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Home My WebLink About201-047Nolan 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: 1/28/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240128 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 14B 50133205390200 222057 10/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 232-04 50283100230000 162037 1/8/2025 AK E-LINE TubingPlugCut BRU 241-34S 50283201980000 224077 1/11/2025 AK E-LINE Perf END 2-16 50029218850000 188134 10/6/2024 YELLOWJACKET PERF MPU H-08B 50029228080200 201047 1/9/2025 READ CaliperSurvey MRU M-25 50733203910000 187086 1/2/2025 AK E-LINE Perf PEAR 11 50133207120000 223032 10/2/2024 YELLOWJACKET PLUG-PERF Please include current contact information if different from above. T40025 T40026 T40027 T40028 T40032 T40033 T40035 MPU H-08B 50029228080200 201047 1/9/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.29 10:55:36 -09'00' 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: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' 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: Tubing Swap 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,445'N/A Casing Collapse Conductor N/A Surface 5,410psi Liner 7,500psi Liner A 11,170psi Liner B 11,170psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,389 MD/ 3,761 TVD & 8,421 MD/ 3,783 TVD aqnd N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 11,403' Perforation Depth MD (ft): 11,485' See Schematic 2,352' See Schematic 4-1/2" 4,192'2-7/8" 110' 20" 7" 4-1/2" 8,588' 2-7/8"2,455' 664' MD N/A 10,570psi 7,240psi 8,430psi 3,899' 4,156' 4,252' 8,588' 9,085' Length Size Proposed Pools: 110' 110' 12.6 / L-80 / IBT-M TVD Burst 8,425' 10,570psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 201-047 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22808-02-00 Hilcorp Alaska LLC C.O. 477.07 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 11/26/2024 7" x 4-1/2" Baker S-3 & Baker ZXP LTP and N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT H-08B MILNE POINT SCHRADER BLUFF OIL N/A 4,197' 11,445' 4,197' 894 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:04 pm, Nov 15, 2024 Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2024.11.15 11:09:08 - 09'00' Scott Pessetto (9864) 324-650 477.005 SFD * Approved for forward circulating jet pump only. ADL0025906, ADL0025518 SFD 11,430' 10-404* Tubing injection trip pressure not to exceed 3650 psi. Tubing low pressure trip pressure no lower than 1800 psi. * SSV closure on tubing to initiate SSV on IA within 2 minutes and visa versa. * Approved variance to 20 AAC 25.265 (c)(1) - SSV on IA will not be located in the vertical run of the tree. * Biennial MIT-IA * Caliper log to AOGCC upon completion. DSR-11/21/24SFD 11/18/2024 SFD Witnessed BOP Test and Annular Test to 2500 psi. X MGR25NOV24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.25 15:46:46 -09'00'11/25/24 RBDMS JSB 112624 ®ôīīϙbÍıôϡ aϙFϱ͏͗IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͗ϱ͏͑ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ IϙVϙŘĺî ĖČϡ ϙϭ͐ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͕͑ϙbĺŽϙ͑͏͓͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͔ϙ"ÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͑͏͐ϱ͏͓͖ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ͐͒͏͗ϙŕŜĖϙЬϙ͘͏͒͏ϱċťϙa"ϙϼ͓͓͐͒ϱċťϙ«"ϽϙèÍīèŪīÍťôîϙ ċŘĺıϙFϙŜŪŘŽôƅ ͑͏ϙŪČϙ͑͏͐͘ϙиϙ͕ϟ͐ϙ(a®ϙϼ͗ϟ͔ϙX®>Ͻ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͓͗͘ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϙϼŘôīÍťĖŽôϙťĺϙŕŘĺèôîŪŘôϽϡ ͗͏ϟ͓еϙЬϙ͖͒͗͘ϱċťϙa" aÍƄϙ"ĺČīôČϙϼŘôīÍťĖŽôϙťĺϙŕŘĺèôîŪŘôϽϡ ͓ϟ͓еϯ͐͏͏ϱċťϙЬϙ͗͐͘͏ϱċťϙa" aĖĲϙI"ϙϼŘôīÍťĖŽôϙťĺϙŕŘĺèôîŪŘôϽϡ ͒ϟ͖͔͑ЋϙĖĲϙ͓ϱΫЋϙϼ͒ϟ͗͐͒ϱĖĲϽϙЌ³bЍϙĲĖŕŕīôϙŕŘĺƱīôϙÍťϙ ͓͗͐͒ϱċťϙa" ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙFϱ͏͗ϙĖŜϙÍϙèēŘÍîôŘϙīŪƯϙiϙЭϙiϙıŪīťĖīÍťôŘÍīϟϙϙēôϙſôīīϙſÍŜϙŜĖîôťŘÍèħôîϙſĖťēϙbÍæĺŘŜϙ͒ϙ"ϙĖĲϙ͑͏͏͐ϟϙϙ IĲϙ͑͏͏͔ϙĖťϙſÍŜϙèĺĲŽôŘťôîϙċŘĺıϙĤôťϙŕŪıŕϙťĺϙ(ϙæƅϙbÍæĺŘŜϙ͓(ϙťēôĲϙæÍèħϙťĺϙĤôťϙŕŪıŕϙĖĲϙ͑͏͏͖ϟϙϙēôϙſôīīϙēÍŜϙ æôôĲϙĺĲϙŕŘĺîŪèťĖĺĲϙŪĲťĖīϙVŪīƅϙ͑͏͓͑ϙſēôĲϙĖťϙſÍŜϙĲĺťôîϙťēôϙĤôťϙŕŪıŕЍŜϙôƯĖèĖôĲèƅϙēÍîϙċÍīīôĲϙĺƯϙŜĖČĲĖƱèÍĲťīƅϟϙϙ >ŪŘťēôŘϙîĖÍČĲĺŜťĖèŜϙŘôŽôÍīôîϙôƄťôĲŜĖŽôϙèĺŘŘĺŜĖĺĲϙĖĲϙťēôϙŕŘĺîŪèťĖĺĲϙťŪæĖĲČϙÍĲîϙÍťϙīôÍŜťϙĺĲôϙŕĺťôĲťĖÍīϙēĺīôϙĖĲϙ ťēôϙťŪæĖĲČϟ bĺťôŜϙôČÍŘîĖĲČϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -ÍŜŜĖĲČϙaIϱƄIϙĺĲϙ͔͑ϙVŪĲôϙ͑͏͓͑ϙϼ͓͓͑͘ϙŕŜĖϽ -(ƄťôĲŜĖŽôϙīĺſϙŜĖîôϙŕĖťťĖĲČϯèĺŘŘĺŜĖĺĲϙċŘĺıϙѹ͑͏͏͏ϱċťϙťĺϙѹ͗͒͏͏ϱċťϙa" -ĺťôĲťĖÍīϙēĺīôϙĖĲϙťŪæĖĲČϙīĺèÍťôîϙſĖťēϙēĺŘŜôťÍĖīϙÍťϙ͔͖͏͏ϱċťϙ[a" -īĖîĖĲČϙīôôŽôϙÍťϙ͓͗͒͑ϱċťϙa"ϙĖŜϙèŪŘŘôĲťīƅϙĺŕôĲ ->ϙŕŪıŕôîϙĖĲťĺϙſôīīϙĺĲϙ͓͐ϙVŪīƅϙ͑͏͓͑ ->[ϙôŜťĖıÍťôîϙÍťϙѷ͔͐͑͏ϱċťϙa"ϙĺĲϙ͔͑ϙVŪĲôϙ͑͏͓͑ϙ® ®ôīīϡ aϙFϱ͏͗ "ϡ ͑͏͐ϱ͏͓͖ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͗ϱ͏͑ϱ͏͏ "Íťôϡ ͓͐ϙbĺŽϙ͑͏͓͑ iæĤôèťĖŽôϡ ®ĖťēϙťēĖŜϙŕŕīĖèÍťĖĺĲϙċĺŘϙŪĲîŘƅϙŕŕŘĺŽÍīϙſôϙÍŘôϙŘôŗŪôŜťĖĲČϙťĺϙŕŪťϙϙϭ͐ϙĺĲϙťēĖŜϙſôīīϙĖĲϙĺŘîôŘϙťĺϙŕôŘċĺŘıϙÍϙ ťŪæĖĲČϙŜſÍŕϙÍĲîϙæŘĖĲČϙťēôϙſôīīϙæÍèħϙĺĲϙťĺϙŕŘĺîŪèťĖĺĲϟ ēĖŜϙŕŘĺèôîŪŘôϙîôťÍĖīŜϙťēôϙæôīĺſϙĺŪťīĖĲôϙĺċϙťēôϙŜèĺŕôϙĺċϙťēĖŜϙŕŘĺĤôèťϡ -ŪťϙťæČ -ŪīīϙôƄĖŜťĖĲČϙťæČϙÍĲîϙŘŪĲϙĲôſϙèĺıŕīôťĖĺĲϙťæČϙſϯϙŜťÍèħϙŕħŘ -ôťϙV -iϙ ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ ͐Ͻ (ϱ[ĖĲô ÍϽ ŪťϙťæČϙıĖîϱĤťϙĖĲϙ͐ ŜťϙċŪīīϙĤťϙÍæĺŽôϙ͖ЋϙƄϙ͓ϱΫЋϙÍħôŘϙϱ͒ϙŕŘĺîŪèťĖĺĲϙŕħŘϙſϯϙèēôıϙèŪťťôŘϙĺŘϙ bi(ϡϙϙæČϙÍīīƅϙċŘĺıϙbÍæĺŘŜϙ͓(ϙîÍťôîϙ͐͘ϙbĺŽϙ͑͏͏͖ϙīĖŜťŜϙťēĖŜϙÍŜϙVťϙϭ͐ϙſĖťēϙťĺŕϙÍťϙ͖͗͒͒ϱċťϙa"ϙ ÍĲîϙæťıϙÍťϙ͖͗͒͘ϱċťϙa" ͑Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ īôÍŘϙÍĲîϙīôŽôīϙŕÍîϙÍŘôÍϙĖĲϙċŘĺĲťϙĺċϙſôīīϟϙϙŕĺťϙŘĖČϙıÍťŜϠϙ͔͏͏ϙææīϙťÍĲħϠϙÍĲîϙèĺĲťÍĖĲıôĲťϟ æϽ "ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜϟϙϙīôÍŘϙÍĲîϙīôŽôīϙÍŘôÍϙÍŘĺŪĲîϙſôīīϟ èϽ aIϙèŘÍĲôϟϙϙôťϙ«ϟϙϙb"ϙťŘôôϙÍĲîϙbϙi(ϟϙϙbϙi(ϙēĺŪŜôϟϙϙŕĺťϙıŪîϙæĺÍťϟ bi(ϡϙϙ«ϙŘĺƱīôϙĖŜϙ͓ЋϙI®ϙFϙŜťƅīô ®iϙŘĺèôîŪŘôϙϼŪĲîŘĖôîϙ®ĺŘħϽϡ aIϙϯϙôŜťϙi(ϡ ͐Ͻ aIϙFĖīèĺŘŕϙϠϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲťϠϙÍĲîϙīĖĲôŜϙťĺϙ͔͏͏ϙææīϙŘôťŪŘĲϙťÍĲħ ͑Ͻ ēôèħϙċĺŘϙŕŘôŜŜŪŘôϙÍĲîϙĖċϙ͏ϙŕŜĖϠϙŜôťϙϙŕīŪČϟϙϙIċϙĲôôîôîϠϙæīôôîϙÍĲƅϙŘôŜĖîŪÍīϙŕŘôŜŜŪŘôϙĺƯϙĺċϙťæČϙ ÍĲîϙèŜČϟϙϙIċϙŘôŗЍîϠϙèĖŘèŪīÍťôϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙťēŘĺŪČēϙĺŕôĲϙŜīĖîĖĲČϙŜīôôŽôϙŕŘĖĺŘϙťĺϙŜôťťĖĲČϙ ϟ bi(ϡϙϙ>īŪĖîϙīôŽôīϙôŜťĖıÍťôîϙťĺϙæôϙѷ͔͐͑͏ϱċťϙa" ͒Ͻ ôŜťϙi(ϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϠϙÍĲĲŪīÍŘϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϙϼēĺīîϙôÍèēϙ ŘÍıϯŽÍīŽôϙťôŜťϙċĺŘϙ͔ϱıĖĲϽϟϙϙôèĺŘîϙÍèèŪıŪīÍťĺŘϙŕŘôϱèēÍŘČôϙŕŘôŜŜŪŘôŜϙÍĲîϙèēÍŘťϙťôŜťŜϟ ÍϽ ôŘċĺŘıϙťôŜťŜϙÍŜϙŕôŘϙϙ͐ϙi(ϙôŜťϙŘĺèôîŪŘô æϽ bĺťĖċƅϙi@ϙ͓͑ϙēĺŪŘŜϙĖĲϙÍîŽÍĲèôϙĺċϙi(ϙťôŜťĖĲČ èϽ ĺĲƱŘıϙťôŜťϙŕŘôŜŜŪŘôϙŕôŘϙťēôϙŪĲîŘƅϙĺĲîĖťĖĺĲŜϙĺċϙŕŕŘĺŽÍī îϽ ôŜťϙ«ŜϙĺĲϙ͓ϱΫЋϙϼôƄĖŜťĖĲČϙèĺıŕīôťĖĺĲϙťæČϙÍĲîϙĲôſϙèĺıŕīôťĖĺĲϙťæČϽϙťôŜťϙĤťŜ ôϽ ŪæıĖťϙťĺϙi@ϙèĺıŕīôťôîϙ͐͏ϱ͓͓͑ϙċĺŘıϙſĖťēĖĲϙ͔ϙîÍƅŜϙĺċϙi(ϙťôŜť ͓Ͻ ŪīīϙϙīŪČϟϙϙīôôîϙÍĲƅϙŕŘôŜŜŪŘôϙĺƯϙĺċϙťĺϙťæČϙťĺϙťēôϙŘôťŪŘĲŜϙťÍĲħϟϙϙIċϙŘôŗЍîϠϙèĖŘèŪīÍťôϙ͗ϟ͔ϙīæϯČÍīϙ ŜĺŪŘèôϙſťŘϙťēŘĺŪČēϙĺŕôĲϙŜīĖîĖĲČϙŜīôôŽôϟϙϙŪīīϙ«ϟϙϙ[ŪæŘĖèÍťôϙĖċϙŕŘôŜŜŪŘôϙĖŜϙôƄŕôèťôîϟ ŪīīϙŘĺîϙæČϡ ͔Ͻ aϙīÍĲîĖĲČϙĤťϙĺŘϙŜŕôÍŘϙÍĲîϙŪĲīÍĲîϙťæČϙēČŘ ®ôīīϡ aϙFϱ͏͗ "ϡ ͑͏͐ϱ͏͓͖ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͗ϱ͏͑ϱ͏͏ "Íťôϡ ͓͐ϙbĺŽϙ͑͏͓͑ ͕Ͻ ôèĺŽôŘϙťæČϙēČŘ bi(ϡϙϙæČϙFČŘϙŕŪŕϙēÍŜϙæīÍŜťϙŘĖĲČŜϙĖĲŜťÍīīôîϙÍĲîϙĖŜϙ͓ϱΫЋϙIIϙϼŪŕϽϙƄϙIϱaϙϼîĺſĲϽϙϙƄϙ ͖Ͻ aĺĲĖťĺŘϙſôīīϙċĺŘϙƲĺſ ͗Ͻ iiFϙīÍƅĖĲČϙîĺſĲϙôƄĖŜťĖĲČϙ͓ϱΫЋϙ͐͑ϟ͕ϭϠϙ[͗͏ϙIϱaĺîϙťæČϟϙϙ®ÍŜēϙÍĲîϙťŘÍŜēϙÍīīϙĤťŜϙÍĲîϙĤôſôīŘƅϟ bi(ϡϙϙæČϙſÍŜϙīÍĲîôîϙſϯϙ͖͔Xϙīæċϙ®ϙÍĲîϙ͒͑Xϙīæċϙi®ϟϙϙ@[aϙÍĲîϙīĖîĖĲČϙīôôŽôϙēÍŽôϙIIϙƄϙ IϱaĺîϙƄϱĺŽôŘϙŕŪŕŜϟ ͘Ͻ aIϙīĖèħīĖĲô ÍϽ IFϙſϯϙıôıĺŘƅϙèÍīĖŕôŘϙĺċϙťēôϙ͖ЋϙèŜČϙťĺϙťēôϙťæČϙŜťŪæϙϼѷ͔͗͒͗ϱċťϙa"ϽϙŕôŘϙiϙ͗͏͗ϙŘôŗŪĖŘôıôĲť ͐͏Ͻ "aiϙīĖèħīĖĲô bi(ϡϙϙĺĲťÍèťϙXϙċĺŘϙŜŕĺĺīôŘϙŘĖČϙŪŕϙťĺϙîôŕīĺƅϙèÍŕϙīĖĲôϙĺĲϙŘôèĺıŕīôťôϙŘŪĲ ŪĲϙťÍèħϙħŘϙôϱĺıŕīôťĖĺĲϡ ͐͐Ͻ aϙÍĲîϙIFϙſϯϙĲôſϙVϙèĺıŕīôťĖĺĲϡ bi(ϡϙϙĺĲťÍèťϙi(ϙċĺŘϙƱīīϙŜèēôîŪīôϙſēĖīôϙIFϙťĺϙÍŽĺĖîϙŕŘôıÍťŪŘôϙŜôťϙĺċϙťēôϙŕħŘ ÍϽ ĺĺŘϙĺƅϙiŽôŘŜēĺťϙϼſϯϙťÍťťīôϙťÍīôϙŜēôÍŘϙŕĖĲŜϽϙŜôťŪŕϙċĺŘϙѷ͔ϱċťϙŜſÍīīĺſϙĺĲϙ͓ϱΫЋϙťæČ æϽ ͐ϙĤťϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ³ϱ èϽ ͓ϱΫЋϙŪŘŜťϙ"ĖŜèϙŪæϙϼ͓XϙŕŜĖϽϠϙ͐͑ϟ͕ϭϙV>(ϙôÍŘϙϙƄϙϙſϯϙ͐͏ϱċťϙƄϱĺŽôŘϙƄϱĺŽôŘϙŕŪŕŜϙťĺϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ [͗͏ϙ³ϱ îϽ ͓ϱΫЋϙЌ³bЍϙĲĖŕŕīôϙŕŘĺƱīôϙϼ͒ϟ͗͐͒ГϙĺŘôϙϯϙ͒ϟ͖͔͑Гϙbĺϱ@ĺϽϠϙ͐͑ϟ͕ϭϠϙ[͗͏ϙϠϙϙƄϙϙſϯϙ͐͏ϱċťϙēÍĲîīĖĲČϙ ŕŪŕŜ ôϽ ͐ϙĤťϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ³ϱϙ ċϽ ͖ЋϙƄϙ͓ϱΫЋϙFƅîϙôťϠϙēôÍŘϱťĺϱôīôÍŜôϙŕħŘϙĺŘϙôŘıϙſϯϙ͐͏ϱċťϙēÍĲîīĖĲČϙŕŪŕŜϙϼƄϱĺŽôŘϙÍŜϙ ĲôèôŜŜÍŘƅϽ ČϽ ͐ϙĤťϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ³ϱ ēϽ ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ((ϙ͗ŘîϙXϙ@ÍŪČôϙÍŘŘĖôŘϙÍĲîϙ¾ôĲĖťēϙ@ÍŪČôϙſϯϙ͕ϱċťϙƄϱĺŽôŘϙēÍĲîīĖĲČϙŕŪŕŜ ĖϽ ͓ϱΫЋϙŜīĖîĖĲČϙŜīôôŽôϠϙ͘ŘϙϙĺŘϙ³ϙϼ͒ϟ͗͐͒Ћϙ³ϱŕŘĺƱīôϠϙ"iϽϠϙϙƄϙϙſϯϙ͐͏ϱċťϙēÍĲîīĖĲČϙŕŪŕŜ bi(ϡϙϙŪĲϙŜīĖîĖĲČϙŜīôôŽôϙĖĲϙèīĺŜôîϙŕĺŜĖťĖĺĲ ĤϽ ³³³ϙĤťŜϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ³ϱϙťĺϙŜŪŘċÍèô ħϽ ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ³ϱϙƄϱĺŽôŘϙťĺϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙIIϙťĺϙıÍħôϙŪŕϙťĺϙťæČϙēČŘ ͐͑Ͻ IFϙÍƯĖƄĖĲČϙèŘĺŜŜϱèĺŪŕīĖĲČϙèīÍıŕŜϙťĺϙŜôèŪŘôϙèÍŕϙīĖĲôϙϼôŽôŘƅϙĤťϙĺĲϙ͐Ŝťϙ͔͐ϙĤťŜϙťēôĲϙôŽôŘƅϙĺťēôŘϙĤťϙťĺϙ ŜŪŘċÍèôϽϙÍĲîϙťôŜťĖĲČϙèĺĲťĖĲŪĖťƅϙôŽôŘƅϙѷ͑͏͏͏ϱċť ͐͒Ͻ [ĺèÍťôϙťæČϙŜťŪæϙϼѷ͔͗͒͗ϱċťϙa"ϽϙſϯϙĺĺŘϙĺƅϙiŽôŘŜēĺť ͓͐Ͻ ċťôŘϙīĺèÍťĖĲČϙťæČϙŜťŪæϙŕĖèħϙæÍèħϙŪŕϙťĺϙƱČŪŘôϙŜŪŘċÍèôϙŜŕÍèôϙĺŪťϙÍĲîϙaϙťæČϙēČŘ ͔͐Ͻ IFϙťĺϙĤŪŜťϙÍæĺŽôϙťæČϙŜťŪæϙÍĲîϙèīĺŜôϙÍĲĲŪīÍŘϙĺĲϙ͓ϱΫЋϙťæČϙÍĲîϙèÍŕϙīĖĲôϟϙϙŪīīēôÍîϙѷ͐͏ϙææīŜϙIϱ æŘĖĲôϙîĺſĲϙIϟϙϙ"ĖŜŕīÍèôϙſϯϙѷ͔͐͏ϙææīŜϙŜĺŪŘèôϙſÍťôŘϙťĺϙŕīÍèôϙIϱæŘĖĲôϙÍŘĺŪĲîϙĲôſϙŜťÍèħϙŕħŘϟ bi(ϡϙϙIĲŜŪŘôϙĖĲĤôèťĖĺĲϙŕŘôŜŜŪŘôϙŜťÍƅŜϙſôīīϙæôīĺſϙ͔XϙŕŜĖϙˏϙŘôŗŪĖŘôîϙťĺϙŜēôÍŘϙŪŘŜťϙ"ĖŜèϙŪæ ͕͐Ͻ iĲèôϙIϱæŘĖĲôϙĖŜϙĖĲϙŕīÍèôϠϙŜīÍèħĺƯϙťĺϙŜſÍīīĺſϙťæČϙŜťŪæϙÍĲîϙīÍĲîϙťæČϙēČŘϟϙϙI["ϙÍĲîϙīÍƅϙîĺſĲϙ īÍĲîĖĲČϙĤťϟϙϙbĺťôϙϙÍĲîϙiϙſťŜϙĺĲϙťÍīīƅϟ ͖͐Ͻ ŘôŜŜŪŘĖĲČϙŪŕϙÍČÍĖĲŜťϙťēôϙŪŘŜťϙ"ĖŜèϙŪæϠϙŜôťϙŕħŘϙŕôŘϙŽôĲîĺŘϙæôŜťϙŕŘÍèťĖèôŜϟ ͐͗Ͻ iĲèôϙŕħŘϙŜôťťĖĲČϙŜôŗŪôĲèôϙĖŜϙèĺıŕīôťôϠϙŕôŘċĺŘıϙaIϱIϙťĺϙ͕͔͒͏ϙŕŜĖϙϼ͒͏ϙıĖĲŜϽϟϙϙēÍŘťϙÍĲîϙ ŘôèĺŘîϙaIϟ ®ôīīϡ aϙFϱ͏͗ "ϡ ͑͏͐ϱ͏͓͖ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͗ϱ͏͑ϱ͏͏ "Íťôϡ ͓͐ϙbĺŽϙ͑͏͓͑ ͐͘Ͻ ôťϙ«ϙÍĲîϙŕŘôŕϙťĺϙıĺŽôϙϙĺƯϙťēôϙſôīī ĺŜťϱĖČϙŘĺèôîŪŘôϡ ͐Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ "ϙıŪîϙæĺÍťϟϙϙ"ϙi(ϙēĺŪŜôϟϙϙaĺŽôϙťĺϙĲôƄťϙīĺèÍťĖĺĲϟ æϽ ϙèŘÍĲôϟϙϙb"ϙi(ϙÍĲîϙbϙťŘôôϟ èϽ ôŜťϙťæČϙēČŘϙŽĺĖîϙťĺϙ͔͏͏ϙŕŜĖϙ[ĺſϙϯϙ͔͏͏͏ϙŕŜĖϙFĖČēϟϙϙŪīīϙ«ϟ îϽ "ϙèŘÍĲôϟϙϙaĺŽôϙ͔͏͏ϙææīϙŘôťŪŘĲŜϙťÍĲħϙÍĲîϙŘĖČϙıÍťŜϙťĺϙĲôƄťϙſôīīϙīĺèÍťĖĺĲϟ ôϽ ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜ ͑Ͻ īĖèħīĖĲô ÍϽ ŘôŜŜŪŘôϙŪŕϙĺĲϙťæČϙťĺϙŜēôÍŘϙŪŘŜťϙ"ĖŜèϙŪæϙϼ͓XϙŕŜĖϽ æϽ ēĖċťϙĺŕôĲϙ͓ϱΫЋϙŜīĖîĖĲČϙŜīôôŽôϙϼ͒ϟ͗͐͒Ћϙ³ϱŕŘĺƱīôϠϙ"iϽ èϽ ôťϙ³³³ϙVϙÍŜŜôıæīƅϙŜīĖîĖĲČϙŜīôôŽô îϽ ŪŘĲϙſôīīϙĺŽôŘϙťĺϙŘĺîŪèťĖĺĲϙċĺŘϙi ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè ͒Ͻ i(ϙèēôıÍťĖè * Approved for forward circulating jet pump only per CO808. - mgr _____________________________________________________________________________________ Revised By: TDF 11/7/2024 SCHEMATIC Milne Point Unit Well: MPU H-08B Last Completed: 11/22/07 PTD: 201-047 16 21 15 20 TD =11,445’(MD) / TD =4,197’(TVD) Orig. KB Elev.: 65.68’/ Orig. GL Elev.: 36.0’ RKB – Hanger: 23.38’ (Nabors 4ES) 4-1/2” 7” 19 “OB” Lateral PBTD =11,445’(MD) / TD = 4,197’(TVD) “OA” Lateral 14 20” 13 17 2 4 3 5 7 Min ID = 3.725” ID Min ID = 3.813” ID 1 18 6 8 9 12 10 11 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / Welded N/A Surface 110' N/A 7” Surface 26 / L-80 / BTC-MOD 6.151” Surface 8,588’ 0.0382 4-1/2" Liner 12.6 / L-80 / IBT-MOD 3.833” 8,421’ 9,085’ 0.0152 2-7/8” Liner “A” 6.4 / L-80 / ST-L 2.347” 9,030’ 11,485’ 0.0057 2-7/8” Liner “B” 6.4 / L-80 / ST-L 2.347” 9,078’ 11,430’ 0.0057 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / IBT-M 3.958” Surface 8,425’ 0.0152 JEWELRY DETAIL No Depth Item 1 22’ 4-1/2” Carbide Blast Rings below tubing hanger (2.63’ Long) 2 2,478’STA #1: KMG-2, 4-1/2” x 1” BK latch –DGLV set 11/22/2007 3 8,324’ 4-1/2” XD Sliding Sleeve (3.813” Packing Bore Min ID; 10A JP set 6/25/2024 4 8,389’ 7” x 4-1/2” Baker S-3 Packer (3.870” ID) 5 8,413’ 4-1/2” XN Profile (3.813” Packing Bore;3.725” No-Go Min ID) 6 8,421’ Baker ZXP Liner Top Packer w/ 6’ Tieback (5.25” ID) 7 8,424’ Wireline Entry Guide (Btm at 8,425’) 8 8,436’ Baker HMC 7” x 5” Liner Hanger (4.375” ID) 9 8,953’ Baker Indicator Sub (Min ID 3.844”) 10 8,961’ Baker HMCV Cementing Valve (3.875” ID) 11 8,971’ Baker Indicator Sub (Min ID 3.844”) 12 8,979’ Baker CTC 20’ PZP Payzone ECP (3.937” ID) 13 9,030’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 14 9,062’ Flow-thru TIW Whipstock 15 11,450’ 2-3/8” Packoff Bushing (Min ID 1.29”) 16 11,485’ 2-3/8” Btm Baker Guide Shoe 17 9,078’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 18 9,082’ Baker Whipstock 19 9,082’ Cement Plug (Squeezed 26 bbl of 15.8 ppg Class G cement below whipstock) 20 11,396’ 2-3/8” Packoff Bushing (Min ID 1.29”) 21 11,430’ 2-3/8” Btm Baker Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arctic Set in 24” Hole 7”Cmt w/ 2,047 sx PF E, 263 sx Class “G”, 191 sx PF ‘C’ in 8-1/2” Hole 4-1/2” Cmt w/ 46 sx Class “G” in 6” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Wellbore Angle = 78 to 80 deg f/ 3,600 to 7,450’ MD Hole Angle thru pers = Horizontal WELLHEAD Tree 4-1/16” CIW – 5M Cameron Wellhead 11” x 4-1/2” TC-II Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22808-02-00 Sidetracked & Liners Run by Nabors 3S – 4/20/2001 Convert from Jet Pump to ESP by Nabors 4ES – 8/30/2005 ESP Replacement by Nabors 3S – 5/14/2006 Convert from ESP to Jet Pump by Nabors 4ES – 11/22/2007 LATERAL WINDOW DETAIL Top of “OB” Window @ 9,060’ MD; Bottom @ 9,067’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 9,085’MD; Bottom @ 9,097’ MD; Angle @ top of window is 75 deg _____________________________________________________________________________________ Revised By: TDF 11/15/2024 PROPOSED Milne Point Unit Well: MPU H-08B Last Completed: 11/22/07 PTD: 201-047 20 22 19 21 TD =11,445’(MD) / TD =4,197’(TVD) Orig. KB Elev.: 65.68’/ Orig. GL Elev.: 36.0’ RKB – Hanger: 23.38’ (Nabors 4ES) 4-1/2” 7” 24 “OB” Lateral PBTD =11,445’(MD) / TD = 4,197’(TVD) “OA” Lateral 17 20” 16 20 7 1 8 10 Min ID = 3.725” ID 23 9 11 12 15 13 14 Tubing Cut @ ±8,363’ 4 3 6 2 5 Min ID = 3.725” ID CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / Welded N/A Surface 110' N/A 7” Surface 26 / L-80 / BTC-MOD 6.151” Surface 8,588’ 0.0382 4-1/2" Liner 12.6 / L-80 / IBT-MOD 3.833” 8,421’ 9,085’ 0.0152 2-7/8” Liner “A” 6.4 / L-80 / ST-L 2.347” 9,030’ 11,485’ 0.0057 2-7/8” Liner “B” 6.4 / L-80 / ST-L 2.347” 9,078’ 11,430’ 0.0057 TUBING DETAIL 341/2” Tubing 9.2 / L-80 / TXP-BTC 3.958” Surface ±8,368’ 0.0152 4-1/2” Tubing 12.6 / L-80 / IBT-M 