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Home My WebLink About202-1671. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Well lock 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,142' N/A Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 6,590psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MPSP (psi): Plugs (MD): MILNE PT UNIT H-13A Milne Point SCHRADER BLUFF OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: 4,109' Surface Surface 23 Surface & 5,326' Subsequent Form Required: Suspension Expiration Date: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/1/2026 6,198' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 / ADL0025906 202-167 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22818-01-00 Hilcorp Alaska LLC C.O. 477.05 Length Size Proposed Pools: 112' 112' TVD BurstMD N/A PRESENT WELL CONDITION SUMMARY 7,910psi 5,750psi 7,240psi 2,908' 4,016' 4,109' 3,880' 6,742' 112' 20" 9-5/8" 7" 3,880' 4"2,500' 6,742' Perforation Depth MD (ft): 9,142' See Schematic See Schematic 7" x 4.5" SC-1R and N/A 6,642MD / 4,002TVD and N/A Taylor Wellman twellman@hilcorp.com 907-777-8449 4-1/2" 12.6 / L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.12.09 12:29:21 - 09'00' Taylor Wellman (2143) 325-748 By Grace Christianson at 3:10 pm, Dec 09, 2025 TS 12/12/25 DSR-12/9/25MGR17DEC2025 * State witness cement in all annuli before welding plate. 24-hour notice. * Photo document as described. 10-407 JLC 12/17/2025 12/18/25 OA Well Lock Well: MPU H-13A Date: 11/15/2025 Well Name:MPU H-13A API Number:50-029-22818-01-00 Current Status:Suspended Pad:H-pad Estimated Start Date:1/1/2026 Rig:Fullbore Regulatory Contact:Tom Fouts Permit to Drill Number:2021670 First Call Engineer:Ryan Thompson 907-564-5005 Second Call Engineer:Taylor Wellman 907-777-8449 AFE Number:Job Type:OA Well lock Bottom Hole Pressure 894 psi @ 1,986 TVD UGNU - Normally pressured MPSP 23 psi (max WHP recorded in last year) Brief Well Summary: MPH-13A was drilled in September 2002 as a Schrader Bluff N sand ESP producer . During the 2009 RWO a tight spot was encountered at 304-320 while pulling and running the ESP completion. A caliper was run on the 7 casing during the 2009 RWO indicating bends in the casing from 260 286. A reservoir P&A was pumped by coil in July 2014 and tagged @ 5,326 CTM after passing a MIT- T & MIT-IA. The well was now classified as suspended. In May of 2015, Nordic 3 performed an MIT-IA to 1500 psi & cut tubing @ 250, recovering the tubing & ESP cable, performed a 7 casing punch @ 203 and circulated cement into the OA w/ 5 bbls of returns. Cement was now at surface across all annuli. In Dec 2017 as preparations were made for surface abandonment, ~40 psi of WHP was observed on the OA, after multiple bleed attempts the OA continued to re-pressurize. In May of 2018, 6 gallons of welllock was pumped into the OA achieving squeeze pressure of 1680 psi. A passing MIT-OA was then performed to 1068 psi. In May 2024, the well was being prepared for cutting off of the wellhead. While bleeding off the IA, fluid flow was observed and further diagnostics showed that the fluid in the Tbg/IA was slowly inflowing. Sundry 324-536 was approved in December 2024 to mill out cement in the 7 casing and perform a remedial cement job across all annuli at the 9 5/8 window and then re-cement at surface. Following the initial cement job, TOC was tagged at 3497 but the well failed an CMIT-TxIxO to 1500 psi and the OA pressured up 44 psi. A second cement job was completed laying in cement from 2952 to 2500 in the 4 ½, setting a cement retainer at 2000 pumping 35 bbls of cement into the OA and laying in cement to surface in the tubing and from the tubing stub @ 250 in the 7 casing. The well passes a CMIT-TxIA to 1500 psi but fails an CMIT-TxIxO and an MIT-OA to 1500 psi losing 450 psi in 15 minutes. This sundry submittal is a change of program to approved sundry 324-536 in order to complete abandonment operations and obtain a passing MIT of surface cement for all annuli. OA Well Lock Well: MPU H-13A Date: 11/15/2025 Notes Regarding Wellbore Condition Cement to surface in all annuli. Well passed CMIT-TxI to 1500 psi 7/22/25 Well fails MIT-OA to 1500 psi 7/26/25 Open bleed on OA produced zero returns (105 min) 9/28/25 Objective: To complete the surface abandonment by re-squeezing the OA with well lock resin and perform a passing state witnessed CMIT-TxIxO. Surface excavation and cut & cap of the well. Procedure DHD/Special Projects 1. ND OA Gate Valve, NU OA Integral. 2. Well Lock (or similar) squeeze on OA to 2500 psi 3. Re-treat OA if necessary. 4. ND OA Integral, NU OA Gate Valve. 5. Perform AOGCC witnessed CMIT-TxIxO to 1500 psi Operations 1. Photo document all steps. 2. Cut off all casings and wellhead 3 below tundra. 3. Top off tubing and annuli with cement if needed. 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska, LLC. b. Permit to Drill Number 202-167 c. Well Name MPU H-13A d. API Number - 50-029-22818-01-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. As-built Schematic _____________________________________________________________________________________ Revised By: TDF 12/3/2025 SCHEMATIC Milne Point Unit Well: MPU H-13A Abandoned: 5/15/2015 PTD: 202-167 6-1/8 Hole TD @ 9,142 Baker GPV 5 Guide Shoe N-Sand Horizontal CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc.Mod 8.835 Surface 3,880 7" Intermediate 26 / L-80 / Btc Mod 6.276 Surface 6,742 4 Liner 9.5 / L-80 / 521 Hydril 3.548 6,642 9,142 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / N/A 3.958 250 6,198 JEWELRY DETAIL No Depth Item 1 2,000 Cement Retainer 4-1/2 CICR 2 2,955 Cement Retainer 4-1/2 CICR 3 3,550 Cement Retainer 4-1/2 CICR 4 3,920 Cement Retainer 4-1/2 CICR 5 5,280 Cement Retainer 4-1/2 CICR 6 6,140 D&D Tubing Stop 7 6,142 D&D Pack-off Assembly Top 8 6,151 Centrilift TTC-ESP Top 9 6,159 TTC Drilled Tubing Crossover 10 6,169 Tandem Seal Sections 11 6,183 Motor 12 6,192 PumpMate XTO w/ 6 Fin Centralizer 13 6,642 7 x 4.5 SC-1R Packer 14 6,688 4.5 CMD Sliding Sleeve OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24 Hole 9-5/8" Cmt w/ 1,948 sks PF E,2785 sx Class G & 200sx PFC in 12-1/4 Hole 7 Cmt w/ 230 sks Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 400 Max Hole Angle = 71.1 deg. @ 6,000 Hole Angle @ TTC-ESP= 75Deg. TREE & WELLHEAD Tree Cameron 4-1/16 5M Wellhead 11 x 11 5M FMC Gen 6, w/ 11 x 4-1/2 FMC Tbg. Hngr. 4-1/2 521 Hydril T&B, 4 H BPV Profile GENERAL WELL INFO API: 50-029-22818-01-00 Drilled and Cased by Nabors 22E - 10/22/1997 De-completed for Sidetrack by Nabors 4ES 7/25/2002 Sidetrack & ESP Completion w/ Doyon 141 9/12/2002 ESP Change-out w/ Nabors 4-ES 12/8/2004 Convert to TTC-ESP w/ Nabors 4-ES 11/14/2009 Punch Holes / Coil Cement 7/31/2014 Abandonment by Nordic 3 5/15/2015 20 Howco 9-5/8 ES Cementer @ 2,113MD Orig.DF Elev.:66 (N 22E)/ GL Elev.: 36.7 /Orig. DF to Csg. Hgr.= 30.62(N 22E) 7 8 & 9 10 11 12 13 9-5/8 6&7 203 Cement Plug Tag Cement @ 5,326 CTM Window Cut in 9-5/8 3,880 to 3,910 14 PunchTbg 6,110 to 6,120. 37 Joints of 4 Screen C27 Baker Med. Excluder 2000 w/ 37 of 4 Blank & 5.75 OD Centralizer Alternating TD =9,142 (MD) / TD = 4,109(TVD) PBTD =Surface (MD) / PBTD = Surface (TVD) Punch 5,295 to 5,300 2 4 3 5 1 A B C D F G E PUNCH DETAIL Letter Top (MD) Btm (MD) Size SPF Date A 233 238 2 6 7/5 & 7/6/25 B 2,040 2,050 3.13 4 7/10/2025 C 2,980 2,985 1.56 10 7/5/2025 D 3,600 3,605 2 4 7/2/2025 E 3,750 3,755 1.56 4 6/29/2025 F 4,005 4,010 2 4 6/29/2025 G 5,295 5,300 2 4 6/29/2025 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Scott Pessetto; Lau, Jack J (OGC) Cc:Taylor Wellman; Aubrey Malik; Josh Stephens Subject:20250707 1627 APPROVAL MPU H-13A (PTD 202-167) P&A Sundry 324-536 Date:Monday, July 7, 2025 4:28:16 PM Scott, Hilcorp’s planned placement of cement in 7” X 9-5/8” annulus as described below is approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Taylor Wellman, Malik, Stephens From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Monday, July 7, 2025 10:10 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Taylor Wellman <twellman@hilcorp.com>; Aubrey Malik <Aubrey.Malik@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com> Subject: MPU H-13A (PTD 202-167) P&A Sundry 324-536 Jack, CTU #2 was unable to get circulation on H-13A yesterday after punching holes as planned. We suspect that OA may be cemented off near the upper or lower punch/perfs. We were able to get injectivity through the retainer but never saw returns to surface. We attempted a re-punch at 250’ but still couldn’t get injection down the OA to the lower perfs. The proposed plan forward is to squeeze off the perfs below the retainer, perforate and set a retainer just above the stage collar in the 9-5/8” casing at 2,113’ and pump a ~1000’ cement plug into the OA. We won’t know if the cement will go up or down until we set the retainer and pump, but we should end up with 900-1000’ of cement in the OA. Currently we have the CTU unit rigging down and moving to PBU. If the the below is approved we will plan to have CTU back on MPH-13A on Wednesday. Steps updated to reflect squeezing off the lower perfs and putting a 300’ plug in the TBG. 1. MIRU CTU, PT to 250/4200psi 2. Make up YJOFS 4.5” Retainer Stinger, RIH and sting into retainer set at 2,955’ a. Confirm injectivity into formation with 1% KCL b. Pump 15bbls of cement c. Once 10bbls of cement has been pumped through retainer, or a 500psi squeeze is achieved, unsting and lay in cement 1:1 in 4.5” TBG i. TBG volume from 2955-2655’ is 4.6bbls (300’) d. If excess cement is laid into tubing contaminate cement withpowervis down to 2655’ and circulate to surface. e. Jet BOPs/Tree with powervis to wash up. 3. Make up 5’ Perf gun (Perf gun specifications TBD based on Modeling from HES) RIH and Perforate 4.5” and 7” Casing at 2,050’ 4. Make up 4.5” one trip retainer, RIH and set retainer at ~2,000’ a. Confirm circulation down the CT and up the 9-5/8”x7” annulus and out the CTBS with KCL. If circulation cannot be achieved perform injectivity test at 2,000psi. b. Pump 80bbsls (17bbls excess)of 15.8ppg cement c. Once 30bbls of cement has been pumped through the retainer, or a 1500psi squeeze has been achieved, unsting and lay in cement 1:1in 4.5” TBG/7” CSG. i. 9-5/8”x7” OA Volume from 2050-2985’ = 26.39bbls, 4.5” TBG volume between retainer and punch = .76bbls ii. TBG volume from 2,955’-250’ = 27bbls, 7” CSG volume from 250-surface = 9.5bbls d. Pump excess cement to empty gauge tank. e. Jet BOPs/Tree with powervis to wash up, close swap and washupcoil per LRS procedures. f. RDMO CTU WOC 24hrs CMIT-TxIAxOA to 1,500psi Thank you, Scott Scott Pessetto Operations Manager | Milne Point | Hilcorp Alaska, LLC Office: 907-564-4373 | Cell: 801-822-2203 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Taylor Wellman Subject:20250701 1425 APPROVAL Additional Cement MPU H-13A (PTD 202-167) P&A Sundry 324-536 Date:Tuesday, July 1, 2025 2:26:53 PM Taylor, Changes to abandonment sundry 324-526 as described below is approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday, June 30, 2025 10:02 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPU H-13A (PTD 202-167) P&A Sundry 324-536 Mel, With respect to the P&A on MPU H-13A (PTD 202-167) under the approved Sundry 324-536, I would like to make a slight change. Instead of leaving 9.8ppg brine between the cemented SC shoe and the surface plug, I’d like to fill the entire 7” with cement. Short version of steps to add: 16.1 Punch tbg at 3,700’ MD. 16.2 RIH w/ single run cement retainer and set at 3,675’ MD. 16.3 Circulate cement up the 4-1/2” x 7” annulus to the top of the tbg stub, unsting from cement retainer and lay in cement in 4-1/2” tbg and then 7” casing to surface. The attached is an updated proposed schematic (Rev 1) as well as the currently approved proposed schematic for what it would look like. If there is any issue with this plan of attack please let me know as I’d like to put this well to bed for all time. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,142'N/A Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 6,590psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7" x 4.5" SC-1R and N/A 6,642MD / 4,002TVD and N/A Taylor Wellman twellman@hilcorp.com 907-777-8449 4-1/2" 12.6 / L-80 4"2,500' 6,742' Perforation Depth MD (ft): 9,142' See Schematic See Schematic 3,880' 6,742' 112' 20" 9-5/8" 7" 3,880' 7,910psi 5,750psi 7,240psi 2,908' 4,016' 4,109' Length Size Proposed Pools: 112' 112' TVD BurstMD N/A PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 / ADL0025906 202-167 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22818-01-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/15/2024 6,198' 4,109' Surface Surface 23 Surface & 5,326' Subsequent Form Required: Suspension Expiration Date: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: MILNE PT UNIT H-13A Milne Point SCHRADER BLUFF OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:34 am, Sep 19, 2024 Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2024.09.18 22:54:05 - 08'00' Scott Pessetto (9864) 324-536 * AOGCC to witness cement tops in annuli before welding plates. * Photo document cement tops in all annuli. * AOGCC to witness marker plate welded in place. 23 10-407 SFD 10/4/2024 DSR-9/27/24 Perforate MGR22NOV24MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.30 15:56:24 -09'00'12/30/24 RBDMS JSB 123124 Plug and Abandon Well: MPH-13A PTD: 2021670 API: 50-029-22818-01-00 Well Name:MPH-13A API Number:50-029-22818-01-00 Current Status:Suspended Rig:Coil Tubing Estimated Start Date:10/15/2024 Estimated Duration:4 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:2021670 First Call Engineer:Taylor Wellman 907-777-8449 907-947-9533 (M) Second Call Engineer:Todd Sidoti 907-777-8443 907-632-4113 (M) AFE Number:TBD MP Bottom Hole Pressure:894 psi @ 1,986’ TVD UGNU – Normally pressured at the 9- 5/8” window MPSP:23 psi (Max WHP recorded in last year) Max Deviation:71° 4,027’ MD Max dev above TOC Min ID:3.958” @ 0’ MD (4-1/2” hanger installed in wellhead) Brief Well Summary MPH-13A was drilled in September 2002 as a Schrader Bluff N sand ESP producer . ESP changeouts were performed in 2004 & 2009 via RWO. During the 2009 RWO a tight spot was encountered at 304’-320’ while pulling and running the ESP completion. A caliper was run on the 7” casing during the 2009 RWO indicating bends in the casing from 260’ – 286’. A tubing caliper was run in May 2014 indicating axial displacement in the 4 ½” tubing from ~240-300’. A reservoir P&A was pumped by coil in July 2014 and tagged @ 5,326’ CTM after passing a MIT- T & MIT-IA. The well was now classified as suspended with initial inspection on 9/14/14. In May of 2015, Nordic 3 rigged up, performed MIT-IA to 1500 psi & cut tubing @ 250’, recovering the tubing & ESP cable, performed a 7” casing punch @ 203’ and circulated cement into the OA w/ 5 bbls of returns. Cement was now at surface across all annuli. In Dec 2017 as preparations were made for surface abandonment, ~40 psi of WHP was observed on the OA, after multiple bleed attempts the OA continued to re-pressurize. In May of 2018, 6 gallons of welllock was pumped into the OA achieving squeeze pressure of 1680 psi. A passing MIT-OA was then performed to 1068 psi. Multiple extended bleed periods have been performed in 2018, 2020 & 2021 on the IA and OA. In November 2023 the IA/OA were bled to 0. Feb 2024 the IA is at 4 psi, the OA is at 0 psi. In May 2024, the well was being prepared for cutting off of the wellhead. While bleeding off the IA, fluid flow was observed. Further diagnostics have shown that the fluid in the Tbg/IA is slowly inflowing. Notes Regarding Wellbore Condition x Tubing stub @ 250’, no tubing to surface. x Cement to surface across all Annuli. Plug and Abandon Well: MPH-13A PTD: 2021670 API: 50-029-22818-01-00 Objective: x Place kill weight fluids in the wellbore between the reservoir cement plug and the surface cement plug. x Re-cement the surface abandonment plug. x To perform a complete P&A of the well prior to suspension renewal due in July 2024. Procedure Coil: 1. MIRU CTU (1.75” or 2.0” coil preferred) and PT to 250 psi low / 2000 psi high. 2. MU milling BHA w/ 3.60” PDC mill. a. Consider using a pipe straightener to help ensure passing through the hanger. 3. Establish milling parameters and mill pilot hole through the surface cement to ~10’ MD below the tubing hanger. POOH. 4. MU Underreaming BHA and underream the 7” casing to from below the hanger to ±204’ MD. a. Reciprocate as needed to allow underreamer blades to fully open. b. When close to punching through the cement, circulate/pump sweeps to help prevent dropping large chunks of cement down. 5. Once through the cement, circulate clean and POOH. 6. MU drift BHA to dry drift into 4-1/2” tubing stub to ensure it is clear of any cement debris. a. Top of tubing stub is at ~250’ MD. b. Note that a 3.60” mill/JSN should prevent running alongside the 4-1/2” OD tubing while inside 7” casing (ID = 6.276”). c. TOC in tubing is 5,326’ CTM from 7/31/2014 WSR. d. PU ±50’ and flag pipe. e. Contingency: MU mill BHA and drift down tubing stub to tag TOC if cement/trash is suspected hanging up in the tubing stub. 7. Perform pressure test of the 7” casing to 1,500 psi for 30 minutes (charted). a. Contact OE with results of pressure test. If the casing test fails see contingency below. 8. MU tubing punch BHA and RIH to ±5,300’ MD. Punch tubing and POOH. 9. MU one trip retainer and RIH to ±5,280’ MD. Set retainer and circulate down coil while taking returns from the CTx7” annulus until clean water is returned. Circulate the well to 9.8 ppg brine. 10. Release from retainer and circulate the CTx4-1/2” annulus to 9.8 ppg brine. 11. MU 5’ of guns and perforate 4-1/2” tubing and 7” casing at ±3,750’ MD. 12. Establish injectivity out the 7” casing and out the 9-5/8” millout window. 13. MU 5’ of tubing punches and punch tubing at ±4,010’ MD. 14. MU one trip cement retainer BHA. RIH to ±3,920’ MD. Mix and pump 15.5 bbls of 15.8ppg cement while taking returns to formation. After ±11.0bbls of cement out the nozzle, lay in the remaining remaining 2.5bbls into the tubing. a. Attempt to build any squeeze pressure possible prior to releasing from the retainer and laying cement on top of the retainer. Estimated TOC in 4-1/2” tbg ~3,705’ MD. b. Volumes: i. 4-1/2” tbg (retainer to lower tbg punch) = 260’ x .0152 bpf = 1.4 bbls ii. 4-1/2” x 7” (lower tbg punch to upper perfs) = 260’ x 0.01859 bpf = 4.9 bbls suspension renewal due in July 2024 Plug and Abandon Well: MPH-13A PTD: 2021670 API: 50-029-22818-01-00 iii. 7”x9-5/8” Annulus (upper perfs to millout window) = 0.2823 bpf x 160’ = 4.6 bbls 15. POOH and circulate coil clean. 16. WOC and CMIT-TxIAxOA to 1,500psi. 17. MU cementing BHA and RIHto 225’ MD and lay in cement plug to surface. 18. Circulate clean once above the tubing hanger. 19. RDMO CTU. Operations 1. Photo document all steps. 2. Cut off all casings and wellhead 3’ below tundra. 3. Top off tubing and annuli with cement if needed. 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska, LLC. b. Permit to Drill Number – 202-167 c. Well Name – MPU H-13A d. API Number - 50-029-22818-01-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: - Wellbore Schematic - Proposed Wellbore Schematic _____________________________________________________________________________________ Revised By: TDF 6/14/2018 SCHEMATIC Milne Point Unit Well: MPU H-13A Abandoned: 5/15/2015 PTD: 202-167 6-1/8” Hole TD @ 9,142’ Baker GPV 5” Guide Shoe N-Sand Horizontal CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc.Mod 8.835 Surface 3,380’ 7" Intermediate 26 / L-80 / Btc Mod 6.276 Surface 6,742’ 4” Liner 9.5 / L-80 / 521 Hydril 3.548 6,642’ 9,142’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / N/A 3.958 250’ 6,198 JEWELRY DETAIL No Depth Item 1 203’ Casing Punch 2 205’ Casing Punch 3 6,140’ D&D Tubing Stop 4 6,142’ D&D Pack-off Assembly Top 5 6,151’ Centrilift TTC-ESP Top 6 6,159’ TTC Drilled Tubing Crossover 7 6,169’ Tandem Seal Sections 8 6,183’ Motor 9 6,192’ PumpMate XTO w/ 6 Fin Centralizer 10 6,642’ 7” x 4.5” SC-1R Packer 11 6,688’ 4.5” CMD Sliding Sleeve OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,948 sks PF “E”,2785 sx Class “G” & 200sx PF”C” in 12-1/4” Hole 7” Cmt w/ 230 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = ख़71.1 deg. @ 6,000’ Hole Angle @ TTC-ESP= 75Deg. TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5M FMC Gen 6, w/ 11 x 4-1/2”” FMC Tbg. Hngr. 4-1/2” 521 Hydril T&B, 4” H BPV Profile GENERAL WELL INFO API: 50-029-22818-01-00 Drilled and Cased by Nabors 22E - 10/22/1997 De-completed for Sidetrack by Nabors 4ES – 7/25/2002 Sidetrack & ESP Completion w/ Doyon 141 – 9/12/2002 ESP Change-out w/ Nabors 4-ES – 12/8/2004 Convert to TTC-ESP w/ Nabors 4-ES – 11/14/2009 Punch Holes / Coil Cement – 7/31/2014 Abandonment by Nordic 3 – 5/15/2015 TD =9,440’ (MD) / TD = 7,191’(TVD) 20” Howco 9-5/8” ES Cementer @ 2,113’MD Orig. DF Elev.: 66 (N 22E)/ GL Elev.: 36.7’ /Orig. DF to Csg. Hgr.= 30.62’(N 22E) 7” 5 7 8 9 1 0 9-5/8” 3 & 4 203’ Cement Plug 15.8 ppg Class “G” Cement. Tag Cement w/ 4k down @ 5,326’ CTM PBTD =9,332’ (MD) / PBTD = 7,123’(TVD) 6 Window Cut in 9-5/8” 3,880’ to 3,910’ 1 1 Punch Tbg 6,110’ to 6,120’. 37 Joints of 4” Screen C27 Baker Med. Excluder 2000 w/ 37’ of 4” Blank & 5.75” OD Centralizer Alternating 1 2 _____________________________________________________________________________________ Revised By: TDF 9/18/2024 PROPOSED Milne Point Unit Well: MPU H-13A Abandoned: 5/15/2015 PTD: 202-167 6-1/8” Hole TD @ 9,142’ Baker GPV 5” Guide Shoe N-Sand Horizontal CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc.Mod 8.835 Surface 3,380’ 7" Intermediate 26 / L-80 / Btc Mod 6.276 Surface 6,742’ 4” Liner 9.5 / L-80 / 521 Hydril 3.548 6,642’ 9,142’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / N/A 3.958 250’ 6,198 JEWELRY DETAIL No Depth Item 1 203’ Casing Punch 2 205’ Casing Punch 3 6,140’ D&D Tubing Stop 4 6,142’ D&D Pack-off Assembly Top 5 6,151’ Centrilift TTC-ESP Top 6 6,159’ TTC Drilled Tubing Crossover 7 6,169’ Tandem Seal Sections 8 6,183’ Motor 9 6,192’ PumpMate XTO w/ 6 Fin Centralizer 10 6,642’ 7” x 4.5” SC-1R Packer 11 6,688’ 4.5” CMD Sliding Sleeve OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,948 sks PF “E”,2785 sx Class “G” & 200sx PF”C” in 12-1/4” Hole 7” Cmt w/ 230 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = ख़71.1 deg. @ 6,000’ Hole Angle @ TTC-ESP= 75Deg. TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5M FMC Gen 6, w/ 11 x 4-1/2”” FMC Tbg. Hngr. 4-1/2” 521 Hydril T&B, 4” H BPV Profile GENERAL WELL INFO API: 50-029-22818-01-00 Drilled and Cased by Nabors 22E - 10/22/1997 De-completed for Sidetrack by Nabors 4ES – 7/25/2002 Sidetrack & ESP Completion w/ Doyon 141 – 9/12/2002 ESP Change-out w/ Nabors 4-ES – 12/8/2004 Convert to TTC-ESP w/ Nabors 4-ES – 11/14/2009 Punch Holes / Coil Cement – 7/31/2014 Abandonment by Nordic 3 – 5/15/2015 TD = 9,440’ (MD) / TD = 7,191’(TVD) 20” Howco 9-5/8” ES Cementer @ 2,113’MD Orig. DF Elev.: 66 (N 22E)/ GL Elev.: 36.7’ /Orig. DF to Csg. Hgr.= 30.62’(N 22E) 7” 5 7 8 9 1 0 9-5/8” 3 & 4 203’ Cement Plug 15.8 ppg Class “G” Cement. - TOC IA6,110’ MD - TOC Tbg (Tag Cement w/ 4k down @ 5,326’ CTM PBTD =9,332’(MD) / PBTD = 7,123’(TVD) 6 Window Cut in 9-5/8” 3,880’ to 3,910’ 1 1 PunchTbg 6,110’ to 6,120’ 37 Joints of 4” Screen C27 Baker Med. Excluder 2000 w/ 37’ of 4” Blank & 5.75” OD Centralizer Alternating 1 2 Punch Tbg ±5,300’ Cmt Retainer ±5,280’ MD Punch Tbg ±4,010’ MD Punch Tbg & Csg ±3,750’ MD Cmt Retainer 2 3,920’ MD 9.8ppg brine 9.8ppg brine TOC in 4-1/2 Tubing @ ±3,705’ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Tom Fouts To:AOGCC Permitting (CED sponsored) Cc:Taylor Wellman; Scott Pessetto Subject:MP H-13A AOGCC 10-403 Withdrawal Request for Sundry #: 324-127, PTD: 202-167 Date:Thursday, September 19, 2024 8:09:15 AM Grace, Hilcorp Alaska LLC requests the withdrawal of the 10-403 submittal for MP H-13A, Sundry 324- 127. We will be replacing it with an updated version. Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Inspect Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Surface & Total Depth measured 9,142 feet 5,326 feet true vertical 4,109 feet NA feet Effective Depth measured Surface feet 6,642 feet true vertical Surface feet 4,002 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 6,198' 3,926' Packers and SSSV (type, measured and true vertical depth) NA See Above NA 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: None 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 9-5/8" 7" x 4.5" SC- 1R Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 N/A measured true vertical Packer MD 112' Size 112' 2,908' Length 2,500' Casing Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf TVD 4" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-167 50-029-22818-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025518, ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT H-13A Plugs Junk measured measured Conductor 4,109'9,142' 6,742' 3,880'Surface Intermediate Liner 20" 7" 112' 3,880' 6,742' 4,016' 6,590psi 5,750psi 7,240psi 7,910psi 5,410psi Burst N/A Collapse N/A 3,090psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:07 pm, Jun 23, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.21 09:33:28 - 08'00' Taylor Wellman (2143) 202-167 MILNE PT UNIT H-13A DSR-6/23/23WCB 1-18-2024 Other: Inspect Well MILNE POINT / SCHRADER BLUFF OIL RBDMS JSB 071123 _____________________________________________________________________________________ Revised By: TDF 6/14/2018 SCHEMATIC Milne Point Unit Well: MPU H-13A Abandoned: 5/15/2015 PTD: 202-167 6-1/8” Hole TD @ 9,142’ Baker GPV 5” Guide Shoe N-Sand Horizontal TD =9,440’ (MD) / TD = 7,191’(TVD) 20” Howco 9-5/8” ES Cementer @ 2,113’MD Orig. DF Elev.: 66 (N 22E)/ GL Elev.: 36.7’ /Orig. DF to Csg. Hgr.