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Home My WebLink About202-131Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov January 6, 2026 Ms. Vanessa Hughes PBW Asset Team Leader Hilcorp North Slope, LLC 3800 Centerpoint Dr. Suit 1400 Anchorage, AK 99503 Re: Docket Number: OTH-25-009 – Closeout Investigation of Self-reported Discovery of Unallocated Commingled Injection into PBU Orion/Borealis Wells L-103 (PTD# 202-139) and V-105 (PTD# 202-131) Prudhoe Bay Unit Dear Ms. Hughes: After completing its review of Hilcorp North Slope, LLC’s (Hilcorp) investigation into the self- reported incident noted above that was submitted on February 25, 2025, the Alaska Oil and Gas Conservation Commission (AOGCC) has decided that no further action is required on this matter. While not properly allocating injection between the two pools is a violation of conditions of approval contained in Area Injection Order No. 26A.002 and Conservation Orders No. 471.007 and 505A.001, which authorized downhole commingling of injection between the two pools and within the subject wells, Hilcorp did not configure the wells to be in commingled injection for the period when the unallocated injection occurred but rather the commingled injection occurred due to unknown at the time mechanical conditions down hole. When Hilcorp became aware of the unallocated commingling through unexpected flowing conditions of offset production wells, it notified the AOGCC and took actions to investigate the unintended downhole commingling, as well as to take corrective action and revise the injection reports for these wells to properly allocate the injection volumes. Because the unintended downhole commingling of injection couldn’t be predicted or detected until offset producers started showing anomalous production and Hilcorp’s action to correct the issue, there is no need for the AOGCC to take any further action on this matter. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner Cc: Phoebe Brooks (AOGCC) Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2026.01.06 10:30:23 -09'00' Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2026.01.06 11:07:19 -09'00' Hilcorp North Slope, LLC Vanessa Hughes, PBW Asset Team Leader 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 02/25/2025 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Investigation of Self-reported Discovery of Unallocated Commingled Injection into PBU Orion/ Borealis Wells L-103 (PTD# 202-139) and V-105 (PTD# 202-131), Hilcorp North Slope (HNS), LLC. Dear Mr. Wallace, Please see below for investigation information compiled regarding the self-reported discovery of unallocated commingled injection of produced water and enriched hydrocarbon gas into PBU Orion/ Borealis well L-103 (PTD# 202-139), between 03/09/2022-09/21/2024 and V-105 (PTD# 202-131), between 05/18/2024- 02/09/2025. Well History and Event Summary: L-103 is a multi-pool injector completion in the Orion and Borealis pools with AOGCC approval for both commingled water and enriched hydrocarbon gas (MI) injection with specific allocation methodology requirements for each service type. The completion style allows the Orion pool to be isolated from the Borealis with regulation of injection through waterflood mandrels between packers isolating the Orion perforations. From 03/9/2022- 08/17/2022, L-103 was on MI service and has since been on produced water injection into the Borealis pool with dummy waterflood regulator valves (DWFRVs) set in the two mandrels between the packers, isolating the Orion perforations from the wellbore. On 09/20/2024, Orion pool production trends in offset producer L-201 (PTD# 204-064) indicated possible communication with well L-103. L-103 was immediately shut- in and the AOGCC notified the same day. On 09/21/2024, a plug was set at 8569’ MD to isolate the Borealis and test tubing integrity between the packers isolating the Orion pool. This MIT-T failed with a liquid leak rate of 2 BPM at 240 psi. On 11/25/2024, a leak detection log found a hole in the 3.5” tubing at 6443’ MD. The tubing plug was then removed and an injection profile was run on 11/26/2024 to determine injection splits between the Orion and Borealis. Once this data was collected, a nipple reducer and plug were set at 8548’ MD in preparation for a tubing patch to be installed over the leak at 6443’ MD. Review of injection and offset production trends indicate that the hole in the tubing developed in March of 2022. Injection allocation corrections for L-103 have been submitted to the AOGCC on 02/17/2025. Allocation methodology was based on historic offset production changes to gas and water volumes in Borealis and Orion wells and more recently injection splits from the 11/26/2024 injection profile log. L-103 Borealis/ Orion allocation splits: Stemming from the investigation into L-103, all other active, multi-pool completion injection wells are under review. A recent result of this broader investigation led to diagnostic work on V-105 (PTD# 202-131), also resulting in the discovery of unintended commingled injection due to a completion component failure. WAG injection well, V-105 has a dual reservoir completion that can be mechanically manipulated to inject into the Borealis Oil Pool and/or Orion Oil Pool. V-105 was on PWI By Samantha Coldiron at 11:06 am, Feb 25, 2025 until 07/04/2024, after which it was placed on MI, and then returned to PWI on 01/25/2025. Throughout this timeframe V-105 was mechanically arranged to inject into the Borealis Oil Pool only. Due to an increase in water volumes found in offset Orion Pool producers, a tubing tail plug was set on 01/20/2025 and the well passed a MIT-T to 2641 psi indicating competent tubing across the upper injection zone. A subsequent injection profile log was executed on 02/9/2025 in V-105 due to the unresolved increased Orion producer water volumes. Interpretation of the log has shown that the majority of injection is not going into the intended Borealis perforations, but out the 3.5” tubing, up the backside of the tubing tail, through the apparently failed packer at 7555’ MD and into the Orion perforations. The well has been shut-in and freeze protected since this log was executed and work is being planned to set an IBP in the 7” casing to isolate the Borealis from the Orion perforations as soon as possible. Based on initial analysis, injection into the Orion perforations started on 05/18/2024. Additional work is being done to verify the timeframe of the packer failure and resolve the injection allocation. Allocation corrections on V-105 will be submitted to the AOGCC as soon as possible. Both L-103 and V-105 are authorized for produced water and enriched hydrocarbon gas injection into the Borealis pool (AIO 24C, Rule 2) and the Orion pool (AIO 26B, Rule 3). L-103 and V-105 were both approved for commingled injection in AIO 26A.002 based off approved allocation methodology from 08/21/2008. Unfortunately, due to the completion failures in both wells and the subsequent unrecognized commingled injection, volumes were not correctly allocated to the Orion and Borealis pools. We are retroactively allocating corrected injection volumes to both pools from the time of the completion failure dates and submitting updated 10-406’s to the AOGCC. Hilcorp does not believe that these incidents have promoted waste nor jeopardized ultimate recovery of hydrocarbons from the Borealis and Orion pools as all injection fluid and intervals were previously approved. Root cause of the incident: x Inadequate surveillance work process to monitor for anomalous deviations in injection pressures/ rates, resulting in unmonitored commingled injection. Contributing factors of the incident: x Initial failure of the 3.5” tubing sting resulting in commingled injection in L-103, failure of lower injection packer resulting in commingled injection in V-105. x Inadequate awareness of risk for unintended commingled injection in multi-pool completion wells. Actions to prevent recurrence: x Downhole logging verification of injection conformance in all active PBU multi-pool completion wells by 06/30/2025. x Implement immediate review and establish quarterly process by Reservoir Engineer for review of injection trends in active multi-pool completion wells. If you have any questions, please call me at 907-777-8445 or Oliver Sternicki at 907-564-4891. Sincerely, Vanessa Hughes PBW Asset Team Leader Digitally signed by Vanessa Hughes (793) DN: cn=Vanessa Hughes (793) Date: 2025.02.25 10:27:17 - 09'00' Vanessa Hughes (793) Reservoir Engineer finds anomalous offset production in well L-201. Well L-103 shut-in.09/20/2024AOGCC notified of possible unauthorized commingled injection into L-103. Plug set, MIT-T failed.09/21/2024L-103: Plug pulled, injection profile run to determine injection splits between Orion and Borealis Pools. Tubing tail plug reset.11/26/20243/2022Page 1/2Deviation from expected injection rate vs pressure into L-103 not recognized.L-103/ V-105 Misallocated Injection Timeline3-1 Lack of knowledge of hazards presentL-103: Leak detection log finds hole in 3.5” tubing at 6443’ MD.14.1 Lack of PSP for the task – No established review process evaluating injection conformance in multi-pool completion wells.11/25/202405/18/2024Deviation from expected injection rate vs pressure into V-105 not recognized.14.1 Lack of PSP for the task – No established review process evaluating injection conformance in multi-pool completion wells.Unallocated Injection into L-103 in Orion PoolInjection occurs through hole in tubing @ 6443’ MD in section straddling the Orion PoolInjection occurs up through the lower packer at 7555’ MD straddling the Orion PoolTubing failed due to corrosion/erosion of tubing.Packer failed due to corrosion, soft goods or mechanical failureL-103 Swapped from MI to water injectionAug 2022Dec 2023V-105 swapped from MI to water injection.L-103 Swapped from MI to water injectionSep 2021Tubing failure results in change to injection pressure vs rateChange in injection response does not trigger diagnostics/SIMarch 2022Unallocated Injection into V-105 in Orion PoolPacker failure results in change to injection pressure vs rateChange in injection response does not trigger diagnostics/SIImplement immediate review and establish quarterly process for review of injection trends in active multi-pool completion wells.Downhole logging verification of injection conformance in all active PBU multi-pool completion wells by 06/30/20253-1 Lack of knowledge of hazards presentCFCFBy Samantha Coldiron at 11:06 am, Feb 25, 2025 Page 2/2L-103/ V-105 Misallocated Injection TimelineCFOpportunity for ImprovementCritical/Causal FactorOFICorrective Action System CauseImmediate CauseV-105: I-Prof interpretation finalized indicating failure of lower completion packer, indicating unintended injection into the Orion perforations.02/14/2025V-105: Plug set, MIT-T passed to 2641 psi. Plug removed, well placed back on injection.01/20/202502/09/2025Possible anomalous V-105 injection volumes/ pressure noted. Injection profile logged. Well shut-in.Start of multi-pool injector completion review. 01/22/2025 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251016 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 2-36 50029220140000 190024 9/17/2025 BAKER SPN T40994 END 2-74 50029237850000 224024 9/22/2025 HALLIBURTON PATCH T40995 KU 12-17 50133205770000 208089 9/23/2025 YELLOWJACKET TEMP-CALIPER T40996 KU 24-7RD 50133203520100 205099 9/24/2025 YELLOWJACKET TEMP-CALIPER T40997 M-25 50733203910000 187086 8/31/2025 YELLOWJACKET CALIPER T40998 MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey T40999 MPF-61 50029225820000 195117 9/27/2025 READ CaliperSurvey T41000 MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG T41001 NIK SI17-SE2 50629235120000 214041 9/23/2025 HALLIBURTON IPROF T41002 NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG T41003 NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG T41003 ODSN-26 50703206420000 211121 10/7/2025 HALLIBURTON MFC24 T41004 PBU 01-25A 50029208740100 225056 9/13/2025 BAKER MRPM T41005 PBU 01-25A 50029208740100 225056 9/13/2025 HALLIBURTON RBT-COILFLAG T41005 PBU 01-31A 50029216260100 225070 9/22/2025 BAKER MRPM T41006 PBU 01-31A 50029216260100 225070 9/23/2025 HALLIBURTON RBT-COILFLAG T41006 PBU 05-09A 50029202540100 199014 9/18/2025 READ ArcherVIVID T41007 PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT T41008 PBU 07-23C 50029216350300 225043 7/4/2025 BAKER MRPM T41009 PBU 13-24B 50029207390200 224087 9/18/2025 HALLIBURTON RBT T41010 PBU 15-11C 50029206530300 210163 9/6/2025 HALLIBURTON RBT T41011 PBU 15-49C 50029226510300 215129 9/10/2025 HALLIBURTON RBT T41012 PBU H-07B 50029202420200 225064 9/30/2025 HALLIBURTON RBT-COILFLAG T41013 PBU P19 L1 50029220946000 212056 10/3/2025 HALLIBURTON RBT T41014 PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT T41015 PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D T41016 Please include current contact information if different from above. PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.20 13:17:06 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/2/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250302 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# CLU 11 50133205590000 206058 2/19/2025 AK E-LINE CBL,CIBP CLU 11 50133205590000 206058 2/13/2025 AK E-LINE CIBP END 1-65A 50029226270100 203212 1/27/2025 HALLIBURTON COILFLAG END 2-56A 50029228630100 198058 2/6/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 2/2/2025 HALLIBURTON PPROF MPU F-29 50029226880000 196117 1/31/2025 HALLIBURTON MFC24 MPU L-02A 50029219980100 209147 2/17/2025 READ CaliperSurvey MPU L-36 50029227940000 197148 1/18/2025 HALLIBURTON MFC24 MPU R-144 50029238090000 224148 2/11/2025 HALLIBURTON WFL-TMD3D NCIU A-21 50883201990000 224086 2/18/2025 AK E-LINE Perf ODSN-25 50703206560000 212030 2/16/2025 READ MemoryLeakPoint PBU 06-05A 50029202980100 224115 1/15/2025 BAKER MRPM PBU 06-15A 50029204590200 224108 12/27/2024 HALLIBURTON RBT PBU 06-16B 50029204600200 223072 1/25/2025 BAKER MRPM PBU B-12B 50029203320200 224133 1/19/2025 BAKER MRPM PBU S-126B 50029233630200 224084 2/7/2025 HALLIBURTON RBT PBU V-105 50029230970000 202131 2/9/2025 HALLIBURTON IPROF PBU W-01A 50029218660100 203176 1/19/2025 AK E-LINE CBL PBU W-01B 50029218660200 224149 1/28/2025 HALLIBURTON RBT PCU 02A 50283200220100 224110 1/24/2025 AK E-LINE CIBP Please include current contact information if different from above. T40161 T40161 T40162 T40163 T40164 T40165 T40166 T40167 T40168 T40169 T40170 T40171 T40172 T40173 T40174 T40175 T40176 T40177 T40178 T40179 PBU V-105 50029230970000 202131 2/9/2025 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.03 10:15:14 -09'00' 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW7XHVGD\$SULO30 7R3%:HOOV,QWHJULW\ &F5HJJ-DPHV%2*& 6XEMHFW5(+LOFRUS3%80DUFK0,7)RUPV $WWDFKPHQWV0,73%8$5HYLVHG[OV[0,73%89$5HYLVHG[OV[0,73%899 5HYLVHG[OV[0,73%895HYLVHG[OV[ ,ŝŶĚǇ͕ ƚƚĂĐŚĞĚĂƌĞƌĞǀŝƐĞĚƌĞƉŽƌƚƐĂƐĨŽůůŽǁƐ͗ x D/dWhϬϮͲϯϭϬϯͲϭϵͲϮϮʹdŚĞƐƵŶĚƌǇηƌĞĨĞƌĞŶĐĞĚŝŶƚŚĞŶŽƚĞƐǁĂƐĐŚĂŶŐĞĚƚŽϯϮϭͲϲϮϯ x D/dWhsͲϮϭϯϬϯͲϬϯͲϮϮʹϰǁĂƐĂĚĚĞĚƚŽƚŚĞ>WƵŵƉĂŶĚƚŚĞWĂĐŬĞƌdsǁĂƐĐŚĂŶŐĞĚƚŽϮϰϱϱ͛ƉĞƌƚŚĞ ŝŶƐƉĞĐƚŽƌ͛ƐƌĞƉŽƌƚ x D/dWhsͲϬϱsͲϭϬϱϬϯͲϬϳͲϮϮΘD/dsͲϭϬϱϬϯͲϬϱͲϮϮʹƚŚĞĐŽŵƉůĞƚŝŽŶĚŝĚŶŽƚŵĞĞƚƚŚĞƐƚĂŶĚĂƌĚƐŽĨĂƐŝĚĞƚƌĂĐŬ͕ ďƵƚĚŝĚĨŽƌĂůĂƚĞƌĂůƐŽsͲϭϬϱǁĂƐĐŚĂŶŐĞĚƚŽsͲϭϬϱ>ϭ͖ƐŝŶĐĞǁĞĚŽŶŽƚĂƐƐŽĐŝĂƚĞĂŶǇD/dƌĞĐŽƌĚƐĂŐĂŝŶƐƚ ůĂƚĞƌĂůƐ͕ƚŚĞWdηǁĂƐĐŚĂŶŐĞĚƚŽϮϬϮϭϯϭϬĨŽƌǁĞůůsͲϭϬϱ͘ WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉŝĞƐŽƌůĞƚŵĞŬŶŽǁŝĨǇŽƵĚŝƐĂŐƌĞĞ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ^ƚĂƚŝƐƚŝĐĂůdĞĐŚŶŝĐŝĂŶ// ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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). 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PTD 2021310 Type Inj N Tubing 596 3521 3481 3468 Type Test P Packer TVD 4273 BBL Pump 1.1 IA 87 171 173 173 Interval O Test psi 3150 BBL Return 1.1 OA 341 340 339 339 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp North Slope, LLC Prudhoe Bay / PBU / V Pad Caleb Piaskowski 03/05/22 Notes:Offline MIT-T post CTD sidetrack to max expected header pressure per Email from Mel Rixse on 02/02/22. Not Witnessed. Notes: Notes: Notes: V-105 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanicall Integrityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0305_MIT_PBU_V-105 - 5HJJ 9 9 9 9 9 03/05/22 Not Witnessed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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Date:Monday, January 24, 2022 3:20:40 PM From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, January 19, 2022 10:54 AM To: Roby, David S (OGC) <dave.roby@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Salazar, Grace (OGC) <grace.salazar@alaska.gov> Subject: RE: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Will do, thanks Dave. From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Wednesday, January 19, 2022 10:41 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Salazar, Grace (OGC) <grace.salazar@alaska.gov> Subject: RE: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Oliver, Rule 6 of AIO 26B allows for commingled injection, but part b of the rule requires the AOGCC to approve an allocation methodology prior to commencement of injection. Since V-105A will be a new wellbore you’ll need to get an allocation methodology for it approved, so send a letter/email addressed to Chairman Price requesting approval of an allocation methodology for this well to myself and Grace Salazar (copied on her so you’ll have her email address) and we’ll process it for you. Regards, Dave Roby (907)793-1232 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, January 19, 2022 10:34 AM To: Roby, David S (OGC) <dave.roby@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> 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. Subject: RE: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Dave, Another question for you about V-105. This well is going to be sidetracked under PTD# 221-080. Will V-105a also be authorized for commingled MI injection under AIO 26A.002 or do we need to new AA request because of the new PTD? Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Roby, David S (CED) <dave.roby@alaska.gov> Sent: Thursday, February 11, 2021 10:08 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Hi Oliver, Since the current method was approved in an admin approval a revision to that methodology should also be done via an admin approval. So, just send a letter in requesting an admin approval to modify the allocation methodology and explain how the new methodology would work. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907-793-1232 or dave.roby@alaska.gov. From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, February 10, 2021 1:46 PM To: Roby, David S (CED) <dave.roby@alaska.gov> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Dave, Follow up question for the highlighted piece below. For V-105, if we were to propose changing the allocation confirmation method in the 2018 application from an injection profile to isolating the zones and conducting step rate tests, how would we do this? Is that a request to amend the AIO or does it fall under a sundry request? Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Roby, David S (CED) <dave.roby@alaska.gov> Sent: Thursday, January 28, 2021 4:43 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Oliver, After reviewing the record it’s clear that AIO 26B, Rule 6.c. should not reference water, it should say “…for determining the allocation of injected fluids between pools…” We’ll issue a corrected order to make this correction when we have a moment. AIO 26B superseded AIO 26A.002, so the conditions in the latter no longer apply and only the conditions in AIO 26B apply to commingled injectors. Namely you need approval from us before converting a well to be a commingled injector, and you’ll have to demonstrate mechanical isolation between the pools and have a method for allocating injection between the pools. This can be done by submitting a 10-403, that has the required isolation/allocation details, to convert a well to a commingled injector. And yes, you are still authorized to do commingled MI injection in the L-103 and V-205 wells. MI allocation for these wells shall be done in accordance with the approved allocation methodology from the August 21, 2008, application that led to the issuance of AIO 26A.002. Let me know if you have any further questions or need any additional clarification. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907-793-1232 or dave.roby@alaska.gov. From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, January 28, 2021 4:15 PM To: Roby, David S (CED) <dave.roby@alaska.gov> Subject: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Dave, I’ve got a couple questions for you regarding V-105 (PTD 212-131) and commingled injection of MI into the Orion and Borealis oil pools. Back in 2008 commingled injection of MI into the Orion and Borealis pools was requested and received for L-103 and V-105 per AIO 26A 002. AIO 26A 002 also amended rule 6 to remove the word “water”. AIO 26A 002 was then replaced by AIO 26B. Since 26A 002 is no longer active what does that mean for the “conditions” set forth in that amendment. Are those condition still active since AIO 26B Rule 6 references 26A002 as a source? Is Hilcorp still authorized to have Orion- Borealis commingled MI into L-103 and V-205? Does the process for requesting Orion- Borealis commingled MI for other well follow the requirement of the conditions in 26A 002? When reading 26B rule 6 ( c) there is still has a reference to “water”, how does this impact any request for Orion- Borealis commingled MI under 26B. AIO 26A 002 AIO 26B Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 theonward 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. 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. 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. 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,255'None Casing Collapse Conductor 470 Surface 3090 Production 5410 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: November 1, 2021 4-1/2" 12.6# x 3-1/2" 9.2# 4-1/2" Baker Premier Packer 4-1/2" Baker S-3 Packer Authorized Title: Drilling Manager Authorized Name: Monty Myers 25' - 8243' Perforation Depth MD (ft): 5,392' - 7,806' 8218' Perforation Depth TVD (ft): Tubing Size: 25' - 7124'7" 20" 9-5/8" 80' 2944' MD 1490 5057 29' - 109' 28' - 2752' 29' - 109' 28' - 2972' Prudhoe Bay Field / Borealis Oil Pool and Schrader Bluff Oil Pool Orion Development Area PBU V-105 PRESENT WELL CONDITION SUMMARY L-80 TVD Burst 7613' 7240 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 028240 202-131 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 50-029-23097-00-00 Hilcorp Alaska, LLC COMMISSION USE ONLY Tubing Grade: Tubing MD (ft): 4,430' - 6,692' 5,211' / 4,273' 7,555' / 6,445' Trevor Hyatt trevor.hyatt@hilcorp.com 777-8396 7,136' 8,157' 7,039' 3,207 None Length Size No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 9.29.2021Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.09.29 15:56:16 -08'00' Monty M Myers By Meredith Guhl at 8:48 am, Sep 30, 2021 321-514 X DSR-9/30/21MGR06OCT2021DLB 10/01/2021 Variance to 20AAC 25.112(i) alternate plug placement approved. 