3.958”±8,363’8,425’ 0.0152 JEWELRY DETAIL No Depth Item 1 ±X,XXX’ 4-1/2” XD Sliding Sleeve 2 ±X,XXX’ 4-1/2” Carrier & Zenith Guage w/ I-wire to Surface 3 ±X,XXX’ 7” x 4-1/2” Packer 4 ±X,XXX’ 4-1/2” XN Profile (3.725” No-Go Min ID) 5 ±X,XXX’ Burst Disk 6 ±X,XXX’ Overshot – Btm @ ±8,368’ 7 8,389’ 7” x 4-1/2” S-3 Permanent Hydraulic Set Packer (3.856” ID) 8 8,413’ 4-1/2” XN Profile (3.813” Packing Bore;3.725” No-Go Min ID) 9 8,421’ Baker ZXP Liner Top Packer w/ 6’ Tieback (5.25” ID) 10 8,424’ Wireline Entry Guide -Btm at 8,425’ 11 8,436’ Baker HMC 7” x 5” Liner Hanger (4.375” ID) 12 8,953’ Baker Indicator Sub (Min ID 3.844”) 13 8,961’ Baker HMCV Cementing Valve (3.875” ID) 14 8,971’ Baker Indicator Sub (Min ID 3.844”) 15 8,979’ Baker CTC 20’ PZP Payzone ECP (3.937” ID) 16 9,030’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 17 9,062’ Flow-thru TIW Whipstock 18 11,450’ 2-3/8” Packoff Bushing (Min ID 1.29”) 19 11,485’ 2-3/8” Btm Baker Guide Shoe 20 9,078’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 21 9,082’ Baker Whipstock 22 9,082’ Cement Plug (Squeezed 26 bbl of 15.8 ppg Class G cement below whipstock) 23 11,396’ 2-3/8” Packoff Bushing (Min ID 1.29”) 24 11,430’ 2-3/8” Btm Baker Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arctic Set in 24” Hole 7”Cmt w/ 2,047 sx PF E, 263 sx Class “G”, 191 sx PF ‘C’ in 8-1/2” Hole 4-1/2” Cmt w/ 46 sx Class “G” in 6” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Wellbore Angle = 78 to 80 deg f/ 3,600 to 7,450’ MD Hole Angle thru pers = Horizontal WELLHEAD Tree 4-1/16” CIW – 5M Cameron Wellhead 11” x 4-1/2” TC-II Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22808-02-00 Sidetracked & Liners Run by Nabors 3S – 4/20/2001 Convert from Jet Pump to ESP by Nabors 4ES – 8/30/2005 ESP Replacement by Nabors 3S – 5/14/2006 Convert from ESP to Jet Pump by Nabors 4ES – 11/22/2007 LATERAL WINDOW DETAIL Top of “OB” Window @ 9,060’ MD; Bottom @ 9,067’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 9,085’MD; Bottom @ 9,097’ MD; Angle @ top of window is 75 deg Updated 10/24/2024 Milne Point ASR Rig 1 BOPE 2024 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR 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: 7/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240730 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 5/22/2024 YELLOW JACKET PERF BCU 14B 50133205390200 222057 6/11/2024 YELLOW JACKET GPT-PLUG-PERF BCU 19RD 50133205790100 219188 7/17/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/1/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 7/11/2024 AK E-LINE PressureTemp CLU 16 50133207200000 224021 5/16/2024 YELLOW JACKET SCBL CLU 16 50133207200000 224021 5/31/2024 YELLOW JACKET SCBL END 2-14 50029216390000 186149 5/9/2024 YELLOW JACKET PLUG KU 33-08 50133207180000 224008 5/9/2024 YELLOW JACKET GPT-PLUG-PERF MPU H-08B 5.00292E+13 201047 7/14/2024 READ CaliperSurvey MPU I-40 50029236890000 220071 7/6/2024 AK E-LINE TubingCut MPU R-101 50029237930000 224078 7/16/2024 YELLOW JACKET SCBL MPU S-17 50029231150000 202173 7/12/2024 AK E-LINE TubingCut MPU S-17 5.00292E+13 202173 7/18/2024 READ CaliperSurvey PBU NK-43 50029229980000 201001 6/11/2024 YELLOW JACKET PL PBU PTM P1-13 50029223720000 193074 7/4/2024 YELLOW JACKET PL Pearl 11 50133207120000 223032 7/10/2024 AK E-LINE Plug/Perf Please include current contact information if different from above. T39310 T39310T T39311T T39312T T39312 T39313 T39313 T39314 T39315 T39316 T39317 T39318 T39319 T39319 T39320 T39321 T39322 MPU H-08B 5.00292E+13 201047 7/14/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.30 13:09:33 -08'00' Image °reject Well History File Cover~i'--~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~.~1 "0 ~L'7 Well History File Identifier Organizing .,. ~. [] R~iSCAN Color items: E'] Grayscale items: Poor Quality Originals: [] Other: NOTES' DIGITAL DATA [] Diskettes, No. Other, No/Type BY: BEVERLY ROBIN VINCENT SHER~INDY OVERSIZED (Scannable) Maps: E-J Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds 5/// ~ Other DATE:/SI Project Proofing BY: BEVERLY ROBIN VINCENT SHERYI..~ WINDY Scanning Preparation ~ x 30 = /2i~ BY: BEVERLY ROBIN VINCENT SHERYL~INDY ,, Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: .... !!~.......!' PAGE COUNT MATCHES NUMBER iN SCANN"NG PREPARATION: )~L__. 'YES BY: BEVERt.~INCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE t, PAGE(S) DISCREPANCIES WERE FOUND: ................... YES ................... (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMA~8 ) I II II NO NO RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ts/ General Notes or Cornrnents about this file: 12/10l02Rev3NOTScanned,wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 S N D FEB 1 1 2012 Mr. Tom Maunder � � 1 � 7,c2, Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 �� Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH-02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH-15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: f~~;~'; +~.-;;~;; ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change out ESP ~ ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-047 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22808-02-00 ' 7. KB Elevation (ft): 65 68 ~ 9. Well Name and Number: . MPH-08B 8. Property Designation: 10. Field /Pool(s): ADL 380109 Milne Point Unit / Schrader Bluff ' 11. Present well condition summary Total depth: measured 11445 ~ feet true vertical 4197 feet Plugs (measured) N/A Effective depth: measured 11445 feet Junk (measured) N/A true vertical 4197 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' 1490 470 Surface 8557' 7" 8588' 3899' 7240 5410 Intermediate Production 649' 4-1/2" 8436' - 9085' 3793' - 4157' 8430 7500 Liner 2352' 2-7/8" 9078' - 11430' 4155' - 4195' 13450 13890 ~'~~~ ~~ ~ ~ ~ 207 Perforation Depth MD (ft): Slotted 9151' - 11395' Perforation Depth TVD (ft): 4169' - 4192' 4-1/2", 12.6# L-80 8425' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1 /2" Baker S-3 8389' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil' ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si nature Phone 564-4750 Date p~ -~~" Sondra Stewman, 564-4750 ~~aska Ds~ ~ G~~ ~i~r;~. ~` `. ~~ _- ~ " ~~ ~ ~~~7 Submit Ori mal Onl Form 10-404 Revised 04/2006 ~r:,''i ~ ~ ~~~ , ,~ ^ ~ / ~yl~~ g' y • • Tree: 4-1/16" - 5M Cameron Wellhead: 11" x 11" 5M FMC Gen 6, w/ 11" x 4 1/2" tubing hanger TC-II threads top and btm 4" CIW "H" style BPV Profile 20" 91.1 ppf, H-40 115' M P H X08 B Orig. KB Elev. = 64.9' (N 22E) Orig. GL Elev. = 36.0' RT To Tbg. Spool = 30.6(N 22E) SLB 4 1/2" x 1" KBG-2 2478` ID = 3.833" 4 1/2" 12.6 ppf L-80 IBT-M tbg. MINiD in tbg =.3.725" @ (cap = .0152 bpf) 8413` and "HES XN Nipple" 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) (capacity w/ 4 1/2 tbg = 0.0186 bpf) HES XD Sliding Sleeve " 8324' polish bore 3.81 KOP @ 300' Max hole angle = 78 to 80 deg ` . . f/ 3600' 7450' Baker S-3 packer 8389 to Hole angle thru' perfs =Horizontal 4 1/2" HES "XN" ni le ` pp 8413 3.813 polish bore & 3.725 No-go ID 4 1/2" WLEG 8424` Baker ZXP Liner top packer " ' 8421 ` w/6 tie back (5.25 ID) Baker 5" x 7" HMC liner hanger 8436` NB Lateral (4.375" ID) Milled 6-1/8" window at 8588'- Baker HMCV cement valve 61 ` asoo• (t2') Baker CTC 20' PZP ECP 8979' OA Lateral 4.5", 12.6# L-80 IBT Solid liner. H-08A P&A with cement below bottom whi pstock 3/15/01 H-086 (OA sand) TOL 9078' Baker whipstock top 9082' RA marker 9092' X Whipstock bottom 9096' X X X H-08B L1 (OB sand) x -~~-~ "Ld ~~ TOL 9030' X X X TIW whipstock 9062' X X ()( ;OA sand ; RA marker 9071' X Whipstock bottom 9075' TD 11,448' Shoe 11,430' X X Both laterals lined with 2 7/8", 6.6# tubin X X g, predrilled at 4 spf X X TD 11,510' Shoe 11,485' Note: It is not possible to reenter the OA lateral X X X X X X X OB sand X DATE I REV. BY 4/20/01 MDO 8/30105 MDO 05/14/06 MDO 11/22/07 JLP & LH COMMENTS 10-01-97 Drilled and Cased by Nabors 22~. 6/20/98 Frac and completion by Nabors 4-E1 12/19/99 P&A well sidetrack 4-ES t/19/0o Sidetrack completed for jet pump CTU Sidetrack Nabors 3S Jet Pump to ESP Conversion Nabors 4-es ESP RWO & Heat trace instalation 3S Conversion to JP -Nabors 4ES MILNE POINT UNIT WELL No: MPH-08B API : 50-029-22808-02 BP EXPLORATION (AK) • BP EXPLORATION' Page 1 of 5 Operations. Summary' Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/13/2007 06:00 - 08:00 2.00 RIGD P PRE PJSM. Rig down rig components, scope down & lay over derrick. 08:00 - 13:00 5.00 MOB P PRE PJSM. Move rig & rig components from MPF-25 to MPH-08. 13:00 - 15:00 2.00 RIGU P PRE Spotted and bermed rig. 15:00 - 18:00 3.00 RIGU P PRE Raised and scoped derrick. Leveled rig, RU mud and derrick lines. Accepted rig @ 18:00 hrs 11/13/2007. 18:00 - 20:00 2.00 WHSUR P DECOMP Held crew change and performed pre-tour checks. RU lines to tree and tiger tank. Took on 130 deg seawater. 20:00 - 21:00 1.00 WHSUR P DECOMP RU lubricator and tested to 500 psi. Pulled BPV and LD same. 21:00 - 21:30 0.50 KILL P DECOMP 'Tested lines to 3500 psi. 21:30 - 00:00 2.50 KILL P DECOMP Opened well to closed choke. Tubing pressure 80 psi, annulus pressure 80 psi. Opened choke, bled pressures to 0 psi. Displaced tubing volume (45 bbls) with heated 8.5 ppg seawater. Closed choke and attempted to bullhead; pump pressure increased to 2000 psi after 9 bbls injected. Shut down and bled tubing pressure through choke. Opened choke and continued circulating the long way through holes in tubing at 7178'; staged pump up to 5 bpm @ 1400 psi holding 330 psi back pressure. Circulated a total of 355 bbls, getting crude, diesel, and brine in returns. 11/14/2007 00:00 - 01:00 1.00 KILL P DECOMP Stopped pumping, well initially on vacuum. Closed choke and monitored well; 0 psi on tubing and casing. 01:00 - 02:30 1.50 DHB P DECOMP RU lubricator and tested to 500 psi. FMC set TWC. Tested TWC from above to 3500 psi for 10 minutes. Pumped into annulus, tested TWC from below to 850 psi. Charted both tests. 02:30 - 04:30 2.00 WHSUR P DECOMP RD and blew down lines. Bled pressure from tubing hanger void. ND tree. 04:30 - 11:30 7.00 BOPSU P DECOMP Installed spacer spool. NU BOPE. Problems associated with wellhead on previous RWO in may did not reoccur. Stabilized BOP stack with turnbuckles and continued on with nippling up. 11:30 - 18:00 6.50 BOPSU P DECOMP PIT BOPE to 250-psi LO / 3500-psi HI per BP/AOGCC requirements. Choke manifold valve #12 failed to test. Disassembled same and cleaned out frac proppant. Retested O.K, AOGCC -Lou Grimaldi waived State of Alaska right to witness BOPE testing. Repaired drive chain on drawworks, loaded pipe shed with 4-1/2" completion tubing, rabbited and strapped same. Also performed various rig maintenance activities while testing BOPE. Totco RigWatch system non-operational. Investigated trouble with RigWatch system with aid of Quadco technician via telephone. Unable to return to service. Quadco dispatching technician to slope to repair !, system. ', 18:00 - 20:30 2.50 WHSUR P DECOMP RU lubricator. Pulled and LD TWC. RD lubricator. 20:30 - 22:30 2.00 KILL P DECOMP Circulated seawater surface to surface with full returns. Well took 4 bbls to fill initially. Pumped 2 bpm @ 270 psi, 3 bpm @ 570 psi, 4 .bpm @ 970 psi, 5 bpm @ 1350 psi. Shut down and monitored after getting bottoms up, had 10 psi on tubing and annulus. Continued circulating a total of 265 bbls. Shut down and monitored; 0 psi on tubing and annulus. 22:30 - 00:00 1.50 PULL P DECOMP Held PJSM. PU landing joint and cross-over to 2-7/8" 8rd. Screwed into tubing hanger. BOLDS. Putted tubing hanger to floor with 48k Ib PU. Disconnected ESP cable and heat trace Printed: 12/4/2007 9:23:15 AM • • BP EXPLORATION Page 2'of 5 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 Rig Name: NABORS 4ES Rig Number: Date 11 /14/2007 11/15/2007 From - To ~ Hours ~ Task ~ Code ~ NPT Phase Description of Operations 22:30 - 00:00 ( 1.501 PULL I P 00:00 - 02:00 2.00 PULL P DECOMP from tubing hanger. LD landing joint and tubing hanger. DECOMP Pulled ESP cable and heat trace cable over double cable sheave and through elephant trunk to ESP cable spooler. Prepared and attached cable ends to spools in ESP cable spooler. DECOMP Continued POH, standing back 2-7/8" tubing. Spooled ESP cable and heat trace. Cut 45 flat guard bands per stand. Recovering heat trace flat guards and bands. Well remaining full after adding twice steel displacement plus about 1 bbl seawater per 10 stands. Recovered hardware heavily coated with crude. 