= 30.62’(N 22E) 7” 5 7 8 9 10 9-5/8” 3 4 203’ Cement Plug 15.8 ppg Class “G” Cement. Tag Cement w/ 4k down @ 5,326’ CTM PBTD =9,332’(MD) /PBTD = 7,123’(TVD) 6 Window Cut in 9-5/8” 3,880’ to 3,910’ 11 Perf Tbg 6,110’ to 6,120’. Able to Inject @ 1bpm w/ 386psi 37 Joints of 4” Screen C27 Baker Med. Excluder 2000 w/ 37’ of 4” Blank & 5.75” OD Centralizer Alternating 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc.Mod 8.835 Surface 3,380’ 7" Intermediate 26 / L-80 / Btc Mod 6.276 Surface 6,742’ 4” Liner 9.5 / L-80 / 521 Hydril 3.548 6,642’ 9,142’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / N/A 3.958 250’ 6,198 JEWELRY DETAIL No Depth Item 1203’Casing Punch 2205’Casing Punch 3 6,140’ D&D Tubing Stop 4 6,142’ D&D Pack-off Assembly Top 5 6,151’ Centrilift TTC-ESP Top 6 6,159’ TTC Drilled Tubing Crossover 7 6,169’ Tandem Seal Sections 8 6,183’ Motor 9 6,192’ PumpMate XTO w/ 6 Fin Centralizer 10 6,642’ 7” x 4.5” SC-1R Packer 11 6,688’ 4.5” CMD Sliding Sleeve OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,948 sks PF “E”,2785 sx Class “G” & 200sx PF”C” in 12-1/4” Hole 7” Cmt w/ 230 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = ख़71.1 deg. @ 6,000’ Hole Angle @ TTC-ESP= 75Deg. TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5M FMC Gen 6, w/ 11 x 4-1/2”” FMC Tbg. Hngr. 4-1/2” 521 Hydril T&B, 4” H BPV Profile GENERAL WELL INFO API: 50-029-22818-01-00 Drilled and Cased by Nabors 22E - 10/22/1997 De-completed for Sidetrack by Nabors 4ES – 7/25/2002 Sidetrack & ESP Completion w/ Doyon 141 – 9/12/2002 ESP Change-out w/ Nabors 4-ES – 12/8/2004 Convert to TTC-ESP w/ Nabors 4-ES – 11/14/2009 Punch Holes / Coil Cement – 7/31/2014 Abandonment by Nordic 3 – 5/15/2015 MILNE P O I N T H P A D 18 17 16 15 4 5 3 6 2 8 1 7 9 10 11 12 13 19 14 Chemical Injection 02 Operations Trailer 31 ESP Building 01 Test Separator Water Injection Booster Pumps ! ! ! ! ! ! MILNE POINT UNIT F B C L S EJ I KH G CFP A MILNE POINT UNIT MPU H PAD LOCATION MAP Map Date : October 2017 Map 9 of 15Map Author: MR Anderson E 1 inch = 125 feet 0 50 100 150 200 Feet H-13 H-13 suspended well inspecƟon pics Back of well H-13 suspended well inspecƟon pics Cellar H-13 suspended well inspecƟon pics TBG gauge H-13 suspended well inspecƟon pics IA gauge H-13 suspended well inspecƟon pics OA gauge H-13 suspended well inspecƟon pics Front view H-13 suspended well inspecƟon pics Side view H-13 suspended well inspecƟon pics Back view H-13 suspended well inspecƟon pics Side view 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 12 Month Extension_ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,142'N/A Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 6,590psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT H-13A Milne Point SCHRADER BLUFF OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 4,109' Surface Surface 4 Surface & 5,326' Subsequent Form Required: Suspension Expiration Date: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 6/21/2024 6,198' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 / ADL0025906 202-167 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22818-01-00 Hilcorp Alaska LLC C.O. 477.05 Length Size Proposed Pools: 112' 112' TVD BurstMD N/A PRESENT WELL CONDITION SUMMARY 7,910psi 5,750psi 7,240psi 2,908' 4,016' 4,109' 3,880' 6,742' 112' 20" 9-5/8" 7" 3,880' 4"2,500' 6,742' Perforation Depth MD (ft): 9,142' See Schematic See Schematic 7" x 4.5" SC-1R and N/A 6,642MD / 4,002TVD and N/A Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 4-1/2" 12.6 / L-80 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:25 am, Jun 20, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.06.19 16:09:23 - 08'00' Taylor Wellman (2143) 324-360 DSR-6/25/24 Suspend 10-403 for full abandonment SFD 6/20/2024 31-Dec-2024 MGR20JUN2024 * IA fluid chemistry analysis to be performed and results to AOGCC no later than 15-JULY-2024 * Full abandonment plan to AOGCC no later than 15-SEP-2024 * Approved for suspension extension to 31-DECEMBER-2024 12 Month Extension_ *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.26 12:34:58 -08'00'06/26/24 RBDMS JSB 062624 Hilcorp Alaska, LLC Taylor Wellman, Milne Point Wells Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 06/18/2024 Chairman Brett Huber, Sr. Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Milne Point MPH-13A (PTD #2021670) Application for 12 Month Suspension Extension (10-403) Dear Chairman Huber, An AOGCC witnessed suspended well inspection of Milne Point well MPH-13A was conducted on 06/16/2023 (20 AAC 25.110 (h)). The submitted suspended well inspection reflects the current surface condition of the well (reference 20 AAC 25.110 (f)) and supports the request for a 12 month extension of suspension status. On 3/22/24 a 10-403 (Sundry 324-127) was approved by AOGCC to perform final surface abandonment of well MPH-13A. Current well condition is cement to surface across all annuli with tubing removed to 250’. In preparation for cutting off the wellhead, surface pressures were bled to 0, at which point the IA returned ~ 10 gallons of fluid (diesel/crude). Previous IA bleeds were assumed to have evacuated all fluid from the void down to the IA valve. Further activity related to final abandonment was paused and AOGCC was notified on 5/31/24. An MIT of the Tubing/IA void was performed with diesel to 3000 psi and failed. The Tubing/IA void was evacuated of fluid down to the IA valve with nitrogen and bled to 0. The near term plan forward is to monitor and bleed the Tubing/IA void, document and sample any fluid returns, and provide a summary to AOGCC of results at which time a P&A/suspension plan can be agreed within the 12 month extension timeframe. Request In lieu of a full suspension renewal, Hilcorp Alaska, LLC requests approval for a 12 month extension of the existing suspension status for this well while a final P&A plan forward is finalized. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). If you have any questions, please call me at 907-777-8449 or Ryan Thompson at 907-564- 5005. Sincerely, Taylor Wellman Milne Point Wells Manager Attachments Technical Justification 2023 Suspended Well Site Inspection Form Wellbore Schematic pp g , IA returned ~ 10 gallons of fluid (diesel/crude) Milne Point Well MPH-13A (PTD #2021670) Technical Justification for 12 month extension of Suspended Status Well History and Status Milne Point well MPH-13A was suspended on 7/31/2014 after the reservoir cement plug was pumped via coiled tubing. Cement top was tagged at 5326’ with 4k downweight and the well passed an MIT-T to 1660 psi and an MIT-IA to 1650 psi post cement job. In May 2015 a subsequent MIT-IA to 1500 psi passed, tubing was cut and pulled at 250’, the OA was punched at 203’ and cement was circulated to surface up the OA with 5 barrels of cement returns. The well was now cemented to surface across all Annuli. OA repressurization was experienced in December 2017 during final abandonment preparations. A LLR down the OA was confirmed at .3 gal/min. A well lock cement squeeze was performed on 5/15/2018 and passed an MIT-OA to 1000 psi. Bleed operations were performed in 2018, 2020 & 2021. In November 2023, bleed operations were performed with <1 cup fluid returned from the IA and gas on the initial bleed. On 5/29/24 in preparation for final abandonment, the IA was bled from a starting pressure of 3 psi and had returns of ~10 gallons of diesel/crude therefore pausing final abandonment operations. Current wellhead pressures are 23 psi on the Tubing/IA void and 2 psi on the OA. MPH-13A is located on an active pad with current surface conditions outlined in the attached inspection report. 2024-0604_Suspend_MPU_H-13A_ss Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 6/4/2024 P. I. Supervisor FROM: Sully Sullivan SUBJECT: Suspended Well/Location Petroleum Inspector MPU H-13A Hilcorp Alaska LLC PTD 2021670; Sundry 324-127 6/4/2024: I stopped by Milne Point Unit H-13A this morning as requested and talked with pad operator. MPU H-13A is a suspended well that has plugs to surface and Hilcorp was attempting the final abandonment under Sundry 324-127 when they observed well pressures and well fluids leaking from the well. It appears the abandonment plugs set years ago may be leaking. The production tree remains on the well. Hilcorp backfilled around the tree/casing after excavating for the P&A cutoff. Current well pressures are: -Tubing 0 psi -IA 15 psi -OA 2 psi The pad operator did not have much to share; I requested a call from the Well Ops Coordinator Matt Ross. I took several pictures. Attachments: Photos (5)     2024-0604_Suspend_MPU_H-13A_ss Page 2 of 4 Suspended Well – MPU H-13A (PTD 2021670) Photos by AOGCC Inspector S. Sullivan 6/4/2024 2024-0604_Suspend_MPU_H-13A_ss Page 3 of 4 2024-0604_Suspend_MPU_H-13A_ss Page 4 of 4 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,142' N/A Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 6,590psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,198' 7" x 4.5" SC-1R and N/A 6,642MD / 4,002TVD and N/A Ryan Thompson ryan.thompson@hilcorp.com 907-564-5280 4-1/2" 12.6 / L-80 4"2,500' 6,742' Perforation Depth MD (ft): 9,142' See Schematic See Schematic 3,880' 6,742' 112' 20" 9-5/8" 7" 3,880' 7,910psi 5,750psi 7,240psi 2,908' 4,016' 4,109' Length Size Proposed Pools: 112' 112' TVD BurstMD N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 / ADL0025906 202-167 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22818-01-00 Hilcorp Alaska LLC C.O. 477.05 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3/15/2024 4,109' Surface Surface 4 Surface & 5,326' Subsequent Form Required: Suspension Expiration Date: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: MILNE PT UNIT H-13A Milne Point SCHRADER BLUFF OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:41 am, Mar 04, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.01 15:18:04 - 09'00' Taylor Wellman (2143) MGR21MAR24 * AGOCC to witness cement tops and final marker plate. * Photodocument TOC and marker plate. DSR-3/4/24 Abandon 10-407 SFD 3/4/2024JLC 3/22/2024 Plug and Abandon Well: MPH-13A PTD: 2021670 API: 50-029-22818-01-00 Well Name:MPH-13A API Number:50-029-22818-01-00 Current Status:Suspended Rig:Surface Ops Estimated Start Date:3/15/2024 Estimated Duration:2 days Reg.Approval Reqd? Yes Date Reg. Approval Recvd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:2021670 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) Second Call Engineer:Brian Glasheen 907-545-1144 (M) AFE Number:TBD MASP:4 psi Brief Well Summary MPH-13A was drilled in September 2002 as a Schrader Bluff N sand ESP producer . ESP changeouts were performed in 2004 & 2009 via RWO. During the 2009 RWO a tight spot was encountered at 304- 320 while pulling and running the ESP completion. A caliper was run on the 7 casing during the 2009 RWO indicating bends in the casing from 260 286. A tubing caliper was run in May 2014 indicating axial displacement in the 4 ½ tubing from ~240-300. A reservoir P&A was pumped by coil in July 2014 and tagged @ 5,326 CTM after passing a MIT-T & MIT-IA. The well was now classified as suspended with initial inspection on 9/14/14. In May of 2015, Nordic 3 rigged up, performed MIT-IA to 1500 psi & cut tubing @ 250, recovering the tubing & ESP cable, performed a 7 casing punch @ 203 and circulated cement into the OA w/ 5 bbls of returns. Cement was now at surface across all annuli. In Dec 2017 as preparations were made for surface abandonment, ~40 psi of WHP was observed on the OA, after multiple bleed attempts the OA continued to re-pressurize. In May of 2018 6 gallons of welllock was pumped into the OA achieving squeeze pressure of 1680 psi. A passing MIT-OA was then performed to 1068 psi. Multiple extended bleed periods have been performed in 2018, 2020 & 2021 on the IA and OA. In November 2023 the IA/OA were bled to 0. Feb 2024 the IA is at 4 psi, the OA is at 0 psi. Notes Regarding Wellbore Condition Tubing stub @ 250, no tubing to surface. Cement to surface across all Annuli. Bleed I/O to 0 psi on 11/21/23. 02/14/24 pressures are 0 psi on the OA and 4 psi on the IA. Objective: To perform a complete P&A of the well prior to suspension renewal due in July 2024. Procedure Operations 1. Photo document all steps. 2. Cut off all casings and wellhead 3 below tundra. 3. Top off tubing and annuli with cement if needed. 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska, LLC. b.Permit to Drill Number 202-167 c. Well Name MPU H-13A d. API Number - 50-029-22818-01-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) PTD 202-167 Plug and Abandon Well: MPH-13A PTD: 2021670 API: 50-029-22818-01-00 Attachments: 1. As-built Schematic Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/31/2023 InspectNo:susAGE230620122032 Well Pressures (psi): Date Inspected:6/16/2023 Inspector:Adam Earl If Verified, How?Other (specify in comments) Suspension Date:7/31/2014 #314-153 Tubing:20 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Roger Allison Date AOGCC Notified:6/15/2023 Type of Inspection:Subsequent Well Name:MILNE PT UNIT H-13A Permit Number:2021670 Wellhead Condition good working order Surrounding Surface Condition Clean, free of trash/dunnage Condition of Cellar A little rain/meltoff water in celler, several feet below any wellhead valves, looks clean, no sheens. Comments pad map verified Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, July 31, 2023              1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect well Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,142 feet Surface & 5,326'feet true vertical 4,109 feet N/A feet Effective Depth measured Surface feet 6,642 feet true vertical Surface feet 4,002 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 6,198' 3,926' Packers and SSSV (type, measured and true vertical depth)N/A See above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WDSP2 WAG Water-Bbl MD 9,142' TVDSize Oil-Bbl measured true vertical Packer 4" Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-167 50-029-22818-01-00 Plugs ADL0025518 / ADL0025906 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com MILNE PT UNIT H-13A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured N/A Casing Conductor Liner 2,500' Length 112' 4,109' 3,880' 6,742' Surface Intermediate 9-5/8" 7" 5,750psi 7,240psi 20" 5,410psi6,742' 3,880' 112' 2. Operator Name Senior Engineer: Senior Res. Engineer: 7,910psi Collapse 7" x 4.5" SC- 1R 2,908' 112' Burst 777-8333 6,590psi 4,016' N/A N/A 3,090psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 11:06 am, Jul 28, 2020 Chad A Helgeson 2020.07.28 10:12:38 -08'00' RBDMS HEW 7/28/2020 MGR30JUL2021 DSR-7/29/2020 SFD 7/28/2020 Matt Herrera _____________________________________________________________________________________ Revised By: TDF 6/14/2018 SCHEMATIC Milne Point Unit Well: MPU H-13A Abandoned: 5/15/2015 PTD: 202-167 6-1/8” Hole TD @ 9,142’ Baker GPV 5” Guide Shoe N-Sand Horizontal TD =9,440’ (MD) / TD = 7,191’(TVD) 20” Howco 9-5/8” ES Cementer @ 2,113’MD Orig. DF Elev.: 66 (N 22E)/ GL Elev.: 36.7’ /Ori g. DF to Csg. Hgr.= 30.62’(N 22E) 7” 5 7 8 9 10 9-5/8” 3 4 203’ Cement Plug 15.8 ppg Class “G” Cement. Tag Cement w/ 4k down @ 5,326’ CTM PBTD =9,332’(MD) /PBTD = 7,123’(TVD) 6 Window Cut in 9-5/8” 3,880’ to 3,910’ 11 Perf Tbg 6,110’ to 6,120’. Able to Inject @ 1bpm w/ 386psi 37 Joints of 4” Screen C27 Baker Med. Excluder 2000 w/ 37’ of 4” Blank & 5.75” OD Centralizer Alternating 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc.Mod 8.835 Surface 3,380’ 7" Intermediate 26 / L-80 / Btc Mod 6.276 Surface 6,742’ 4” Liner 9.5 / L-80 / 521 Hydril 3.548 6,642’ 9,142’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / N/A 3.958 250’ 6,198 JEWELRY DETAIL No Depth Item 1203’Casing Punch 2205’Casing Punch 3 6,140’ D&D Tubing Stop 4 6,142’ D&D Pack-off Assembly Top 5 6,151’ Centrilift TTC-ESP Top 6 6,159’ TTC Drilled Tubing Crossover 7 6,169’ Tandem Seal Sections 8 6,183’ Motor 9 6,192’ PumpMate XTO w/ 6 Fin Centralizer 10 6,642’ 7” x 4.5” SC-1R Packer 11 6,688’ 4.5” CMD Sliding Sleeve OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,948 sks PF “E”,2785 sx Class “G” & 200sx PF”C” in 12-1/4” Hole 7” Cmt w/ 230 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = ख़71.1 deg. @ 6,000’ Hole Angle @ TTC-ESP= 75Deg. TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5M FMC Gen 6, w/ 11 x 4-1/2”” FMC Tbg. Hngr. 4-1/2” 521 Hydril T&B, 4” H BPV Profile GENERAL WELL INFO API: 50-029-22818-01-00 Drilled and Cased by Nabors 22E - 10/22/1997 De-completed for Sidetrack by Nabors 4ES – 7/25/2002 Sidetrack & ESP Completion w/ Doyon 141 – 9/12/2002 ESP Change-out w/ Nabors 4-ES – 12/8/2004 Convert to TTC-ESP w/ Nabors 4-ES – 11/14/2009 Punch Holes / Coil Cement – 7/31/2014 Abandonment by Nordic 3 – 5/15/2015 SFD 7/28/2020 MILNE P O I N T H P A D 18 17 16 15 4 5 3 6 2 8 1 7 9 10 11 12 13 19 14 Chemical Injection 02 Operations Trailer 31 ESP Building 01 Test Separator Water Injection Booster Pumps ! ! ! ! ! ! MILNE POINT UNIT F B C L S EJ I KH G CFP A MILNE POINT UNIT MPU H PAD LOCATION MAP Map Date : October 2017 Map 9 of 15Map Author: MR Anderson E 1 inch = 125 feet 0 50 100 150 200 Feet H-13 Suspended Well Inspection Review Report InspectNo: susMFH200620144309 Date Inspected: 6/20/2020 Inspector: Matt Herrera Type of Inspection: Well Name: MILNE PT UNIT H -13A Permit Number: 2021670 Suspension Approval: Sundry Suspension Date: 7/31/2014 Location Verified? W Subsequent Date AOGCC Notified: 6/19/2020 Operator: Hilcorp Alaska, LLC k 314-153 - Operator Rep: Josh McNeal Wellbore Diagram Avail? 2 ` Photos Taken? O If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: BPV Installed? ❑ OA: VR Plug(s) Installed? ❑ Wellhead Condition Good. No leaks on any flange connections or lock down screws. No SSV. All Valves operational. Gauges installed and in , .working order to note tubing and annulus pressures Condition of Cellar Surrounding Surface Condition Comments Well location verified by pad map. Barrier around wellhead and cellar. Well sign with proper info was missing - operator instructed to rectify with new sign; send photo when corrected. Supervisor Comments Photos (2) attached; includes photo from Pad Operator after correcting well sign issue. � r` X1231 ZauD Thursday, July 23, 2020 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Pfq 61111/6 DATE: May 30, 2018 P.I. Supervisor C I SUBJECT: Well Bore Plug &Abandonment MPU H-13A FROM: Lou Laubenstein Hilcorp Alaska Petroleum Inspector PTD 202-167:Sundry 318-174 Section: 34 Township: 13N Range: 10E - Meridian: Umiat i Drilling Rig: n/a - Rig Elevation: n/a Total Depth: 9440' - Lease No.: ADL25906 Operator Rep: Bill Kruskie Suspend: X P&A: Casing/Tubing Data: Casing Removal: Conductor: 20" - O.D. Shoe@ 112 • Feet Csg Cut@ Feet Surface: 9-5/8" - O.D. Shoe@ 3380 - Feet Csg Cut@ Feet Intermediate: 7" ` O.D. Shoe@ 6742 - Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 4" • O.D. Shoe@ 9142 ' Feet Csg Cut@ Feet Tubing: 4-1/2" - O.D. Tail@ 6198 - Feet Tbg Cut@ Feet Plugging Data: Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Annulus Bottom 2113 ft • 0 ft - N/A Test Data: Initial 15 min 30 min 45 min Result Tubing 5 5 5 4 IA 50 83 66 11 P V OA 14 1107 • 1076 - 1068 - Remarks: I arrived on location to get up with Bill Kruskie for an MIT-OA on MPU H-13A.A Hot oil pump truck was on location to perform this test. Prior to my arrival a product called "Well Lock"was pumped into the outer annlus to remdiate a slow leak in the cement plug priro to final abandonment. It took .02 bbl of fluid to pressure up to 1107 psi with 38psi loss during the 30 minute test (31 psi during first 15 min; 8psi during last 15 min). Attachments: none SCANNED JUN 2 2 214 rev. 05-02-18 2018-0530_Plug_Verification_MPU_H-13A_II A OF Tjcj • �w_��\��s� THE STATE Alaska Oil and Gas k' ��- 7� OPAL /� sKA Conservation Commission tt"t• - 333 West Seventh Avenue .41 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 la-77 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov rte+ Bo York Operations Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU H-13A Permit to Drill Number: 202-167 Sundry Number: 318-174 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, LCQCS -- Hollis S. French Chair �. DATED this 2-`& day of April, 2018. RBDMS1C AN 3 0 2018 0 0 RECEIVED STATE OF ALASKA APR 1 9 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION P7'S 44 24_/ ) e APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Bb Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install WellLock Resin Dr- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: 0'A LC'i-k:— Hilcorp Alaska LLC Exploratory ❑ Development D. 202-167 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22818-01-00 7.If perforating: 8.Well Name and Number: �Ih What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 i' Will planned perforations require a spacing exception? Yes ❑ No ❑., MILNE PT UNIT H-13A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518/ADL0025906 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,142' - 4,109' , Surface - + Surface 40 Surface&5,326' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,880' 9-5/8" 3,880' 2,908' 5,750psi 3,090psi Intermediate 6,742' 7" 6,742' 4,016' 7,240psi 5,410psi Liner 2,500' 4" 9,142' 4,109' 7,910psi 6,590psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic r See Schematic 4-1/2" 12.6#/L-80 6198 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 4.5"SC-1R and N/A s 6,642MD/4,002TVD and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑., ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: ____--- 5/2/2018 "". Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑., 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Wt. "2 1-4(60 i Authorized Name: Bo York Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wrivard cl.hilcorp.com 1k Contact Phone: 777-8547 Authorized Signature: tF1�IKJir'^ ✓ Date: 4ION USE18 COMMISSION ONLY Conditions of approv otify Commission so that a representative may witness Sundry Number: 318- I44 Plug Integrity I BOP Test ElMechanical Integrity Test DI Location Clearance El Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ 4-iSpacing Exception Required? Yes ❑ Nod Subsequent Form Required: /ID- APPROVED BY LI ! Approved by: 4`' - -_► COMMISSIONER THE COMMISSION Date: U Z`{ o i R �. 8/4111t Submit Form and Form 10-403 Revised 412017 Approved appitEatTovd o 1 ALom the date of approval. achments in Duplicate • • Micro OA Squeeze Well: MPU H-13A u le ro Alaska,LLI Date:4/9/18 Well Name: MPU H-13A API Number: 50-029-22818-01 Current Status: Suspended Pad: H-Pad Estimated Start Date: May 2"d, 2018 Rig: N/A Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-167 First Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Current Bottom Hole Pressure: 0 psi (Plugged to Surface) Maximum Expected BHP: 0 psi (Plugged to Surface) MPSP: 40 psi (Max OA after bleed on 4/10/18) Brief Well Summary: H-13A was drilled as a Schrader Bluff development well in October 2007. The well was suspended with a reservoir abandonment plug utilizing coil tubing in July 2014.The Nordic#3 rig plugged the well back at surface in May 2015 including circulating a cement plug through casing punches in the 7" at 203' and up into the OA to surface. The OA surface plug had good returns throughout with 5 bbls of clean cement returned. However in December 2017, as preparations were made for surface abandonment, ^'40 psi pressure was observed on the OA.The pressure slowly returns despite multiple bleed downs of diesel freeze protect. f Follow-up injectivity testing confirmed an LLR of roughly .3gal/min at 1000 psi. Slow leakoff indicates a micro annulus in the —203' OA surface plug. The well's OA was bled down and the OA valve temporarily removed. Cement was found at surface, immediately behind the valve with a small weep hole that appeared to be allowing communication.The valve was reinstalled. / Objective: Repair micro annulus in H-13A OA surface cement plug with WeIlLock Resin to allow for future surface abandonment.d Sundry Procedure(Approval Required to Proceed): 1. Install heater trunk 48 hr prior to application, pointing to the surface casing/conductor. a. Targeting a treatment temp of 70-80 degF 2. Immediately prior to application, record all WHPs, bleed any IA or OA pressure to zero and record type/quantity of returns. 3. Ensure sufficient Musol A and 55 gallon open top drum are available in the event that excess mixed WeIlLock must be diluted. 4. Record initial starting temperature of lowest accessible point on surface casing or starting head and at the OA valve. 5. Mix initial WeIlLock batch per HES recommended volumes,concentration and pumping procedure to pump initial volume through the OA valve. 6. Once initial volume away, apply squeeze pressure of at least 1000 psi to push WeIlLock into OA. 7. Monitor pressure leak off for indication of WeIlLock movement into micro annulus. a. LLR with diesel was roughly.3gal/min or 80 psi/min at 1000 psi. LLR with higher viscosity WeIlLock epoxy expected to be significantly less. 8. If no leakoff, increase squeeze pressure to 2000 psi. a. Contingency, if no pressure leakoff at 2000 psi, bleed back pressure to 0 psi. Remove OA valve and clean valve, iron and VR profile with Musol A to remove residual WeIlLock • Micro OA Squeeze Well: MPU H-13A ilileorp Alaska,Lia Date:4/9/18 9. Once OA pressure leaks off at least—500 psi, repeat steps 6-8 with additional batches of WeIlLock until all 10 gallons of WeIlLock are away or until squeeze pressure can be held.Assume initial batch of WeIlLock will gel within 12-24 hrs to the point that additional WeIlLock cannot be squeezed away. 10. Once WeIlLock application complete, bleed back pressure to 0 psi. Remove OA valve and clean valve, iron and VR profile with Musol A to remove residual WeIlLock 11. Reinstall OA valve and reapply pressure using N2 bottle to max bottle pressure but no higher than original squeeze pressure. 12. Note total volumes pumped &approximate volume squeezed into OA(don't count volume cleaned from OA valve) 13. Allow WeIlLock to cure for minimum of 7 days. a. Maintain wellhead temp with heater trunk targeting a treatment of 70-80 degF. b. Monitor temperature during curing phase per HES recommendation. 