UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field Operations (MS 5231)

Public Information copy of Exploration Plan
Control # - R-05906
Type - Revised Exploration Plan
Lease(s) - OCS-G31613 Block - 213 Garden Banks Area OCS- Block - 169 Garden Banks Area
Operator - Apache Deepwater LLC
Subsea Wells A, B, and C

Not Found

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

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

Michelle Griffitt Plan Coordinator Description -
Rig Type - Subject: From: September 5, 2013PUBLIC COPY



## RECORD OF CHANGES

Operator: Apache Deepwater LLC 

## Lease: OCS-G 31613 

## Area/Block: Garden Banks Block 213 

## Plan Type: Revised Initial Exploration Plan 

## Plan Control No.: R-5906 

## Complete Plan Submitted: August 21, 2013 

## BOEM Coordinator: Michelle Griffitt



## Date Appendix Page Revision 7/1/13 H 1 Add statement regarding submittal/verification of the WCS for the Regional OSRP to the Proprietary and Public Copies 7/17/13 H Provide Apache’s Merlin/Avalon Software version E 1 Revised statement due to anchor radius is around numerous potentially sensitive biological features 8/13/13 H WCD revision submitted also with revised .nod/.mer files

# REVISED INITIAL EXPLORATION PLAN

PUBLIC COPY August 21, 2013

Area/Block: Garden Banks Block 213 Lease Number(s): OCS-G 31613 Prospect Name: Bimini 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.: R-5906 Assigned to: Michelle Griffitt 

## Date of Submittal: August 21, 2013 Estimated Start-up Date: January 3, 2014

### REVISED INITIAL EXPLORATION PLAN LEASE OCS-G 31613 GARDEN BANKS BLOCK 213

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 (Not Required)

C-4 Shallow Hazard Assessment

F-1 Projected Generated Wastes

G-1 AQR Worksheets

H-2 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 AnalysisApache Deepwater LLC Page A

‐ 1 Revised Initial Exploration Plan August 20, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### SECTION A PLAN CONTENTS (30 CFR 550.211 and 550.241)

A. PLAN INFORMATION FORM Apache Deepwater LLC submits this Revised Initi al Exploration Plan to propose the drill and completion of three (3) well locations, Garden Ba nks Block 213. The revisions include adding the rig type, DP Semi-Submers ible along with the Semi-Subme rsible. These revisions will comply with the NTL 2010-N06 and the December 13, 2010 Guidance. The Initial EP, Plan No. 9283 was approved January 5, 2009. Tentative schedul es 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.

Apache Deepwater is submitting Right-of-Use and Easement for the three (3) surface locations in Garden Banks Block 169 (expired November 30, 2007 via OWL Database). The RUE will be filed in conjunction with this Revised Initial Exploration Plan.

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 wate r depths across the lease block is included as Attachment A-3 . These attachments are in accorda nce with the Notice to Lessees (NTL) 2010-N06, Information Requirements for Exploration Plans, Development and Production Plans and Development Operations Coordination Documents on the OCS.

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 CF R 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 th e 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 Revised Initial Exploration Plan August 20, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### D. STORAGE TANKS AND/OR PRODUCTION VESSELS The Garden Banks Block 213 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 105 1 105 35° Fuel Oil Day Semisubmersible 98 1 98 35° Emergency Generator Semisubmersible 5.5 1 5.5 35° Forward Hull – Fuel Oil Semisubmersible 3,416 1 3,416 35° Lower AFT Hull – Fuel Oil Semisubmersible 3,416 1 3,416 35° Lube Oil Services Semisubmersible 61 7 427 26° Dirty Lube Oil Semisubmersible 30 1 30 26° Dirty Bilge Semisubmersible N/A N/A N/A N/A Fuel Oil (Marine Diesel) DP Semisubmersible 164 1 164 35° Fuel Oil Day DP Semisubmersible 262 1 262 35° Emergency Generator DP Semisubmersible 31 1 31 35° Forward Hull – Fuel Oil DP Semisubmersible 4,541 2 9,082 35° Lower AFT Hull – Fuel Oil DP Semisubmersible 6,790 2 13,580 35° Lube Oil Services DP Semisubmersible 115 1 115 26° Dirty Lube Oil DP Semisubmersible 33 2 66 26° Dirty Bilge DP Semisubm ersible N/A N/A N/A N/A

E. ADDITIONAL MEASURES Apache Deepwater does not prop ose additional safety, polluti on prevention or early spill detection measures beyond t hose required by 30 CFR 550.

F. COST RECOVERY FEE No cost recover fees are associated with this revised initial exploration plan.U.S. Department of the Interior OMB Control Number: 1010-0151 Bureau of Ocean Energy Management OMB Approval Expires: 12/31/14



### OCS PLAN INFORMATION FORM General Information 7\SHRI2&63ODQ  ([SORUDWLRQ3ODQ(3 'HYHORSPHQW2SHUDWLRQV &RRUGLQDWLRQ'RFXPHQW'2&' 

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 (0DLO$GGUHVV ,IDVHUYLFHIHHLVUHTXLUHGXQGHU&)5DSURYLGHW KH $PRXQWSDLG  5HFHLSW1R 
Project and Worst Case Discharge (WCD) Information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escription of Proposed Activities and Tentative Schedule (Mark all that apply) Proposed Activity Start Date End Date No. of Days 'ULOO&RPSOHWH	7HVW/RFDWLRQV	,QVWDOO6XEVHD:HOOKHDGV     