15 stands pulled @ 05:30 hrs. Ordered 50-Bbls. diesel to flush tubing and cables to aid in removing crude oil. DECOMP Continued on POH w/ESP-Heat Trace completion. Recovered 3415' heat trace cable, 2-7/8" tubing and ESP cable @ 0930-hrs. Rigged down heat trace handling tools. Cleared and cleaned floor of heat trace flat guards and baskets. Spooled up end of heat trace cable to cable spooler. DECOMP MIRU LRS. PJSM to discuss diesel heating/pumping. Pumped 50-bbls. 120E diesel down tubing @ 1.5-bpm @ 600-psi taking returns to rig pits. S/D LRS. Closed annular preventer on tubing and ESP cable to divert returns through super choke. Circulated diesel out with heated SW from rig pits @ 5.0-bpm @ 900-psi while holding 300-psi backpressure on choke. Tubing and cable coming out much cleaner. DECOMP Continued POH w/ESP cable and tubing. Recovered 69 total Lasalle clamps, 6 protectorlisers and 3 Armstergaurds. Recovered 515 6' flat guards, 28 4' flat guards, 20 3' flat guards and 1726 carbon steel superbands. The ESP pump shaft rotation was locked and the ESP motor passed all integrity tests. DECOMP BO/LD and inspect ESP BHA. Tubing in good condition. No signs of scale or other foreign material deposition on ESP assembly or tubing. Pulled ESP cable over cable sheave. LD ESP assembly. Cleared rig floor. DECOMP Held crew change. Performed pre-tour checks. Continued LD ESP and motor assembly. Cleared and cleaned floor. DECOMP RU to run bit and scraper on 2-7/8" tubing from derrick. Loaded BHA into pipe shed. WAIT DECOMP MPU declared Phase III weather conditions @ 1630-hrs.. 17 rig related personnel on location. Cleared location. Performed general rig housekeeping, including painting rig floor, organizing rig floor equipment, maintaining rig vehicles, and updating operations procedures. WAIT DECOMP Continued clearing location, painting rig floor, organizing rig floor equipment, maintaining rig vehicles, performing general rig housekeeping, and updating rig operations procedures. Continued in Phase ill weather conditions. WAIT DECOMP WOW. Phase condition reduced to Phase II at 0730-hrs. by MPU Operations. DECOMP PJSM -BHA Handling. PUMU 7" casing scraper/4-3/4" bit BHA as follows: 4-3/4" bit, bit sub, 2-7/8" PAC pup jt., double pin sub, 7" scraper & XO. DECOMP R!H w/7" scraper/4-3/4" bit BHA, 2-7/8" tubing from derrick and 02:00 - 06:00 I 4.001 PULL ~ P 06:00 - 10:30 I 4.501 PULL P 10:30 - 13:30 ( 3.001 PULL I P 13:30 - 16:30 I 3.00 ~ PULL 16:30 - 18:00 I 1.50 ~ PULL I P 18:00 - 19:30 I 1.501 PULL I P 19:30 - 20:30 I 1.001 CLEAN I P 20:30 - 00:00 I 3.501 CLEAN I N 111/16/2007 100:00 - 06:00 I 6.001 CLEAN I N 06:00 - 07:30 I 1.50 ~ CLEAN I N 07:30 - 09:00 I 1.501 CLEAN I P 09:00 - 14:30 I 5.501 CLEAN I P Printed: 12/4/2007 9:23:15 AM • • BP EXPLORA710N Page 3 of 5 Operations Summary Report; Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 j Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task .Code NPT Phase Description of Operations 11/16/2007 09:00 - 14:30 5.50 CLEAN P DECOMP singles of 2-7/8" tubing from pipe shed. Target depth for 4-3/4" bit = 8433'. Noted an obstruction @ 7314'. Worked scraper through section and obstruction no longer there. Obtained PUW and SOW before tagging liner top. PUW = 45K; SOW = 22; Tagged liner top @8421'. Tagged bottom of liner tie-back receptacle @ 8431' w/bit. Reciprocated scraper from 8398' to 8418' four times. 14:30 - 18:00 3.50 CLEAN P DECOMP Make up headpin and circulating hose to tubing. Circulate long way @ 5.5-bpm @ 850-psi. Recovered small amount of very fine sediment and crude oil across shaker screen. Mixed and circulated 30-Bbl. Hi-Vis sweep long way @ 5.5-bpm @ 850-psi. Monitored well, 0 psi. 18:00 - 22:00 4.00 CLEAN P DECOMP Held crew change and PJSM. Performed pre-tour checks. TOH with BHA #1 (4-3/4" bit, 7" casing scraper). LD double, stood back 89 stands. Filled well with calculated pipe displacement plus 1 bbl seawater. 22:00 - 23:00 1.00 CLEAN P DECOMP Held PJSM with rig crew and tool operator. LD BHA #1 (bit and scraper). PUMU 7" RTTS. 23:00 - 00:00 1.00 CLEAN P DECOMP TIH with 7" RTTS on 2-7/8" tubin from derrick. Continued loading pipe shed with 4-1/2" tubing, tallying joints, cleaning and inspecting threads. 11/17/2007 00:00 - 02:30 2.50 CLEAN P DECOMP Continued TIH with 7" RTTS on 2-7/8" tubing from derrick. Continued preparing for 4-1/2" completion. 02:30 - 04:00 1.50 CLEAN P DECOMP PU wt 45k Ib. SO wt 20k Ib. Set RTTS Ccil 8397' with 10k Ib additional SO. Closed VBR and annular BOP. RU to pressure up annulus. Tested 7" casing to 3500 psi for 30 minutes. Bled pressure, opened VBR and annu ar. 04:00 - 04:45 0.75 CLEAN P DECOMP Made up head pin and circulating hose to tubing. Circulated seawater 5 bpm at 1200 psi. 04:45 - 06:00 1.25 CLEAN P DECOMP POOH LD 2-7/8 tbg 36 jts LD at 0600-hrs. Pre-tour HSE meeting with day crew 0530-0600 hrs. 06:00 - 13:45 7.75 CLEAN P DECOMP Crew change at 06:00-hrs. Check PVT alarms, grease drawworks and blocks, grease crown and derrick inspection. Cont. POOH LD 2-7/8 tbg 36 jts LD at 06:00-hrs. 189 jt. POH at 10:45-hrs. BO/LD 7" Halco RTTS packer. Packer returned to surface with all parts intact. Currently in Phase 1 weather conditions. 13:45 - 14:15 0.50 CLEAN P DECOMP Clear & clean rig floor.. 14:15 - 14:45 0.50 EVAL P DECOMP ND flow nipple. 14:45 - 15:30 0.75 EVAL P DECOMP NU shooting flange. 15:30 - 16:30 1.00 EVAL P DECOMP Weekly HSE meeting -All day crew. 16:30 - 18:15 1.75 EVAL N WAIT DECOMP SWS a-line enroute to wellpad from Deadhorse and are behind Nordic 1 rig move. 18:15 - 23:30 5.25 EVAL P DECOMP Held crew change and performed pre-tour checks. Cleared pad and spotted E-line equipment. Held PJSM. RU E-line service with full pressure control. MU USIT tool string. 23:30 - 00:00 0.50 EVAL P DECOMP RIH with USIT. 11/18/2007 00:00 - 00:30 0.50 EVAL P DECOMP Continued RiH with USIT. Could not work logging tools deeper than 3380'. Well bore inclination at 3380' is 77 deg. 00:30 - 06:00 5.50 EVAL P DECOMP Logged up with USIT from 3380' to surface. Made repeat passes across TOC and corco a interva s. Sent logging information to Schlumberger town and engineer who spoke to RWO engineer about results. No further action required with Printed: 12/4/2007 9:23:15 AM • • BP EXPLORATION Page4 of 5 .Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date I From - To I Hours ~ Task I Code I NPT 11 /18/2007 100:30 - 06:00 I 5.501 EVAL I P 06:00 - 07:30 I 1.501 EVAL I P 07:30 - 09:00 I 1.501 RU 09:00 - 09:30 I 0.501 RU 09:30 - 18:00 I 8.50 18:00 - 21:00 I 3.00 21:00 - 22:30 I 1.501 RU 22:30 - 00:00 I 1.50 11/19/2007 100:30 - 00:00 0.50 01:00 - 02:00 1.00 02:00 - 04:00 2.00 04:00 - 08:30 I 4.50 08:30 - 11:30 I 3.001 RU Spud Date:. 9/3/1997 Start: 11/13/2007 End: Rig Release: 11 /20/2007 Rig Number: Phase ~ Description of Operations DECOMP respect to casing integrity. Held weekly HSE meeting with night crew. Continued clearing location with front loader. Maintainance mud pump. Performed general rig housekeeping. DECOMP Rig down -move off SWS a-line unit. Reviewed "Rigging Down E-line and Tools" procedure with rig crew. RUNCMP ND shooting flange. NU flow nipple. RU floor with 4-1/2" tubing handling tools. Review completion running order with Baker Packers representative. Note: Well program completion running order modified per MPU H pad engineer to include 4-1/2" x 1" GLM w/OCK-2 shear valve set to shear at 3000-psi and located at -2500' MD. Tool Service expeditor NORM tested and cleared all pulled completion jewelry, tubing, tubing hanger, tree and tubing adapter spool. RUNCMP PJSM -Reviewed "RIH w/Completion Tubing" procedure with crew and described requirements for running in hole with IBT-M tubing. Sanded well pad area around rig to ensure all walking/working surfaces safe. RUNCMP PUMU WLEG/XN nipple assy., 7" x 4-1/2" Baker packer assy., and HES sliding sleeve assy. and RIH on 4-1/2" 12.6#, L-80 IBT-M tubing. Made up all connections to mark and using Best-O-Life 2000 joint compound. Inspecting teflon seal rings in each connection joint by joint prior to makeup. LD and replaced jt. #73 due to bad threads. RIH w/105 jts. at 1620-hrs. RUNCMP Held crew change. Performed pre-tour checks. Held PJSM. Continued RIH with 4-112", 12.6#, L-80 IBT-M tubing. Made up connections to mark and used Best-O-Life 2000 joint compound, inspected teflon seal rings in each connection joint by joint prior to makeup. RUNCMP Established parameters: PU 75k Ib, SO 32k Ib. PU jt #204. Tagged 2.5' in on jt #204 @ 8427'. SO 12k Ib, carefully rotated tubing. Circulated the long way 3 bpm @ 260 psi. Saw no indication of circulating through tie-back receptacle. RUNCMP LD jts 204, 203, 202. Spaced out 2' above tag depth @ 8425'. MU 7.80' spaceout pup, jt #202, tubing hanger, XO and landing joint with TIW valve. Based on measured depth of tubing, RUNCMP Landed tubing hanger and RILDS. DPRB RUNCMP Closed blind rams. Confirmed ability to circulate the long way 3 bpm at 260 psi. DPRB RUNCMP ND flow nipple. NU shooting flange. DPRB RUNCMP Held PJSM. RU slickline with riser extension, pump in sub, BOP, and lubricator. Tested lubricator and flange connections to 500 psi. DPRB RUNCMP RIH with ball and rod on slickline. Ball and rod fell to -4450'. Began pumping with rig 1 bpm, and increasing rate in 1/2 bpm increments to 3 bpm. Wireline RIH speed '40 ft./min. Line speed decreased to 10-20 ft.lmin. when tool string depth reached 6800'. Tag RHC seat at 8420' WLM. Pull ball & rod up 200'. RUNCMP MIRU CH2 vac trucks and reverse cirulate 200-Bbls. 140E seawater and 125 bbls. 140E corrosion inhibited seawater @ Pdnted: 12!4/2007 9:23:15 AM 7 i ~ • • BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Dater 9/311997 Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 Rig Name: NABORS 4ES Rig Number: Date ~ From - To ~ Hours Task Code ~ NPT Phase Description of Operations ;1111912007 108:30 - 11:30 I 3.00 11:30 - 13:30 I 2.00 13:30 - 16:15 I 2.75 16:15 - 0.00 RUNCMP 3.0-bpm @ 190-psi taking returns to rig pits. No indication of slickline tool string moving uphole while reverse circulating @ 3.0-bpm. WAIT RUNCMP Clean rig while working plan forward with Anchorage engineering staff. RUNCMP PJSM and review newly developed plan forward. DPRB RUNCMP slickline RIH and set ball & rod on seat. Pressure tubing up to 3500-psi to set packer. held 3500-psi on tubing for 30-charted i.minutes. Bled tubing pressure to 1500-psi. Pressure up IA to 16:15 - 17:00 I 0.75 RU 17:00 - 18:00 1.00 RU 18:00 - 20:00 f 2.001 RU 20:00 - 20:30 I 0.501 RU 20:30 - 22:30 I 2.00 N 22:30 - 23:30 I 1.001 WHSUR I P 23:30 - 00:00 0.50 BOPSU P 11120!2007 00:00 - 01:30 1.50 BOPSU P 01:30 - 04:00 2.50 WHSUR P 04:00 - 05:00 I 1.001 WHSUR 1 P 05:00 - 06:00 I 1.001 WHSUR I P 06:00 - 07:30 1 1.501 WHSUR I P 07:30 - 08:30 I 1.001 WHSUR 1 P 08:30 - 09:00 I 0.501 WHSUR I P 3500-psi and held pressure for 3U charted minutes. ttlea tubing to 0-psi and sheared DCK-2 shear valve. Circulated both ways through shear valve at 3.0-bpm at 1100-psi. DPRB RUNCMP slickline POH wlball & rod. DPRB RUNCMP Held PJSM with all personnel; discussed handling of high-explosive E-fire equipment. RU wireline retrievable plug setting head arming and firing equipment. DPRB RUNCMP Held crew change and performed pre-tour checks. PU and RIH with wireline retrievable plug (WRP). Established depth, detonated E-fire head, set WRP @ 2650'. DPRB RUNCMP RU to pump down tubing. Tested WRP to 1000 psi for 10 minutes. DPRB RUNCMP Held PJSM with all personnel on retrieving and handling spent firing head. POH with slickline and firing head. RDMO slickline service. RD pert flange. Installed flow nipple. RUNCMP FMC representative installed TWC. RU to pressure test. Tested TWC from above and below to 1000 psi for 10 minutes each. Charted tests. Released pressure, blew down lines. RUNCMP Drained BOPE stack. RUNCMP Held PJSM. ND BOPE. Disconnected choke and kill lines. ND spool extension. ND DSA. Held fire drill in well cellar. RUNCMP NU lock down flange and adapter spool. Tested to 5000 psi for 30 minutes. Moved in LRS in preparation for rig up. RUNCMP NU tree and tested to 5000 psi. MPH-Pad operator verified tree orientation. RUNCMP PU lubricator and makeup to tree cap. PR lubricator to 500-psi against closed swab valve. MPU Well Support pull TWC. Set lubricator back. RUNCMP RU LRS and P/T lines to 3500-psi. Pump 85-Bbls. diesel through swab valve on tree and through shear valve at 2.0-bpm to freeze protect tubing and IA taking returns to rig pits. RUNCMP PU lubricator and makeup to tree cap. P/T lubricator to 500-psi against closed swab valve. MPU Well Support set BPV. LD lubricator. RDMO LRS. RUNCMP Secure tree and cellar. Release rig @ 0900-hrs., Printed: 12/4/2007 9:23:15 AM STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 1 9 2006 REPORT OF SUNDRY WELL OPE~TdQNS;ons. Commission . RECEIVED 1. Operations Performed: AbandonD Alter CasingD Change Approved ProgramD 2. Operator Name: 3. Address: Repair WellO Pull TubingD Operation ShutdownD Pluç Perforations 0 Perforate New PoOIO Perforate 0 Stimulate 0 WaiverD orage otherID Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 01- 7 6. API Number 50-029-22808-02-00 BP Exploration (Alaska), Inc. 4. Current Well Class: Development 00 ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO ServiceD 9. Well Name and Number: MPH-08B 10. Field/Pool(s): Milne Point Unit I Schrader Bluff Sands 65.68 8. Property Designation: ADL·380109 11. Present Well Condition Summary: Total Depth measured 11445 feet true vertical 4197.0 feet Plugs (measured) None Effective Depth measured 11445 feet Junk (measured) None true vertical 4197.