10-407 dts 10/6/1021 JLC 10/7/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.07 10:00:58 -08'00' RBDMS HEW 10/7/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 29, 2021 Re: PBU V-105 Sundry Request Sundry approval is requested to set and cement a whipstock in V-105 pre-rig as part of the drilling and completion of the proposed V-105A CTD lateral. Proposed plan for V-105A Injector: Prior to drilling activities, a 3-1/2" x 7" Whipstock will be set pre-rig with E-line in the 7" casing. The parent Kuparuk perforations and whipstock will be cemented pre-rig (Schrader perfs will be behind tubing and dummied GLMs, thus not cemented). See the V-105A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A single string window exit (7” casing) + 10’ of rathole will be milled. The well will kick off in the Kuparuk C, build through the C and land in Kuparuk B. The well will build back up and complete the lateral in Kuparuk C to TD. The proposed sidetrack will be completed with a 2- 3/8” L-80 solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate and abandon the parent Kuparuk perforations but will NOT isolate and abandon the Schrader perfs. This Sundry covers plugging the existing Kuparuk perforations via the pre-rig cement squeeze, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work (Estimated to start in November 2021): 1. Slickline: Dummy WS drift and dummy all mandrels a. Drift past whipstock setting location. b. Dummy all 4-1/2” GLMs and 3-1/2” Water Injection Mandrels. 2. E-line: Set 3-1/2” x 7” whipstock a. Top of whipstock set at 7,745’ MD b. Oriented 120° LOHS c. Top of window (pinch point) at 7,749’ MD 3. Service Coil: Cement whipstock and perforations* a. Squeeze existing perforations and cement the whipstock in place b. ~20 bbls of 15.8 ppg Class G cement c. Planned TOC is at the whipstock tray. 4. Fullbore: MIT-IA to 3,500 psi 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: Reference PBU V-105A PTD submitted in concert with this request for full details. General work scope of Rig work: 1. MIRU and Test BOPE. MASP with gas (0.10 psi/ft) to surface is 3,207 psi. 2. Mill Window 3. Drill Build and Lateral 4. Run and Cement Liner* 5. Freeze Protect and RDMO 6. Perforate Post Rig and set LTP* if needed * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Sundry 321-154 PTD Well Slimhole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" Pipe/Slips 12.6 ft CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2" Pipe/Slips 7-1/16" 5k Mud Cross 2" Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" Pipe/Slips MEMORANDUM TO: Jim Regg P.I. Supervisor c FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 15, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-105 PRUDHOE BAY ON BORE V-105 Src Inspector Reviewed By: q P.1. Supry JU.— Comm Well Name PRUDHOE BAY UN BORE V-105 API Well Number 50-029-23097-00-00 Inspector Name: Bob Noble Permit Number: 202-131-0 Inspection Date: 2/13/2021 ' IUsp Num: mi[RCN210214163528 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-105 Type Inj w JTVD 4273 i Tubing 2143 2144 - 2147 - 2150 - � PTD 2021310 Type Test SPr jTest psi 1500 - IA 268 - 2945 - 2822 - 2814 BBL Pumped: 1.6 - IBBL Returned: 1.6 _ OA 688 709- 711 - 712 Interval 4YRTSr P/F P Notes:. Monday, March 15, 2021 Page I of 1 MEMORANDUM To: Jim Re -P h z5 2vz 1 P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Friday, February 19, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-105 PRUDHOE BAY ON BORE V-105 Src: Inspector Reviewed By: P.I. Sup" Comm Well Name PRUDHOE BAY UN BORE V-105 API Well Number 50-029-23097-00-00 Inspector Name: Bob Noble Permit Number: 202-131.0 Inspection Date: 2/14/2021 - Insp Num: mitRCN210214163528 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well v -los Type Inj I w TVD 4273 ' Tubing 2143 2144 2147 - 2150 PTD 2021310 • Type Test SPT. Test psi 1500 - IA 268 2945 - 2822 - 2814 - BBL Pumped: 1 1.6 ' BBL Returned: 1.6 _ OA Ess • 769- 7D - 712 Interval 4YRTST p/p P Notes: Friday, February 19, 2021 Page I of I Wallace, Chris D (CED) From: Roby, David S (CED) Sent: Thursday, February 11, 2021 10:08 AM To: Oliver Sternicki Cc: Wallace, Chris D (CED) Subject: RE: [EXTERNAL] RE: AIO 26A 002, AIO 26B and V-105 (PTD 202-131) commingled injection Hi Oliver, Since the current method was approved in an admin approval a revision to that methodology should also be done via an admin approval. So, just send a letter in requesting an admin approval to modify the allocation methodology and explain how the new methodology would work. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robv@alaska.eov. From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, February 10, 20211:46 PM To: Roby, David S (CED) <dave.roby@alaska.gov> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: AID 26A 002, AID 26B and V-105 (PTD 202-131) commingled injection Dave, Follow up question for the highlighted piece below. For V-105, if we were to propose changing the allocation confirmation method in the 2018 application from an injection profile to isolating the zones and conducting step rate tests, how would we do this? Is that a request to amend the AID or does it fall under a sundry request? Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Roby, Da ED) <dave.robv@alaska.eov> Sent: Thursday, January 28, 24-4;43 PM To: Oliver Sternicki <Oliver.Sternicki(@hilcoro.c Wallace, Chris D (CED) From: Rixse, Melvin G (CED) Sent: Friday, September 11, 2020 11:31 AM To: Aras Worthington; Roby, David S (CED); Wallace, Chris D (CED) Cc: Oliver Sternicki; Travis Smith - (C); Brodie Wages Subject: RE: [EXTERNAL] RE: V-105 PTD #202-131 Aras, Then Roby and Wallace will need to provide their approval. I looked at the USIT for Shrader Bluff isolation. Second stage cementing looked like good isolation for the SB sands. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This a -mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sale 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.Kov). cc. Roby and Wallace From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Friday, September 11, 2020 11:18 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Roby, David S (CED) <dave.roby@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brodie Wages <David. Wages@h ilcorp.com> Subject: RE: [EXTERNAL] RE: V-105 PTD #202-131 Mel, Yes the proposal is to inject through both those mandrels with Water -Flood -Regulator Valves installed. Thanks, Aras Worthington Hilcorp Alaska LLC Well Integrity Engineer Aras.worthineton Philcoro.com 907.564.4763 907.440.7692 mobile From: Rixse, Melvin G (CED) [mailto:melvin.rixse@alaska.gov] Sent: Friday, September 11, 2020 11:15 AM To: Aras Worthington <Aras.Worthineton@hilcorp.com>; Roby, David S (CED) <dave.roby@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.aov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brodie Wages <David. Wages@hilcorp.com> Subject: [EXTERNAL] RE: V-105 PTD #202-131 Aras, Injecting though mandrels at 5310' and 5371'? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 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.Rixserdalaska.govI. Cc Roby and Wallace From: Aras Worthington <Aras.Worthington(a@hilcorp.com> Sent: Friday, September 11, 2020 10:21 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Roby, David S (CED) <dave.robv@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brodie Wages <David. Wages@hilcorp.cc m> Subject: RE: V-105 PTD #202-131 Mel, This well was originally permitted, drilled, and completed in 2002 in the Kuparuk and Schrader as in Injector. The well has only ever injected into the Kuparuk. Hilcorp proposes to run Water -Flood -Regulator valves and inject in both Kuparuk and Schrader. Please let us know if this is approved. Thanks and Best Regards, Aras Worthington Hilcorp Alaska LLC Well Integrity Engineer Aras.worthington@hilcorp.com 907.564.4763 907.440.7692 mobile • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,February 13,2017 TO: Jim Regg P.I.Supervisor N' FiZ� I /7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-105 FROM: Bob Noble PRUDHOE BAY UN BORE V-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 17;1— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-105 API Well Number 50-029-23097-00-00 Inspector Name: Bob Noble Permit Number: 202-131-0 Inspection Date: 2/2/2017 Insp Num: mitRCN170210063333 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min I J Well I - V 105 ITYP a In FW• ;TVD r 4273 • Tubing 1362 1368 1378 1386 PTD1_ 1 2021310 Type Test SPT r Test psi 1500 IA 304 2860 • 2834, 2905, BBL Pumped: I BBL Returned: 2 - OA 751 782 793 • 803 Interval 4YRTST P/F I • Notes: IA failed to stabilize.Injection rate increasing.Test#2 of 4. Monday,February 13,2017 Page 1 of 1 • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,February 13,2017 P.I.Supervisor ' `e/ly' 47(ft 7 SUBJECT: Mechanical Integrity Tests t BP EXPLORATION(ALASKA)INC. V-105 FROM: Bob Noble PRUDHOE BAY UN BORE V-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv� L— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-105 API Well Number 50-029-23097-00-00 Inspector Name: Bob Noble Permit Number: 202-131-0 Inspection Date: 2/2/2017 Insp Num: mitRCN170210063851 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 v-1o5 • Type Inj W iTVD 4273 • i Tubing 1389 j 1392 1395 1399 PTD j 2021310 Type Test SPT Test psi 1500 IA 242 2863 2808 2843 BBL Pumped: I BBL Returned: 2 - OA 778 800 809 - 814 - Interval Ii 4YRTST P/F • I V" Notes: IA failed to stabilize.Test#3 of 4. Monday,February 13,2017 Page 1 of 1 D • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,February 13,2017 TO: Jim Regg *4117 P.I.Supervisor l/i SUBJECT: Mechanical Integrity Tests ll BP EXPLORATION(ALASKA)INC. V-105 FROM: BobMEMORAN NobleUM PRUDHOE BAY UN BORE V-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T8P-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-105API Well Number 50-029-23097-00-00 Inspector Name: Bob Noble Permit Number: 202-131-0 Inspection Date: 2/2/2017 Insp Num: mitRCN170210062523 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-105 . Type Inj W -TVD 1 4273 ' Tubing 1163 1170 1167 1308 1341 1344 PTDi 2021310Type Test SPT Test psi 1500 - IA 175 2980 - 2846 - 2924 3042 2950. BBL Pumped: L 2.5 - BBL Returned: 2.4 - OA 725 755 760 768 778 779 Intervalil 4YRTST iP/ F j I Notes: Injection rate was increased and IA would not stablize.Test#1 of 4. '/ SCANNED APR 2 ` 201 Monday,February 13,2017 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,February 13,2017 TO: Jim Regg •wf ei Z zit/7 P.I.Supervisor 1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-105 FROM: Bob Noble PRUDHOE BAY UN BORE V-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry t--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-105 API Well Number 50-029-23097-00-00 Inspector Name: Bob Noble Permit Number: 202-131-0 Inspection Date: 2/2/2017 Insp Num: mitRCN170203131329 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-105 - Type Inj W- TVD 4273 Tubing 1405 1412 - 1411 , 1415 - 1418.. PTD 2021310 Type Test SPT Test psi 1500 , IA 264 2930, 2820 . 2836 - 2857 BBL Pumped: 2.5 - BBL Returned: 2.4 OA 413 425 428. 431 - 432 Interval 4YRTST P/F P Notes: Well never stabilized.Test#4.Per J.Regg,review of 4 tests indicates thermal effects of injection influencing the test.Max differential pressure changed during final 3 tests was just 3.75%.Test#4 deemed"P". ct tc :lSCAMS LAPP. 2 x. 2017, Monday,February 13,2017 Page 1 of 1 • • 1 I 1 M � C t-- --6- -1:-., O — O Met \N\ 0. \ ''c'i= O N M CT a <�' b M ct N oo , Lc) ^- N N M MNP:3-1 .-. • vl ,I. \O (V r rn N ch CC 71- 00 N N O -12 M cn 00 'd' to oo ezn c) --+ O . OU ,r-, M 00 M 00 7r CO � .5 in "r -- N –r N —, N k./\ ' , o Mc .0Cv0 ^' rn , ,N4O * N — N - N en 00 HH.. C = H H H ' z O 3iCO N M71- a N N p,,, N H H H r6u., v • • rrN3( C Regg, James B (DOA) From: Ross, Matthew <rossmo@BP.com> Sent: Monday, February 06, 2017 12:24 PM To: Regg,James B (DOA) Subject: RE: MIT state testing results - DS 09-17, DS 09-20 &V-105 Attachments: TIO &temp plot V-105.docx Jim; V pad injection and production has been off line for some time due to subsidence. Here's the plots both 90 days &recent activity(last week). V-105 is currently shut in so the Parker rig can maneuver around the pad. The TIO plot data is from the operator reads off of the wellhead for pressure & temp (flowline). From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, February 06, 2017 11:36 AM To: Ross, Matthew Subject: RE: MIT state testing results - DS 09-17, DS 09-20 &V-105 Can you provide a TIO pressure plot for V-105 (90 days leading up to MIT). Also, if available. provide a temperature plot for V-105 for the same timeframe (and note where it is measured)? Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.reggPalaska.gov. From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Monday, February 06, 2017 10:47 AM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: RE: MIT state testing results- DS 09-17, DS 09-20&V-105 Here you go. Thanks. From: Regg, James B (DOA) [mailto jim.reggOalaska.gov] Sent: Monday, February 06, 2017 10:22 AM To: Ross, Matthew Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: RE: MIT state testing results - DS 09-17, DS 09-20 &V-105 V-105; need to revise report to include all tests (4). Jim Regg 1 • O Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.reggPalaska.gov. From: Ross, Matthew [mailto:rossmo@BP.com] Sent:Saturday, February 04, 2017 10:53 AM To: Regg,James B (DOA)<iim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: MIT state testing results- DS 09-17, DS 09-20&V-105 Here's the MIT testing reports. 1) DS 09-17 Produced water only injector. It has an AA due to IAxOA. It passed the MIT-IA to 2547psi. Attached is the MIT form. 2) DS 09-20 Produced water only injector. It has an AA due to IAxOA. It passed the MIT . It passed the MIT-IA to 2617psi. Attached is the MIT form. 3) V-105 WAG, Currently on Produced water injection. The MIT performed was inconclusive due to increased injection rate within the first MIT IA testing attempt. The rate was stabilized(choke put in manual)and an attempt to MIT IA three subsequent times was performed with results that appears to be thermal expansion related trends and not communication issues. Attached is the MIT form along with the well service report to provide more clarity. This well is still currently on injection pending your decision. I appreciate the time &patience Bob Noble gave us with allowing the retesting on V-105. Thanks! Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 2 ` S w 3 --Y,6L gerci STATE OF ALASKA rL I ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rega6talaska.00v AOGCC.Inspectors(6/alaska.00v phoebe.brooksCclalaska.aov chris.wallacenalaska.00v OPERATOR: BP Exploration(Alaska),Inc. FIELD/UNIT/PAD: GPB/Prudhoe Bay/V Pad DATE: 02/02/17 OPERATOR REP: Matt Ross AOGCC REP: Bob Noble Well V-105 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2021310 Type Inj W Tubing 1163 1170 1167 1308 1341 1344 Type Test P Packer TVD 6445 BBL Pump 2.5 IA 175 2980 2846 2924 3042 2950 Interval 4 Test psi 1611 BBL Return 2.4 OA 725 755 760 768 778 779 Result I Notes: Maximum wellhead injection pressure last 2 yrs=2366psi.Start test with choke in auto at 26%.Injection rate increaed to 31%during remaining 4minutes of the last 15 of the test.Bleed down IAP. Called PPC&put choke to manual setting of 31%. Well V-105 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2021310 Type Inj W Tubing 1362 1368 1378 1386 Type Test P Packer TVD 6445 BBL Pump 1.0 IA 304 2860 2834 2905 Interval 4 Test psi 1611 BBL Return 2.0 OA 751 782 793 803 Result I Notes: Choke is at 31%(manual) Well V-105 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2021310 Type Inj W Tubing 1389 1392 1395 1399 Type Test P Packer TVD 6445 BBL Pump 1.0 IA 242 2863 2808 2843 Interval 4 • Test psi 1611 BBL Return 2.0 OA 778 800 809 814 Result I Notes: Choke is at 31% (manual) Well V-105 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2021310 Type Inj W Tubing 1405 1412 1411 1415 1418 Type Test P Packer TVD 6445 BBL Pump 2.5 IA 264 2930 2820 2836 2857 Interval 4 Test psi 1611 BBL Return 2.4 OA 413 425 428 431 432 Result I Notes: Choke at 31%(manual).Bled OA from 786psi to 400psi(gas)before starting 4th test. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) 2017-0202_MiT PBU_V-105_4tests_bn.xisx 0 day plot for V-105 i • Well:V-105 TIO Plot 4.00: + 3,500 -200 • Tbg 3.000 f IA 2.500 -150 0 —A -- OA 004 2.000 _100= 0004 1.500 m —On •1.000 _50 • Bleed * Operable _ 111.1.011-_ + Not Oper 11/06/16 11:'20716 12104/16 12/18/16 —01/01/17 01115/17 01129117 • Under Eval Temperature Well:V-106 1.600- '-900 1.400 _800 1.200 [it 700 —WHIP 1.000 —SW a -500 —RAI 840 :400; —Ml 600 m —GI 40: -200 —Ower On 200. -100 y 11106116 11/20/16 12/04/16 1211816 0101/17 01/15.1' 01.2911' lot from1/24/17 to current date(it was P01 1/25/17). Well V-105 TIO Plot 4.000• - 3.500 • Tbg 3:000' - Si IA 2.500. - _ OA 004 2.000- _1 0004 C0 se 1.500-. 3 —on 1.000. -50 Bleed 500 t Operable Y Not Oper 01124./17 01:2617 01'28,17 01'30'17 0201/17 0203117 02/05/17 • Under Eval • Temperature Well V-105 900 1.400: 800 1.200• 700 1.000- - 600 —WHIP —SW c 800. 500 —pW 600- --GI 3 _ _Ower 400 —Oe 200- 100 • 01/24/17 01126/17 01/28/17 01/30/17 02/01/17 02/03/17 02/05/17 he TIO plot data is pulled from operator entries.This data comes off the wellhead (pressures &temps).V-105 is currently off line for Parker 72 to move to its new surface drilling location. 4110 • 6- 1 7 41(3 Well Integrity - PBU V -105 (PTD 2021310) Report and Photos by AOGCC Inspector L. Grimaldi 12/26/2012 Reference: AOGCC hlspection #mitLG121216101256 (12/16/2012) December 16, 2012: While witnessing the mechanical integrity test on water - alternating -gas (WAG) injector PBU V -105 I observed the wellhead jacked out of the conductor approximately 16 inches. The wellhead was visibly pulled backwards by the WAG manifold and flowline. The wellhead could be moved laterally by myself. The weight of the WAG manifold and flowline is tremendous along with thousands of pounds of pressure on the miscible gas injectant and water lines. I gave my business card to Ryan Holt (BPXA DHD Supervisor) and asked him to have the GC -2 Supervisor send me an e -mail with their plan of action to remedy. December 17, 2012: I received a phone call the morning of December 17 from Mr. Richard Faucett (PBU GC -2 Supervisor). He called to tell me how important this was, to assure me that the well has been under the field engineer's watch, and that they are trying to develop a long term strategy to address the concern. He also wanted me to be assured that they would not let the concern slip under the radar and were very serious about this. I finally had to interrupt Richard, rude me, and ask him if BPXA could just send a crew out and put some dunnage under the flow line to get the weight off the wing of the tree. His response was that the engineers will go back out and look at it again and they will do what is necessary — up to and including shutting the well in. I instructed Mr. Faucett to e -mail me with the results of the BPXA engineer's observations. December 25, 2012: The following status update was provided on December 25, 2012 by electronic mail from Mr. Faucett: "I just wanted to follow up with another email regarding subsidence issues at V -pad. We had our Mechanical piping Engineer go out and look at V 105. His assessment was that the s -riser was not in any danger and was not under too much stress. He did recommend that we raise the adjustment on the vsm behind the well house, and to adjust the support jack inside the well house. This will be done tomorrow." Pictures of wellhead as observed on 12/16/2012 are attached SCANNED MAY 3 0 2013 2012- 1226_Tree_PBU_V- 105_Ig.docx Page 1 of 4 • • 4 ., *-* } k} 4 l • S r I ir .1 f '"",, '.... ,01,14400- eam * 0 mom, 4 . z PBU V -105 surface casing hanger approx 16 inches out of conductor landing ring 2012- 1226_Tree_P BU_V- 105_Ig.docx Page 2 of 4 , • • .. Ak -:: _.- ,., . .. ' - . it l t I I 1 , 1 1Li_ 44- 4 i i i .. _ ..,,, 1 r , ..t i i ,, , . — .; ` , A ' '' - too _ t .., \- . , „ — „ -1.- ',„ :I f li . _ v=c * . , . ,.,... �. * ,9 R '� r ''L kY A DIY 'rte Lw. .4....A 4.r. L L ttP ', ... IiiiiiH''- 1IIIII11It' PBU V -105 surface casing hanger approx 16 inches out of conductor landing ring 2012- 1226_Tree_PBU_V- 105_Ig.docx Page 3 of 4 3 ,- y .... -.,, 7 \ t y iiikillk ......,, b■ PP ' 1 10 i •" , lir i t V.../05 , , ir a Cs! I i ... ,,., prii.• f i .a. PBU V -105 leaning 2012 -1226_ Tree _ PBU _V- 105_Ig.docx Page 4 of 4 2k4 6 SCHLUMBERGER STATE OF ALASKA AOGCC ALASKA DATA & CONSULTATION SERVICES W. 7th AVE 2525 GAMBELL STREET, SUITE 400 %AN' JUL ! t 0 3 2013 SUITE 100 ANCHORAGE, AK 99503 -2838 ANCHORAGE, AK 99501 ATTN: STEPHANIE PACILLO ATTN: MAKANA BENDER WELL SERVICE OH RESV CNL LOG DESCRIPTION DATE B/W COLOR CD NAME ORDER # DIST DIST DIST Prints Prints lio 11 -38A B088 -00196 X MEMORY TEMP SURVEY 7- Feb -12 1 1 H -22A BUTT -00059 X MEMORY LEAK DETECT LOG 19- Feb -12 1 1 13 -03A BD88 -00195 X MEMORY PPROF 5- Feb -12 1 1 B -29A BUTT -00061 X MEMORY PPROF 25- Feb -12 1 1 J -26 BAUJ -00111 X MEMORY LEAK DETECT LOG 6- Feb -12 1 1 L4 -18 BBRC -00166 X MEMORY LEAK DETECT LOG 5- Mar -12 1 1 V -105 BAUJ -00109 X MEMORY IPROF 30- Jan -12 1 1 12 -10A BD88 -00202 X MEMORY PPROF 6- Mar -12 1 1 P -15L1 BBSK -00105 X LEAK DETECT LOG 18- Feb -12 1 1 S -05A BD88 -00201 X MEMORY (PROF 17- Feb -12 1 1 Y -19 BINC -00091 X PRIMARY DEPTH CONTROL 9- Jan -12 1 1 P -01A BD88 -00193 X MEMORY DEPTH DETERMINATION 15- Jan -12 1 1 MPJ -11 BAUJ -00100 X MEMORY IPROF 17- Aug -11 1 1 MPL -33 COT4 -00005 X MEMORY IPROF 22- Feb -12 1 1 . -at 0 TRANS #: 5915 �/ DATE: 30- Mar -12 / X X �f Please Return a Signed opy to: G Please Return a Signed Copy to: BP PDC LR2 -1 900 E Benson Blvd Anc AK 99508 DCS 2525 Gambell St Ste 400 Anch AK 99503 04/28/11 Schlumberger NO. 5729 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE ( -y, ^ 0 03/14/11 1 .. 0"/ 1 17 -06 BBKA -00094 INJECTION PROFILE ) „(t ( 'a 03/10/11 1 l 1 C -12B BAUJ -00064 MEM PRODUCTION PROFILE - 03/08/11 1 5► O 1 G -23B BLPO -00079 MEM PRODUCTION PROFILE 4- (. 4 03/09/11 1 � 1 16 -08A BJGT -00022 GLS I C t 'I- ( ?f 03/07/11 1 45; 1 02.188 BLPO -00087 MEM CBL • , - 03/25/11 • ' Z 1 1 J -22A BJGT -00023 CBL •14 - _ 03/10/11 _ _ 1 L -210 BLPO -00086 MEM INJECTION PROFLE ' I 03/23/11 1 • 1 V -105 BLPO-00091 MEM INJECTION PROFLE Tr • � d 1 3 I 03/29/11 1 1 V -220 BBSK -00065 INJECTION PROFILEIWFL � , • 04/11/11 1 F 1 V -212 BD88-00096 MEM INJECTION PROFILE. ,c 04/03/11 1, , 7 ---> L • -214A BCRJ -00073 INJECTION PROFILE " ..Ii - - j 03/18/11 1 1 V -223 BAUJ -00071 MEM INJECTION PROFILE ,• r - r r] l 1 1 V -217 BAUJ -00077 1',Iii•N OIKIitll BrJrie Itt t „ 11117/7/6" 1 3- 05/0 -29 BG4H -00043 i �';LI2[M' 03/20/11 1 r I 1 1- 47A/M -20 BLPO.00092 MEM PRODUCTION PROFILE i r er�S 1 1.25AIK -22 BBSK -00057 IMIIIIIIIL rL I S -01 BCUE -00113 e e1Li r • iWM111111 1 11 -30 BD88 -00097 MEM INJECTION PROFILE "rf r �j� �Jr?,- 1 04 -11A AWJI -00134 INJECTION PROFILE • -warm r iitt%L`; 1 P2 -41 BG4H -00044 PRODUCTION PROFILE g . S '41'15 03/22/11 1 1 D -26B BMSA -00009 SCMT • 03/24/11 3 • ". 