Description of Drilling Rig Description of Structure  -DFNXS  'ULOOVKLS  &DLVVRQ  7HQVLRQOHJSODWIRUP  *RULOOD-DFNXS  3ODWIRUPULJ  )L[HGSODWIRUP  &RPSOLDQWWRZHU  6HPLVXEPHUVLEOH  6XEPHUVLEOH  6SDU  *X\HGWRZHU  '36HPLVXEPHUVLEOH  2WKHU$WWDFK'HVFULSWLRQ 'ULOOLQJ5LJ1DPH,I.QRZQ  )ORDWLQJSURGXFWLRQ V\VWHP  2WKHU$WWDFK'HVFULSWLRQ

Description of Lease Term Pipelines From (Facility/Area/Block) To (Facility/Area/Block) Diameter (Inches) Length (Feet)

Form BOEM- 0137 (December 2011

- Supersedes all previous editions of this form which may not be used.) Page 1 of 4 

### ATTACHMENT A-1

GB 213 A
GB 213 B
GB 213 C X Revised Apache Deepwater LLC 03165 Terri Young 2000 W. Sam Houston Pkwy, South, Ste. 1600 713-296-7456 Houston, TX 77042 terri.young@apachecorp.com 

### NA NA

OCS-G 31613 GB 213 Bimini
X Port Fourchon 395,611 36 113 395,611
X N-09283 Approved 1/5/2009
X
X
X

1/3/2014 4/9/2014 96
1/3/2015 4/9/2015 96
1/3/2016 4/9/2016 96

X
XOCS PLAN INFORMATION FORM ( CONTINUED ) Include one copy of this page for each proposed well/structure Proposed Well/Structure Location Well or Structure Name/Number (If renaming well or structure, reference previous name): Previously reviewed under an approved EP or DOCD? Yes No

Is this an existing well or structure? Yes No If this is an existing well or structure, list the Complex ID or API No. Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes No

WCD info For wells, volume of uncontrolled blowout (Bbls/day): For structures, volume of all storage and pipelines (Bbls): API Gravity of fluid Surface Location Bottom-Hole Location (For Wells) Completion (For multiple completions, enter separate lines) Lease No. OCS OCS OCS OCS Area Name

Block No.

Blockline Departures (in feet) N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ LLambert XY coordinates X: X: X: X: X: Y: Y: Y: Y: Y: Latitude/ Longitude Latitude Latitude Latitude Latitude Latitude Longitude Longitude Longitude Longitude Longitude Water Depth (Feet): MD (Feet): TVD (Feet):

Anchor Radius (if applicable) in feet: MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet):
Anchor Locations for Drilling Rig or Construction Barge ( If anchor radius supplied above, not necessary)
Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

Form BOEM- 0137 (December 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4 A 

## X

X
X

Expired - RUE Submittal 

### Garden Banks
169

S 

## 3,155'

W 

## 655'


# 1,917,295'
10,093,235'

27.8113111

-92.1431972

919' 

## 5,946'OCS PLAN INFORMATION FORM ( CONTINUED ) Include one copy of this page for each proposed well/structure Proposed Well/Structure Location Well or Structure Name/Number (If renaming well or structure, reference previous name): Previously reviewed under an approved EP or DOCD? Yes No

Is this an existing well or structure? Yes No If this is an existing well or structure, list the Complex ID or API No. Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes No

WCD info For wells, volume of uncontrolled blowout (Bbls/day): For structures, volume of all storage and pipelines (Bbls): API Gravity of fluid Surface Location Bottom-Hole Location (For Wells) Completion (For multiple completions, enter separate lines) Lease No. OCS OCS OCS OCS Area Name

Block No.

Blockline Departures (in feet) N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ LLambert XY coordinates X: X: X: X: X: Y: Y: Y: Y: Y: Latitude/ Longitude Latitude Latitude Latitude Latitude Latitude Longitude Longitude Longitude Longitude Longitude Water Depth (Feet): MD (Feet): TVD (Feet):

Anchor Radius (if applicable) in feet: MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet):
Anchor Locations for Drilling Rig or Construction Barge ( If anchor radius supplied above, not necessary)
Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

Form BOEM- 0137 (December 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4 B 

## X

X
X

Expired - RUE Submittal 

### Garden Banks
169

S 

## 3,520'

W 

## 1,797'


# 1,918,437'
10,093,600'

27.8122934

-92.1396557

923' 

## 5,966'OCS PLAN INFORMATION FORM ( CONTINUED ) Include one copy of this page for each proposed well/structure Proposed Well/Structure Location Well or Structure Name/Number (If renaming well or structure, reference previous name): Previously reviewed under an approved EP or DOCD? Yes No

Is this an existing well or structure? Yes No If this is an existing well or structure, list the Complex ID or API No. Do you plan to use a subsea BOP or a surface BOP on a floating facility to conduct your proposed activities? Yes No

WCD info For wells, volume of uncontrolled blowout (Bbls/day): For structures, volume of all storage and pipelines (Bbls): API Gravity of fluid Surface Location Bottom-Hole Location (For Wells) Completion (For multiple completions, enter separate lines) Lease No. OCS OCS OCS OCS Area Name

Block No.