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20" 91.5# H-40 22 110 22.0 110.0 1490 470 SURFACE 8557 7" 26# L-80 21 · 85S8 21.0 - 3899.0 7240 5410 PRODUCTION 649 4-1/2" 12.6# L-80 8436 · 9085 3793.0 - 4157.0 8430 7500 LINER 2352 2-7/S" 6.5# L-SO 9078 · 11430 4155.0 - 4195.0 10570 11160 Perforation depth: SCANNE~,J '. ':t\ (J' ç:)' Measured depth: Slotted Liner 9151-11395 True vertical depth: Slotted Liner 4169-4192 Tubing ( size, grade, and measured depth): 2-7/8" 6.5# L-80 Bottom of Jet Pump No Packer in well. No SSSV in well. @ 19 @ 7294 7245 Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 722 SI Representative Dailv Averaoe Production or Iniection Data Gas-Met Water-Bbl Casin Pressure 127 94 o 0 Tubin Pressure 292 280 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: DilŒI GasD DevelopmentŒ ServiceD WAG 0 GINJO WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: NIA Printed Name Title Petroleum Engineer Signature Form 1 0-404 Revis~d 4/2004 0 R \ Date 10117106 . . MPH-08B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/16/2006 T/I=OIO Freeze Protected Tbg and IA. Pumped 65 bbls crude down IA and 15 bb/s crude down TBG. Final WHP=O/O 06/04/2006 Well Support T echs rigged up and pressure tested the flowlines to 1150 psi. They then removed the back pressure valve. The leak test was GOOD. 07106/2006 T/I/O= 300/250/na (Injectivity test) Pump 125 bbls dead crude down IA. IA pressured up to 2500 psi (tbg 2450 psi). Bled pressure down flowline to common line pressure. FWHP's=300/350/na 07107/2006 T/1/0=300/250/na Freeze protect tbg, flowline and test line. Pump 15 bbls diesel down tbg, 5 bbls diesel down flowline and test line. FWHP's=1500/1500 09/09/2006 PMD: ***WELL S/I ON ARRIVAL***. RIH W/2.5 GR PULL AA-SLlP STOP @ 2571' SLM, PULL AD-2 UPPER PACK -OFF @ 2572' SLM, PULL AD-2 LOWER PACK-OFF @ 2583' SLM RAN 2.3 CENT 2.5 JU TO PULL A-2 SLIP STOP @ 2585' SLM. PULL DV @ 3552 SLM AND DPSOV @ 118' SLM SET DV @ 118' SLM.. SET BPV. NOTE LEFT BTM POCKET @ 3552' SLM EMPTY.. ***LEFT WELL 51 *** FLUIDS PUMPED BBLS 25 203 228 I~~~~ TOTAL Page 1 . . ,J MPU H-08B Orig. KB Elev. = 64.9' (N 22E) Orig. GL Elev. = 36.0' RT To Tbg. Spool = 30.6 (N 22E) ~ 2-9/16" - 5M FMC Wellhead' 11" x 2-9/16" SM FMC Gen 6, w 2-7/8" FMC Tbg. Hgr., 8rd.EUE Top & 8tm, 2.5" CIW BPV Profile 20" 91.1 ppf, H-40 115' KOP @ 300' Max. hole angle = 78 to 80 deg. f/ 3600' to 7450' Hole angle thru' perfs = Horizontal 2-7/8" 6.5 ppf, L-80 8rd eue tbg. (drift id = 2.347" cap = ,00592 bpf) 7" 26 ppf, L-80, BTC mod production csg, ( drift ID = 6.276", cap. = 0.0383 bpf) Note: Centrilift Motor was re-rated KME-1 130 HP 2145V 135A Milled 6-1/8" window at 8588'- 8600' (12') 4,5", 12,6# L-80 IBT Solid liner. H-08B (OA sand) TOL Baker whipstock top RA marker Whipstock bottom 9078' 9082' 9092' 9096' Cameo 2-7/8" x l' KBMM [JEJ Heat trace installed @ 3415' md. Camco 2-7/8"x l' KBMM 7,083' XN Nipple (2,313 packing 10) I 7,224' (2.205 no-go 10) Centrilift GPMTAR 1/1 145/GC 538P11 7,24S' Tandem I Gas Separator GRSFTX AR H6 I 7,262' Tandem Seal Assembly I I GSB3DBUT AB/HSN PFSA 7,266' GS83DBLTAB I HSN¡C;SA Centrilift KMH Motor I 7,280' I 152 HP, 2325 v 140 amp Pumpmate Sensor wI tins I 7.294' I Baker ZXP Liner top packer I 8421' I w/6' tie back (5.2S" ID) Baker S"xT' HMC liner I 8436' I hanger (4,37S" ID) Baker HMCV cement valve 8961' Baker CTC 20' PZP ECP 8979' H-08A P&A with cement b"ow bo.om whl",,,k ~ 3/15/01 H-08B L 1 (OB sand) TOL 9030' TIWwhipstock 9062' ~ RA marker 9071' Whipstock bottom 9075' Both laterals lined with 2 7/8", 6.6# tubing, predrilled at 4 spt Note: It is not possible to reenter the OA lateral DATE REV, BY COMMENTS 10-01-97 Drilled and Cased by Nabors 22 6/20/9E Frac and com letion b Nabors 4-E 12/19/9f P&A well sidetrack 4-ES 1/19/0C Sidetrack completed for jet pump CTU Sidetrack Nabors 3S Jet Pump to ESP Conversion Nabors 4-es ESP RWO & Heat trace instalation 3S 4/20/01 8/30/0S 05/14/06 MDO MDO MOO MILNE POINT UNIT WELL No : H-08B L-01 API : 50-029-22808-02 BP EXPLORATION (AK) (J//lfloG RECEIVED STATE OF ALASKA I ALA& OIL AND GAS CONSERVATION COM SSION JUL 142006 REPORT OF SUNDRY WELL OPERA TION§aska 0'1 & G . . J as Cons. ComrmsslOn . 1. Operations Performed: "e o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 201-041 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22808-02-00 7. KB Elevation (ft): 65.68 9. Well Name and Number: MPH-08B 8. Property Designation: 10. Field I Pool(s): ADL 380109 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 11445 feet true vertical 4197 feet Plugs (measured) N/A Effective depth: measured 11445 feet Junk (measured) N/A true vertical 4197 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' 1490 470 Surface 8557' 7" 8588' 3899' 7240 5410 Intermediate Production 649' 4-1/2" 8436' - 9085' 3793' - 4157' 8430 7500 Liner 2352' 2-718" 9078' - 11430' 4155' - 4195' 13450 13890 >",. i ""'\j:;{y - Perforation Depth MD (ft): Slotted 9151' - 11395' 1.;7"" ... Perforation Depth TVD (ft): 4169' - 4192' 2-7/8",6.5# L-80 7300' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram fgOil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 ~~ Sond,. Stewman Title Technical Assistant .' a;¡,~ Prepared By Name/Number: \" Signature,,, v'-<-JA..... (,J', CC;r'YV';;'~' Phone 564-4750 Date DI-J -e·! -Olí\Sondra Stewman, 564-4750 .. Form 10-404 Revised 04/2006 0 R 1 G , r~ A L ","",">:~~: <";"',._-' ..-.i/~·-Z····RSDMS BFL JUl I 4 Z006 (."..,- Submit Original Only ~ 2-9/16" - SM FMC Wellhead' 11" x 2-9/16" SM FMC Gen 6, w 2-7/8" FMC Tbg. Hgr" 8rd.EUE Top & Btm, 2.S" CIW BPV Profile 20" 91.1 ppf, H-40 115' KOP @ 300' Max. hole angle = 78 to 80 deg. f/ 3600' to 7450' Hole angle thru' perfs = Horizontal 2-7/8" 6.5 ppf, L-BO Brd eue tbg. (drift id = 2,347" cap = .00592 bpf) 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap, = 0.0383 bpf ) Note: Centrilift Motor was re-rated KME-1 130 HP 2145V /35A Milled 6-1/8" window at 8588'- 8600' (12') 4.5", 12,6# L-80 1ST Solid liner. H-08B (OA sand) TOL Baker whipstock top RA marker Whipstock bottom 9078' 9082' 9092' 9096' e Orig. KB Elev. = 64.9' (N 22E) Orig. GL Elev. = 36.0' RT To Tbg. Spool = 30.6 (N 22E) Cameo 2-7/8" x l' KBMM DE] Heat trace installed @ 3415' md. Cameo 2-7/8"x l' KBMM 7,OB3' XN Nipple (2.313 packing ID) I 7,224' (2.205 no-go ID) CentrUift GPMT AR 1/1 145/GC 538P11 7,245' Tandem I Gas Separator GRSFTX AR H6 7,262' Tandem Seal Assembly I GSG30BUT AGJHSN PFSJ\ 7,266' GSB3DBl TAB! HSNFSA Centrilift KMH Motor I 7,280' 152 HP, 2325 v /40 amp Pumpmate Sensor wi fins I 7,294' Baker ZXP Liner top packer I 8421' w/6' tie back (5.25" 10) Baker 5"x7" HMC liner I 8436' hanger (4.375" 10) Baker HMCV cement valve 8961' Baker CTC 20' PZP ECP 8979' H-08A P&A with cement below bottom whipstock I 3115101 ... H-OSB L 1 (OB sand) TOL 9030' TIWwhipstock 9062' ~ RA marker 9071' Whipstock bottom 9075' Both laterals lined with 2 7/8", 6.6# tubing, predrilled at 4 spf Note: It is not possible to reenter the OA lateral DATE REV. BY COMMENTS 10-01-97 Drilled and Cased bv Nabors 22 6/20/9£ Frae and eom letion b Nabors 4-E 12/19191 P&A well sidetrack 4-ES 1/19/0< Sidetrack completed for jet pump CTU Sidetrack Nabors 3S Jet Pump to ESP Conversion Nabors 4-es ESP RWO & Heat trace instalation 3S 4/20 I 01 8/30/0S OS/14/06 MDO MDO MDO MILNE POINT UNIT WELL No : H-08B L-01 API : 50-o29-22S0S-02 BP EXPLORATION (AK) e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRilLING I NABORS 3S Start: 5/7/2006 Rig Release: Rig Number: N3S Spud Date: 9/3/1997 End: 5/8/2006 00:00 - 03:00 3.00 MOB P PRE RDMO GPB DS15-06 03:00 - 18:00 15.00 MOB P PRE Move rig from GPB DS15-06 to MPH-08B. 18:00 - 00:00 6.00 MOB P PRE MIRU on MPH-08B. 5/9/2006 00:00 - 06:30 6.50 MOB P PRE MIRU on MPH-08B, 0030-hrs. - 24-hr. notification to AOGCC of impending BOPE test. ATP meeting held at 0530-hrs. with MPU management and day rig crew and tool pusher. 06:30 - 11 :00 4.50 MOB P PRE RIU Vac Trucks and take on 1200 F seawater to Pits. H/U hardline to Tiger Tank and test with air. Check all circulating lines. Actuate SSV with Porta-Power pump, install Fusible Cap, bleed off actuator pressure. P/U Lubricator and pull BPV. Casing and Tubing pressures = O-psi. Wait on Mist Extractor for Tiger Tank. Install Mist Extractor. Hold PJSM for circulating out diesel freeze protect. Rig accept @ 0700 hrs. 11 :00 - 13:00 2.00 KILL P DECOMP Line up valves to Reverse Circulate Tubing. Take all returns to Tiger Tank. Mud Pump developed a pounding sound. Troubleshoot to ensure pump not being starved. Check individual cylinders and find chunks of rubber under valve plates. Clean out Mud Pump Fluid End. 13:00 - 16:00 3.00 KILL P DECOMP Reverse circulate, 3.5-BPM, 300-psi Annulus, 20-psi Tubing for 75-Bbls. Realign valves and circulate long way 3.5-BPM, 500 to 650-psi Tubing, 300 down to 10-psi Annulus for 355-Bbls until returns cleaned up. S/I and Tubing and Casing at O-psi. No fluid losses to formation. 16:00 - 18:30 2.50 WHSUR P DECOMP Install TWC and N/D Tree. 18:30 - 00:00 5.50 BOPSU P DECOMP N/U BOPE 5/10/2006 00:00 - 03:00 3.00 BOPSU P DECOMP N/U BOPE 03:00 - 06:00 3.00 BOPSU N DECOMP The Wellhead rotates and sways back and forth once the BOP Stack is set on it. FMC and Pad Op notified. FMC says that swaying should not be possible due to an existing load shoulder. FMC to come inspect swaying. 06:00 - 08:00 2.00 BOPSU N DECOMP The ground surface inside and surrounding the Cellar appears to have subsided 3 to 4 inches, allowing the 20" conductor slip bowl to drop away from the fluted landing ring of the 7" Casing. Nabors 3S Tool Pusher said they had not encountered the same problem when they worked over the well in August 2005. The 7" Casing to Casing Head seal will only hold 800-psi, but the leak is to the inside because fluid was used to fill the void during the pressure test and none of it escaped to the outside of the Casing Head Seal Lock Ring. Discussed with engineering and will use normal turnbuckle restraints to centralize the 7" Casing and BOP Stack in order to continue with the RWO. 08:00 - 09:30 1.50 BOPSU DECOMP Finish N/U BOPE and stabilizing BOP Stack. 09:30 - 12:30 3.00 BOPSU DECOMP Test BOPE 250-psi low and 3500-psi high. The Hydril bag won't seal, so decide to complete all tests, with exception of the Hydril. When Driller released the pressure on the Hydril bag, he inadvertently actuated the blind shear rams which cut the test joint. 12:30 - 13:30 HMAN DECOMP Open Hydril, open Blind Rams doors and inspect shear faces and find them in good shape. Lasso the 2-7/8" test joint stump and POH. Close doors. 13:30 - 15:30 2.00 BOPSU DECOMP Complete remaining BOPE tests, except the Hydril test. 15:30 - 00:00 8,50 BOPSU RREP DECOMP Change out Hydril bag and seals. Printed: 5/22/2006 11 :55:55 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/7/2006 Rig Release: Rig Number: N3S Spud Date: 9/3/1997 End: Finish BOPE Test to 250 psi Low 13500 psi High, Pre-job safety meeting. RIU Sheave and Elephant Trunk. PUMU lubricator. Pull TWC, SITP = 0, SICP=O. UD lubricator. PUMU landing jt. Screw into tubing hanger. BOLDS, Unland tubing hanger. Hanger pulled free @ 44,000 Ibs. Pull and UD landing jt. and tubing hanger. FMC transported tubing hanger to their shop for redress. 07:30 - 16:30 9.00 PULL P DECOMP POOH 2 7/8 tbg wI ESP pump. SIB dbls in derrick. SLM 16:30 - 18:00 1.50 PULL P DECOMP Pull ESP pump and tail out cable. 18:00 - 20:00 2.00 PULL P DECOMP UD pump and motor, clear and clean rig floor. 20:00 - 20:30 0.50 PULL P DECOMP Service crown and blocks, straighten wrap on dead man anchor 20:30 - 00:00 3.50 PULL X WAIT DECOMP Clean rig, wait on 2 7/8 pac pipe. 5/12/2006 00:00 - 01 :00 1,00 CLEAN P CLEAN Load and strap 2 7/8 pac in pipe shed, Remove 21 jts. 2 7/8 EUE from shed, install wear bushing. 01 :00 - 12:00 11.00 CLEAN P CLEAN P/U and RIH 21 jts.2 7/8 PAC, followed by 49 jts. 27/8 EUE tubing from pipe shed, and 101 stands of 2-7/8" EUE. Drift tubularson skate. Tagged Fill @ 8522'. 12:00 - 18:00 6.00 CLEAN P CLEAN RIH wI single jt. 3.5" DP while Circulating @ 5 BPM. Reverse Circulate @ 5 BPM bottoms up plus 5 Bbls. 18:00 - 23:00 5.00 CLEAN P CLEAN Cont. RIH wI work string on 3.5" DP, washing down & reverse circulating drill string volume on each connection. Can not RIH with out washing down. 23:00 - 00:00 1.00 CLEAN P CLEAN Taking weight wI pump on @ 8970'. Wash t/ 8975 in 1-2' increments. Reverse circulate bottoms up @ 167 GPM 720 PSI 5/13/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Cont. RIH fl 8975' t/9001' washing down in 2-4' increments, picking up & working through. Max set down weight 1-2K, before P/U. 01 :00 - 02:00 1.00 CLEAN P CLEAN Pump 25 BBL Hi Vis sweep & reverse CBU surface to surface @ 9001' 02:00 - 02:45 0.75 CLEAN P CLEAN Cont. to wash f/ 9001' to 9004' taking weight and making no headway. 02:45 - 03:00 0.25 CLEAN P CLEAN Reverse tubing volume 03:00 - 05:00 2,00 CLEAN P CLEAN Cont. attempts to wash from 9004' setting down no more than 2-3 K. No headway. 05:00 - 06:00 1.00 CLEAN P CLEAN Pump 25 BBL Hi-Vis sweep reverse circulate surface to surface. 06:00 - 09:00 3.00 CLEAN P CLEAN POOH to 8400' MD, above 4,5" Liner, and perform injectivity test. 0.15 BPM @ 1500 psi. 09:00 - 14:00 5.00 CLEAN P CLEAN RIH and Tag up once more. Tagged @ 9009' MD. Wash down to 9027' and tag top of Liner. Reverse Circulate Duo-Vis Pill surface to surface. Found metal shavings in returns. 14:00 - 17:00 3,00 CLEAN P CLEAN POOH to 8400' MD and perform injectivity test. 2.5 BPM @ 1000 psi. Reverse Circulate Duo-Vis Pill surface to surface, At 1000 PSI pressure dropped off to 0 PSI. Monitor well & check surface equipment. Well on vacuum. Losses @ - 15 BBUHR 17:00 - 22:00 5.00 CLEAN P CLEAN POOH SIB 101 stds. 2 7/8 EUE tbg. Losses @ -22 BBLS I HR 22:00 - 00:00 2.00 CLEAN P CLEAN PJSM- POOH & UD 49 Jts. 2718 EUE Tbg. 5/14/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN PJSM, Change out handling equipment & UD 21 Jts. 2 7/8 PAC 01 :30 - 03:30 2.00 RIGU P RUNCMP Clear floor & rig up to run ESP 03:30 - 06:00 2.50 RUNCO RUNCMP PJSM, P/U & M/U ESP & motor assy. Printed: 5/22/2006 11 :55:55 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/7/2006 Rig Release: Rig Number: N3S Spud Date: 9/3/1997 End: RIH wI new ESP Completion on 2-7/8" Tubing from Derrick. Heat trace line picked up @ 3415' From surface. Check conductivity of electric cable every 2000'. 18:00 - 00:00 RUNCMP Cont. RIH wI ESP completion assy, on 2 7/8 EUE Tbg. wI dual cables, testing conductivity every 2000' Ran in to -6133' 5/15/2006 00:00 - 05:30 5.50 RUNCMP Cont. RIH WI ESP completion assy. F/6133' WI dual cables testing conductivity every 2000' 05:30 - 06:00 0.50 RUNCMP MU Tubing hanger Prep cables for splice. Ran 69 LaSalle Clamps, 5 Protectolizers, 3 Flat Guards. 06:00 - 11 :00 5.00 RUNCMP Space out ESP Cable and Heat Trace to Hanger and make electrical connection to the Penetrator. 