1 02 -18B BLPO -00087 MEM PRODUCTION PROFILE - ,i. 03/24/11 1 wer1gi. 1 Z -20 BP5G -00010 GLS i in -(0 0 - 03/29/11 1 6951 1 Y -29A BCUE -00122 MEM LDL i-J ec, r (- 4If 03/20/11 1 a' - 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E Benson Blvd Anchorage, AK 99503 -2838 11 10 SO A STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI1110 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ig CONVERT TO WAG Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ S 202 -1310 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 23097 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028240 . V -105 10. Field /Pool(s): PRUDHOE BAY FIELD / BOREALIS OIL POOL 11. Present Well Condition Summary: Total Depth measured 8255 feet Plugs (measured) None feet true vertical 7135.65 feet Junk (measured) None feet Effective Depth measured 8157 feet Packer (measured) 5211 7555 feet true vertical 7038.75 feet (true vertical) 4273 6445 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface 2944' 9 -5/8" 40# L -80 28 - 2972 28 - 2752 5750 3090 Intermediate 8218' 7" 40# L -80 25 - 8243 25 - 7124 7240 5410 Production Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23 - 5268 23 - 4321 3 -1/2" 9.3# L -80 5268 -7613 4321 -6501 Packers and SSSV (type, measured and true vertical depth) 7" X 4 -1/2" Baker Premier Packer 11241R110 II'? 4273 4 -1/2" X 3 -1/2" Baker S -3 Perm Packer 7555 6445 s JAN 1 ; Z.0 — — 12. Stimulation or cement squeeze summary: summa ECEIVED Intervals treated (measured): DEC 0 7 2010 Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commission Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl / Casing Pressure Tubing pressure Prior to well operation: 1915 2011 Subsequent to operation: SI 14. Attachments: 15. Well Class after work: it Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: f Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed N : • • : Lastu ( Title Data Manager Signatu��I`% Phone 564 -4091 Date 12/7/2010 RBDMS DEC 0 a i 2..1. Form 10 -404 Revised 10/2010 Submit Original Only /2f/� V -105 202 -131 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -105 9/8/02 PER 5,392. 5,424. 4,429.53 4,458.02 V -105 9/8/02 PER 5,466. 5,482. 4,495.67 4,510.07 V -105 9/8/02 PER 5,490. 5,504. 4,517.29 4,529.93 V -105 9/8/02 PER 5,512. 5,534. 4,537.17 4,557.1 V -105 9/8/02 PER 5,576. 5,588. 4,595.14 4,606.02 V -105 9/8/02 PER 5,633. 5,678. 4,646.8 4,687.58 V -105 9/9/02 STC 5,211. 7,555. 4,272.7 6,445.05 V -105 10/28/02 APF 7,800. 7,806. 6,686.33 6,692.24 0 V -105 10/28/02 APF 7,784. 7,794. 6,670.55 6,680.41 V -105 10/28/02 APF 7,754. 7,760. 6,640.95 6,646.87 V -105 10/28/02 APF 7,750. 7,752. 6,637.01 6,638.98 V -105 10/28/02 APF 7,770. 7,780. 6,656.74 6,666.6 V -105 12/1/03 STO 5,211. 7,555. 4,272.7 6,445.05 V -105 3/4/09 BPS 7,581. 7,582. 6,470.59 6,471.57 V -105 3/5/09 BPP 7,581. 7,582. 6,470.59 6,471.57 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED • MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • V -105 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/28/2010' * ** WELL INJECTING ON ARRIVAL * ** (wag swap) LRS FREEZE PROTECTED FLOW LINE AND S- RISER. EQUALIZE AND PULL 3 -1/2" MCX (ser.# NM -302) 7,565' SLM (7,580' BRUSHED 4 -1/2" TBG W/4 -1/2" BLB, 3.75" G -RING, 80 BBLS DIESEL 'BRUSHED 3 -1/2" TBG W/3 -1/2" BLB, 2.70" G -RING, 25 BBLS DIESEL 1***LAY DOWN FOR NIGHT, CONT. WSR ON 11- 29 -10 * ** 11/28/2010 T /I /0= 1150/380/540 Temp =S /I Assist SL as directed. (WAG Swap) RU to S -Riser and pumped 8 bbls 60/40 meth down F/L to the Common Line. S/I LV and opened 'wing. Attempted to pump up S- Riser. S -Riser is frozen. Put heater on S- Riser. RD, RU to P -Sub. Pumped 100 bbls 180* DSL down TBG while S/L RIH for Brush & Flush. RU to S- riser- open WV pumped 1 bbls 60/40 to tree, SI WV -open laterals, pumped 4 bbls 60/40 down FL per WPO request. Valve postition upon departure: SV,WV= closed; SSV,MV,IA,OA =open, operator notified. FWHP's= 1380/380/560 11/29/2010 ** *WSR CONT. FROM 11/28/10 * ** (wag swap) SET X CATCHER SUB @ 7,530' SLM (7,542' MD) PULLED RK -P15 WFR @ 5,296' SLM (5,310' MD) SET RKP MODIFIED NOVA VALVE © 5,310 ' MD ;PULLED X CATCHER SUB @ 7,530' SLM (7,542' MD) SET 3 -1/2" MCX (ser.# MCX346, .625 bear) @ 7,580' MD * * *CONT. WSR ON 11/30/10, PAD OP NOTIFIED * ** 11/30/2010 * ** CONT. WSR FROM 11 -29 -10 * ** (wag swap) 'RUN 3 -11? CHECK -SET TO MCX © 7,567' SLM (7,580' MD) :DRIFT 3.84" NOGO CENT. TO SSSV NIPPLE @ 2,186' SLM (2,208' MD) !SET 4 -1/2" MCX (ser.# M -15, .625 bean) @ 2,197' SLM (2,208' MD) :RUN 4 -1/2" CHECK -SET TO MCX @ 2,197' SLM (2,208' MD) PERFORMED PASSING CLOSURE TEST ON MCX VALVES 1 ** *WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS * ** FLUIDS PUMPED BBLS 12 60/40 106 DIESEL 118 TOTAL TREE= 4- 1/16" C C • I SAFETY OS: I A R FMC V -10 5 ACTUATOR = NA KB. ELEV = 82.3' BF. ELEV = 56.8' - KOP = 1221' imi — 1005' I - I 9 -5/8" TAM PORT COLLAR I Max Angle = 53 @ 3648' Datum MD = 7796' ' I 2208' H4 HES X NIP, ID = 3.813" I Datum 1VD = 6600' SS 9 -5/8" CSG, 40 #, L -80, ID = 8.835" H 2972' I - 4111 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE l 5 4165 3502 51 KBG -2 DMY BK 0 01/11/03 4 4668 3840 43 KBG -2 DMY BK 0 09/10/02 3 5133 4207 34 KBG -2 DMY BK 0 _01/11/03 Minimum ID = 2.813" @ 7542' WATER INJECTION MANDRELS 3 -1/2" HES X NIPPLE ST MD ND DEV TYPE VLV LATCH PORT DATE 2 5310 4358 30 M M G -W P -15 RK 15 10/02/09 1 5371 4411 28 M M G - DMY RK 0 03/05/09 I 5200' -14-1/2" HES X NIP, ID = 3.813" I 2 0 5211' 7" X 4 -1/2" BKR PREMIER PKR, ID = 3.875" I 14 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 5268' 1 I 5268' H4 -1/2" X 3 -112" XO, ID = 2.992" I MI 7542' H 3 -1 /2" HES X NIP, ID = 2.813" 75' I_13 - 1/2" X 4 -1/2" XO, ID = 2.930" 5' H 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 1 1 r 7559' I — I4 - 1/2" X 3 -1/2" XO, ID = 2.940" I 13 -1/2" TBG, 9.2 #, L -80, .0087 bpf, ID = 2.992" H 7612' 7580' H3 -1/2" HES X NIP, ID = 2.813" I 7580' H 3 -1/2" MCX (03/06/09), PERFORAl1ON SUMMARY I 7601' 1_13-1/2" HES X NIP, ID = 2.813" I REF LOG: SWS PEX09/04/02 ANGLE AT TOP PERF: 28 @ 5392' 7613' I- -I3 - 1/2" WLEG, ID = 2.905" I Note: Refer to Production DB for historical perf data I 7611' I — I ELMD TT LOGGED ? ?? I SIZE SPF INTERVAL Opn /Sqz DATE 4 -5/8" r 5 5392 - 5434 0 09/08/02 4 -5/8" ' 5 5466 - 5482 0 09/08/02 4 -5/8" r 5 5490 - 5504 0 09/08/02 I I 7669' H 7 " MARKER JT WI RA TAG I 4 -5/8" r 5 5512 - 5534 0 09/08/02 4 -5/8" r 5 5576 - 5588 0 09/08/02 _ 4 -5/8" r 5 5633 - 5678 0 09/08/02 2 -7/8" r 6 7750 - 7752 0 10/28/02 2 -7/8" r 6 7754 - 7766 0 10/28/02 2 -7/8" r 6 7770 - 7780 0 10/28/02 — 2 -7/8" ► 6 7784 - 7794 0 10/28/02 2 -7/8" F 6 7800 - 7806 0 10/28/02 111 I 7975' H 7" MARKER JT W/ RA TAG I PBTD I--I 8157' I 17" CSG, 26 #, L -80, ID = 6.276" I-1 8243 - 1 ..4 i � i�i � i�i � i * DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 09/10/02 JDM /KK ORIGINAL COMPLETION 1 10/14/09 JLJ /PJC GLV CIO (10/02/09) WELL: V -105 11/17/07 MGS/ PJC PULL XX PLUG /SET MCX (04/24/07) PERMIT No: 2021310 11/21/08 DTR/PJC GLV C/0 API No: 50- 029 - 23097 -00 12/12/08 MBM/SV GLV C/O /SET MCX (12/01/08) SEC 11, T11N, R11E, 4859' NSL & 1692' WEL 03/19/09 MF /SV GLV C/O /RESET MCX (03/06/09) 05/31/09 MBM/TLH GLV C/0 (04/14/09) BP Exploration (Alaska) 10/16/09 Schlumberger, NO. 5418 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2839 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job If Log Description Date BL Color CD P1 -25 AP3G -00063 INJECTION PROFILE 10/0209 1 1 W -01A B2NJ -00026 MEMORYGLS 10/02/09 1 1 12 -06A AZCM -00043 LDL — 10103/09 1 1 W -36 AVIIH -00028 PROD PROFILEW /GL 09129/09 1 1 E -35A B2NJ -00027 MEM CEMENT BOND LOG 10/03/09 1 1 12 -34 AYS4 -00104 INJECTION PROFILE 10/11/09 1 1 Z -07A AYS4 -00101 PRODUCTION PROFILE 10/08/09 1 1 15 -18A B2WY -00015 MEM PROD PROFILE 07/01/09 1 1 05 -18A B04C -00069 SCMT 07/30109 1 1 U -05A B148 -00068 USIT — 09117/09 1 1 P -07A AWJI -00051 MEM P PROFILE 10/09/09 1 1 09 -03 AZCM -00044 PRODUCTION LO210/10/09 1 1 1- 45/0 -26 82NJ -00032 MEM LDL JWJ f 10/10/09 1 1 5 -134 AWLS -00039 USIT _ 61A A 09128/09 1 1 V -105 83SO -00026 [PROF 10/03/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suae 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 i a�49, �! SChlUderger NO Alaska Data Consulting Services Cot 2625 Gambol! Street, Suite 400 i ,f t ZOOS Anchorage, AK 99503 -2838 ATTN: Beth Well Job Log Description Date BL H -26 BOCV -00028 PRODUCTION LOG his .4"+"4 .4"+"4 6f., 3,s 10/06/09 1 12 -31 B14B -00076 INJECTION PROFILE t l"C�a lag —1')( f 3 10/12/09 1 P2 -21 BOCV -00029 PRODUCTION LOG J 9L /.-O 10/07/09 1 12 -35 B2NJ -00029 MEM PROD PROFILE 5 J 6 (n3 10/04/09 1 IP 12 -30 B3SQ -00030 INJECTION PROFILE 0 T,{+ i-2 /U,Q /V T --3- c 10/11/09 1 K -19AL1 B69K -00028 LDL (9()3 9 Q 4 4 10/18/09 1 C -19B B5JN -00016 SCMT,40 6(\ r y56� 10/11/09 V -105 AYS4 -00100 INJECTION PROFILE (Jz oo a -131 'G>S' 10/05/09 1 OWDW -SE B69K -00021 RST J (j P: j 09/23/09 1 OWDW -NW B69K -00022 RST /(Y) -/D (q1, (o 09/24/09 1 OWDW -SW B69K -00023 RST s6�3 S r� 09/25/09 1 ST 04 -26 B5JN -00014 R 6s 09/26/09 1 12 -05A 40015441 OH M D/L D EDIT 003- 07/26/07 2 M -19B 09AKA0028 OH MWD /LWD EDIT ,Qms /9 �S 01/29/09 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: l BP Exploration (Alaska) Inc. I A �l P Petrotechnical Data Center LR2 -1 2' 900 E. Benson Blvd. A • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 `~ ~ ~ a ~:~~~.~~w~~~~` ~`~ ";~ .~ ~' ~~~ ~ bp ~~VG~ V ~~ OCT 0 ~ 2~09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, Ale~ce ~il & Gas Cons. ~~mmi~~~on Anchor~p~ ~p~,- ~31 ~~ 10~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger 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) Date V-pad 8/13/2009 Well Name PTD # API # Initiai top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-Ot 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7i2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA t4.5 7/10/2009 V-1o9 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-t 11 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-t 13 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-1t4A 2031850 5002923178ot00 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9l2009 V-t17 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-201 2012220 500292305a000o SC leak NA 4 NA 90.6 8!7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061500 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7(11l2009 V-2t1 2042200 50029232320000 NA 1.5 NA 13.6 7l10/2009 V-212 2051500 50029232790000 NA 12 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 500292335t0000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA t3.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ",-'~^ 2080200 50029233830000 NA 1.75 NA ~ 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6l29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 ~~~ ~~ ____ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/men Hole/Mechanical Logs and/or Tubing Inspeotion(Caliper/ MI`(7 The technical date listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc ~~ -s,,, ~~ ~,~ ~ . -- Petrotechnical Data Cerrter Attn: Joe Lastuflca LR2-1 900 Benson Bhrd. Anchorage, Alaska 99508 v~ X02 -~ 3 / and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-6952 1) Leak Detection - STf~ 15,Jan-09 V 105 2) Leak Detection - WLD 15-Jart-09 V 105 R Signed . Print Name; I~SS~ !~-5 ~ 1 Color Log / E~ 50-029-23097-00 1 Color Log / EDE 50-029-23097-00 v._ ~ .~. ~ , ~ ~~~. t; r _ Date : ~ ~ a; ;~ ~n~n d~ ~-,~.-~-- --- ~ ~,>o-9... PROACTNE DIAGNOSTIC SERVICES, INC., 730 W. INTERNATIONAL AIRPdRT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~s~sanchora~e~r~era~mr+~9sac~ c~rsl WEBS(iE: wnv~nr.asle~QrJg~~.conra C:lDocoments and Settings\Owner\Desktop\Tcanstnit BP.docx MEMORANDUM To: Jim Re P.I.Supggisor 11~~~~ i~t~~;~~ FROM: Jeff Jones Petroleum Inspector • State of Alaska Alaska OiI and Gas Conservation Commission DATE: Monday, January O5, 2009 SUBJECT: Mechanical Inteo ity Tests BP EXPLORATION (ALASKA) INC V-105 PRUDHOE BAY UN BORE V-105 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN BORE V-105 Insp Num: mitJJ081230101057 Rel Insp Num: API Well Number: 50-029-23097-00-00 Inspector Name: Jeff Jones Permit Number: 202-131-0 Inspection Date: 12/29/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ v-los jType Inj. l w ~ TVD ~ az~3 -~ IA zo ~- aooo '~ 3s6o~ 3aao ' ~ _ -;-- --- P.T. I 2021310 TypC'I`eSt ~ SPT 'l'est pSl ~ - --- 1500 '~ QA 40 ~I 40 ------- ; 40 ~ 40 f - Interval aYRTST p~ P - i Tubing ~; 22~s ~ 22so ----- - - -- --------- zzso zzso ', , I I - - --- ------ - NOteS: 3 BBLS methanol pumped. I well inspected; no exceptions noted. - ---- -- _ ---- i L. :~4': Monday, January O5, 2009 Pale 1 of I 03/13/07 Schlumberger NO. 4179 Schlumberger·DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·2838 A TTN: Beth U:I'O- 8D'd-l3 i Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Borealis Orion Well Job# Log Description Date BL Color CD L·213 11212849 CH EDIT USIT lPDC·GR .. 04/27/06 1 W·204 11630451 CEMENT BOND & IMAGE LOG 02/02/07 1 W·205L2 11626070 RSTIWFL 02/05/07 1 S·213A 11628755 MEMORY GLS 02114107 1 V·105 11626370 IPROFILEIWFL .. 01129107 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Petrotec.hnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508·4254 Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·2838 A TTN: Beth . Date Delivered ~, 'I I"~ ! 11 \ \ ,(.' (,~ ') '¡WI' L LI Received by $CANNS> APR 0 3 i007 (',- \t>' ,-., dDd-- \S\ MECHANICAL INTEGRITY REPORT' ......... :_ ~ G 2 S ~ :: ;_ ~ .:: : OPER & FIELD ß?~ß Ù___~~Q\\S ~~LL NUM:EER \j ~ va 5 .: ? U D G.:". -=-:::: : _::"':ìe-::-: ~~ Shoe: l1D TVD i ?BTD: HD TVD ~ \J~ TVD ; DV: ~O\ \ MD ·TVD 'Ivu; :CF: l·rn --::~,iTJ t TVTI ; Set ê.L: 53<;;) S~~&· S\~ Pe:r.-£3 '\ ~ .s-C) to 'ì~ ~ \l..~f> 'rl t:. LL ù AT .!._ TD: ,lID.. C¿Si~6: '\ \\ Sho e: '6d ~ èill F - ,. "4\J "D'~C"' -, _....J __.::::. J " .5";) \ , P 2. eKe 1:' -:") 55 $'" MD ~-:()le Size ~\/-:J 2.na ~P\ ..r:: ~~;.\ ':T~ ",*"aN,. . .' NED~.¡d ~ '1.007 ~-'::"L.['.r.J.'1~C;'..L INTEGRITY - PART /1 '~v rcyv'" Annulus Press Test: ~~ : 15 Iilin i 30 min Cou.:aents: ...-- Q:.~\\,)c...~ .\:(),~<d t\ \ \ \J ~ dO \ 1\. :-Œ:CHÞ_NICÞ..l INTEGRITY - PART ! 2 ()(J ~ - OJ-\-{ C em en c Volumes:' ÞJIlt 4 ~iner "-J ~ ; Cs g 3S ~\\s; DV <.0 \ b ~ \ S Cillt --/01 to cove:!:" per':s Q ~\)~ 'I..~ ~S ~"\~'~c,·-\L'-.)~ ~ '5 ~ bh\~ ~\~~ \-c <-a..x,-\o~ ~," +SO()' , 'Iheoretical Toe ~ ~'Q(c ~ ~ .~C)\'~ C\q .\\)~51i 3 S ';.J·G bi \o~ "<)c6ð"-\-0t'<> ~S(){) ¢ L\ b.OO ~t~~-Q~ ~1 Cement Bond Log (Yes or No) ''{<t~ i In AO"GCC File ,(c; CBL i::valuation, ;:one ê.Dove perf-S . ~~ \.", Sê)~-<è'-¡:Œ\~~\ (Ä.\')() 0(( r~~ ~t- o~ f~T~<:;' ç; 'œ \0 \.<. , "-' ~\X\ ~~+ P roåuc..tion Log: 'Iyp e Evalua tion . CONC.LUSIOI-!S : r ?ar~ fl: k,~ u..')Ct. ~~Cr-~~.H~\dp; ? ar:: ; 2 : t-'\ \ .l";. \; ~\ ~~j........:- .. - ~~~(¡ç-ù~' ur c...- dO ð- --l3 ( 06/21/06 Scblumþepgep NO. 3862 Schlumberger-DCS 2525 Gambell S~ Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~f_ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Well Job# Log Description Date BL Color CD S-111 11216189 MEMORY INJECTION PROFILE 04/15/06 1 S-114A 10572082 RST UPFLOW WFL 03/01/03 1 V-105 10663005 INJECTION PROFILE 03/12/04 1 E-103 10560276 TEMPERATURE WARM BACK 06/22/03 1 V-214 11162720 UBI 11/24/05 1 V·213 11076450 INJECTION PROFILE 07/01/05 1 V-216 11076451 INJECTION PROFILE 07/02/05 1 V-221 11058523 INJECTION PROFILE 07/03/05 1 L-103 N/A INJECTION PROFILE 07/18/09 1 W-209 11076461 INJECTION PROFILE 08/20/05 1 W-207 10980589 INJECTION PROFILE 07/20/05 1 W-212 N/A INJECTION PROFILE 07/19/05 1 e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotecnnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: (ì..£t Schlumberger-DCS 2525 Gambe" St, Suite 400 Anchorage, AK 99503-2838 A TTN: Betl1 Received by: e RECEJ\/ED JUN 2 3 2006 ~ Oil &: Gas Gens. Commission Anchorage Id- e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm_ Marker.doc Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well E-102 i.<. V ,.4 ~ \a E-102 J",(,¡, 'I -,..\, ~ _ V-105 .l (j J.... - ¡ 3l W-212 :lCl..c.....·'i:'t W-207)Ì[)'~ .. L(; ~ 10708040 10672378 10687690 10679053 10703968 Field: Borealis Midnight Sun Polaris Date BL Color CD 12/10103 05101108 06/26/04 '(;1(... 01/28104 ¡"'ic.. 01/26104 (ft1C. Job# Log Description SBHP SURVEY PPROF W/DEFT/GHOST INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: J ~ 'Mi~ \ SCANNEL SEP () ? 2005 NO. 3462 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 08/30/05 aÐ~-tóJ' -. Schlumberger-DCS 2525 Gambe" St, Suite 400 Anchorage. AK 99503-2838 1 ATTN Beth c--j I (fIll / Received by. ~..- UMÆ/trvI -. MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg "Ke;, Z(~,-::Jùç- P.I. Supervisor (1 1( DATE: Wednesday, January 05, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-I05 PRUDHOE BAY UN BORE V-I05 dÞ:r\ ?JI FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ß-' Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE V-I05 API Well Number: 50-029-23097-00-00 Insp Num: mitLG050102222509 Permit Number: 202-131-0 Rei Insp Num: Inspector Name: Lou Grimaldi Inspection Date: 1/1/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-I05 Type Inj. P TVD 4272 IA 500 4000 3830 3820 P.T. 2021310 TypeTest SPT Test psi 1068 OA 800 820 830 830 Interval OTHER P/F P Tubing 2100 2100 2100 2100 Notes: Pre-MI swap SCANNED MAR 1 4 Z005 Wednesday, January 05, 2005 Page 1 of 1 1 0 D~' À6c\ t..( DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021310 Well Name/No. PRUDHOE BAY UN BORE V-105 Operator BP EXPLORATION (ALASKA) INC MD 8255~' TVD 7136 /' Completion Date 9/10/2002 /' Completion Status WAGIN Current Status WAGIN S(J~ )( (~ API No. 50-029-23097-00-00 /~-:~J,IC;~~ ,,~ REQUIRED INFORMATION Mud Log No Samples No Directional surv~~~ \ "------/ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, DIR, Rap, PWD, RES/AIT, DT/BHC, CNL, LDL, GR, Cailip Well Log Information: Logl Data Digital Type MedlFrmt vtog ~ I/((;;g -lag 4 ..-tog ¿tag A:69 -tog ¡~g LMg C169 75D/-c LJ..øg J..øg , ..cD-:e=-- L°v- v~ Electr Dataset Number, ~me e<:famma Ray vSee Notes Log Log Run Scale Media No 25 Blu 1 c..2'Š BI u vi od<iction/Resistivity - Indl.lr.tio.n/REi'sistivity Casing collar locator - .-Gamma Ray ~roSity -Gamma Ray ~mperature L,Æaliper log 25 Blu ?5 Rill ~I 2 5 Blu 1 25 Blu ~ol 2 ---Col 2 Blu 25 Blu 25 Blu ,:...-8'0 n ic ~ u...--0 vSonic .oA191 See Notes L--Néutron uDensity 11017 ,~ð Þ~etes - 5 Blu 25 Blu Wll~~'::.? '-'-J ~ " ~utron 25 Blu (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 108 8202 ~QO 8356 OHI ~~),,,- Received Comments ~ 11/8/2002 Open 9113/2002 Quad Combo TVDSS Log Platform Express I DSL T . ectional Survey Log is require ~be submitted. This record à 'atically create m Perml Drill ule on: 6/21/2002. 2700 8356 Open t9tf3/2002 2700 8356 Cj:)eM 9/13J2QQ2 DELETE 3400 8120 Open 9/13/2002 ~ 8106 .~^'í2/20/2002 2700 8356 Open 9/13/2002 CBlatform Express I DSL T 3400 8120 Open 9/13/2002 4000 8120 Open 9/13/2002 L-2900 8254 Open 10/25/2002 4Jfatform Express I DSL T t:-2700 8356 Open 9/1.3/2002 l.-fJ1atform Express I DSL T ¿2900 8254 Open 10/25/2002 c.-pratform Express I DSL T 110 8255 ~~1/á/2002 ~editofLWDGR and ROP5 log 2900 8254 Open 10/25/2002 L-Ptãifurm Express I DSL T C290Ô 8254 Open 1 0/25/2002 ~tform Express I DSL T ~LO!L_,~8356_---.-Operr-~-9/-1~/2ðÐ2--~--L13W&Wir$Ae'-~-~~ AIT7PEXfBHG-Gata 2900 8254 Open 1 0/25/2002 ~form Express I DSL T 2N1- ~' ~- DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021310 Well Name/No. PRUDHOE BAY UN BORE V-105 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23097-00-00 MD 8255 ìVD 7136 Completion Date 9/1 0/2002 Completion Status WAGIN Current Status WAGIN UIC Y --1.og -----Gamma'-Ray -'- 25 Diu 108 -8202 Case 11/8/2002- DELETE [/og L-Ðénsity 25 Blu "'2700 8356 Open 9/13/2002 c..J31ãtform Express I DSL T Log Temperature Col 2 3400 8120 Open 9/13/2002 Log Pressure 5 Blu 5100 8106 Case 12/20/2002 ~ L/i'nduction/Resistivity 25 Blu c..296ó 8254 Open 1 0/25/2002 ~orm Express I DSL T .JæQ .-Neutron 25 Blu £/'2700 8356 Open 9/13/2002 ?platform Express I DSL T ~ ~eNotes 2 Blu ~ 8356 Open 9/13/2002 ~rehole Profile Log / latform Express I DSL T ~ C-óensity 5 Blu r-2900 8254 Open 10/25/2002 L---f5Íatform Express I DSL T ßsrñma Ray ~ 46ÕÕ 8120 Open 9/13/2002 vlog ~onic ~Ol 2 ~O 8120 Open 9/13/2002 ~,V ~I Survey ~ 0 8255 Open 10/2/2002 ~ ~ional Survey 1 0 8255 Open 10/2/2002 ~ LfnduCtionÎResistiviiY' 5 Blu ¿29ðÔ 8254 Open 10/25/2002 ¿pfátform Express I DSL T ./ ~utron 25 Blu ~O 8356 Open 9/13/2002 ?-Pfãtform Express I DSL T 1.I::;0g ~ ;¡); 25 Blu ~O 8356 Open 9/13/2002 wfátform Express I DSL T v enslty ;; e-ß'onic Blu / Open \) vJ{) 25 V'270Q 8356 9/13/2002 t.patform Express I DSL T "Log ,§ooic £Gol 4000 8120 Open 9/13/2002 )..6g .-Cásing collar locator ¿,c(5( 4000 8120 Open 9/13/2002 ~~ r~' '''", , ,,' 5,...-------8 I u 2900 8254 Open 1 0/25/2002 Platform Express / DSL T ~C U1248 Density 2834 8206 Open 1 0/25/2002 ~- ~perature ,5 Blu ~ 81 06 ~ 12/20/2002 '\ -ED D Las ""1'2378 Injection Profile 5200 7580 Case 1/20/2004 Injection Profile \ ÆD ~8 Casing collar locator 5200 7580 Case 1/20/2004 Injection Profile D Las V/ ED D Las 12378 Temperature 5200 7580 Case 1/20/2004 Injection Profile ED D Las t 2378 Pressure 5200 7580 Case 1/20/2004 Injection profile -ED D Las 12378 Spinner 1 5200 7580 Case 1/20/2004 Injection Profile aôg ~ection Profile 5 V¡{~ 1 5200 7580 Case 1/20/2004 Injection Profile ~ Injection Profile ~ 1 5200 5800 5/3/2004 INJECTION PROFILE, PRESS- TEMP-CFS- SPINNER '-- ~ DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permitto Drill 2021310 Well Name/No. PRUDHOE BAY UN BORE V-105 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23097-00-00 MD 8255 Well Cores/Samples Information: TVD 7136 Name Well Cored? ADDITIONAL INFORMATION Y/~ Chips Received? ~- Analysis Received? Comments: Y!"'N- Compliance Reviewed By: Completion Date 9/10/2002 Completion Status WAGIN J-~J Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status WAGIN Sample Set Number Comments ~/N f(0N Date: UIC Y '~' / (1 ð?i-m i .~ -"\' STATE OF ALASKA \ ALASKJ-\'6IL AND GAS CONSERVATION corv"vìfsSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator SuspendD Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool ]] 4. Current Well Class: Perforate D WaiverD Stimulate 0 Time Extension 0 Re-enter Suspended WellO 5. Permit to Drill Number: 202-1310 OtherD Name: BP Exploration (Alaska), Inc. Development 0 82.30 8. Property Designation: ADL-0028240 11. Present Well Condition Summary: Stratigraphic 0 9. Well Name and Number: V-105 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool ExploratoryD Service ŒJ 6. API Number 50-029-23097-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 8255 feet true vertical 7135.7 feet Effective Depth measured 8157 feet true vertical 7038.8 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 109 29.0 - 109.0 1490 470 Production 8218 7" 26# L-80 25 - 8243 25.0 - 7123.8 7240 5410 Surface 2944 9-5/8" 40# L-80 28 - 2972 28.0 - 2752.2 5750 3090 Perforation depth: Measured depth: 7750 -7752, 7754 -7760, 7770 -7780, 7784 - 7794, 7800 - 7806 Behind Straddle 5392 - 5434,5466 - 5482,5490 - 5504,5512 - 5534,5576 - 5588,5633 - 5678 True vertical depth: 6637.01 - 6638.98,6640.95 - 6646.87,6656.74 - 6666.6,6670.55 - 6680.41,6686.33 - 6692.24, .A.O. 0 ~ '¡PO/} Behind Straddle 4347.2 - 4384.7,4413.4 - 4427.8,4435.0 - 4447.6,4454.9 - 4474.8,4512.8 - 4523.7,4564.5 - y~ t.