Blockline Departures (in feet) N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L N/S Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ L E/W Departure: F____ LLambert XY coordinates X: X: X: X: X: Y: Y: Y: Y: Y: Latitude/ Longitude Latitude Latitude Latitude Latitude Latitude Longitude Longitude Longitude Longitude Longitude Water Depth (Feet): MD (Feet): TVD (Feet):

Anchor Radius (if applicable) in feet: MD (Feet): MD (Feet): MD (Feet): TVD (Feet): TVD (Feet): TVD (Feet):
Anchor Locations for Drilling Rig or Construction Barge ( If anchor radius supplied above, not necessary)
Anchor Name or No. Area Block X Coordinate Y Coordinate Length of Anchor Chain on Seafloor

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

X = Y =

Form BOEM- 0137 (December 2011

- Supersedes all previous editions of this form which may not be used.) Page 2 of 4 C 

## X

X
X

36

Expired - RUE Submittal 

### Garden Banks
169

S 

## 1,650'

W 

## 3,500'


# 1,920,140'
10,091,730'

27.8071153

-92.1344270

821' 

## 4,867' 423,942Y = 10,090,080'

Y = 10,074,240'

Y = 10,058,400'X = 1,916,640'X = 1,932,480'



# 213 214 212 168

256 169 170

257 258

British-Borneo 1 AP A Loc. “A” AP

A Loc. “B”

AP

A Loc. “C” SL SL

SL Loc. A (SL) 3,155' FSL 655' FWL Loc C (SL) 1,650' FSL 3,500' FWL Loc. B (SL) 3,520' FSL 1,797' FWL



### Surface Location Map
1" = 4000' AP ACHE DEEPW

A TER, LLC Garden Banks 213 OCS-G 31613 Apache Loc. GB 213 A

Surface Location Apache Loc. GB 213 B Surface Location

Apache Loc. GB 213 C Surface Location 3,155' FSL

& 655' FWL

of GB 169 X = 1,917,295' Y = 10,093,235' Lat. = 27.81 131 1 1 27 48' 40.720" Long. = -92.1431972 -92 08' 35.510" 3,520' FSL & 1,797' FWL

of GB 169 X = 1,918,437' Y = 10,093,600' Lat. = 27.8122934 27 48' 44.256" Long. = -92.1396557 -92 08' 22.761"

1,650' FSL

& 3,500' FWL

of GB 169 X = 1,920,140' Y = 10,091,730' Lat. = 27.8071 153 27 48' 25.615" Long. = -92.1344270 -92 08' 03.937"

5/28/13Y = 10,090,080'

Y = 10,074,240'

Y = 10,058,400'X = 1,916,640'X = 1,932,480'



# 213 214 168

256 212 169 170

257 258 AP A Loc. “A” AP A Loc. “B” AP

A Loc. “C” SL SL

SL



### STRUCTURE MAP

Bathymetry Map 1" = 4000' AP ACHE DEEPW

A TER, LLC Garden Banks 213 OCS-G 31613 C.I. = 20' 

### -900' -1000' -1 100'

-800'

5/28/13Apache Deepwater LLC Page B

‐ 1 Revised Initial Exploration Plan June 18, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### 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) 30,000 bbl / well total Oil-based (diesel, minerals, oil) 0 bbl / well total Synthetic-based (internal olefin , ester) 13,948 bbls / well total Product Name Amount to be Used M-I Bar 5,800,200 lbs / well total Synthetic B 582,112 gal / well total

Suremul 12,192 gal / well total Surewet 6,336 gal / well total Rheflat 1,848 gal / well total Rhethik 891 gal / well total

Lime 61,680 lbs / well total Calcium Chloride 201,840 lbs / well total

C. NEW OR UNUSUAL TECHNOLOGY Apache Deepwater does not propose to use an y new or unusual technology to carry out the proposed exploration activities.

D. BONDING STATEMENT The bond requirements for the activities and facili ties proposed in this EP are satisfied by a $3,000,000.00 area wide 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 Natio nal 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 CF R Part 253 and NTL No. 2008-N05 - “Guidelines for Oil Spill Financial Responsibil ity for Covered Facilities”.Apache Deepwater LLC Page B

‐ 2 Revised Initial Exploration Plan June 18, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### F. DEEPWATER WELL CONTROL STATEMENT Apache Deepwater LLC, (company number 03165) has the financial capabil ity 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 Disc harge (WCD) modeled for this scenario is 395,611 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, dr illing a relief well to kill the blowout. The expected maximum time frames fo r 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 96 Days.
Maximum discharge volume The following table is a linear estimate of th e 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 395,611 2 791,222
Surface Intervention 395,611 15 5,934,165

Relief Well 395,611 96 37,978,656

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 drawdow n calculated between the formation and the open hole section. A Merlin reservoir simulation mode l was used to investigate the well conditions during the WCD blowout scenario. The estimated reservoir pressure is 17,437 psi. The reservoir model estimates bottom hole flowing pressures, ba sed upon reservoir properties and flow rates. The calculated drawdown is modeled to be 4,619 psi.Apache Deepwater LLC Page B

‐ 3 Revised Initial Exploration Plan June 18, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### In our experience in the deepwater GOM, we stri ve 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 reduc ing the rates that 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 4.6 times or greater than our operating practices,

 The blowout occurs in a long open hole s ection 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 th e conditions cited are estimated not to exceed 2 days.