11:00 -13:00 2.00 RUNCMP Land tubing hanger, P/U Wt. 46K S/O Wt. 26K. RILDS. Set TWC & test same 13:00 - 17:00 4.00 RUNCMP N/D BOPE. 17:00 - 00:00 7.00 RUNCMP N/U lockdown flange, tubing head adapter and tree. PIT tubing head adapter and tree to 5000 psi. Good test. Centriflift run final checks. P/U lubricator. Pull TWC. Set BPV. UD Lubricator. Wait on Veco to locate BPV. Clean pits, Remove valves & flanges from well head. Prep for move. 5/16/2006 00:00 - 01 :00 1.00 RIGD P RUNCMP Cont. Prep for rig move, while wait on Veco for BPV. 01 :00 - 01 :30 0.50 RIGD P RUNCMP Set BPV, Secure well. 01 :30 - 06:00 4.50 RIGD P RUNCMP Cont. RID, cleaning pits, jack down pits & pipe shed, blow down steam, disconnect electrical lines. Printed: 5/22/2006 11 :55:55 AM e e r~' '" ' "'" '''...... .,':.. ':' . ...... . , "i;¡{\~ _""'" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Mìcrofilm _ Marker. doc " STATE OF ALASKA ". R.EO!IV!D ALASKA .l AND GAS CONSERVATION CO. ,~ISSION C 0 2005 REPORT OF SUNDRY WELL OPERATIONSJ T 1 Alaska Ou & Gas Cons. Commission chan~nJth'J1Jf8 to ESP 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate III Other III Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well III Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 65.68 '8. Property Designation: ADL 380109 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 11445 4197 11445 4197 Casing Structural Conductor Surface Intermediate Production Liner Length 781 85571 649' 23521 Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: III Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 201-047 6. API Number: 50-029-22808-02-00 99519-6612 9. Well Name and Number: MPH-08B 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 110' 1101 1490 470 7" 85881 3899' 7240 5410 4-1/2" 84361 - 90851 37931 - 41571 8430 7500 2-7/8" 9078' - 11430' 41551 - 41951 13450 13890 Slotted 9151' - 113951 41691 - 4192' ',~ANNE[; NO\} [; 8 2005 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 73461 N/A Treatment description including volumes used and final pressure: RBDMS 8Ft 0 CT 1 1 20D5 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run III Daily Report of Well Operations III Well Schematic Diagram Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure Tubinq Pressure 15. Well Class after proposed work: o Exploratory III Development 0 Service 16. Well Status after proposed work: III Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Si Form 10-404 Revised 04/2004 Title Technical Assistant Phone ,&ß& \:50 n R·,'"~ ' I, _.~ ¡- J^ L \... . ,! '. t ~j'! M .....{\ _ _ r-: Prepared By Name/Number. Date C>1. -Ol-cD Sondra Stewman, 564-4750 Submit Original Only ) .Iœ.e.; 2-9/16" - 5M FMC Wellhead: 11" x 2-9/16" 5M FMC Gen 6, W 2-7/8" FMC Tbg. Hgr., 8rd.EUE Top & Btm, 2.5" CIW BPV Profile MPU 20" 91.1 ppf, H-40 I~ 115' KOP @ 300' Max. hole angle = 78 to 80 deg. fl 3600' to 7450' Hole angle thru' perfs = Horizontal 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) 7" 26 ppf, L-80, BTC mod production csg. ( drift 10 = 6.276", cap. = 0.0383 bpf ) Milled 6-1/8" window at 8588'- ~ 8600' (12') 1 4.5", 12.6# L-80 1ST Solid liner. H-088 (OA sand) - TOL Baker whipstock top RA marker Whipstock bottom 9078' 9082' 9092' 9096' .. ) H -Dad {or~'. KB Elev.: 64.~' (N 22E) ..., 1.et:16. GL Elev. - 36.0 RT To Tbg. Spool = 30.6 (N 22E) Ii Cameo 2-7/8"x l' KBMM I 170' I Cameo 2-7/8"x l' KBMM 7,094' XN Nipple (2.813 packing 10) I 7,235' (2.75 no-go ID) Centrilift GPMTAR 1/1 100/GC 1150 ESP, 7,256' 16 GCNPSH Tandem Gas Separator GRSFTX AR H6 I 7,309' I Tandem Seal Assembly I I GSB~~Df.\lrr At~/H~::'N PFSAJFSA 7,314' GSß3DBL TAB I HSNFSA Centrilift KMH Motor I 7,328' I 13:, HP, 2205 vI :,7 amp Pumpmate Sensor wI fins L 7,344' I .' Baker ZXP Liner top packer I 8421' I w/6' tie back (5.25" ID) - Baker 5"x7" HMC liner I 8436' I "'- - hanger (4.375" ID) r Baker HMCV cement valve 8961' Baker CTC 20' PZP ECP 8979' H-08A P&A with cement below bottom whipstock 3/15/01 , x.~ ~ X ) ~ TD 11 448' Shoe 11,430' XX ' Both laterals lined with 2 7/8", 6.6# tubing, predrilled at 4 spf X XX X TD 11,510' Shoe 11,485' X X X X ^ .-.; ,... ...... ...... ,... ^ ql v X X X X 08 sand X . . ., .. ., . . . . H-088 L 1 (08 sand) TOL 9030' TIW whipstock 9062' RA marker 9071 ' Whipstock bottom 9075' Note: It is not possible to reenter the OA lateral DATE COMMENTS REV. BY 10-01-97 Drilled and Cased by Nabors 2:< 6/20/9f Frac and completion by Nabors 4·E 12/19/9~ P&A well sidetrack 4-ES 1/19/0( Sidetrack completed for jet pump CTU Sidetrack Nabors 3S Jet Pump to ESP Conversion Nabors 4-es 4/20101 8/30/05 MDO MDO MILNE POINT UNIT WELL No : H-088\L-01 API: 50-029-2280å-02-00 A?". 5o~-~9n1(- U?~ BP EXPLORATION (AK) ) ') BPEXRl..O~h\TtON Qiperat!iê>l1s. .SL.Ín1l11ary....Repørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/25/2005 Rig Release: 8/31/2005 Rig Number: *4ES Spud Date: 9/3/1997 End: 8/31/2005 Date From ..To Ho u rs Task Code NPT Phase Descri ptionofOperations 8/25/2005 12:00 - 22:00 10.00 RIGU P DECOMP Move rig from MPC-43 to MPH-08B. 5 mile move. Spot rig over well, ACCEPT RIG @ 2200 hrs. 22:00 - 00:00 2.00 RIGU P DECOMP MIRU. Hook up kill lines and rig up Tiger tank. Fill rig pits with 460 bbls. 2% KCL water. Prep to kill well. 8/26/2005 00:00 - 02:00 2.00 RIGU P DECOMP PIT kill lines to 3500 psi and return line to Tiger tank to 120 psi. 02:00 - 04:30 2.50 KILL P DECOMP Notify Milne Point front desk of gas venting on H pad. SITP = 40 psi, SICP = 180 psi. Open well & Bleed off well to Tiger tank. Fill hole. Break conventional circulation down 4.5" tubing at 4 bpm at 220 psi. Take returns from annulus to Tiger tank. Pumped 350 bbls. 2% KCL to displace tubing and casing and kill well. 04:30 - 06:00 0.00 PULL P DECOMP Install TWC. Attempt to test, No good. P/?U lubricator & pull TWC. Install new TWC & test to 1000 psi, Ok. 06:00 - 08:00 2.00 WHSUR P DECOMP Bleed off tubing void. N/D tree & adapter flange. 08:00 - 11 :30 3.50 BOPSUP P DECOMP N/U DSA & test spool. N/U BOPE. 11 :30 - 12:30 1.00 BOPSUP. P DECOMP R/U test equip. Set test plug. 12:30 - 16:30 4.00 BOPSUR P DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Bop test witnessing waived by Jeff Jones w/ AOGCC. All tests good, no failures. RID test equip. 16:30 - 18:00 1.50 WHSUR P DECOMP P/U lubricator & pull TWC. LId lubricator. Monitor well. Well dead. 18:00 - 19:00 1.00 PULL P DECOMP M/U landing jt into hanger. P/U & pull hanger to floor. Pulled 1 OOK# to 150K# to try to work tubing free at jet cut. LID landing jt. 19:00 - 22:00 3.00 FISH P DECOMP P/U double grapple spear w/one jt. 3 1/2" DP. Engage tubing hanger. Clear rig floor of all personnel. Work tubing pulling 160k# to 21 OK# in 10K# increments from 80K# pickup weight. No-go. Land tubing hanger. LID DP and spear. 22:00 - 23:00 1.00 PULL P DECOMP N/D flow nipple. N/U shooting nipple. 23:00 - 00:00 1.00 PULL P DECOMP Prep rig for E-line ops. Wait on SWS e-line. 8/27/2005 00:00 - 03:30 3.50 PULL C DECOMP PJSM with rig crew and SWS e-line crew. MIRU SWS e-line eqpt. Kinked e-line. Cut and rehead e-line. 03:30 - 09:00 5.50 PULL C DECOMP P/U wireline packoff and pump-in sub. RIH wI tool string and string shot to +/-8398. Pumped tools in well @ 3.0 bpm @ 200 psi. Could not get below +1- 3100'. Made several attempts. 09:00 - 11 :00 2.00 PULL C DECOMP POOH & LID string shot. Mix & pump 40 bbl E-P Mud Lube pill. Spot to 4000'. 11 :00 - 14:00 3.00 PULL C DECOMP Hold PJSM prior to P/U chemical cutter. M/U & arm chemical cutter. RIH. Had to pump down. Pumped .5 to 3.0 BPM to get tool to go. At 3 BPM pressure was 800 psi. Correlate & tie-in to cutting depth. Fire cutter @ 8396.5'. Good indication of firing. POOH & LID cutter. 14:00 - 16:30 2.50 PULL C DECOMP RID & set aside logging equip. M/u 4 1/2" Double spear, RIH & engauge into tubing. Pull & work pipe to 190K. Tubing not coming free. 16:30 - 18:00 1.50 PULL DECOMP Call town & review operation. Mix 50 bbl E-P Mud Lube pill. N/D shooting flange. N/U flow nipple. 18:00 - 20:00 2.00 PULL C DECOMP Reverse circulate 50 bbl. pill of water and EP mud lube down annulus. Work pipe from 25K# to 170k#. Pipe came free. P/U wt. 65K#. Finish rigging down SWS e-line eqpt. 20:00 - 00:00 4.00 PULL P DECOMP Rig up floor. LID tubing hanger. POH & LID 41/2" production tubing. Printed: 9/12/2005 10:04:24 AM ') ) BP<EXPL0RA TION Operªtiøns$urnmary...·Report PaÇJe 2Öf 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/25/2005 Rig Release: 8/31/2005 Rig Number: *4ES Spud Date: 9/3/1997 End: 8/31/2005 Date From- To Hours Task Code NPT Phase Descri ptionofOperations 8/28/2005 00:00 - 06:00 6.00 PULL P DECOMP POH & LID completion. Recovered 5 x 10' 12.6# L80 BTC pup jts., 202 jts. - 41/2" 12.6# L80 BTC tubing, 1 x 41/2" HES "XD" SSD assy. wI 1 x 4 1/2" 3' 12.6# L80 pup jt. in top of assy. and 1 x 4 1/2" 3' 12.6# L80 pup jt. in bttm .of assy. and 1 x cut 10' 12.6# L80 BTC pup jt. Cut 4 1/2" x 10' pup jt. in top of packer - recovered 6.46'. Stub looking up - 41/2" X 3.18'. Possible chemical cut at 1.5' down from top of stub. 06:00 - 06:30 0.50 PULL P DECOMP Service rig. 06:30 - 07:30 1.00 PULL P DECOMP Clear & clean rig floor. Install Wear Bushing. 07:30 - 09:00 1.50 PULL P DECOMP Load, tally & M/U BHA #1 as follows: 6 3/4" MM Mill, 4 Boot Baskets, Bit Sub, LBS, Oil Jars, 9 * 4 3/4" Dcs, Acce!. TL = 328.75'. 09:00 - 14:30 5.50 PULL P DECOMP P/U 3 1/2" DP, 1x1 & RIH wI BHA #1. 14:30 - 18:00 3.50 CLEAN P DECOMP P/U kelly. Break circulation. Tag up @ 8368'. Mill from 8368' to 8381'. P/U Wt = 85K, S/O Wt = 52K, Rot Wt = 63K. 60 RPMs, 10-13 WOB, Torq. 3.2K, 3 BPM @ 450 psi. Fluid losses = 55 bbls./hr. 18:00 - 00:00 6.00 CLEAN P DECOMP Mill from 8381' to 8389". P/U Wt = 85K, S/O Wt = 52K, Rot Wt = 63K. 60 RPMs, 10-13 WOB, Torq. 3.2K, 3 BPM @ 450 psi. Fluid losses = 55 bbls/hr. 8/29/2005 00:00 - 04:00 4.00 FISH P DECOMP Mill from 8389' to 8393'. P/U Wt = 85K, S/O Wt = 52K, Rot Wt = 63K. 40-120 RPMs, 5-15 WOB, Torq. 1.5K, 3-5 BPM @ 450 psi. Fluid losses = 55 bbls/hr. 04:00 - 06:00 2.00 FISH P DECOMP Repair rig mud pump. Line up manifold for reverse circulation. 06:00 - 06:30 0.50 CLEAN P DECOMP Service rig. 06:30 - 07:30 1.00 FISH P DECOMP Close annular & reverse 2 bottoms up. 4 BPM @ 800 psi. Recovered a very small amount of sand & scale. 07:30 - 10:00 2.50 FISH P DECOMP POOH & stand back 31/2" DP & 4 3/4" DCs. 10:00 - 12:00 2.00 FISH DECOMP Break off MM Mill & inspect same. Mill worn out. Appears to have run on Packer. Break out & empty junk baskets. Recovered approx. 35# of metal shavings & some piece of slips. Discuss options wI town engineer. Clear & clean rig floor. 12:00 - 12:30 0.50 FISH P DECOMP M/U BHA #2 as follows: Spear wI 3.947" Grapple,LBS, Oil Jar, 9* 4 3/4" DCs, Accel. TL = 313.49'. 12:30 - 15:00 2.50 FISH P DECOMP RIH wI BHA #2. 15:00 - 15:30 0.50 FISH P DECOMP P/U kelly & 24' pup jt. RIH & engauge fish. Set down wI 15K. P/U & had 25K overpull to 108K. Weight dropped to 83K. Appears to be dragging slightly. P/U Wt = 82K, S/O Wt = 52K. 15:30 - 16:00 0.50 FISH P DECOMP Pump tubng volume. 3 BPM @ 400 psi. Set back kelly. 16:00 - 20:00 4.00 FISH P DECOMP POOH w/ BHA #2. UD fish. Packer completely milled up except for bottom 4/1/2" NSCT connection. Recovered 3x 4 1/2" 10' 12.6# L80 pup jts., 1x 41/2" HES "XN" nipple and 1x 4 1/2" muleshoe WLEG. Now have 100% completion recovery. 20:00 - 00:00 4.00 FISH P DECOMP RIH w/9x 43/4" DC's and 3 1/2" DP. 8/30/2005 00:00 - 06:00 6.00 FISH P DECOMP POH LDDP 06:00 - 06:30 0.50 FISH P DECOMP Service rig 06:30 - 07:00 0.50 FISH P DECOMP Finish POOH & UD a total of 253 jts 31/2" DP. 07:00 - 07:30 0.50 FISH P DECOMP Change out handling tools & UD 9 * 4 3/4" DCs. 07:30 - 08:30 1.00 RUNCOrvP RUNCMP Pull Wear Bushing. Clear & clean rig floor. 08:30 - 11 :30 3.00 RUNCOrvP RUNCMP P/U, M/U & service ESP. Run attach and test cable 11 :30 - 12:00 0.50 RUNCOtvP RUNCMP Clean and clear rig floor 12:00 - 21 :00 9.00 RUNCO~ RUNCMP . TIH 2-7/8" 6.5# EUE 8rd New Tbg ESP Completion with LaSalle Clamps on cable testing cable continuity and filling tbg Printed: 9/12/2005 10:04:24 AM ) -) SF' EXPLORATION Operati()ns..·SUrnrnary·.·.Re~lort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/25/2005 Rig Release: 8/31/2005 Rig Number: *4ES Spud Date: 9/3/1997 End: 8/31/2005 Date From'- To HoUrs Task Code NPT Phase Description of Ope rations 8/30/2005 12:00 - 21 :00 9.00 RUNCOMP RUNCMP every 2000' 21 :00 - 23:00 2.00 RUNCOIVP RUNCMP Make up Tbg Hanger I Make up and test connector cable I P/U Wt. 39K S/O Wt. 24K Land Hanger and RILDS. 222 Lasalle Clamps, 3 Flat Gaurds, & 6 Protectrolizers run 23:00 - 00:00 1.00 RUNCOMP RUNCMP PJSM for BOPE rig down. Set TWC and test 1000 psi 8/31/2005 00:00 - 03:00 3.00 RUNCOM RUNCMP N/D Flow nipple and BOPE 03:00 - 05:00 2.00 RUNCOM RUNCMP N/U Tree Test Hanger 5000 psi, Test Tree 5000 psi 05:00 - 06:00 1.00 RUNCOM RUNCMP Clear rig and pits for rig move: Rig released @ 06:00 Printed: 9/12/2005 10:04:24 AM Permit to Drill 2010470 MD 11445 z TVD DATA SUBMITTAL COMPLIANCE REPORT 4118~2003 Well Name/No. MILNE PT UNIT SB H-08B Operator BP EXPLORATION (ALASKA) INC 4197 ~ Completion Dat 4/20/2001 .._ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22808-02-00 UIC N REQUIRED INFORMATION Mud Log No Sample N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media~.~ Fmt D D R L Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments 8699 11445 Open 9/13/2001 /.,,1~267 8699-11445 MWD Survey FINAL _.-I~rectional Survey FINAL -AO2'-67 FINAL ~erification FINAL ~ 215 FINAL -~'I'VD 2/5 FINAL ~JettB~re Profile/W'D 5 FINAL _10_1.~363 FINAL ,MO~Resistivity / GR ,,5 ,~ ! FINAL ~ellbore Profile/ 5 P~ I FINAL GR ~3~e-sistivity / GR 2/~ ! FINAL .-L-l'5~Verificatio n FINAL ...1.e305 FINAL ~D Resistivity / GR 5 FINAL ~Resistivity / GR 2/5 FINAL 1~3A/Vellbore Profile / 2/5 FINAL GR L~rification FINAL 8699 10180 8699 11445 8699 11445 Open 9/20/2001 ~ 8699-10180 Open 9/20/2001 OH 7/6/2001 OH 7/6/2001 oh oh 91J38~f1445 oh 9~8~445 oh ~ 11445 oh 8699 10180 OH .9~08 1018O 'OH ~ 10180 OH 9t-e8"~- 10180 OH OH 8699 11445 OH ...9'~8 11445 OH _.9~8 11445 OH ,:9-t.08~-11445 OH OH /,,,1'0305 9/17/2001 ~'0267 9/17/2001 9/17/2001 9/17/2001 9/17/2001 9/20/2001 9/20/2001 9/20/2001 9/20/2001 9/20/2001 9/20/2001 9/20/2001 9/20/2001 9/20/2001 9/20/2001 ~0~5 8699-11445 MWD Survey, Digital Data Directional Survey, Paper Copy 8699-11445 Digital Data LIS Verification 91,!.08--11445 BL, Sepia 9A-98=-11445 BL, Sepia 9'1-0871-1445 BL,Sepia 8699-10180 Digital Data 9108-10180 BL, Sepia 9108-10180 BL, Sepia 9108-10180 BL, Sepia /~ LIS Verification 8699-11445 Digital Data 9108-11445 BL, Sepia ~1J38-11445 BL, Sepia (_~1~08-11445 BL, Sepia LIS Verification Well Cores/Samples Information: Permitto Drill 2010470 MD 11445 TVD Name DATA SUBMITTAL COMPLIANCE REPORT 411812003 Well Name/No. MILNE PT UNIT SB H-08B Operator BP EXPLORATION (ALASKA) INC 4197 Completion Dar 4/20/2001 Interval Start Stop Completion Statu 1-OIL Sent Received Current Status 1-OIL Dataset Number Comments APl No. 50-029-22808-02-00 UIC N ADDITIONAL INFORMATION Well Cored? Y / ~ Chips Received? Analysis Daily History Received? Formation Tops Comments: Compliance Reviewed By: Transmittal Form HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Miline Point Unit MPH-08B PB 1 C'ontains tile following: I I.AS Format disk I I:ilm Set 1 Measured l)epth GR print 1 TVD-GR print 1 Resistivity Print LAC Reference Number: 1532.7 Sent By: Josef~crg Date: Sept 17,2001 Receive,~:~.