment N-1. 

Apache Deepwater LLC	 	 Page O‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION O 

ENVIRONMENTAL IMPACT ANALYSIS (EIA) 

(30 CFR 550.227 and 550.261) 

The Environmental Impact Analysis has been prepared and is included as Attachment O-1. 
Apache Deepwater LLC

Initial Exploration Plan 

Mississippi Canyon Block 983 

OCS-G 34468

(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 X(4) 

Water quality X X X 

Fisheries X 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 X(6) 

Marine and pelagic birds X X X 

Public health and safety (5) 

Coastal and Onshore 

Beaches X(6) X 

Wetlands X(6) 

Shore birds and coastal nesting 

birds 

 X(6) X 

Coastal wildlife refuges X 

Wilderness areas X 
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 983 

Proposed operations consist of drilling, installing subsea wellhead and completing of 3 (three) 

well locations. 

Operations will be conducted with a Semisubmersible or DP Semisubmersible. 

1. Designated Topographic Features 

Potential IPFs on topographic features include physical disturbances to the seafloor, effluents, 

and accidents. 

Physical disturbances to the seafloor: Mississippi Canyon Block 983 is 48.2 miles from the 

closest designated Topographic Features Stipulation Block (Sackett Bank); therefore, no adverse 

impacts are expected. 

Effluents: Mississippi Canyon Block 983 is 48.2 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 Apache Deepwater 

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

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

effluents, and accidents. 

Physical disturbances to the seafloor: Mississippi Canyon Block 983 is 96.7 miles from the 

closest live bottom (pinnacle trend) area; therefore, no adverse impacts are expected. 
Effluents: Mississippi Canyon Block 983 is 96.7 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 Apache Deepwater 

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

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

effluents, and accidents. 

Physical disturbances to the seafloor: Mississippi Canyon Block 983 is not located in an area 

characterized by the existence of live bottoms, and this lease does not contain a Live-Bottom 

Stipulation requiring a photo documentation survey and survey report. 

Effluents: Mississippi Canyon Block 983 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 Apache Deepwater LLC’s Regional OSRP (refer to information 

submitted in Section H). 

There are no other IPFs (including emissions and wastes sent to shore for disposal) from the 

proposed activities which could impact an Eastern Gulf live bottom area. 
4. Benthic Communities 

Mississippi Canyon Block 983 is located in water depths 984 feet (300 meters) or greater. IPFs 

that could result in impacts to benthic communities from the proposed activities include physical 

disturbances to the seafloor. 

Physical disturbances to the seafloor: Mississippi Canyon Block 983 is approximately 40.3 

miles from a known benthic community site (Mississippi Canyon Block 969), listed in NTL 

2009-G40. This Initial Exploration Plan submittal includes the required maps, analyses, and 

statement(s). The proposed activities will be conducted in accordance with NTL 2009-G40, 

which will ensure that features or areas that could support high-density benthic communities will 

not be impacted. 

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

accidents) from the proposed activities which could impact benthic communities. 

5. Water Quality 

IPFs that could result in water quality degradation from the proposed operations in Mississippi 

Canyon Block 983 include disturbances to the seafloor, effluents and accidents. 

Physical disturbances to the seafloor: Bottom area disturbances resulting from the 

emplacement of drill rigs, the drilling of wells and the installation of platforms and pipelines 

would increase water-column turbidity and re-suspension of any accumulated pollutants, such as 

trace metals and excess nutrients. This would cause short-lived impacts on water quality 

conditions in the immediate vicinity of the emplacement operations. 

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 Apache Deepwater LLC’s Regional Oil Spill Response Plan (refer to information 

submitted in Section H). 

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 983 include physical disturbances to the seafloor, effluents and accidents. 

Physical disturbances to the seafloor: The emplacement of a structure or drilling rig results in 

minimal loss of bottom trawling area to commercial fishermen. Pipelines cause gear conflicts 

which result in losses of trawls and shrimp catch, business downtime and vessel damage. Most 

financial losses from gear conflicts are covered by the Fishermen’s Contingency Fund (FCF). 

The emplacement and removal of facilities are not expected to cause significant adverse impacts 

to fisheries. 