Surface intervention to stop the blowout In the event of a blowout and assuming the blow out prevention equipment is still intact; the subsea BOP will be used for succes sful shut-in of the well. The well would then be killed and re-entered to either abandon or return to norm al 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 abil ity 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 sy stem to achieve successful containment of the well. The system will be employed, while simultaneously initiating relief well planning and operations. Specifics will be submitted within the Well Containment Plan. Typically blowouts can be controlled with surf ace 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 uncont rolled blowout and the MODU has sunk with displacement from the wellhead. Additionally, it assu mes 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 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 para llel. 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 Revised Initial Exploration Plan June 18, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### 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 a platform as a relief well location. Relief well location and drilling strategy Proprietary InformationApache Deepwater LLC Page B

‐ 5 Revised Initial Exploration Plan June 18, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### Relief well rig availability The rigs listed below could be ava ilable for relief well operations:

Rig Name Contractor Rated Water Depth MODU Type Rig Status

Ocean Victory Diamond 5,500 Moored Semi Contracted GOM Amos Runner Noble 8,000 Moored Semi Contracted GOM Jim Thompson Noble 6,000 Moored Semi Contracted GOM Driller Noble 5,000 Moored Semi Contracted GOM Deepwater Nautilus Transocean 8,000 Moored Semi 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 require ments and will be re-inspected in transit, prior to drilling a relief well to th e required true vertical depth. Relief well rig contract and mobilization timing A suitable rig could be selected and a contra ct finalized in 48 hours after undertaking the decision to begin relief well operations. Ba ckup tubular goods 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 su spend 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 96 days and is summarized be low. The relief well with surface location of GB 213 Location B was used for this example.Apache Deepwater LLC Page B

‐ 6 Revised Initial Exploration Plan June 18, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### 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 10 26 Spud and drill to the top of the zone of interest and set casing. 60 86

Mag-Range relief well into intersecting position. 5 91 R/U pumping equipment and kill well. 5 96 R/D Pumping Equipment, PA Wellbore, Pull Riser, and Demobilize 15 111

Blowout Prevention and Intervention Summary of prevention measures Apache Deepwater LLC has maintained a safe track record of prudent op erations 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 de sign, drilling and completion operations.

 BOP Certification, BOP Drills, Pit Dril l’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 duri ng 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 displ acements 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.Apache Deepwater LLC Page B

‐ 7 Revised Initial Exploration Plan June 18, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### The utilization of Pre-Job Safety meetings will continue to be implemented prior to each operation with all of the rig crew s. 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. Early well control intervention In the event of a blowout situation, due to fa iled 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, we ll kill operations can be initiated through the existing wellbore. Well control engineering services Apache will have service agreements in pla ce 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 isolat ion techniques, all cementing operations will be modeled and designed under the gu idelines set forth in API Recommended Practice 65 Part 1 & 2. Operations will be dictated by the rules and requirements set forth in Federal Regulations, under the wellbore cementing requirements.
API Standard 53 for Blowout Prevention E quipment Systems for Drilling Wells and Recommended Practice 16Q for Marine Drilling Ri sers will be used as the guidelines for installation, testing and mainte nance 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 preven tion 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, an d integrity of the drilling equi pment and preservation of the environment for floating marine drilling opera tions. These recommended practices help to facilitate the broad availability of prove n, sound engineering and operating practices. These practices are considered acceptable for accomplishing BOP and Marine Riser associated operations. However, equivalent alternative inst allations 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 Revised Initial Exploration Plan August 20, 2013 Garden Banks Block 213 (OCS

‐ G 31613) 

### 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 Garden Banks Block 213 by Geoscience Earth & Marine Services, Inc. (GEMS). One (1) copy of 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 th e proposed surface locatio ns utilizing the 3-D seismic exploration data and is included as Attachment C-4.

G. HIGH-RESOLUTION SEISMIC LINES Proprietary Information

H. STRATIGRAPHIC COLUMN Proprietary Information

I. TIME VS DEPTH TABLES Proprietary Information10615 Shadow Wood Drive, Suite 200 Houston, Texas 77043 713.468.1410[o] 713.468.1438 [f] www.gemsinc.com

May 14, 2013 Project No. 0712-2118b Apache Deepwater LLC 2000 W. Sam Houston Parkway South Suite 1600 Houston, TX 77042

Attention: Mr. John Worthen



### Site Clearance Letter Proposed Wellsite GB213-A

Block 213 (OCS G-31613) Garden Banks Area Gulf of Mexico

Apache Deepwater LLC (Apache) contracted Geoscience Earth & Marine Services, Inc. ® , (GEMS) to prepare a Site Clearance Letter for the proposed bottom hole location in Block 213 (OCS G-31613), Garden Banks (GB) Area. The surface location for GB213-A is in Garden Banks Block 169. This letter addresses specific seafloor and subsurface geologic conditions around the proposed location to the limit of investigation, 4,282 ft below the mudline (bml). Apache will drill the proposed GB213-A with an anchored semi-submersible drilling rig. The seabed conditions within a 5,946 ft mooring radius plus an additional 1,000 ft buffer zone are discussed to satisfy seabed disturbance guidelines.
Surface conditions are clear at t he proposed wellsite; however, moorings or other seabed disturbance activities need to avoid unidentified sonar contac ts and potential sites for benthic communities. Overconsolidated soils will exist beneath a thin drape of soft clays. A sandy interval with some potential for shallow gas occurs at 594 ft bml to 1,475 ft bml. This letter provides the following details specific to the well location: available data, attachments (accompanying the letter), Notice to Lessees (NTL) r equirements, man-made features and archaeological assessment, wellsite conditions, anchoring consider ations, and the conclusions and recommendations.