~"~~.~'""~'~"'~'~'' Date: RECEIVE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COP~-~ 2 0 2001 BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER AIlt$[[it0i[ 900 E. BENSON BLVD. ~~O ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Transmittal Form BAKER i , ,~-,,-,~.,~ HUGH~ ~ Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Miline Point Unit MPH-08B ....... ... ....... ... .. ... . . . .......... . . . ... . .... . . .. . .. Contains the following: · ~ 1 LAS Format disk 1 Fihn Set 1 Measured Depth GR print 1 TVD-GR print '! Resistivity Print LAC Reference Number:: 15147 Sent By~ Date: SeplJ7, 2001 ~~--/~-' ~ ~ RECEIVE Received B~!._._...~"_/_: 0_(7) Date' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COP~ 2 0 2001 BP EXPLO~TION (ALASKA) ~8ka~/~ GaS ~ns. PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ~,cnorage ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Transmittal Form HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Prudhoe Bay North Slope, Alaska MPH-08B 1 ...... . ...... . ........ ....~.~.~:.~....-.~..~.~....... .... . Contains the following: I LAS Format Pisk 1 Film Set I Measured Depth GR Print 1 TVD-GR Print 1 - Resistivity Print Senti._ Received .~~ ~/~~_ _..J Date: Sept 13, 2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED SEP ¢i7001 Alaska 0il & Gas Cons. Commission Anchorage KA STATE OF ALASKA ALAS UIL AND GAS CONSERVATION COMM~;SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service ~2. Name of Operator ';L(~Tff:~ 7. Permit Number BP Exploration (Alaska) Inc.I ¥ .~ i 201-047 3. Address l~u 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~i 50- 029-22808-02 4. Location of well at surface ~-'~:": '="" ......... 9. Unit or Lease Name 2767' NSL, 4061' WEL, SEC. 34, T13N, R10E, UM ! '."-' ~ Milne Point Unit At top of productive interval 877' SNL, 1979' NWL, SEC. 01, T12N, R10E, UM (OA Sands) ' '":.'~'.'~:, ' 10. Well Number At total depth '~ _. ~i MPH-08B 2744' SNL, 3080' NWL, SEC. 01, T12N, R10E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 65.68' AMSL ADL 380109 12. Date Spudded3/31/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'4/10/2001 4/20/2001 115' Water depth' if °"sh°reN/A MSL [ 16. No. of CompletiOnSone 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 11445 4197 FTI 11445 4197 FTI aYes I'=lN°I N/AMDI 1800'(Approx.) 22. Type Electric or Other Logs Run GR, RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 110' 24" 260 sx Arctic Set (Approx.) 7" 26# L-80 31' 8588' 8-1/2" 2047 sx PF 'E', 263 sx 'G', 191 sx PF 'C 4-1/2" 12.6# L-80 8436' 9085' 6" ¢6 sx Class 'G' 2-7/8" 6.16# L-80 9078' 11430' 3-3/4" Uncemented Slotted Liner' , , ' 24. Perforations pp. en to. Producti.on (MD+TVD of Top and 25. TUBING RECORD Bottom and ~merva~, size anc~ number) SIZE DEPTH SET (MD) PACKER SET (MD) Uncemented Slotted Liner 4-1/2", 12.6#, L-80 8433' 8398' MD TVD MD TVD 9151'- 11395' 4169'-4192' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 30, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ] GAS-OIL RATIO 5/1/2001 12 TEST PERIOD 1048 179 0I 171 , , ,, ,, . Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER'BBL 0iL GRAVITY-APl (CORR) Press. 24-HOUR RATE ,, , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ",, '"'":' 7_.00! · .!'~. ,;, ,!-, ! ~.,~ ~'~",. ,'~'-, r Form 10-407 Rev. 07-01-80 r~l~ Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Schrader OA Sands 9070' 4153' Top Schrader OA Sands 9475' 4169' Top Schrader OA Sands 9548' 4172' Base Schrader OA Sands 10470' 4179' , 31. List of Attachments: Summary of Daily Drilling Reports, Surveys '32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubblo~~ ~ Title TechnicalAssistant Date (~°,..~"Oj~ MPH-08B 201-047 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: MPH-08B & MPH-08BL1 Accept: 03/28/01 Field: Milne Point Unit Spud: 03/31/01 APl: 50-029-22808-02 & 50-029-22808-60 Release: 04/20/01 Permit: 201-047 & 201-048 Drilling Rig: Nabors 3S Date PRE - RIG WORK 03/11/01 MIRU. Complete weekly BOP test. Make up TIW whipstock anchor, Sperry memory directional tool, HES CT CCL tool, MHA. RIH and tie into GR/CCL PSP log dated 02/25/01. Park whipstock anchor at 9114', corrected. Set anchor and confirm set. POOH. Make up whipstock tray w/RA tag. Ready to RIH. 03112/01 Attempt to set whipstock. Standby waiting on weather. 03113/01 Make up Baker 3.75" OD whipstock anchor setting tool, Sperry memory directional, HES CCL, MHA. Tie-in and set anchor with top at 9096' elm. POOH. OOH w/o whipstock anchor/packer. RIH w/ whipstock tray. 03/14/01 Attempted to stab whipstock for two hours. POOH to pick up knuckle joint. Marks on tools indicate 8" to go to get tool latched. RIH w/same tools and KJ. Repeat performance, no latch up. Pump lubetex pill. Try again to latch. No luck. POOH. Marks show within 3" of latching. C/O pack-offs. RIH w/same BHA, minus KJ, added two 3-5/8" weight bars, up / down jars. After several attempts latched into anchor and sheared. POH. Whipstock in place. Top of whipstock at 9081.5' elmd (R/A tag at 9091.5 elmd). 03/15/01 RIH with w/2-7/8" motor, 3.80" mill assembly. Mill "notch" (1.6' long). POOH. Wear marks on mill show casing is cut. RIH w/2.25" ball-drop nozzle, tag whipstock at 9081' ctm. PUH 10', flag pipe. Cemented well w/29 bbls 15.8 ppg Class 'G' cement. Squeezed 26 bbls below whipstock at final squeeze pressure of 1000 psi. Laid in 3 bbls above whipstock. Circulated out cement to 9030'. POH circulating. Wash sliding sleeve. Freeze protect tubing to 2000' with methanol. RDMO. 03/18/01 Attempted to pressure test against cement plug. Unable to get a test. Pressure leaked off and it appeared to be pumping away at 1.1 bpm at 1300 psi. Pumped total of 10 bbls of diesel in tubing. BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: RIG Rig Name: NABORS 3S Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 3/27/2001 00:00 - 06:00 6.00 MOB PRE Rig down from MPC-12A. 06:00 - 18:00 12.00 MOB TRAN PRE Wait on trucks to move rig. 18:00 - 20:00 2.00 MOB PRE Move rig and equipment from MPC to MPH pad. 20:00 - 22:00 2.00 MOB PRE Set rig mats. Back rig over well. 22:00 - 00:00 2.00 MOB PRE Set pits. Build dike for return tanks. 3/28/2001 00:00 - 04:00 4.00 RIGU PRE Rig up. Rig accepted @ 00:01 3/28/01 04:00 - 16:00 12.00 RIGU PRE Nipple up BOP stack. Install second set of TOT's to stack. 16:00 - 19:30 3.50 RIGU PRE Function test BOP. Attempt body test. Determine master valve leaking. Call for test plug. 19:30 - 20:15 0.75 RIGU PRE Hold EMS meeting with new crews on slope. Presented by MPU Environmental. 20:15 - 00:00 3.75 RIGU TREE PRE Wait for test plug. Grease valves. 3/29/2001 00:00 - 01:30 1.50 RIGU TREE PRE Install test plug, grease choke manifold. Test witness waived by AOGCC inspector Lou Grimaldi. 01:30 - 10:30 9.00 RIGU PRE Pressure test BOP.. 10:30 - 12:00 1.50 RIGU PRE , Pull test plug. Make up OXP coil connector. 12:00 - 13:00 1.00 RIGU PRE Hold pre-spud meeting with day crew. Stress differences in operation; MPU, Schrader Bluff formation, OXP. 13:00 - 18:30 5.50 RIGU PRE M/U BHI electrical connection. 18:30 - 19:30 1.00 RIGU PRE Hold Pre-spud meeting with night crew. 19:30 - 20:20 0.83 RIGU ~PRE Complete M/U of BHI electrical connections. 20:20 - 21:30 1.17 STWHIP PROD1 Circulate methanol water into e-coil. Pump 44 Bbls. Coil pressures up. (6.5 Bbls short of displacement ,,, 1000') Two heaters have been on coil since yesterday when it arrived. Decide to M/U BHA and run into hole to thaw. 21:30 - 23:00 1.50 STWHIP PROD1 M/U BHA #1, Window Master mill, string reamer, Mud Motor, PH-6, Mech. release, EDC. OAL = 100.11'. 23:00 - 00:00 1.00 STVVHIP PROD1 Surface test BHA. Witness EDC functioning. Printed: 5/1/2001 10:29:37AM BP EXPLORATION Page 1 ofll Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From-To Hours Task Sub Code Phase Description of Operations 3/30/2001 00:00 - 01:20 1.33 STWHIP PROD1 Continue surface checks with EDC. 01:20 - 03:45 2.42 STWHIP PROD1 RIH. Pump 10 Bbls methanol @ 4000'. Pressures up once to 1600#. Broke free. 8300' tool shorts out. Pump and move pipe. No change. 03:45 - 07:30 3.75 STWHIP BHA PROD1 POH. Change out pawl on level-wind. 07:30 - 09:30 2.00 STWHIP BHA PROD1 At surface. Break off below EDC. EDC found to be the problem. Change out and surface test. OK. 09:30 - 11:15 1.75 STWHIP BHA PROD1 RIH with BHA #2. Circulate in milling fluid; l/2ppb Biozan in 9.2 ppg KCL/NaCL, with Klagard and corrosion inhibitor. RIH weight ~ 2-4k#. 11:15 - 11:45 0.50 STWHIP PROD1 Set down on 5" x 7" liner hanger. Complete displacement of 60~40 from coil. close EDC. Pump minimum rate. Make it past liner hanger. Continue RIH pumping minimum rate. Tag cement at 9051' CTM. 11:45 - 12:20 0.58 STWHIP PROD1 Pick up 40k#. Bring pump rate up to 2.8 bpm. 3200 free spin. Wash through soft cement to 9088'. Start seeing motor work. Call this notch. 12:20 - 14:30 2.17 STWHIP PROD1 Mill window from 9085'. String weight showing -4k#. Milling rate increases @9097'. (BOW) Make pass, up through window. 1 stall in up direction. 14:30 - 17:15 2.75' STWHIP PROD1 Milling open hole at 6-21 fph from 9097'. Mill OH to 9108'. Circulate 30 Bbls 2 ppb Biozan pill on bottom. Catch samples on bottoms up. Shut down pump. Drift window. Clean up and down. Above window, open EDC. 2.8 bpm, 2900# ctp. No fluid losses through milling operation. 17:15 - 18:00 0.75 STWHIP PROD1 Circulate milling fluid at 9070' while wiating on mud truck. Mud arrives. 18:00 - 18:30 0.50 STWHIP PROD1 I~JSM with night crew. Mud swap and recovery. 18:30 - 19:30 1.00 STWHIP PROD1 Pump down pit levels. Ship milling fluids to clean tiger tank. Displace well to 9.2ppg FIoPro. 19:30 - 21:30 2.00 STWHIP PROD1 POH circulating. 21:30 - 23:40 2.17 STWHIP PROD1 LID BHA #2. Window mill guages 3.73" (chromed from formation) string reamer guages 3.8". M/U BHA #3, build assembly w/1.7 M.Motor. 23:40 - 00:00 0.33 DRILL PROD1 RIH with BHA #3. OAL = 63.1' 3/31/2001 00:00 - 01:30 1.50 DRILL PROD1 RIH w/BHA #3. 01:30 - 06:30 5.00 DRILL DATA PROD1 Attempt GR tie-in twice. ComputedDepth problems. 06:30 - 07:30 1.00 DRILL PROD1 Log GR tie-in, -4'. 07:30 - 08:10 0.67 DRILL PROD1 RIH and tag bottom @ 9104'. 08:10 - 09:30 1.33 DRILL PROD1 Drill build f/9104' to 9163'. 1.8 bpm, 2920 psi off bottom, 3200 drilling, BHP=2500. Up wt 35k#, slack off to 2k#, DH WOB ~ 2k#. TF 33L. (oriented from 111 L, slow due to temp. 65 F.) Begin heating recovered milling fluid w/HB&R. Fluid temp. starting @ 30 F. 09:30 - 11:15 1.75 DRILL POWR PROD1 Repair Dowell and BHI computer problems along with rig fuel line freezing. 5 sec. sample rate on Dowell computer appears to be locking it up. Second time in two days. Adjust rate to 30 sec. rate. Wind picking up to 30 mph. Phase one conditions called. 11:15 - 12:25 1.17 DRILL PROD1 Drill to 9200' with 3k# WOB. Losses at 1 bph. 12:25 - 15:00 2.58 DRILL PROD1 POH. Open circ. valve above window. ,15:00- 16:30 1.50 DRILL PROD1 Change bit, adjust AKO, add resistivity. 16:30 - 21:00 4.50 DRILL OTHR PROD1 USMPR resistivity tool not responding in string. Trouble shoot. Break out tool. Retest. Working. M/U BHA #4. 21:00 - 00:00 3.00 DRILL OTHR ~PROD1 RIH w/BHA #4. OAL = 74.86'. Continue to trouble shoot USMPR 3roblem. 4/1/2001 00:00 - 00:30 0.50 DRILL OTHR PROD1 Trouble shoot USMPR. May be mud-temperature induced. 00:30 - 03:00 2.50 DRILL PROD1 RIH. 03:00 - 04:30 1.50 DRILL OTHR PROD1 Configure Resistivity display out-put. Printed: 5/1/2001 10:29:37AM BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Date From -To Hours Task Code Phase Description of Operations ,, 4/1/2001 04:30 - 05:00 0.50 DRILL PROD1 Log GR tie-in. 05:00 - 07:15 2.25 DRILL TREE PROD1 POH for o-ring failure on lubricator. 07:15 - 08:00 0.75 DRILL TREE PROD1 CIO O-ring. 08:00 - 09:30 1.50 DRILL TREE PROD1 RIH circulating through circ. sub. OXP power supply problem. 09:30 - 11:00 1.50 DRILL BHA PROD1 POH due to OXP problems. 11:00 - 21:00 10.00 DRILL BHA PROD1 Trouble shoot OXP problems. Witness communication problem w/ OXP computers. Erratic voltage through CTE-line. USMPR still not working on surface. Cut coil to straighten and re-head e-line. Find collector drive-bolts sheared. Repair with hardened bolts the propper length. 21:00 - 22:15 1.25 DRILL BHA PROD1 Make up CT to BHA. Test electrical connections. Circulate out meth/wtr. '22:15 - 23:30 1.25 DRILL PROD1 RIH w/BHA #.4. 23:30 - 00:00 0.50 DRILL PROD1 Log GR tie-in. 4/2/2001 00:00 - 04:00 4.00 DRILL OTHR PROD1 Shut down Dowell computer and replace hard drive. 04:00 - 04:45 0.75 DRILL PROD1 Log GR Tie-in. (-11') 04:45 - 05:10 0.42 DRILL PROD1 RIH to bottom. 05:10 - 06:10 1.00 DRILL PROD1 Close circ. sub. Orient TF to 90R and drill 3'. 06:10 - 06:55 0.75 DRILL PROD1 'Safety meeting and discussion of directional plan between Geo. and D.D. 06:55 - 07:20 0.42 DRILL PROD1 Drill f/9203' to 9230'. 2.2 bpm, 3500 ctp, 2970 inner/2440 outer pressure, 34k# up, 3k# dn, 2k# wob. 07:20 - 08:30 1.17 DRILL PROD1 Orient TF f/75 R to 90 L. Find clockwise stop at 103 L. Turn TF CCW to 70L. 08:30 - 09:25 0.92 DRILL PROD1 Drill f/9230' to 9295'. 2.1 bpm, 3300 ctp, 2950 inner/2430 outer, 2k# wob. Stalled motor. Calcite stringer? Kicked inclination up to 95 deg. 09:25 - 11:45 2.33 DRILL PROD1 Drill to 9350'. Appear to be in calcite stringer. 11:45- 12:15 0.50 DRILL PROD1 Short trip to window. 12:15 - 16:50 4.58 DRILL PROD1 Pull above window to log from 8950' to TD to get one continuous log from above Shrader Bluff formation to TD for definitive Geological reference. Hole in good condition. Logging at 100 fph, 0.5 bpm. Mud weight @ 9.1 ppg. Add NaCI to bring back up to 9.2 ppg. 16:50 - 19:05 2.25 DRILL PROD1 Drill f/9350' to 9480'. Bringing angle down. ROP varies from 10 to 100 fph. 19:05 - 19:50 0.75 DRILL PROD1 Short trip to window. Replace Nabors pump pop-off and clean suction s. creens. 