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 Apache Deepwater 

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

There are no IPFs from emissions, 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 983 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). 

Apache Deepwater 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 Apache Deepwater 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 Apache Deepwater 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 Apache Deepwater 

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

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). Apache Deepwater 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 Apache Deepwater 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 Apache Deepwater LLC’s Regional Oil Spill Response 

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

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 983 is located 101.6 miles from the Breton Wilderness Area and 68 

miles from shore. Applicable emissions data is included in Section G 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 983 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) 

IPFs that could impact known or unknown shipwreck sites as a result of the proposed operations 

in Mississippi Canyon Block 983 include disturbances to the seafloor and accidents (oil spill). 

Mississippi Canyon Block 983 is not located in or adjacent to an OCS block designated by 

BOEM as having a high probability for occurrence of shipwrecks. Apache Deepwater LLC will 

report to BOEM the discovery of any evidence of a shipwreck 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 which could impact shipwreck sites. 

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

shipwreck 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 Apache Deepwater LLC’s Regional Oil Spill Response 

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

Apache Deepwater 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 Apache Deepwater 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, Apache Deepwater 
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, or wastes sent to shore for treatment or 

disposal) 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 983 are physical disturbances to the seafloor and 

accidents (oil spills). 

Physical Disturbances to the seafloor: Mississippi Canyon Block 983 is located inside the 

Archaeological Prehistoric high probability lines. Apache Deepwater 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. 

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 Apache Deepwater LLC’s Regional Oil 

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

Apache Deepwater 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 Apache Deepwater 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, Apache Deepwater 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) from the proposed activities that could cause impacts to prehistoric archaeological 

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 983 include physical disturbances to the seafloor, effluents and accidents. EFH 

includes all estuarine and marine waters and substrates in the Gulf of Mexico. 
Physical disturbances to the seafloor: 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 bottom 

disturbing activities (e.g., anchoring, structure emplacement and removal). 

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 Apache Deepwater LLC’s Regional OSRP (refer to 

information submitted in Section H). 

There are no other IPFs (including emissions, or 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 Apache 

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

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). Apache Deepwater 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 Apache Deepwater 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 releases) 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 D

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 (68 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 Apache Deepwater LLC’s Regional OSRP (refer to information 

submitted in Section H). 
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). Apache Deepwater 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 Apache Deepwater 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 (68 miles) and the response capabilities that 

would be implemented, no impacts are expected. The activities proposed in this plan will be 

covered by Apache Deepwater LLC’s Regional OSRP (refer to information submitted in Section 

H). 

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). Apache Deepwater 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 Apache Deepwater 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 (68 miles) and the response capabilities that would be 

implemented, no impacts are expected. The activities proposed in this plan will be covered by 

Apache Deepwater LLC’s Regional OSRP (refer to information submitted in Section H). 

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). Apache 

Deepwater 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 Apache Deepwater 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 (68 miles) and the response 

capabilities that would be implemented, no impacts are expected. The activities proposed in this 

plan will be covered by Apache Deepwater LLC’s Regional OSRP (refer to information 

submitted in Section H). 

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). Apache Deepwater 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 Apache Deepwater 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 (101.6 

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 Apache Deepwater LLC’s 

Regional OSRP (refer to information submitted in Section H).

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). Apache Deepwater 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 Apache Deepwater 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 983 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) 

Krystal Nava 

J. Connor Consulting, Inc. 

16225 Park Ten Place, Suite 700 

Houston, TX 77084 

(281) 578-3388 

krystal.nava@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. MMS 2000-001 

o GOM Central and Western Planning Areas Sales 166 and 168 Final Environmental 

Impact Statement. MMS 96-0058. 
Apache Deepwater LLC	 	 Page P‐1

Initial Exploration Plan	 	 April 23, 2013

Mississippi Canyon Block 983 (OCS‐G 34468)	 	

SECTION P 

ADMINISTRATIVE INFORMATION 

(30 CFR 550.228 and 550.262) 

A. EXEMPTED INFORMATION DESCRIPTION

The proposed bottom-hole locations of the planned well have been removed from the public 

information copy of the EP as well as any discussion of the target objectives, geologic or 

geophysical data and any interpreted geology. 

B. BIBLIOGRAPHY

N/A