### Proposed Well Location and Available Data The proposed GB213-A surface location lies in the s outhwestern corner of GB 169 (Figure GB213-A-1). Apache provided the following coordinates:
Proposed Wellsite GB213-A (Surface Location GB 169) Spheroid & Datum: Clarke 1866, NAD27 Projection: UTM Zone 15 North Line Reference Block Calls GB 169 X: 1,917,295 ft Latitude: 27o 48’ 40.72” N Inline 4899 655 ft FWL Y: 10,093,235 ft Longitude: 92o 08’ 35.51” W Crossline 5212 3,155 ft FSL
The details provided in this letter are based on t he findings from a geohazard assessment performed by GEMS (GEMS, 2013a). The report, which was subm itted to Apache in January 2013 described the geologic and archaeological conditions within the Bimini Prospect (GB 168 and GB 213 and surrounding area). Apache provided two sets of geophysica l data for this assessment: a conventional, 3-D exploration seismic volume and high-resoluti on Autonomous Underwater Vehicle (AUV) data. The detailed data specifications are provided in the ma in report (GEMS, 2013a). Integrating these data allowed a thorough analysis of potential drilling hazard s within the suprasalt stratigraphy at the proposed wellsite. In addition, a seafloor survey was con ducted in February, 2013 using a Remotely OperatedProposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 2 FORUM ENERGY TECHNOLOGIES, INC. Vehicle (ROV). The survey documented seabed sedim ent distribution, assessed types and diversity of benthic communities, and investigated several unident ified sonar contacts delineated in the geohazard survey (GEMS, 2013b).



### Attachments The maps and accompanying illustrations were extract ed from the available data provided by Apache. A moored semi-submersible drilling platform is planned for this location; therefore, a maximum anchor radius of 5,946 ft and an additional 1,000 ft buffer zone are included on the maps. The figures embedded within the body text are also provided below. Map No. GB213-A-1: Bathymetry Map Map No. GB213-A-2: Seafloor Features Map Map No. GB213-A-3: Side-Scan Sonar Mosaic Map No. GB213-A-4: Geologic Features Map Illustration GB213-A-1: Portions of Inline 489 9 and Crossline 5212 Showing Conditions Beneath Proposed Wellsite GB213-A Illustration GB213-A-2: Tophole Prognosis C hart, Proposed Wellsite GB213-A, Garden Banks, Block 213 Figure GB213-A-1: Regional Rendering of the Garden Banks Area, Gulf of Mexico Figure GB213-A-2: Power Spectrum Anal ysis Curve, Proposed Wellsite GB213-A Figure GB213-A-3: Seafloor Cond itions at the Proposed Wellsite

Figure GB213-A-1 . Regional Rendering of the Garden Banks Area, Gulf of MexicoProposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 3 FORUM ENERGY TECHNOLOGIES, INC. 

### NTL Requirements The following letter complies with the Bureau of Ocean Energy Management (BOEM) Notice to Lessees (NTL’s) 2008-G04, 2008-G05, 2009-G39, and 2009-G40, (MMS, 2008a,b and 2010a,b). The requirements set forth in NTL 2005-G07 are applicable because the Federal lease block GB 213 is considered to be a high probability archaeological block (MMS, 2005 and BOEM, 2011). In compliance with NTL 2005-G07, the required archaeological assessment was performed by GEMS and included as an appendix in the main report (GEMS, 2013a). Garden Banks Blocks 168, 169, and 213 are located in Military Warning Area W-147 AB. Drilling operations, therefore, must be coordinated with the appropriate military command as per NTL 2009-G06 (MMS, 2009). According to NTL 2008-G05 (MMS, 2008b), 3-D seismi c reflection data may be used for shallow hazard assessments with approval from the BOEM, Gulf of Mexico Region. A power spectrum analysis was conducted from the 3-D seismic da ta cube provided by Apache to illustrate the data parameters (Figure GB213-A-2). The power spectrum curve was ge nerated within a 500 ft radius of the intersection of the inline and crossline at the proposed wellsite. 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 GB213-A-2 . Power Spectrum Analysis Curve, Proposed Wellsite GB213-A