14. Once WellLock has cured, MIT-OA to 1000 psi with diesel .---i' 3 3'`v` 15. Bleed OA to 0 psi and monitor daily for any signs of repressurization. Attachments:Well Schematic trvT II h Milne Point Unit Well: MPU H-13A '� SCHEMATIC Abandoned: 5/15/2015 Hilcorp Alaska,LLC AD e PTD: 202-167 CASING DETAIL Orig.DF Elev.:66(N 22E)/GL Elev./316.7 /Ori.DF toCsg.Hgr.=3 62'(N 27E) Size Type Wt/Grade/Conn ID Top Btm 4 20" Conductor 91.1/H-40/N/A N/A Surface 112' 95/8" Surface 40/L-80/Btrc.Mod 8.835 Surface 3,380' 1 7" Intermediate 26/L-80/Btc Mod 6.276 Surface 6,742' �'g, = 2 4" Liner 9.5/L-80/521 Hydril 3.548 6,642' 9,142' 203'Cement . Plug tt �LiA TUBING DETAIL ie 158ppg 4-1/2" Tubing 12.6/L-80/N/A 3.958 250' 6,198 l-k co 95/8" q ES Cementer is Class"G' @2,113'ND :ement.Tag JEWELRY DETAIL Nib O,..enentw/ No Depth Item 4k down @ 5,326'CTM 1 203' Casing Punch 2 205' Casing Punch 3 6,140' D&D Tubing Stop Perf Tbg 6,110' 4 6,142' D&D Pack-off Assembly Top to 6,120.Able 5 6,151' Centrilift TTC-ESP Top to Inject @ 3 lbpmw/386psi 6 6,159' TTC Drilled Tubing Crossover 7 6,169' Tandem Seal Sections 8 6,183' Motor 9-5/8 j„3pu 9 6,192' PumpMate XTO w/6 Fin Centralizer WndowCut in 9-5/8” 10 6,642' 7"x 4.5"SC-1R Packer 3,880'to3,910 11 6,688' 4.5"CMD Sliding Sleeve WELL INCLINATION DETAIL 4 KOP @ 400' Max Hole Angle=<71.1 deg. @ 6,000' Hole Angle @ TIC-ESP=75Deg. 5 OPEN HOLE/CEMENT DETAIL 6 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/1,948 sks PF"E",2785 sx Class"G"&200sx PF"C"in 12-1/4"Hole 7" Cmt w/230 sks Class"G"in 8-1/2"Hole hl' TREE&WELLHEAD 7 Tree Cameron 4-1/16"5M Wellhead 11"x 11"5M FMC Gen 6,w/11 x 4-1/2""FMC Tbg.Hngr.4-1/2"521 Hydril T&B,4"H BPV Profile 8 GENERAL WELL INFO `9 API:50-029-22818-01-00 Drilled and Cased by Nabors 22E -10/22/1997 De-completed for Sidetrack by Nabors 4ES—7/25/2002 Sidetrack&ESP Completion w/Doyon 141—9/12/2002 ESP Change-out w/Nabors 4-ES—12/8/2004 Convert to TTC-ESP w/Nabors 4-ES—11/14/2009 Punch Holes/Coil Cement—7/31/2014 Abandonment by Nordic 3—5/15/2015 ' A. as+ 10 11 7„ 6-1/8"Hole TD @ 9,142' N-Sand Horizontal 1 37 Joints of4"Screen C27Baker Abed.Exduder2000 Baker GPV 5"Guide Shoe W 37 of 4"Bank&5.75"OD Centralizer Alternating TD=9,440'(MD)/TD=7,191'(TVD) PBTD=9,332'(MD)/PBTD=7,12T(TVD) Created By:STP 9/08/2016 • • vOF 7' �j,�s THE STATE Alaska Oil and Gas Of/` L /\ sKA. Conservation Commission _ — 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of AL AS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCANNED F -B 162.017' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-13A Permit to Drill Number: 202-167 Sundry Number: 316-473 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this 4 day of September, 2016. RBDMS w SEP 2 6 2016 • • STATE OF ALASKA SEP 1 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION - APPLICATION FOR SUNDRY APPROVALS GC; c-n-.k'-- 20 AAC 25.280 1.Type of Request: Abandon 2 , Plug Perforations 9 Fracture Stimulate 9 Repair Well 9 Operations shutdown 9 Suspend 9 Perforate 9 Other Stimulate 9 Pull Tubing 9 Change Approved Program 9 Plug for Redrill 9 Perforate New Pool 9 Re-enter Susp Well 9 Alter Casing 9 Other: MBE Treatment 9 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory 9 Development Q, 202-167 " 3.Address: 3800 Centerpoint Dr,Suite 14000 6.API Number: Stratigraphic 9 Service Anchorage Alaska 99503 50-029-22818-01-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 '- Will planned perforations require a spacing exception? Yes 9 No ❑., J MILNE PT UNIT SB H-13A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518/ADL0025906 " MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,142' ' 4,109' • Surface - Surface 0 Surface&5,326' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,880' 9-5/8" 3,880' 2,908' 5,750psi 3,090psi Intermediate 6,742' 7" 6,742' 4,016' 7,240psi 5,410psi Liner 2,500' 4" 9,142' 4,109' 7,910psi 6,590psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 6198 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 4.5"SC-1R and N/A 6,642MD I 4,002TVD and N/A 12.Attachments: Proposal Summary 9 Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch 9 Exploratory 9 Stratigraphic ❑ Development 2Service 9 14.Estimated Date for 15.Well Status after proposed work: 9/30/2016 Commencing Operations: OIL ❑ WINJ 9 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 9 WAG 9 GSTOREl❑ SPLUG Commission Representative: GINJ 9 Op Shutdown 9 Abandoned Q , 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola SiI Email sporholaahilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 9/13/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity (` BOP Test 9 Mechanical Integrity Test 9 Location Clearance 9 Other: e. `e ell) de.c •--»t.:. Ctet.S;'� c:..4. --e 7 r r F LI `- Post Initial Injection MIT Req'd? Yes 9 No V Acc- a. (L t 1 b Spacing Exception Required? Yes 9 No Subsequent Form Required: A/ - 4/0 -7'.. APPROVED BY RBDMS ( �' SEP 2 6 2016 Approved by: COMMISSIONER THE COMMISSION Date��z 7 /Kh i �eIIC R I C I N AL ��6�� ,-Z�-�6 * Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of appr al. Attachments in Duplicate • S Well Prognosis Well: MPU H-13A Hilcarp Alaska,LU Date:9/08/2016 Well Name: MPU H-13A API Number: 50-029-22818-01 Current Status: Suspended Pad: H-Pad Estimated Start Date: September 30th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-167 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Job Type: Surface P&A Current Bottom Hole Pressure: 0 psi (Plugged to Surface) Maximum Expected BHP: 0 psi (Plugged to Surface) MPSP: 0 psi (0.10 psi/ft gas gradient) Brief Well Summary: The Milne Point H-13A well was drilled as a Schrader Bluff development well that TD'd at 9,440' and ran and cemented 7" casing in October 2007. An open hole lateral/screened completion was subsequently drilled and lined with 4" screens in the Schrader Bluff N sand. Cement of 9-5/8" surface casing was to surface during the second stage cement job from the cementer at 2,113'. The well was suspended with a reservoir abandonment plug utilizing coil tubing in July 2014. During these operations an abandonment plug was set at 5,326'. The most recent casing pressure test of casing & reservoir abandonment plug at 5,326' was performed to 1,650psi on 7/26/14. Subsidence issue identified by tubing caliper from 260' to 290' in this well. The Nordic #3 rig plugged the well back to the surface in May 2015. Notes Regarding Wellbore Condition • Plugged back to surface in 2015. Objective: Finalize the surface abandonment of the well. •' Surface Procedure: 1. Notify AOGCC inspectors 24 hrs prior to cutoff of wellhead and welding marker plate. 2. Excavate cellar, cut off wellhead and casing 3' below natural GL. a. If cement fell back, bring cement top to level of cut. 3. Photograph casing stub before setting marker plate. — , h:1 ,l' LL 4. Set marker plate, collect GPS coordinates. f � , L�✓ 1:119 - tcrA*1 5. Photograph casing stub after setting marker plate. 12"u 6. Backfill cellar, close out location. Attachments: 1. As-built Schematic il Milne Point Unit Well: MPU H-13A 14 • SCHEMATIC Abandoned: 5/15/2015 Hilcorp Alaska,LLC PTD: 202-167 Orig.OFElev.:66(N22E)/GLElev.:36.7 CASING DETAIL /Orip DF toCssg.FIN.=31.62'(N22E) Size Type Wt/Grade/Conn ID Top Btm ( o S ' ,4 20" Conductor 91.1/H-40/N/A N/A Surface 112' 6 20' 'T *�•* r 9-5/8" Surface 40/L-80/Btrc.Mod 8.835 Surface 3,380' Mottli* 7" Intermediate 26/L-80/Btc Mod 6.276 Surface 6,742' 203'Cement = C1 2 4" liner 9.5/L-80/521 Hydril 3.548 6,642' 9,142' Plug w, 4 TUBING DETAIL IA4-1/2" Tubing 12.6/L-80/N/A 3.958 250' 6,198 Homco 95/8"ii 4f 15.8 ppg ES Cementer k Class"G @2,113MD l 'Cement Tag / JEWELRY DETAIL ,� Ai Cementw/ No Depth Item 4k down @ 5,326'CTM 1 203' Casing Punch 2 205' Casing Punch 3 6,140' D&D Tubing Stop ?, Perf Tbg 6,110' 4 6,142' D&D Pack-off Assembly Top to 6,120'.Able ix ' to Inject @ 5 6,151' Centrilift TTC-ESP Top 6 6,159' TTC Drilled TubingCrossover rt 0,z-',, 3 1bpm w/386psi 7 6,169' Tandem Seal Sections 8 6,183' Motor 9-5/8' .;' 9 6,192' PumpMate XTO w/6 Fin Centralizer Wndowlutin9-5/8' 1y ,r ' 10 6,642' 7"x4.5"SC-1R Packer 3,880'to3,910' , t 11 6,688' 4.5"CMD Sliding Sleeve WELL INCLINATION DETAIL 4 KOP @ 400' Max Hole Angle=<71.1 deg. @ 6,000' , Hole Angle @ TTC-ESP=75Deg. -1;,,,,':,,,‘- 'e.,,, 5 OPEN HOLE/CEMENT DETAIL < " ., 6 20" Cmt w/250 sks of Arcticset I in 24"Hole bx'lt9-5/8" Cmt w/1,948 sks PF"E",2785 sx Class"G"&200sx PF"C"in 12-1/4"Hole `�, 7" Cmt w/230 sks Class"G"in 8-1/2"Hole > °* TREE&WELLHEAD r " 4. ,� 7 Tree Cameron 4-1/16"5M -f t `� �� Wellhead 11"x 11"SM FMC Gen 6,w/11 x 4-1/2""FMC ) t f Tbg.Hngr.4-1/2"521 Hydril T&B,4"H BPV Profile " � ;, GENERAL WELL INFO `� API:50-029-22818-01-00 4' Drilled and Cased by Nabors 22E -10/22/1997 *'..-f;,:',4" -,.„ni sti ::* De-completed for Sidetrack by Nabors 4ES—7/25/2002 ti ;gym k 1 Sidetrack&ESP Completion w/Doyon 141—9/12/2002 t1,-,,,;,-1'4-',,,4,S' ESP Change-out w/Nabors 4-ES—12/8/2004 r . xP' ,. Convert to TTC-ESP w/Nabors 4-ES—11/14/2009 r # Punch Holes/Coil Cement—7/31/2014 1110.`1 .'''>1" Abandonment by Nordic 3—5/15/2015 . 10 11 7" 6-1/8"Hole TD @ 9,142' 4 N-Sand Horizontal 37 Joints of 4"Screen C27 Baker Med.Excluder 2000 Baker GPV 5"Guide Shoe W37 of 4"Blank&575'OD Centralizer Alternating TD=9,440'(MD)/TD=7,191'(TVD) PBTD=9,332'(MD)/PBTD=7,123'(TVD) Created By:STP 9/08/2016 STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforatioi l Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforat❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program [11 Plug for Redrill 0 Re-enter Susp.W[] Repair Well ❑ Re-enter Susp We( ❑ Other: ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑✓ Exploratory 0 202-167 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22818-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL0025518/ADL0025906 MILNE PT UNIT SB H-13A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL SEP 1 2016 11.Present Well Condition Summary: AOGCC Total Depth measured 9,142 feet Plugs measured Surface&5,326' feet true vertical 4,109 feet Junk measured N/A feet Effective Depth measured Surface feet Packer measured 6,642 feet true vertical Surface feet true vertical 4,002 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,880' 9-5/8" 3,880' 2 908' 5 750psi 3,090psi Intermediate 6,742' 7" 6,742' 4,016' 7,240psi 5,410psi Liner 2,500' 4" 9,142' 4,109' 7,910psi 6,590psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic r° t ) 2 3 LW! Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 6,198' 3,926' _ + Packers and SSSV(type,measured and true vertical depth) 7"x 4.5"SC-1R N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A -3 (6' '(Q 1 d 13. Representative Daily Average Production or Injection Data ` ' ``Lk, �� Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑, WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ ❑ SUSP rig Abandoned' j 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-284 Contact Stan Porhola Email sporhola(p hilcorp.com Printed Name Bo York Title Operations Engineer Signature /0/7/ 57- ZPhone 777-8345 Date 9/13/2016 jo7l4' t4' ,0 1°1'4 7(6 RBDMS SEP 16 2016 Form 10-404 Revised 5/2015 Submit Original Only • • Milne Point Unit Well: MPU H-13A SCHEMATIC Abandoned: 5/15/2015 flilcorp Alaska,LLC PTD: 202-167 CASING DETAIL Clog.DF Elev.:66(N 22E)/GL Elev.:36.7 /Ori DF to Cs H = x.62'N22E) Size Type Wt/Grade/Conn ID Top Btm " 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20k yam" ":t.„7,0". ' 4 k 9-5/8" Surface 40/L-80/Btrc.Mod 8.835 Surface 3,380' i +} k._ 7" Intermediate 26/L-80/Btc Mod 6.276 Surface 6,742' 203'Cement 2 4" Liner 9.5/L-80/521 Hydril 3.548 6,642' 9,142' Plug TUBING DETAIL y, 4-1/2" Tubing 12.6/L-80/N/A 3.958 250' 6,198 Howco 9-5/8"$, il 15.8 ppg ES Cementer i" 4Class"G' @2,113'MD 7 iCement Tag JEWELRY DETAIL • Ai Cementw/ No Depth Item 4k down @ 5,326'CTM 1 203' Casing Punch 2 205' Casing Punch 3 6,140' D&D Tubing Stop ,r ? Perf Tbg 6,110' 4 6,142' D&D Pack-off Assembly Top t ,.-4,':,!-, to 6,120'.Able 5 6,151' Centrilift TTC-ESP To l> s to Inject @ p y + 3 lbpmw/386psi 6 6,159' TTC Drilled Tubing Crossover 7 6,169' Tandem Seal Sections 4 k" o- 8 6,183' Motor g5/g '' 9 6,192' PumpMate XTO w/6 Fin Centralizer WndwCut in9-58 t'1',;11,3:.,„'';',-;; . :s 10 6,642' 7"x4.5"SC-1R Packer 3,880 to 3,910' l',--.,..t.` 11 6,688' 4.5"CMD Sliding Sleeve a i l' WELL INCLINATION DETAIL " '" k; 4 KOP @ 400' Max Hole Angle=<71.1 deg. @ 6,000' Hole Angle @ TTC-ESP=75Deg. 9 1 k> S OPEN HOLE/CEMENT DETAIL ifiert v 6 20" Cmt w/250 sks of Arcticset I in 24"Hole '3':,.4.81.;,.. 9-5/8" Cmt w/1,948 sks PF"E",2785 sx Class"G"&200sx PF"C"in 12-1/4"Hole fT "� 7" Cmt w/230 sks Class"G"in 8-1/2"Hole TREE&WELLHEAD ;; Tree Cameron 4-1/16"5M Wellhead 11"x 11"5M FMC Gen 6,w/11 x 4-1/2""FMC R Tbg.Hngr.4-1/2"521 Hydril T&B,4"H BPV Profile tz: 8 t„ '' ; GENERAL WELL INFO pitp;., API:50-029-22818-01-00 9 Drilled and Cased by Nabors 22E -10/22/1997 � N �3� ;. De-completed for Sidetrack by Nabors 4ES—7/25/2002 Sidetrack&ESP Completion w/Doyon 141—9/12/2002 5 > r`f: ESP Change-out w/Nabors 4-ES—12/8/2004 * Convert to TTC-ESP w/Nabors 4-ES—11/14/2009 " '' Punch Holes/Coil Cement—7/31/2014 Abandonment by Nordic 3-5/15/2015 s x11 7 "z4 i K........_ 6-1/8"Hole TD @ 9,142' A N-Sand Horizontal 37 Joints of 4"Screen C27 Baker Med.Excluder 2000 Baker GPV 5"Guide Shoe W37 of 4"Blank&5.75'OD Centralizer Alternating TD=9,440'(MD)/TD=7,191'(TVD) PBTD=9,332'(MD)/PBTD=7,123'(TVD) Created By:STP 9/08/2016 • Hilcorp Alaska, LLC WeeklyOperations HirIcorp Alaska,LLC p Summary Well Name API Number Well Permit Number Start Date End Date MPH-13A 50-029-22818-00-00 202-167 5/14/2015 5/15/2015 ITEM m 6.U11' 5/13/15-Wednesday,' No operations to report. 5/1.4/151-Thursday};: r r '''• Accept rig H-13. Berm cellar,well dead ND Tree. NU BOPE.Test BOPE 250psi low/3,000psi high.Test Annular 250psi low/2,500psi high,accumulator draw down test all good. Rig down test gear. Pull TWC, rig upbses._chart.and test 4.5"._. x 7"annulus to 1,5002si for 30 minutes.50psi drop equivalent to expansion of 7"x 9-5/8"to 300psi from original 1' 250psi. Bleed off OA to 50 psi.SI IA stable @ 1,500psi. Bleed off all side, rig down hose. PU 4.5" Hydril LD, install same BO hanger pins. PU and set 10K in slips. MU gauge ring and Junk basket RIH to 300'. POOH LD same MU/PU 3-5/8"jet cutter, RIH and Cut 4.5"pipe @ 250'. RD e-line, PU to 5-6 K(48k) no drag cable possibly finished parting SW 42K POOH decomplete hanger.Attempt to POOH diesel and casing test fluid swapping sides well out of balance. Build 8.5ppg brine and displace diesel to kill tank. Resume POOH and LD 5 jts and cutoff 10.6'.Total recovery w/hanger 252.3'. ESP cable recovery same as pipe. Install Dutch riser, RU a-line RIH w/2"decentralized circ.gun 4 spf and shoot circ shots @ 205'. No well response,attempt to circ.pressure to 900psi,no circ,bleed off pull to surface with e-line to surface. Open annulus check for Ice plugs in IA valves no evidence. POOH with gun,all shots fired. MU new 2"circ.gun PU RIH perf again at 203'circ.attempt successful. POOH with e-line. 5/15/15-Friday _ i,l = !6,; Circ.at 2 BPM 160psi>120psi current tries to pack off at 3 BPM circulating out all!diesel. RD e-line.Shut down circulation to wait on hot water to flush OA before cementing.Offloading hot seawater and begin pumping hot water to clean up annulus. Pressure dropped during pumping to 234psi @ 3bpm 290 bbls pumped and recovered. Pressure 90,4 test all lines 2,300psi all good, pump 10 bbls spacer,18.8 bbls 15.8 pp&_retarded Arctic Class C Cement, 15.8,ppggood returns throughout.5 bbls good clean cement returns.RD cementers,flush stack and lines, PU landing JT,land hanger 04' w/4' pup. Heat expansion creating imitation gas install BPV.Clean out BOP from cement job. ND BOPE NU Tree. RDMO 5/1671S-Saturday JI=,,111r[' ,. p No operations to report. 5/1//15-54.0 ,I�� No operations to report. 5/18/15-Monday i "i' �'I I Imp' No operations to report. 5/19/15-Tuesda i.; l _ i �' � � � �� i all'�i� � � No operations to report. 41716 - L113 tom_ ��,v oF/T,„ s THE STATE Alaska Oil and Gas 'rw��'- — � v Conservation Commission _� fl 1JJASJ(/\ 4 x_—_-=_ 333 West Seventh Avenue *h, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OF ALAS�� Fax: 907.276.7542 www.aogcc.alaska goy Chris Kanyer SCANNED MAY 1 3 2015 Operations Engineer Hilcorp Alaska, LLC ao a 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-13A Sundry Number: 315-284 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, f.gf /0 204_ ,74._____ Cathy P y oerster Chair DATED this /Z day of May, 2015 Encl. RECEIVED STATE OF ALASKA MAY 0 8 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION D7-5 51 . 2 IS APPLICATION FOR SUNDRY APPROVALS ,AOGCC 20 MC 25.280 1.Type of Request: Abandon I Plug for Redrill ❑ Perforate New Pool El Repair Well 0 Change Approved Program ❑ Suspend I Plug Perforations ❑ Perforate❑ Pull Tubing Q Time Extension 0 Operations Shutdown El Re-enter Susp.Well [t7f Stimulate❑ Atter Casing❑ Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0- 202-167 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22818-01-00 . 7.If perforating: i( r' .Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 47-7- Will planned perforations require a spacing exception? Yes ❑ No D MILNE PT UNIT SB H-13A- 9.Property Designation(Lease Number): ?iiio10.Field/Pool(s): ADL0025518 I Me.. 3.5-Vg. MILNE POINT/SCHRADER BLUFF OIL, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,142 • 4,109 ' 5,326' 3,577 • 5,377' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 3,880' 9-5/8" 3,880' 2,908' 5,750psi 3,090psi Intermediate 6,724' 7" 6,742' 4,016' 7,240psi 5,410psi Production Liner 2,500' 4" 9,142' 4109' 7,910psi 6,590psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 6,198 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 4.5"SC-1R Packer and N/A s 6,642(MD)/4,002(TVD)and N/A 12.Attachments: Description Summary of Proposal ❑l 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development❑✓ - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: e Commencing Operations: 5/16/2015 Oil 0 Gas ❑ WDSPL ❑ Suspended J 16.Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned 5Vf Commission Representative: N/A GSTOR ❑ SPLUG LI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email Chris Kanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377 Date 5/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 (5 - 2Vy Plug Integrity 1 BOP Test Z- Mechanical Integrity Test ❑ Location Clearance ❑ Other: x 300Z) A S- &�1 4- ( AAA ioT" - 3s )/ /HA2 „coc 4.-S;'3e c.-_ 16 G' Lk)titi/�t� P/&&, Spacing Exception Required? Yes LI No 2 Subsequent Form Required: /0 --`f&- APPROVED BY 1— Approved by: P ,.moi COMMISSIO�N,E�R THE COMMISSION Date:J /2.---/c" mit Form and Form 10elz_ Rev pg Id 1c s id for 12 months/ran the date of approval �� Attachments in Duplicate RBDMS J1h MAY 1 2 15 57'7! Well Prognosis • Well: MPH-13A Hilcorp Alaska,LL Date:5/08/2015 Well Name: MPH-13A API Number: 50-029-22818-01-00 Current Status: Suspended Pad: H Pad Estimated Start Date: May 16, 2015 Rig: Nordic 3 Reg.Approval Req'd? May 15, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-167 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) AFE Number: 1551190 Current Bottom Hole Pressure: N/A (N/A- No open Perfs) Maximum Expected BHP: N/A (N/A- No open Perfs) Max. Allowable Surface Pressure: 358 psi (Assume 0.1 psi/ft to plug at 3,577'TVD) Brief Well Summary: The Milne Point H-13A well was drilled as a Schrader Bluff development well that TD'd at 9,440' and ran and cemented 7" casing in October 2007. An open hole lateral/screened completion was subsequently drilled and lined with 4" screens in the Schrader Bluff N sand. Cement of 9-5/8" surface casing was to surface during the second stage cement job from the cementer at 2,113'. The well was suspended with a reservoir abandonment plug utilizing coil tubing in July 2014. During these operations an abandonment plug was set at 5,326'.The most recent casing pressure test of casing & reservoir abandonment plug at 5,326' was performed to 1,650psi on 7/26/14. Subsidence issue identified by tubing caliper from 260'to 290' in this well. Notes Regarding Wellbore Condition Current well status is suspended. RWO Objective: Complete install surface abandonment plug&abandon onshore well that has no future wellbore utility Brief Procedure: 1. MIRU Nordic#3 Rig. 2. ND tree, NU 11" BOPE and test to 250psi low/3, QQ i high,annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 3• Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. gt.i.e,5' b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at � surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. . 11 Well Prognosis • Well: MPH-13A Hilcory Alaska,LL Date:5/08/2015 e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 4. RU Eline. 5. Unseat hanger put tubing in tension. yl_ 6. Perform tubing cut at+/-200'. 7. Perform secondary tubing cut at+/-200' in attempt to cut ESP cable. (Repeat if necessary.) 8. RIH and punch 7" casing at+/- 175'. 9. Circulate well with 8.5ppg seawater from tubing punch at+/-175',down 7" casing and up 7"x 9-5/8" casing annulus. Monitor well. 10. Circualte cement plug from 175'to surface. 11. ND BOP, NU dry hole tree. Ale�' 2:1- c 12. RDMO workover rig and equipment. ` -4-ft-44-- Post Rig Activities: 13. Excavate well/remove cellar as necessary. 14. Cut off wellhead and casing at least 3' below original/natural ground level. 15. Install marker plate in accordance to 20AAC25.120 Re7.65 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit • Well: MPU H-13A SCHEMATIC Last Completed: 11/14/2009 Hilcorp Alaska,LLC PTD: 202-167 CASING DETAIL orig DF Bev.:66(N 22E)/GL Elev.:36.7 '• DFYQCV-W 30.621N22E) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20"I t• 9-5/8" Surface 40/L-80/Btrc.Mod 8.835 Surface 3,380' • 7" Intermediate 26/L-80/Btc Mod 6.276 Surface 6,742' 4" Liner 9.5/L-80/521 Hydril 3.548 6,642' 9,142' TUBING DETAIL 8 PPg 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surf 6,198 l-km o9Sr8'j i4 ES Cementer 1 ,n ass"G' @2,113'ND merit Tag JEWELRY DETAIL d 4kd gint @ No Depth Item 6'CTM 1 6,140' D&D Tubing Stop 2 6,142' D&D Pack-off Assembly Top Perf nig 6,110 3 6,151' Centrilift TTC-ESP Top to 6,120.Pole 4 6,159' TTC Drilled Tubing Crossover to Inject @ 5 6,169' Tandem Seal Sections 1 1ban w/386Psi 6 6,183' Motor 7 6,192' PumpMate XTO w/6 Fin Centralizer 9-5/8" 8 6,642' 7"x 4.5"SC-1R Packer 9 6,688' 4.5"CMD Sliding Sleeve Wndow Cut in 9-58" 3,880 to 3,910 WELL INCLINATION DETAIL KOP @ 400' 2 Max Hole Angle=<71.1 deg. @ 6,000' Hole Angle @ TTC-ESP=75Deg. vOPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole 3 9-5/8" Cmt w/1,948 sks PF"E",2785 sx Class"G"&200sx PF"C"in 12-1/4"Hole 4 7" Cmt w/230 sks Class"G"in 8-1/2"Hole TREE&WELLHEAD Tree Cameron 4-1/16"5M Wellhead 11"x 11"5M FMC Gen 6,w/11x4-1/2""FMC 5 Tbg.Hngr.4-1/2"521 Hydril T&B,4"H BPV Profile GENERAL WELL INFO API:50-029-22818-01-00 6 Drilled and Cased by Nabors 22E -10/22/1997 De-completed for Sidetrack by Nabors 4ES—7/25/2002 ! Sidetrack&ESP Completion w/Doyon 141—9/12/2002 ESP Change-out w/Nabors 4-ES—12/8/2004 ?• Convert to TTC-ESP w/Nabors 4-ES—11/14/2009 Punch Holes/Coil Cement—7/31/2014 F,, 8 9 7' 6-1/8"Hole TD @ 9,142' N-Sand Horizontal 37 Joints of 4"Saeen C27 Baker M .Excluder 2000 Baker GPV 5"Guide Shoe W 37 of 4 Blank&5.75"OD Cattralizer Alternating TD=9,440'(MD)/TD=7,191'(1VD) PBTD=9,332'(MD)/PBTD=7,123'(TVD) Created By:TDF 5/4/2015 Milne Point Unit Well: MPU H-13A PROPOSED Last Completed: 11/14/2009 Ililcarp Alaska,LLC PTD: 202-167 CASING DETAIL Orig.IX Bev.:66(N 22E)/GL Elev.:36.7 /OriptDFtoCsx.Hp.31.621N22E) Size Type Wt/Grade/Conn ID Top Btm V 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20 9 5/8" Surface 40/L-80/Btrc.Mod 8.835 Surface 3,380' 7" Intermediate 26/L-80/Btc Mod 6.276 Surface 6,742' 175 Cements 4" Liner 9.5/L-80/521 Hydril 3.548 6,642' 9,142' Plug TUBING DETAIL 8 PPg Harsco 9-5/8" r 4-1/2" Tubing 12.6/L-80/N/A 3.958 ±200' 6,198 ESCementer'' Cass"G" JEWELRY DETAIL ©ammo1 4 Cement.Tag No 1 #4,Cement w/ No Depth Item 4k down @ 5,326'UM 1 ±175' Casing Punch 2 6,140' D&D Tubing Stop 3 6,142' D&D Pack-off Assembly Top •," Perf Tbg 6,11tY 4 6,151' Centrilift TTC-ESP Top to 6,120'.able 5 6,159' TTC Drilled Tubing Crossover to Inject @ 6 6,169' Tandem Seal Sections 2 lbpmw/3861si 7 6,183' Motor 8 6,192' PumpMate XTO w/6 Fin Centralizer 9-5/8" 9 6,642' 7"x 4.5"SC-1R Packer VIAndovrCut 10 6,688' 4.5"CMD Sliding Sleeve 3,880to3,910 1 WELL INCLINATION DETAIL 1 KOP@400' 3 Max Hole Angle=<71.1 deg. @ 6,000' ( Hole Angle @ TTC-ESP=75Deg. OPEN HOLE/CEMENT DETAIL ' 4 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/1,948 sks PF"E",2785 sx Class"G"&200sx PF"C"in 12-1/4"Hole 5 7" Cmt w/230 sks Class"G"in 8-1/2"Hole TREE&WELLHEAD Tree Cameron 4-1/16"5M Wellhead 11"x 11"5M FMC Gen 6,w/11 x 4-1/2""FMC 6 Tbg.Hngr.4-1/2"521 Hydril T&B,4"H BPV Profile GENERAL WELL INFO API:50-029-22818-01-00 Drilled and Cased by Nabors 22E -10/22/1997 De-completed for Sidetrack by Nabors 4ES—7/25/2002 ' 8 Sidetrack&ESP Completion w/Doyon 141—9/12/2002 ESP Change-out w/Nabors 4-ES—12/8/2004 Convert to TTC-ESP w/Nabors 4-ES—11/14/2009 Punch Holes/Coil Cement—7/31/2014 *0 lio 9 It ;,10 7' v: -4 ,,,,..: 6-1/8"Hole TD @ 9,142' N-Sand Horizontal 37Joints cf4"Sawn C27Baker kW.Excluder 2000 Baker GPV 5"Guide Shoe H/3T cf 4"Blank&5.75"CO Centralizer Alternating TD=9,440'(MD)/TD=7,191'(TVD) PBTD=9,332'(Mi))/PBTD=7,123'(TVD) Created By:TDF 5/8/2015 11" BOP Stack r \ 0 0 ii i i 11. 1111, Hydril 11" SM c i iiiii / Shaffer — a°101 ( 2 3/8" Rams _01:1) a210 --.0 11" 5M 2 7/8-5.5 OD variables 0o o i 9 Hydril — CIO . 11" 5M OD Blinds 4.034 - ; , Optional valve port ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q.;;l - L to '!- Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 p£scan Needed 11111III11111111111 RESCAN ~Ior Items: 0 Greyscale Items: DI~TAl DATA ~ Diskettes, NO.,~ 0 Other, NofType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: Scanning Preparation BY: Helen S 0 Other:: " Date I ó 'J-r 0 if /s/ ~ , , 1111111111111111111 Date ¡ () ~r. '() If- /s/ }In p +~.CS- = TOTAL PAGES 6S (count., dOEfS.. nO~!clude cove..r sheet) iAI1P Date I () J-~ /)'f /s/ t' f Production Scanning . 