~.I .I¡ Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 23 5268 3-1/2" 9.3# L-80 @ 5268 7613 A\a~'ka Oit ,&, Ga~ Packers & SSSV (type & measured depth): 4-1/2" Baker Premier Packer @ 5211 Ant' 4-1/2" Baker S-3 Perm Packer @ 7555 R,ECE ';''i£m;;siOR 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef I Water-Bbl Casing Pressure New Well, No Prior Production 0 13 Prior to well operation: Subsequent to operation: 459 0.23 371 0 Tubing Pressure 0 200 Oil-Bbl 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ) 16. Well Status after proposed work: ~ Operational Shutdown D OilD GasD WAG"'i1~ GINJD WINJŒJ WDSPLD Daily Report of Well Operations, ! Prepared by Garry Catro~) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Garry Catron NI A Printed Name G,ia~ry,r Catron Title Production Technical Assistant Signature p~ ~- Phone 564-4657 Date .,uó.8 Copies of Logs and Surveys run - 3/4/04 RIØIS 8FL OR'G'NAL Form 1 0-404 Revised 12/2003 ') ) V-105 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/28/02 Complete Jewelry log/press/temp log prior to perforation job. 10/28/02 Shoot additional perforations at 77501-775216 SPF, 77541-776016 SPF,77701-77801 6 SPF, 7784'-7794' 6 SPF,78001-7806' 6 SPF. FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL RE(,~ IVED MPj 052004 Oil Cons< Com~:" ).:\ ,\ct!Ofiige: Page 1 sdrealis V-105i comp,et,dn TREE: 4-1/16. - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = 53.8' RKB-MSL = 82.3' . . 4-1/2" 'X' Landing Nipple with 3.813" bore. I 2208' I I 9-5/8", 40 #/ft, L-80, STC j ~ 2972' Gas Lift Mandrels with handling pups installed. L L GAS LIFT MANDRELS # MD Type Valve Type 1 5371' 3-1/2" MMGW Dummy 2 5310' 3-1/2" MMGW Dummy 3 5133' 4-1/2" KSG-2 DCK 4 4668' 4-1/2" KBG-2 Dummy 5 4165' 4-1/2" KSG-2 Dummy I L 7" x 4-1/2" Baker "Premier" Production Packer - 5211' ~IEI ~ 4-1/2"12.6# l-BO, TC-IITubing ~ I 4-1/2" 'X' Landing Nipple with 3.813" bore - 5200' . ---- ----!: 3-1/2" MMGW Water Flood GLM with Injection Valve 3-1/2" 9,3#, L-80, TC-II Tubing below top packer "--- - L 7" 'ES cementer - 6012' ,r 3-1/2" 'X' Landing Nipple with 2,813" bore - 7542' 7" x 4-1/2" Baker "S-3" Packer - 7555' 3-1/2" 'X' Landing Nipple with 2.813" seal bore - 7580' 3-1/2" 'X' Landing Nipple with 2.813" seal bore - 7601' 3-1/2" WireLine Entry Guide -7613' Plug Sack Depth I 7",26 #/ft, L-80, STC-Mod ~ I 8157' ~ 8243' Date Rev By Comments Borealis 7 -8-02 NM Proposed Completion (P4) WELL: V-105i 7-31-02 jdf Proposed Completion (P4) API NO: 50-029-23097 9-09-02 dm Initial Completion BP Alaska . ids CÆJ II. ) WELL, LOG TRANSIVII"AL @Cd-/3/ ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7tt1Street Suite # 700 Anchorage, Alaska 99501 HE: Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton jJeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska),lnc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL MYLAR / BLUE LINE REPORT OR SEPIA PRINT(S) OR CD-ROM FILM COLOR 1 1 1 Open Hole V105-j 12-07-03 Res. Eva!. CH 1 1 1 JC) 3 '13 Mech. CH 1 Caliper Survey Signed: ~0\.~~~~~Q~C'Jy\ Date: R-I:CEIVED Print Name: J.'\N 2 0 2004 ,¡}JækaOiI & Gas Cons. Commilion Anchorage PRoAcTivE DiAGNOSTic SERvicES, INC., PO Box 1 ~b9 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~f\\~ s ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner DATE: February 16, 2003 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder t' n11Vl BPX P.I. Supervisor ~ ~) PBU "" I\~ V Pad FROM: John Crisp V-105 Petroleum Inspector Prudhoe Bay Field NON. CONFIDENTIAL Packer Depth Well V-105 Type Inj. S TV.D. 5211 Tubing P.TD. 2021310 Type test P Test psi 1500 Casing Notes: OA pressure start was 400 - final OA pressure 450 Well Type Inj. T.V.D. Tubing P.T.D. Type test Test psi Casing Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Pretest Initial 15 Min. 30 Min. 1300 1300 1300 1300 Interval I 16502230 2190 2180 P/F f Interval P/F Type Inj. Type test TV.D. Test psi Tubing Casing Interval P/F Type Inj. Type test TV.D. Test psi Tubing Casi ng Interval P/F Type Inj. Type test T.V.D. Test psi Tubing Casing Interval P/F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPX PBU to witness the initia MIT on V-I05. This well was converted from producer to injector. No failures witnessed. M.I.T.'s performed: 1 Attachments: Number of Failures: Q Total Time during tests: 2 hrs. cc: MIT report form 5/12/00 L.G. MIT BPX PBU V-105 02-16-03 JC.xls 2/19/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 12/19/02, Put on Production 1. Status of Well rm 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. Location of well at surface ~-"",~''''f 4859' NSL, 1693' WEL, SEC. 11, T11 N, R11 E, UM ~ l{)C~1~'~ At top of productive interval ij¡Î"'~~'" ' ;f, 1942' NSL, 1190' WEL, SEC. 02, T11 N, R11 E, UM ~ ",,,,,..t' ,J 10. Well Number At total depth 'I ','" ':.:~-'i1) 2804' NSL, 1018' WEL, SEC. 02, T11 N, R11 E, UM :':" ~.1i. ~~~~ -.,'" '"¡'¡:''''--''l''' , 'ICn;! 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 82.3' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/27/2002 9/3/2002 9/10/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8255 7136 Fr 8157 7039 FT rm Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, DIR, ROP, PWD, RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, BHC Sonic, USIT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 91.5# H-40 Surface 108' 42" ~60 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 2972' 12-1/4" 488 sx PF 'L', 293 sx Class 'G' 7" 26# L-80 25' 8243' 8-3/411 171 sx Class 'G', 304 sx Class 'G' t ) ) Classification of Service Well Pre-Produced Injector (About 10 Full Days) 7. Permit Number 202-131 8. API Number 50- 029-23097-00 9. Unit or Lease Name Prudhoe Bay Unit V-105i 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2208' MD 1900' (Approx.) 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf 2-7/8" Gun Diameter, 6 spf MD TVD MD TVD 5392' - 5434' 4430' - 4467' 7750' - 7752' 6637' - 6639' 5466' - 5482' 4496' - 4510' 7754' -7766' 6641' - 6653' 5490' - 5504' 4517' - 4530' 7770' -7780' 6657' - 6667' 5512' - 5534' 4537' - 4557' 7784' - 7794' 6671' - 6680' 5576' - 5588' 4595' - 4606' 7800' - 7806' 6686' - 6692' 5633' - 5678' 4647' - 4699 25. SIZE 4-1/2", 12.6#, L-80 3-1/211,9.2#, L-80 AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 5268' 5268' - 7613' PACKER SET (MD) 5211' 7555' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2800' Freeze Protect with 95 Bbls of Diesel 27. Date First Production Novewmber 20, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SttrtTV E D No core samples were taken. DEC ? ':) v 28. ~BOMS BFl Form 10-407 Rev. 07-01-80 DEC 1 9 2002 Alaska Oil & Gas Cons. Commission Anchorage Submit In Duplicate ) '~ 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Schrader 81uff N Sands 5206' 4269' Schrader Bluff 0 Sands 5392' 4430' Base 08f I Top Colville 5803' 4801' HRZ 7440 6332' Kalubik 7651' 6539' Kuparuk D 7740' 6627' Kuparuk C 7748' 6635' Kuparuk B 7876' 6762' Kuparuk A 7995' 6879' Miluveach 8060' 6943' ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECEIVED DEC 1 9 2002 31. list of Attachments: Alaska Oil & Gas Cons. Commission Summary of Daily Drilling Reports and Post Rig Work, Surveys Am;hurage 32. I ~erebY certify that the foyoin~ is true and correct to the best of my knowledge Signed TerrieHubble '1~~ Title Technical Assistant Date ) ~"'(9"'~ V-105i 202-131 Prepared By NameINumber: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: NeH Magee, 564-5119 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: Ifthis 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 form tor 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 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 I\. Well: Field: API: Permit: ) ') V -1 05i Prudhoe Bay Unit 50-029-23097 -00 202-131 Rig Accept: 08/27/02 Rig Spud: 08/27/02 Rig Release: 09/10/02 Drilling Rig: Nabors 9ES POST RIG WORK 09/16/02 PULL BALL & ROD. PULL RHC-M PLUG BODY. PULL DGLV-BK FROM STA-3. PULL SHEAR VLV FROM STA-1. INSTALL BOREALIS GLV DESIGN. DRIFT 2-1/2" D-GUN TO 8165' MD CORR. WELL TO REMAIN SI. 1 0/28/02 COMPLETE JEWELRY LOG, PRESSURE / TEMP LOG PRIOR TO PERF. PERF 40 FT 2.52506 POWERJET @ 6 SPF, 60 DEG PHASING, 10 DEG OFF BTM. TAGGED @ 8106. PERF INTERVALS ARE (7750 TO 7752), (7754 TO 7766), (7770 TO 7780), (7784 TO 7794), (7800 TO 7806). BOTTOM STICKY. WELL TURNED BACK TO PAD OP. WELL LEFT SHUT IN. 11/19/02 PUMP 5 BBLS NEAT, 100 BBLS DIESEL HOT, 30 BBLS NEAT WARM TO POP WELL. 11/23/02 T/I/0=300/860/100 (IA FL FOR GLE) GAS RATE 2.0, IA FL @ 5133'. Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# V-105 ..:1();).-/3L L-108 .~Dd- 10'1 1-108 V-109 alB -õlOri. JEWELRY LOG/GRlPRESS JEWELRY LOG/PSP LDUPSP 22501 USIT Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Jnc, Petrotectnical Data Center LRZ-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: RECEIVED DEC 1 0 2002 Alaska Oi1 & Gas Cons. Commission Anchorage 10/28/02 10/29/02 11/03/02 10/28/02 12/10/02 NO. 2590 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color BL CD Sepia 2 SchJumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth ~ Iì Receive~~~ ~' SchlulD~erger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well V-105 ~O!"'131 V-105 V-105 Job# Log Description 22467 OH EDIT GR & ROP5 22467 MD CDR-GR 22467 TVD CDR-GR PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: Rt:CEIVED NOV 08 2002 Alaska a~ & Gas Cons. Commission Anchorage 09/03/02 09/03/02 09/03/02 11/05/02 NO. 2532 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color CD Sepia BL ~' Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 :~:~~ ~' aca - / 8C'o dOdJ/5/ a~-ltj:2 Schlum~ergel' Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth V-103 V-105 V-105 V-105 V-105 V-105 V-105 'v-104 V-104 V-104 V-104 V-104 V-104 Well Job# Log Description 22466 USIT 22419 OH PEX AIT/BHC SONIC/DEN/NEUTRON 22419 PEX RESISTIVITY 22419 PEX SONIC 22419, PEX NEUTRON/DENSITY 22419 PEX RES/NET/DEN/SONIC LOGS 22419 PEX CALIPER 22394 OH EDIT AIT/BHC SONIC/PEX NEUTRON/DEN 22394 PEX RESISTIVITY 22394 PEX BHC SONIC 22394 PEX NEUTRON/DENSITY 22394 PEX TRIPLE COMBO & SONIC 22394 PEX CALIPER PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: RECE\VED OCT 25 2002 Alaska Oil &. = CommiaeiOR 10/05/02 09/04/02 09/04/02 09/04/02 09/04102 09/04/02 09/04/02 08/23/02 08/23/02 08/23/02 08/23/02 08/23/02 08/23/02 NO. 2491 10/17/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis P. Bay Date Color Sepia 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth R.~ BL CD ~/ . G C1op~ ~ ÿJ6~ 1~~t~~/o ~ ~z..ö /0/'5'/0"7.- 0/5 /fJ/3/ 4: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Pre-Producer Alter casing - Repair well - Converted to Inject Change approved program- 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 421' FNL, 1691' FEL, Sec. 11, T11N, R11 E, UM At top of productive interval 3337' FNL, 1190' FEL, SEC 02, T11 N, R11 E, UM At effective depth 2489' FNL, 1019' FEL, Sec. 02, T11 N, R11 E, UM At total depth 2475' FNL, 1018' FEL, See 02 T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 108' 20" Surface 2944' 9-5/8" Production 8218' 7" Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 590609, 5970107) (asp's 591080, 597476) (asp's 591240, 5973326) (asp's 591240, 5973340) 8255 feet 7136 feet 8157 feet 7039 feet Plugs (measured) Junk (measured) Re-enter suspended well - Pre-Producer Converted Time extension - Stimulate - /' to Injector Variance - Perforate.¿" Other _X ./' 6. Datum elevation (OF or KB feet) RKB 82.3 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number V-105 9. Permit number I approval number 202-131 10. API number 50-029-23097 -00 11. Field I Pool Prudhoe Bay Field / Borealis Pool Measured Depth 136' 2972' True vertical Depth 136' 2752' Cemented 260 sx ArcticSet (Approx) 488 sx PF 'L', 293 sx Class 'G' 171 sx Class 'G', 304 sx Class 'G' 8243' 7124' measured Open Perf 5&5434" 5466'-5482', 5490'-5504', 5512'-5534', 5576'-5588',5633'-5678' true vertical Open Perfs 4430'-4467',4496'-4510',4517'-4530', 4537'-4557', 4595'-4606', 4647'-4699' Perforation depth: Tubing (size, grade, and measured depth 4-1/2" 12.6# L-80 TBG @ 5268'. 4-1/2" x 3-1/2" XO @ 5268'. 3-1/2" 9.2# L-80 TBG @ 5268'. 3-1/2" x 4-1/2" XO @ 7553'. 4-1/2" 12.6# L-80 TBG @ 7559'. 4-1/2" x 3-1/2" XO @ 7612'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 5211' MD. 7" x 4-1/2" Baker S-3 Packer @ 7555' MD. 4-1/2" HES 'X' Nipple @ 2208'. n f'! r r:- J V E D 13. Attachments Description summary of proposal _X Detailed operations program - BOP~eL:~t 14. Estimated date for commencing operation 15. Status of well classification as: November, 2002 16. If proposal was verbally approved OCT 2 1 2002 Suspended - Alaskl on & a'l Cons. Commillíor, Name of approver Date approved Service WATER INJECTOR Anehofl{fe 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Bruce W. Smith @ 564-5093. Si9nedBr~uce w, S~ml'th .-J ~ ~ ~ Title: Borealis Development Petroleum Engineer Date October 18.2002 ~. Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - .BFP Test - Location clearance- Mechanical Integrity Test ~ Subsequent form required 10- MIT ye1~~-,d . Approved by order of the Commission Form 1 0-403 Rev 06/15/88 . Oil- 00glnal Signed By Cammy Qechslí T ayla«' Gas- 407 I Approval no. .3O'Ä-3:3'2) Commissioner f°J.~' /D~ Date SUBMIT IN TRIPLICATE bp ( . October 18, 2002 "t~11. ~~~ ~~. 1- -~. w~..~...~. "J'~\" BP Exploration (Alaska) Inc, 900 East Benson Boulevard P, 0, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for V-1 05 Conversion from Pre-Produced Injector to Water Injector (Kuparuk 'c' Sands) BP Exploration Alaska, Inc. proposes to convert well V-105 from a pre-produced injection well to an active water injector as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: 1. S Drift, run initial Borealis GL design, place MEOH in IA. 2. E Jewelry log 3. E Perforate 401 (Bottom shot @ 78061MD) / 4. 0 Hot Oil Well simultaneously to POP 5. S Run Static Survey MITIA to 4000 psig. / Last test: Max Deviation: Perf deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Wellböre Fluids: BHT & BHP: Reference Log: Note: New completion, never tested. 53° @ 3648' MD 10° @ 7795' MD 2.813"XN nipple @ 7542' MD None initial entry None initial entry Not tested (new well). Offset well V-101 '0' ppm 9/01/02. Freeze protected tubing & IA to 3500' with diesel. , L-105 158°F & 2250 psia @ 6600' TVDSS Schlumberger PEX Sept. 04, 2002 Simops on QoinQ Construction. drillinQ. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW @BP.com ( Slickline: 1. Drift using 20 ft+--2.5" dummy gun drift run (min 2.77 inch) to TD, Run initial Borealis gas lift design for pre-produced injector. (4-1/2 design, 1400 BOFPD expected, 1.8 MMSCF), Pump 30 bbls of Neat MEOH into IA once GL design is complete, take returns down flowline. Leave Neat MEOH in IA for POP later. E-Line: 2. Run Jewelry Log (GR-CCL-Temp) from PBTD (8157') to 5100' MD. Oewelry over lowest GLM (5133)) . Reference Log Schlumberger PEX 04-Sept-02. . Let Temp log stablize in sump for 20 min minimum. 3. Perf Kuparuk C4 & C2 from 7806-7800, 7794-7784, 7780-7770, 7766- 7754 and 7752-7750 MD, 40 ft net, 235 shots 30 ft gun with GR and SAFE has total length of 45.5 ft. . 2 1/2" Hollow steel carrier. 2506 PJ, HMX , 6 SPF, 0 60° phasing, oriented +/-10 deg off bottom 0 EHD 0.32" & TTP 25.2", swell 2.66 inch.. . Record before and after each run WHPIWHT/IAP/OAP number of shots fired. Note any indication of low order detonation, charge type, phasing and oriention. Hot Oiler: 4. POP well as soon as possible. . CRITICAL ISSUE: . Open lateral valve and wing valve, Pump 100 BBLs heated diesel, followed by 30 bbls warm Neat MEOH down IA. 5. Immediately place well on gas lifted production. (POP well). Start with 2.0 mmscf/d GL. Test Mother Well prior to POP, Test V-1 05i as soon as possible, solo. Late into test, pull samples from separator, send to Lab; pull oil sample from oil leg of separator, test for Oil Grav (Carl Fisher), pull sample from up stream of separator for water cut. Re test combined with Mother well and V-105i. Back to back if possible. Slickline: 6. (Slickline or E-line) Run Static Survey with pressure gauges and 2 spun down calibrated MRT's. Stops at 7897md/ 6700 tvd, 7795 md/6600 tvd . and 7694 md/6500 tvd. Once Static survey is complete, place 30 bbls Neat MEOH into IA prior to bring well back on. Return well to Production as soon as possible. Sincerely, þ~~~~ Bruce W. Smith GPB Borealis Development Engineer .~. ..."f.'1 -.....~ ~.,- ..~,.. ~-- .'.i~~.\'" ". Well: Date: bp ( PERFORATING PROCEDURE API #: 50-029-23097-00 ..,.........................,...,.............. Prod Engr ..~~~,~.~..yy':..,~~,i,~~....,... Office Ph:,.........................,??~,:?9~~,...,.........,..,..,...... Home Ph: 345-2948 "'I'I""""'J"""""'''''''''''''''''....n...................",,-.-,- CelUPager: "....",.............".~~,Q:~.Q~~.............."......... CC or AFC: 5m4092 Detail Code: 9335-070-770 Description::Þ.BI~Tç9J0.~Çgf:(QNTE:~.!3.~...""..".......,,,,,......:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::."".."..........'''''''''''''''''''''''''''''''''''''''''''''''''''''''''' WBL Entries Work Desciption V-105i "H....,....................................................... 9/24/02 -'-'0'-"'''''''''''''',-""",,,,,,,,,,,,,,,,,,,,,,,,,,,,......' lOR Type E version micky !f H2~ Level: No Data - new well ' Jewelry log & perforate 40' (Bottom shot 7806 ') Well Objectives and Logging Notes: Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: .P..~~................... ..""........~"...."",,... *Not Logged Yet Date: 9/4/2002 Company: :~~b!~ii):þ.~ige~:::::::::::::::::::::::::::::: Depths (from-to) Depths (from-to) ".......?'!~Q,§~........ - ......,7.!?'.Q~t...., "'"'''''''''''''''''''''''''' - ,....................,.....,.., ".."...Z.!Z~:~E"...." - .""..?,!Zê4~...". """""''''''''''''''''''''' - .....................,,,,,,,... """".Z.!Z§.9:"...... - ."""?'.\ZZQ~...,,, ,,,,,..,,......,,,,,,,,,,.....' - """".................."... f:;~~: :::iJ2 ............................... : ................................ Gas Jetting Expe . ' ......."""~g..........,,, Feet ,,2.. 10 10 12 2 Add/Subtract to the tie-in lõ'g.'tõ"be"öiï"'''''''''''''''''''' depth with the reference log. SPF Orient. .........~,....... 1 0..9.~,9..9ftþtm """J?"....., 1 0..9.~9..9ff..þtm """".§"...... 1 O,.9.~.g"Qff..Þ,tm ,,,,,.JL.,,.. 1 °..9~,g"Q!f..þ,tm ......JL...., 1 °..9~,g.g!f..þ,tm At what Depth? Requested Gun Size: 21/2 Charge: 2506 PJ HMX ''''''''''''''''''Deslred Penetration: ................??:,?........,....... Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check wi Pad Operator to see if necessary piping is installed) (e,g, N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) Tie in to Jewelry @ Minimum ID: Tail Depth: MD .....""....."................ 2.813 in :::::::::?§:t~:::::::::: ft MD Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ Last Tag: ........,D2D,~""".... ft MD on new well ""'....................,-..... Perforation Summary Well: Date: V-105i N_-W""___M'___W__.W API#: 50-029-23097-00 ''''''''''''''..",,,,,,.,,,...... "-'0'-"""""""""""""""'-"""""""".." General Comments: feet Phasing ............"......,§Q.~,..................., 60° '"''''''''''''''''''60';;''''''''''''''''''''' :::::::::::::::::::::~Q~::::::::::::::::::::: .........,....,......~Q,~..................... Zone Ad/Re/lperf C I """'°",-..........,.,..........,...,-,................"J"""'" C I ,.,.....,<><>...,.....,.....,..~."...>... ..,.................,.,<,. C I ,.,...,.,.......,...........",...,.,.,.,...,.,.....,.,.,.,...,.,.,. C I """'''''''''''.-,-.....................,........,-,.............. C I """'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' N/A Under Balanced .>...,.,.>.....,<...<,...,.,.,.,.,...............,.,.,.,.,...........,.........,.................,.,.,...,.....,...............,...........",.,..<,..<,.....,.............. Entry Hole Diam: ,.........Q:~?'......... ..~,~~..!!~!..f!9.~,~~!.I..~g..þ~,~..Q~YJ4.?Q?T.YPt9.P~!:!..~,~,I.I..19..f!9.~!!~~!..~~9.9.t.9. will provide approx 600-1000 psi underbalanced. ,E~f~~~Dg,~..!9.9......,,,,,........,....,........,,......................................"'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' ....,.......,......."......"""....~..!:!!p.p.!.~.....,,,.,........,,.,,,...,...,,,,,,, @ ...?!.?4.?... 'MD 7 in ::::::f!~~:::::: MD is 2400 psi "",."",.,...,.,.......". Summary Dist Town: Prod Engr: Anch Prod Engr """""""'"'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' P. D. Center Phasing ,,,,,,,,,,'..,, '''''''''''.'''''' """""...,"'",.."'",,,,, PBTD ""'"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''...,.,.""..,..."..,..,..,.....,.....,..,.....,.",.,.",.".....,"""'"'''''''''''''''''''''''''''''''''''''''''''''''''''''''''',..,..,..,..,..""""...""".........,....",,,.,,,..,,.,.,,,'..""''''''''''''''''''.'''''''",,,,,,,,,,,, Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. Orient. SPF """..."",..,,,......,,...,,,,,,,,,,..................',,,,,,,,,,'..,,.,.,,,,,...,,,,.......,""'"'''''''''''''''.''''''''''''''''''''''''''''''''''''''''''''''''''''..'''''''''''''''",,,,,,.,,,.,,,,,...,,,,,,,,,.....,...,,..,,,,,,...,....,,.,...,,,,,,,,,,,...,.,,,,,.'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''.''''''''''''''''''''""'''''''''''''' Zone Aperf/Reperf ....""......""...."",...",,,, ...."",...,..... "'"".... ,,,,,,.... ",...,,,,,.,...,,,,,,,,,,........., ,.,,,,,,,,,,,,,,,,,,,,""'.,,,,,,,"', 00 00 0 "",.."""....,..."..,..",,,...,,,..,..,,,,..,,,,,...,,,,,.,,,..,....""',.,,,"''''''. ""'''''''''''''''''''''''''''''''"''''''''''''''''''''''''',,,,,,,,,,,.,,,-,,,,... "'.''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''""".". \ TREE = 4-1/16" CrN WELLHEA 0 = FWC AClUATOFf;------ NA KB -:EL'È\! -;;--'-----8-i.3ï SF :'ELEV-;-~------"-56.8' KOP-;;------'~ 'MiXÃñgîe~53^@ 3648' --- Datum fv[) = "^""~~~~~~.