### Man-Made Features and Archaeological Assessment The surface location is clear of any wells, pipelin es, or platforms within a 2,000 ft radius from the proposed wellsite. The closest existing well (McM oran GB 168-001) is located approximately 3 miles west-northwest of the proposed wellsite locati on in GB 169 (Map GB 213-A-1). The well was an exploratory well and has been plugged and abandoned. No pipelines or umbilicals occur within 3 miles of the proposed location.
GEMS delineated nine unidentified side-scan sonar c ontacts within 6,946 ft (5,946 ft maximum anchor radius plus 1,000 ft buffer) of the proposed GB213-A wellsite (Maps GB213-A-2 and 213-A-3). None of the nine contacts appear to represent cultural resources and no target has been recommended for archaeological avoidance or investigation. In additi on, these contacts were investigated during an ROVProposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 4 FORUM ENERGY TECHNOLOGIES, INC. survey in February 2013 (GEMS, 2013b). Contacts Nos. 32 through 43 were man-made debris which included piles of modern cable or rope, a steel beam, and a 55-gallon drum. These objects do not appear to be of archaeological significance. No archaeol ogical or hazard avoidance is recommended for these objects. Contacts Nos. 45 through 51 were small patches of carbonate rubble and rock with anemones and a few other benthic organisms. Only Contact No. 51 showed any appreciable relief. A 100 ft avoidance is required by NTL 2009-G39 for t he outcrop represented by Contact No. 51.

Sonar Contacts Located Within 6,946 ft of GB213-A

No. Area Block Length (ft) Width (ft) Height (ft) Shape X NAD27

(ft) Y NAD27

(ft) ROV Identification of Contact Avoidance Radius (ft)

32* GB 168 27.21 5.12 0.00 Linear 1915172.17 10096921.19 Pile of cable 0

38* GB 168 42.69 2.07 0.00 Linear 1915827.66 10094509.00 Steel beam 0

39* GB 169 16.46 3.21 0.00 Irregular 1921872.49 10094142.83 Pile of cable 0

42* GB 169 12.55 3.01 0.00 Linear 1920493.75 10093433.92 55-gallon drum 0

43* GB 168 12.06 2.51 0.00 Linear 1912268.41 10092780.58 Rock outcrop 0

45* GB 168 33.11 5.12 0.00 Linear 1912569.00 10091898.82 Rock outcrop 0

46* GB 168 18.58 9.03 0.00 Irregular 1912591.60 10091862.18 Rock outcrop 0

47* GB 168 14.76 6.04 0.00 Irregular 1912890.96 10092189.33 Rock outcrop 0

51* GB 212 18.56 8.03 20.36 Irregular 1915932.82 10087450.33 Rock outcrop 100 *Sites investigated during ROV survey in Feb. 2013 (GEMS, 2013b).


### Wellsite Conditions The proposed surface location is clear of any constrai ning seafloor geologic conditions as defined by the available geophysical data. GB 213-A is not expect ed to intersect faults (seabed or buried) and the potential for encountering significant amount s of shallow gas is generally low. Water Depth and Seafloor Conditions The water depth at the proposed surface location is approximately -919 ft and the seafloor slopes northnorthwest at 2.7° (Map GB213-A-1). The seabed is re latively featureless within 2,000 ft of the proposed wellsite (Map GB213-A-2).
Side-scan sonar data show that the s eabed in the vicinity of the proposed wellsite is characterized by uniform, low-reflectivity sediments (Map GB213-A-3). The low reflectivity is caused by a drape of soft clays. Subbottom profiler data indicate a 10 ft thick acoustic ally transparent layer at the seabed (Figure GB213-A3). The drape overlies intervals of parallel bedded and ac oustically amorphous sediments. The drape thins to the south and southeast along the flank of Muskogee Mound.Proposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 5 FORUM ENERGY TECHNOLOGIES, INC.

Figure GB213-A-3 . Seafloor Conditions at the Proposed Wellsite Biologically Sensitive Features and Deepwater Benthic Communities The water depth at GB213-A is less than 300 m (984 ft); therefore, guidelines set forth in NTL 2009-G39 (MMS, 2010a) are in effect. There are no apparent geophy sical indicators at the seafloor or at depth that would suggest conditions capable of supporting bi ologically sensitive benthic communities in the immediate vicinity of the proposed lo cation (Maps GB213-A-2 and GB213-A-3). The 300-m contour, defining deepwater areas, oc curs about 1,200 ft to the north of the GB213-A proposed location. The deepwater portion of the 2,000 ft radius shows no features or conditions indicative of hydrocarbon seepage or hardgrounds; t herefore, there is a negligib le potential for deepwater benthic communities within 2,000 ft of the proposed location. Stratigraphy Stratigraphic conditions are shown on Illustrations GB213-A-1 and GB213-A-2. The sediments below the seafloor to the limit of investigation (4,282 ft bml or -5,201 ft bsl) consist primarily of hemipelagic clays, muddy- to sand-prone turbidites, and mass-transport deposits. The shallow stratigraphy (Seafloor to Horizon 10) is interpreted to be hemipelagic, clay-rich sediments down to approximately 96 ft bml. The surficial 10 ft thick drape will consist of soft, normally consolidated sediments. Beds beneath the drape thin and pinch-ou t to the south along the flank of Muskogee Mound. Bed truncations indicate unconformities in the shallow section. Soils will likely increase in shear strength and become overconsolidated above Horizon 10. St iffer than normal sediments should be expected when installing the surface conductor. The sequence from Horizon 10 to Horizon 40 cons ists of bedded hemipelagic sediments and mud-rich turbidites (Illustrations GB213-A-1 and GB213-A-2). Horizons 20 and 30 appear to onlap Horizon 40 to the north of the proposed location. The interval from Horizon 10 to Horizon 40 is about 498 ft thick. Beneath Horizon 40 (594 ft bml) the sequence shows discontinuous to bedded reflectors of low to moderate amplitudes. The interval likely repres ents turbidites that hav e been disrupted by faulting caused by uplift of the diapir beneath Muskogee Mound. Scattered small amplitude events within this interval suggest sand-rich layers and seams. The turbidite interval extends from 594 ft to 1,475 ft bml.Proposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 6 FORUM ENERGY TECHNOLOGIES, INC. The section from 1,475 ft to 3,506 ft bml consists of layers of chaotic mass-transport sediments. The lowamplitude character of these interval s suggests mud-rich sediments. The section from 3,506 ft to the limit of the invest igation (4,282 ft bml) consists of steeply dipping beds along the flank of the salt diapir. Turbidites consisting of alternating layers of clay, silt, and sand comprise this interval.
Faults A vertical wellbore at the proposed location will no t penetrate seafloor or buried faults between the seafloor and the limit of investi gation (Illustrations GB213-A-1 and GB213 -A-2). However, the top of a buried fault occurs a few hundred feet southeast of the proposed wellsite GB213-A. The fault is downthrown southeast away the wellbore and is buried by at least 550 ft of sediment.
Shallow Gas and Shallow Water Flow
Shallow Gas. No high-amplitude events will be intersect ed by the wellbore beneath GB213-A; however, a few small events occur along the fault plane to the s outheast of the location. The moderate amplitude of the interval beneath Horizon 40 (594 ft to 1475 ft bm l) has some potential for shallow gas. Pressures significantly greater than hydrostatic are not antici pated but drillers may notice an increase in the amount of solution gas when penetrating this interval.
Shallow Water Flow. There is a negligible to low potential for overpressured sands in this area. The deformation of the section by faulting, folding, and erosion has likely allowed any overpressured sands to dewater through time. In addition, most of the sequences appear to be mud-rich units. 