1111111111111111111 Stage 1 Page Count from Scanned File: ~ 1)"((J (Count does i70ver sheet) Page ~atches Number in Scanning Preparation: IY/E~ Ill-- N/OSI . A~..," BY: Helen ( ,v,aria../ Date: It) D ( V VI, . . YES NO Helen . C~aria) BY: Project Proofing BY: Helen ~ I x 30 = 30 Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: Isl Scanning is complete at this point unless rescanning is required. 1111111111111111111 ReScanned 1111111111111111111 BY: Helen Maria Date: Is/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc (-- T r i + : 'y'C J .2__ .1 )-1\\.1`i \2 }n 4i.:..,:,,•-•,--1",;.----:-- — — 333 Wet Seventh Avenue / GOVERNOR SiAN PARNELI. Anchorage Alaska 99501 3572 `_4>® Main_ 937.279.1 433 6s "'s'>P e, SCANNED MAY 0 7 2014 Clint Spence aag- t 6 Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPH-13A Sundry Number: 314-153 Dear Mr. Spence: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, aiti,,A,79Cat y Poerster Chair DATED this j4 day of April, 2014. Encl. STATE OF ALASKA • ' ALASh,.JIL AND GAS CONSERVATION COMMIE—,ON RECEIVED APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 MAR 11 2014 1. Type of Request: l .$ 41(9-/) s- ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Progr QGCC ®Suspend • 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory 0 Stratigraphic \ 202-167 3. Address: 6. API Number: ,®Development 0 Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22818-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPH-13A Will planned perforations require a Spacing Exception? 0 Yes ® No 9. Property Designatior , 10.Field/Pool(s): ADL 025906&025518 Milne Point Unit/Schrader Bluff • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9142' • 4109' - 9142' - 4109' - None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32' - 112' 32'- 112' 1490 470 Surface 3849' 9-5/8" 31'-3880' 31'-2908' 5750 3090 Intermediate Production 6697' 7" 27'-6724' 27'-4014' 7240 5410 Liner 2500' 4" 6642'-9142' 4002'-4109' Perforation Depth MD(ft): , Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Gravel Screen Assembly: 6682'-9137' Gravel Screen Assembly: 4008'-4109' 4-1/2", 12.6# L-80 6198' Packers and SSSV Type: None Packers and SSSV None MD(ft)and ND(ft): 12. Attachments: 112 13.Well Class after proposed work: IN Description Summary of Proposal , I BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic,IN Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: March 25,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended , 17. I hereby certify that the foregoing i true and correct to the best of my knowledge. Contact: Abhijeet Tambe,564-4993 Printed Name: li Sp ce Title: Well Interventions Team Lead Email: Abhijeet.Tambe@bp.com Signature: Phone: 564-5709 Date: 3//i/i/) Commission Use Only _/ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: --).z\.14..— Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance I Other: 1 1 Spacing Exception Required? 0 Yes L'1 No Subsequent Form Required: 0 4 0 a / RBDM • .,,-,,AY 0 7 20)4 / APPROVED BY / Approved By: ( /P J �v�.— COMMISSIONER THE COMMISSION Date: (-/ t Form 10-403 Revised /2012 A r 11c r v li o1112 months from the date of approval 01.2) MJl`1)7 Submit In Duplicate V`LF 4/Jl/) pp �l � ` pp .,04-- ,M,-- 1 bP MPH-13A Suspension Plan Objective: This Program represents the initial down-hole intervention to permanently suspend Operation of this Well. The goal of the steps presented here are to force cement from the bottom of the production tubing (just above the ESP) at approx. 6097' MD, down-hole to the top of the N-Sands Screen at 6692' MD (in the "horizontal" section of the well). Additional abandonment work is intended be conducted in the future to secure the wellbore all the way to surface. It has not yet been determined what these additional steps will be. BP feels it is prudent to take this first step, however, as soon as practical, due to the unpredictable nature of the speed with which shallow subsidence is occurring (and the potential for additional Casing/Tubing restriction). X CanGr/ 340y Well History: MPH-13 (Milne Schrader) drilled by Nabors 22-E Oct. 1997. Original completion run by Nabors 4ES in June, 1998 (2-7/8" in 7"with tbg-retrievable ESP) ESP#1 failed July, 2002. Well sidetracked (MPH-13A) and completed by Doyon-141 September, 2002 (2-7/8" in 7") RWO Dec., 2004 to swap ESP (again 2-7/8" in 7"; Nabors-4ES) MPH-13A worked over by Nabors 4-ES in Nov., 2009 (4-1/2" in 7"with "TTC ESP"). Tight spot noted at 304' MD but completion was successfully run. Surveillance data indicate N-sand MBE between MPG-09 & MPH-13A. Pump has plugged off. Calliper Logs indicate axial displacement of tbg from 260-300' (and a minimum 5.91" ID in 7" Csg at 284'). High Level Steps: 1. S-Line Drift Tbg to 3.65" I.D. (top 1000' MD). 2. Service Wellhead, Tree &Valves. Pump 10 bbl Crude or diesel down I/A(to confirm communication with reservoir). 3. Utilize CT to perform Fill Cleanout&tag ESP Assembly. 4. CT convey"PowerCutter"to cut Tbg (& ESP cable) immediately above TTCESP (in between pipe joints). Page 1 5. Utilize CT to pump cement thru Tbg cut(up to 23 bbl cement chased by 2 bbl warm Fresh Water, or vol. pumped at"bump", whichever occurs first)for Reservoir Abandonment. Pump ball to "swap" nozzle, cleanout&freeze protect Tbg as necessary. 17 A 6. WOC 72 hours; confirm >200 psi compressive strength. Pump down I/A to ,- LI determine if I/A&Tbg are still in communication. If they are, perform CMIT to 1500 psi. If they are not, perform MIT-I/A and MIT-T independently. NOTE: If the CMIT/MIT fails, further diagnostics will be prepared and the work carried out under a separate procedure. Page 2 • • • APPNEDIX A— Current Wellbore Schematic Cameron 4 111 d"5M M ;1; Cng. DF Bey = 86.0'(N 22E1 ,e mead: 11"x 11"51y/FMC Gen 6, Ong GL Eben = 36 T N, 11'x 4 1i2"FMC Tbg Hgr 4 112" Ong_DF to csg hgr =30.62'(N 21 Hycfrel TM.4"H BPV profile 20' 01.1 ppf, H-4 r 112 -Iowoo 0 518"'ES Cenrerrter+113mct-, hot= le 400' Hole angle= <7110,6000' -sole angle fa ITC-ESP = 7° u 5'8 40 ppf, L-80 BTC mod prod cs anft ID=8 835" cap =0 0758 bpf :,30 Tbg Sox 1 'micro cut In 9 SJ$"; 3.800 -3,910 i D&C Note'Assy Top I : `- CentrEift TTC-ESP Tcp 18.'g• I • TTC Drifted Tbg Ctmssaver 0,150 1.2" 12.6 pp( L-80. 521 Hydnl Trbir4 Drift ID=3.833'. cap=0 0152 Tandem Seal Sectons 26 poi, L-80. BTC-Mod Cooing Men Model 0583 08 UT LT HL Ft$PFS 6.'c !Daft ID=6 151".cap =0-00383 bpr. Cap w; i 112' lbg +Horde=0.0186 bpi-, Motu.55 HP 1258 volt. -r 2f armm.Model KMHA 18 183' °urroMate e 4'r Ce-i aLzer 8,102' a npAAate =3r:` T':^ 7'x 4 5'gaiter 3C-'P Packer 70-4c L leaf caw a.E'- 45'gate"GMC Sirar,g Sleeve I J Scat s"oe 0,724' 4 1?''OE'7 14-Sam!4przont,j 37 joints 4'Screen C27 Barer W Excluder 7000 t W:37"4'E a•+ 5.75'00 Cent-Ater altemat-'3 6.697-9.130 DATE ._, = COMMENT: f�1ILNE P'=.INT hN .zA' '' Zr ro rc cased%yam .r sA= _et- 'e oery-pex'3".4e-rad r+aoce:sE., _ A ELL No:MPH-13a 1202 MOO Siet ack&ESP 0orrCleto-Doyon-'4- API - 5C-02'd-2__818-0' _=94 Le*Huirre ESP Changeout- Nabors 4ES _: _e.Huime CarventoTTC-E3P- Nabors 4E: BP EXPLORATION IAK, Page 3 v • APPNEDIX B -Wellbore Schematic Post Cement Plug Tree :.3'-1erc-4 15 514 '``PI.i U.a Ong DF Elev - bb: ,N 2.E :venneao. 11• k t 1 5114 FMC Gert b �-�' GL E - 36 T a Ong 1e1t w it'x 4 i.2'fMC Tbg Mgr 4 1,2 I Ong.Of to cig P -30.62'IN 2_E H 1nl Td®.4' M 8PV polite 1.1 20' 9" I pd1 14.4. 11Z -:Marco 9 5,5-'ES-Cementer r--.., or DP 0 400 .rte ange- - -1,C FCC: .1�..�:1- _ -3c sc sT. read prcc .$4 t -\ "PowerCut"at 6097'MD ...t IC : :-• cap -30759 CG' t \ DIM T5g DOD I Et.: I ow .1 m;+-5/3".3 t c1�'-3 r t J \2 h C80 PatxCr' TOp Com, Z.: t- CMtrIel TTC-EOP Tcp r \.:: l . C Drips tt9:1-364.3•44 1 6.1'5'1 3 1:2. .:8 pOf. L-s0. 6:1 FhyW. T„t. Droit ID-3 333'. bap-0 0162 .‘ , 1181111 "28 woo. L-63 STC-Mod Car.,Ca ••g ".. u• \ vole1 G363 DE._-H..-re ofs 1 f 155 I G 2 A 0 0^4 10-6.161' caw-00383 bpi, .`. Cao w 4 1 tbg,nckla-00186 be :Utf¶E•'P 19 rot. \ \ :t art voset KM-41 1 6.1E3 I ` 7 r\ :"1;,KiE'r 4 m CerV]lzer I e 19,I �� ,� Dtrrp ti!-3-E'T.'D Top DPZ=>Top of Schradr 6400'MO 3902TVDSS � ement squeezed from ..\1.: kieI Fr-ut to top of screen - ,_ Faker;GR.' Pater t .aL�: 16.543- 1 / 5atef C15C bite�Dee e F- -ALa7t3,113 p---,_1 - PF \\\ \` 14...nt:Hpr=mak Excluder SOC w 3' Sant 3 l' -- sir 0D Cerballar Merlin-1 6.552-9 135" =_ = MILNE POINT UP,T- • • • ' 'NELL No.MPM-I z „ ,.,. AP 50.0243-:..2818-0' '.CC _.1-^3..;e-- _ -)ems'_k_y_- a PTD 7O2167Q N. ...te 14Jr'1e E:P 2ratgewt-Nap=-E_ *am _ee-*um . Con er:to TTcF3P-tlatrs sE_ - E P EXPLORATION(AK) Page 4 - • • 0 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Sc.ANNEOFFB 11 7 201 Mr. Tom Maunder � y I / (0 Alaska Oil and Gas Conservation Commission ' o 7 333 West 7 Avenue Anchorage, Alaska 99501 rY' Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD if API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH -02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 "-," MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 STATE OF ALASKA RECEIVED ALAS &IL AND GAS CONSERVATION COMMI•ON Q E C j 4 7009 REPORT OF SUNDRY WELL OPERATION aska Oil & Gas Cons. Commission 1. Operations Performed: Anftrage ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change Out ES,P 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number. BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 202 -167 3. Address: ❑ Service ❑ Stratigraphic 1 4 API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 029 - 22818 - 01 - 00 7. Property Designatiorl� 8. Well Name and Numbwr. ADL 025518 MPH -13A 9. Field/ Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary q 0 Total depth: measured feet true vertical et Plugs (measured) None Effective depth: measured 9142 feet Junk (measured) None true vertical 4109 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 3849' 9-5/8" 3880' 2908' 5750 3090 Intermediate Production 6697' 7" 6724' 4014' 7240 5410 Liner 2500' 4" 6642'-9142' 4002' - 4109' Perforation Depth: Measured Depth: Gravel Screen Assembly: 6682'- 9137' True Vertical Depth: Gravel Screen Assembly: 4008'- 4109' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# L -80 6198' 3926' Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 15 5 362 60 212 Subsequent to operation: 15 6 269 240 226 13. Attachments: ❑ Copies of Logs and Surveys run I t Well Class after work: ❑Exploratory ®Development ❑Service ® Daily Report of Well Operations ® Well Schematic Diagram 5. Well Status after work: M oil ❑ Gas ❑ WDSPL [I GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Mehrdad Nadem, 564 -5941 WA I Printed Name Terrie Hubble Title Drilling Technologist Prepared By Na TWNumber: Signature Phone 564 -4628 Date �7 /Q Terrie Hubble, 564 -4628 Form 10-404 Revised 07/2009 Submit Original Only A /Z- -1s 0 1 MPH -13A, Well History (Pre Rig Workover) Date Summary 09/02/09 WELL S/I ON ARRIVAL. (DRIFT /CALIPER TBG /RIG PREP) RAN 2.15" CENT, S. BAILER TO 6372'. SLM WORK THROUGH TO 6399', SLM UNABLE TO GO ANY FURTHER. RECOVERED TEASPOON OF SAND. 09/03/09 RAN CALIPER PER PROCEDU GOOD DATA. PULLED 1" BK -DGLV FROM ST #1 @ 5,948' MD. PULLED 1" BK -DGLV FROM ST #2 @ 2,509' MD, SET 1" BK -DGLV IN ST #2 @ 2,509' MD. PULLED 1" BEK -DPSOV FROM ST #3 @ 166' MD, SET 1" BK -DGLV IN ST #3 @ 166' MD. WELL S/I ON DEP, TURNED OVER TO DSO. JOB COMPLETED. 09/03/09 T /I /O= 250/0/160 Freeze Protect Lateral Line. Pumped 2 bbls 60/40 methanol, 3 bbls Diesel, and 2 bbls 60/40 methanol down production and test flowlines. Closed Lateral valves and bleed flowline pressures to 0 psi. FWHP = 250/0/160 Master, IA, and OA open. Swab, SSV, and wing closed. 10/23/09 WELL S/I ON ARRIVAL. RIH W/ 2.07" CENT, S.S, DUAL SPARTEK GAUGES. MADE 3 HOUR STOP @ 6265' SLM & 20 MINUTE STOP @ 5765' SLM. ASSIST SUPPORT TECHS INSTALL BPV. BPV INSTALLED. WELL LEFT S /1. Page 1 of 1 BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 11/5/2009 16:00 - 22:00 6.00 RIGD P PRE RIG DOWN FROM WELL MPI -19. 22:00 - 00:00 2.00 RIGD P PRE SCOPE DOWN DERRICK. LOWER DERRICK. 11/6/2009 00:00 - 02:00 2.00 MOB P PRE MOVE SUB AND PITS OFF OF MPI -19. 02:00 - 06:00 4.00 MOB P PRE MOVE SUB AND PITS ONTO MPH -13. -SPOT SUB OVER MPH -13. -SPOT PITS. 06:00 - 08:00 2.00 MOB P PRE SPOT PIPE SHED. 08:00 - 11:00 3.00 MOB P PRE RAISE DERRICK. -R/U LINES. -RIG ACCEPTED AT 11:00 HRS 11/6/2009 11:00 -12:00 1.00 RIGU P PRE R/U TIGER TANK. 12:00 - 14:00 2.00 RIGU N RREP PRE #1 RIG GENERATOR DIED. -PURGE AIR FROM FUEL SYSTEM. - RESTART. 14:00 - 15:00 1.00 RIGU P PRE BPV. -M /U AND TEST LUBRICATOR TO 500 PSI. -PULL BPV. -L/D LUBRCATOR. -TBG PRESSURE BELOW 100 PSI. -IA = 160 PSI. -TAKE ON HEATED SEAWATER 15:00 - 15:30 0.50 RIGU P PRE PJSM WITH CREW AND TRUCK DRIVERS. 15:30 -16:00 0.50 KILL P DECOMP TEST SURFACE LINES TO 3,500 PSI. 16:00 - 21:30 5.50 KILL P DECOMP CIRCULATE KILLFLUID, 8.45 PPG SEAWATER. -BLEED DOWN TBG AND IA. -TBG AND IA PRESSURE BELOW 100 PSI. -PUMP 35 BBLS HEATED SEAWATER DOWN THE TBG, -TAKE RETURNS UP THE IA THROUGH THE CHOKE. - CIRCULATE @ 3 BPM / 200 PSI. -BULL HEAD 65 BBLS HEATED SEAWATER. - CIRCULATE @ 2 BPM / 480 PSI. -STOP PUMPING, TBG = 0 PSI AND IA = 200 PSI. -PUMP 200 BBLS HEATED SEAWATER. -PUMP DOWN THE TBG UP THE IA THROUGH THE CHOKE. - MONITOR WELL - WELL ON VACUUM. 21:30 - 23:00 1.50 KILL P DECOMP SET & TEST TWC. -TEST FROM BELOW 3 BPM / 50 PSI. -TEST FROM ABOVE 3500 PSI / 10 CHARTED MINUTES -PASS. 23:00 - 00:00 1.00 WHSUR P DECOMP ND TREE & ADAPTOR. 11/7/2009 00:00 - 00:30 0.50 KILL P DECOMP CONTINUE TO ND TREE & ADAPTOR. 00:30 - 05:00 4.50 BOPSUF P DECOMP NU BOPS. -MU TEST EQUIPMENT. 05:00 - 11:00 6.00 BOPSUF P DECOMP TEST BOPE PER BP & AOGCC REGULATIONS: -BOP CONFIGURATION: - 13 -5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. - SPACER SPOOL. -2 7/8" X 5" VARIABLE BORE RAMS. TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, - MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. Printed: 11/23/2009 9:43:55 AM BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/7/2009 05:00 - 11:00 6.00 BOPSUF P DECOMP -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -USED 2 7/8" AND 4 1/2" TEST JOINTS ON RAMS & ANNULAR. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESED BY BOB NOBLE AOGCC. -TEST WAS WITNESSED BY WSL & TP. 11:00 -13:30 2.50 WHSUR P DECOMP TWC -M /U DUTCH LOCK DOWN SYSTEM. -PU /MU & PRESSURE TEST LUBRICATOR. -TEST TO 500 PSI W/ DIESEL FOR 5 MINUTES - GOOD TEST. -PULL TWC. TBG AND IA ON VACUUM -LD LUBRICATOR AND DUTCH LOCK DOWN SYSTEM. 13:30 - 16:00 2.50 PULL P DECOMP PULL TBG HANGER. -FMC BACKED OUT LOCK DOWN SCREWS. - PULLED 2 -7/8" TUBING HANGER. -PULL OFF SEAT AT 42K WITH 44K PUW. -BREAK OUT LAY DOWN HANGER. 16:00 - 17:00 1.00 PULL P DECOMP R/U TO PULL ESP. FILL HOLE WITH 32 BBLS. - PUMPED TBG VOLUME. 3 BPM / 340 PSI. -R/U ESP CABLE TRUNK. STRING ROPE. -R/U FLOOR. 17:00 - 18:00 1.00 PULL P DECOMP PU LASALLE CLAMP BASKETS & THREAD PROTECTORS. -TIE INTO ESP CABLE. 18:00 - 18:30 0.50 PULL P DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. 18:30 -19:30 1.00 PULL P DECOMP PULL ESP CABLE OVER SHEAVE. - ATTACH CABLE TO SPOOLING UNIT. 19:30 - 00:00 4.50 PULL P DECOMP POH W/ 2 -7/8" ESP COMPLETION ASSEMBLY & CABLE -LD 2 -7/8' TBG. 11/8/2009 00:00 - 06:00 6.00 PULL P DECOMP CONTINUE TO POH. -POH W/ 2 -7/8" ESP COMPLETION ASSEMBLY & CABLE. -LD 2 -7/8' TBG. -TIGHT SPOT NOTED AT 320'. 06:00 - 08:00 2.00 PULL P DECOMP BREAK OUT AND LAY DOWN ESP BHA, - DETACH ESP CABLE FROM MOTOR. - CENTRILIFT DISASSEMBLED ESP BHA SECTION BY SECTION. - INSPECT EACH SECTION. - SPOOLED UP CABLE INTO CABLE SPOOLER. - RECOVERED 119 LASALLE CLAMPS, 4 PROTECTOLIZERS, - 2 FLAT GUARDS. 08:00 - 10:00 2.00 CLEAN P DECOMP R/U FLOOR TO P/U DP 10:00 -11:00 1.00 WHSUR P DECOMP INSTALL WEAR RING. 11:00 -11:30 0.50 CLEAN P DECOMP PJSM PU / MU BHA. 11:30 -13:30 2.00 CLEAN P DECOMP BHA # 1: - 3 -1/2" MULE SHOE, (1) 4 -3/4" DC, XO, 6.151 O.D. - SMOOTH STRING MILL, (4) BOOTBASKET, XO, - 4 -3/4" BUMPER SUB, 4 -3/4" OIL JARS, -(6) 4 -3/4" DC'S, = 261.03'. 13:30 - 15:00 1.50 CLEAN P DECOMP DRIFT 6.151" -WORK TIGHT SPOT AT 312' MD TO 342' MD WITH MULE Printed: 11/23/2009 9:43:55 AM BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From To Hours Task Code NPT Phase Description of Operations 11/8/2009 13:30 - 15:00 1.50 CLEAN P DECOMP SHOE. -WITH THE SMOOTH STRING MILL AT 279' MD TO 309' MD. -5K OVER PULL. -NO -GO WITH ALL AVAILABLE STRING WEIGHT, 10,000 #. - CONSULT WITH ADW RWO ENGINEERING. - DISCUSS PLAN FORWARD. 15:00 -16:00 1.00 CLEAN P DECOMP P/U TEST KELLY. -TEST UPPER AND LOWER VALVES. -250 PSI AND 3,500 PSI. -5 CHARTED MINUTES. 16:00 -19:00 3.00 CLEAN P DECOMP 2010 ASH HAND BOOK TRAINING FOR BOTH CREWS - SUNDAY SAFETY MEETING. 19:00 -19:30 0.50 CLEAN P DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. 19:30 - 00:00 4.50 CLEAN P DECOMP POH LD STRI MILL. - MU CSG SCRAPER. RIH PU DP 1 X 1. -TIGHT SPOT FROM 279' TO 509' MD, CSG SCRAPER DEPTH. - CONTINUE TO PU DP 1 X 1 TO 2,480' MD. 11/9/2009 00:00 - 00:30 0.50 CLEAN P DECOMP CONTINUE TO PU DP 1 X 1 TO 2,781' MD. 00:30 - 02:00 1.50 CLEAN P DECOMP CIRCULATE IN 175 BBL SAFE -LUBE PILL. - CAUGHT FLUID @ 1,060' MD (7 BBLS). 02:00 - 03:00 1.00 CLEAN P DECOMP POH W/ 3 -1/2" DP FROM 2,781' MD TO SURFACE. 03:00 - 04:00 1.00 CLEAN P DECOMP BREAK & LD MULE SHOE. -MU 6" BIT. -FILL HOLE WITH LUBRICATED SEAWATER. 04:00 - 06:00 2.00 CLEAN P DECOMP RIH OUT OF DERRICK. -VERY SLIGHT WT TAKEN @ =/- 300' MD. - CONTINUE TO RIH. 06:00 - 10:00 4.00 CLEAN P DECOMP CONTINUE TO PU DP 1 X 1 from 2,781' MD. -TO 6,002' MD. - PUMPED 55 BBLS SEAWATER. -WORK BOOT BASKETS. 10:00 -15:00 5.00 CLEAN P DECOMP POH F/ 6,002' MD. -L/D 50 JOINTS 3 1/2" DP. -POH STAND IN DERRICK. 15:00 - 16:30 1.50 CLEAN P DECOMP BO /LD BHA. -3 -5K OVER PULL THROUGH TIGHT SPOT. - 500 - -280' MD. - SERVICE (4) BOOT BASKETS. - RECOVERED (5) PIECES OF BRASS 3/4" TALL BY 1.5" LONG. +- 3/16" THICK. -1.5" LONG METAL BAND. 16:30 - 18:00 1.50 CLEAN P DECOMP CLEAN & CLEAR RIG FLOOR. -RD DP EQUIPMENT. RU TBG EQUIPMENT. 18:00 -18:30 0.50 CLEAN P DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. 18:30 - 19:30 1.00 CLEAN P DECOMP CONTINUE TO RU TO RUN 4 -1/2" TBG DUMMY RUN. 19:30 - 21:30 2.00 CLEAN P DECOMP PU & MU 6" BULL NOSE DUMMY RUN ASSEMBLY. -RUN 15 JTS OF 4 -1/2 ", L -80, HYDRIL 521 TBG. - UTILIZE "JET LUBE SEAL GUARD" THREAD COMPOUND. - MINIMUM MAKE UP TQ APLLIED @ 3,700 FT /LBS. - INSTALL CANNON CLAMPS ON JTS 1 & 2. -USE A 6' MOTOR CLAMP ON JT # 3. -USE CANNON CLAMPS ON JTS # 4 & 5. Printed: 11/2312009 9:43:55 AM 0 BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/9/2009 19:30 - 21:30 2.00 CLEAN P DECOMP -NOTED @ JT # 9 @ 360' MD IN 1 K DRAG. -1 K DRAG NOTED TO JT 3 15 @ 636' MD. 21:30 - 23:30 2.00 CLEAN P DECOMP MOVE TBG EQUIPMENT. -POH, LD 4 -1/2" TBG & BULL NOSE ASSEMBLY. -1 K DRAG NOTED ON THE WAY OUT FROM 636' TO 380' -POH TO SURFACE. - CANNON CLAMPS WERE SLID DOWN 8 -10" ON THE WAY OUT. -THE 6' CLAMP WAS PULLED DOWN 17' TO THE TOP OF THE NEXT CLAMP. - SLIGHT SCRATCHS ON CLAMPS & TBG INDICATE: -ALL CLAMP MOVEMENT WAS ON THE WAY OUT. 23:30 - 00:00 0.50 CLEAN P DECOMP CLEAN & CLEAR RIG FLOOR. 11/10/2009 00:00 - 04:30 4.50 CLEAN P DECOMP PJSM W/ SLB & PDS. -RU SLICK LINE W/ FULL PRESSURE CONTROL. 04:30 - 06:30 2.00 CLEAN P DECOMP RIH W/ SLB SLICKLINE - CALIPER RUN AT ASSET'S REQUEST. 06:30 - 08:30 2.00 CLEAN P DECOMP POH W/ SLB SLICKLINE. 08:30 - 10:00 1.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR -WAIT ON CALIPER INFORMATION. 10:00 - 12:00 2.00 CLEAN P DECOMP RD SLB SLICKLINE. -RU DUTCH SYSTEM RISER. 12:00 - 12:30 0.50 DHB P DECOMP PJSM W/ HES AND RIG CREW. -PU & MU 7" HES RBP. 12:30 - 17:00 4.50 DHB P DECOMP RIH W/ 7" HES RBP ON 3 1/2" DP FROM DERRICK. -SET RBP @ 4,992' MD COE. FN @ 4,988' MD. -SET W/ 15K DOWN WT. 2 LA TURNS. -FILL HOLE W/ 25 BBLS. - PRESSURE TEST RBP. TEST TO 1000 -PSI F/ ABOVE. -TEST FOR 10- CHARTED MINUTES. - PASS. 17:00 - 18:00 1.00 DHB P DECOMP STAND BACK 1 STD. -MU STORM PKR. SET @ 38' MD COE. FN @ 31' MD. -SET 55K DOWN WT. 18:00 - 18:30 0.50 DHB P DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. 18:30 - 19:00 0.50 DHB P DECOMP PRESSURE TEST STORM PKR F/ ABOVE TO 3500 PSI. -TEST FOR 30 CHARTED MINUTES. - PASS. 19:00 - 19:30 0.50 BOPSUF P DECOMP MU RUNNING TOOL. PULL WEAR RING. -LD SAME. BLOW DOWN LINES. 19:30 - 21:00 1.50 BOPSUF P DECOMP ND BOP'S. 21:00 - 23:00 2.00 WHSUR P RUNCMP NU NEW FMC 11" X 11" 5M TBG SPOOL WITH TC ATTACHMENT -TEST BREAK TO 3500 -PSI. -NU BOPE. 23:00 - 00:00 1.00 BOPSUF P RUNCMP RU & MU TEST EQUIPMENT. 11/11/2009 00:00 - 05:30 5.50 BOPSUF P DECOMP RU & TEST BOP S. -TEST BOPE PER BP & AOGCC REGULATIONS: BOP CONFIGURATION: - 13 -5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. - SPACER SPOOL. Printed: 11/23/2009 9:43:55 AM • i BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/11/2009 00:00 - 05:30 5.50 BOPSUF P DECOMP -2 7/8" X 5" VARIABLE BORE RAMS. -TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, - MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -USED 3 1/2" AND 4 1/2" TEST JOINTS ON RAMS & ANNULAR. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESS WAIVED BY JOHN CRISP AOGCC. -TEST WITNESSED BY WSL & TP. 200 PSI BUILD UP FROM 1700 PSI = 44 SECONDS. -FULL BUILD UP TO 3050 PSI = 166 SECONDS. -4 BOTTLES x 1550 PSI. 05:30 - 06:00 0.50 DHB P DECOMP PTSM - CREW CHANGE. - REVIEWED PULLING STORM PACKER AND RBP PROCEDURES. - REVIEWED PLAN FORWARD FOR NEXT 18 -HRS. 06:00 - 10:30 4.50 DHB P DECOMP RETRIEVE 7" HALCO STORM PACKER: -PUMU PACKER RETRIEVING TOOL ON 3 -1/2" DP JT. WITH CLOSED TIW VALVE. STING INTO 7" HALCO STORM PACKER WITH RETRIEVING TOOL AND RETRIEVE SAME. - ENCOUNTERED BLOCKAGE AT 5' ABOVE TOP OF PACKER. - HOOKED UP CIRCULATING HOSE AND WASHED SLUSH PLUG OFF TOP OF PACKER AND ENGAGED PACKER SUCCESSFULLY WITH RETRIEVING TOOL. - RELEASED STORM PACKER AND ALLOWED PACKER ELEMENTS TO RELAX FOR 10- MINUTES. -POH AND LAY DOWN 7" HALCO STORM PACKER. RELEASE 7" HALCO RBP: -RIH WITH ONE STAND 3 -1/2" DP FROM DERRICK. PU SINGLE JT. OF 3 -1/2" DP WITH CLOSED TIW VALVE. - ENGAGE RBP FISHING NECK AT 4988'. SET DOWN W /15K DOWNWEIGHT. - PICKED UP STRING AND RELEASED RBP. -RIH PAST PREVIOUS RBP SET DEPTH TO VERIFY RBP RELEASED. -CBU LOSING 30% RETURNS TO WELL. 10:30 - 14:30 4.00 DHB P DECOMP POH LAYING DOWN 3 -1/2" DP 1 X 1 THROUGH PIPE SHED. 14:30 -15:30 1.00 DHB P DECOMP BREAK OUT AND LAY DOWN HALCO 7" RBP THROUGH PIPE SHED. 15:30 - 16:30 1.00 RUNCOMP RUNCMP PJSM: - REVIEW CLEAR & CLEAN RIG FLOOR. - REVIEW RIGGING UP TO RUN COMPLETION TUBING & ASSEMBLY. 16:30 - 18:00 1.50 RUNCOMP RUNCMP RD DP LD HANDLING EQUIPMENT. -PU TBG HANDLING EQUIPMENT. MAINTAIN CONTINUOUS 20 -BPH SEAWATER INTO WELL. 18:00 - 18:30 0.50 RUNCOMP RUNCMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. 18:30 - 21:00 2.50 RUNCOMP RUNCMP RU TORQUE TURN EQUIPMENT TO RUN 4 -1/2" DP. 21:00 - 23:30 2.50 RUNCOhF RUNCMP PU & SERVICE MOTOR & SEAL ASSEMBLY. Printed: 11/2312009 9:43:55 AM BP EXPLORATION Page 6 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 11/11/2009 23:30 - 00:00 0.50 RUNCOMP RUNCMP PULL MLE OVER SHEAVE. 11/12/2009 00:00 - 00:30 0.50 RUNCOMP RUNCMP BRING CANNON CLAMPS UP TO RIG FLOOR. - CONTINUE TO FILL WELL WITH SEAWATER @ 20 BPH. 00:30 - 02:30 2.00 RUNCOMP RUNCMP PLUG MLE INTO MOTOR. INSTALL FLAT GUARD & PROTECTORS. 02:30 - 03:00 0.50 RUNCOMP RUNCMP TEST MOTOR LEAD EXTENSION. 03:00 - 08:30 5.50 RUNCOMP RUNCMP PU & RUN 4 -1/2" TBG WITH NABORS TORQUE TURN CSG SERVICES. -RUN 4-1/2",12.6#, L -80, HYDRIL 521TBG. - OPTIMUM TORQUE 4,700 FT /LBS. - UTILIZE "JET LUBE SEAL GUARD" THREAD COMPOUND. - INSTALL CANNON CLAMPS ON EVERY JT. -TEST CABLE EVERY 25 JTS. - CONTINUE TO FILL WELL WITH SEAWATER @ 20 BPH. - ENCOUNTERED A TIGHT SPOT @ - 304' MD. -BEGAN LOSING 2 -4K LBS -15' IN ON JT #7, -304' MD. -LOST STRING WT. -20' IN ON JT. #7,309 MD. - WORKED STRING UP & DOWN 5 TIMES, ABOUT 20' STROKE. -MADE ABOUT 5' OF PROGRESS. -HELD A SHORT DISCUSSION WITH CENTRILIFT HAND. - ROTATED STRING -15 DEG TO EACH SIDE. - REGAINED ALL OF STRING WT -30' IN ON JT #7,-320 MD. RIH WITH JT #8 AND TEST CABLE CONDUCTIVITY. -GOOD TEST. RIH TO JT #15 AND TEST CABLE CONDUCTIVITY. -GOOD TEST. - CONTINUE TO RIH. RIH TO JT #51 AND TEST CABLE CONDUCTIVITY. -GOOD TEST. 08:30 - 09:30 1.00 RUNCOMP RUNCMP PUMU 11" FMC TUBING HANGER ON 3 -1/2" DP LANDING JT. WITH CLOSED TIW VALVE AND MAKEUP TO 4 -1/2" TUBING. - CENTRILIFT CUT ESP CABLE V BELOW TUBING HANGER AND ATTACHED TO TUBING WITH CROSS COUPLING CANNON ESP CABLE CLAMP. -FMC PREPARED TUBING HANGER FOR LANDING. - LANDED TUBING HANGER AND RILDS. -P /U WT. = 31 K, S/O WT. = 26K - CONTINUE TO FILL WELL WITH SEAWATER @ 20 BPH. 09:30 - 10:00 0.50 RUNCOMP RUNCMP PJSM - ALL CREW: RIGGING UP SLICKLINE AND DUTCH SYSTEM. 10:00 - 15:00 5.00 RUNCOMP RUNCMP RIG UP DUTCH SYSTEM AND SLICKLINE WITH FULL PRESSURE CONTROL. -RIG UP DUTCH SYSTEM TO TOP OF ANNULAR PREVENTER. -PICK UP SLICKLINE TOOLS AND EQUIPMENT TO RIG Printed: 11/2312009 9:43:55 AM BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/12/2009 10:00 - 15:00 5.00 RUNCO RUNCMP FLOOR. -RIG UP SLICKLINE LUBRICATOR TO DUTCH SYSTEM. - PRESSURE TEST LUBRICATOR AGAINST CLOSED BLIND RAMS TO 500 -PSI. - PREPARE TO PICK UP ESP PUMP AND RIH ON SLICKLINE. 15:00 -18:00 3.00 RUNCOMP RUNCMP PU AND RIH WITH WIRELINE DEPLOYED ESP EQUIPMENT. CONTINUE TO RUN #1: RIH WITH: -PUMP EYE FLANGE, GAS SEPARATOR, PUMP DISCHARGE HEAD - AND HANGER RECEPTACLE TO 2,146' MD. -TIGHT @ 270' MD. WORK UP. PUMP 10 BBLS SEAWATER & SAFE -LUBE. -RIH TIGHT @ 276' MD. PUMP 1 BBL W/ SEAWATER & SAFE -LUBE TO PUSH ESP THROUGH TIGHT SPOT. -FILL IA WITH SEAWATER & SAFE -LUBE. -SET DOWN INTO PUMP EYE AND JAR RUNNING TOOL OFF ASSEMBLY. -SET PUMP IN XO. POH WITH RUNNING TOOLS. 18:00 - 22:00 4.00 RUNCOMP RUNCMP RUN # 2: RIH WITH: -PU STINGER. RIH W/ PACK OFF ASSEMBLY. -SET PACK OFF @ 2,146' MD. POH. RUN # 3: -RIH WITH PRESSURE TEST TOOL. SET TOOL @ 2,146' MD. -TEST TO 1,000 PSI / 15 MINUTES - PASS. -POH W/ PRESSURE TEST TOOL. RUN # 4: -RIH W/ TBG STOP ON RUNNING TOOL. SET @ 2,138' MD. -POH W/ RUNNING TOOL. 22 :00 - 00:00 2.00 RUNCOMP RUNCMP RD SLB SLICK LINE. 11/13/2009 00:00 - 00:30 0.50 RUNCOMP RUNCMP RD DUTCH SYSTEM. 