~-,^"""""",,",,.....,,"^,",,,,,,^,,, Datum TV 0 = 8800' SS 9-5/8" CSG, 40#, L-80, 10 = 8.835" H 2972' ~ Minimum ID = 2.813" @ 7542' 3-1/2" HES X NIPPLE 1 4-1/2" TBG, 12.6#, L-80, ,0152 bpf, 10 = 3.958" H 5268' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, [) = 2,992" 1 3-1/2"TBG, 9.2#, L-80, .0087 bpf, 10 =2.992" H 7612' PERFORATION SUMrvIA RY RB= LOG: ANGLE AT TOP PERF: 28 @ 5392' t\bte: Refer to A'oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA TE 4-5/8" 5 5392 - 5434 0 09/10/02 4-5/8" 5 5466 - 5482 0 09/10/02 4-5/8" 5 5490 - 5504 0 09/10/02 4-5/8" 5 5512 - 5534 0 09/10/02 4-5/8" 5 5576 - 5588 0 09/10/02 4-5/8" 5 5633 - 5678 0 09/10/02 1 FBTD H 8157' 17" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 8243' DA TE RE\! BY COMMENTS 09/10102 JDM/KK ORIGINAL COMPLETON 10/15102 TI-VKAK PERF DEPlH CORREcrlON V -1 05 = ( SAFETY NOTES: GLM'S @ STA #1 & #2 ARE 3-1/2" X 1-1/2" MfIIG-Ws, WHICH ARE W A TERFLOOD MA. NDR8..S. :~ 1005' H 9-5/8" TAM PORT COlLAR I 1 2208' H 4-1/2" I-ES X NIP, 10 = 3.813" I I I ~ ST MD TVD DE\! TYPE VL V LA Ta-J PORT DATE L 5 4165 3502 51 KBG-2 DOME BK-5 16 09/16/02 4 4668 3855 43 KBG-2 av1Y BK-5 0 09/10/02 3 5133 4207 34 KBG-2 SO BK-5 20 09/16/02 W A TERFLOOD rvIA NDR8..S ST MD TVD DE\! TYPE VL V LA Ta-J PORT DATE 2 5310 4358 30 rvTv1G- W av1Y RK 0 09/10/02 1 5371 4411 28 rvTv1G- W av1Y RK 0 09/10/02 I I :8: ~ ---'= ~ . . ~ DA TE REV BY COMMENTS 5200' H 4-1/2" I-ESX NIP, 10 =3.813" I 5211' H 7" X4-1/2" BKR FREMERPKR, D =3.875" I 5268' H 4-1/2"X 3-1/2" XO,ID =2.992"1 7542' 7553' 7555' 7559' 7580' 7601' 7613' H 3-1/2" HES X NIP, 10 = 2.813" I H 3-1/2" X 4-1/2" XO, 10= 2.930"1 H 7" X4-1/2" BKR &3 A<R, 10= 3.875" I H 4-1/2" X 3-1/2" XO, 10 = 2.940"1 H 3-1/2" HES X NIP, 10 = 2.813" I H 3-1/2" HESX NIP, 10 =2.813" I H 3-1/2" WLEG,ID =2.905" 1 7669' I~ 7' rvlARKERJTW/ RA TAG I 7975' H 7" rvlARKERJTW/ RA TAG I GPB BOREALIS WELL: V-105 PERMT t\b: 2021310 AR No: 50-029-23097-00 4859' NSL, 1692' WEL, SEC. 11, T11N, R11E BP Exploration (Alaska) ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned a Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L~~~~~~~[,~~~~~ ~~~~~EC. 11, T11 N, R11 E, UM ~--'" ~,."~.t'~}ii'.~ Jl~~' :ÄtIDf~išI At top of productive interval ~ :l~2ë£:..t22J ,r, " ¡ 1Ãiî~~~àè~t~90'WEL, SEC. 02, T11N, R11E, UM L v~ J i~:~ 10. Well Number 2804' NSL, 1018' WEL, SEC. 02, T11 N, R11 E, UM i,':~",..~:~'(a;$ -.~~-",""".! 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 82.3' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/27/2002 9/312002 9/10/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8255 7136 FT 8157 7039 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, DIR, ROP, PWD, RES 1 AIT, DT 1 BHC, CNL, LDL, GR, Caliper, SP, MRES, BHC Sonic, US IT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 2011 91.5# H-40 Surface 108' 4211 260 sx Arctic Set (Approx.) 9-5/811 40# L-80 28' 2972' 12-1/4" 488 sx PF 'L', 293 sx Class 'G' 711 26# L-80 25' 8243' 8-3/411 171 sx Class 'G', 304 sx Class 'G' Classification of Service Well Water & Gas Injector 7. Permit Number 202-131 8. API Number 50- 029-23097-00 9. Unit or Lease Name Prudhoe Bay Unit V-105i 11. Field and Pool Prudhoe Bay Field 1 Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2208' MD 1900' (Approx.) 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/811 Gun Diameter, 5 spf MD TVD 5392' - 5434' 4430' - 4467' 5466' - 5482' 4496' - 4510' 5490' - 5504' 4517' - 4530' 5512' - 5534' 4537' - 4557' 5576' - 5588' 4595' - 4606' 5633' - 5678' 4647' - 4699 25. MD TVD SIZE 4-1/211, 12.6#, L-80 3-1/211,9.2#, L-80 AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 5268' 5268' - 7613' PACKER SET (MD) 5211' 7555' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2800' Freeze Protect with 95 Bbls of Diesel Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oNf-rW, î:,t",e,r. VsubEm, ", itDcore chips. No core samples were taken. K C \.. tJ ' 26. 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-MCF WATER-BBL OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) OCT 2 I 2002 ORIGINAl OCT 15 2002 RBDMS BFL Alaska OIi&Sas Gone. GamIDIIs.IDn Ancftoran ,.... GI~ Form 10-407 Rev. 07-01-80 Submit In Duplicate (' 29. Geologic Markers Marker Name Measured Depth Schrader Bluff N Sands 5206' Schrader Bluff 0 Sands 5392' Base OBf / Top Colville 5803' HRZ 7440 Kalubik 7651' Kuparuk D 7740' Kuparuk C 7748' Kuparuk B 7876' Kuparuk A 7995' Miluveach 8060' 31. List of Attachments: ( 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4269' 4430' 4801' 6332' 6539' 6627' 6635' 6762' 6879' 6943' Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin~ is true and correct to the best of my knowledge Signed Terrie Hubble /fßJV\J.L ~ Title Technical Assistant Date D-l<5"O~ V-105i 202-131 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Neil Magee, 564-5119 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 form 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 (DF, 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 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 Legal Name: V-105 Common Name: V-105 Test Date 8/31/2002 Test Type LOT Test Depth (TMD) 3,007.0 (ft) BP AMERICA Leak-Off Test Summary Test Depth (TVD) 2,751.0 (ft) AMW 9.70 (ppg) Surface Pressure 375 (psi) Leak Off Pressure (BHP) 1 761 (psi) Page 1 of 1 EMW 12.32 (ppg) >~ Printed: 9/25/2002 4: 12: 19 PM BP AMERICA Operations Summary Report Page 1 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-105 V-105 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9ES 8/27/2002 Spud Date: 8/27/2002 End: Date Ftöm ~T () Hours" Task Code NPT Phase DØ~cription9f QÞØréltions 8/27/2002 03:00 - 06:30 3,50 MOB P PRE MOVE SHOP & PITS. MOVE RIG FROM V-1 04i & SPOT SUB, 06:30 - 08:30 2.00 RIGU P PRE SPOT PITS, HOOK UP ALL LlNES@ INTERCONNECT.. SPOT SHOP & CUTTINGS TANK. RIG ACCEPTED @ 0830 HRS, 8/27/02. 08:30 - 13:30 5.00 RIGU P PRE MIU RISER & DRESSER SLEEVE. MIX MUD. 13:30 - 16:00 2.50 RIGU P PRE TAKE DIVERTER LINE APART & RERIG LINE w/o 45 DEG BEND AS PER AOGCC REP. 16:00 - 16:30 0.50 BOPSUR P PRE P/U 1 JT HWDP & FUNCTION TEST DIVERTER SYSTEM. TEST WITNESSED BY LOU GRIMALDI wI AOGCC. 16:30 - 17:30 1.00 RIGU P PRE P/U JARS & DRILL COLLARS & STAND BACK IN DERICK. 17:30 - 18:30 1.00 RIGU P PRE CLEAR & CLEAN RIG FLOOR AFTER MOVE & RIG UP. 18:30 - 19:30 1.00 RIGU P PRE MIU BHA #1 ORIENT & TEST MOTOR. 19:30 - 20:00 0.50 RIGU P PRE FILL HOLE & CIRCULATE. CHECK SYSTEM FOR LEAKS. 20:00 - 20:30 0.50 RIGU P PRE HOLD PRE-SPUD MEETING WI ALL HANDS. 20:30 - 21 :00 0.50 DRILL P SURF MIU STAND DCs, CHECK MWD. RIH & WASH DOWN & TAG CMT @ 108'. 21 :00 - 23:00 2,00 DRILL P SURF SPUD WELL. DRILL FROM 108' TO 353', 23:00 - 23:30 0.50 DRILL P SURF POOH w/2 STANDS, MIU JAR STAND & RIH. 23:30 - 00:00 0.50 DRILL P SURF CON'T TO DIRECTIONALL Y DRILL fl 353 TO 386'. P/U 60K, SIO 60K. TORO OFF 700, ON 1600, 680GPM @ 1350 PSI. 8/28/2002 00:00 - 08:30 8.50 DRILL P SURF DIRECTIONAL Y DRILL FROM 386 TO 1467'. P/U 84K, SIO 69K, ROT 76K. 230 SPM, 650 GPM, 2100 PSI ON, 1900 PSI OFF. 80 RPM, TORO ON 3.5K, TORO OFF 1.8K, WOB 40K. AST 3.7 HRS, ART 2.7 HRS. 08:30 - 09:00 0.50 DRILL P SURF CIRCULATE SWEEP AROUND @ DRILLING RATE & CLEAN HOLE. 09:00 - 10:30 1.50 DRILL P SURF MONITOR WELL. POOH FOR BIT @ 1467'. P/U 93K, SIO 69K. 10:30 - 11 :00 0.50 DRILL P SURF CHANGE OUT BIT. CLEAR & CLEAN FLOOR. 11 :00 - 12:30 1.50 DRILL P SURF TRIP IN HOLE TO 1374'. FILL PIPE. WASH TO BOTTOM @ 1467', NO FILL. 12:30 - 20:00 7.50 DRILL P SURF DIRECTIONAL Y DRILL FROM 1467 TO 2987'. (CSG PT) SLIDE 1/2 OF EVERY STAND, TO BUILD ANGLE. 650 GPM, 3200 PSI, TORO ON 6.5K, TORO OFF 3K. 20:00 - 21 :00 1.00 DRILL P SURF CIRCULATE 2 BOTTOMS UP & CLEAN HOLE @ DRILLING RATE. 21 :00 - 21 :30 0.50 DRILL P SURF POOH TO 2800'. STARTED SWABBING & PULLING TIGHT, 21 :30 - 00:00 2.50 DRILL P SURF MIU TOP DRIVE & BREAK CIRCULATION. START BACKREAMING FROM 2800 TO 1700'. ATTEMPT TO POOH w/o PUMP, 8/29/2002 00:00 - 01 :00 1.00 DRILL P SURF CONTINUE POH TO 1200' DRY. STARTING TO SWAB AND PULL TO 30K OVER. 01 :00 - 01 :30 0.50 DRILL P SURF BREAK CIRC & CBU @ 650 GPM. CIRC HOLE CLEAN - OK. 01 :30 - 02:00 0,50 DRILL P SURF CO NT POH TO 600'. 02:00 - 03:30 1.50 DRILL P SURF RIH & WORK PAST OBSTRUCTION AT 950'. RIH TO 1800'- TOOK WEIGHT. REAM 1 STAND DOWN THEN RIH TO 2900' -OK. 03:30 - 05:00 1.50 DRILL P SURF REAM LAST STAND DOWN TO 2987'. CBU X3 AT 680 GPM. CLEAN HOLE & COND MUD TO 9.8 PPG, FV 250. SO & MONITOR WELL - OK. 05:00 - 06:30 1,50 DRILL P SURF POH FOR 9 5/8" CASING. NO OVER PULLS OR SWABBING - HOLE CONDITION GOOD. 06:30 - 08:00 1.50 DRILL P SURF LD BHA. Printed: 9/25/2002 4:12:26 PM ( BP AMERICA Operations Summary Report Page 2 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 05 V-105 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9ES 8/27/2002 Spud Date: 8/27/2002 End: Date From.. To Hours Task Code NPT Phase Description ofOþerations 8/29/2002 08:00 - 10:30 2,50 CASE P SURF CLEAR FLOOR. MAKE DUMMY RUN WITH HANGER AND LANDING JT. CHG BAILS. RU FRANKS TOOL & CASING EQUIPMENT. 10:30 - 11 :00 0.50 CASE P SURF PJSM WITH ALL HANDS + ANCH DE. 11 :00 - 15:00 4.00 CASE P SURF RUN 72 JTS 9 5/8" 68# L-80 CASING WITH SHOE AT 2972' MD. 100K ON. 160K UP. NO PROBLEMS RUNNING CASING. 15:00 - 15:30 0.50 CEMT P SURF MU CEMENT HEAD & CEMENT LINES. 15:30 - 18:00 2.50 CEMT P SURF BREAK CIRC. STAGE RATE UP TO 8.5 BPM @ 600 PSI. CIRC & COND MUD. SPOT CEMENTERS AND TRUCKS FOR CEMENT JOB. 18:00 - 21:30 3.50 CEMT P SURF HOLD PJSM. PUMP 5 BBLS WATER & TEST LINES TO 3500 PSI, OK. PUMP 15 BBLS WATER FOLLOWED BY 75 BBLS ALPHA SPACER MIXED @ 10.5 PPG. MIX & PUMP 360 BBLS OF PERMAFROST "L" CMT @ 10.7 PPG. YLD 4.6 CUFT/SX. TAIL IN WI 60 BBLS PREMIUM "G" WI 2% CaCI2 @ 15.8 PPG, YLD 1,15 CUFT/SX. DROP PLUG & DISPLACE WI 10 BBLS WATER + 209 BBLS MUD, DISPLACE AT 8 BPM @ 600-1100 PSI. LOST RETURNS WI 30 BBLS TO GO ON DISPLACEMENT. REDUCE TO 4 BPM & BUMPED PLUG TO 1200 PSI. FLOAT HELD, HAD 50 BBLS OF CEMENT RETURNS TO SURFACE. PD. @ 2110 HRS. HOLE STAYED FULL. 21 :30 - 22:30 1.00 CEMT P SURF RID CEMENTING HEAD & BACK OUT LANDING Jr. FLUSH OUT SURF EQUIP. CLEAR & CLEAN FLOOR. 22:30 - 23:30 1.00 CEMT P SURF RID CASING TOOLS & CHANGE BAILS, 23:30 - 00:00 0.50 CEMT P SURF CLEAN OUT DRIP PAN UNDER ROTARY TABLE WI SUPER SUCKER. 8/30/2002 00:00 - 03:00 3.00 DIVRTR P PROD1 N/D DIVERTER SYSTEM. NIU 16" BOOT. 03:00 - 04:30 1.50 WHSUR P PROD1 NIU FMC GEN 5 LOWER SPLIT UNIHEAD. & TEST METAL TO METAL SEAL TO 1000 PSI, FOR 10 MIN, OK. 04:30 - 07:30 3.00 BOPSURP PROD1 NIU 135/8" BOP STACK & INSTALL 2nd ANNULAR VALVE. NIU ALL LINES & HOSES. 07:30 - 08:00 0,50 BOPSUR P PROD1 MIU JOHNNY WACKER & FLUSH OUT BOP STACK, 08:00 - 12:00 4,00 BOPSUR P PROD1 RlU TEST EQUIP & TEST BOPE & RELATED SURFACE EQUIP. LP 250 PSI, HP 4000 PSI. ANNULAR HP 3500 PSI.. WITNESSING OF TEST WAIVED BY JEFF JONES WI AOGCC. 12:00 - 12:30 0.50 WHSUR P PROD1 RID TEST EQUIP. BLEED DOWN ALL LINES. INSTALL WEAR BUSHING. 12:30 - 17:30 5,00 DRILL P PROD1 P/U 111 JTS DP RIH & STAND BACK IN DERRICK 17:30 - 18:30 1.00 DRILL P PROD1 P/U BHA# 3 AS PER DIRECTIONAL DRILLER. 18:30 - 21 :00 2.50 DRILL N DPRB PROD1 ATTEMPT to RIH WI BHA. BHA #3 WOULD ONLY GO IN 32'. ATTEMPT TO WORK THRU TIGHT SPOT, NO GO. BIT APPEARS TO HANG UP @ BOTTOM OF 4' PUP BELOW HANGER. STRAIGHTEN MOTOR & ATTEMPT RIH, WOULD NO GO. ATTEMPT RIHWI 8.75" TRI-CONE BIT, NO GO. 21 :00 - 22:00 1.00 DRILL N DPRB PROD1 HOLE PJSM. NID BOP STACK & STAND BACK. 22:00 - 23:00 1.00 DRILL N DPRB PROD1 INSPECT CASING & HANGER. NO OBVIOUS OBSTRUCTION OR DAMAGE NOTICEABLE. MIU BHA WI 8.5" BIT & MOTOR. RUN THRU HANGER & THRU 1 st CONNECTION OFJT#72 & CSG HANGER, OK. CONFER WITH ANCH DE & DECIDE TO SWITCH TO 8 1/2" BIT + BHA TO DRILL NEXT HOLE SECTION. Printed: 9/25/2002 4:12:26 PM BP'AMERICA Page.30f9 OperatioASS.Umma.ry.,Report Legal Well Name: V-1 05 Common Well Name: V-105 Spud Date: 8/27/2002 Event Name: DRILL +COMPLETE Start: 8/27/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 9ES Rig Number: 9ES Date F"Øm~ To HOurs Task Code" NPT pèscriþtiQn oJ OþèratiohS 8/30/2002 23:00 - 00:00 1,00 DRILL N DPRB PROD1 NIU BOP STACK. 8/31/2002 00:00 - 01 :00 1.00 DRILL N DPRB PROD1 FINISH NIU BOP STACK. TEST BREAK. LP 250 PSI, HP 4000 PSI. 01 :00 - 02:30 1.50 DRILL P PROD1 CHANGE OUT STABILIZER BLADE TO 8.5". MIU BHA #4. RIH. 02:30 - 03:00 0.50 DRILL P PROD1 P/U SINGLE JTS OF DP & RIH TO BELOW TAM COLLAR. 03:00 - 03:30 0.50 CASE P PROD1 PRESSURE TEST TAM COLLAR & CSG TO 1000 PSI, OK. 03:30 - 04:00 0.50 DRILL P PROD1 P/U SINGLES & RIH. 04:00 - 05:00 1.00 DRILL P PROD1 CUT & SLIP 60' OF DRILLING LINE. INSPECT & ADJUST BRAKES. 05:00 - 06:00 1,00 DRILL P PROD1 SERVICE TOP DRIVE & CROWN. CLEAN UNDER DRAWWORKS, CHANGE OUT LOWER SAFETY VALVE ON TOP DRIVE & TEST SAME. 06:00 - 07:00 1.00 DRILL P PROD1 CON'T TO P/U SINGLES & RIH TO 2789'. FILL PIPE & BREAK CIRCULATION. 07:00 - 08:00 1,00 CASE P PROD1 PRESSURE TEST 9 5/8" CASING TO 3500 PSI FOR 30 MIN & CHART SAME. TEST OK. 08:00 - 10:00 2.00 DRILL P PROD1 WASH DOWN TO 2888' & TAG FLOAT COLLAR. DRILL OUT SHOE TRACK. CLEAN OUT RATHOLE & DRILL 20' OF NEW HOLE TO 3007'. 220SPM, 550 GPM, 1910 PSI, TORO 3.5K, 50 RPM, WOB 0-5K. 10:00 - 11 :00 1.00 DRILL P PROD1 CIRCULATE OUT SPUD MUD & REPLACE WI 9.7 PPG LSND MUD SYSTEM. PULL UP INTO CSG. 11 :00 - 11 :30 0.50 DRILL P PROD1 CONDUCT LOT TO 12.3 PPG EMW - (375 PSI OVER 9.7 PPG MUD). 11 :30 - 12:00 0.50 DRILL P PROD1 CIRCULATE & OBTAIN BENCHMARK ECD READINGS WI PWD TOOL. 12:00 - 20:30 8.50 DRILL P PROD1 DRILL FROM 3007 TO 4283'. P/U 120K, SIO 80K, ROT 95K. 598 GPM, TORO ON 8K, TORO OFF 5K. 80 RPM. AST .3. ART 2.43 20:30 - 21 :30 1.00 DRILL P PROD1 CIRCULATE & PUMP LO-HI SWEEP, ECD 11.24 PPG EMW. 21 :30 - 00:00 2.50 DRILL P PROD1 WIPER TRIP TO 3080', PULLED TO 25K OVER COMING OFF BOTTOM. HOLE SWABBING, RIH TO BOTTOM & BACK REAM TO SHOE. ECD CLIMBING. PUMP SWEEPS & POOH SLOWLY TO CONTROL ECD. 9/1/2002 00:00 - 03:00 3.00 DRILL P PROD1 CON'T TO BACKREAM @ 550 GPM, 2000 PSI, 100 RPM, TORO 4K, ROT 85K. POOH SLOWLY TO KEEP ECD WITHIN ACCEPTABLE PARAMETERS. CIRC HI-VIS SWEEPS TO CLEAN HOLE & REDUCE ECD. 03:00 - 03:30 0.50 DRILL P PROD1 PULL UP INTO CSG @ 2971' CIRCULATE SWEEP & CLEAN HOLE. 03:30 - 04:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE & CROWN. 04:00 - 04:30 0.50 DRILL P PROD1 RIH TO 4188'. HOLE IN GOOD SHAPE. 04:30 - 10:30 6.00 DRILL P PROD1 MIU TOP DRIVE, FILL DP, & REAM LAST STAND TO BOTTOM. STAGED UP PUMPS. DRILL AHEAD FROM 4281 TO 5215'. 598 GPM, 3200 PSI ON, 2880 PSI OFF, 80 RPM, WOB 10-20K, TORO ON 6-7K, TORO OFF 5.3K. P/U 142K, SIO 94K, ROT 111 K. AST 1.55 HRS, ART 2.39 HRS. 10:30 - 11 :00 0.50 DRILL P PROD1 CIRCULATE & OBTAIN BENCHMARK ECDs. 11 :00 - 15:00 4.00 DRILL P PROD1 DRILL FROM 5215 TO 5681'.600 GPM, 3365 PSI ON, TORO ON 6-8K, TORO OFF 6K, P/U 148K, SIO 103K, ROT 120K, ACT. ECD 11,14 PPG EMW. 15:00 - 16:30 1.50 DRILL P PROD1 SURVEY, PUMP LO-HI SWEEP. CALC ECD 10.59, ACT ECD Printed: 9/25/2002 4:12:26 PM BPAMERICA Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 05 V-105 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9ES 8/27/2002 Spud Date: 8/27/2002 End: Date Fröm-To Hours Task Code NPT Phase DescriptiÖnof qperatipns 9/1/2002 15:00 - 16:30 1,50 DRILL P PROD1 10.9. 16:30 - 19:00 2.50 DRILL P PROD1 MONITOR WELL. POH FI WIPER TRIP. HAD INTERMTTENT DRAG FI 5588 TO 4562'. WORK PIPE THRU WITH OVERPULLS TO 30KLBS. HOLE GOOD FI 4562 TO 4096', P/U 150K, SIO 95K. 19:00 - 19:30 0.50 DRILL P PROD1 RUN BACK TO BOTTOM, NO PROBLEM. 19:30 - 20:00 0.50 DRILL P PROD1 BREAK CIRCULATION, STAGE UP PUMPS & PUMP LO-HI SWEEP. ECD 10.76 PPG EMW. 20:00 - 00:00 4.00 DRILL P PROD1 CON'T DRILLING AHEAD FI 5681 TO 5962'. P/U 150K, SIO 95K, ROT 121K. 240 SPM, 600 GPM, 3370 PSI, TORQ ON 6-7K, TORQ OFF 6K. ART 3.55, AST .65 9/2/2002 00:00 - 08:30 8.50 DRILL P PROD1 DRILL AHEAD TO 6865' MD. 600 GPM @ 3710 PSI ON I 3390 PSI OFF BTM. 100 RPM. 20K WOB. START ADDING WEIGHTED "SPIKE FLUID" TO BRING MUD WEIGHT UP TO 10,1 PPG, 08:30 - 10:00 1,50 DRILL N FLUD PROD1 CIRC AND COND MUD TO BRING RHEOLOGY DOWN. SPIKE FLUID WAS BUILT FROM A USED MUD SYSTEM AND MUD RHEOLOGY CLIMBED SEVERELY WHEN THIS WAS ADDED TO THE ACTIVE SYSTEM. 10:00 - 13:30 3.50 DRILL P PROD1 DRILL AHEAD TO 7175' MD. 590 GPM @ 4090 PSI ON BTM PRESSURE. ECD 10.95 PPG CALC VS 11.5 PPG MEASURED, 13:30 - 15:00 1.50 DRILL P PROD1 CIRC HOLE CLEAN PRIOR TO SHORT TRIP BEFORE DRILLING INTO HRZ. ECD 10.95 PPG CALC VS 11.2 PPG MEASURED PRIOR TO STARTING OUT OF HOLE. 15:00 - 17:30 2.50 DRILL P PROD1 POOH fl 7175 TO 6523'. NO PROBLEMS, HAD INTERMITTENT DRAG & SWABBING fl 6523 TO 5775'. CON'T POOH fl 5775 TO 5588', HOLE GOOD. P/U 180K, SIO 115K. 17:30 - 19:00 1.50 DRILL P PROD1 TIH SLOWLY DUE TO HIGH GEL STRENGTHS. 19:00 - 20:30 1.50 DRILL P PROD1 STAGE UP PUMPS. CIRCULATE & CONDITION MUD DUE TO HIGH GEL STRENGTHS. REDUCE ECD TO 11.14, 20:30 - 00:00 3,50 DRILL P PROD1 DRILL fl 7175 TO 7453', P/U 185K, SIO 110K, ROT 141 K,237 SPM, 597 GPM, 4145 PSI, TORQ ON 7-9K, TORQ OFF 8K. CALC ECD 10.89, ACT ECD 11.14. ART 4.1 HRS. 9/3/2002 00:00 - 09:30 9.50 DRILL P PROD1 DIRECTIONAL DRILL WI 1.15 DEGREE ABH AND SURVEY WI MWD-GR-PWD FI 7453' - 8255', 218K UP, 127K DN, 158K RTWT, 236 SPM, 4150 PSI ON, 3825 PSI OFF, 592 GPM, 100 RPM, 10.5K TQ ON, 10K TQ OFF, ECD 11.28 PPG, ART 7.3 HRS, AST 0 HRS 09:30 - 11 :00 1.50 DRILL P PROD1 CIRC AND COND MUD, ADD 250 BBLS OF 10.1 PPG NEW MUD TO SYSTEM, PUMPED HI VIS SWEEP AROUND AT 596 GPM, 3600 PSI, 110 RPM, 9.6 K TQ UP; 480 GPM, 2400PSI, 110 RPM, 9K TQ DN, ECD 11.08 PPG 11 :00 - 16:00 5.00 DRILL P PROD1 MONITOR WELL, STABLE, PUMP DRY JOB, POH TO SHOE. INTERMITTENT DRAG FI 7820' TO 7650' OF 20 - 30 K OVERPULL, TIGHT HOLE FI 3260' TO 2972' WI 20 - 25 K OVERPULL, WELL SWABBING, WORK THROUGH SAME, OK, UP WT 230K, DN WT 129 K 16:00 - 17:00 1,00 DRILL P PROD1 CBU'S AT 2971' 17:00 - 19:00 2,00 DRILL P PROD1 PJSM, SERVICE TOP DRIVE, CUT AND SLIP 35' OF DRILLING LINE, ADJUST BRAKES 19:00 - 20:00 1.00 DRILL P PROD1 TIH, WORKED THROUGH TIGHT HOLE FI 2971' TO 3360' WI Printed: 9/25/2002 4:12:26 PM ( ( BP AMERICA Operations Summary Report Page 5 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-105 V-105 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9ES 8/27/2002 Spud Date: 8/27/2002 End: Date Ftötn';Tö Hours Task Code NPT Phase pe$criPtipnofQperé3tiöns 9/3/2002 19:00 - 20:00 1,00 DRILL P PROD1 DOWN DRAG OF 25 - 35K 20:00 - 20:30 0,50 DRILL P PROD1 WASH AND REAM, WORKING THROUGH TIGHT HOLE FI 3360' TO 3411' 20:30 - 21 :00 0.50 DRILL P PROD1 RIH TO 4625', OK 21 :00 - 21 :30 0.50 DRILL P PROD1 BREAK CIRC AT 4625',250 GPM, 800 PSI 21 :30 - 22:30 1.00 DRILL P PROD1 RIH TO 6399', SLOWLY, MONITORING RETURNS 22:30 - 23:00 0.50 DRILL P PROD1 BREAK CIRC AT 6399',250 GPM, 930 PSI 23:00 - 00:00 1.00 DRILL P PROD1 RIH TO 8170', SLOWLY, MONITORING RETURNS 9/4/2002 00:00 - 00:30 0.50 DRILL P PROD1 PRECAUTIONARY WASHING AND REAMING FI 8170' - 8255', NO FILL 00:30 - 03:00 2.50 DRILL P PROD1 CIRC HOLE CLEAN WI LO - HI VIS SWEEP, ECD 11.2 PPG, SPOT 175 BBLS OF 10.1 PPG MUD WI 2 DRUMS OF EZ GLIDE LUBE PILL FI 8255' TO 6000' 03:00 - 04:00 1.00 DRILL P PROD1 POH, WORKED PIPE THROUGH TIGHT HOLE FI 8170'. 7791', WITH 45 - 65K OVERPULL 04:00 - 04:30 0,50 DRILL P PROD1 RIH TO BOTTOM AT 8255' 04:30 - 06:00 1.50 DRILL P PROD1 BREAK CIRC SLOWLY, STAGING PUMPS UP FI 120 TO 595 GPM AT 3650 PSI, 112 RPM, SWEEPING HOLE CLEAN WITH HI-VIS PILL 06:00 - 08:30 2,50 DRILL P PROD1 MONITOR WELL. POH SLOW TO AVOID SWABBING. PULLS TO 35-50K OVER FROM 8015'.7735'. WORK ONE SPOT SEVERAL TIMES AT 7820' TO GET PAST. CONTINUE POH TO 5960' - NO PROBLEM ABOVE 7735'. 08:30 - 09:00 0.50 DRILL P PROD1 BREAK CIRC AND STAGE PUMPS UP TO 590 GPM, SPOT STEEL SEAL PILL UP TO CASING SHOE FROM 5960'. 09:00 - 11 :00 2.00 DRILL P PROD1 CONTINUE POH TO 3350' - OK. WANTING TO SWAB ABOVE THIS. RUN STAND BACK DOWN TO 3350', 11 :00 - 12:30 1.50 DRILL P PROD1 BACKREAM FI 3350' TO 9 5/8" CASING SHOE AT 2971' WI 160 SPM, 1150 PSI, 397 GPM, 100 RPM TO PREVENT SWABBING AND PULLING HOLE IN BEHIND BIT. NO OVERPULL OR TIGHT HOLE. 12:30 - 14:00 1,50 DRILL P PROD1 CBU'S, 160 SPM, 1150 PSI, 397 GPM, ECD 11.6 -11.4 PPG. INCR RATE TO 580 GPM ROTATING AT 110 RPMTO CLEAN UP CASING. 14:00 - 15:30 1.50 DRILL P PROD1 POH TO BHA 15:30 - 17:00 1.50 DRILL P PROD1 STD BACK 4" HWDP, LD DC'S, MWD-LWD, STAB, MOTOR, AND BIT 17:00 - 17:30 0.50 DRILL P PROD1 CLEAR AND CLEAN RIG FLOOR OF BHA 17:30 - 19:00 1.50 EVAL P PROD1 PJSM, RU E-LlNE, PU, CALIBRATE PEX/DIPOLE SONIC, LOAD SOURCE 19:00 - 20:00 1.00 EVAL P PROD1 RIH WI PEXlDIPOLE SONIC, LOGGED DOWN WI GR-RES FI 2900' TO 8254' ELM 20:00 - 23:00 3.00 EVAL P PROD1 LOG UP FI 8254' TO 7700', REPEAT LOG FI 8210' TO 2900', POH, LD LOGGING TOOLS, RD E-LlNE 23:00 - 00:00 1.00 CASE P PROD1 PULL WEAR RING, WAS PACKOFF WI DRILL CUTTINGS, FLUSH BOPS WI JOHNNY WHACKER 9/5/2002 00:00 - 01 :30 1.50 CASE P COMP INSTALL TEST PLUG, CIO TOP RAMS TO 7", VOLUME TEST STACK AGAINST ANNULAR TO 250 - 3500PSI, 5 MINUTES, PULL TEST PLUG 01 :30 - 02:00 0.50 CASE P COMP MAKE DUMMY RUN WI CASING HANGER AND LANDING JOINT, LAND IN CASING HEAD, CIO TO 15' BAILS 02:00 - 03:00 1,00 CASE P COMP RU CASING HANDLING TOOLS, POWER TONGS AND UNIT 03:00 - 03:30 0,50 CASE P COMP PJSM ON 7" CASING JOB WITH ALL INVOLVED Printed: 9/25/2002 4:12:26 PM ( ( BP AMERICA Operations 'Summary Report Page 6 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-105 V-105 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9ES 8/27/2002 Spud Date: 8/27/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/512002 03:00 - 03:30 0.50 CASE P COMP PERSONNEL 03:30 - 04:00 0,50 CASE P COMP MU AND BAKERLOC SHOE TRACK, RU FRANKS FILL-UP TOOL, CIRC THROUGH FLOAT EQUIPMENT 04:00 - 09:00 5.00 CASE P COMP PU, RIH WI 7" 26# L-80 BTC-M CASING TO 9 5/8" SHOE AT 2972', UP WT 109K, ON WT 90K, WITHOUT PUMP; MU TORQUE TO TRIANGLE, AVG TORQUE 9000 FTLBS, FILL EVERY JT, BRK CIRC FOR 5 MIN EVERY 15 JTS, DOPED CASING WI BEST-O-LlFE 2000 NM 09:00 - 09:30 0.50 CASE P COMP CIRC 1.5 TIMES ANNULAR VOLUME, STAGE PUMP UP SLOWLY TO 6 BPM, 325 PSI, RECIPROCATE CASING 09:30 - 00:00 14.50 CASE P COMP PU, RIH WI 7" 26# L-80 BTC-M CASING TO 7493', UP WT 275K, ON WT 120K, WITH PUMP AT 68 SPM, 685 PSI; MU TORQUE TO TRIANGLE, AVG TORQUE 9000 FTLBS, FILL EVERY JT, BRK CIRC FOR 5 MIN EVERY 15 JTS, CBU'S EVERY 30 JTS; DOPED CASING WI BEST-O-LlFE 2000 NM, LOST 12 BBLS TO HOLE 9/6/2002 00:00 - 01 :00 1.00 CASE P COMP PU, RIH WI 203 JOINTS OF 7" 26# L-80 BTC-M CASING, MU AND LAND 7" CASING HANGER, FLOAT SHOE AT 8242', FLOAT COLLAR AT 8199', LANDING COLLAR AT 8157', AND ES CEMENTER AT 6011', MU TORQUE TO TRIANGLE A VG 9000 FTLB, ALL 7" CASING TUBULARS WERE DRIFTED TO 6.151", FILL EVERY JT, DOPED CASING WI BEST-O-LlFE 2000 NM 01 :00 - 01 :30 0.50 CASE P COMP RD FRANKS FILL-UP TOOL, RU CEMENT HEAD AND LINES 01 :30 - 02:30 1.00 CEMT P COMP BRK CIRC SLOWLY, STAGE UP PUMPS TO 7 BPM AT 922 PSI, RECIPROCATING CASING, UP WT 265K, ON WT 130K 02:30 - 05:00 2.50 CEMT P COMP PJSM, CIRC AND RECIPROCATING PIPE AT 8242' WI 7 BPM, 922 PSI, 298 GPM WHILE BATCH MIXING CEMENT 05:00 - 05:30 0.50 CEMT P COMP PUMP CEMENT JOB AS FOLLOWS WI HES: 5 BBLS OF H2O, TEST LINES TO 4000 PSI, LOAD BTM DART, 5 BBLS OF H2O, 35 BBLS OF 11.1 PPG ALPHA SPACER AT 3.5 BPM 400 PSI, DROP BTM DART, 35 BBLS (170 SX) OF 15.8 PPG 1.16 YIELD OF CLASS "G" CEMENT WI 2 GPS LATEX-2000, .36 GPS HALAD 434B, .05 GPS D-AIR 3000L, .4 BWOC CFR-3, AT 4 BPM 650 PSI, FLUSH OUT CEMENT LINE THROUGH TEE WI FW. 05:30 - 06:45 1.25 CEMT P COMP LOAD AND DROP TOP DART, RIG DISPLACED WELL WI 10.1 PPG MUD AT 7 BPM @ 590 PSI. SLOW DISPLACEMENT TO 2 BPM @ 290 BBL AWAY. BUMP PLUG WITH 312 BBL AS CALC AND 1500 PSI- OK. RECIPROCATE PIPE THROUGHOUT JOB. CIP 06:35 HRS. NO LOSSES DURING JOB. BLEED OFF PRESSURE - FLOATS HOLDING. 06:45 - 07:30 0.75 CEMT P COMP LOAD ES CEMENTER CLOSING PLUG. PRESSURE UP AND OPEN CEMENTER WITH 3100 PSI. BREAK CIRC AND CBU AT 7 BPM @ 575 PSI- NO LOSSES. 