19:50 - 21:20 1.50 DRILL PROD1 Drill ahead f/9480'. Snubbing -6k# and getting 4-5k# WOB. Drilling slow. Angle dropping below 90 deg. 21:20 - 00:00 2.67 DRILL PROD1 Continue drilling at 9630'. Still stacking 4-6k# w/1-3k# getting to BHA. 2 bpm, 3500# surface pressure, 3145# inned2570# outer pressure. 4/3/2001 00:00 - 12:45 12.75 DRILL PROD1 Make wiper trip f/9630'. 12:45 - 04:10 15.42 DRILL PROD1 Drill to 9770'. Hit fast-drilling streak @9680'. 2 BPM, 3430 surface pressure, 3110 inner/2588 outer. 2k-4k WOB. 04:10 - 04:55 0.75 DRILL PROD1 Wiper trip f/9770'. Hole clean, complete string weight running back in hole 2k-3k#. 04:55 - 09:45 4.83 DRILL PROD1 Slow drilling to 9926'. Break through stringer @ 9886'. ROP increases to 100 fph. 09:45 - 10:45 1.00 DRILL PROD1 Short trip to window. Hole is clean. 10:45 - 12:25 1.67 DRILL PROD1 Drill fl 9925'. Takes off drilling 70 fph for short distance. Goes slow again to 9960'. 12:25 - 14:40 2.25 DRILL PROD1 Drilling and string weight and ROP increase intermitantly. Lose weight transfer to bit. Drilled to 9997'. 14:40-16:10 1.50 DRILL PROD1 Shorttrip 100'. No improvement. Pull wiper trip to window. Ordernew Printed: 5/1/2001 10:29:37AM BP EXPLORATION Page 3 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/3/2001 14:40 - 16:10 1.50 DRILL PROD1 batch of mud to be mixed. 16:10 - 19:10 3.00 DRILL PROD1 Drilling with -7k# string weight. 2 bpm, 3750 surface/3240 inner/2630 outer, 3k# wob. 10,036' rop increases slightly. Drill to 10056'. 19:10 - 19:45 0.58 DRILL PROD1 PUH to casing. 19:45 - 20:45 1.00 DRILL PROD1 Repair Dowell computer. 20:45 - 21:20 0.58 DRILL PROD1 Log GR tie-in. (+8') 21:20 - 21:50 0.50 DRILL PROD1 RIH 21:50 - 22:50 1.00 DRILL PROD1 Drill to 10,092' Still within shale In side BHA pressure 3330 psi outside 2635 psi,Coil pressure 3750 free spin 3500psi. WOB 3.6K 22:50 - 00:00 1.17 DRILL PROD1 Drill to 10,110 still in shale. Inside BHA pressure 3335psi, outside BHA pressure 2660 psi, Coil tubing presssure 3820 psi. 4/4/2001 00:00 - 03:40 3.67 DRILL PROD1 Drill to 10180' still in shale 03:40 - 04:30 0.83 STKOH PROD1 Pull to window 04:30 - 04:45 0.25 STKOH PROD1 Open circulation port and circulate bottoms up. 04:45 - 07:15 2.50 STKOH PROD1 Discuss options with Anchorage team members and develop open-hole side-track directional plans. Target Iow-side kick-off @ 9800' md. 07:15 - 08:00 0.75 STKOH PROD1 RIH to begin trenching. 08:00 - 12:30 4.50 STKOH PROD1 Begin "trenching" for Iow-side exit f/9770' to 9800'. Tool Face ~ 177 R. Pumping 2 bpm, 3550 CTP, 3080 inner/2615 outer, 3k# string weight reaming down. 12:30 - 18:00 5.50 STKOH PROD1 Shut down pump and test ledge. RIH and stack lk# on lip at 9800'. Pick up and begin time drilling @ 9800'. Make several repeats of 9803'. Appear to be drilling new hole. 18:00 - 19:00 1.00 STKOH PROD1 Drill to 9813. Inner BHA pressure 2884 psi, outer BHA pressure 2559, WOB .4K 1.6 bpm. 19:00 - 23:00 4.00 STKOH PROD1 Drill to 9819. Inner BHA pressure 2884 psi, outer BHA pressure 2559, WOB .4K 1.6 bpm. Drill to 9928 Inner BHA pressure 3148 psi, outer BHA pressure 2635 psi, WOB 1.6 K 2.0bpm. 23:00- 00:00 1.00 STKOH PROD1 Drill to 9960'. Inner BHA pressure 3166 psi, outer BHA pressure 2647psi, WOB 2.6 K 2.0 bpm. 4/5/2001 00:00 - 00:23 0.38 STKOH PROD1 Wiper trip to window 900'. 00:23 - 01:24 1.02 STKOH PROD1 ; Reboot Computers 01:24 - 03:30 2.10 STKOH PROD1 Directionally drill to 10,110 03:30 - 04:00 0.50 STKOH PROD1 Tie in +6' RIH 04:00 - 05:30 1.50 STKOH PROD1 Directionally drill to 10116. Pressur inside BHA 3252 psi, Pressure outside BHA 2686 psi, WOB 4.6K 4129 TVD, @2bpm. 05:30 - 09:00 3.50 STKOH PROD1 Drill ahead. Hit hard stringer or shale @ 11,115'. Break through hard spot @ 10125'. (Confirmed calcite) Drilling 90 fph. 2.6k# wob, -lk# string weight. Run into hard stall/drilling @ 10185'. Make 10200'. Still drilling slowly. Acts like shale. 09:00 - 09:20 0.33 DRILL PROD1 Drill to 10201' @ 1.9 bpm. Stacking and stalling motor. Poorweight transfer. Acts like fault. BHP at 1.9 bpm @ 2700#. Begin losing returns up to 20 bph. Reduce circ. rate to 1 bpm and regain 1 for 1 returns. BHP 2550#. 09:20 - 13:00 3.67 DRILL PROD1 Pull up to casing at 1 for 1 returns. Shut down pump. No flow. Circulate 1 bpm, POH for BOP test. 13:00 - 13:15 0.25 DRILL PROD1 PJSM for BHA, Slack management. 13:15 - 13:45 0.50 DRILL PROD1 Rack back BHA. Bit in good shape. Guages at 3.75". 13:45 - 16:15 2.50 DRILL PROD1 Cut off e-line anchor. Reverse circulate 150 bbls mud up coil at 3 BPM, 4000 psi. Pump coil volume of meth/water at 1 bpm. Find 41" of e-line hanging out of coil. 16:15 - 17:15 1.00 DRILL PROD1 Set two way check for BOP test. Cut extra e-line. Stab on well. 17:15 - 18:00 0.75 DRILL PROD1 Reverse circ. 70 Bbls mud into coil @ 3bpm. Check coil. E-line further Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From -To Hours Task Sub Phase Description of Operations Code 4/5/2001 17:15 - 18:00 0.75 DRILL PROD1 than 5' inside coil. 18:00 - 19:30 1.50 DRILL PROD1 Freeze protect coil with methanol reversing. 19:30 - 00:00 4.50 DRILL PROD1 Cut off 7' coil. install and pull test coil connector. Pressure test coil connector. Test BOP. 4/6/2001 00:00 - 00:45 0.75 BOPSUF PROD1 Continue to rehead and Test BOP. 00:45 - 05:30 4.75 BOPSUF PROD1 Continue to test BOP 05:30 - 06:30 1.00 BOPSUF PROD1 Pull TWC. 06:30 - 08:00 1.50 DRILL PROD1 M/U BHA #5. RR DS-49. Test OXP tools. Open circ. sub. Circulate out methanol water. 08:00 - 08:45 0.75 DRILL PROD1 RIH with BHA #5, OAL = 74.75'. Make 2200'. 08:45 - 09:15 0.50 DRILL BHA PROD1 Problem with OXP. Check collector. POH. 09:15 - 10:45 1.50 DRILL BHA PROD1 OOH. Put on circulating sub on coil. Check out tools. Replace EDC. Retest tools. OK. M/U to coil. 10:45 - 11:15 0.50 DRILL BHA PROD1 RIH w/BHA. 2000'. Looking good. 11:15 - 13:00 1.75 DRILL PROD1 Continue running in hole. 13:00 - 13:20 0.33 DRILL PROD1 Log GR tie-in, (-2') 13:20 - 14:00 0.67 DRILL PROD1 Close circ. valve, pass window. RIH. Hole in good, smooth condition. Tag @ 10198'. Circulating 0.5 bpm, getting 1 for 1 returns.-2300 bhp Circulating 1.0 bpm, getting 80% returns. -2400 bhp Circulating 1.5 bpm, getting 50% returns. ~2500 bhp 14:00 - 18:00 4.00 DRILL SUPP PROD1 PUH to casing and wait for new mud. Ordered @ 05:30. Waiting for vac. truck transportation. Perform step rate test in casing again. This time work up to 2 bpm at 1/4 bpm increments, 100% returns. (yesterday had losses) 18:00 - 18:45 0.75 DRILL PROD1 Circulate in new mud through circulating sub in casing @ 2 bpm. 18:45 - 20:00 1.25 DRILL PROD1 Dowell computer locks up. Reboot. Change data sample time from 5 second to 10 second. 120:00 - 21:00 1.00 DRILL PROD1 Continue to circulate in new mud. 21:00 - 22:00 1.00 DRILL PROD1 RIH ,22:00 - 00:00 2.00 DRILL PROD1 Drilling at hard spot @ 10200' 5k# wob (calcite?) Initial losses 30 BPH but heal as we drill. Drill to 10205'. Loss rate .2 bpm. Pressure at inside BHA 3086 psi, Pressure outside BHA 2577 psi. Coil tubing pressure 3366 psi @ 2pbm wob 2k. 4/7/2001 00:00 - 03:30 3.50 DRILL PROD1 Drill to 10273, Coil tubing pressure 3200 psi Pessure inside BHA 3000 psi, Pressure outside BHA 2590 @ 1.8 BPM WOB lk loss rate .1 bpm 03:30 - 04:30 1.00 DRILL PROD1 Drill to 10,338 Coil tubing pressure 3495 psi Pressure inside BHA 3180 psi, Pressure outside BHA 2605 @ 2.0 BPM WOB 3.9 k loss rate .1 bpm 04:30 - 05:00 0.50 DRILL PROD1 Drill to 10345' Coil tubing pressure 3380 psi Pessure inside BHA 3050 psi, Pressure outside BHA 2593 @ 2.0 BPM .loss rate .1 bpm 05:00 - 06:45 1.75 DRILL PROD1 Wiper trip to window. See motor work back reaming @ 9380'. Hole takes weight @ 9430' when RIH. (Shale at top of OA sand) Hole takes weight @ 10000'. (silt stone) 06:45 - 08:15 1.50 DRILL PROD1 Resume drilling f/10345'. 2 bpm, 3600 ctp, 2620 outer, -6k# string wt, 3k# wob. Appear to be in shale. Drill to 10397'. 08:15 - 09:45 1.50 DRILL PROD1 Short trip for geological analysis. 09:45 - 13:25 3.67 DRILL PROD1 Resume drilling f/10397'. Progress increases slightly @ 10415'. Lose resistivity signal and regain 30 minutes later. Drilling in decent sand to 10550'. ROP @ 70 fph. Make wiper trip. OXP acting up. 13:25 - 15:00 1.58 DRILL LMWD 'PROD1 OXP Shorts out during wiper trip. Pull up to casing to check collector. All surface equipment checks out. Hole in decent shape. Slight bobble @ 9380'. Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 5 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From-To Hours Task Sub Code Phase Description of Operations 4/7/2001 15:00 - 18:50 3.83 DRILL LMWD PROD1 POH to check out eXP. 18:50 - 20:30 1.67 DRILL LMWD PROD1 ECD bad replace. No resistivity at surface. 20:30 - 21:30 1.00 DRILL LMWD PROD1 Wait on information regarding availibility of subs to change out Circulation sieve. No additional subs availabe. Could use the ones we have on the other tool but choose to proceed with the current BHA. Have had previous instances where resisitivity didn't work onsurface but later did after it RIH and got warmed up. Decided to precede and if necessary we will mad pass to get resistivity. 21:30 - 22:00 0.50 DRILL LMWD PROD1 MU BHA. 22:00-00:00 2.00 DRILL LMWD PROD1 RIH 4/8/2001 00:00 - 00:45 0.75 DRILL LMWD PROD1 Tie in with RA tag -3'. Close circulation ports. 00:45 - 01:45 1.00 DRILL PROD1 Drill ahead 10550 to 10554 01:45 - 02:00 0.25 DRILL PROD1 Tool shorted out. Diagnose to confirm down hole failure 02:00-04:00 2.00 DRILL LMWD PROD1 POH 04:00- 04:30 0.50 DRILL LMWD PROD1 Break down BHA 04:30 - 07:15 2.75 DRILL LMWD PROD1 Find broken wire in cable head. Repair and M/U BH^. 07:15 - 08:20 1.08 DRILL LMWD PROD1 4500' develope another short. 08:20-09:00 0.67 DRILL LMWD PROD1 POH. 09:00 - 11:15 2.25 DRILL !LMWD PROD1 Rack back tools. Find connector on flapper valves off, and crimp connector on e-line disconnected. Find crimping tool set too strong. Reset. Make up new crimp connection. M/U BH^. Surface test ok. 11:15 - 12:10 0.92 DRILL LMWD PROD1 Tool shorts out at 5500'. 12:10-13:00 0.83 DRILL LMWD PROD1 POH. 13:00 - 19:40 6.67 DRILL LMWD PROD1 EDC crapped out. Rehead and set up for dual mechanical release system. 12,140# shear value in upper and lower as per town discussions. Check tools, ok. Break off of tools and circulate out methanol water. Make back up to tool. 19:40 - 22:50 3.17 DRILL LMWD PROD1 RIH w/BHA. Tie into whipstock pip-tag. (-9') Run to bottom. Resistivity not working at this time. 22:50 - 00:00 1.17 DRILL PROD1 Drill f/10554', lk# RIH wt. 2 bpm, 3350 free spin 3500 drilling, losing 15 bph mud initially. Drill to 10560'. 4/9/2001 00:00 - 00:15 0.25 DRILL POWR PROD1 Reboot BHI and Dowell computers. 00:15 - 03:00 2.75 DRILL PROD1 Drill f/10560'. 2 bpm, 3350 ctp, 3050 inner, 2600 outer. Up wt 28k#, slack off wt lk#, snubbing >8k# getting 2k# web. Drilling 10t o 60 fph. Drill to 10682'. Losses heal to 1 bph. 03:00 - 04:45 1.75 DRILL PROD1 Short trip. 04:45 - 06:00 1.25 DRILL PROD1 Drilling f/10,682'. Break out into upper OA sand. ReP increases dramatically to >120 fph. Drill to 10800'. 06:00 - 08:30 2.50 DRILL PROD1 i Short trip. Hole appears in good shape. 08:30 - 09:40 1.17 DRILL PROD1 Drill 10800'-10908', 75R-95R, 2 BPM, 3500 CT, 3100 inside, 2600 outside, good ReP (~120 fph) until hard spot at 10908'. In upper OA sand lobe. ' 09:40 - 10:00 0.33 DRILL PROD1 Short trip 200' to improve weight transfer. 10:00 - 10:20 0.33 DRILL PROD1 Drill 1' to 10909', hard calcite. Slow ReP of 3 fph. 1.5k lbs WeB with ~-7k snubbing. 10:20 - 12:35 2.25 DRILL I PROD1 Decide to perform wiper trip to the window. PUH smooth. RBIH and set down at 9340' twice (OA sand upper lobe). Seems like a ledge. Orient to ~90L to get by. RIH and set down at 10650' and 10710' (silt). Work through and RIH to bottom. 12:35 - 15:20 2.75 DRILL PROD1 Hard to get started drilling due to calcite stringer. Work through and ReP picks up to 120 fph, 2.6k lbs WeB. Drill 10909'-11070' in OA sand. ECD up 50 psi to 2650 psi. Have only lost 17 Bbl of mud from 0600-1530. Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/9/2001 15:20 - 16:30 1.17 DRILL PROD1 Wiper trip to the casing. 16:30 - 17:30 1.00 DRILL DATA PROD1 Load software on SLB computer to help troubleshoot intermittent crashes. 17:30 - 18:15 0.75 DRILL PROD1 RBIH. Set down at 10553' at directional change from 90L to 90R. Orient and go through at 10R. Set down at 11017, another directional change 90R to 90L. 18:15 - 19:00 0.75 DRILL DIR PROD1 Attempt to orient from 90R to 90L, but hole keeps pushing BHA over to 90R. PU to 10800 and get 90L orientation. RBIH past 11017' and tag bottom at 11070'. 19:00 - 21:30 2.50 DRILL PROD1 Drill 11070'-11203 '. Periodically hitting calcite stringers which slows ROP way down. Pump 2 BPM, 3500 psi CT, 3057 inner, 2670 psi outer. Hit another apparent calcite stringer at 11203'. Cannot get good weight transfer to the bit. Snub to -10klbs and see <lklbs at bit. Short trip and call for new mud. Current system is at ~0.8% solids. Had 5 Bbls of EMI 544 on location, but decide to swap mud to finish hole. 21:30 - 00:00 2.50 DRILL PROD1 Short trip to window. Hole smooth on the way up. Tie in and add 10'. New TD 11213'. RBIH and stack at 9380' & 10474 and push through. Stack at 10984' & 11025' and have to orient to direction drilled to get through. 4/10/2001 00:00 - 03:35 3.58 DRILL PROD1 Drill 11213-11320', 2 BPM, 3280 psi CT, 3100 psi inner, 2660 psi outer. PUW 28k, SOW to -10klbs when stacking out. Wieght transfer becoming a major problem. Stacking out with <lklbs WOB. New mud expected soon. 03:35 - 07:20 3.75 DRILL PROD1 Wiper trip to window. Log tie in and at 10'. RBIH. Take weight at 9385', 10630', 10648', 10972', 10990', 11025', and 11150'. Orient or push through. Various reasons for stacking, ledges & DLS speculated. Also mud is old. Short trips are down with full pump rate while POOH (2 BPM). When RIH pump rate is at minimum (0.5 BPM) to reduce the chance of sidetracking in soft sand. 07:20 - 10:00 2.67 DRILL PROD1 Drill 11320-11443'. New mud in hole. Noticable increase in drill rate. 60 fph in sand. Dropping down from upper OA sand lobe to lower OA sand lobe at ~85 degree inclination. Stack out at 11443'. 