00:30 - 01:30 1.00 RUNCOMP RUNCMP PU LANDING JT. MU LANDING JT INTO HANGER. - BOLDS. UNSEAT HANGER @ 32K. -PULL HANGER TO FLOOR @ 32K. -LD HANGER & LANDING JT 01:30 - 07:00 5.50 RUNCOMP RUNCMP CENTRILIFT MAKE FLAT CABLE TO FLAT CABLE SPLICE ON RIG FLOOR. 07:00 - 16:00 9.00 RUNCOMP RUNCMP CONTINUE RIH WITH 4 -1/2" ESP COMPLETION. - INSTALL CANNON MID -JOINT CABLE CLAMP ACROSS CABLE SPLICE. - PICKING UP 4 -1/2 ", 12.6 #, L -80 HYDRIL 521 TUBING 1 X 1 FROM PIPE SHED. - INSTALLING CANNON CROSS COUPLING CABLE CLAMPS ON EVERY TUBING COUPLING. - TORQUE TURNING EACH TUBING CONNECTION TO 4700 FT -LBS. OPTIMUM TORQUE AND USING JET LUBE SEAL GUARD THREAD COMPOUND. Printed: 11/2312009 9:43:55 AM BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: MPH -13 Common Well Name: MPH -13 Spud Date: Event Name: WORKOVER Start: 10/30/2009 End: 11/14/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/14/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/13/2009 07:00 - 16:00 9.00 RUN= RUNCMP - FILLING TUBING WITH 20 -BPH OF SEAWATER CONTAINING 0.6% BY VOLUME OF MI SAFE -LUBE. -BAD MAKEUP ON JT. #104. REPLACED WITH JT4155 WITH SAME LENGTH. -RAN: 2 FLAT GUARDS, 3- PROTECTOLIZERS, - 3 -(5') CANNON CLAMPS, 147- (2') CANNON CLAMPS. 16:00 - 17:30 1.50 RUNCO RUNCMP PUMU 4 -1/2" LANDING LANDING JT. WITH CLOSED TIW VALVE AND CIRCULATING HOSE CONNECTED AND MAKEUP TO FMC 11" TUBING HANGER AND COMPLETION TUBING. 17:30 - 21:00 3.50 RUNCOMP RUNCMP CENTRILIFT SPLICE: -LOWER WELLHEAD CONNECTOR PIGTAIL TO ESP CABLE. -TEST SPLICE. PLUG INTO CONNECTOR AND RETEST SPLICE. -GOOD. -LAND HANGER 79K PUW. 43K SOW. - RILDS. 21:00 - 22:00 1.00 RUNCOMP RUNCMP RD TORQUE TURN EQUIPMENT. 22:00 - 23:00 1.00 RUNCOMP RUNCMP SET TWC. TEST TWC FROM ABOVE TO 3500 PSI. -TEST FOR 10 CHARTED MINUTES. -PASS 23:00 - 00:00 1.00 RUNCOhF RUNCMP ND BOP'S & DOUBLE STUD ADAPTER. 11/14/2009 00:00 - 02:00 2.00 RUNCOhF RUNCMP NU TREE & ADAPTER. -CLEAN & CLEAR RIG FLOOR. -CLEAN & CLEAR CELLAR. 02:00 - 03:30 1.50 RUNCOMP RUNCMP TEST TBG HANGER VOID & SEAL TO 5000 PSI FOR 30 MINUTES. -PASS. -BODY TEST TREE TO 5000 PSI FOR 5 CHARTED MINUTES. -PASS. - PERFORM FINAL ESP CHECK CHECK. 03:30 - 04:30 1.00 RUNCOMP RUNCMP PU LUBRICATOR. PRESSURE TEST LUBRICATOR TO 500 PSI. -PASS. -PULL TWC. SET BPV. 04:30 - 06:00 1.50 RUNCOMP RUNCMP SECURE TREE AND CELLAR -RD LINES TO PITS. -AFTER ACTION REVIEW OF MPH -13 RWO WITH FULL RIG CREW. RELEASE RIG @ 06:00 HRS. Printed: 11/2312009 9:43:55 AM ` Tree Cameron 4 1/16" 5M MPH -13a Orig. DF E1W 66.0' (N 22E) Wellhead: 11" x 11" 5M FMC Gen 6, Orig. GL Elev. = 36.7' w/ 11" x 4 1/2" FMC Tbg Hgr 4 1/2" Orig. DF to csg. hgr. = 30.62' (N 22E 521 Hydril T &B, 4" H BPV profile 20" 91.1 ppf, H -40 112' Howco 9 5/8" "ES" Cementer 2113' and KOP @ 400' Hole angle = < 71 to 6000' Hole angle @ TTC -ESP = 75 9 5/8 40 ppf, L -80, BTC mod prod. csg. ( drift ID = 8.835 ", cap. = 0.0758 bpf ) D &D Tbg Stop 6,140` 6,142' Window cut in 9 -5/8" (3,880' - 3,910') D &D Packoff Assy Top Centrilift TTC -ESP Top 6,151' i� TTC Drilled Tbg Crossover 6,159` 4 112" 12.6 ppf, L -80, 521 Hydril Tubin Drift ID = 3.833 ", cap = 0.0152 Tandem Seal Sections 7" 26 ppf, L -80, BTC -Mod Casing Model GSB3 DB UT /LT HL H6 PFS 6,169' (Drift ID = 6.151 ", cap = 0.0383 bpf) (Cap w/ 4 1/2" tbg inside = 0.0186 bpf) Motor, 55 HP, 1259 volt, 26 amp, Model KMHA 6,183' PumpMate w/ 4 fin Centralizer 6,192' I PumpMate = 3925' TVD Tx 4.5" Baker SC -1 R Packer (70 -40) 6,642' 7" float collar 6,638` 4.5" Baker CMD Sliding Sleeve 6,688` 7" float shoe 6,724' 6 1/8" Hole td @ 9,142' N -Sand Horizontal Baker GPV 5" Guide Shoe 37' joints 4" Screen C27 Baker Med. g 142 Excluder 2000 / W/ 37'4" Blank & 5.75" OD Centralizer alternating 6,692'- 9,139' DATE REV. BY COMMENTS 10/22/97 MDO Drilled and Cased Nabors 22 -e MILNE POINT UNIT 07/25/02 Lee Hulme Decomplete for Side Track Nabors 4ES WELL No: MPH -13a 09/12/02 MDO Sidetrack & ESP Completion Doyon - 141 API : 50 -029- 22818 -01 12/8/04 Lee Hulme ESP Changeout - Nabors 4ES 1 1/1 4/09 Lee Hulme Convert to TTC -ESP - Nabors 4ES BP EXPLORATION (AK) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _In.serts\Microfilm _ Marker.doc ccelVE JAN 0 6 200~ " STATE OF ALASKA .~ ALASKA ~)L AND GAS CONSERVATION COh.¡~ISSION REPORT OF SUNDRY WELL OPERATIONS . Alaska Oil & G!;"",L.. Change O~i¡tMW¡<i;ì~>b iii Other 0 Time Extension 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 64.20' iii Repair Well 0 Plug Perforations 0 Stimulate iii Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 8. Property Designation: ADL 025518 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9142 4109 9142 4109 Casing Structural Conductor Surface Intermediate Production Liner Length 80' 3849' 6697' 2500' Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: iii Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 202-167 6. API Number: 50-029-22818-01-00 9. Well Name and Number: MPH.13A 10. Field / Pool(s): Milne Point Unit / Schrader Bluff feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 9-5/8" 3880' 2908' 5750 3090 7" 6724' 4014' 7240 5410 4" 6642' - 9142' 4002' - 4109' SCANNED ~JAN 11 2005 Gravel Screen Assembly 6682' - 9137' Gravel Screen Assembly 4008' - 4109' 2-7/8" L-80, 6.5# 6562' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker SC-1 R Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): 6642' Treatment description including volumes used and final pressure: RBDMS BFl .IAN () 7 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure 23 1172 408 931 15. Well Class after proposed work: 0 Exploratory iii Development 0 Service 16. Well Status after proposed work: iii Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 13. Tubinq Pressure Oil-Bbl Prior to well operation: 235 Subsequent to operation: 663 14. Attachments: 0 Copies of Logs and Surveys run iii Daily Report of Well Operations iii Well Schematic Diagram Printed Name Sondra Stewman ~ Form 1 U-404 Revised 04/2004 Title Technical Assistant Ph"" R. \ 66't-ktt5t ^ L Date ot ~ ()5~{)~~~:r~t:~~~~~~~~~~750 LJ . \J ¡ I \! Submit Ongrnal Only Tree: Cameron 2 9/16" , .) Wellhead: 11" X 11" 5M FI\tI~ Gen 6, wI 11" X 2 7/8" FMC tbg. hng., 2 7/8" EUE NSCT T&B, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 I 112' I Howco 9 5/8" "ES" Cementer 2113' mdo KOP @ 400' Max. hole angle == 68 to 40 deg. fl 3100' - 4900' Hole angle thru' perfs == 39 deg. 9 5/840 ppf, L-80, BTC mod prod. csg. ( drift 10 == 8.835", cap. == 0.0758 bpf ) Window cut in 9-5/8" ( 3,880' - 3,910' ) 2 7/8" 6.5 ppf, L-80, EUE-8rd Tubing Orift 10 == 2.347", cap == 0.0058 7" 26 ppf, L-80, BTRC-Mod Casing (Orift 10 == 6.151", cap == 0.0383 bpf) (Cap wI 2 7/8" tbg inside == 0.0302 bpf) 7" float collar I 6,638' I T' float shoe I 6,724' I ~ MPH-13a Orig. ):Iev. == 66.0' (N 22E) Orig. GL Elev. == 36.7' Orig. OF to csg. hgr. == 30.62' (N 22E ~ Cameo 2-7/8" x 1" side pocket KBMM GLM Cameo 2-7/8" x 1" sidepoeket KBMM GLM Camco 2-7/8" x 1" sidepocket KBMM GLM HES 2.313" 'XN' Nipple (2.250 No-go ID) ESP Single Pump 122 Stg. GC2200 Model GPMT AR 1: 1 Bolt-on Intake GPINTXAR Intake = 3972' TVD Tandem Seal Section Model GSB3 DB L T AB/HSN FSA Motor, 133 HP, 2205 volt, 37 amp, Model KMH PumpMate w/6 fin Centralizer (6.25' long) PumpMate = 3990' TVD N-Sand Horizontal 37' joints 4" Screen C27 Baker Med. Excluder 2000 I W/37' 4" Blank & 5.75" od. Centralizer alternating I 6,692' - 9,139' I 7' x 4.5" Baker SC-1 R Packer (70-40) I 6,642' I 4.5" Baker CMD Sliding Sleeve I 6,688' I ~ I 166' I I 2,509' I I 5,948' I I 6,465' I I 6,508' I 16,529' I I 6,530' I I 6,544' I I 6,557' I 6 1/8" Hole td @ 9,142' /1 "J Baker GPV 5" Guide Shoe I 9,142' I DATE REV. BY COMMENTS MILNE POINT UNIT 10/22/97 MDO Drilled and Cased Nabors 22-e WELL No : MPH-13a 07/25/02 Lee Hulme Decomplete for Side Track Nabors 4ES API: 50-029-22818-01 09/12/02 MDO Sidetrack & ESP Completion Doyon -141 12/8104 Lee Hulme ESP Changeout - Nabors 4ES BP EXPLORATION (AK) ') ) BP EXPLORATION Operatiohs"SQl11rnätYR.~P9rt Page 1 of 1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-13 MPH-13 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours Task I Code NPT Phase 12/7/2004 PRE PRE PRE 00:00 - 02:00 2.00 MOB P 02:00 - 04:30 2.50 MOB P 04:30 - 07:00 2.50 RIGU P 07:00 - 08:30 1.50 RIGU P 08:30 - 09:30 1.00 WHSUR P 09:30 - 10:30 1.00 KILL P 10:30 - 13:00 2.50 KILL P DECOMP DECOMP DECOMP DECOMP 13:00 - 14:00 1.00 KILL P I 14:00 - 14:30 0.50 WHSUR' P 14:30 - 15:30 1.00 WHSUR P 15:30 - 18:00 2.50 BOPSUR P 18:00 - 21 :30 3.50 BOPSUP. P 21 :30 - 22:30 1.00 WHSUR P 22:30 - 23:00 0.50 WHSUR P 23:00 - 00:00 1.00 PULL P 12/8/2004 00:00 - 03:00 3.00 PULL P 03:00 - 06:00 3.00 PULL P 06:00 - 07:30 1.50 RUNCOMP 07:30 - 10:30 3.00 RUNCOMP 10:30 - 15:00 4.50 RUNCOMP 15:00 - 15:30 0.50 RUNCOrvP 15:30 - 17:30 2.00 RUNCOMP 17:30 - 18:00 0.50 WHSUR P 18:00 - 19:00 1.00 BOPSUR P 19:00 - 20:00 1.00 WHSUR P 20:00 - 20:30 0.50 WHSUR P 20:30 - 21 :00 0.50 RUNCOtvP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Start: 12n /2004 Rig Release: 12/8/2004 Rig Number: Spud Date: End: 12/8/2004 Description of Operations Rig downfrom MPG-03i. Lower & scope down derrick. Move rig from MPG-03i to MPh-13. Distance approx. 1 mile. Spot in & rig up on MPH-13. Raise & scope up derrick. R/U lines from pits to rig sub. ACCEPTED RIG @ 0700 hrs. R/U lines to tiger tank & X-mas tree. Take on seawater. P/U lubricator & pull TWC. UD lubricator. Con't to take on seawater. Hold PJSM & Pre-spud meeting wi all hands. Test lines to 3500 psi, OK. Open well SITP = 480 psi, SICP 480 psi. Circulate & kill well. Pumped 2 BPM @ 300 psi. Bullheaded 65 bbls into well. Con't to pump 4 BPM @ 300 psi. Monitor well. Well still gassy. Bullhead 50 bbls down annulus, 4 BPM @ 100 psi. Monitor well, well on vacuum. Set TWC & test to 3500 psi. Blow down & rig down lines to tree. Bleed off tbg void & N/D X-mas tree. N/U BOPE. R/U test equip. Test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Chuck Sheve wI AOGCC. Blow down lines. Drain BOP stack. M/U lubricator & pull TWC. UD lubricator. M/U landing jt. Pull hanger to floor. P/U wt = 60 K. Check ESP cable. UD hanger. POOH & stand back 2 7/8" completion. POOH & stand back 27/8" completion. Stood back 66 stands. Recovered 3 Flat Guards, 6 Protectolizers & 125 LaSalle Clamps. Test, inspect & UD ESP. Clear Iclean rig floor. PJSM. Pick up & service ESP assembly. PJSM. RIH wi ESP assembly on 27/8" EUE 8 rnd tbg. checking conductivity of cable and breaking circulation @ 2 bpm I 100 psi every 2000'. PJSM. Make up headpin & landing joint. Install penetrator. Make field connection. Plug into penetrator & test connection. Land hanger. P/U 44K, SIO 29K. RILDS. Set & test TWC. N/D BOPE. N/U X-mas tree. Pressure test tree & void to 5000 psi, OK. Made final check on ESP cable. Secure well. Clean cellar. RELEASE RIG @ 2100 hrs. Printed: 12/14/2004 8:22:15 AM 13 tJ ck' À;~~ DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021670 Well Name/No. MILNE PT UNIT SB H-13A MD 9142-../ --------~_._-_.~ ---->-~.---------------- TVD 41 09 ~ Completion Date 9/13/2002 ~ REQUIRED INFORMATION Mud Log No ---- DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, lAW, PWD Well Log Information: Log/ Data Digital Type / Med/Frmt ~ ~ vE6 0 ~D ~.D reo C Asc )=0 C Pdf L,./ -ED C Pdf Electr Dataset Number Name ~ctionilÌ~suïVey ... As Verification U;rectional Survey [Directional Survey ~()llal.SLJfvey {1X337 r ~ 1957 1:957 1'1957 LIS Verification LIS Verification Induction/Resistivity Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Samples No Log Log Run Scale Media No 1 1 25 25 Sent 1,2,3 Final Final Received Current Status 1-OIL f/ßLcL ) Jti¡f-- ~}i ( API No. 50-029-22818-01-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) ,,-,' Interval OH / Start Stop CH Received Comments 3814 9142 Open 10/2/2002 MWD 3878 9088 ~6/2002 3814 9142 Open 10/2/2002 3814 9142 Open 10/2/2002 3814 9142 Open 10/2/2002 3878 9088 Case 12/6/2002 3877 9142 Open 6/2/2003 3880 9142 Open 6/2/2003 3880 4109 Open 6/2/2003 Sample Set Number Comments A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 8/12/2002. MWD MWD - Rap, DGR, EWR- MD MWD - DGR, EWR - TVD , ""-'/ Permit to Drill 2021670 MD 9142 TVD 4109 ADDITIONAL INFORMATION y~ Well Cored? Chips Received? --y-.¡ N -VI N Analysis Received? -------------~ Comments: ---~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Well Name/No. MILNE PT UNIT SB H-13A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22818-01-00 Completion Date 9/13/2002 Completion Status 1-01L UIC N Current Status 1-01L ~/N Daily History Received? ly) Formation Tops ŒY ~' ~.-t Date: ¡V¡ ð>t-~ Y ,--. ) ",dOd-! (0'9- ~!951 WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 14,2003 RE: MWD Formation Evaluation Logs: MPH-13A, AK-MW-22149 MPH-13A: Digital Log Images: 50-029- 22818-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATIACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Datj:UN 0 2 2003 Ala.! OK & Gas Coos. Cörr~ Anchorege :':J.- c' ó1 - l (c -, Sign~l,,~~~ ~~~,\¡\~ ;;<Òd.-/07 ( 1331 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I December 04, 2002 RE: MWD Formation Evaluation Logs MPH-13A, AK-MW-22149 1 LIS formatted Disc with verification listing. API#: 50-029-22818-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~'iJ}¡¡g¡Q<~ I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well ŒI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L~~~g~~~L~~I~~~ ~~~~~EC. 34, T13N, R10E, UM r'Ò¡:¡::;'\:~t.:fj¡)¡~'l At top of productive interval 1..9- /'di;;.~ 4009' NSL, 447' WEL, SEC. 34, T13N, R10E, UM ~ Vf4!.g¡FL:D i At total depth ¡ ~ 540' NSL, 4070' WEL, SEC. 26, T13N, R10E, UM L::;,::~:J 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 64.2' ADL 025518 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 9-3-2002 / 9-9-2002 . 9/13/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9142 4109 FT 9142 4109 FT ŒI Yes 0 No 22. Type Electric or Other Logs Run MWD , DIR , GR , RES, lAB, PWD Classification of Service Well 7. Permit Number 202-167 8. API Number 50- 029-22818-01 9. Unit or Lease Name Milne Point Unit 10. Well Number MPH-13A 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) 1/4J~Û> .3f?ð '/hb Z ~ D<6I'TÝð 23. CASING SIZE 20" 9-5/8" WT. PER FT. 91.1# 40# 26# 9.5# GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 321 112' 24" 250 sx Arcticset I (Approx.) 31' 3880' 12-1/4' 1948 sx PF lE', 278 sx 'GI, 200 sx PF IC 271 6724' 8-1/2" 230 sx Class IGI 6642' 9142' 6-1/8" Gravel Pack Screen Assembly AMOUNT PULLED 7" 4" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25. 4" Gravel Pack Screen Assembly SIZE 2-7/8",6.5#, L-80 TUBING RECORD DEPTH SET (MD) 65811 PACKER SET (MD) NIA MD TVD MD TVD 6682' - 9137' 4008' - 4109' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 60 Bbls of Diesel. 27. Date First Production September 23, 2002 Date of Test Hours Tested 9/26/2002 6 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 1189 OIL-BBL GAs-McF 54 GAs-McF WATER-BBL 625 WATER-BBL CHOKE SIZE GAS-OIL RATIO 46 CALCULATED 24-HoUR RATE OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit Tm1 IVED OCT 1 5 2002 No core samples were taken. Form 10-407 Rev. 07-01-80 ORt ' 'GINA/ RBDMS BFl OCT 21 2002 AlasKa on& Gas Cons. Commission Anchorage e ç; Submit I n Duplicate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. SBF2-NA 6400' 3966' SBF1.NB 6667' 4006' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys and Leak-Off Test Summary. 32. I hereby certify that th Signed ~w;"'n MPH-13A Well Number regoing is true ~nd correct to the best of my knowledge Title Technical Assistant Date \b. \J4 -D~ 202-167 Permit No. I Approval No. Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Steve Campbell, 564-4401 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate fonn for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) BP EXPLORATION Operations Summary Report Page 1 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-13A MPH-13A DRILL +COMPLETE DOYON DOYON 141 Start: 9/2/2002 Rig Release: 9/13/2002 Rig Number: 141 Spud Date: 9/4/2002 End: 9/13/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/2/2002 00:00 - 13:30 13.50 RIGU P PRE MOVE RIG FROM MPI-15, AND RIG UP 13:30 - 16:30 3.00 WHSUR P INT1 NIPPLE DOWN TREE, AND PULL HANGER REMOVE FMC GEN 6 CSG HEAD 16:30 - 17:30 1.00 WHSUR P INT1 INSTALL FMC, GEN 5 CSG HEAD AND TUBING HEAD, TEST TO 1000 PSI 17:30 - 20:00 2.50 BOPSUR P INT1 NIPPLE UP BOPS, 20:00 - 00:00 4.00 BOPSUR P INT1 INSTALL TEST PLUG, TEST BOPS 250-3500 PSI FOR 5 MIN ANNULAR 250-3500 ALL VALVES 250-3500 FOR 5 MIN WITNESS OF BOP TEST WAS WAIVED BY JEFF JONES AOGCC 9/3/2002 00:00 - 00:30 0.50 BOPSUR P INT1 INSTALL WEAR RING 00:30 - 02:30 2.00 DRILL P INT1 PICKING UP BIT ,BIT SUB,8 3/4 MILL,S" DRILL PIPE TO 2260' 02:30 - 03:00 0.50 DRILL P INT1 DISPLACE DIESEL OUT OF WELL, WITH WATER 03:00 - 04:30 1.50 DRILL P INT1 PICKING UP 5' S-135 19# PIPE TO 3904' 04:30 - 05:30 1.00 DRILL P INT1 DISPLACE WELL WITH MUD 05:30 - 06:00 0.50 DRILL P INT1 TEST CSG TO 3000 PSI FOR 1/2 HR 06:00 - 08:00 2.00 DRILL P INT1 PUMP DRY JOB - POOH 08:00 - 09:30 1.50 STWHIP P INT1 MAKE UP BAKER WHIPSTOCK ASSEMBLY - PICK UP MWD - UPLOAD MWD 09:30 - 12:30 3.00 STWHIP P INT1 CON'T MAKE UP BHA - RIH TO 3843' 12:30 - 13:00 0.50 STWHIP P INT1 ORIENT BAKER WHIPSTOCK TO 43 DEGREE TO LEFT OF HIGH SIDE - SET ANCHOR WITH 25K DOWN - PU 5K TO CHECK ANCHOR - SHEAR MILL OFF SLIDE 13:00 -18:30 5.50 STWHIP P INT1 MILLING WINDOW FROM 3880' TO 3910' - TOP WINDOW 3880' - BOTTOM WINDOW 3896' - WOM 3K TO 10K - RPM 100 to 110 - TQ 5K TO 15K - GPM 375 - PP 800 - PU 125K- SO 70K - ROT 94K 18:30 - 20:00 1.50 STWHIP P INT1 CIRCULATE HOLE CLEAN - CONDITION MUD 20:00 - 20:30 0.50 STWHIP P INT1 PREFORM FIT - DEPTH 3880' MD 2908 TVD - MUD WEIGHT 8.7# - SURFACE PRESSURE 380 PSI - EMW 11.21# 20:30 - 21 :30 1.00 STWHIP P INT1 OBSERVE WELL - PUMP DRY JOB - POOH 21 :30 - 00:00 2.50 STWHIP P INT1 STAND BACK HWDP - LAY DOWN DC'S - HWDP - MILLS 9/4/2002 00:00 - 00:30 0.50 BOPSUR P INT1 FLUSH BOP'S 00:30 - 02:30 2.00 DRILL P INT1 MAKE UP DRILLING ASSEMBLY - UP LOAD MWD 02:30 - 04:30 2.00 DRILL P INT1 CON'T MU BHA - SINGLE IN 78 JOINTS OF 5" DRILL PIPE TO 3150' 04:30 - 05:00 0.50 DRILL P INT1 RIH FROM 3150' TO 3815' 05:00 - 05:30 0.50 DRILL P INT1 ORIENT MTR - SLIDE THROUGH WINDOW - NO PROBLEMS 05:30 - 00:00 18.50 DRILL P INT1 DIRECTIONAL DRILL FROM 3910' TO 5590' - WOB 20K TO 35K - RPM 120 - TQ ON BTM 8K - OFF BTM 6K - GPM 410- PP ON BTM 2000 - OFF BTM 1750 - PU 115 - SO 90 - ROT 100 9/5/2002 00:00 - 10:00 10.00 DRILL P INT1 DIRECTIONAL DRILL FROM 5590' TO 6724' T.D. 8.5" HOLE - MUD GAS CUT TO 8.2 FROM 9.5+ @ 5870' - MUD GAS / OIL CUT TO 7.8 FROM 9.5 @ 5928' - RAISE MUD WEIGHT TO 9.7 - LOTS OIL OVER SHAKERS - WOB 20K TO 30K - RPM 120 - TQ ON BTM11K - OFF BTM 7K - GPM 410 - PP ON BTM 2000 - OFF BTM 1700 - PU 145K - SO 86K - ROT 106K 6245' MUD CUT TO 9.4 FROM 9.7 - 6250' MUD CUT TO 8.9+ FROM 9.7 10:00 - 12:00 2.00 CASE P INT1 CIRCULATE 3 X - RPM 120 - GPM 425 - PP 1750 Printed: 9/25/2002 4:10:16 PM ') ) BP EXPLORATION Operations Summary Report Page 2 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-13A MPH-13A DRILL +COMPLETE DOYON DOYON 141 Start: 9/2/2002 Rig Release: 9/13/2002 Rig Number: 141 Spud Date: 9/4/2002 End: 9/13/2002 Date From - To Hours Task Code NPT - Phase Description of Operations 9/5/2002 12:00 - 14:30 2.50 CASE P INT1 PUMP OUT TO 3907' - PULL THROUGH WINDOW TO 3815' WITHOUT PUMP - GPM 400 14:30 - 15:00 0.50 CASE P INT1 OBSERVE WELL - WELL STATIC - TOP DRIVE SERVICE 15:00- 16:00 1.00 CASE P INT1 RIH TO 6624' - PRECAUCTIONARY WASH AND REAM FROM 6624' TO 6724' 16:00 - 18:30 2.50 CASE P INT1 CIRCULATE 4 X BOTTOMS UP - 400 GPM - PP 1750 - RPM 120 - TQ 7K (15000 STKS) - NO GAS CUT MUD ON BTMS UP 18:30 - 20:00 1.50 CASE P INT1 OBSERVE WELL - WELL STATIC - POH TO 3815' 20:00 - 22:00 2.00 CASE P INT1 OBSERVE WELL - WELL STATIC - LAY DOWN 5" DP - 99 JOINTS 22:00 - 00:00 2.00 CASE P INT1 LAY DOWN BHA - HWDP - JARS - STABILIZERS - FLEX DC'S - DOWN LOAD MWD 9/6/2002 00:00 - 00:30 0.50 CASE P INT1 CON'T LAY DOWN BHA - MWD - MOTOR 00:30 - 01 :00 0.50 CASE P INT1 CLEAR FLOOR - PULL WEAR RING 01 :00 - 02:30 1.50 CASE P INT1 CHANGE TOP RAMS TO 7" - TEST DOOR SEALS TO 2500 PSI 02:30 - 04:00 1.50 CASE N SFAL INT1 TEST PLUG STUCK IN WELL HEAD WITH CUTTINGS / SMALL PIECES OF METAL - WORK LOOSE WITH 105K 04:00 - 05:00 1.00 CASE P INT1 RIG UP CASING EQUIPMENT TO RUN 7" CASING - PJSM ON RUNNING CASING 05:00 - 09:00 4.00 CASE P INT1 RUN 7" CASING TO 3800' 09:00 - 10:00 1.00 CASE P INT1 CIRCULATE CASING VOLUME 2400 STKS - 217 GPM - 380 PSI 10:00 -12:30 2.50 CASE P INT1 CON'T RIN 7" CASING TO 6683' - BREAK CIRCULATION @ 2 BPM - WASH TO BTM 6724' 12:30 - 13:00 0.50 CASE P INT1 CIRCULATE WITH FRANKS TOOL @ 5 BPM - 500 PSI 13:00 - 13:30 0.50 CASE P INT1 RIG DOWN FRANKS TOOL - RIG UP HOWCO CEMENTING HEAD 13:30 - 15:00 1.50 CASE P INT1 CIRCULATE 2 HOLE VOLUMES - CONDITIONING MUD FOR CEMENT OF 7" CASING - 210 GPM - PP 500 RECIPROCATE CASING WHILE CIRCULATING - 30' CYCLE - PU 160K - SO 80K 15:00 - 16:30 1.50 CASE P INT1 CEMENT 7" CASING - PUMP 5 BBLS WATER - TEST LINES TO 3500 PSI- PUMP 5 BBLS WATER - MIX AND PUMP 30 BBLS ALPHA SPACER AT 10.2 # - DROP BOTTOM PLUG- MIX AND PUMP 230 SXS CLASS G CEMENT - WITH 1 % CACL + .3% HALAD 344 + .2% CFR 3 - YIELD 1.15 SX - 47 BBLS OF SLURRY MIXED @ 15.8 PPG - DROP PLUG - DISPLACE WITH 30 BBLS WATER THRU TUB - 224.5 BBLS MUD - PUMPING RATE 5 TO 5.5 BBLS MIN - BUMP PLUG WITH 1600 PSI 1000 PSI OVER PUMPING RATE - HOLD FOR 5 MINS - BLEED OFF PRESSURE - FLOATS HELD- CIP @ 16:30 HRS - RECIPROCATED PIPE THROUGH OUT CEMENT JOB 16:30 - 18:00 1.50 CASE P INT1 LAY DOWN CEMENT HEAD - PICK UP BOP STACK W / TUBING HEAD - SET EMERGENCE SLIPS WITH 165K DOWN WEIGHT 18:00 - 20:30 2.50 CASE P INT1 CUT OFF 7" CASING - DRESS CASING -INSTALL PACK OFF - TEST TO 3786 PSI FOR 10 MINS - TEST GOOD - NIPPLE UP STACK 20:30 - 22:30 2.00 CASE P INT1 CHANGE OUT TOP AND BOTTOM RAMS TO 3.5" - CHANGE OUT SAVOR SUB - GRABBERS / GUIDE ON TOP DRIVE Prìnted: 9/25/2002 4:10:16 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/6/2002 9/7/2002 9/8/2002 9/9/2002 Date ) ) BP EXPLORATION Operations Summary Report MPH-13A MPH-13A DRILL +COMPLETE DOYON DOYON 141 Page 30f6 Start: 9/2/2002 Rig Release: 9/13/2002 Rig Number: 141 Spud Date: 9/4/2002 End: 9/13/2002 22:30 - 00:00 From - To Hours Task Code NPT Phase Description of Operations 00:00 - 01 :30 01 :30 - 02:00 02:00 - 05:00 05:00 - 05:30 05:30 - 07:30 07:30 - 09:30 09:30 - 10:00 10:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 18:30 18:30 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 00:00 00:00 - 00:00 00:00 - 03:30 03:30 - 07:30 07:30 - 10:00 10:00 -11 :00 11 :00 - 12:30 12:30 - 14:00 14:00 - 14:30 1.50 CASE P INT1 1.50 CASE P 0.50 CASE P 3.00 CASE P INT1 INT1 INT1 0.50 CASE P INT1 2.00 CASE P INT1 2.00 CASE P INT1 0.50 CASE P 5.00 CASE P INT1 INT1 0.50 CASE P INT1 1.00 CASE P 2.00 CASE P INT1 INT1 1.00 CASE P 0.50 CASE P INT1 INT1 1.00 CASE P 3.00 DRILL P 24.00 DRILL P INT1 PROD1 PROD1 3.50 DRILL P PROD1 4.00 CASE P COMP 2.50 CASE P COMP 1.00 CASE P COMP 1.50 CASE P COMP 1.50 CASE P 0.50 CASE P COMP COMP RIG UP TO LAY DOWN 5" DRILL PIPE - LAYING DOWN 5" DRILL PIPE FROM DERRICK LAY DOWN 5" DRILL PIPE OUT OFF DERRICK INSTALL TEST PLUG - RIG UP TO TEST BOP'S TEST BOP'S - ANNULAR 250 LOW 2500 HIGH - TOP / BTM RAMS - BLIND - CHOKE MANIFOLD - HYD CHOKE - HYD KILL - MANUAL CHOKE - MANUAL KILL - TIW - FLOOR SAFETY VALVE - UPPER / LOWER IBOP - 250 LOW - 3500 HIGH - ALL TEST 5 MINS EACH - ACCUMULATOR TEST - (3000 START -1800 - 200 PSI INCREASE 37 SEC - 3000/3 MINS /27 SEC - 5 BOTTLES NITROGEN AVG 2125) RIG DOWN TESTING EQUIPMENT - PULL TEST PLUG - INSTALL WEAR RING P/U 3.5" 15.50 S-1'35 DRILL PIPE FROM PIPE SHED - PULL OUT STAND BACK IN DERRICK - FOR PIPE TO DRILL WITH MAKE UP BHA: PICK UP SPERRY 4.75" MOTOR WITH ABI SET AT 1.5 DEGREE - PU MWD / GR / RES / PWD - ORIENT MWD - UP LOAD MWD - PU SECURITY RE-RUN 6.125 FM-2643 WITH 3 /12 JETS TEST MWD RIH WITH BHA - PICKING UP SINGLES FROM PIPE SHED - TO 6566' TAG CEMENT TEST 7" CASING TO 3500 PSI - HOLD FOR 30 MINS - RECORD ON CHART CUT DRLG LINE - SERVICE TOP DRIVE DRLG CEMENT FROM 6566' TO 6638' TAG FLOAT COLLAR - DRLG FLOAT COLLAR - 83' CEMENT - SHOE - 30' NEW HOLE TO 6754' - (RUBBER PLUGS - TROUBLE DRILLING CORED OUT MIDDLE OF PLUGS) CIRCULATE CONDITION MUD FOR FIT PREFORM FIT - TVD 4013' - MUD WEIGHT 9.6 - SURFACE PRESSURE 390 PSI = 11.47 PPG DISPLACE WELL TO 9.8 PPG FLO PRO DIRECTIONAL DRILL FROM 6754' TO 6960' DIRECTIONAL DRILLING FROM 6960' TO 8861' - WOB 1 K TO 2K - GPM 240 - PP ON BTM 2560 - OFF BTM 2400 - RPM 100 - TQ ON BTM 5K - OFF BTM 4K - PU 98 - SO 63 - ROT 79 DIRECTIONAL DRILL 8.5" HOLE - FROM 8861' TO 9142' T.D. - WOB 2K TO 4K - RPM 100 - TQ ON BTM 5K - OFF BTM 4K - GPM 240 - PP ON BTM 2630 - OFF BTM 2500 - ECD 11.7 - PU 100 - SO 60 - ROT 80 CIRCULATE CONDITION HOLE 5 X CBU -15000 STKS- GPM 245 - RPM 100 - PP 2500 - ECD 11.6 - SHAKERS DID NOT ENTIRELY CLEAN UP PUMP OUT TO SHOE 6700' - NO PROBLEMS - HOLE IN GOOD SHAPE CIRC HOLE CLEAN @ 6700' - GPM 7 BBLS PER MIN -120 RPM OBSERVE WELL - WELL STATIC - PUMP DRY JOB - POH TO BHA LAY DOWN BHA - DOWN LOAD MWD PJSM WITH CO-MAN - GO OVER UP COMING OPERATION Printed: 9/25/2002 4:10:16 PM ') ) BP EXPLORATION Operations Summary Report Page 4 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-13A MPH-13A DRILL +COMPLETE DOYON DOYON 141 Start: 9/2/2002 Rig Release: 9/13/2002 Rig Number: 141 Spud Date: 9/4/2002 End: 9/13/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/9/2002 14:00 - 14:30 0.50 CASE P COMP WITH NEW CREW 14:30 - 15:00 0.50 CASE P COMP MAKE UP BIT SUB WITH FLOAT - PICK UP 6 JTS OF 3.5" DP 15:00 - 18:30 3.50 CASE P COMP RIH TO 6690' 18:30 - 19:00 0.50 CASE P COMP CIRCULATE HOLE 30' ABOVE SHOE -120 RPM -7 BPM- PUMP 3000 STKS - PU 1 OOK - SO 60K - ROT 80K 19:00 - 20:00 1.00 CASE P COMP MONITOR WELL - CLEAN PIT # 5 TO RECIEVE 9.8 BRINE 20:00 - 21 :00 1.00 CASE P COMP RIH - PUMP 30 BBLS MUD PUSH - 84 BBLS 9.8 BRINE - STKS 85 (7 BPM) AFTER PUMPING 1350 STKS (114 BBLS) PRESSURE INCREASED FROM 2500 PSI