07:30 - 08:00 0.50 CEMT P COMP PUMP 5 BBL WATER. TEST LINES TO 4500 PSI. PUMP 5 BBL WATER FOLLOWED BY 35 BBL ALPHA SPACER AT 10.5 PPG. MIX & PUMP 300 SX (69 BBL) CLASS G WITH CALSEAL - 4 BPM @ 300 PSI. WEIGHT 15.6 PPG. 08:00 - 08:45 0.75 CEMT P COMP RELEASE CLOSING PLUG AND PUMP 5 BBL WATER FROM HOWCO TO CLEAR LINES. SWITCH TO RIG PUMP AND DISPLACE WITH 225 BBL MUD -7 BPM INITIAL RATE Printed: 9/25/2002 4:12:26 PM BP AMERICA Operations Summary Rep.ort Page 7 of 9 Legal Well Name: V-1 05 Common Well Name: V-105 Spud Date: 8/27/2002 Event Name: DRILL +COMPLETE Start: 8/27/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 9ES Rig Number: 9ES Date From;,; To Hours Task Code NPT Phase 9/612002 08:00 - 08:45 0.75 CEMT P CaMP REDUCING TO 6.5 BPM AFTER 85 BBL AWAY (SLIGHT LOSS). BUMP PLUG AS CALCULATED, CIP AT 0845 HRS. 08:45 - 09:00 0.25 CEMT P CaMP PRESSURE UP TO 2250 PSI AND HOLD FOR 5 MIN TO CLOSE ES CEMENTER. BLEED OFF PRESSURE AND CHECK FOR FLOWBACK - NONE. RD CEMENT LINES AND HEAD. 09:00 - 10:00 1.00 CEMT P CaMP RD CEMENT HEAD, LD LANDING JOINT, RD CASING HANDLING EQUIPMENT 10:00 - 11 :00 1.00 WHSUR P CaMP MU, INSTALL 7" PACKOFF, RILDS, TEST TO 5000 PSI 10 MINUTES 11 :00 - 12:00 1.00 BOPSURP CaMP CHANGE OUT TOP RAMS TO 3.5 " X 6" VBR'S 12:00 - 15:30 3.50 BOPSUR P CaMP RU, TEST BOPE'S AS PER SOP, TEST ALL LINES, VALVES AND RAMS FI 250 - 4000 PSI FOR 5 MINS EACH, ANNULAR PREVENTER FI 250 -3500 PSI FOR 5 MINS EACH, RD. CHUCK SHEEVE WI AOGCC WAIVED WITNESSING BOP TEST 15:30 - 16:30 1.00 CLEAN P CaMP MU CLEANOUT BHA, RIH 16:30 - 19:00 2.50 CLEAN P CaMP RIH WI BHA ON 4" DP TO 5988' 19:00 - 19:30 0.50 CLEAN P CaMP DRILL CMT AND ES CEMENTER FI 5988 TO 6012',227 SPM, 3650 PSI, 558 GPM, UP WT 135 K, ON WT 75 K 19:30 - 20:30 1.00 CLEAN P CaMP RIH TO 8156, TAG UP ON PBTD, TEST CSG TO 1000 PSI, OK 20:30 - 22:00 1.50 CLEAN P CaMP CIRC 50 BBLS 8.4 PPG KCL WATER WI DIRT MAGNET, 100 BBLS OF 8.4 PPG KCL, 35 BBL BARAZAN SWEEP, FOLLOWED WI 370 BBLS OF 8.4 PPG KCL, CIRC HOLE CLEAN 22:00 - 23:00 1.00 CLEAN P CaMP REVERSE CIRC 271 BBLS OF 8,9 PPG KCL BRINE AROUND AT 180 SPM, 2980 PSI, 440 GPM 23:00 - 23:30 0.50 CLEAN P CaMP CLEAN UNDER SHAKERS, TAKE ON REMAINING BRINE 23:30 - 00:00 0.50 CLEAN P CaMP MONITOR WELL, STABLE, POH 9/7/2002 00:00 - 00:30 0.50 CLEAN P COMP POH TO 5801' 00:30 - 01 :00 0.50 CLEAN P CaMP SPOT 35 BBL 8.9 PPG KCL PERF PILL FI 5801' TO 5400' 01 :00 - 03:00 2.00 CLEAN P CaMP POH TO BHA 03:00 - 04:30 1.50 CLEAN P CaMP STAND BACK HWDP, LD JAR, BIT AND BOOT BASKETS, CLEAN OUT SAME, RECOVERED VERY LITTLE JUNK 04:30 - 10:00 5.50 EVAL P CaMP PJSM, RU E-LlNE, PU USIT LOGGING TOOL, SURFACE CALIBRATE AND FUNCTION TOOLS, RIH, LOG ON TO 8120', LOG UP FI 8120' TO 3960', POH, LD TOOLS, RD E-LlNE EQUIPMENT, CLEARED FLOOR. NOTE: WHILE LOGGING INJECTED 20 BBLS OF MUD DOWN 7" X 9 5/8" ANNULUS AT 1 BPM 675 PSI. LOT = 14.8 PPG EMW. 10:00 - 11 :00 1.00 CASE P CaMP RU, TEST 7" CSG TO 4000 PSI FOR 30 MINUTES, OK. 11 :00 - 12:00 1.00 PERF P CaMP LOAD 4 5/8" PERF GUN ASSY IN PIPE SHED, BRING EQUIPMENT AND TOOLS TO RIG FLOOR 12:00 - 15:30 3.50 EVAL P CaMP MU BIT, BOOT BASKETS, AND SCRAPER, RIH TO 8157' 15:30 - 16:00 0.50 EVAL P CaMP SERVICE TOP DRIVE AND CROWN 16:00 - 17:00 1.00 EVAL P CaMP SWEEP HOLE WI 25 BBLS BARAZAN PILL FOLLOWED BY 300 BBLS OF 8.4 PPG KCL AT 170 SPM, 2700 PSI, 503 GPM, UP 225K, ON 115K 17:00 - 17:30 0.50 EVAL P CaMP CLEAN PITS, TAKE ON 8.9 PPG KCL 17:30 - 18:30 1.00 EVAL P CaMP CUT AND SLIP DRILLING LINE, CUT 84' 18:30 - 19:30 1,00 EVAL P CaMP DISPLACE WELL AT 8157' WITH NEW 8,9 PPG KCL, UP WT 225K, ON WT 115, 100 RPM Printed: 9/25/2002 4:12:26 PM ( ( BP'AMERICA Operations Summary. Report Page 8of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-105 V-105 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9ES 8/27/2002 Spud Date: 8/27/2002 End: Date From ~ To Hours Task Cödë NPT Phase pescriptionof Opëratiof\s 9/7/2002 19:30 - 20:30 1.00 EVAL P COMP MONITOR WELL, STABLE, POH TO 5800' 20:30 - 21 :00 0.50 EVAL P COMP SPOT 35 BBL 8.9 PPG KCL PERF PILL FI 5800' TO 5400' 21 :00 - 22:30 1.50 EVAL P COMP POH TO BHA 22:30 - 23:30 1,00 EVAL P COMP STD BACK HWDP, LD BIT SCRAPER AND BOOT BASKET, CLEAN OUT BOOT BASKETS, NO RECOVERY 23:30 - 00:00 0.50 EVAL P COMP PJSM, RU E-LlNE, PU USIT TOOLS, CALIBRATE AND FUNCTION TEST 9/8/2002 00:00 - 01 :00 1.00 EVAL P COMP RIH, LOG DN TO 8120' 01 :00 - 03:00 2.00 EVAL P COMP LOG UP FI 8120' TO 3400', POH, LD USIT TOOLS, RD E-LlNE EQUIPMENT, CLEARED FLOOR. CEMENT QUALITY ON LOG SHOWS MUCH IMPROVED ON THIS RUN. 03:00 - 04:30 1.50 PERF P COMP PJSM, RU TO RUN PERF GUNS, PU 286' - 135' BLANK AND 151' OF HALLIBURTON 4 5/8" 5 SPF, 72 DEGREE PHASE MILLENIUM GUNS. RIH. 04:30 - 07:00 2,50 PERF P COMP RIH W/4 5/8" PERF GUN ASSY ON 4" DP. POSITION GUNS APPROX 30' DEEP & PULL TO PU WT. 07:00 - 09:00 2.00 PERF P COMP RU SWS, RIH WITH GR TO 5400'. LOG UP AND GET LOG ON DEPTH TO OH LOGS. LOG ACROSS RA TAG AND FIGURE GUN SPACEOUT (UP 24'). RD SWS. 09:00 - 10:00 1.00 PERF P COMP PJSM. PU 24' TO PUT GUNS ON DEPTH, TEST SURFACE LINES TO 2500 PSI. BLEED OFF PRESSURE AND WAIT 6 MIN FOR GUNS TO FIRE - NO DOUBT! PERF INTERVALS: 5678-5633, 5588-5576, 5534-5512, 5504-5490,5482-5466,5434-5392. MONITOR WELL - STATIC. 10:00 - 12:30 2.50 PERF P COMP POH 4 STANDS - NO OVERPULL. MONITOR WELL- STATIC. POH WITH GUNS. 12:30 - 12:45 0.25 PERF P COMP PJSM. 12:45 - 14:00 1.25 PERF P COMP BREAK OUT & LD PERF GUNS. ALL SHOTS FIRED. 14:00 - 14:30 0.50 PERF P COMP CLEAR AND CLEAN RIG FLOOR, LD PERFORATING EQUIPMENT 14:30 - 15:30 1,00 CLEAN P COMP MU CLEANOUT ASSY WI BIT AND SCRAPER, RIH WI BHA 15:30 - 18:00 2.50 CLEAN P COMP RIH WI BHA ON 4" DP TO 8157' 18:00 - 19:00 1.00 CLEAN P COMP CIRC HI VIS SWEEP AROUND WI 150 SPM 2075 PSI 19:00 - 21 :30 2.50 CLEAN P COMP MONITOR WELL, STATIC, POH, LD 147 JTS 21 :30 - 22:30 1.00 CLEAN P COMP POH TO BHA, STD BACK 32 STDS OF 4" DP 22:30 - 00:00 1.50 CLEAN P COMP UD BHA, FREEZE PROTECT 7" X 9 5/8" WI 66 BBLS OF 60/40 DEAD CRUDE/DIESEL AT 3 BPM 1150 PSI. PREV AI LOT = 14.8 PPG EMW. 9/9/2002 00:00 - 01 :30 1.50 CLEAN P COMP LD BHA, CLEAN AND CLEAR RIG FLOOR 01 :30 - 02:30 1.00 RUNCOIVP COMP PULL WEAR RING, FLUSH STACK, MAKE DUMMY RUN WI TUBING HANGER 02:30 - 04:00 1.50 RUNCOIVP COMP RU TUBING HANDLING EQUIPMENT, COMPENSATOR, TORQUE TURN COMPUTER, CIO BAILS 04:00 - 08:30 4.50 RUNCOIVP COMP PJSM, PU, BAKERLOC 31/2" TUBING TAIL ASSY TO BAKER PACKER/NIPPLE ASSY, PU, RIH WI 72 JOINTS OF 31/2" 9.3# L-80 TC-11 TUBING AND ACCESSORIES, USING BEST-O-LlFE PTC THREAD COMPOUND, DRIFTED 31/2" TUBING WI A 2.867" RABBIT, TORQUE TURN TO 2300 FTLBS 08:30 - 17:00 8,50 RUNCOIVP COMP X-O, PU, RIH WI 128 JOINTS OF 41/2" 12.6# L-80 TC-11 TUBING AND ACCESSORIES, TORQUE TURN TO 2700FTLBS, DOPE WI BEST-O-LlFE PTC, DRIFT WI 3.833" Printed: 9/25/2002 4:12:26 PM (' BP AMERICA Operations ,Summary Report Page 90f 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-105 V-105 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9ES 8/27/2002 Spud Date: 8/27/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/912002 08:30 - 17:00 8.50 RUNCO~ COMP RABBIT 17:00 - 17:30 0.50 RUNCO~ COMP PU LANDING JOINT AND TUBING HANGER, RIH, LAND TBG HGR, PU WT 120 K, SO WT 80 K, RILDS 17:30 - 19:30 2.00 RUNCO~ COMP REVERSE CIRC, 225 BBLS 8.9 PPG KCL, FOLLOWED BY 45 BBLS OF CORROSION INHIBITED KCL AT 3 BPM 260 PSI 19:30 - 21 :30 2.00 RUNCO~ COMP PRESSURE TEST SURFACE LINES TO 4500 PSI, PRESSURE UP DOWN TUBING TO 2500 PSI, SET BOTTOM PACKER AT 7554', CONTINUED TO PRESSURE UP TO 4200 PSI, SET TOP PACKER AT 5211', HELD FOR 30 MINUTES, OK. RELEASED TUBING PRESSURE TO 2500 PSI, PRESSURED UP ON ANNULUS TO 4000 PSI, HELD FOR 30 MINUTES, OK. RELEASED PRESSURE ON ANNULUS AND TUBING TO 0 PSI, PRESSURED UP ON ANNULUS TO 2925 PSI, DCK VALVE SHEARED, RD LINES AND LANDING JOINT 21 :30 - 22:00 0,50 RUNCO~ COMP RUN TWC, TEST TO 2800 PSI 22:00 - 23:00 1.00 RUNCO~ COMP BLOW DOWN, RD SURFACE LINES, CLEAR FLOOR, LD MOUSE HOLE 23:00 - 00:00 1,00 BOPSURP COMP ND BOP 9/10/2002 00:00 - 01 :30 1.50 BOPSUR P COMP ND BOP, SET BACK ON STUMP 01 :30 - 03:30 2.00 WHSUR P COMP NU ADAPTER AND TREE 03:30 - 04:00 0.50 WHSUR P COMP TEST TREE TO 5000 PSI 04:00 - 04:30 0.50 WHSUR P COMP RU LUBRICATOR, PULL TWC, RD LUBRICATOR 04:30 - 06:30 2.00 WHSUR P COMP RU, TEST LINES, PUMP 95 BBLS OF DIESEL DOWN 41/2" X 7" ANNULUS, U-TUBE TO TUBING, FREEZE PROTECT WELL FI 2800' TO SURFACE 06:30 - 07:30 1.00 WHSUR P COMP RU DSM. INSTALL BPV. PRESSURE TEST TO 1000 PSI. LD LUBRICATOR. 07:30 - 08:00 0.50 WHSUR P COMP SECURE TREE. INSTALL GAUGES, SECURE CELLAR FOR MOVE TO V-1 08. RELEASE RIG @ 08:00 HRS 09/10/2002, Printed: 9/25/2002 4:12:26 PM ANADRILL SCHLUMBERGER Survey report Client.... ...... ..... ....: BP Exploration (Alaska) Inc, Field........... .........: Prudhoe Bay I Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-105i API number.......... .....: 50-029-23097-00 Engineer.................: E. Roux COUNTY:................ ..: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.. ........: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 53.80 ft KB above permanent. . . . . . . : n/a DF above permanent.......: 82.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-) ........: -999.25 ft Azimuth from rotary table to target: 12.89 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] 3-Sep-2002 14:01:23 Spud date. . . . . . . . . . . . . . . . : Last survey date. ........: Total accepted surveys. . . : MD of first survey..... ..: MD of last survey... .....: Page 1 of 4 27-Aug-02 03-Sep-02 90 0.00 ft 8255.00 ft ~ ----- Geomagnetic data ---------------------- Magnetic model.. .... ... ..: BGGM version 2001 Magnetic date... ..... ....: 27-Aug-2002 Magnetic field strength..: 1149.62 RCNT Magnetic dec (+E/W-).....: 25.95 degrees Magnetic dip.... .... ... ..: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.62 HCNT 80.76 degrees (+1-) 2.50 mGal (+1-) 6.00 HCNT (+1-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.84 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.84 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) .... ....: No degree: 0.00 ~' ANADRILL SCHLUMBERGER Survey Report 3-Sep-2002 14:01:23 Page 2 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 199.09 0.49 163.17 199.09 199.09 -0.74 -0.81 0.25 0.85 163.17 0.25 MWD_IFR_MSA 3 295.18 0.53 178.42 96.09 295.17 -1.53 -1.65 0.38 1.70 167.12 0.15 MWD_IFR_MSA 4 383.36 1.45 153.84 88.18 383.34 -2.79 -3.06 0.88 3.19 163.95 1.13 MWD- IFR_MSA 5 477.80 2.48 152.35 94.44 477.72 -5.27 -5.94 2.36 6.39 158.38 1.09 MWD_IFR_MSA 6 570.94 3.22 160.96 93.14 570.75 -9.02 -10.20 4.14 11.01 157.89 0.92 MWD_IFR_MSA 7 662.48 3.35 161.50 91.54 662.14 -13.49 -15.17 5.83 16.25 158.97 0.15 MWD- IFR_MSA "~ 8 754.68 3.69 163.18 92.20 754.16 -18.36 -20.56 7.55 21.90 159.85 0.39 MWD_IFR_MSA 9 847.36 3.12 172.93 92.68 846.68 -23.32 -25.92 8.72 27.35 161.41 0.87 MWD - IFR_MSA 10 941.96 3.22 181.37 94.60 941.14 -28.35 -31.13 8.97 32.40 163.92 0.50 MWD - IFR_MSA 11 1034.33 1.62 173.90 92.37 1033.42 -32.12 -35.02 9.05 36.17 165.51 1.76 MWD_IFR_MSA 12 1127.19 1.69 19.60 92.86 1126.27 -32.00 -35.04 9.65 36.34 164.61 3.48 MWD- IFR_MSA 13 1220.75 5.10 8.61 93.56 1219.65 -26.49 -29.63 10.73 31.51 160.09 3.69 MWD_IFR_MSA 14 1313.18 7.02 12.13 92.43 1311.56 -16.74 -20.04 12.54 23.64 147.97 2.11 MWD_IFR_MSA 15 1407.08 7.81 12.41 93.90 1404.67 -4.62 -8.20 15.11 17.19 118.49 0.84 MWD - IFR_MSA 16 1501.44 9.33 15.47 94.36 1497.98 9.43 5.43 18.53 19.31 73.66 1.68 MWD - IFR_MSA 17 1594.70 11.44 11.62 93.26 1589.71 26.23 21.78 22.41 31.25 45.82 2.38 MWD_IFR_MSA 18 1687.82 11.31 9.98 93.12 1681.00 44.58 39.82 25.85 47.48 32.99 0.37 MWD_IFR_MSA 19 1780.24 12.94 11.31 92.42 1771.35 63.98 58.89 29.45 65.85 26.57 1.79 MWD_IFR_MSA 20 1873.59 15.60 9.74 93.35 1861.81 86.96 81.52 33.63 88.18 22.42 2.88 MWD- IFR_MSA 21 1966.98 19.67 12.51 93.39 1950.80 115.23 109.25 39.16 116.06 19.72 4.45 MWD _IFR_MSA 22 2060.33 23.83 11.99 93.35 2037.48 149.81 143.05 46.48 150.41 18.00 4.46 MWD_IFR_MSA ~ 23 2153.36 27.85 10.15 93.03 2121.20 190.33 182.84 54.22 190.71 16.52 4.41 MWD_IFR_MSA 24 2246.85 30.25 10.33 93.49 2202.92 235.67 227.51 62.29 235.88 15.31 2.57 MWD- IFR_MSA 25 2341.03 32.22 12.86 94.18 2283.45 284.48 275.33 72.13 284.62 14.68 2.51 MWD_IFR_MSA 26 2434.80 34.28 11.82 93.77 2361.86 335.89 325.55 83.11 336.00 14.32 2.28 MWD_IFR_MSA 27 2527.73 36.75 12.22 92.93 2437.50 389.86 378.35 94.36 389.94 14.00 2.67 MWD- IFR_MSA 28 2621.01 40.19 12.35 93.28 2510.52 447.88 435.04 106.70 447.94 13.78 3.69 MWD_IFR_MSA 29 2714.34 43.55 12.07 93.33 2580.01 510.16 495.92 119.87 510.20 13.59 3.61 MWD- IFR_MSA 30 2807.60 46.48 13.08 93.26 2645.93 576.11 560.29 134.25 576.14 13.47 3.23 MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report 3-Sep-2002 14:01:23 Page 3 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2899.66 50.56 11.74 92.06 2706.89 645.06 627.63 149.04 645.09 13.36 4.56 MWD _IFR_MSA 32 2928.80 51.81 11.93 29.14 2725.16 667.76 649.85 153.70 667.78 13.31 4.32 MWD_IFR_MSA 33 2994.33 50.33 11.82 65.53 2766.34 718.73 699.74 164.19 718.74 13.20 2.26 MWD Incl. Only 34 3088.31 50.18 11.71 93.98 2826.42 790.98 770.48 178.92 790.98 13.07 0.18 MWD_IFR_MSA 35 3181.25 49.29 11.93 92.94 2886.49 861.88 839.90 193.45 861.89 12.97 0.97 MWD_IFR_MSA 36 3274.55 48.71 11.83 93.30 2947.70 932.29 908.80 207.94 932.29 12.89 0.63 MWD_IFR_MSA 37 3368.25 49.88 11.85 93.70 3008.81 1003.31 978.32 222.52 1003.31 12.81 1.25 MWD _IFR_MSA ~. 38 3461.04 52.00 12.55 92.79 3067.28 1075.35 1048.74 237.75 1075.35 12.77 2.36 MWD_IFR_MSA 39 3554.90 52.70 12.08 93.86 3124.61 1149.66 1121.34 253.60 1149.66 12.74 0.84 MWD_IFR_MSA 40 3648.32 52.96 11.06 93.42 3181.05 1224.08 1194.27 268.52 1224.09 12.67 0.91 MWD- IFR_MSA 41 3742.20 52.66 9.82 93.88 3237.80 1298.79 1267.82 282.08 1298.82 12.54 1.10 MWD_IFR_MSA 42 3835.67 52.10 9.22 93.47 3294.86 1372.70 1340.83 294.32 1372.75 12.38 0.79 MWD_IFR_MSA 43 3928.28 51.33 8.81 92.61 3352.24 1445.23 1412.63 305.72 1445.33 12.21 0.90 MWD _IFR_MSA 44 4021.58 50.99 8.30 93.30 3410.75 1517.69 1484.49 316.53 1517.86 12.04 0.56 MWD_IFR_MSA 45 4114.93 50.57 7.49 93.35 3469.77 1589.73 1556.12 326.46 1590.00 11.85 0.81 MWD _IFR_MSA 46 4208.60 50.57 7.15 93.67 3529.27 1661.74 1627.88 335.68 1662.13 11.65 0.28 MWD_IFR_MSA 47 4298.40 49.39 7.57 89.80 3587.01 1730.19 1696.08 344.49 1730.72 11.48 1.36 MWD _IFR_MSA 48 4392.62 48.44 8.48 94.22 3648.93 1800.95 1766.41 354.40 1801.61 11.34 1.24 MWD_IFR_MSA 49 4486.99 46.95 9.59 94.37 3712.45 1870.58 1835.33 365.35 1871.34 11.26 1.80 MWD - IFR_MSA 50 4580.70 45.33 11.17 93.71 3777.38 1938.08 1901.79 377.51 1938.89 11.23 2.11 MWD _IFR_MSA 51 4672.84 43.24 12.13 92.14 3843.34 2002.39 1964.79 390.49 2003.22 11.24 2.38 MWD _IFR_MSA 52 4766.82 40.69 12.78 93.98 3913.21 2065.23 2026.15 404.03 2066.04 11.28 2.75 MWD_IFR_MSA .~/ 53 4860.42 38.28 13.88 93.60 3985.45 2124.74 2084.07 417.74 2125.52 11.33 2.68 MWD _IFR_MSA 54 4953.67 35.82 15.94 93.25 4059.87 2180.88 2138.35 432.17 2181.59 11.43 2.95 MWD_IFR_MSA 55 5046.04 34.80 15.89 92.37 4135.24 2234.19 2189.70 446.81 2234.82 11.53 1.10 MWD _IFR_MSA 56 5140.20 33.48 16.94 94.16 4213.18 2286.93 2240.39 461.73 2287.47 11.65 1.54 MWD_IFR_MSA 57 5234.34 31.63 17.43 94.14 4292.52 2337.45 2288.78 476.69 2337.90 11.76 1.99 MWD_IFR_MSA 58 5327.03 29.32 17.98 92.69 4372.40 2384.29 2333.56 490.98 2384.66 11.88 2.51 MWD_IFR_MSA 59 5420.01 26.77 18.63 92.98 4454.46 2427.80 2375.07 504.70 2428.10 12.00 2.76 MWD_IFR_MSA 60 5513.44 25.10 16.47 93.43 4538.48 2468.52 2414.01 517.04 2468.76 12.09 2.05 MWD_IFR_MSA ANATIRILL SCHLUMBERGER Survey Report 3-Sep-2002 14:01:23 Page 4 of 4 --- -------- ------ ------- ------ --------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5606.57 25.01 14.25 93.13 4622.85 2507.92 2452.04 527.49 2508.13 12.14 1.01 MWD_IFR_MSA 62 5699.00 24.98 13.66 92.43 4706.62 2546.96 2489.94 536.90 2547.17 12.17 0.27 MWD_IFR_MSA 63 5793.30 24.77 13.12 94.30 4792.17 2586.63 2528.53 546.09 2586.82 12.19 0.33 MWD_IFR_MSA 64 5886.91 24.49 12.70 93.61 4877.26 2625.64 2566.55 554.81 2625.83 12.20 0.35 MWD_IFR_MSA 65 5980.31 24.63 11.66 93.40 4962.21 2664.46 2604.50 563.00 2664.65 12.20 0.49 MWD_IFR_MSA 66 6073.68 24.06 10.43 93.37 5047.28 2702.93 2642.27 570.38 2703.13 12.18 0.82 MWD_IFR_MSA 67 6167.93 23.70 10.05 94.25 5133.46 2741.04 2679.82 577.16 2741.27 12.15 0.42 MWD_IFR_MSA ~ 68 6261.02 23.49 9.60 93.09 5218.77 2778.25 2716.53 583.52 2778.50 12.12 0.30 MWD_IFR_MSA 69 6354.67 23.10 9.89 93.65 5304.79 2815.23 2753.03 589.79 2815.50 12.09 0.43 MWD_IFR_MSA 70 6447.99 22.55 9.37 93.32 5390.80 2851.37 2788.72 595.84 2851.67 12.06 0.63 MWD_IFR_MSA 71 6541.58 21.94 8.94 93.59 5477.42 2886.72 2823.70 601.48 2887.05 12.02 0.67 MWD_IFR_MSA 72 6633.83 21.50 8.41 92.25 5563.12 2920.77 2857.45 606.63 2921.13 11.99 0.52 MWD_IFR_MSA 73 6726.59 20.96 7.17 92.76 5649.59 2954.22 2890.73 611.19 2954.63 11.94 0.76 MWD_IFR_MSA 74 6821.10 20.32 11.45 94.51 5738.04 2987.45 2923.58 616.56 2987.89 11.91 1.73 MWD_IFR_MSA 75 6914.00 18.88 15.23 92.90 5825.56 3018.60 2953.90 623.71 3019.03 11.92 2.06 MWD_IFR_MSA 76 7008.55 17.35 13.94 94.55 5915.42 3047.98 2982.34 631.12 3048.39 11.95 1.67 MWD_IFR_MSA 77 7101.71 15.84 14.85 93.16 6004.69 3074.58 3008.12 637.73 3074.97 11.97 1.64 MWD_IFR_MSA 78 7194.02 15.58 15.19 92.31 6093.56 3099.55 3032.26 644.21 3099.93 11.99 0.30 MWD_IFR_MSA 79 7286.48 14.27 14.66 92.46 6182.89 3123.35 3055.26 650.34 3123.71 12.02 1.42 MWD_IFR_MSA 80 7378.54 12.98 12.46 92.06 6272.36 3145.03 3076.34 655.45 3145.39 12.03 1.51 MWD_IFR_MSA 81 7472.79 11.68 11.36 94.25 6364.44 3165.15 3096.03 659.61 3165.51 12.03 1.40 MWD_IFR_MSA 82 7565.86 10.84 10.16 93.07 6455.71 3183.31 3113.88 663.01 3183.68 12.02 0.94 MWD_IFR_MSA ~ 83 7661.27 10.00 6.96 95.41 6549.55 3200.51 3130.93 665.60 3200.90 12.00 1.07 MWD_IFR_MSA 84 7753.99 9.42 6.23 92.72 6640.94 3216.06 3146.47 667.39 3216.47 11.98 0.64 MWD_IFR_MSA 85 7846.96 9.56 5.18 92.97 6732.64 3231.27 3161.72 668.92 3231.70 11.95 0.24 MWD_IFR_MSA 86 7940.16 9.45 2.72 93.20 6824.56 3246.47 3177.07 669.98 3246.94 11.91 0.45 MWD_IFR_MSA 87 8033.43 9.00 1.33 93.27 6916.62 3261.15 3192.01 670.51 3261.67 11.86 0.54 MWD_IFR_MSA 88 8125.49 8.61 0.93 92.06 7007.60 3274.95 3206.10 670.79 3275.52 11.82 0.43 MWD_IFR_MSA 89 8179.67 8.59 0.68 54.18 7061.17 3282.87 3214.20 670.90 3283.47 11.79 0.08 MWD_IFR_MSA 90 8255.00 8.59 0.68 75.33 7135.65 3293.87 3225.45 671.04 3294.51 11.75 0.00 Projected to TD [(c)2002 Anadrill IDEAL ID6_1C_10J bp V-105 Schlumberuer Survey Report - Geodetic Report Date: 3-Sep-02 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 11.750° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: V-Pad / V.1 05 TVD Reference Datum: KB Well: V-105 TVD Reference Elevation: 82.300 ft relative to MSL Borehole: V-105 Sea Bed / Ground Level Elevation: 55.000 ft relative to MSL UWIIAPI#: 500292309700 Magnetic Declination: +25.824 ° Survey Name / Date: V-1 05 I September 3, 2002 Total Field Strength: 57504.101 nT Tort / AHD I DDII ERD ratio: 123.055° I 3369,29 ft 15.681/0.472 Magnetic Dip: 80.769° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: September 04, 2002 '-" Location Lat/Long: N 701941.042, W 149 15 54.57~ Magnetic Declination Model: BGGM 2002 Location Grid NIE YIX: N 5970107.310 ftUS, E 590607.900 ftUS North Reference: True North Grid Convergence Angle: +0.69195680° Total Corr Mag North -> True North: +25.824° Grid Scale Factor: 0.99990933 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S, EI-W DLS Northing Easting Latitude Longitude (tt) (°) (°) (tt) (tt) (tt) (tt) (0/100tt) (ttUS) (ttUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970107.31 590607.90 N 70 1941.042 W 149 1554.572 199.09 0.49 163.17 199.09 -0.75 -0.81 0.25 0.25 5970106.50 590608.16 N 701941.034 W 149 1554.565 295.18 0.53 178.42 295.17 -1.54 -1.65 0.38 0.15 5970105.66 590608.30 N 70 1941.026 W 149 1554.561 383.36 1.45 153.84 383.34 -2.82 -3.06 0.88 1.13 5970104.26 590608.82 N 70 1941.012 W 1491554.546 477.80 2.48 152.35 477.72 -5.34 -5.94 2.36 1.09 5970101.40 590610.33 N 70 19 40.983 W 149 15 54.503 570.94 3.22 160.96 570.75 -9.14 -10.20 4.14 0.92 5970097.16 590612.17 N 701940.941 W 149 1554.451 662.48 3.35 161.50 662.14 -13.66 -15.17 5.83 0.15 5970092.21 590613.91 N 70 19 40.893 W 149 15 54.402 754.68 3.69 163.18 754.16 -18.60 -20.56 7.55 0.39 5970086.84 590615.69 N 70 19 40.840 W 149 15 54.352 847.36 3.12 172.93 846.68 -23.60 -25.92 8.72 0.87 5970081.50 590616.93 N 701940.787 W 149 1554.318 941.96 3.22 181.37 941.14 -28.65 -31 . 1 3 8.97 0.50 5970076.29 590617.25 N 701940.736 W 1491554.310 '~ 1034.33 1.62 173.90 1033.42 -32.45 -35.02 9.05 1.76 5970072.40 590617.37 N 70 19 40.697 W 149 15 54.308 1127.1 9 1.69 19.60 1126.27 -32.34 -35.04 9.65 3.48 5970072.39 590617.97 N 70 19 40.697 W 149 15 54.290 1220.75 5.10 8.61 1219.65 -26.82 -29.63 10.73 3.69 5970077.82 590618.99 N 701940.750 W 149 1554.259 1313.18 7.02 12.13 1311.56 -17.07 -20.04 12.54 2.11 5970087.42 590620.68 N 70 19 40.845 W 149 15 54.206 1407.08 7.81 12.41 1404.67 -4.95 -8.20 15.11 0.84 5970099.29 590623.11 N 701940.961 W 149 1554.131 1501.44 9.33 15.47 1497.98 9.09 5.43 18.53 1.68 5970112.97 590626.36 N 701941.095 W 1491554.031 1594.70 11.44 11.62 1589.71 25.89 21.78 22.41 2.38 5970129.36 590630.04 N 70 1941.256 W 1491553.918 1687.82 11.31 9.98 1681.00 44.25 39.82 25.85 0.37 5970147.44 590633.27 N 70 19 41.433 W 149 15 53.817 1780.24 12.94 11.31 1771.35 63.66 58.89 29.45 1.79 5970166.55 590636.64 N 70 1941.621 W 149 1553.712 1873.59 15.60 9.74 1861.81 86.66 81.52 33.63 2.88 5970189.22 590640.54 N 701941.844 W 14915 53.590 V-105 ASP Final Survey.xls Page 1 of 3 10/1/2002-10:02 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S E/.