### Anchoring Considerations The 5,946 ft radius outlined on the accompanying maps represents the area of potential effect for anchoring. An additional 1,000 ft buffer zone is also included although, technically, this buffer is only required in deepwater areas (i.e. >300 m or 984 ft) as specified in NTL 2009-G40. The following discussions address the seafloor conditions related to anchoring considerations within the total 6,946 ft radius. Water Depth and Seafloor Conditions Water depths within the potential mooring area rang e from about -610 ft to -1,260 ft (Map GB213-A-1). The seafloor generally slopes to the north away from an east-west trending topographic high that crosses the southern one-third of the mooring radius. The s hallowest water depths within the anchor radius are associated with this high. The elongated topographi c high approximates the crest of Muskogee Mound. The seafloor slopes to the south into deeper wa ter on the southern margin of the high. Seafloor gradients within th e northern two-thirds of the mooring radius range from 2° to 4°. The seabed in this area consists of soft, clay-rich sediments. T he normally consolidated clay sediments thicken to the north away from the topographic high in the southeast. The normally consolidated silty clays will range from 10 ft at the proposed wellsite to over 200 ft alon g the northern boundary. The normally consolidated drape will pinch-out a few hundred feet south of the proposed wellsite. Relatively stiff, overconsolidated sediments will occur throughout most of t he southern half of the mooring pattern. The irregular seabed in the southern one-third of t he mooring pattern occurs along the flanks of the topographic high. Slopes ranging from 6° to 12° are common (GEMS, 2013a). Local gradients of 25° are associated with some high-relief carbonate outcrops. Ar eas of nearly flat seafloor occur along the crest of the topographic high in the southeas t quadrant of the mooring pattern. The irregular seafloor morphology is associated with carbonate hardgrounds probably representing relict reef formations. The hardgrounds include large boul ders, pinnacles, and slabs (Map GB213-A-2). The area around the hardgrounds and across the relatively flat-topped crest of Muskogee Mound consists of muds with varying amounts of sand to cobble-sized carbonate rubble. The hi gh-relief outcrops exhibit a rough and rocky character on side-scan sonar records (Map GB213-A-3). The flat-lying areas consistingProposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 7 FORUM ENERGY TECHNOLOGIES, INC. of muds with varying amounts of sand to cobble-size d carbonate rubble show a uniformly high reflectivity seabed but lack the “rocky” texture. Portions of Muskogee Mound are affected by seafloor faults. Low-relief, northwest-southeast trending fault escarpments occur along the southwestern edge of the anchor radius (Map GB213-A-2). East-west trending escarpments occur within the southern and southeastern portion of the mooring pattern. The faults will not be a constraint to anchoring. A few scattered seafloor depressions or “pockmarks” occur in the western half and near the northern border of the mooring pattern (Map GB213-A-2). Th e pockmarks are not asso ciated with gas-charged sediments at the seafloor. In addition, there are no indications on the seabed of hydrocarbon seepage or the presence of hardgrounds with in the pockmarks (Map GB213-A-3). Biologically Sensitive Communities and Deepwater Benthic Communities Most of the mooring pattern will occur in water depths less than 300 m (984 ft); therefore, NTL 2009-G39 guidelines regarding biologically sensitive communiti es will apply to rig and anchor placement (MMS, 2010a). Lithified hardgrounds of moderate to high re lief (i.e., 8 ft or greater) occur along the flanks of Muskogee Mound in the southern half of the mooring pattern (Map GB213-A-2). The hardgrounds support sessile invertebrates and attract large numbers of fish. The hardgrounds will need to be avoided by 30 m (~100 ft) by rig placement, construction barg es, and supporting anchors, chains, cables and wire ropes. The mooring pattern north and west of the proposed wellsite will extend into water depths greater than 300 m (Map GB213-A-2). No features occur within the deepwater portion of the mooring pattern that are likely to be sites of deepwater benthic communities. A few subtle depressions occur to the north and west of the proposed wellsite; however, the AUV data over these depressions show no indications of gascharged sediments or hardground formati on at the seabed (Map GB213-A-3).