TO 3560 - NO INDICATION OF HOLE PROBLEMS - PICK UP / SLACK OFF WEIGHT SAME - SLOWED PUMP TO 65 STKS (5.5 BPM) PRESSURE 3500 PSI - CON'T PUMPING ADDITIONAL 71 STKS (6 BBLS) OF 9.8 BRINE - FOR TOTAL BRINE PUMPED 120 BBLS - SWITCHED TO SOLIDS FREE FLO PRO - PUMPED 130 BBLS OF FLO PRO - 65 STKS (5.5 BPM) @ 3500 PSI- (UP / DOWN WEIGHT'S -10 STANDS IN FROM SHOE 95K PU 70K SO - 20 STANDS IN 92K PU - 67K SO) - DIGITAL PUMP GAUGE ON CONSOLE / PRESSURE GAUGE ON CHOKE PANEL BAD - HOLDING 2900 PSI ON GAUGE'S WITH PUMPS OFF AND NO PRESSURE 21 :00 - 23:30 2.50 CASE P COMP PUMP OUT TO SHOE FROM 9142' TO 6700' - PUMP 18 STKS (1.5 BPM) PRESSURE 600 PSI - NO PROBLEMS ON TRIP OUT - HOLE IN GOOD SHAPE 23:30 - 00:00 0.50 CASE P COMP DISPLACE CASING WITH 9.8 BRINE - 3400 STKS (287 BBLS) - 85 STKS (7 BPM) - PRESSURE 1530 PSI - RPM 120 - RECIPROCATE PIPE 90' - CLEAN BRINE BACK TO SURFACE 9/10/2002 00:00 - 00:30 0.50 CASE P COMP CON'T CIRC 9.8 BRINE (3400 STKS) BRINE CLEAN ON RETURNS 00:30 - 02:30 2.00 CASE P COMP MONITOR WELL - WELL STATIC - POH 02:30 - 04:00 1.50 CASE P COMP PICK UP BHA - BIT - TWO SCRAPERS - 20 4.75 DC'S /10 HWDP 3.5" 04:00 - 05:30 1.50 CASE P COMP CON'T RIH WITH 3.5" DRILL PIPE TO 6700' 05:30 - 08:00 2.50 CASE P COMP CIRCULATE CLEAN BRINE @ 6700' - RPM 120 - 85 STKS (7 BPM) PP 1530 PSI FOR 1 CIRCULATION 08:00 - 10:30 2.50 CASE P COMP CIRCULATE / FILTER BRINE TO < 60 NTU 10:30 - 12:30 2.00 CASE P COMP PJSM - PUMP CAUSTIC WASH 75 BBLS - ROTATE- RECIPROCATE PIPE WHILE PUMP WASH- 12:30 - 13:00 0.50 CASE P COMP FLUSH BOP'S WITH FRESH WATER - SECURE WELL 13:00 - 15:00 2.00 CASE P COMP FILTERING 9.8 BRINE TO < 60 NTU 15:00 - 16:00 1.00 CASE P COMP DISPLACE 9.8 BRINE TO 9.8 SOLIDS FREE FLO PRO - RPM 120 - 85 STKS PER MIN (7 BPM) - 3400 STKS 287 BBLS - PP 1530 16:00 - 16:30 0.50 CASE P COMP MONITOR WELL - WELL STATIC - PUMP DRY JOB 16:30 - 17:00 0.50 CASE P COMP POH TO 6100' - IMPROPER HOLE FILL TREND- SWABBING 17:00 - 19:30 2.50 CASE P COMP PUMP OUT FROM 6100' TO 3700' 19:30 - 21 :00 1.50 CASE P COMP POH - PROPER HOLE FILL 21 :00 - 21 :30 0.50 CASE P COMP BREAK BIT - CASING SCRAPERS - BIT SUB - LAY DOWN - CLEAR FLOOR 21 :30 - 23:00 1.50 CASE P COMP PJSM - RIG UP 4" HANDLING TOOLS - CASING EQUIPMENT Printed: 9/25/2002 4:10:16 PM ) ) BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: MPH-13A Common Well Name: MPH-13A Spud Date: 9/4/2002 Event Name: DRILL +COMPLETE Start: 9/2/2002 End: 9/13/2002 Contractor Name: DOYON Rig Release: 9/13/2002 Rig Name: DOYON 141 Rig Number: 141 Date From - To Hours Task Code NPT Phase Description of Operations 9/10/2002 23:00 - 00:00 1.00 CASE P CaMP PICK UP AND RUN BAKER 4" SCREENS - @ 640' 9/11/2002 00:00 - 02:30 2.50 CASE P CaMP CON'T RUNNING BAKER 4" SCREENS TO 2411' 02:30 - 03:30 1.00 CASE P COMP RIG DOWN 4" HANDLING EQUIPMENT - RIG UP 2 7/8" HANDLING EQUIPMENT - PJSM - 03:30 - 06:30 3.00 CASE P CaMP PICK UP AND RUN 2 7/8" INNER STRING - SPACE OUT - MAKE UP TO BAKER SC-1 R PACKER 06:30 - 13:00 6.50 CASE P CaMP RIH WITH LINER - TAG UP 9142' - FILL EACH STAND WITH FILL LINE - BREAK CIRC EVERY 5 STANDS TO SHOE 6724' FILL EVERY STAND WITH FILL LINE FROM 6724' TO 9142' 13:00 - 15:00 2.00 CASE P CaMP DROP BALL PUMP DOWN TO SEAT 442 STKS (37 BBLS) - BALL ON SEAT - PRESSURE UP TO SET PACKER / HANGER TO 3100 PSI- TEST 1000 PSI- RECORD ON CHART FOR 15 MINS - RELEASE FROM LINER HANGER- BLOW BALL WITH 3900 PSI - LINER TOP 6642' 15:00 - 16:30 1.50 CASE P CaMP MONITOR WELL - PUMP OUT TO 8100' 16:30 - 19:00 2.50 CASE N RREP CaMP RIG REPAIR - TOP DRIVE SHOT PIN HYDRAULIC MOTOR DEVELOPED A LEAK - CHANGE OUT HYDRAULIC MOTOR 19:00 - 20:30 1.50 CASE P CaMP CaN'T PUMP OUT TO SLIDING SLEEVE 20:30 - 21 :00 0.50 CASE P CaMP WORK STRING 4 TIMES ACROSS SLIDING SLEEVE TO CLOSE SLEEVE - DID NOT SEE ANY INDICATION OF SLEEVE CLOSING - 21 :00 - 22:00 1.00 CASE P CaMP ESTABLISH CIRC RATE 85 STKS (7.1 BPM) @ 1450 PSI- DISPLACE 9.8 SOLIDS FREE FLO PRO TO 9.2 BRINE - PUMPED 4700 STKS (398 BBLS) - CLEAN BRINE BACK TO SURFACE 22:00 - 22:30 0.50 CASE P CaMP MONITIOR WELL - WELL STATIC - BLOW DOWN TOP DRIVE 22:30 - 00:00 1.50 CASE P COMP LAYING DOWN 3.5" DRILL PIPE - FLOWING BACK THROUGH TOP OF STRING - MIX / PUMP DRY JOB - CaN'T LAY DOWN 3.5" DRILL PIPE 9/12/2002 00:00 - 01 :30 1.50 CASE P CaMP LAY DOWN 3.5" DRILL PIPE 01 :30 - 04:00 2.50 CASE P CaMP RIG UP HANDLING TOOLS FOR 27/8" INNER STRING - LAY DOWN INNER STRING 04:00 - 1 0:00 6.00 CASE P CaMP LAY DOWN 3.5" DP /4.75" FROM DERRICK 1 0:00 - 1 0:30 0.50 CASE P CaMP PULL WEAR RING 10:30 - 11 :30 1.00 CASE P CaMP CHANGE OUT UPPER RAMS TO 2 7/8" RAMS - TEST DOOR SEALS TO 2500 PSI 11 :30 - 12:30 1.00 CASE P CaMP RIG UP DOYON CASING EQUIPMENT 12:30 - 13:30 1.00 CASE P CaMP RIG UP CENTERLlFT ESP WIRE LINE UNIT - PJSM 13:30 - 16:00 2.50 CASE P CaMP MAKE UP CENTERLlFT MTR - TANDEM PUMP ASSEMBLY 16:00 - 23:30 7.50 CASE P CaMP RUN 2 7/8" COMPLETION - 204 JTS 2 7/8" EUE 6.5# TUBING - CIRC TUBING VOLUME @ 4200' - 25 BBLS -10 SPM -1380 PSI 23:30 - 00:00 0.50 CASE P CaMP PICK UP LANDING JOINT - MAKE UP 11" X 2 7/8" TUBING HANGER WITH TWC INSTALLED - PU 64K - SO 51K -125 LASALLE CLAMPS - 6 FLAT CLAMPS INSTALLED ON STRING - TEST ESP EVERY 2000' RAN IN HOLE 9/13/2002 00:00 - 02:30 2.50 CASE P COMP MAKE UP PIGTAIL TO ESP / HANGER - TEST SAME 02:30 - 03:00 0.50 CASE P CaMP LAND 2 7/8" TUBING HEAD - RUN IN LOCK DOWN SCREWS - BACK OUT / LAY DOWN LANDING JOINT - TEST TWC TO 1000 PSI - OK - CLEAR FLOOR OF HANDLING TOOLS - CASING EQUIPMENT 03:00 - 04:30 1.50 CASE P CaMP CHANGE RAMS FROM 2 7/8" UPPER / 3.5" LOWER TO 4' Printed: 9/25/2002 4:10:16 PM ) ') BP EXPLORATION Operations Summary Report Page 6 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-13A MPH-13A DRILL +COMPLETE DOYON DOYON 141 Start: 9/2/2002 Rig Release: 9/13/2002 Rig Number: 141 Spud Date: 9/4/2002 End: 9/13/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/13/2002 03:00 - 04:30 1.50 CASE P COMP LOWER - 3.5" X 6" VARIABLE UPPER 04:30 - 06:00 1.50 BOPSUR P COMP NIPPLE DOWN BOP'S 06:00 - 07:00 1.00 WHSUR P COMP NIPPLE UP CAMERON 2-9/16" 5M TREE. TESTED TREE AND ADAPTER TO 5000 PSI FOR 10 MINUTES. 07:00 - 08:00 1.00 WHSUR P COMP RIGGED UP LUBRICATOR AND PULLED TWC AND INSTALLED BPV. 08:00 - 09:00 1.00 CLEAN P COMP SECURED WELL AND CLEARED CELLAR. RELEASED RIG AT 0900 HRS 9-13-2002. Printed: 9/25/2002 4:10:16 PM Legal Name: MPH-13A Common Name: MPH-13A Test Date 9/3/2002 9/7/2002 FIT FIT Test Type Test Depth (TMD) 3,880.0 (ft) 6,754.0 (ft) BP'ë;){B,U~.Rli\7P1<DN' . . Lea ~4.C>ff'17@~~§Qmtlrlij@ ry Test Depth (TVD) 2,908.0 (ft) 4,013.0 (ft) AMW 8.70 (ppg) 9.60 (ppg) Surface Pressure 380 (psi) 390 (psi) Leak Off Pressure (BHP) 1,694 (psi) 2,391 (psi) Page 1 of 1 EMW 11.22 (ppg) 11.47 (ppg) ~ ~ Printed: 9/25/2002 4:09:58 PM ) ó? C:Jd) - J to f 01-0ct-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPH-13A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 3,814.31 ' MD Window / Kickoff Survey 3,880.00' MD (if applicable) Projected Survey: 9,142.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) C'''''...,... (;-' 1"'''''','' i'l..- ¡ ') L~. I,~.;. ". Sperry-Sun Drilling Services Milne Point Unit BPXA Milne PointMPH MPH-13A '~' Job No. AKZZ22149, Surveyed: 9 September, 2002 Survey Report 30 September, 2002 Your Ref: API 500292281801 Surface Coordinates: 6010070.40 N, 556503.05 E (70026' 17.3883" N, 149032' 21.4224" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 "~ Surface Coordinates relative to Project H Reference: 1010070.40 N, 56503.05 E (Grid) Surface Coordinates relative to Structure Reference: 1090.14 N, 1106.43 E(True) Kelly Bushing: 64.20ft above Mean Sea Level Elevation relative to Project V Reference: 64.20ft Elevation relative to Structure Reference: 64.20ft 5¡ ,,,,""''''''Y-5UI! D Ftn:::L.ï],rG..'m5r~ R'l,rç E? S A Halliburton Company Survey Ref: svy10192 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A Your Ref: API 500292281801 Job No. AKZZ22149, Surveyed: 9 September, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3814.31 68.740 111.760 2820.48 2884.68 268.29 S 1930.37 E 6009816.74 N 558435.39 E 1304.27 Tie On Point 3880.00 ,. 69.590 113.950 2843.85 2908.05 ~ 292.14 S 1986.93 E 6009793.33 N 558492.14 E 3.374 1332.20 Window Point 4027.81 70.880 104.030 2893.94 2958.14 337.28 S 2118.28 E 6009749.18 N 558623.82 E 6.375 1403.63 4122.99 69.170 97.950 2926.48 2990.68 354.35 S 2206.03 E 6009732.77 N 558711.70 E 6.266 1459.78 4216.09 67.370 93.110 2960.97 3025.17 362.70 S 2292.07 E 6009725.07 N 558797.81 E 5.201 1520.24 ~ 4309.89 66.990 88.330 2997.37 3061.57 363.80 S 2378.49 E 6009724.64 N 558884.23 E 4.714 1585.66 4406.01 64.700 81.840 3036.73 3100.93 356.33 S 2465.81 E 6009732.76 N 558971.49 E 6.604 1657.28 4501.25 61.240 77.180 3080.03 3144.23 340.95 S 2549.19 E 6009748. 78 N 559054.75 E 5.673 1730.98 4591.12 57.780 74.430 3125.62 3189.82 321.99 S 2624.26 E 6009768.30 N 559129.67 E 4.666 1800.62 4682.74 57.300 73.880 3174.80 3239.00 300.89 S 2698.63 E 6009789.97 N 559203.88 E 0.729 1871.11 4777.48 57.360 70.610 3225.95 3290.15 276.57 S 2774.56 E 6009814.86 N 559279.63 E 2.906 1944.87 4870.81 57.000 70.060 3276.53 3340.73 250.18S 2848.42 E 6009841 .81 N 559353.28 E 0.628 2018.38 4964.38 58.450 64.540 3326.52 3390.72 219.64 S 2921.35 E 6009872.90 N 559425.98 E 5.222 2093.84 5058.05 58.870 60.060 3375.26 3439.46 182.46 S 2992.15 E 6009910.62 N 559496.50 E 4.109 2171.95 5152.69 58.690 56.440 3424.33 3488.53 139.88 S 3060.96 E 6009953.71 N 559564.98 E 3.276 2252.01 5244.84 59.320 51 .140 3471.81 3536.01 93.24 S 3124.65 E 6010000.84 N 559628.32 E 4.977 2330.78 5340.82 59.820 44.890 3520.45 3584.65 37.91 S 3186.11 E 6010056.63 N 559689.36 E 5.638 2413.43 5433.91 60.670 40.410 3566.67 3630.87 21.52 N 3240.83 E 6010116.47 N 559743.63 E 4.276 2493.57 5528.24 62.400 34.850 3611.66 3675.86 87.17 N 3291.41 E 6010182.51 N 559793.70 E 5.496 2574.54 5619.49 64.210 28.910 3652.68 3716.88 156.37 N 3334.41 E 6010252.03 N 559836.18 E 6.144 2651.99 5714.02 64.500 24.000 3693.61 3757.81 232.64 N 3372.35 E 6010328.58 N 559873.54 E 4.692 2730.13 5807.60 65.280 19.860 3733.34 3797.54 311.22 N 3403.98 E 6010407.40 N 559904.57 E 4.092 2804.92 5901.35 67.430 17.660 3770.94 3835.14 392.53 N 3431.58 E 6010488.92 N 559931.56 E 3.143 2878.40 '~ 5994.84 70.610 18.600 3804.41 3868.61 475.47 N 3458.75 E 6010572.07 N 559958.10 E 3.529 2952.59 6090.04 73.970 18.850 3833.36 3897.56 561.35 N 3487.86 E 6010658.16 N 559986.56 E 3.538 3030.15 6183.46 75.130 20.120 3858.25 3922.45 646.23 N 3517.90E 6010743.27 N 560015.95 E 1.805 3107.79 6278.00 78.350 21.150 3879.93 3944.13 732.33 N 3550.33 E 6010829.61 N 560047.72 E 3.567 3188.04 6372.59 80.030 21.310 3897.67 3961.87 818.94 N 3583.97 E 6010916.47 N 560080.71 E 1.784 3269.54 6464.70 81.410 21.910 3912.53 3976.73 903.45 N 3617.45 E 6011001.23 N 560113.55 E 1.630 3349.57 6558.89 82.090 22.540 3926.04 3990.24 989.74 N 3652.71 E 6011087.79 N 560148.15 E 0.979 3432.10 6660.26 81 .480 22.400 3940.53 4004.73 1082.45 N 3691.05 E 6011180.79 N 560185.79 E 0.617 3521.14 6738.69 82.030 23.270 3951.77 4015.97 1153.98 N 3721.17 E 6011252.55 N 560215.37 E 1.303 3590.24 6784.17 82.650 29.160 3957.84 4022.04 1194.40 N 3741.08 E 6011293.11 N 560234.97 E 12.907 3631.50 6832.41 84.580 31 .480 3963.21 4027.41 1235.78 N 3765.28 E 6011334.67 N 560258.86 E 6.233 3676.65 6877.12 87.600 34.160 3966.25 4030.45 1273.26 N 3789.45 E 6011372.33 N 560282.75 E 9.021 3719.28 30 September, 2002.14:13 Page2of5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A Your Ref: API 500292281801 Job No. AKZZ22149, Surveyed: 9 September, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6924.75 85.810 36.910 3968.99 4033.19 1311.95 N 3817.08 E 6011411.23 N 560310.08 E 6.881 3765.33 6970.61 83.330 41.500 3973.33 4037.53 1347.32 N 3845.93 E 6011446.82 N 560338.66 E 11.336 3810.18 7011.58 86.240 47.370 3977.06 4041.26 1376.43 N 3874.48 E 6011476.15N 560366.99 E 15.937 3850.77 7062.70 86.740 48.860 3980.19 4044.39 1410.49 N 3912.47 E 6011510.50 N 560404.72 E 3.069 3901.76 7110.95 91.050 50.970 3981.12 4045.32 1441.55 N 3949.36 E 6011541.83 N 560441.38 E 9.945 3949.99 ~ 7155.82 93.510 51.800 3979.34 4043.54 1469.53 N 3984.39 E 6011570.07 N 560476.19 E 5.786 3994.81 7205.77 93.570 51.470 3976.25 4040.45 1500.47 N 4023.48 E 6011601.31 N 560515.05 E 0.670 4044.64 7247.94 93.080 51. 640 3973.81 4038.01 1526.64 N 4056.45 E 6011627.74 N 560547.82 E 1.230 4086.72 7298.80 89.880 49.680 3972.49 4036.69 1558.87 N 4095.77 E 6011660.26 N 560586.89 E 7.377 4137.55 7341.06 89.820 49.790 3972.60 4036.80 1586.18 N 4128.02 E 6011687.82 N 560618.93 E 0.296 4179.81 7390.57 89.020 49.450 3973.10 4037.30 1618.26 N 4165.73 E 6011720.17 N 560656.40 E 1.756 4229.32 7434.79 87.170 48.840 3974.57 4038.77 1647.17 N 4199.16 E 6011749.33 N 560689.60 E 4.405 4273.51 7483.27 86.610 47.680 3977.20 4041.40 1679.39 N 4235.28 E 6011781.83 N 560725.48 E 2.654 4321.89 7527.59 88.890 48.220 3978.94 4043.14 1709.05 N 4268.16 E 6011811.74 N 560758.14 E 5.286 4366.15 7576.32 87.480 47.370 3980.49 4044.69 1741.77 N 4304.24 E 6011844.73 N 560793.97 E 3.378 4414.82 7620.57 86.610 46.720 3982.77 4046.97 1771.88 N 4336.58 E 6011875.09 N 560826.08 E 2.453 4458.96 7670.94 84.820 46.190 3986.53 4050.73 1806.49 N 4372.98 E 6011909.97 N 560862.22 E 3.705 4509.09 7714.65 84.890 45.690 3990.45 4054.65 1836.76 N 4404.27 E 6011940.48 N 560893.28 E 1.150 4552.52 7762.01 86.490 45.910 3994.01 4058.21 1869.68 N 4438.12 E 6011973.66 N 560926.88 E 3.410 4599.62 7807.47 86.800 47.180 3996.67 4060.87 1900.90 N 4471.07 E 6012005.12 N 560959.59 E 2.871 4644.92 7855.98 88.340 46.810 3998.73 4062.93 1933.95 N 4506.51 E 6012038.44 N 560994.78 E 3.265 4693.33 7899.09 88.770 46.680 3999.82 4064.02 1963.48 N 4537.90 E 6012068.21 N 561025.94 E 1.042 4736.36 7948.23 88.830 46.310 4000.85 4065.05 1997.30 N 4573.53 E 6012102.30 N 561061.32 E 0.763 4785.40 ~ 7992.10 88.830 46.020 4001.74 4065.94 2027.68 N 4605.17 E 6012132.92 N 561092.72 E 0.661 4829.16 8040.99 87.600 45.310 4003.26 4067.46 2061.83 N 4640.12 E 6012167.33 N 561127.42 E 2.905 4877.89 8084.57 87.970 46.700 4004.95 4069.15 2092.08 N 4671.45 E 6012197.81 N 561158.51 E 3.298 4921.34 8133.56 88.400 47.500 4006.50 4070.70 2125.41 N 4707.32 E 6012231.41 N 561194.13 E 1.853 4970.24 8176.78 88.030 46.520 4007.85 4072.05 2154.87 N 4738.92 E 6012261.11 N 561225.50 E 2.423 5013.39 8226.23 88.460 46.620 4009.36 4073.56 2188.84 N 4774.81 E 6012295.36 N 561261.14 E 0.893 5062.73 8269.65 88.580 45.080 4010.48 4074.68 2219.08 N 4805.95 E 6012325.83 N 561292.05 E 3.556 5106.02 8318.00 86.610 42.100 4012.51 4076.71 2254.06 N 4839.26 E 6012361.06 N 561325.09 E 7.384 5154.03 8363.45 86.800 43.360 4015.12 4079.32 2287.39 N 4870.04 E 6012394.62 N 561355.62 E 2.799 5199.05 8412.39 86.300 41.690 4018.07 4082.27 2323.39 N 4903.06 E 6012430.87 N 561388.37 E 3.556 5247.49 8455.93 86.300 41 .520 4020.88 4085.08 2355.88 N 4931.91 E 6012463.58 N 561416.97 E 0.390 5290.48 8504.54 87.290 40.080 4023.60 4087.80 2392.62 N 4963.62 E 6012500.56 N 561448.40 E 3.591 5338.40 30 September, 2002 - 14:13 Page 3 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A Your Ref: API 500292281801 Job No. AKZZ22149, Surveyed: 9 September, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8549.71 86.120 38.180 4026.19 4090.39 2427.60 N 4992.08 E 6012535.75 N 561476.59 E 4.934 5382.70 8599.47 86.120 38.640 4029.56 4093.76 2466.50 N 5022.93 E 6012574.89 N 561507.14 E 0.922 5431.34 8640.93 87.410 38.630 4031.90 4096.10 2498.83 N 5048.77 E 6012607.41 N 561532.74 E 3.112 5471.94 8689.23 87.350 38.380 4034.11 4098.31 2536.59 N 5078.81 E 6012645.40 N 561562.49 E 0.532 5519.23 8734.67 86.490 37.740 4036.55 4100.75 2572.32 N 5106.78 E 6012681.33 N 561590.19 E 2.358 5563.64 '~ 8782.65 85.930 36.590 4039.72 4103.92 2610.47 N 5135.70 E 6012719.70 N 561618.83 E 2.661 5610.33 8826.43 88.090 37.150 4042.00 4106.20 2645.44 N 5161.93 E 6012754.88 N 561644.79 E 5.096 5652.92 8874.81 89.200 36.400 4043.15 4107.35 2684.18 N 5190.89 E 6012793.83 N 561673.45 E 2.769 5700.02 8920.84 89.690 36.860 4043.59 4107.79 2721 .12 N 5218.35 E 6012830.98 N 561700.63 E 1 .460 5744.81 8968.69 89.510 36.670 4043.93 4108.13 2759.45 N 5246.99 E 6012869.53 N 561728.98 E 0.547 5791.40 9013.03 89.510 36.420 4044.31 4108.51 2795.07 N 5273.39 E 6012905.35 N 561755.11 E 0.564 5834.54 9073.05 89.820 35.510 4044.66 4108.86 2843.65 N 5308.64 E 6012954.19 N 561789.99 E 1.602 5892.79 9142.00 89.820 35.510 4044.87 4109.07 2899.77 N 5348.69 E 6013010.62 N 561829.61 E 0.000 5959.57 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPH-13. Northings and Eastings are relative to MPH-13. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from MPH-13 and calculated along an Azimuth of 49.920° (True). Magnetic Declination at Surface is 25.736°(02-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 9142.00ft., The Bottom Hole Displacement is 6084.17ft., in the Direction of 61.536° (True). ,-" 30 September, 2002 - 14:13 Page 4 of 5 DrillQuest 3.03.02.002 Milne Point Unit Comments Measured Depth (ft) 3814.31 3880.00 9142.00 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A Your Ref: AP/500292281801 Job No. AKZZ22149, Surveyed: 9 September, 2002 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2884.68 2908.05 4109.07 268.29 S 292.14 S 2899.77 N Survey tool proqram for MPH-13A From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 30 September, 2002 - 14:13 To Measured Vertical Depth Depth (ft) (ft) Comment 1930.37 E 1986.93 E 5348.69 E Tie On Point Window Point Projected Survey '~ Survey Tool Description 9142.00 4109.07 AK-6 BP _IFR-AK(MPH-13A) '~ Page 5 of 5 DrillQuest 3.03.02.002 AOGCC 333 W. 7th Ave. Suite 1 00 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPH-13A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 3,814.31' MD Window / Kickoff Survey 3,880.00' MD (if applicable) Projected Survey: 9,142.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) 01-0ct-02 ~J ~':;l¡?~~' F ä '\ W:!:J ~..4. It¡~tffi~ OCT (: ~~ . \'J .;:: va ;;t ¿;{Oc9-/ro I Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPH MPH-13A MWD ~. Job No. AKMW22149, Surveyed: 9 September, 2002 Survey Report 30 September, 2002 Your Ref: API 500292281801 Surface Coordinates: 6010070.40 N, 556503.05 E (70026' 17.3883" N, 149032' 21.4224" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~. Surface Coordinates relative to Project H Reference: 1010070.40 N, 56503.05 E (Grid) Surface Coordinates relative to Structure Reference: 1090.14 N, 1106.43 E(True) Kelly Bushing: 64.20ft above Mean Sea Level Elevation relative to Project V Reference: 64.20ft Elevation relative to Structure Reference: 64.20ft 5pel''''''Y~5UI1 D'FffI:~L'íIN"ç5,mI",'^~e'^FimvrEË!S,~ A Halliburton Company Survey Ref: svy10193 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A MWD Your Ref: API 500292281801 Job No. AKMW22149, Surveyed: 9 September, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (It) (It) (It) (ft) (It) (ft) (It) (o/100ft) 3814.31 68.740 111.760 2820.48 2884.68 268.29 S 1930.37 E 6009816.74 N 558435.39 E 1304.27 Tie On Point 3880.00 69.590 113.950 2843.85 2908.05 292.14 S 1986.93 E 6009793.33 N 558492.14 E 3.374 1332.20 Window Point 4027.81 70.880 99.050 2894.08 2958.28 331.43 S 2119.86 E 6009755.04 N 558625.36 E 9.523 1408.61 4122.99 69.170 97.640 2926.60 2990.80 344.42 S 2208.36 E 6009742.72 N 558713.96 E 2.273 1467.96 4216.09 67.370 93.240 2961.08 3025.28 352.64 S 2294.43 E 6009735.16 N 558800.08 E 4.797 1528.52 352.28 S .~ 4309.89 66.990 86.280 2997.50 3061.70 2380.81 E 6009736.16 N 558886.46 E 6.851 1594.85 4406.01 64.700 80.880 3036.85 3101.05 342.52 S 2467.92 E 6009746.59 N 558973.50 E 5.652 1667.79 4501.25 61.240 76.180 3080.15 3144.35 325.71 S 2551.03 E 6009764.03 N 559056.48 E 5.702 1742.20 4591.12 57.780 73.770 3125.74 3189.94 305.67 S 2625.81 E 6009784.64 N 559131.10 E 4.490 1812.32 4682.74 57.300 73.500 3174.92 3239.12 283.89 S 2699.99 E 6009806.98 N 559205.11 E 0.580 1883.10 4777.48 57.360 70.150 3226.07 3290.27 259.02 S 2775.74 E 6009832.42 N 559280.68 E 2.977 1957.08 4870.81 57.000 69.610 3276.65 3340.85 232.04 S 2849.39 E 6009859.96 N 559354.11 E 0.621 2030.80 4964.38 58.450 64.41 0 3326.64 3390.84 201.13 S 2922.16 E 6009891.42 N 559426.65 E 4.947 2106.38 5058.05 58.870 59.610 3375.38 3439.58 163.59 S 2992.77 E 6009929.49 N 559496.98 E 4.399 2184.58 5152.69 58.690 56.220 3424.45 3488.65 120.61 S 3061.33 E 6009972.98 N 559565.21 E 3.069 2264.71 5244.84 59.320 50.790 3471.93 3536.13 73.65 S 3124.79 E 6010020.43 N 559628.31 E 5.097 2343.50 5340.82 59.820 44.600 3520.57 3584.77 17.98 S 3185.94 E 6010076.56 N 559689.04 E 5.584 2426.14 5433.91 60.670 40.230 3566.79 3630.99 41.67 N 3240.43 E 6010136.62 N 559743.07 E 4.176 2506.23 5528.24 62.400 34.940 3611.77 3675.97 107.37 N 3290.95 E 6010202.70 N 559793.09 E 5.259 2587.19 5619.49 64.210 29.020 3652.79 3716.99 176.49 N 3334.07 E 6010272.15 N 559835.69 E 6.125 2664.69 5714.02 64.500 23.800 3693.73 3757.93 252.78 N 3371.95 E 6010348.72 N 559872.99 E 4.987 2742.79 5807.60 65.280 20.760 3733.45 3797.65 331.18 N 3404.07 E 6010427.36 N 559904.51 E 3.057 2817.84 5901.35 67.430 18.230 3771.05 3835.25 412.13 N 3432.71 E 6010508.53 N 559932.54 E 3.372 2891.88 ~ 5994.84 70.610 18.670 3804.52 3868.72 494.92 N 3460.33 E 6010591.53 N 559959.54 E 3.430 2966.32 6090.04 73.970 18.910 3833.47 3897.67 580.76 N 3489.54 E 6010677.59 N 559988.09 E 3.538 3043.94 6183.46 75.130 20.070 3858.36 3922.56 665.64 N 3519.59 E 6010762.69 N 560017.49 E 1.725 3121.58 6278.00 78.350 21.140 3880.04 3944.24 751.76 N 3551.97 E 6010849.05 N 560049.22 E 3.580 3201.80 6372.59 80.030 21.480 3897.78 3961.98 838.32 N 3585.74 E 6010935.86 N 560082.33 E 1.811 3283.37 6464.70 81.410 21.950 3912.64 3976.84 922.77 N 3619.37 E 6011020.57 N 560115.32 E 1.581 3363.48 6558.89 82.090 22.730 3926.15 3990.35 1008.99 N 3654.80 E 6011107.05 N 560150.10 E 1.092 3446.10 6660.26 81 .480 22.170 3940.64 4004.84 1101.71N 3693.11 E 6011200.06 N 560187.71 E 0.813 3535.12 6738.69 82.030 24.090 3951.89 4016.09 1173.09 N 3723.60 E 6011271.67 N 560217.66 E 2.522 3604.40 6784.17 82.650 29.040 3957.95 4022.15 1213.39 N 3743.76 E 6011312.12 N 560237.50 E 10.872 3645.77 6832.41 84.580 31.580 3963.32 4027.52 1254.77 N 3767.95 E 6011353.68 N 560261.38 E 6.587 3690.92 6877.12 87.600 34.160 3966.37 4030.57 1292.23 N 3792.16 E 6011391.32 N 560285.31 E 8.875 3733.56 30 September, 2002 - 14:22 Page2of5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A MWD Your Ref: AP/500292281801 Job No. AKMW22149, Surveyed: 9 September, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6924.75 85.810 36.800 3969.10 4033.30 1330.94 N 3819.75 E 6011430.25 N 560312.61 E 6.689 3779.60 6970.61 83.330 41.270 3973.45 4037.65 1366.40 N 3848.49 E 6011465.92 N 560341.08 E 11 .1 08 3824.42 7011.58 86.240 47.080 3977.17 4041.37 1395.64 N 3876.91 E 6011495.38 N 560369.27 E 15.807 3865.00 7062.70 86.740 48.500 3980.30 4044.50 1429.92 N 3914.70 E 6011529.94 N 560406.81 E 2.940 3915.98 7110.95 91.050 50.500 3981 .23 4045.43 1461.24 N 3951.38 E 6011561.54 N 560443.24 E 9.847 3964.21 ~ 7155.82 93.510 51.290 3979.45 4043.65 1489.52 N 3986.16 E 6011590.08 N 560477.81 E 5.758 4009.03 7205.77 93.570 50.950 3976.36 4040.56 1520.81 N 4024.97 E 6011621.66 N 560516.38 E 0.690 4058.88 7247.94 93.080 51.080 3973.92 4038.12 1547.30 N 4057.70 E 6011648.40 N 560548.91 E 1.202 4100.97 7298.80 89.880 49.240 3972.60 4036.80 1579.86 N 4096.73 E 6011681.26 N 560587.69 E 7.257 4151.80 7341.06 89.820 49.300 3972.71 4036.91 1607.44 N 4128.75 E 6011709.07 N 560619.51 E 0.201 4194.06 7390.57 89.020 48.840 3973.22 4037.42 1639.87 N 4166.16 E 6011741.79 N 560656.66 E 1.864 4243.56 7434.79 87.170 48.280 3974.69 4038.89 1669.12 N 4199.29 E 6011771.29 N 560689.57 E 4.371 4287.74 7483.27 86.610 47.040 3977.32 4041.52 1701.72 N 4235.07 E 6011804.16 N 560725.10 E 2.803 4336.11 7527.59 88.890 47.490 3979.06 4043.26 1731.77 N 4267.59 E 6011834.46 N 560757.40 E 5.243 4380.35 7576.32 87.480 47.110 3980.60 4044.80 1764.80 N 4303.39 E 6011867.76 N 560792.94 E 2.997 4429.00 7620.57 86.610 45.920 3982.88 4047.08 1795.21 N 4335.45 E 6011898.41 N 560824.77 E 3.328 4473.11 7670.94 84.820 45.620 3986.64 4050.84 1830.25 N 4371.44 E 6011933.72 N 560860.50 E 3.603 4523.21 7714.65 84.890 45.070 3990.56 4054.76 1860.85 N 4402.41 E 6011964.55 N 560891.23 E 1.263 4566.60 7762.01 86.490 45.250 3994.12 4058.32 1894.15 N 4435.89 E 6011998.10N 560924.46 E 3.400 4613.66 7807.47 86.800 45.900 3996.78 4060.98 1925.91 N 4468.30 E 6012030.11 N 560956.63 E 1.582 4658.92 7855.98 88.340 45.590 3998.84 4063.04 1959.73 N 4503.02 E 6012064.20 N 560991.09 E 3.238 4707.25 7899.09 88.770 45.520 3999.93 4064.13 1989.91 N 4533.78 E 6012094.60 N 561021.63 E 1.011 4750.22 7948.23 88.830 45.880 4000.96 4065.16 2024.22 N 4568.94 E 6012129.18 N 561056.53 E 0.7 43 4799.22 '~ 7992.10 88.830 45.750 4001 .85 4066.05 2054.79 N 4600.40 E 6012159.99 N 561087.75 E 0.296 4842.97 8040.99 87.600 45.060 4003.37 4067.57 2089.10 N 4635.19 E 6012194.56 N 561122.28 E 2.884 4891.68 8084.57 87.970 46.350 4005.06 4069.26 2119.51 N 4666.36 E 6012225.21 N 561153.22 E 3.077 4935.11 8133.56 88.400 47.200 4006.61 4070.81 2153.04 N 4702.04 E 6012259.01 N 561188.64 E 1.944 4984.00 8176.78 88.030 46.220 4007.96 4072.16 2182.67 N 4733.48 E 6012288.87 N 561219.86 E 2.423 5027.13 8226.23 88.460 46.240 4009.47 4073.67 2216.86 N 4769.18 E 6012323.33 N 561255.29 E 0.871 5076.46 8269.65 88.580 44.660 4010.59 4074.79 2247.31 N 4800.11 E 6012354.01 N 561285.99 E 3.648 5119.73 8318.00 86.610 41.950 4012.62 4076.82 2282.46 N 4833.24 E 6012389.41 N 561318.85 E 6.925 5167.71 8363.45 86.800 43.180 4015.23 4079.43 2315.87 N 4863.93 E 6012423.06 N 561349.29 E 2.734 5212.71 8412.39 86.300 41.500 4018.18 4082.38 2351.98 N 4896.83 E 6012459.42 N 561381.92 E 3.576 5261.13 8455.93 86.300 41.410 4020.99 4085.19 2384.55 N 4925.60 E 6012492.20 N 561410.44 E 0.206 5304.11 8504.54 87.290 40.010 4023.71 4087.91 2421.33 N 4957.25 E 6012529.22 N 561441.81 E 3.524 5352.01 30 September, 2002 - 14:22 Page 3 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A MWD Your Ref: AP/500292281801 Job No. AKMW22149, Surveyed: 9 September, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8549.71 86.120 38.060 4026.30 4090.50 2456.36 N 4985.65 E 6012564.46 N 561469.94 E 5.028 5396.29 8599.47 86.120 38.390 4029.67 4093.87 2495.36 N 5016.37 E 6012603.70 N 561500.37 E 0.662 5444.91 8640.93 87.410 38.420 4032.01 4096.21 2527.80 N 5042.08 E 6012636.33 N 561525.83 E 3.112 5485.47 8689.23 87.350 38.200 4034.22 4098.42 2565.66 N 5071.99 E 6012674.41 N 561555.46 E 0.472 5532.73 8734.67 86.490 37.550 4036.66 4100.86 2601.47 N 5099.85 E 6012710.44 N 561583.04 E 2.371 5577.11 --.../ 8782.65 85.930 36.390 4039.83 4104.03 2639.72 N 5128.64 E 6012748.91 N 561611.54 E 2.680 5623.76 8826.43 88.090 36.850 4042.11 4106.31 2674.81 N 5154.72 E 6012784.19 N 561637.35 E 5.044 5666.31 8874.81 89.200 36.190 4043.26 4107.46 2713.68 N 5183.50 E 6012823.28 N, 561665.84 E 2.669 5713.36 8920.84 89.690 36.680 4043.70 4107.90 2750.71 N 5210.84 E 6012860.51 N 561692.90 E 1.505 5758.11 8968.69 89.510 36.610 4044.04 4108.24 2789.10 N 5239.40 E 6012899.12 N 561721.16 E 0.404 5804.68 9013.03 89.510 36.220 4044.42 4108.62 2824.78 N 5265.72 E 6012935.00 N 561747.21 E 0.880 5847.80 9073.05 89.820 35.340 4044.77 4108.97 2873.47 N 5300.81 E 6012983.95 N 561781.93 E 1.554 5906.00 9142.00 89.820 35.340 4044.99 4109.19 2929.72 N 5340.69 E 6013040.50 N 561821.39 E 0.000 5972.73 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPH-13. Northings and Eastings are relative to MPH-13. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from MPH-13 and calculated along an Azimuth of 49.920° (True). Magnetic Declination at Surface is 25.736°(02-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 9142.0Oft., The Bottom Hole Displacement is 6091.49ft., in the Direction of 61.252° (True). .~ 30 September, 2002 - 14:22 Page 4 of 5 DrillQuest 3.03.02.002 Milne Point Unit Comments Measured Depth (ft) 3814.31 3880.00 9142.00 Sperry-Sun Drilling Services Survey Report for Milne Point MPH - MPH-13A MWD Your Ref: AP/500292281801 Job No. AKMW22149, Surveyed: 9 September, 2002 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2884.68 2908.05 4109.19 268.29 S 292.14 S 2929.72 N Comment 1930.37 E 1986.93 E 5340.69 E Tie On Point Window Point Projected Survey .~ Survey tool proqram for MPH-13A MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 30 September, 2002 - 14:22 To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 9142.00 4109.19 MWD Magnetic(MPH-13A MWD) ~' Page 5 of 5 DrillQuest 3.03.02.002 ) ~lT~lJŒ (ill TONY KNOWLES, GOVERNOR ATtASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPH-13A BP Exploration (Alaska), Inc. Permit No: 202-167 Surface Location: 2920' NSL, 4142' WEL, Sec. 34, T13N, R10E, UM Bottomhole Location: 677' NSL, 3975' WEL, Sec. 26, T13N, R10E, UM Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, CØh ~~ Camm~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED thisd~day of August, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ItJCA- :tIIL/OL ALASKh )LAND ~~;~g:S~':::;;ON COM¡:JSION -dr <6{,4Z-2- PERMIT TO DRILL 20 MC 25.005 1 a. Type of work [J Drill II Redrill 1 b. Type of well [J Exploratory [J Stratigraphic Test II Development Oil [J Re-Entry [J Deepen [J Service [J Development Gas [J Single Zone [J Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 67' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface 7. Unit or Property Name 2920' NSL, 4142' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3831' NSL, 537' WEL, SEC. 34, T13N, R10E, UM MPH-13A ( At total depth 9. Approximate spud date 677' NSL, 3975' WEL, SEC. 26, T13N, R10E, UM 08/23/02 / Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well / 14. Number of acres in property 15. Proposed depth (MD and TVD) , ADL025906, 1305' MD No Close Approach 2560 9331' MD / 4149' tvd 16. To be completed for deviated wells 17. Anticipated pressure {s, 20 MC 25.035 (e) (2)} Kick Off Depth 3890' MD Maximum Hole Angle 90.16 0 Maximum surface 1390 psig, At total depth (TVD) 3976' I 1788 psig 18. Casin~ Program Specifications Setting Depth Size T9P Botom Hole Casing Weiaht Grade Couplina Lenath MD TVD M.D it~ TVD 8-1/2" 7" 26# L-80 BTC-M 6489' Surface Surface 6~9' 4001' 6-1/8" 4" 2942' 6389' 3901' 9331' 4149' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Cement (include stage data) 264 sx Class 'G' / Gravel Pack Screen Assembly 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9800 feet 7439 feet 3905 feet 2918 feet Length Plugs (measured) CIBP at 3905' (07/02); CIBP at 5902' (07/02); 60 Bbls Cement Plug below CIBP at 59021 (07/02) Junk (measured) Size Cemented MD TVD 80' 6587' 20" 9-5/8" 250 sx Arcticset I (Approx.) 1948 sx PF 'E', 278 sx 'G', 374 sx PF 'C' 112' 6618' 112' 4421' RECEIVE ^ ¡ It:': n P ¡Jon? .r\'>,) ",,' v J t- l't.". Perforation depth: measured None Alaska Oil & Gas Cons. ComcmsslOn Anchorage true vertical 20. Attachments II Filing Fee [J Property Plat [J BOP Sketch [J Diverter Sketch II Drilling Program II Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis [J Seabed Report [J 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 Prepared By Name/Number: Sandra Stewman, 564-4750 21. ~:~:~c;:~:;ti::~~;i~,:;:.an..,fZt£~;:;~1~:;¿Z~;H;¿:V"~ ;,~...~~~..:.......f- 7- ..~ L Permit Number API Number Approval pate See cover letter 20'::>. - / b '? 50- 029-22818-01 $,Id:;;./ó~ for other reauirements Conditions of Approval: Samples Required 0 Ves a No Mud Log Äequired 0 Ves ~ No Hydrogen Sulfide Measures 0 Ves .f8I No Directional Survey Required EVes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other' L:æs f: ß 0 i> E ~ ŠSO(l p!: . . urtglnal SIgned 8~ by order of Approved By G8nmy 0echsIí T~ C.Pq1~~~ß{ ~ ~f e rmmission Form 10-401 Rev. 12-01-85 ì. ¡ Fi ~ 1 mì ¡: t=- \..>l¡\~\.j: ¡ Date J.~ h 52... ~bm¡{í~ Triplicate ) ) MPH-13a Drilling Permit 1. Well PlanSummarv Well Name: MPH-13a I Type of Well (producer or injector): Surface Location: H-13a "NB" Target: H-13a Target (Bottom Hole Location): I Rig: I DOYON 141 I / I Schrader Bluff Single Lateral producer 2919' FSL, 11381 FWL, SEC. 34, T13N, R10E X = 556503.05 Y = 6010070.40 3830' FSL, 47421 FWL, SEC.34, T13N, R10E X =560098.71 Y =6011009.36 Z =4001 TVD/RKB 6761 FSL, 13041 FWL, SEC.26, T13N, R10E X =561920.00 Y =6013150.00 Z = 4149 TVD/RKB I KOP: I 3890' I I TVDrkb (TD) I 4149' I I Operating days to complete: I 20 I I Max. Inc. I 90° I I KBE: I 67' I I I I Estimated Start Date: I 8/23/02 I MDrkb I 9331' I r Well Design (conventional, slim hole, etc.): I Sidetrack single lat Producer I Scope: I Drill and Complete a single lat Producer in the NB sands. 2. Current Well Information 2.1 General Well Name: MPH-13a API Number: Well Type: Current Status: BHP: BHT: MPH-13a Development - Schrader Bluff Sidetrack Single Lat Producer MPH-07 presently P&A'd with plug set at 3905' MD. 1788 psi @ 3976' TVDrkb Top of NB sand. 78°F @ 3976' TVDss Estimated 2.2 Current Mechanical Condition MPH-13a: Doyon 141: Casing: 2.3 Target Estimates Cellar Box above MSL = 37.1 ' KB I MSL = 67' 95/8" 47# @ 6618' MD Estimated Reserves: 2.1 MMBBL Expected Initial Rate: 2000 BOPD Expected 6 month avg: 1000 BOPD Version #1 1/28/2001 ^'~) ) MPH-13a Drilling Permit 3. Drillinf:l Hazards and Continf:lencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill 01 02 03 04 05 Type Tripping Drilling Diverter Accumulator Well Kill Frequency (1) per week, per crew (1) per week, per crew N/A Prior to spud or RWO Prior to drill out, per crew Comments Conducted only inside casing. Either in cased or open hole. DO NOT shut-in well in open hole. N/A Approx. every 30 days, thereafter at convenient times. Prior to drill out the intermediate and production strings. Never carry out this drill when open hole sections are exposed. / 3.2. Hydrates 3.2.1. Hydrates should not pose a problem due to the kick off point being well below the depths at which we see hydrates in the area. 3.3. Kick Tolerance 3.3.1. The 9 5/8" casing is being sidetracked at 3890 MD, 2911' TVD 3.3.2. The Kick Tolerance for the production casing based on the 8.65 psi expected pore pressure is infinite. 3.4. Lost Circulation 3.4.1. H-pad has not been known for lost circulation in the past. 3.4.2. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.5. Unexpected Pressures 3.5.1. It is unlikely there will be unexpected overpressure when drilling to the NB formation. 3.6. Stuck Pipe 3.6.1. Risk of stuck pipe has been minimized due to this well being a sidetrack and already having the majority of the formation behind pipe from the bottom of the UGNU back to surface. 3.6.2. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the M-I mud program must be closely followed. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! /' 3.7. Pad Data Sheet 3.7.1. Please Read the H-Pad Data Sheet thoroughly. 2 3.8. Hydrocarbons ) ^) MPH-13a Drilling Permit 3.8.1. Hydrocarbons will be encountered in the Ugnu and NB intervals. 3.11 Hydrogen Sulfide 3.11.1. MPH Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S / readings: Well H- 1 2 3 4 5 6i 7 Well Type Producer Producer Producer Producer Producer Injector Producer H2S Status Shut In Shut In Shut In <2 <2 Injector <2 Date Taken June 2001 June 2001 Feb 2000 Well H- Well Type H2S Status Date Taken 8 Producer <2 June 2001 9 Producer <2 June 2001 10 Producer <2 June 2001 11 i Injector Injector 12 Producer <2 June 2001 13 Producer <2 June 2001 14 Producer <2 June 2001 4.0 DrillinQ ProQram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut..in for the rig move on and off MPH-13a Close Approach Wells: There are no close approach wells Well Name N/A 4.2. Well Control Expected BHP 1788 psi @ 3976' TVDrkb (estimated) 4.3. Mud Program Cu rrent Status N/A Production Priority N/A Max Exp Surface Pressure 1390 psi / (0.1 psi/ft gas gradient) 8-1/2" Kickoff and Intermediate Mud Properties: Density (ppa) Funnel visc YP HTHP 8.6-9.2/ 50-150 15-40 N/A 6-1/8" Production Hole Mud Properties: OA/OB Density (ppg) Funnel visc YP HTHP 8.6 I 40 - 55 22 - 27 < 10 Precautions N/A BOPE Rating 135/8" 5M Planned BOPE Test Pres. / Rams & Valves: 3500 psi/250 psi Annular: 2500 psi 1250 psi Spud - LSND Freshwater Mud Ph API Filtrate LG Solids 9.0 - 9.5 < 6 < 6.5 KCI-CaC03 FloPro PH API Filtrate LG Solids 8.0 - 8.5 4 - 6 < 12 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 3 ) ~ ) MPH-13a Drilling Permit 4.4. Formation Markers Formation Tops ft MD ft TVDrkb Pore (psi) EMW (ppg) Base Permafrost Top Ugnu / Base Ugnu 6262 3944 1774 8.65 Schrader-NA 6364 3973 1787 8.65 Schrader-NB 6489 4001 1799 8.65 TD 9331 4149 1866 8.65 4.5. CasinglTubing Program / Hole Size Csgl WtlFt Grade Conn Length Top Bottom Tbg O.D. MD 1 TVDrkb MD 1 TVDrkb 81/2" 7" 26# L-80 BTC-M 6489' 0 6489' 1 4001 ' 6 1/8" (OB) 4" G P screens +1-2942' 6389'/3901 9331 '/4149' Tubing 2-7/8" 6.4# L-80 EUE-Mod +1- 6389' 0' 6389'/3901' 4.6. Cement Calculations Casins Size 17" 261b/ft L-80 BTC-M Basis 50% excess Total Cement Volume: Wash 50 bbl Freshwater Spacer 75 bbl of Viscosified Alpha Spacer weighted to 9.2 ppg Tail ~64 sxs (yield=1.15éu.ft.lsk.) 15.8 Ib/gal Class G + additives (with 50% excess) Estimated Top of Cement @ 4890' MD./ Temp I BHST == 78° F , BHCT 65° F 4.7. Survey and Logging Program 8 1/2" Hole Section: Open Hole: MWD 1 DIR 1 GR 1 Res 6-1/8" Hole Section: Open Hole: DIRlGRlRes/lAB Res placed as close to bit as possible. Cased Hole: None 4 ) -) MPH-13a Drilling Permit 5. MPH-13a Operations Summary 5.1. Procedure / 1. MIRU, NU BOPE on wellhead, PU 3 1/2" drill pipe 2. MU whipstock assembly, RIH and set at +1-3890' MD 3. Mill window out of 9 5/8" casing, POOH 4. MU 6 3,4" drilling BHA, RIH / 5. Drill 8 1/2" Intermediate hole as per directional plan and drill to 6489' MD/4001' TVD. 6. Condition mud and POOH /' 7. Run and cement T' casing from TD to surface. 8. MU 43,4" drilling assembly, RIH and change over to MI Drill-in fluid ,- 9. Test casing to 3500 psi, Drill out float equipment and 30' of new hole and perform a FIT to 11.0 ppg 10. Drill 6-1/8" NB lateral geosteering and short tripping as required. Maintain FloPro mud properties. 11. Displace NB lateral with clean FloPro mud /' 12. POOH laying down 3 1/2" drill pipe 13. Run 4" Gravel Pack screens ,,/ 14. Run in hole with 2 %" ESP completion 15. Land tubing hanger 16. Set tubing plug and BPV 17. ND BOP 18. Install and test tree 19. Pull tubing plug and SPV 20. Freeze protect the tubing and annulus ./ 21. Freeze protect the 9-5/8" x 7" annulus 22. Install BPV and secure the well 23. RD/MO 5 Tree: Cameron 2 9/16" 5M (,''''0 U H 1 3 C rre nt W-;¡jh"ead: 11" x 11" 5M FMC Gen 6, r' - U wI 11" x 27/8" FMC tbg. hng., 2 7/8"-~ EUE NSCT T&S, 2.5" CIW SPV profile 20" 91.1 ppf, H-40 112' I KOP @ 400' Max. hole angle = 68 to 40 deg. fl 3100' - 4900' Hole angle thru' perfs = 39 deg. 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. (drift 10 = 2.347", cap. = 0.00592 bpf) 95/840 ppf, L-80, STC mod prod. csg. ( drift 10 = 8.835", cap. = 0.0758 bpf ) Stimulation Summary 05/31/98 - 'OS' Sand PropLok frac, 72.5 M# 12-20 Ottawa sand behind pipe 06/02/98 - "OA' Sand PropLok frac, 17.8 M# 12-20 Ottawa sand behind pipe 06/07/98 - 'N' Sand Frac Pack, 75.0 M# 16/20 Carbolite behind pipe Perforation Summary Ref log: 5/31/98 Atlas GRlCCL Size SPF Interval (TVD) 'N'Sand' 4.5 12 6082' - 6102' 4002' - 4017' 'OA' Sand' 4.5 4 6246' - 6266' 4128' - 4144' 'OS' Sand' 4.5 4 6324' - 6344' 4189' - 4204' Jumbo Jet ("big hole") charges @ 0 - 180 deg. phasing on 'OA' and 'OS' sands Jumbo Jet ("big hole") charges @ 45/135 deg. phasing on 'N' sand DATE REV. BY 10-22-97 MDO 06/09/98 JSF 7/16/2002 RSO COMMENTS Nabors 22-E . Diesel ') Orig. OF Elev. = 66.0' (N 22E) " Orig. GL Elev. = 36.7' Orig. OF to csg. hgr. = 30.62' (N 22E) 0 Howco 7" "ES" Cementer 12113' MO I 9.0 PPG KCL ---- 9.0 PPG KCL , , .. '. .... 2200' MD Cast Iron Bridge Plug 13905' MD, 2914' TVD I Cast Iron Bridge Plug 15902' MD, 3862' TVD / ":':", .. 60 bbbls of Class "G" Cement 9 5/8" HES Versatrieve pkr. 16024' md 1 Closing sleeve ass'bly 4.5", 12.6 ppf, N-80, NU blank pipe (10 = 3.958") 4.5", 0.020" Ga. pre-pack ~ screen (10 =3.958") HES seal unit (10 = 3.880") 4.5" 'XN' npl. (3.813" no go) 9 5/8" HES 'SWO' sump pkr. 9 5/8" HES EZSV retainer WI 2 Sbls cement above 9 51B' landing collar 9 51B' float collar \.-f 9 51B' float shoe Open hole Cement plug 9,800' - 8,682' Well TO @ 9.800' 16076' md I 16106' md I 6108' md 6112' md 6107' wlm 6538' md 6,532' md 6,575' md 6,618' md Initial ESP Completion by Nabors 4ES H-13 Proposed MILNE POINT UNIT WELL No : H-13i API: 50-029-22818 , , ~ f . , I r;j~¡>r1}'~;.¡::!:j;~ ¡ BP EXPLORATION (AK) Tree: Cameron 2 9/16" 5Mf'-"P' U H 13 P r") Wellhead: 11" X 11" 5M FMC Gen 5, _.Ii - a roposec ,,', wi 11" x 27/8" FMC tbg. hng., 27/8" EUE NSCT T&S, 2.5" CIW SPV profile 20" 91.1 ppf, H-40 112' I KOP @ 400' Max. hole angle = 68 to 40 deg. fl 3100' - 4900' Hole angle thru' perfs = 39 deg. ~ ... Orig. OF Elev. = 66.0' (N 22E) Orig. GL Elev. = 36.7' Orig. OF to csg. hgr. = 30.62' (N 22E) 0 Howco 7" "ES" Cementer 12113' MO I Cast Iron Bridge Plug whipstock I 3905' MD, 2914' TVD I ----- 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. (drift 10 = 2.347", cap. = 0.00592 bpf ) 9 5/840 ppf, L-80, STC mod prod. csg. ( drift 10 = 8.835", cap. = 0.0758 bpf ) Stimulation Summary 05/31/98 - 'OS' Sand PropLok frac, 72.5 M# 12-20 Ottawa sand behind pipe 06/02/98 - 'OA' Sand PropLok frac, 17.8 M# 12-20 Ottawa sand behind pipe 06/07/98 - 'N' Sand Frac Pack, 75.0 M# 16/20 Carbolite behind pipe Perforation Summary Ref log: 5/31/98 Atlas GRlCCL Size SPF Interval (TVD) 'N' Sand' 4.5 12 6082' - 6102' 4002' - 4017' 'OA' Sand' 4.5 4 6246' - 6266' 4128' - 4144' 'OS' Sand' 4.5 4 6324' - 6344' 4189' - 4204' Jumbo Jet ("big hole") charges @ 0 - 180 deg. phasing on 'OA' and 'OS' sands Jumbo Jet ("big hole") charges @ 45/135 deg. phasing on 'N' sand DATE REV. BY 10-22-97 MDO 06/09/98 JSF 7/16/2002 RSO COMMENTS Nabors 22-E 9.0 PPG KCL ~ , " ~ !;'. 'j,;;; ,;':":';'~' ! g'::f::,~~~:~~:~~'( ¡ 4" Gravel Pack Screen @ 9331' MD, 4149' TVD Cast Iron Bridge Plug 15902' MD, 3862' TVD ",'" . ,/ 60 bbbls of Class "G" Cement 9 5/8" HES Versatrieve pkr.16024' md I Closing sleeve ass'bly 4.5", 12.6 ppf, N-80, NU blank pipe (10 = 3.958") 16076' md I 4.5", 0.020" Ga. pre-pack H screen (10 =3.958") HES seal unit (10 = 3.880") 4.5" 'XN' npl. (3.813" no go) 9 5/8" HES 'SWO' sump pkr. 16106' md ] 6108' md 6112' md 6107' wlm 9 5/8" HES EZSV retainer WI 2 Sbls cement above 9 5/8' landing collar U 9 5/8' float collar 9 5/8' float shoe Open hole Cement plug 9,800' - 8,682' Well TO @ 9.800' 6538' md 6,532' md 6,575' md 6,618' md Initial ESP Completion by Nabors 4ES H-13 Proposed MILNE POINT UNIT WELL No : H-13i API : 50-029-22818 BP EXPLORATION (AK) End Dir : 5912.18' MO, 3818.12' TVD Start Dir4/100': 6137.33' MO, 390L76'TVD Start Dir 5/100' : 6539.53' MD, 4008.3'TVD ~ I End Dir : 6842.18' MD, 4021.15' TVD \'1805 &0. I Start Dir 3/100': 6909.94' MD, 4020.96'TVD 6000 .<::! ß I End Dir : 7233.43' MO, 4029.74' TVD BU&11u o-i!J: ~ I I 0 Stir2-NA - ~ 00 I gg SRF!-N~ ' /I ~~M ~" 'I . J.. 2/10)': 6<-89.3 MD 400 .3'TVD ö REFERENCE INFORMATION COMPANY DETAILS HP Amoco Co.ordinate (NiB) Reference: Well Centre: MPH-13, True North Vertical (lVD) Reference: 6430' 6430 Section (VS) Reference: Slot - 13 (O.OON,O.OOE) Measured Depth Reference: 6430' 6430 Calculation Method: MinimtUn Curvature Cakulati,)ß Method: Minimum ('urvature ~~~l;; ~~~~~~ ~~~~~~~Irl:r North Error Surface: Elliptknl t Casing Warnin~ Mcdl0d: Rules Based CASING DETAILS No. TVD MD Size Name 4001.30 6489.30 7" 4149.30 9331.70 41/2" 7.000 4.500 All TVD depths are ssTVD plus 64.3'forRKBE. FORMATION TOP DETAILS No, TVDPath MDPath Fonnation 1 3859.30 6023.03 M80S 2 3944.30 6262.17 BUgnu 3 3973.30 6364.48 SBF2-NA 4 4001.30 6489.30 SBFI-NB 2400- Start Dir 12/100': 3890' MD, 291 1.59'TVD Start Dir4.4/l00': 3910' MD, 2918.48'TVD É 3000 42 0 0 ~ -5 P- o ~ 1:: > 2 f-< 3600 '0".', " ----~ ___-400 \ \ \\ \ \ \ \ , 1~\Dir I 800C I Sta t Dir 3/100' : 8(27.58' MD, 40l4.14'fVD Lnd Dir : 84:0.34' MO, 408(..3' T/D Total Depth: 9331.71' MD,4149.3' TVD k \, -we.o ~' 41/2" 4200 1800 2400 3000 3600 4200 Vertical Section at 60.82° [600ft/in] SURVEY PROGRAM Plan: MPH-13a wp06 (MPH-13/P1anMPH-13a) Depth Fm Depth To SUlveyiPlan 3890.00 9331.71 Planned: MPH-13a wp06 V4 Tool Crealed By: Ken Allen Checked: ------- Date: 712512002 MWD+IFR+MS Date: Reviewed: Date: WELL DETAILS Name +NI-S +Eí-W Northing Basting Latitude Longitude Slot MPH-13 1090.41 110637 6010070.40 556503.05 70'26'17.388N 149'32'21.422W 13 TARGET DETAILS Name TVD +N/-S +-EJ-W Northing Eastillg Shape MPH-l3a Tl 400830 947.29 3619.58 6011045.00 560115.00 Point MPH-13a T2 4021.30 1290.57 385221 6011390.00 560345.00 Point MPH-13a T3 4086.30 2307.76 4900.05 6012415.00 561385.00 Point MPH-13a Polygon 4086.30 320422 5381.90 6013315.00 561860.00 Polygon MPH-13a T4 414930 3038.76 5440.66 6013150.00 561920.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I '~'''I.OO 69.73 114.28 2911.59 -295.93 1995.41 /'0.00 0.00 1597_80 2 "'111.00 69.96 111.73 2918.48 -303.27 2012.69 12.00 -85,00 1609.30 3 ,''1-'..18 68.19 15.54 3818.12 385.28 3425.20 4.40 .112.55 3178_26 4 '.1 \ 7.33 68.19 15.54 3901.76 586.67 3481.20 .-r1,00 0.00 3325.35 5 -,,~:".30 78.97 25.00 4001.30 902.23 3598.57 4.00 41.54 3581.70 6 '.', ").53 85.00 25.00 4008.30 947.29 3619.58 12.00 0.00 3622.01 MPH-13a Tl 7 ,.:'>~ _~.18 90.16 39.24 4021.15 1202.60 3779.96 5.00 70.48 3886.52 ~ 8 ''''''''.94 90.16 39.24 4020.96 1255.08 3822.83 0.00 0.00 3949.54 9 ''''''';.03 89.00 40.00 4021.30 1290.57 3852.21 3.00 146,85 3992.50 MPH-13a T2 10 7; \ \.43 87.52 48.19 4029.74 1489.54 4044.99 3,00 100.37 4257.83 II ~"-' 7.58 87.52 48.19 4064.14 2018.43 4636.38 0.00 0.00 5032.05 12 ,.-'1 :'1.34 86.04 36.48 4086.30 2307.76 4900.05 3.00 -97.53 5403.33 MPH-13a T3 13 "_1 11.71 86.04 36.48 4149.30 3038.76 5440.66 0.00 0.00 6231. 76 MPH-13a T4 , .~ .~/ - .". -'~ - , ", .~ 4800 6000 5400 d COMPANY DETAII.S HI' Amoco Calculation Method: Minimum ('urvatu{{: l~rr1Jr SyslclI1: ISCWSA Scan Method: Tmv Cylinœr North Error Surface: Elliptical;- Casing W8l11in~ Method: Rules Based 2700 1800 ~ 4:: 0 0 ~ +' ~ ~ ::<: ;:; 0 CIJ 900 '- REFERENCE INFORMATION SURVEY PROGRAM Plan: MPH-13a wp06 (MPH - I3/Plan MPH- I3a) Co-ordinate (NÆ¡ Reference: Well Centre: MPH-13. True North Vertical (1VD) Reference: 64.30' 6430 Section (VS) Reference: Slot - 13 (O.ooN.O.ooE) Measured Deplh Reference: 64.30' 64.30 Calculation Method: Minimwn Curvature Depth Fm Depth To Survey/Plan 3890.00 933L71 Planned: MPH-13a "'1'06 V4 Tool MWD+IFR"MS Date: ~------ Date: 7/25/2002 Created By: Ken Allen Checked: --~----- Reviewed: -------- Date: WELL DETAILS Name +Nf~S Easting Longitude Slot Latitude +FJ-W Northing MPH-13 1090.41 110637 6010070.40 556503.05 70'26'17.388N 149'32'2L422W 13 Name 1VD eN/oS +E!-W Northing Easting Shape MPH-13a Tl 4008.30 94729 3619.58 6011045.oo 560115.00 Point MPH-13a T2 402130 1290.57 385211 6011390.00 560345.00 Point MPH-13a T3 4086.30 2307.76 4900.05 6012415.00 561385.00 Point MPH-13a Polygon 408630 320422 5381.90 6013315.00 561860.00 Polygon MPH-13a T4 414930 3038.76 5440.66 6013150.00 561920.00 Point TARGET DETAILS All TVD depths are ssTVD plus 64.3'for RKBE. SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target I "'''1.00 69.73 114.28 2911.59 -295.93 1995.41 0.00 0.00 1597.80 2 "'111.00 69.96 111.73 2918.48 -303.27 2012.69 12.00 -85.00 1609.30 3 "'I_~.18 68.19 15.54 3818.12 385.28 3425.20 4.40 -112.55 3178.26 4 '.1 ,7.33 68.19 15.54 3901.76 586.67 3481.20 0.00 0.00 3325.35 5 ,.~,,'1.30 78.97 25.00 4001.30 902.23 3598.57 4.00 41.54 3581.70 MPH-13a Tl '~ 6 ,., "¡.53 85.00 25.00 4008.30 947.29 3619.58 12.00 0.00 3622.01 7 ,.!\~ ~..18 90.16 39.24 4021.15 1202.60 3779.96 5.00 70.48 3886.52 8 '''''''¡.94 90.16 39.24 4020.96 1255.08 3822,83 0.00 0.00 3949.54 9 '''''';.03 89.00 40.00 4021.30 1290.57 3852.21 3.00 146.85 3992.50 MPH-13a T2 10 ): '\.43 87.52 48.19 4029.74 1489.54 4044.99 3.00 100.37 4257.83 11 SII: 7.58 87.52 48.19 4064.14 2018.43 4636.38 0.00 0.00 5032.05 12 ~-I:".34 86.04 36.48 4086.30 2307.76 4900.05 3.00 -97.53 5403.33 MPH -13a T3 13 "" 1.71 86.04 36.48 4149.30 3038.76 5440.66 0.00 0.00 6231.76 MPH-13a T4 Total Depth: 9331.71' MD, 4149.3' TVD 41/2" :\1PH-13a wp06 cnd UI- : !!42U. :14' MJ, &.U~ó.jI TVL ~PH_13'T4 CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Formation 4001.30 6489.30 7" 7.000 I 3859.30 6023.03 M80S 4149.30 9331.70 4 1/2" 4.500 2 3944.30 6262.17 BUgnu 3 3973.30 6364.48 SBF2-NA 4 4001.30 6489.30 SBFI-NB ~-' Stut :Jir 3f 00' : 8027.58' MD, 4064.14'TVD M>HI~~ MP 1- 3, TI / // œ", D;- ,68'2.\8' M', -1011.\5' TV\) Stur! Dir 5/1 JO' : 6'53?53' MD. 4C'08.3'TVD 7" J-pStart Dir 2/ OC: M~9.~' tvD, 400 13'TVD 4( OC --. St~rt)ir 4/ Oo. : 6137.33' MI:', 3901.7f'TVD EnJ [Jir : 5:)12.18' MD. 3818 12 TVD S:arl Dr 12/100': 3890' MD 2911.~TVD : ~,rt ¡y" 4.' /1(" 3\10 M D, 29"8.48--V 0 ----~~ - -~---_._~.,.- --~_._- -'~--.-.:::: 0 -900 1800 2700 :p¡I~-(:;'ì:l3k 3600 4500 W est( - )/East( +) [900ft/in] "., " -' ... ~ "'II:> 4i" , '" ~ MP'-!-' 3 (M->H-13) I I I I I I I I 6300 5400 ) BP My Planning Report MAP Company: BPAnioco Field: Milne Point Site: M Pt H Pad Well: MPH.,13 Wellpath: Plan. MPH.,13a ) Date: 7/25/2002 Time: 11 :09:01 Co,:,ol'diiiate(NE) Reference: Well: MPHë 13, . True North Vertical (TVD) Reference: 64.30'64~3 Seetion{VS}Referen.:e: W~II (0.00N;0.(}OE,60.82Azi) Survey Calculation Method: Minimum Curvature Db: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: M Pt H Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 6008971.91 ft 555404.91 ft Latitude: Longitude: North Reference: Grid Convergence: MPH-13 MPH-13 Well Position: +N/-S 1090.41 ft +E/-W 1106.37 ft Position Uncertainty: 0.00 ft Well: Slot Name: Northing: 6010070.40 ft Easting: 556503.05 ft Latitude: Longitude: Wellpath: Plan MPH-13a Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 64.30' 5/8/2002 57493 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 64.30 ft Plan: MPH-13a wp06 Date Composed: Version: Tied-to: Principal: Yes Casing Points Page: Oracle Alaska, Zone 4 Well Centre BGGM2002 70 26 6.665 N 149 32 53.895 W True 0.43 deg 13 70 26 17.388 N 149 32 21.422 W MPH-13 3890.00 ft Mean Sea Level 25.85 deg 80.80 deg Direction deg 60.82 7/25/2002 5 From: Definitive Path MD TVD Diameter Hole Size Name ft ft in in 6489.30 4001.30 7.000 8.500 7" 9331.70 4149.30 4.500 6.125 41/2" Formations Formations Lithology Dip Angle Dip Direction ft deg deg 0.00 BPRF 0.00 0.00 6023.03 3859.30 M80S 0.00 0.00 6262.17 3944.30 BUgnu 0.00 0.00 6364.48 3973.30 SBF2-NA 0.00 0.00 6489.30 4001.30 SBF1-NB 0.00 0.00 Targets Map Map <--. . Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min' See Deg Min See Dip. Dir. ft ft ft ft ft MPH-13a T1 4008.30 947.29 3619.58 6011045.00 560115.00 70 26 26.696 N 149 30 35.172 W MPH-13a T2 4021.30 1290.57 3852.21 6011390.00 560345.00 70 26 30.071 N 149 30 28.338 W MPH-13a T3 4086.30 2307.76 4900.05 6012415.00 561385.00 70 26 40.069 N 149 29 57.559 W M PH-13a Polygon 4086.30 3204.22 5381.90 6013315.00 561860.00 70 26 48.882 N 149 29 43.393 W -Polygon 1 4086.30 3204.22 5381.90 6013315.00 561860.00 70 26 48.882 N 149 29 43.393 W -Polygon 2 4086.30 2537,89 4886.79 6012645.00 561370.00 70 26 42.332 N 149 29 57.943 W -Polygon 3 4086.30 1069.12 3380.47 6011165.00 559875.00 70 26 27.895 N 149 30 42.189 W -Polygon 4 4086.30 839.10 3378.73 6010935.00 559875.00 70 26 25.633 N 149 30 42.244 W ) BP My Planning Report MAP ) Company: BPAtnoco Field: Mitne P6int Site: MPtHPad Well: MPH..13 We'.path: Plan MPH-13a Targets Date: 7/25/2002 Time: 11 :09:01 Co~rdinát~NErReferençe: Well:' MPH~t3. True North Vêrtieal(TV])rRefê~Dce: 64.30'64,3 . See~ion(VS)~ference: WeU {Q~00N,0..OOE,60.82Azi) Survey CâkulatioÏ1M~tbod: MinimÍJmCurvature Db: Oracle Page: 2 Map. Map. <.;-;.. . Làtitude . --...:> <-...,Longitude --> Name De~riptiöÏ1 TVD +N/;;S +E/-W Northing . Easting . Deg' MiD $ee Deg . Min'.' "See Dip. Dir. ft ft ft ft ft -Polygon 5 4086.30 651.59 3707.35 6010750.00 560205.00 70 26 23.787 N 149 30 32.600 W -Polygon 6 4086.30 901.53 3719.25 6011000.00 560215.01 70 26 26.246 N 149 30 32.247 W -Polygon 7 4086.30 2320.56 5190.18 6012430.00 561675.00 70 26 40.193 N 149 2949.040 W -Polygon 8 4086.30 3036.71 5710.67 6013150.00 562190.00 70 26 47.232 N 149 29 33.743 W MPH-13a T4 4149.30 3038.76 5440.66 6013150.00 561920.00 70 26 47.254 N 1492941.671 W Plan Section Information MD lucl Azim TVD +N/-S +]J;/;;W DLS Build Turn TFO Target ft deg dèg ft ft ft deg/10OO deg/100ft . degl1 OOft deg 3890.00 69.73 114.28 2911.59 -295.93 1995.41 0.00 0.00 0.00 0.00 3910.00 69.96 111.73 2918.48 -303.27 2012.69 12.00 1.14 -12.73 -85.00 5912.18 68.19 15.54 3818.12 385.28 3425.20 4.40 -0.09 -4.80 -112.55 6137.33 68.19 15.54 3901.76 586.67 3481.20 0.00 0.00 0.00 0.00 6489.30 78.97 25.00 4001.30 902.23 3598.57 4.00 3.06 2.69 41.54 6539.53 85.00 25.00 4008.30 947.29 3619.58 12.00 12.00 0.00 0.00 MPH-13a T1 6842.18 90.16 39.24 4021.15 1202.60 3779.96 5.00 1.70 4.71 70.48 6909.94 90.16 39.24 4020.96 1255.08 3822.83 0.00 0.00 0.00 0.00 6956.03 89.00 40.00 4021.30 1290.57 3852.21 3.00 -2.51 1.64 146.85 MPH-13a T2 7233.43 87.52 48.19 4029.74 1489.54 4044.99 3.00 -0.53 2.95 100.37 8027.58 87.52 48.19 4064.14 2018.43 4636.38 0.00 0.00 0.00 0.00 8420.34 86.04 36.48 4086.30 2307.76 4900.05 3.00 -0.38 -2.98 -97.53 MPH-13a T3 9331.71 86.04 36.48 4149.30 3038.76 5440.66 0.00 0.00 0.00 0.00 MPH-13a T4 Survey MD Iud Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 3890.00 69.73 114.28 2911.59 2847.29 6009789.63 558500.45 1597.80 0.00 Start Dir 12/100' : 3890' MD, 3900.00 69.84 113.01 2915.04 2850.74 6009785.93 558509.07 1603.47 12.00 MWD+IFR+MS 3910.00 69.96 111.73 2918.48 2854.18 6009782.42 558517.78 1609.30 12.00 Start Dir 4.4/100' : 3910' MD, 4000.00 68.48 107.80 2950.42 2886.12 6009754.56 558597.15 1664.53 4.40 MWD+IFR+MS 4100.00 66.95 103.34 2988.35 2924.05 6009730.39 558686.42 1730.20 4.40 MWD+IFR+MS 4200.00 65.55 98.79 3028.64 2964.34 6009713.49 558776.34 1800.03 4.40 MWD+IFR+MS 4300.00 64.29 94.13 3071.04 3006.74 6009703.97 558866.37 1873.59 4.40 MWD+IFR+MS 4400.00 63.18 89.38 3115.31 3051.01 6009701.88 558955.97 1950.47 4.40 MWD+IFR+MS 4500.00 62.23 84.55 3161.19 3096.89 6009707.24 559044.63 2030.20 4.40 MWD+IFR+MS 4600.00 61.46 79.64 3208.40 3144.10 6009720.01 559131.82 2112.31 4.40 MWD+IFR+MS 4700.00 60.86 74.66 3256.66 3192.36 6009740.12 559217.02 2196.33 4.40 MWD+IFR+MS 4800.00 60.44 69.63 3305.70 3241.40 6009767.45 559299.74 2281.75 4.40 MWD+IFR+MS 4900.00 60.22 64.57 3355.22 3290.92 6009801.84 559379.48 2368.08 4.40 MWD+IFR+MS 5000.00 60.19 59.50 3404.93 3340.63 6009843.09 559455.78 2454.80 4.40 MWD+IFR+MS 5100.00 60.36 54.44 3454.54 3390.24 6009890.94 559528.18 2541.40 4.40 MWD+IFR+MS 5200.00 60.71 49.40 3503.76 3439.46 6009945.13 559596.26 2627.38 4.40 MWD+IFR+MS 5300.00 61.25 44.41 3552.29 3487.99 6010005.33 559659.62 2712.22 4.40 MWD+IFR+MS 5400.00 61.98 39.48 3599.85 3535.55 6010071.18 559717.89 2795.43 4.40 MWD+IFR+MS 5500.00 62.88 34.62 3646.16 3581.86 6010142.31 559770.71 2876.51 4.40 MWD+IFR+MS 5600.00 63.94 29.84 3690.95 3626.65 6010218.28 559817.78 2954.98 4.40 MWD+IFR+MS 5700.00 65.15 25.16 3733.95 3669.65 6010298.65 559858.83 3030.40 4.40 MWD+IFR+MS 5800.00 66.51 20.57 3774.90 3710.60 6010382.96 559893.61 3102.30 4.40 MWD+IFR+MS 5900.00 68.00 16.08 3813.58 3749.28 6010470.69 559921.91 3170.27 4.40 MWD+IFR+MS 5912.18 68.19 15.54 3818.12 3753.82 6010481.59 559924.90 3178.26 4.40 End Dir : 5912.18' MD, 3818.1 6000.00 68.19 15.54 3850.74 3786.44 6010560.29 559946.15 3235.63 0.00 MWD+IFR+MS 6023.03 68.19 15.54 3859.30 3795.00 6010580.93 559951.72 3250.68 0.00 M80S 6100.00 68.19 15.54 3887.89 3823.59 6010649.92 559970.34 3300.97 0.00 MWD+IFR+MS 6137.33 68.19 15.54 3901.76 3837.46 6010683.38 559979.37 3325.35 0.00 Start Dir 4/100' : 6137.33' MD ) BP ) My Planning Report MAP qo~ïnîny: BPAmocò :natê:: ".7/25/20Q2 'fiØte:.<tt;09:0~ Page: Field: Milnec' Point Ç04)r'din~~)~~fmin~:. W~lt:MPH;.l3.TrUèNbrth Site: MPtH'Pí;1c!' YêrijC#tl(W~)'.Rêf~~Ìl(e~ 64:30'64~3 WeD: MPH~ 13 ~~o~:(Y~)'tlef~~Ìl~~': W~II; (O:oq~(p:OOE~60,82A?i) Wellp~~b: PlariMPH:':13a .Sutyey .ç~c..lþti~IlMetb9d: Minimum: Curvature Db: Survey MD Incl Aihn TV» SYSl'VD ~~pN Må,pE VS DLS ft deg c!èg ft ft .ft ft ft deg/tOQft 6200.00 70.08 17.31 3924.08 3859.78 6010739.66 559995.51 3367.20 4.00 MWD+IFR+MS 6262.17 71.97 19.02 3944.30 3880.00 6010795.65 560013.41 3410.44 4.00 BUgnu 6300.00 73.12 20.04 3955.65 3891.35 6010829.74 560025.22 3437.56 4.00 MWD+IFR+MS 6364.48 75.10 21.76 3973.30 3909.00 6010887.83 560046.91 3485.13 4.00 SBF2-NA 6400.00 76.20 22.69 3982.10 3917.80 6010919.78 560059.68 3512.03 4.00 MWD+IFR+MS - 6489.30 78.97 25.00 4001.30 3937.00 6010999.78 560094.33 3581.70 4.00 7" 6500.00 80.26 25.00 4003.23 3938.93 6011009.36 560098.71 3590.23 12.00 MWD+IFR+MS 6525.00 83.26 25.00 4006.81 3942.51 6011031.85 560108.99 3610.29 12.00 MWD+IFR+MS 6539.53 85.00 25.00 4008.30 3944.00 6011045.00 560115.00 3622.01 12.00 MPH-13a T1 6600.00 86.02 27.86 4013.04 3948.74 6011099.17 560141.42 3671.76 5.00 MWD+IFR+MS 6700.00 87.72 32.57 4018.51 3954.21 6011185.80 560190.99 3757.67 5.00 MWD+IFR+MS 6800.00 89.43 37.26 4021.00 3956.70 6011268.17 560247.56 3847.57 5.00 MWD+IFR+MS 6842.18 90.16 39.24 4021.15 3956.85 6011301.48 560273.42 3886.52 5.00 End Dir : 6842.18' MD, 4021.1 6909.94 90.16 39.24 4020.96 3956.66 6011354.28 560315.89 3949.54 0.00 Start Dir 3/100' : 6909.94' MD 6956.03 89.00 40.00 4021.30 3957.00 6011390.00 560345.00 3992.50 3.00 MPH-13a T2 7000.00 88.76 41.30 4022.16 3957.86 6011423.57 560373.38 4033.77 3.00 MWD+IFR+MS 7100.00 88.23 44.25 4024.79 3960.49 6011497.44 560440.70 4128.81 3.00 MWD+IFR+MS 7200.00 87.69 47.20 4028.35 3964.05 6011567.73 560511.71 4225.29 3.00 MWD+IFR+MS 7233.43 87.52 48.19 4029.74 3965.44 6011590.40 560536.24 4257.83 3.00 End Dir : 7233.43' MD, 4029.7 7300.00 87.52 48.19 4032.63 3968.33 6011635.10 560585.4 7 4322.72 0.00 MWD+IFR+MS 7400.00 87.52 48.19 4036.96 3972.66 6011702.25 560659.43 4420.21 0.00 MWD+IFR+MS 7500.00 87.52 48.19 4041.29 3976.99 6011769.41 560733.39 4517.70 0.00 MWD+IFR+MS 7600.00 87.52 48.19 4045.62 3981.32 6011836.57 560807.34 4615.20 0.00 MWD+IFR+MS 7700.00 87.52 48.19 4049.95 3985.65 6011903.72 560881.30 4712.69 0.00 MWD+IFR+MS 7800.00 87.52 48.19 4054.28 3989.98 6011970.88 560955.25 4810.18 0.00 MWD+IFR+MS 7900.00 87.52 48.19 4058.61 3994.31 6012038.03 561029.21 4907.67 0.00 MWD+IFR+MS 8000.00 87.52 48.19 4062.95 3998.65 6012105.19 561103.16 5005.16 0.00 MWD+IFR+MS 8027.58 87.52 48.19 4064.14 3999.84 6012123.71 561123.56 5032.05 0.00 Start Dir 3/100' : 8027.58' MD 8100.00 87.23 46.04 4067.46 4003.16 6012173.33 561176.19 5102.33 3.00 MWD+IFR+MS 8200.00 86.85 43.06 4072.62 4008.32 6012245.02 561245.69 5198.19 3.00 MWD+IFR+MS 8300.00 86.48 40.08 4078.44 4014.14 6012320.19 561311.34 5292.43 3.00 MWD+IFR+MS 8400.00 86.11 37.09 4084.91 4020.61 6012398.65 561372.97 5384.79 3.00 MWD+IFR+MS 8420.34 86.04 36.48 4086.30 4022.00 6012415.00 561385.00 5403.33 3.00 MPH-13a T3 8500.00 86.04 36.48 4091.81 4027.51 6012479.24 561431.76 5475.74 0.00 MWD+IFR+MS 8600.00 86.04 36.48 4098.72 4034.42 6012559.89 561490.47 5566.64 0.00 MWD+IFR+MS 8700.00 86.04 36.48 4105.63 4041.33 6012640.54 561549.17 5657.54 0.00 MWD+IFR+MS 8800.00 86.04 36.48 4112.54 4048.24 6012721.18 561607.87 5748.44 0.00 MWD+IFR+MS 8900.00 86.04 36.48 4119.46 4055.16 6012801.83 561666.58 5839.34 0.00 MWD+IFR+MS 9000.00 86.04 36.48 4126.37 4062.07 6012882.48 561725.28 5930.24 0.00 MWD+IFR+MS 9100.00 86.04 36.48 4133.28 4068.98 6012963.13 561783.98 6021.14 0.00 MWD+IFR+MS 9200.00 86.04 36.48 4140.20 4075.90 6013043.78 561842.69 6112.04 0.00 MWD+IFR+MS 9300.00 86.04 36.48 4147.11 4082.81 6013124.43 561901.39 6202.94 0.00 MWD+IFR+MS 9331.69 86.04 36.48 4149.30 4085.00 6013149.99 561919.99 6231.74 0.00 41/2" 9331.71 86.04 36.48 4149.30 4085.00 6013150.00 561920.00 6231.76 0.00 MPH-13a T4 Nan).: MI'II-ll 1090.41 ¡ 106.17 -128 -120 -100 -80 --60 -40 -20 -0 270 --20 -40 --60 -80 -100 -120 -128 WIT/. DF.1AILS COMPANY DETAILS ANTI-COLLISION SETTINGS 'NI-S '¡'I-W Latitude Longitude Slot BP Amoco Nnrthing. blsting Interpolation MethodMD Interval: 25.00 Depth Range From: 3890.00 To: 9331.71 Maximum Range: I 130AI Reference: Plan: MPH-13a wp06 Calculation Method: Minimwn Curvature Error System: ISCWSA Scan Method: Tmv Cylinder North Error Surface: Elliptical + Casing Warning Method: Rules Based 601 (X)70.40 556>Cß.05 70026'17.188N 149"12'2L422W 13 0 TrCivetIing From 0 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 0 6000 8000 11000 12000 -.. SURVEY PROGRAM Depth Fm Depth To SurveyiPlan 1890.00 9111.71 Plmmed: MPH-l1a vip06 V4 To01 MWD+IFR+MS WELLPA TH DETAILS Colour Plan MPH-13a ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 6000 8000 11000 12000 15000 Parent Welipath: Tie on MD: MPH-11 1890.00 Rig: Ref. Datum: 64.10' 64.10ft V.Section Angle 60.82" Origin +N/-S Origin +E/-W Starting From lVD 0.00 0.00 0.00 LEGEND - MPG-09 (MPG-09), M~ior Risk - MPH-02 (MPH-02), Major Risk - MPH-03 (MPH-03), Major Risk - MPH-12 (MPH-12), Major Risk - MPH-13 (MPH-13), NOERRORS ~ MPH-14(MPH-14),MajorRisk - PlanMPH-13a - MPH-13a wp06 -...--'" 90 ~' SECTION DETAILS Sec MD Inc Azi TVD +N/-S +FJ-W DLeg TFace VSec Target 1 3890.00 69.73 114.28 2911.59 -295.93 1995.41 0.00 0.00 1597.80 2 3910.00 69.96 11 1.73 2918.48 -303.27 2012.69 12.00 -85.00 1609.10 3 5912.18 68.19 1554 3818.12 385.28 3425.20 4.40 -11255 3178.26 4 6117.13 68.19 1554 3901.76 586.67 3481.20 0.00 0.00 3325.15 5 6489.10 78.97 25.00 4001.30 902.23 359857 4.00 41.54 358 L70 6 653953 85.00 25.00 4008.10 947.29 361958 12.00 0.00 3622.01 MPH-13a TI 7 6842.18 90.16 39.24 402Ll5 1202.60 3779.96 5.00 70.48 3886.52 8 6909.94 90.16 39.24 4020.96 1255.08 3822.83 0.00 0.00 394954 9 6956.03 89.00 40.00 4021.30 129057 3852.21 3.00 146.85 399250 MPH-13a T2 10 7233.43 8752 48.19 4029.74 148954 4044.99 3.00 100.17 4257.83 II 802758 8752 48.19 4064.14 2018.43 4636.18 0.00 0.00 5032.05 12 8420.14 86.04 36.48 4086.10 2307.76 4900.05 3.00 -97.53 5403.13 MPH-13a T3 13 933L71 86.04 36.48 4149.10 3038.76 5440.66 0.00 0.00 623L76 MPH-13a T4 ., . ) BP Anticollision Report j Company: BP Amoco Field: Milne Point Reference Site: M Pt H Pad ReferenceWeU: MPH-:13 Refercmce WelIpath: Plan MPH-13a GLOBAL SCAN APPLIED: All welIpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 3890.00 to 9331.71 ft Maximum Radius: 1130.41 ft Oate: 7/25/2002 Time: 10:27:05 Page: CO:-iOrdinate(NE) Reference: V erticaJ(TVD) Reference: Welt MPH-'13., True North 64.30'64.3 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/8/2002 Validated: No Planned From To Survey ft ft 27.60 3890.00 3890.00 9331.71 Version: Toolcode Tool Name 1 : MWD - Standard (0) Planned: MPH-13a wp06 V4 MWD MWD+IFR+MS MWD - Standard MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 6489.30 4001.30 7.000 8.500 7" 9331.70 4149.30 4.500 6.125 41/2" Summary I Offset Wellpath :> !< ¡ Site Well WelIpath M Pt G Pad MPG-09 MPG-09 V2 M Pt H Pad MPH-02 MPH-02 V1 M pt H Pad MPH-03 MPH-03 V1 M Pt H Pad MPH-12 MPH-12 V2 M Pt H Pad MPH-13 MPH-13 V4 M pt H Pad MPH-14 MPH-14 V5 Reference Offset Ctr.Cti'. No-GO Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft 7123.51 6325.00 417.95 148.35 298.81 Pass: Major Risk 3942.60 3650.00 534.77 183.78 355.14 Pass: Major Risk 3938.42 4150.00 773.94 176.04 632.43 Pass: Major Risk 3908.30 3800.00 327.21 228.22 150.20 Pass: Major Risk 3955.62 3950.00 3.53 227.52 -223.84 FAIL: Major Risk 5582.74 5225.00 216.40 195.68 67.81 Pass: Major Risk Site: M Pt G Pad Well: MPG-09 Rule Assigned: Major Risk Wellpath: MPG-09 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Cti' No-GO Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-'HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 7000.00 4022.16 5225.00 3284.54 25.52 10.99 352.05 310.75 1107.84 134.09 1004.99 Pass 7000.00 4022.16 5250.00 3292.43 25.52 11.06 352.55 311 .25 1084.79 134.22 982.08 Pass 7000.00 4022.16 5275.00 3300.32 25.52 11.14 353.07 311.78 1061.81 134.35 959.26 Pass 7000.00 4022.16 5300.00 3308.21 25.52 11.22 353.62 312.32 1038.93 134.48 936.53 Pass 7000.00 4022.16 5325.00 3316.11 25.52 11.30 354.19 312.90 1016.14 134.61 913.90 Pass 7015.60 4022.51 5350.00 3324.03 25.76 11.37 355.24 313.48 993.28 135.44 889.99 Pass 7016.23 4022.52 5375.00 3331.98 25.77 11.45 355.88 314.10 970.69 135.60 867.53 Pass 7017.03 4022.54 5400.00 3339.95 25.78 11.53 356.55 314.75 948.22 135.77 845.20 Pass 7018.00 4022.56 5425.00 3347.92 25.80 11.61 357.26 315.43 925.89 135.95 822.99 Pass 7019.07 4022.59 5450.00 3355.80 25.82 11.69 358.01 316.15 903.74 136.14 800.97 Pass 7020.25 4022.62 5475.00 3363.60 25.84 11.77 358.81 316.91 881.80 136.33 779.17 Pass 7021.55 4022.65 5500.00 3371.31 25.86 11.86 -0.35 317.72 860.07 136.53 757.60 Pass 7022.92 4022.68 5525.00 3378.95 25.88 11.94 0.54 318.57 838.57 136.74 736.25 Pass 7024.34 4022.71 5550.00 3386.54 25.90 12.02 1.48 319.47 817.29 136.96 715.16 Pass 7025.80 4022.75 5575.00 3394.09 25.92 12.11 2.47 320.41 796.25 137.17 694.32 Pass 7027.30 4022.78 5600.00 3401.58 25.95 12.19 3.52 321.42 775.47 137.39 673.77 Pass 7028.84 4022.82 5625.00 3409.08 25.97 12.27 4.62 322.47 754.94 137.61 653.51 Pass 7030.43 4022.86 5650.00 3416.59 26.00 12.35 5.78 323.59 734.68 137.82 633.53 Pass 7032.06 4022.90 5675.00 3424.12 26.02 12.43 7.01 324.76 714.71 138.04 613.88 Pass 7033.74 4022.94 5700.00 3431.67 26.05 12.51 8.30 326.00 695.04 138.26 594.57 Pass 7035.55 4022.99 5725.00 3439.37 26.08 12.59 9.65 327.31 675.63 138.49 575.56 Pass 7037.50 4023.03 5750.00 3447.24 26.11 12.67 11.08 328.67 656.48 138.72 556.84 Pass 7039.61 4023.09 5775.00 3455.28 26.14 12.74 12.57 330.11 637.62 138.96 538.45 Pass 7041 .87 4023.14 5800.00 3463.49 26.18 12.82 14.15 331.61 619.07 139.22 520.42 Pass 7044.30 4023.21 5825.00 3471.76 26.22 12.90 15.81 333.21 600.94 139.49 502.86 Pass H 207009 DATE INVOICE / CREDIT MEMO DESCRIPTION PERMIT TO DRILL FEE 7/12/02 INV# CK071002I [) F. ,,¡PI ....... ~ \ I r ~~ .."" t I", ~ \ b' ~ l~ \, ~_: ~~_.'"; ~'U. ~ \:/ l.# I', . 'r- 0''1 ,... <-10 f1ð"'o f\Ub U U t. ¡v¿ ß.faska Oir & G(jn~. GorMfiifj~íOf! Anchorage GROSS (h~H~/3/} THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) -INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 PAY [J.:..'... O.."'fJ..'...-'....',.", .." .r¡'-).}'.0'..".;.;1:.'.:... U..'."jÌ1Øh. ". 1...0.' 11ma... ~ì .-....t."'1-. ,.....'1..'. ffl, '- ,'- ,', " -Ii:,:: - "--'ll -,,---/tl"f.-'~~'.-1' f~ - -. . .. .. 0'''' .. ~þ,t ~UtJ -flU II . ..uu. «'" TO THE ORDER OF ALASKAQIL.& GÄ,$CONSERVATION CQMMISSIOl\J 333 W7THA\lE ANCHO~AGE:ì A}<:- FIRST NATIONAL BANK OF ASHLAND ANAFFII.IATE OF NATIONAL CITY BANK CLEVELAND. OHIO 56-389 412 VENDOR DISCOUNT 7/12/02 DATE CHECK NO. CONSOLIDATED COMMERCIAL ACCOUNT H207009 NET No.H..2.070'09 AMOUNT ****$100.00**** f.NQ:t~l"IQ.~r.:n:1l1f,1Q.OA'(e~; " .. -'";;-"'.~. .:\~;~;.:.}.:.:':~ ". ~>: :::::'~'?S:'" ..:::'':-:.~:i.~~:::S:::::~'~.::::. :.:j .:.'....:..."~"':~':'.' ..., ....;,.....;':...-::.....::.....,:..... ...,,~...:;:-......:. 8.8.-...".8.8.- ,....- ..- .."..'. :",.~:~i~¡" , .."" ....- -- . A'I'~ '~j ~t;;~i;t::..::':;:~.~fl~~:.<\.~\;~:Y~};~;:'i:~; ?i~:t~::~,:~ ~~~~ ~.~~'\"i~~iJ "I 2 0 ? 0 0 q III I: 0... ~ 2 0 j a q 51: 0 0 a ...... ~ q /II H '~ ~.. ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME'l1jJ}/-/J~ PTD# 20 <- ... / ~ 7 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ø~ ;LA/,..- ff ///l;t J . WELL PERMIT CHECKLIST COMPANY A¡;y WELL NAME ;41//'1..., /t".1A PROGRAM: Exp- Dev~ Redrll~/Re-Enter - Serv- WeUboreseg- FIELD & POOL () 2-5) l...J ò INIT CLASS Oo-J/ I-<::J // GEOL AREA 17/'J UNIT# 1/ f :/ - '?" ON/OFF SHORE ~ "ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ry~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique wen name and number.. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drHling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N . //Þ. r/JJiJ~ ~ 8. If deviated, iswellbore plat included.. . . . . . . . . . . . . . Y N ff'-' ~~ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . .. . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service WeU Only) 13. Well located wlin area. & strata authorized by injection order #- Y ß 1',,11 ~ (Service Well Only) 14. All wells wlin Y-i mile area of review identified. . . . . . . . .. ~ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . (f) N 16. Surface casing protects all known USDWs. . . . . . . . . . . é1) N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ¥--# ¡\ilk- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ...~. 19. CMT will cover all known productive horizons. . . . . . . . . . j~W çCr~tÄ. ~~: ~~:~~a~:~~~~~;~~~~:~~~~ ~it:.' ~ ~ :~r~~fr.o~t.. : : : : : : . ~ p ~ left. 22. If a re-drill, has a 10-403 for abandonment been approved. . . . N 7;1. 3/0 L . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . i'~ It Atl/.t- 25. Drilling fluid program schematic & equip list adequate. . . . . NII1~ fJ1 /Iv. ( 7¡ 'L P fJ~ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N / 27. BOPE press rating appropriate; test to 3500 psig. N ms P /31 D P ~ t5 . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N. 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ..@t 31. Mechanical condition of wells within AOR verified. . . . . . . . ..:t-N- Ai/ Ar .,..- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . é:£) N 33. Data presented on potential overpressure zones. . . . . . . . ZN v1 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . /Ì.I ~ /"i ¡ 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . Y N 36. Contact namelphone for weekly progress reports. . . . . . . . Y N APPR DATE 14JGA- JI /110 l. . (Service Well Only) . GEOLOGY ÄPPR DATE ~¿. ?Þh7- (Exploratory Only) Rev: 07/12/02 f GEOLOGY: RP~ UIC ENGINEER JBR COMMISSIONER: COT DTS 03/1..0/°< PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH '(.~ Commentsllnstructions: SFD WGA iN 6A- MJW G:\geology\perm its\checklist.doc ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. . To improve the readability of the Well History file and to simpltfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . . organize this category of information. ') ) aO~-lloJ !f33, Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 04 12:26:21 2002 Reel Header .Service name..... ....... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 /12 / 04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ........... . UNKNOWN Continuation Number..... .01 Previous Tape Name.. .... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPH-13A 500292281801 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 04-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22149 B. ZIEMKE C. DIXON MWDRUN 2 AK-MW-22149 B. HENNINGSE C. DIXON MWDRUN 3 AK-MW-22149 B. HENNINGSE C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 13N 10E 2920 4142 64.20 36.70 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3880.0 6.125 7.000 6720.0 ) ) 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL IS A SIDETRACK DRILLED FROM THE MPH-13 WELLBORE. THE TOP OF THE WHIPSTOCK WAS PLACED AT 3880'MD/2908'TVD. 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 1 WAS DIRECTIONAL ONLY TO ORIENT THE WHIPSTOCK, AND ONLY ROP DATA ARE PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 9/18/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1, 2, AND 3 REPRESENT WELL MPH-13A WITH API#: 50-029- 22818-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9142'MD/4109'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.... ........ .STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/12/04 Maximum Physical Record..65535 File Type.... ........... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE 1 clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH ) ) FET 3877.0 9095.0 RPD 3877.0 9095.0 RPM 3877.0 9095.0 RPS 3877.0 9095.0 RPX 3877.0 9095.0 GR 3878.0 9088.0 ROP 3880.5 9142.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 3880.5 2 3877.0 3 6679.0 MERGE BASE 3910.0 6724.5 9142.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type. ....... ..........0 Data Specification Block Type.....O Logging Direction...... ....... ... . Down Optical log depth units..... ..... .Feet Data Reference Point.. ........... . Undefined Frame Spacing.......... ...... .... .60 .1IN Max frames per record... ... ...... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR Min 3877 1.13 8.74 0.09 0.1 0.06 0.02 0.0564 Max 9142.5 1514.01 122.33 2000 2000 2000 2000 59.52 Mean 6509.75 201.041 64.5962 39.6632 75.9583 85.8211 95.9776 1.15876 MWD MWD MWD MWD MWD MWD MWD First Reading For Entire File... ...... .3877 Last Reading For Entire File........ ...9142.5 Nsam 10532 10525 10421 10437 10437 10437 10437 10437 First Reading 3877 3880.5 3878 3877 3877 3877 3877 3877 Last Reading 9142.5 9142.5 9088 9095 9095 9095 9095 9095 ) ) File Trailer Service name.. ... ....... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/04 Maximum physical Record. .65535 File Type.. .... ......... .LO Next File Name.... ..... ..STSLIB.002 Physical EOF File Header Service name..... ...... ..STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/12/04 Maximum Physical Record..65535 File Type.... ........... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 3880.5 $ 2 header data for each bit run in separate files. 1 .5000 STOP DEPTH 3910.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 03-SEP-02 Insite 66.37 Memory 3910.0 3880.0 3910.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 136696 121079 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3880.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): Based Water 8.70 92.0 8.0 1200 ) FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... .... ...... ..0 Data Specification Block Type... ..0 Logging Direction.......... ...... . Down Optical log depth units.......... .Feet Data Reference Point.. .......... ..Undefined Frame Spacing......... .... ...... ..60 .1IN Max frames per record..... ... ... ..Undefined Absent value. .............. ... ... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 11.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 3880.5 1.13 Max 3910 21.13 First Reading For Entire File. ........ .3880.5 Last Reading For Entire File...... .... .3910 File Trailer Service name.. ........ ...STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/12/04 Maximum Physical Record. .65535 File Type................LO Next File Name........ ...STSLIB.003 Physical EOF File Header Service name... ......... .STSLIB.003 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation...... .02/12/04 Maximum Physical Record..65535 Mean Nsam 3895.25 60 9.87717 60 ) .0 .0 .0 .0 First Reading 3880.5 3880.5 Last Reading 3910 3910 ) File Type.. . . . . . . . . . . . . . .LO Previous File Name. ..... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPS RPM GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 3877.0 3877.0 3877.0 3877.0 3877.0 3878.0 3910.5 STOP DEPTH 6678.5 6678.5 6678.5 6678.5 6678.5 6688.5 6724.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 05-SEP-02 Insite 66.37 Memory 6724.0 3910.0 6724.0 57.0 82.1 TOOL NUMBER 066093 103792 8.500 3880.0 LSND 9.50 61.0 8.0 900 5.8 3.700 2.560 2.800 5.000 66.0 98.6 66.0 66.0 ) ') EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ........... ......0 Data Specification Block Type.....O Logging Direction. ........... .....Down Optical log depth units........ ...Feet Data Reference Point........... ...Undefined Frame Spacing.................. ...60 .1IN Max frames per record.......... ...Undefined Absen t value. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 RPX MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPM MWD020 OHMM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 FET MWD020 HOUR 4 1 68 24 7 GR MWD020 API 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3877 6724.5 5300.75 5696 3877 6724.5 ROP MWD020 FT/H 2.8 1514.01 237.339 5629 3910.5 6724.5 RPX MWD020 OHMM 3.64 1546.45 19.2619 5604 3877 6678.5 RPS MWD020 OHMM 4.05 1588.18 20.3715 5604 3877 6678.5 RPM MWD020 OHMM 0.06 1548.17 18.5945 5604 3877 6678.5 RPD MWD020 OHMM 0.02 2000 19.1931 5604 3877 6678.5 FET MWD020 HOUR 0.0564 17.1224 0.626722 5604 3877 6678.5 GR MWD020 API 8.74 122.33 71.1266 5622 3878 6688.5 First Reading For Entire File.. .... ....3877 Last Reading For Entire File......... ..6724.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .02/12/04 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name.... ... ..... .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/12/04 Maximum Physical Record..65535 File Type............... .LO ,) Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 6679.0 6679.0 6679.0 6679.0 6679.0 6689.0 6725.0 STOP DEPTH 9095.0 9095.0 9095.0 9095.0 9095.0 9088.0 9142.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 09-SEP-02 Insite 66.37 Memory 9142.0 6724.0 9142.0 84.8 93.6 TOOL NUMBER 151107 156401 6.125 6720.0 Flo-pro 9.80 64.0 8.0 104000 3.6 .080 .060 .080 .060 78.0 99.7 78.0 78.0 ) # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction........ ........ . Down Optical log depth units. ..... .... .Feet Data Reference Point. ........... ..Undefined Frame Spacing....... ............ ..60 .1IN Max frames per record.... ........ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6679 9142.5 7910.75 4928 6679 9142.5 ROP MWD030 FT/H 1.56 526.03 161.162 4836 6725 9142.5 GR MWD030 API 14.21 106.17 56.9459 4799 6689 9088 RPX MWD030 OHMM 0.09 2000 63.3191 4833 6679 9095 RPS MWD030 OHMM 0.1 2000 140.413 4833 6679 9095 RPM MWD030 OHMM 0.09 2000 163.772 4833 6679 9095 RPD MWD030 OHMM 0.53 2000 185.011 4833 6679 9095 FET MWD030 HOUR 0.2278 59.52 1.77568 4833 6679 9095 First Reading For Entire File.. ....... .6679 Last Reading For Entire File.......... .9142.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/04 Maximum Physical Record. .65535 File Type................LO Next File Name..... "'" .STSLIB.OO5 Physical EOF Tape Trailer Service name... ......... .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name..... ..... .UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services ) Reel Trailer Service name.......... ...LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 /12 / 04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... . UNKNOWN Continuation Number..... .01 Next Reel Name..... ..... . UNKNOWN Comments..... ......... ...STS LIS Physical EOF Physical EOF End Of LIS File ) Writing Library. Scientific Technical Services