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1966.98 19.67 12.51 1950.80 114.94 109.25 39.16 4.45 5970217.01 590645.73 N 70 19 42.116 W 149 15 53.429 2060.33 23.83 11.99 2037.48 149.52 143.05 46.48 4.46 5970250.90 590652.65 N 701942.449 W 149 1553.215 2153.36 27.85 10.15 2121.20 190.05 182.84 54.22 4.41 5970290.77 590659.90 N 70 19 42.840 W 149 15 52.989 2246.85 30.25 10.33 2202.92 235.43 227.51 62.29 2.57 5970335.53 590667.43 N 701943.279 W 1491552.754 2341.03 32.22 12.86 2283.45 284.25 275.33 72.13 2.51 5970383.47 590676.70 N 70 1943.750 W 1491552.466 2434.80 34.28 11.82 2361.86 335.66 325.55 83.11 2.28 5970433.81 590687.06 N 70 1944.244 W 1491552.146 2527.73 36.75 12.22 2437.50 389.64 378.35 94.36 2.67 5970486.74 590697.67 N 701944.763 W 149 1551.817 2621.01 40.19 12.35 2510.52 447.66 435.04 106.70 3.69 5970543.57 590709.33 N 70 1945.320 W 149 1551.457 2714.34 43.55 12.07 2580.01 509.94 495.92 119.87 3.61 5970604.59 590721 .76 N 70 1945.919 W 1491551.072 2807.60 46.48 13.08 2645.93 575.88 560.29 134.25 3.23 5970669.12 590735.36 N 70 1946.552 W 149 15 50.653 ~ 2899.66 50.56 11.74 2706.89 644.83 627.63 , 149.04 4.56 5970736.64 590749.34 N 701947.215 W 149 1550.221 2928.80 51.81 11.93 2725.16 667.54 649.85 153.70 4.32 5970758.91 590753.72 N 70 19 47.433 W 149 15 50.085 2994.33 50.33 11.82 2766.33 718.51 699.74 164.19 2.26 5970808.92 590763.61 N 701947.924 W 149 1549.779 3088.31 50.18 11.71 2826.42 790.77 770.48 178.92 0.18 5970879.82 590777.49 N 70 1948.619 W 1491549.348 3181.25 49.29 11.93 2886.49 861.69 839.90 193.45 0.97 5970949.40 590791.17 N 701949.302 W 149 1548.924 3274.55 48.71 11.83 2947.70 932.10 908.80 207.94 0.63 5971018.47 590804.83 N 701949.980 W 149 1548.501 3368.25 49.88 11.85 3008.81 1003.13 978.32 222.52 1.25 5971088.16 590818.57 N 70 19 50.663 W 149 15 48.075 3461.04 52.00 12.55 3067.28 1075.18 1048.74 237.75 2.36 5971158.75 590832.94 N 701951.356 W 149 1547.631 3554.90 52.70 12.08 3124.61 1149.49 1121.34 253.60 0.84 5971231.53 590847.91 N 70 1952.070 W 1491547.168 3648.32 52.96 11.06 3181.05 1223.93 1194.27 268.52 0.91 5971304.62 590861 .96 N 70 19 52.787 W 1491546.732 3742.20 52.66 9.82 3237.80 1298.69 1267.82 282.08 1.10 5971378.32 590874.62 N 70 1953.511 W 149 1546.336 3835.67 52.10 9.22 3294.86 1372.67 1340.83 294.32 0.79 5971451.47 590885.98 N 70 1954.229 W 149 1545.978 3928.28 51.33 8.81 3352.24 1445.28 1412.63 305.72 0.90 5971523.39 590896.51 N 70 19 54.935 W 149 15 45.646 4021.58 50.99 8.30 3410.75 1517.84 1484.49 316.53 0.56 5971595.37 590906.45 N 70 19 55.642 W 149 15 45.330 4114.93 50.57 7.49 3469.77 1589.99 1556.12 326.46 0.81 5971667.12 590915.52 N 70 19 56.346 W 149 15 45.040 ~ 4208.60 50.57 7.15 3529.27 1662.13 1627.88 335.68 0.28 5971738.98 590923.87 N 70 1957.052 W 149 1544.771 4298.40 49.39 7.57 3587.01 1730.70 1696.08 344.49 1.36 5971807.27 590931.85 N 70 1957.723 W 149 1544.513 4392.62 48.44 8.48 3648.93 1801.56 1766.40 354.40 1.24 5971877.70 590940.91 N 70 1958.414 W 149 1544.224 4486.99 46.95 9.59 3712.45 1871.27 1835.33 365.35 1.80 5971946.75 590951.03 N 70 19 59.092 W 149 15 43.904 4580.70 45.33 11.17 3777.38 1938.81 1901.79 377.51 2.11 5972013.34 590962.38 N 70 1959.746 W 149 1543.549 4672.84 43.24 12.13 3843.34 2003.14 1964.79 390.49 2.38 5972076.49 590974.60 N 70200.365 W 1491543.170 4766.82 40.69 12.78 3913.21 2065.97 2026.15 404.03 2.75 5972138.01 590987.40 N 70200.969 W 1491542.774 4860.42 38.28 13.88 3985.45 2125.46 2084.07 417.74 2.68 5972196.07 591000.41 N 70201.538 W 149 1542.374 4953.67 35.82 15.94 4059.87 2181.55 2138.35 432.17 2.95 5972250.53 591014.17 N 70202.072 W 149 1541.952 5046.04 34.80 15.89 4135.24 2234.80 2189.70 446.81 1.10 5972302.04 591028.19 N 70202.577 W 149 1541.525 V-105 ASP Final Survey.xls Page 2 of 3 10/1/2002-10:02 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (°) n (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 5140.20 33.48 16.94 4213.18 2287.47 2240.39 461.73 1.54 5972352.90 591042.50 N 70 20 3.076 W 1491541.089 5234.34 31.63 17.43 4292.52 2337.90 2288.78 476.69 1.99 5972401.47 591056.87 N 70 20 3.552 W 149 15 40.652 5327.03 29.32 17.98 4372.40 2384.65 2333.56 490.98 2.51 5972446.42 591070.62 N 70 20 3.992 W 149 15 40.235 5420.01 26.77 18.63 4454.46 2428.08 2375.07 504.70 2.76 5972488.08 591083.83 N 70 20 4.400 W 1491539.834 5513.44 25.10 16.47 4538.48 2468.72 2414.01 517.04 2.05 5972527.17 591095.70 N 70 20 4.783 W 14915 39.473 5606.57 25.01 14.25 4622.85 2508.07 2452.04 527.49 1.01 5972565.31 591105.69 N 70205.157 W 149 1539.168 5699.00 24.98 13.66 4706.62 2547.10 2489.94 536.90 0.27 5972603.32 591114.65 N 70 20 5.530 W 149 15 38.893 5793.30 24.77 13.12 4792.17 2586.75 2528.53 546.09 0.33 5972642.01 591123.37 N 70 20 5.909 W 1491538.625 5886.91 24.49 12.70 4877.26 2625.75 2566.55 554.81 0.35 5972680.14 591131.62 N 70 20 6.283 W 149 15 38.370 5980.31 24.63 11.66 4962.21 2664.57 2604.50 563.00 0.49 5972718.18 591139.35 N 70 20 6.657 W 1491538.131 6073.68 24.06 10.43 5047.28 2703.06 2642.27 570.38 0.82 5972756.03 591146.27 N 70207.028 W 1491537.915 ~ 6167.93 23.70 10.05 5133.46 2741.20 2679.82 577.16 0.42 5972793.65 591152.60 N 70 20 7.397 W 149 1537.717 6261.02 23.49 9.60 5218.77 2778.44 2716.53 583.52 0.30 5972830.44 591158.52 N 70 20 7.758 W 149 1537.531 6354.67 23.10 9.89 5304.79 2815.45 2753.03 589.79 0.43 5972867.01 591164.34 N 70 20 8.117 W 149 1537.348 6447.99 22.55 9.37 5390.80 2851.63 2788.72 595.84 0.63 5972902.77 591169.97 N 70208.468 W 1491537.171 6541.58 21.94 8.94 5477.42 2887.02 2823.70 601.48 0.67 5972937.81 591175.18 N 70 20 8.812 W 1491537.007 6633.83 21.50 8.41 5563.12 2921.11 2857.45 606.63 0.52 5972971.61 591179.93 N 70 20 9.144 W 149 1536.856 6726.59 20.96 7.17 5649.59 2954.62 2890.73 611 .19 0.76 5973004.94 591184.08 N 70 20 9.472 W 149 1536.723 6821.10 20.32 11 .45 5738.04 2987.88 2923.58 616.56 1.73 5973037.85 591189.05 N 7020 9.795 W 149 15 36.566 6914.00 18.88 15.23 5825.55 3019.01 2953.90 623.71 2.06 5973068.25 591195.84 N 702010.093 W 1491536.357 7008.55 17.35 13.94 5915.42 3048.37 2982.34 631.12 1.67 5973096.78 591202.91 N 702010.373 W 149 1536.140 7101.71 15.84 14.85 6004.69 3074.95 3008.12 637.73 1.64 5973122.63 591209.20 N 702010.626 W 1491535.947 7194.02 15.58 15.19 6093.56 3099.90 3032.26 644.21 0.30 5973146.84 591215.38 N 702010.863 W 149 1535.758 7286.48 14.27 14.66 6182.89 3123.68 3055.26 650.34 1.42 5973169.92 591221.24 N 70 2011.090 W 149 1535.579 7378.54 12.98 12.46 6272.36 3145.35 3076.34 655.45 1.51 5973191.05 591226.09 N 70 20 11.297 W 149 15 35.430 7472.79 11.68 11.36 6364.44 3165.48 3096.03 659.61 1.40 5973210.79 591230.01 N 702011.491 W 149 1535.308 ~ 7565.86 10.84 10.16 6455.71 3183.64 3113.88 663.01 0.94 5973228.68 591233.20 N 702011.666 W 149 1535.209 7661.27 10.00 6.96 6549.55 3200.87 3130.93 665.60 1.07 5973245.76 591235.58 N 7020 11.834 W 149 15 35.133 7753.99 9.42 6.23 6640.94 3216.44 3146.47 667.39 0.64 5973261.31 591237.19 N 702011.987 W 149 1535.081 7846.96 9.56 5.18 6732.64 3231.69 3161.72 668.92 0.24 5973276.58 591238.53 N 702012.137 W 149 1535.036 7940.16 9.45 2.72 6824.56 3246.93 3177.07 669.98 0.45 5973291.94 591239.40 N 7020 12.288 W 149 15 35.005 8033.43 9.00 1.33 6916.62 3261.67 3192.01 670.51 0.54 5973306.89 591239.76 N 7020 12.435 W 149 15 34.990 8125.49 8.61 0.93 7007.60 3275.52 3206.10 670.79 0.43 5973320.98 591239.86 N 702012.573 W 149 1534.981 8179.67 8.59 0.68 7061.17 3283.47 3214.20 670.90 0.08 5973329.08 591239.88 N 702012.653 W 1491534.978 8255.00 8.59 0.68 7135.65 3294.51 3225.45 671.04 0.00 5973340.33 591239.88 N 702012.763 W 149 1534.974 V-105 ASP Final Survey.xls Page 3 of 3 10/1/2002-10:02 AM .) ') aoa-18¡ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V -1 05i Date Dispatche 15-Apr-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 ¡-CE'V'E"= 'D'*'" 'RJ::, .~-# i - ¡ C C- 0 ^ r,f\f\" I L (VVf.. Receiv~ ¿J)Oor . Aias¡ò~a VIi ¿~ Gat;¡ Gcn~. CommilSli't . Anchorage Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 . nrose1 @slb,com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well V-104 éA(')d,. JL ~ L-105~O~,- i( 1 L-105 L-105 L-105 L-105 L-105 L-105 '-./ V-105 (RUN 1) V-105 (RUN 2¡.....t Job# Log Description 22414 usn 22348 OH EDIT PEXlAIT/BHC DATA (PDC) 22348 OH EDIT PEXlAIT/BHC DATA (PDC) 22348 OH EDIT PEXlAIT/BHC DATA (PDC) 22348 OH EDIT PEXlAIT/BHC DATA (PDC) 22348 OH EDIT PEXlAITIBHC DATA (PDC) 22348 OH EDIT PEXlAIT/BHC DATA (PDC) 22348 OH EDIT PEXlAIT/BHC DATA (PDC) 22420 usn 22421 usn PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: RECEIVED SEP 13 2002 Alaska Qi~ & Gas Con;;;, Ccmmission Anchorage 08/25/02 07/12/02 07/12/02 07/12/02 07/12/02 07/12/02 07/12/02 07/12/02 09/07/02 09/07/02 NO, 2411 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia BL 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth Receivedb~~' r '09/12/02 CD ~ ) ~' V-I05i ) 20Z -/~ I ) Subject: V-I05i Date: Tue, 30 Ju12002 19:35:02 -0500 From: "Franks, James D" <FranksJD@BP.com> To: '''winton - aubert@admin.state.ak.us'" <winton - aubert@admin.state.ak.us> Winton, The V-105i well was permitted as a 3.5" completion from surface to TD. The actual completion will be a 4.5" from the surface to the upper packer and 3.5" the rest of the way. The very same completion as the L-103i well is planned to be. Would you like me to send you a drawing and a page to insert your file or is this enough information to go with? Thanks for the quick return of phone call. james James Franks BP GPB Rotary Drilling - 9ES office: 907-564-4468 cell: 907-440-0187 4-1/2" 'X' Landing Nipple with 3,813" II bore lEI 7" x 4-1/2" Baker "Premium" ~ Production Packer +/-150' above top Schrader perforation 3-1/2" MMGW Water Flood GLM --- --!:: with Injection Valve with New Vam BxP TREE: 4-1/16" -5M CIW Carbon WELLHEAD: 11" -5M FMCG5 9-5/8", 40 #/ft, L-BO, BTC ¡, 2862' 7" 'E8 cementer +/- 200 below Schrader Plug Back Depth 8232' 7",26 #/ft, L-BO, BTC-Mod 8312' Date 7 -8-02 Rev By NM 7-31-02 jdf ) ) Borealis V-105i Proposed Completion Cella r Elevation = :1:47' RKB-MSL = :1:77' . 4-1/2" 'X' Landing Nipple with 3,813" bore, I 2200'1 . Gas Lift Mandrels with handling pups installed, ---b GAS LIFT MANDRELS # MD Type Valve Type 1 TBD 3-1/2" MMGW Dummy 2 TBD 3-1/2" MMGW Dummy 3 TBD 4-1/2" KBG-2 RP 4 TBD 4-1/2" KBG-2 Dummy 5 TBD 4-1/2" KBG-2 Dummy --!: ---b ~ 4-1/2"12,6# L-BO, TC-II Tubing . lEI 3-1/2" 9,3#, L-80, TC-II Tubing below top packer ------ - ---1: 1r 3-1/2" 'X' Landing Nipple with 2,B13" bore, 7" x 4-112" Baker" 8-3" Packer +/- 200' above Kuparuk 3-1/2" 'X' Landing Nipple with 2,813" seal bore, 3-1/2" 'X' Landing Nipple with 2,813" seal bore 3-1/2" WireLine Entry Guide set at +/-130' above the Kuparuk Formation I ,c :';, ' ,",:', "; :' ~,f:<,' .:<,; ,;,,:, ':¡;'~ I Comments Borealis WELL: V-105i API NO: 50-029-???? Proposed Completion (P4) Proposed Completion (P4) BP Alaska ') ~1r AT,ASIiA OIL AND GAS CONSERVATION COMMISSION July 1, 2002 Brian Robertson BP Exploration (Alaska), Inc. Drilling Department PO Box 196612 Anchorage Alaska 99519 Re: Pennit to Drill 202-131 Dear Mr. Robertson: ') TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Last week the Commission approved the above-referenced application for pennit to drill. The approval letter inadvertently included two sentences from a template generally used for exploratory wells. Please disregard the following requirement that was included in the approval letters : "A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use." We apologize for any inconvenience this may have caused you. Sincerely, (f)A1AAA- _/~' ~~ C~~;~hsli Taylor 0 Chair ) TONY KNOWLES, GOVERNOR A.IfA.SIiA OIL AlVD GAS CONSERVATION COMMISSION 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit V-l05i BP Exploration (Alaska), Inc. Pennit No: 202-131 Surface Location: 4859' NSL 1692' WEL, Sec. 11, TllN, RllE, UM Bottomhole Location: 2851' NSL, 941' WEL, Sec. 02, TllN, RIlE, UM Dear Mr. Robertson: Enclosed is the approved application for pennit to drill the above referenced service well. The pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test perfonned before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, &11U~Duh~' ,~ Cammy dèchsli Taylo; ',Û Chair BY ORDER OF THE COMMISSION DATED thisjMbday of June, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA, , STATE OF ALASKA )AND GAS CONSERVATION COMM¡ )ION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well [J Exploratory [J Stratigraphic Test [J Development Oil III Service [J Development Gas [J Single Zone [J Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 82.3' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number V-105i 9. Approximate spud dat~ 07/15/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8311' MD / 7134' TVD /. 17. Anticipated pressure {s7e 20 AAC 25.035 (e) (2)} 53.80 Maximum surface 2674 psig, At total depth (TVD) 6525' / 3326 psig Setting Depth T OD Bottom MD TVD MD TVD Surface Surface 110' 110' Surface Surface 2863' 2690' Surface Surface 8311' 7134' tfJGA- fR/~1 ð 1- ~l{~ 1 a. Type of work III Drill [J Redrill [J Re-Entry [J Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4859' NSL, 1692' WEL, SEC. 11, T11 N, R11 E, (As Staked) At top of productive interval 2674' NSL, 980' WEL, SEC. 02, T11 N, R11 E, UM At total depth 2851' NSL, 941' WEL, SEC. 02, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028238,2851' MD V-106is46'awayat550'MD 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlinQ 20" 91.5# H-40 WLD 12-1/4" 9-5/8" 40# L-80 BTC 8-3/4" 7" 26# L-80 BTC-m 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 42" Lenath 80' 2863' 8149' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 480 sx PF 'L', 292 sx Class 'G' 180 sx Class 'G', 243 sx Class 'G' ./ 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 feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED JUN 2 1 2002 Perforation depth: measured true vertical AlaskB OH& Gas Cons. GomffUSSUM Anchorage 20. Attachments III Filing Fee [J Property Plat [J BOP Sketch [J Diverter Sketch III Drilling Program III Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis [J Seabed Report [J 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Magee, 564-5119 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the foregoinq is true~nd correct to the best of my knowledge Signed Brian Robertson .1, "t;~~ T~le, Senior Drilling Engineer Date ¡;,/ ;z.¡'èl.~ .Coinmt$Sløn"~$&,Only .,: " . . Permit Number API Number AP~cval Data" ~ See cover letter ?'n¿- /3 J 50- 02.9- 2307 "/ J ,/hi D Or/,. for other reQuirements Conditions of Approval: Samples Required 0 Yes ø No Mud Log q~i~'êtt ' 0 Yes LV No Hydrogen Sulfide Measures 0 Yes Ii No Directional Survey Required 18 Yes 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: 'T~s't- BOPE tÞ t./OflO PS;/. 1Arr ~ ~f #}¡1Þvt¡ i-:: k ~ ~1"<A' "-lei. Approved Bv Onglnal SlQnad sy( £orh'missioner Form 10-401 Rev. 12-01-85 Cammy Oechsli TaylOl 0 ¡ ¡ by order of the commission ~ \; L', ; ; , Date ((7 .~l~ Q?- ~nit In Tliplicate ") ) IWell Name: IV-105i Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): 1 Injector ./ Surface Location: As-Built (As Stacked) Target Location: Top Kuparuk Bottom Hole Location: x = 590,608.02' Y = 5,970,107.29' 48591 FSL (4211 FNL), 16921 FEL (3587' FWL), Sec. 11, T11N, R11E X = 591,280.00' Y = 5,973,209.99' 26741 FSL (26061 FNL), 9801 FEL (42991 FWL), Sec. 02, T11 N, R11 E X = 591,317.03' Y = 5,973,387.99' 28511 FSL (24281 FNL), 9411 FEL (43391 FWL), Sec. 02, T11N, R11E /" I AFE Number: 15M4021 1 Estimated Start Date: 17/15/2002 1 1 MD: 18311' 1 TVD: 17134' 1 I RiQ: I Nabors 9ES I OperatinQ days to complete: 116.5 ,.,-" I BF/MS: 153.8' 1 I RKB: 182.3' I Well DesiQn (conventional, slim hole, etc.): I Ultra Slimhole (Iongstring) I Objective: 1 Schrader/Kuparuk Formation Mud Program: 12 %" Surface Hole (O-2862'): Initial Base PF to top SV SV toTO Densitv (ppg) 8.5-9:2 9.0 - 9.5 9.5 max / Viscosity (seconds) 250-300 200-250 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) 50 - 70 15 - 20 30 - 45 < 10 20 - 40 < 10 8.5- 9.5 8.5-9.5 8.5- 9.5 8 3A" Production Hole (2862' - 8311): LSND Interval Density Tau 0 YP PV pH API HTHP (ppg) Fi Itrate Filtrate Upper 9.3-9.7 4-7 25-30 8-12 8.5-9.5 6-10 Interval Top of HRZ 10.1 / 4-7 20-30 8-14 8.5-9.5 4-6 <10 by toTO HRZ V-105i Permit Program Page 1 Directional: Ver. Anadrill P4 Slot NN KOP: 300' Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Intermediate/Production Hole Formation Markers: MDbkb Formation Tops SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma Na Oa Obf Base CM2 (Colville) THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU (Kuparuk B) Kuparuk A TMLV (Miluveach) V-105i Permit Program ') -) A 53Qat 2862' MD All wells pass major risk criteria. V-201 - 86 @ 398' MD V-102 -71' @ 550' MD V-106 - 46' @ 550' MD V-103 -76' @ 550' MD IFR-MS corrected surveys will be used for survey validation. Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: TVDss 1540 1670' 1685' 2184' 2300' 2555' 2880' 3225' 3620' 3950' 4185' 4320' 4715' 4980' 6235' 6415' 6480' 6525' 6525' 6690 6830 6910' MWD / GR None None MWD /GR / PWD PEX/BHC Sonic , USIT cement evaluation / Estimated pore pressure, PPG Hydrocarbon Bearing, Non Commercial Hydrocarbon Bearing, Non Commercial Hydrocarbon Bearing, Non Commercial Hydrocarbon Bearing, Non Commercial Hydrocarbon bearing, 8.4 ppg EMW Hydrocarbon bearing, 8.4 ppg EMW Hydrocarbon Bearing, 9.8 ppg EMW Hydrocarbon Bearing, 9.8 ppg EMW Hydrocarbon Bearing, 9.8 ppg EMW Hydrocarbon Bearing, 9.8 ppg EMW ./' Page 2 ') ) CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg O.D. MDITVD MDITVD bkb 42" 20" Insulated 91.5# H-40 WLD 80' GL 11 0/11 0 12 %" 9 5/8" 40# L-80 BTC 2863' GL 2863'/2690' / 8 3.dt 711 26# L-80 BTC-m 8149' GL 8311 '/7134' Tubing 3 V211 9.2# L-80 TC-II 7450' GL 7450'/6320' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from su rface shoe Test Type LOT EMW 11.9 ppg EMW Target / Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casinq Size 19-5/8" Surface I Basis: Lead: Based on 110' of cased hole, 1661' of annulus in the permafrost @ 2250/0 excess and 341' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOC: To surface Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2112' MD .,/ Total Cement Volume: Lead 355 bbl I 1991fe I 480 sks of Halliburton L at 10.7 ppg and 4.15 dIsk. ~ Tail 60 bbl I 336 fe I 292 sks of Dowell Premium 'G' at 15.8 ppg and 1 .15 dIsk. The 7" production casing will be cemented via an ES cementer in two stages. Casinq Size 17" Production Longstring 1 Basis: Stage 1: Based on TOC 500' above top of Kuparuk formation + 300/0 excess + 80' shoe Cement Placement: From shoe to 7254' MD Stage 2: Based on TOC 500' above top of Schrader +300/0 excess volume Cement Placement: From 200' below Schrade~ (6039/MD) to 4500' MD Total Cement Volume: Stage 1 37 bbls I 207 fe I 180 sks of Halliburton Premium "G" Latex at 15.6 Ppg and 1.15cf/sk. Stage 2 53 bbls 1297 ft~ I 243~ks of Halliburton Premium "G" at 15.6 ppg and 1 .22 dIsk V-105i Permit Program Page 3 ) ) Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the need to test the production casin~o 4000 psi for MI service considerations, the BOP equipment will be tested to 4000 psi. The maximum anticipated surface pressure is 2674 psi with full casing evacuation. / Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: . Maximum surface pressure: 3326 p~@ 6525 TVOss - Kuparuk Sands 2674 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) /' 4000 psi (The casing and tubing will be tested to 4000 psi as . Planned BOP test pressure: required for MI service.) . Planned completion fluid: 8.9 ppg filtered brine / 6.8 ppg diesel Disposal: . No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-105i Permit Program Page 4 ') ') DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor not yet installed. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and lor well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES on Slot NN. /~ 2. Nipple up diverter spool and riser. P 4" D as required and stand back in derrick. 3. MU 12 %" drilling assembly with M and directionally drill surface hole to approximately 2862'. MD 1 2690' TVD. An intermediate wiperlbit trip to surface fora will be performed prioç to exiting the Permafrost. The actual surf~ hole TD will be +1-100' TVD below the top of the SV1 sand. 4. Run and cement the 9-5/8", 40# surface casing back to surface. /' 5. ND diverter spool and NU casing 1 tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drilling assembly with MWD/PWD/GR and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. / ' 7. Drill out shoe joints and displace well to 9.3 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead and increase mud weight to 9.7 ppg prior to first wiper trip. 9. Drill to +1-100' above the HRZ, ensure mud is in condition to 10.1 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to TD at -8311' MD. Lay in "Steel Seal" pill on trip out prior to logging. 11. Rig up Schlumberger and run PEX/Dipole sonic. One attempt on wireline will be made after which TLC will be utilized. / 12. If required, condition hole for running 7" 26# long-string casing. 13. Run and cement the 7" production casing in two stages utilizing a ES cementer. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. . 14. PU drill out assembly and drill out ES cementer. RIH to LC and test casing to 4000 psi for~ minutes. Displace well to 8.9 ppg filtered KCL brine and spot perf pill across the Schrader perforation interval. 15. RU Schlumberger and run USIT log on e-line from the 7" landing collar to TOC. 16. Perforate Schrader interval. 17. Make scraper run and POOH laying down excess drill-pipe. /' 18. Run the combination 3-1/2" 9.3#, L-80 TC-II 1 4-1/2", 12.6#, L-80 TC-II completion assembly. Set packers and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear RP valve and install TWC. Test below to 2750 psi. 19. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 20. RU hot oil truck and freeze protect well to lower GLM. 21. Rig down and move off. V-105i Permit Program Page 5 ') ') V-105i Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location is V-106, 45 feet to the East. A surface shut-in will not be required. ~ Check the landing ring height on the V-105 conductor. The BOP stack may need an additional adapter flange to provide the correct height. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" ~"J.m}....»m>,.."'l'mm}~»)'»»»)m»)»~"""",w...¡.»»»>>>'W.....m>>»m)>»)>> »,,-,"'Ý.>>>>>'...d,>>¡.>>»>>»>>>>w,;m.»>>»»m>>>>>>>>>>>>>> ~'ymy.....»»»)¡.»)>»»»1'h»»» Job 2: Drillina Surface Hole ~ No faults are expected to be penetrated by V-105 in the surface interval. ~ There are two close approach issues in the surface hole. All wells pass major risk criteria. The closest existing well, V-106 is 45' center-center at surface to ~550' MD. GyroData will be on standby while drilling the surface hole until clear of magnetic intereference. ~ Gas hydrates have been observed in wells drilled on V-Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations ~~~mri'. Job 3: Install surface Casina Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 225°k excess cement through the permafrost zone (and 30°10 excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at :!::1 OOO'MD to allow remedial cementing. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30°10 excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. V-105i Permit Program Page 6 ) ) Reference RPs .:. UCasing and Liner Running Procedure" .:. uSurface Casing and Cementing Guidelines" .:. ¡¡Halliburton Cement Program" .:. ¡¡Surface Casing Port Collar Procedure" Note: Check surface cement level prior to leaving well to establish if cement has slumped. If TOC greater than 20' below conductor, perform top job at an opportune time. Note: In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. '~;;'-~;:~IW,.'Ymy,.m'M}»Y'¡:'W..:-}"»}»m,."...../m}}}»})»}-»»)}Jo'»>>}»»¡.)}¡.»>¡.»»»»») »»,>,>:,'m»,),»),,»»»,»".':',»»}¡-»,»»,»»,,»,»11'»»,,"",),,»»,»,y'>,»,,-..1'»),»»»> Job 7: DrillinQ Production Hole HazardsandConUngencres Þ- One fault have been identified as a potential hazard in the well course. The fault is anticipated at 2750' TVDss (2920' MD +/- 150'). The fault has a 75' throw and is not expected to result in drilling losses. If unexpected losses are encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. Þ- KICK TOLERANCE: In the case scenario of 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 11.9 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 11.9 ppg. Þ- V-Pad development wells have "kick tolerances" in the 30-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals ;... There are no "close approach" issues with the production hole interval of V -1051. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. uShale Drilling- Kingak & HrZ" = I'''''~ml:mJ- .,~._""'-- -- "'.w,~----,~. '''''-'~ ... ,,to '.'