### Conclusions and Recommendations We appreciate the opportunity to be of service to Apache and look forward to working with Apache on future projects. The conclusions and recommend ations from this assessment are as follows:
Wellsite Conditions No major seafloor hazards or constraints are defined by the available data within a 2,000 ft radius of the proposed location. Shallow soils are likely to be stiffer and more consolidated than typical slope soil profiles. Caution is recommended when drilling through the turbidite interval between 594 ft and 1,475 ft because of the presence of amp litude events along a nearby fault plane.
Anchor Maximum Radius Conditions The potential seafloor constraints within the moorin g radius include possible hard grounds that could support biologically sensitive communities. A minimum avoidance of 30 m (~100 ft) is recommended around the moderate to high relief hardgrounds. In addition, a 100 ft shallow hazard avoidance is recommended for side-scan sonar contact No 51 which is a rock outcrop >8 ft high within the mooring pattern. If any potentially historic materials such as textiles, wood, ceramics, or other items be uncovered during operations in the area all operations mu st cease and BOEM notified within 48 hours. The proposed wellsite and its moorin g pattern occur within the Militar y Warning area W-147-AB. Drilling operations will need to be coordinated with the appropriate military command prior to commencement.Proposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 8 FORUM ENERGY TECHNOLOGIES, INC. Sincerely,
GEOSCIENCE EARTH & MARINE SERVICES, INC. ®

Thomas Neurauter Ph.D. Daniel Lanier Senior Marine Geologist Vice President-Geosciences

Attachments (4 Maps and 2 Illustrations)
Distribution: Mr. John Worthen, Apache Deepwater LLC (3 copies)

REFERENCES Bureau of Ocean Energy Management, 2013a, ASCII Data F iles, published on the BOEM Gulf of Mexico Region Homepage, <http://www.gomr.boem.gov/homepg/pubinfo /freeasci/freedesc.html>, accessed January, 2013. Bureau of Ocean Energy Management, 2013b, Seismic Water Bottom Anomalies Map Gallery, published on the BOEM Homepage, <http://www.boem.gov/Oil-and-Gas-E nergy-Program/Mapping-and-Data/Map-Gallery/SeismicWater-Bottom-Anomalies-Map-Gallery.aspx>, accessed April, 2013. Bureau of Ocean Energy Management, 2011, Notice to less ees and operators (NTL) of federal oil and gas leases and pipeline right-of-way (ROW) holders on the outer continen tal shelf (OCS), Revisions to the list of OCS lease blocks requiring archaeological resource surveys and report s: U. S. Department of the Interior, Bureau of Ocean Energy Management, Bureau of Safety and Environment al Enforcement Gulf of Mexico Region (GOMR), NTL 2011- JOINT-G01. Effective Date December 29, 2011. Coffeen, J. A., 1978, Seismic Expl oration Fundamentals: Tulsa, the Pe troleum Publishing Co., p. 125. Geoscience Earth & Marine Services, Inc. ® (GEMS), 2013a, Geohazard assessm ent, Bimini Prospect, Blocks 168 and 213, (OCS-G-34516 and OCS-G-31613) Garden Bank Ar ea, Gulf of Mexico, Project No. 0712-2118b. Geoscience Earth & Marine Services, Inc. ® (GEMS), 2013b, Seafloor verifica tion study using ROV data, Bimini Prospect, Blocks 168 and 213, (OCS-G-34516 and OCS-G-31613) Garden Bank Area, Gulf of Mexico, Project No. 0712-2118b. 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 s helf, Gulf of Mexico OCS region, Archaeological resource surveys and reports: U. S. Department of the Interior, Mi nerals 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 shel f, Gulf of Mexico OCS region , information re quirements for exploration plans and development operat ions coordination documents: U. S. De partment of the In terior, 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 Managem ent Service, Gulf of Mexico, NTL 2008-G05. Minerals Management Service, 2009, 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, Military Warning and Water Test Areas: U. S. Department of the Interior, Mineral s Management Service, Gulf of Mexico, NTL 2009-G06. Minerals Management Service, 2010a, Notice to lessees and operators of federal oil a nd gas leases in the outer continental shelf, Gulf of Mexico OCS region, Biologic ally-Sensitive Underwater Features and Areas: U. S.Proposed Wellsite GB 213-A Clearance Letter Apache Deepwater LLC // May 14, 2013

Geoscience Earth & Marine Services, Inc. ® // 9 FORUM ENERGY TECHNOLOGIES, INC. Department of the Interior, Minerals M anagement Service, Gulf of Mexico, NT L 2009-G40. Effective Date January 27, 2010. Minerals Management Service, 2010b, Notice to lessees and operators of federal oil a nd 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, NT L 2009-G40. Effective Date January 27, 2010.