..'" "'''.NHA~''-'}(:''.' . :"""".'.""_m"'..7_'_--'_'.'.>----->.'.'_n-->---J"--->->.'.'.o".,', .... ,,-,.... >L..M ", _1~ Job 8: LOQ Production Hole Hazards and Contingencies Þ- Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. Þ- If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. V-105i Permit Program Page 7 ') ') Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" ~,~ ,~~,~,~ Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The 7" casing is expected to be cemented to 500' above the Schrader sand in a two stage job. The first stage will cover from TD to 500' above the Kuparuk and the second stage will cover from 200' below the Schrader to 500' above the Schrader.. ~ Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 56 bbls of dead crude (2000'), the hydrostatic pressure will be 10.1 ppg vs the 9.8 ppg EMW of the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude however the hydrostatic pressure of the mud and diesel should exert a 46 psì overbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) > A cement bond log (USIT) will be run to confirm the TOC. This will be done with the rig prior to perforating and running the completion. ~ Ensure a minimum hydrostatic equivalent of 10.1 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be issued detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Halliburton Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" ~= ~~~ ..~.~"':.V<X,..':..::..;:'.~." Job 1 0: Perforate Well Hazards and Contingencies ~ The Schrader interval of the well will be TCP perforated prior to running the completion. After placing a brine perf pill weighted to 8.9 ppg the well will be perforated across a 8.4 ppg EMW reservoir for an overbalance of 110 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. ~ A USIT log will be required from the ETD to the top of cement. Send results of USIT log into Anchorage office as soon as practical for evaluation. V-105i Permit Program Page 8 ') ) Reference RPs .:. See attached Initial Perforating Procedures ~MWm.I.W..~.~.X'MC'M'_'»C..«*X M««M¡.~_~~ Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The Schrader interval of the well will be perforated. ~ Take care while passing through ES cementer with packer and completion string. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When test annulus maintain no more than a 1500 psi differential -2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus .y~,mmm""''':<,:,'''Y'''''',,;>>>>Y.>''''' »xm>>>>>,>>y........."w..:-w.>1<):w.>>>>>",.....",....m.IJH "",},X>",»YM,W..m;-_,:-»Y..» V-105i Permit Program Page 9 ') ) V-105i Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates may be encountered near the base of the Permafrost at 1771 'MD and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: . A majority of the V-Pad development wells will have "kick tolerances" in the 35-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. . The production section will be drilled with a recommended mud weight of 10.1 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.8 pore pressure. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . V-105i will cross a fault below the SV-1 at ....2920' MD (+/-150'). The estimated throw of the fault is approximately 75'. Loss circulation is not considered to be a risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies V-105 Schlumbøruør Proposed Well Profile - Geodetic Report Report Date: April 9, 2002 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 12.890° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 f1 Structure I Slot: V-Pad/V-105 illty tu TVD Reference Datum: KB Well: V-105 III TVD Reference Elevation: 82.4 ft relative to MSL Borehole: V-105 51 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL ,~ UWI/API#: 50029 Magnetic Declination: 25.98r Survey Name I Date: V-105 (P4) 1 April 9, 2002 Total Field Strength: 57478.446 nT Tort I AHD I DDII ERD ratio: 94.442° 13409.37 ft 15.5741 0.47E Magnetic Dip: 80.759° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: July 17, 2002 Location Lat/Long: N 70.32806711, W 149.2651579~ Magnetic Declination Model: BGGM 2001 Location Grid N/E Y/X: N 5970107.290 ftUS, E 590608.020 ftUS North Reference: True North Grid Convergence Angle: +0.69195772° Total Corr Mag North .> True North: +25.987° Grid Scale Factor: 0.99990933 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD I VSec N/.S E/.W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (O/100ft) (ftUS) (ftUS) KBE 0.00 0.00 165.00 0.00 0.00 0.00 0.00 0.00 5970107.29 590608.02 N 70.32806711 W 149.26515795 Ndg 1/100 300.00 0.00 165.00 300.00 0.00 0.00 0.00 0.00 5970107.29 590608.02 N 70.32806711 W 149.26515795 400.00 1.00 165.00 399.99 -0.77 -0.84 0.23 1.00 5970106.45 590608.26 N 70.32806482 W 149.26515608 Base Gubik 407.41 1.07 165.00 407.40 -0.89 -0.97 0.26 1.00 5970106.32 590608.29 N 70.32806446 W 149.26515584 500.00 2.00 165.00 499.96 -3.08 -3.37 0.90 1.00 5970103.93 590608.96 N 70.32805791 W 149.26515065 600.00 3.00 165.00 599.86 -6.94 -7.58 2.03 1.00 5970099.74 590610.14 N 70.32804641 W 149.26514149 ~, Drp 1/100 700.00 4.00 165.00 699.68 -12.34 -13.48 3.61 1.00 5970093.86 590611.79 N 70.32803029 W 149.26512867 800.00 3.00 165.00 799.49 -17.73 -19.38 5.19 1.00 5970087.98 590613.44 N 70.32801417 W 149.26511586 900.00 2.00 165.00 899.39 -21.59 -23.59 6.32 1.00 5970083.78 590614.62 N 70.32800267 W 149.26510670 1000.00 1.00 165.00 999.36 -23.90 -26.12 7.00 1.00 5970081.26 590615.33 N 70.32799576 W 149.26510118 SV6 1058.05 0.42 165.00 1057.40 -24.54 -26.81 7.18 1.00 5970080.57 590615.52 N 70.32799387 W 149.26509972 KOP Bid 1.5/100 1100.00 0.00 12.77 1099.35 -24.67 -26.96 7.22 1.00 5970080.42 590615.56 N 70.32799346 W 149.26509940 1200.00 1.50 12.77 1199.34 -23.36 -25.69 7.51 j 1.50 5970081.69 590615.84 N 70.32799693 W 149.26509705 1300.00 3.00 12.77 1299.26 -19.44 -21.86 8.38 1.50 5970085.53 590616.66 N 70.32800739 W 149.26508999 1400.00 4.50 12.77 1399.04 -12.90 -15.48 9.83 1.50 5970091.93 590618.04 N 70.32802482 W 149.26507824 1500.00 6.00 12.77 1498.62 -3.75 -6.56 11.85 1.50 5970100.87 590619.95 N 70.32804919 W 149.26506185 1600.00 7.50 12.77 1597.92 8.01 4.91 14.45 1.50 5970112.37 590622.41 N 70.32808053 W 149.26504077 SV5 1624.70 7.87 12.77 1622.40 11.31 8.13 15.18 1.50 5970115.60 590623.10 N 70.32808932 W 149.26503485 V-105 (P4) report. xis Page 1 of 3 4/9/2002-11 :49 AM Grid Coordinates Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I N/.S I E/.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1700.00 9.00 12.77 1696.89 22.36 18.90 17.62 1.50 5970126.40 590625.41 N 70.32811875 W 149.26501506 End Bid 1746.13 9.69 12.77 1742.40 29.85 26.21 19.28 1.50 5970133.73 590626.98 N 70.32813872 W 149.26500160 SV4 1756.27 9.69 12.77 1752.40 31.55 27.87 19.65 0.00 5970135.39 590627.33 N 70.32814325 W 149.26499860 Base Permafrost 1771.49 9.69 12.77 1767.40 34.12 30.37 20.22 0.00 5970137.90 590627.87 N 70.32815008 W 149.26499398 Bid 2/100 1796.85 9.69 12.77 1792.40 38.39 34.53 21.16 0.00 5970142.07 590628.76 N 70.32816145 W 149.26498636 1800.00 9.75 12.77 1795.50 38.92 35.05 21.28 2.00 5970142.59 590628.87 N 70.32816287 W 149.26498538 Bid 4.25/100 1896.85 11.69 12.77 1890.66 56.94 52.63 25.26 2.00 5970160.22 590632.64 N 70.32821089 W 149.26495311 r""""'" 1900.00 11.83 12.77 1893.74 57.58 53.25 25.41 4.25 5970160.84 590632.78 N 70.32821259 W 149.26495189 2000.00 16.08 12.77 1990.77 81.68 76.76 30.73 4.25 5970184.41 590637.82 N 70.32827682 W 149.26490875 2100.00 20.33 12.77 2085.75 112.91 107.22 37.64 4.25 5970214.95 590644.36 N 70.32836003 W 149.26485272 2200.00 24.58 12.77 2178.14 151.09 144.45 46.07 4.25 5970252.27 590652.34 N 70.32846174 W 149.26478435 SV3 2298.79 28.77 12.77 2266.40 195.43 187.69 55.88 4.25 5970295.62 590661.62 N 70.32857987 W 149.26470480 2300.00 28.83 12.77 2267.46 196.01 188.26 56.00 4.25 5970296.20 590661.74 N 70.32858142 W 149.26470383 2400.00 33.08 12.77 2353.20 247.43 238.41 67.37 4.25 5970346.4 7 590672.50 N 70.32871843 W 149.26461162 SV2 2435.15 34.57 12.77 2382.40 266.99 257.49 71.69 4.25 5970365.60 590676.59 N 70.32877055 W 149.26457658 2500.00 37.33 12.77 2434.90 305.06 294.62 80.11 4.25 5970402.83 590684.56 N 70.32887199 W 149.26450830 2600.00 41.58 12.77 2512.10 368.59 356.57 94.15 4.25 5970464.94 590697.85 N 70.32904123 W 149.26439444 2700.00 45.83 12.77 2584.38 437.66 423.94 109.42 4.25 5970532.48 590712.30 N 70.32922528 W 149.26427060 SV1 2778.49 49.16 12.77 2637.40 495.51 480.36 122.21 4.25 5970589.05 590724.41 N 70.32937941 W 149.26416687 2800.00 50.08 12.77 2651.34 511.90 496.34 125.83 4.25 5970605.07 590727.84 N 70.32942307 W 149.26413751 9-5/8" Csg Pt 2862.63 52.74 12.77 2690.40 560.85 544.07 136.65 4.25 5970652.92 590738.08 N 70.32955346 W 149.26404976 End Bid 2862.72 52.74 12.77 2690.46 560.92 544.15 136.66 4.25 5970653.00 590738.09 N 70.32955368 W 149.26404967 UG4A 3311.91 52.74 12.77 2962.40 918.43 892.82 215.69 0.00 5971002.57 590812.89 N 70.33050621 W 149.26340868 .~ UG3 3881.77 52.74 12.77 3307.40 1371.99 1335.16 315.94 0.00 5971446.04 590907.78 N 70.33171464 W 149.26259549 UG1 4534.22 52.74 12.77 3702.40 1891.28 1841.60 430.72 0.00 5971953.79 591016.43 N 70.33309817 W 149.26166433 Drp 4/100 4579.23 52.74 12.77 3729.65 1927.11 1876.54 438.64 0.00 5971988.82 591023.93 N 70.33319362 W 149.26160007 4600.00 51.91 12.77 3742.35 1943.55 1892.58 442.27 4.00 5972004.90 591027.36 N 70.33323744 W 149.26157062 4700.00 47.91 12.75 3806.73 2020.04 1967.18 459.17 4.00 5972079.69 591043.36 N 70.33344124 W 149.26143350 4800.00 43.91 12.73 3876.29 2091.85 2037.22 475.00 4.00 5972149.91 591058.34 N 70.33363258 W 149.26130507 4900.00 39.91 12.70 3950.70 2158.63 2102.37 489.70 4.00 5972215.23 591072.25 N 70.33381056 W 149.26118579 5000.00 35.91 12.68 4029.58 2220.06 2162.30 503.20 4.00 5972275.31 591085.03 N 70.33397428 W 149.26107626 Ma 5003.48 35.77 12.67 4032.40 2222.10 2164.28 503.64 4.00 5972277.29 591085.44 N 70.33397969 W 149.26107269 5100.00 31.91 12.64 4112.55 2275.84 2216.72 515.42 4.00 5972329.87 591096.59 N 70.33412295 W 149.26097710 5200.00 27.91 12.60 4199.22 2325.69 2265.37 526.31 4.00 5972378.64 591106.89 N 70.33425586 W 149.26088874 Na 5276.12 24.87 12.56 4267.40 2359.52 2298.39 533.68 4.00 5972411.74 591113.86 N 70.33434606 W 149.26082894 V-105 (P4) report.xls Page 2 of 3 4/9/2002-11 :49 AM Grid Coordinates Geographic Coordinates Station ID MD I Incl Azim TVD VSec I N/.S I E/.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 5300.00 23.91 12.54 4289.14 2369.38 2308.01 535.82 4.00 5972421.39 591115.88 N 70.33437235 W 149.26081158 5400.00 19.91 12.47 4381.90 2406.69 2344.43 543.90 4.00 5972457.90 591123.52 N 70.33447184 W 149.26074601 Oa 5421.73 19.04 12.44 4402.39 2413.93 2351.51 545.4 7 4.00 5972465.00 591125.00 N 70.33449118 W 149.26073327 End Orp I Target 5421.74 19.04 12.44 4402.40 2413.94 2351.51 545.4 7 4.00 5972465.00 591125.00 N 70.33449118 W 149.26073327 Obf Base 5839.61 19.04 12.44 4797.40 2550.26 2484.64 574.84 0.00 5972598.46 591152.76 N 70.33485488 W 149.26049495 CM2 6119.95 19.04 12.44 5062.40 2641.72 2573.95 594.55 0.00 5972687.99 591171.39 N 70.33509886 W 149.26033501 CM1 6908.07 19.04 12.44 5807.40 2898.84 2825.03 649.97 0.00 5972939.70 591223.77 N 70.33578477 W 149.25988527 f~ Top HRZ 7447.59 19.04 12.44 6317.40 3074.85 2996.92 687.90 0.00 5973112.02 591259.62 N 70.33625435 W 149.25957745 Base HRZ 7638.01 19.04 12.44 6497.40 3136.97 3057.58 701.29 0.00 5973172.83 591272.27 N 70.33642007 W 149.25946878 K-1 7706.77 19.04 12.44 6562.40 3159.41 3079.49 706.12 0.00 5973194.80 591276.84 N 70.33647992 W 149.25942958 Top Kuparuk I C 7754.37 19.04 12.44 6607.39 3174.93 3094.65 709.47 0.00 5973209.99 591280.00 N 70.33652134 W 149.25940239 Target 7754.38 19.04 12.44 6607.40 3174.94 3094.66 709.47 0.00 5973210.00 591280.00 N 70.33652136 W 149.25940239 LCU I Kup B 7928.93 19.04 12.44 6772.40 3231.88 3150.26 721.74 0.00 5973265.74 591291.60 N 70.33667326 W 149.25930280 KupA 8077.03 19.04 12.44 6912.40 3280.20 3197.45 732.15 0.00 5973313.05 591301.44 N 70.33680217 W 149.25921831 TMLV 8161.65 19.04 12.44 6992.39 3307.81 3224.41 738.10 0.00 5973340.08 591307.06 N 70.33687582 W 149.25917002 TO I 7" Csg pt 8311.66 19.04 12.44 7134.19 3356.75 3272.20 748.65 0.00 5973387.99 591317.03 N 70.33700638 W 149.25908440 LeClal Description: Surface: 4859 FSL 1693 FEL S11 T11 N R11 E UM End Orp I Target : 1931 FSL 1145 FEL S2 T11N R11E UM Target: 2674 FSL 980 FEL S2 T11N R11E UM BHL: 2851 FSL 941 FEL S2 T11N R11E UM Northina (V) rftUSl Eastina (X) rftUSl 5970107.29 590608.02 5972465.00 591125.00 5973210.00 591280.00 5973387.99 591317.03 !~ V-105 (P4) report.xls Page 3 of 3 4/9/2002-11 :49 AM I I I -P~~?-~~-,-,"",~~-~,J~--~~-- - -- ..~-- - - t ,,~ G,'" .." f" 'On", ~rp1l1oo &1 I ~ . ~~0~~~6~,p~~~ I -J~:-~:-._~:-._;¡;;,~:.:I-:~._"._-:_--;;;~_.;;;;;;,;;-J;;:;;:;;::-.__:-- :_~.- - - ---~~~~~~~~:t=~~~:::; ;,,~,,~ = = : = : =_:~ I Bid 4.2~100 1897 MO 1891 TVO ! - t - - -: :: ::":," r::=:~~~~;~i¡:~::: - - - - - - - - - r ~'g..- r-"'~' 'C,"-M~:I~;::;;:~~~;-' 3000 ~--- - ~ ~-F ,: ,ili:~,,,, - . ' ~--=1*-:'~~~,:, - - - - --~ ~-:-: - ..... - - --- "ÜGI~¡;34'Mf):)ïÕ:i 'í'VÕ - ,- 1?:7d~~rt~~e ,,- ....! ,-- -- ...- ...... (]) ...- ~~ g~ 0 Q) ~ > II B c: CO ~~ _0 ..c:~ ã.~ £3 ar 4000 ~,"-:::::-,-::::-'-::::'--',~,:: rn~ .2 'êi> ~o:: > > (])SQ ::sW '- ~ ':: :\.~ ;~ ,,~( ~.~#-. ~ .:~=r '. , ,'1,""' "..'-'::Y ,f~ .j~ . ....~~~ ..' ';,\; "i' ,'~ '" 0-"" 1 000 ~"" 2000 -"" 5000 6000 7000 ') .) VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska V-105 (P4) Schlumberger Prudhoe Bay Unit - WOA Structure: V-Pad Section At: 12.89 deg Date: April 09, 2002 - -- -..¡ ,~ --_._~-- ....~ ..'" , ' , , ........,,,_..,..__..,,,.,..._,-,,,-~J)<I.,:rarpt.,,,.._..,-,....,..,..........,,-;-......- "" ,,,,,,,,, "... "", "¥22'MO"'44Ó2TV6'" ,,,,, "', ,,,, 1¡9,04' 12,44' az ~414,deparlure" ...+ ..... , , , , ! Hold Angle 19.0f ------ J.:<:~t:..~.t.~) Target, 7754 MO !6607 TVO -- ¿:i:~~f~M - - - - --1 ~ 1~~ !f~~ZV' / .~~ ~" ~.w ........ 0 1000 2000 I 3000 I 4000 Vertical Section Departure at 12.89 deg from (0.0, 0.0). (1 in = 1000 feet) ~:,~ .[:.~: .ff... .~~ :~4 'I:', , . ' )? ....:",:.~... . .':$'"': .".~i~, ';J ,~;:f~ 3000 - 2500 _m ^ ^ ^ I .- œ: 2000 _m, 0 Z 1500 _.... I .- ::> 0 (/) 1000 _m, V V V 500-,.. 0 ~;. .:' l :.i;~ -500 I ') Client: PLAN VIEW BP Exploration Alaska Well: V-I05 (P4) Field: Prudhoe Bay unit - WOA Structure: V-Pad Scale: Date: 1 in = 500 ft 09-Apr-2002 0 , True North Mag Dee ( E 25.99° ) .I. 0 "t' "t' N 'I'- is ,::;, ,mm.."W,..mm, .Þ 0 ~ """''''''''''''''','' 500 I ~r I~ !In=.,~ , , :----- 4579 MD 3730 T)' , 52,74' 12.77' az¡ 1877 N 439 E 1000 TD I T' Csg Pt 8312 MD 7134 TVD 19,04' 12.44' az 3272 N 749 E .~ Target : 7754 MD 6607 TVD : 19,04' 12.44' az 3095 N 709 E End Drp I ~arget 5422 MD :4402 TVD 19,04' 1~,44' az 2352 N 5115 E ...........................................,.......... En~ Bid 19-5/8" C / 28~3 MD 2690;~ Pt \J ~ , 52-74' 12,77" az -f- --f 544 N m~n~- KoP Bid 1,51100 ¡ 11<10 MD 1099 TVD : Bid 4,25/100 0,00' 12,77' az d; 1897 MD 1891 TVD 278 7E ' : 11,69' 12,77'az I I I 53 N 25 E Drp 1/'00 : BI.l2I100 7oo~~ 700TVD ~,,: ~ 17~7MD 1792TVD 4.00 ¡165,oo' az ~ "\': 9,~9' 12,77" az 135 fE ~..n' "'_m 35iN 21 E, Ndj¡ 11100 , End Bid: 30q MD 300 TVD ' 1746 MD ¡ 1742 TVD O,op' 165,00' az 9,69' 12¡77" az °li OE 26N 19~ I -500 I 0 «< WEST I 500 I 1000 EAST »> Schlumbepgep 1500 - 3000 m - 2500 .. - 2000 ,.. -1500 m - 1000 -500 -0 I 1500 ) Schlumberger Anticollision Report ) Compan)': Field: Reference Site: Reference \\o'ell: Reference Wellpath: BP Amoco Prudhoe Bay PB V Pad V -105 Plan V-105 Date: 4/9/2002 Time: 13:51 :27 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: V-105, True North V-105 plan 82.4 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 8311.66 ft Maximum Radius: 2000.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 4/9/2002 Validated: No Planned From To Survey ft ft 28.50 500.00 500.00 8311.66 Version: Toolcode 10 Tool Name Planned: Plan #4 V1 Planned: Plan #4 V1 CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station Casing Points 1\10 TVD ft ft 2862.63 2690.40 8311.66 7134.19 Diameter in Hole Size in Name 9.875 7.000 12.250 8.750 97/8" 7" Summary 1< I Site I --- Offset Wellpatb -----> Well Wellpath Reference Offset MD 1\ID ft ft Ctr-Ctr No-Go Allowable Distance Area Deviation ft ft ft Warning EX WKUPST-01 WKUPST-01 WKUPST-01 V1 Out of range PB V Pad V-100 V-100 V7 1148.26 1150.00 200.59 15.03 185.65 Pass: Major Risk PB V Pad V-101 Plan V-101 V5 Plan: PI 599.16 600.00 190.77 12,56 178.22 Pass: Major Risk PB V Pad V-102 Plan V-102 V2 Plan: PI 549.79 550.00 71.17 12.08 59.09 Pass: Major Risk PB V Pad V-103 Plan V-103 V3 Plan: PI 549.23 550.00 75.97 11.98 64.00 Pass: Major Risk PB V Pad V-104 Plan V-104 V3 Plan: PI 599.30 600.00 131.12 12.87 118.25 Pass: Major Risk PB V Pad V-106 Plan V-106 V3 Plan: PI 549.15 550.00 46.18 11.99 34.19 Pass: Major Risk PB V Pad V-108 Plan V., 1 08 V1 Plan: V- 650.04 650.00 221.72 12.58 209.14 Pass: Major Risk PB V Pad V-201 V-201 V8 398.81 400.00 86.41 7.41 79.03 Pass: Major Risk 0 0 0 0 0 ~ 0 J J ~ ~ J ^I J Target: V-105 SB Tgt Site: PB V Pad Drilling Target Conf,: 99% Centre Location: Map Northing: 5972465,00 ft Map Easting : 591125.00 ft Latitude: 70020'04.l68N Shape: Circle ') C) C) -=t- C) C) Lfl C) C) úJ C) C) I "Well: V-105 \ased on: Planned Program fertical Depth: 4320.00 ft below Mean Sea Level Local +N/-S: 2351.50 ft Local +E/-W: 545.52 ft Longitude: 149°15'38,640W Radius: 150 ft C) C) CXJ 2500 2500 24-00 2300 2200 2100 CJ C) U Polygon 1 2 3 4 ~ ') Target: V-I05 Kup Tgt Site: PB V Pad Drilling Target Conf.: 99% Centre Location: Map Northing: 5973210,00 ft Map Easting : 591280,00 ft Latitude: 70020'11.477N +N/-S ft -217,22 191.76 96,98 -301.94 +E/- W ft -232,67 -142.70 251.21 156.37 CJ CJ -=I- CJ CJ Ln CJ CJ I CJ CJ LD ,Well: V-105 \'ased on: Planned Program hertical Depth: 6635.00 ft below Mean Sea Level Local +N/-S: 3094,63 ft Local +E/-W: 709.53 ft Longitude: 149°15'33,849W Northing ft 5972990,00 5973400,00 5973310.00 5972910,00 CJ CJ m CJ CJ CT CJ CJ CJ CJ CJ Easting ft 591050,00 591135,00 591530,00 591440.00 34-00 3300 3200 3100 3000 2900 2800 2100 2500 CJ CJ N ) ) Borealis V-105i Proposed Completion TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = :t47' RKB-MSL = :t77' I . 3-1/2" 'X' Landing Nipple with 2.813" bore. I 2200' I 9-5/8", 40 #/ft, L-80, BTC j .. 2862' Gas Lift Mandrels with handling pups installed. L GAS LIFT MANDRELS # MD Type Valve Type 1 TBD 3-1/2" MMGW Dummy 2 TBD 3-1/2" MMGW Dummy 3 TBD 3-1/2" MMG RP 4 TBD 3-1/2" MMG Dummy L 3-1/2" 'X' Landing Nipple with 2.813" . bore lEI 7" x 4-1/2" Baker "Premium" ~ Production Packer +/-150' above top Schrader perforation 3-1/2" MMGW Water Flood GLM ---- with Injection Valve with New Vam BxP ~ \e. 3-1/2" 9,3# L-80, TC-II Tubing L 3-1/2" 9.3#, L-80, TC-II Tubing below top packer ~ L 7" 'ES cementer +/- 200 below Schrader ,~ 3-1/2" 'X' Landing Nipple with 2.813" bore. 7" x 4-1/2" Baker "S-3" Packer +/- 200' above Kuparuk 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 3-1/2" 'XN' Landing Nipple with 2.750" seal bore 3-1/2" WireLine Entry Guide set at +/-130' above the Kuparuk Formation Plug Back Depth I 7", 26 #/ft, L-80, BTC-Mod ~',' I 8215' ,~ 8300' Date 6-11-02 Rev By NM Comments Borealis WELL: V-105i API NO: 50-029-???? Proposed Completion (P4) BP Alaska H 206925 DATE INVOICE / CREDIT MEMO Permit To Drill Fee GROSS VENDOR DISCOUNT )5/23/02 CK052302H ) DESCRIPTION DATE ) OS/28/02 PIs call Terrie Hubble X4628 e ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BPEXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TOTAL ~ FIRST NATIONAL BANK OF ASHLAND ANAFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO CHECK NO, H206925 NET $100.00 $100.00 CONSOLIDATED COMMERCIAL ACCOUNT NO.'.'H'208925 56-389 412 ",'.,.," ,.,.:',.'.,,> ,'"",' ,',:r;,'.,,',',",;l,' ,',,'" (UI,' k ",dOt,',' . ''''1' ',/ lit "/' ( J 4.... .... ..... . -~l, 01' lUP '111'" TO THE ORDER OF Alaska Oil & Gas CcÙÎ,servå.tion' ", CCmIni s sion :333 with Ave, Ste Anchor;:j,ge AI< 99501 NO¡VALlP AFTER 120 DAys .'!r****$:tOO .OO***'!r*<* , ***May<2.8, 2002*** n,.',.."",:.,'"..,~,.,',',''" "',',',.,.,.,.,.,.".,..,.".",.".,.,:"'",':.".",..',,::,,,.,.,.,,', '" ",'",':,'"',..,..,.,,,.:,.,.,',.,",. .'~~7>,.',".'.".",.,.'," lÇ.~~i{,~ 118 2 0 b q 2 5118 I: 0 L, ~ 20 3 8 q 51: 0 0 8 L,... ~ q 118 ~ CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION ",;\fEr INJECTION ~LL REDRILL Rev: 5/6/02 C\jody\templates ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ../ WELL NAME /.t!q (/-/t:JS/ , '\. CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) ) "CL UE" The permit is for a new wellbore segment of existing well ---J 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). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-> SP ACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. 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. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELLPERMITCHECKLlST COMPANY ßI'X WELLNAME/H4 t/-Io./;/ PROGRAM: Exp- Dev- Redrll- Se~-X.. Wellboreseg- Ann.disposalparareq- FIELD & POOL Co/(?¡~.d INITCLASS /- ~ ß'~7 r"", GEOLAREA ~70 UNIT# /1~,{t1 ON/OFF SHORE 1'1,11 i ,ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 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 . "W~, ~t ~9A''' 12. Permit can be issued without administrative approval.. . . . . Y N {Iff?, '7~ ",,/6,,- 13. Can permit be approved before 15-day wait.. . . . . . . . . . ~' N t ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . Y' N 'kJ" (i) 110 . 15. Surface casing protects all known USDWs. . . . . . . . . . . N J 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ' N AdìL7J-- ~ (W ~ ç ~/r' 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ 18. CMT will cover all known productive horizons. . . . . . . . . . ~) N ~~: ~~:~~a::~~~~:~~i~:~~~~ ;¡t::~ ~ :~r~~fr.o~t.. : : : : : : ~ ~ Ntt b ~ ~ C} £ ~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . IN - Ai/If- 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . ' "N . 23. If diverter required, does it meet regUlations, . . . . . . ., . . ., ,. N I) l \I ~;/féy f'{4e,~, hL J, 24, Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ~,I' I-:: APPR. DAT~ 26. BOPE press rating appropriate; testto 4000 psig. N Pl > /) 2&17'-( fSf" f'hltt ~ ~'lt t:.j.fx;1.J f$ 1'" ~tt- b{~"I()L 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . éi2 N 28. Work will occur without operation shutdown. . . . . . . . . . . mN 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . T@ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . ('ÿ\.¡ 31. Data presented on potential overpressure zones. . . . . .. ,JYN A J /1 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / V7 " ¡ ~R A~T.EJ. 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ~,,~ -0/''':1 In?... 34. Contact name/phone for weekly progress reports [exploratory on'- Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GE°!iß~Y: ENGINEERING: UIC/Annular: éOMMISSION: RPcf5l~ j JDH "Hr COT I ! WGA~ DTS06, 26 I;J,~ ) GEOLOGY APPR DATE ~ øÞ~ '" J ,/l~¡A u Commentsllnstructions: G:\geology\permits\checklist.doc