10:00 - 13:00 3.00 DRILL PROD1 POOH. Pull 5k over (35k) at 9380' for a short period of time and then free. Have 29 deg DLS at this point. Continue up hole with no problems. Re tie in +6' correction to RA tag in whipstock at 9092'. RBIH. 13:00- 13:30 0.50 DRILL 'PROD1 Drill to 11448'. 13:30 - 17:45 4.25 DRILL PROD1 Wiper to window. Tie-in (no correction). TIH. Tag corrected TD 11445'. 17:45 - 21:00 3.25 DRILL PROD1 POOH. Tie-in at RA (+1' correction). Flag pipe 9031' EOP. POOH. 21:00 - 23:00 2.00 DRILL PROD1 !Displace coil with methanol. LD BHA. 23:00 - 00:00 1.00 CASE COMP RU liner running equipment. 4/11/2001 00:00 - 00:30 0.50 CASE COMP Safety meeting -- run liner. 00:30 - 05:00 4.50 CASE COMP MU 72 joints 2-7/8" STL slotted liner. 05:00 - 06:00 1.00 CASE COMP MU swivel, 2-3/8" collar and pup for floor valve. 06:00 - 06:30 0.50 CASE COMP Safety meeting with day crew. 06:30 - 10:30 4.00 CASE COMP MU 72 jts 1-1/4" CSH. Tag top of slick stick in pack-off bushing. Space out with pups. MU GS spear, 2~3/8" collar, and swivel 10:30- 13:30 3.00 CASE COMP Finalize running procedure/equipment. 13:30 - 15:30 2.00 CASE COMP TEST GS SPEAR: PUH to deploy sleeve. Close 2-7/8" slips. LD 2-3/8" collar. Stab CTC on GS spear. NU riser. Pull test GS spear to Printed: 5/1/2001 10:29:37AM BP EXPLORATION Page 7 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 ~Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/11/2001 13:30 - 15:30 2.00 CASE COMP 10k over. Slack-off. Circulate at 1.5 BPM and release spear. OK. Stab back in and pull test. OK. Stand back injector. MU 2-3/8" collar and swivel. 15:30 - 16:15 0.75 CASE COMP Displace methanol out of coil. Stab inj. 16:15 - 18:30 2.25 CASE COMP RIH at minimum rate. Correct depth at 6000' EOP flag (-12.4'). RIH. At 9000', 2k down and 24k up (seems light). RIH clean to 9950', then ratty 2k to -2k. Tag hard 10158'. SD pump. Clean PU to 28k. Try to work down. Repeat tags at same depth. Then got PU to 40k (must have dropped the liner at some point). RIH again and ran to 10860'. 18:30 - 00:00 5.50 CASE COMP Work pipe downhole from 10860' with neg 10k - 15k. To make progress, required alternating pumping (about 10 - 20 bbls) and then working pipe down 5' - 30'. Some lost circulation noted 2.0 BPM in and 1.7 BPM out, but gradually improved to near full returns at tail end of pumping cycle. Occasionally lost liner if not fully bled down, but easy latch. No correction at 9031' EOP flag. RIH with liner to 11425'. 4/12/2001 00:00 - 02:30 2.50 CASE COMP Work liner to 11430'. No further progress. TOL at 9078'. 02:30 - 04:30 2.00. CASE COMP Unsting from GS. Circulate hole to 9.2 ppg brine. 04:30 - 05:30 1.00 CASE COMP Lay in 35 bbls 6 ppb lith hypo water in liner. 05:30 - 09:00 3.50 CASE COMP Park and let soak. 09:00 - 10:30 1.50 CASE COMP RIH displacing bleach. Getting 1:1. 10:30 - 12:00 1.50 CASE COMP Lay in 35 bbls 9.2 ppg Baradrill-N with 31 ppg CaCO3. 12:00- 14:00 2.00 CASE COMP POOH. 14:00 - 14:30 0.50 CASE COMP Set inj on back deck. 14:30 - 15:00 0.50 CASE COMP Safety meeting. 15:00 - 16:30 1.50 CASE COMP Standback 1-1/4" CSH. 16:30 - 18:30 2.00 STWHIP WEXlT Prep for slack management. Pump hot KCL water to pits. 18:30 - 20:00 1.50 s'rWHIP WEXlT Change-out packoff. 20:00 - 22:45 2.75 STWHIP WEXIT Reverse methanol out of coil with hot KCL water. Surge to move cable. Cut pipe. Cable only moved a couple of feet. Repeat surge. Couple more feet. Call this good 22:45 - 00:00 1.25 STWHIP WEXlT Cut 250' of pipe for fatigue management. 4/13/2001 00:00 - 02:30 2.50 STWHIP WEXIT Install CTC. Pull test. Re-head E-line tools. 02:30 - 04:00 1.50 STWHIP WEXIT MU whipstock BHA. 04:00 - 13:30 9.50 STWHIP BHA WEXlT RIH to 3900'. Lost communication with tools. Short. POOH. Had pulled out of weak point. We obviously slacked-off on our slack management. Reverse circulate again 3.5 BPM. Got 6' of cable movement. Re-head. Pump forward at 3.5 BPM to get slack distributed back to downhole end of coil. Heard cable rattle around for about 30 sec. MU BHA. 13:30 - 15:00 1.50 STWHIP WEXIT MU and RIH with whipstock. 15:00 - 15:30 0.50 STWHIP WEXlT Log tie-in. Correct depth (-4'). 15:30 - 16:15 0.75 STWHIP WEXlT RIH to 9078' clean (did not set down) while orienting whipstock face straight down. PUH. RIH to 9075'. Pressure coil to set whipstock. Sheared setting tool at 2400 psi. Stack 5k down on whipstock. Good. Whipstock top 9062'. 16:15 - 17:30 1.25 STWHIP WEXlT POOH. Flag pipe at 8800' EOP. 17:30 - 18:45 1.25 STWHIP WEXlT LD BHA. 18:45 - 19:30 0.75 STWHIP WEXIT Set TWC valve. 19:30 - 20:00 0.50 STWHIP WEXlT Safety meeting. 20:00 - 00:00 4.00 STWHIP WEXlT Perform weekly BOP test. 4/14/2001 00:00 - 02:00 2.00 STWHIP WEXlT Continue weekly BOP test. 02:00 - 04:00 2.00 STWHIP TEST WEXlT Downtime to fix Triplex pump and replace 2-7/8" ram rubbers (SI rams on no-go). Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code .... 4/14/2001 04:00 - 06:00 2.00 STWHIP WEXlT Finish BOP test. 06:00 - 06:30 0.50 STWHIP WEXlT Safety meeting. 06:30 - 07:00 0.50 STWHIP WEXIT Stab inj. PT stripper and inner reel valve. 07:00 - 08:30 1.50 STWHIP WEXIT :Wait on crew to pull TWC. Pull it. 08:30 - 09:30 1.00 STWHIP WEXIT Displace methanol from coil. 09:30- 10:30 1.00 STWHIP WEXlT MU milling BHA #11 (2.5 deg motor; tapered DSM) 10:30- t2:15 1.75 STWHIP WEXlT RIH 12:15 - 12:45 0.50 STWHIP WEXlT Tie-in at 8700'. Correct depth (-3'). 12:45 - 13:00 0.25 STWHIP WEXIT RIH and dry tag whipstock 9062'. PUH. Est circ 2.5/3250'. 13:00 - 17:00 4.00 STWHIP WEXIT Time mill at 180 TF from 9060' to 9062.5'. 17:00- 18:45 1.75; S'I'WHIP WEXIT POOH. 18:45 - 20:00 1.251 STWHIP WEXIT Swap 2.5 deg motor and mill with straight motor and tapered DSM + string mill. 20:00 - 21:30 1.50 STWHIP WEXIT RIH with BHA #12. 21:30 - 21:45 0.25 STVVHIP WEXIT Log tie-in. Correct depth (-2'). 21:45 - 22:00 0.25 STVVHIP WEXIT RIH with pumps 2.5/3050. Stall at 9061'. PUH. RIH slow. Motor work starting 9060.7'. 22:00 - 00:00 2.00 STWHIP WEXIT Mill window. 4/15/2001 00:00 - 01:45 1.75 ST'WHIP WEXIT Mill window to 9067.5'. Couple stalls, then popped thru here. Good ROP in formation. E-line signal going, going, then gone. 01:45 - 02:30 0.75 STWHIP WEXIT Drill formation to 9079' 02:30 - 05:15 2.75 STWHIP WEXIT Ream and backream window. Dry tag clean. Start swapping well over to FIo-Pro. 05:15 - 07:30 2.25 S'I'WHIP WEXIT POOH displacing well to FIo-Pro. 07:30 - 08:15 0.75 STWHIP WEXIT LD milling BHA. 08:15 - 10:15 2.00 STWHIP BHA WEXIT Troubleshoot short. Cable head OK. EDC OK. Short in OXP tool. Swap to different OXP. 10:15 - 11:00 0.75 DRILL PROD2 MU drilling BHA (1.4 deg motor; used DS49 bit). 11:00-12:45 1.75 DRILL PROD2 RIH. Sat down at 6264' with 110LTF. Repeattag. Orient straight down. Run past tight spot. 12:45 - 14:45 2.00 DRILL FILL PROD2 RIH circulating thru bit to 8200'. Some sort of trash staying with us. Open circ sub. CBU at 3.1 BPM; 3700 psi (that's all we can get out of the pump). Bunch of metal puking-out over the shakers. Close circ sub and motor on down to 8900'. Open circ sub and again CBU. 14:45 - 15:15 0.50 DRILL PROD2 Tie-in. Correct depth (-4'). Run thru window clean with Iow side TF. 15:15 - 16:45 1.50 DRILL PROD2 Tag 9077'. Drill 2.5 BPM, 180 TF at 80 - 90 FPH to 9160'. 16:45 - 18:15 1.50 DRILL PROD2 Start working TF up. Drill 18:15 - 21:45 3.50 DRILL PROD2 Short trip to window. Drill to 9460'. 50-90 ft/hr pump pressure 3740 psi. Inside bha pressure 3300 psi, out side bha pressure 2575 psi @ 2.4 bpm. 21:45 - 00:00 2.25 DRILL LOG PROD2 OXP failure. POH 4/16/2001 00:00 - 03:45 3.75 DRILL BHA PROD2 LD BHA #13. MU BHA #14 (new OXP). RIH. Tie-in and correct depth (-6'). 03:45 - 05:00 1.25 DRILL PROD2 Drill to 9620'. 05:00 - 06:00 1.00 DRILL PROD2 Wiper to window. RIH at rain rate. 06:00 - 08:00 2.00 DRILL PROD2 Drill to 9800'. BH AP = 2650 psi (650 psi annular friction). 08:00 - 09:45 1.75 DRILL PROD2 Wiper trip to window. Log tie-in. Looks like RA is at 9069' corrected. 09:45 - 11:45 2.00 DRILL PROD2 Drill to 9986'. BH AP approaching 2700 psi. Drill solids at 0.9%. Call for mud. 11:45 - 12:45 1.00 DRILL PROD2 Wiper to window. 12:45 - 15:30 2.75 DRILL PROD2 Drill to 10106'. Hit hard spot here. TF and inclination did a dance. 15:30 - 16:30 1.00 DRILL PROD2 Drill at a snails pace with -10k to 10132'. Stacking. 16:30 - 18:00 1.50 DRILL PROD2 Wiper to window. No motor work seen. Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From-To Hours Task Sub Code Phase Description of Operations ,, 4/16/2001 18:00 - 20:10 2.17 DRILL PROD2 Drilling at 10283. Pump pressure 3756 psi, Inside BHA pressure 3327 psi, Out side BHA pressure 2756 psi. @ 2.3 bpm. ECD 12.7 20:10 - 21:20 1.17 DRILL PROD2 Circulat in new mud. Pump pressure 3524 psi BHA pressure 3272 psi, Out side BHA pressure 2688 psi. @ 2.4 bpm. ECD 12.4 21:20 - 00:00 2.67 DRILL PROD2 Short trip. drill to 10465. Pump pressure 3548 psi BHA pressure 3230 psi, Out side BHA pressure 2703 psi. @ 2.4 bpm. ECD 12.5 4/17/2001 00:00 - 00:10 0.17 DRILL PROD2 Drill to 10480'. Not seeing much change in pressures since mud swap. BH annular pressure still hanging around at about 2700 psi. 00:10 - 01:30 1.33 DRILL PROD2 Wiper trip to window. 01:30 - 03:00 1.50 DRILL PROD2 Drill to 10650'. 03:00 - 04:45 1.75 DRILL PROD2 Wiper to window. Hole in good shape. 04:45 - 08:30 3.75 DRILL PROD2 Drill. Hit hard spot at 10743'. Little sticky on pickup. Drill to 10776' 08:30 - 10:15 1.75 DRILL PROD2 Wiper to window while looking at the geo picture. Slight motor work at 9631', otherwise very clean. · 10:15 - 12:15 2.00 DRILL PROD2 Drill with neg wt. and lots of stacking to 10880'. BH AP up to 2830 psi. About -10k wt off bottom RIH. 12:15 - 16:00 3.75 DRILL PROD2 Wiper to window. Wiper to 2200' at 2.6 BPM. Open circ sub and RIH at 3.0 BPM. 16:00 - 16:30 0.50 DRILL PROD2 Log tie-in at 8700'. Correct depth (+15'). RA coming in at 9071' corrected. Tag'd something at 9081'. PU. RI and fell thru clean. 16:30 - 17:15 0.75 DRILL PROD2 RIH to TD. 17:15 - 18:30 1.25 DRILL PROD2 Drill. Took off running 100+ FPH. Also, BH AP = 2730 psi (100 psi less than before the long wiper trip). Drilled to 11029'. 18:30 - 21:10 2.67 DRILL PROD2 Wiper trip to window. Pump min rate RIH. Tagged at 10700' Orient TF to 80R then went through okay. Work weight transfer last 5' to bottom. 21:10 - 21:15 0.08 DRILL PROD2 Drill to 11030'. Lost power to BHA. (Generator to BHI went down on "low oil" shut-off.) 21:15 - 21:35 0.33 DRILL PROD2 Restart generator. 21:35 - 23:15 1.67 DRILL PROD2 Resume drilling. 3650 psi 2.3 bpm 1.5klbs WOB 2750 BH AP. Drilled to 11200'. 23:15 - 00:00 0.75 DRILL PROD2 Start wiper trip to window. 4/18/2001 00:00 - 01:30 1.50 DRILL PROD2 Finish wiper trip. No problems. 01:30 - 02:45 1.25 DRILL PROD2 11200' drilling ahead 100+ fph, 3775 psi 2.3/2.3, 1.6 klbs WQB, 2775 BH AP. Drill to 11350'. 02:45 - 05:45 3.00 DRILL PROD2 Wiper trip to window. 05:45 - 06:05 0.33 DRILL PROD2 Stacking weight just off bottom. Drill to 11372'. Stacking weight. Can't get back to bottom 06:05 - 07:30 1.42 DRILL PROD2 Wiper trip to 10200'. Struggle with slide getting back to bottom. Also, looks like a small ledge at about 10630'. 07:30 - 08:30 1.00 DRILL PROD2 Drill to 11383'. Stacking. Pump fresh mud pill while waiting on new mud. Drill to 11500'. 08:30 - 12:30 4.00 DRILL PROD2 Wiper trip to 2000' at 2.8 BPM. Open cir¢ sub. RIH washing at 3.3 BPM out. 12:30 - 13:00 0.50 DRILL PROD2 Log tie-in at 8700'. Correct depth (+13'). RA at 9072'. 13:00 - 14:00 1.00 DRILL PROD2 RIH. Tag TD 11,510' corrected. 14:00 - 17:00 3.00 DRILL PROD2 Wiper to window while displacing well to new FIo-Pro. Open circ sub and POOH circulating 3.1 BPM. Bump up. E-counter at 60.2'. 17:00 - 17:30 0.50 DRILL PROD2 Freeze protect coil. 17:30 - 19:30 2.00 DRILL PROD2 LID BHA set back injector. 19:30 - 21:45 2.25 DRILL PROD2 PJSM. RID rig #4 coil from injector and R/U ROC 2 3/8" coil. Prep rig floor for running liner. 21:45 - 22:20 0.58 CASE COMP PJSM running liner and CSH inner string. 22:20 - 00:00 1.67 CASE COMP Make up 2 7/8" 6.16# STL Slotted liner. Printed: 5/1/2001 10:29:37AM BP EXPLORATION Page 10 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/19/2001 00:00 - 03:00 3.00 CASE COMP Continue M/U 2 7/8" 6.16# STL Slotted liner. ;03:00 - 06:30 3.50 CASE COMP Make up 1 1/4" CSH inner string. Stab into pack-off bushing, PU, and space-out. MU GS spear and 2-3/8" collar. Close 2-3/8" slip rams/ 06:30 - 07:00 0.50 CASE COMP Safety meeting. 07:00 - 09:00 2.00 CASE COMP Rehead. Pull test CTC. Fill coil with mud. MU disc, CV, cir¢ sub. 09:00 - 22:45 13.75 CASE COMP RIH. 28k up; 3k down at window. RIH. Sat down at 10110', but fell thru. Sat down hard at 10820' (good slide until here). Unable to work past. PU and GS unstung from liner. Spent the next two hours trying to latch liner, including pulling washstring up near liner top to wash profile. Finally latched, PU, and RIH clean past 10820'. Work liner to 10885'. PU and lost liner again. Took about 15 attempts to latch liner. Consider POOH to swap GS with CTLRT. Pull liner uphole to 10787'. Nope -- wrong idea. Pulled to 70k here. So much for getting liner back out; past point of no return. Continue working liner downhole, stacking to -20k. GS spear releases after every stack-out, but relatching becoming easier. Circulate 20 bbl slugs (2.5 BPM; 4000 psi) as needed when progress slows. Relatching more difficult after pumping and bleeding (must still be some minor flow across GS). Work pipe to 11,485'. TOL at 9030'. No further progress after a couple of pump and push cycles. 22:45 - 23:00 0.25 CASE COMP Unsting GS spear. 23:00 - 23:30 0.50 CASE COMP Safety meetng -- spotting bleach and displacing mud. 23:30 - 00:00 0.50 CASE COMP (EOP at 11445') Start displacement of FIo-Pro from wellbore w/50 bbl 9.2 ppg 3% KCL. 4/20/2001 00:00 - 01:00 1.00 CASE COMP Continue pumping 50 bbl 9.2 ppg 3% KCL, 35 bbl bleach, followed by 29 bbl KCL. Then lay-in bleach 1:1 f/11445' to 9050'. 01:00 - 01:30 0.50 CASE COMP Switch to KCL and displace remaining FIo-Pro from wellbore. 01:30 - 05:00 3.50 CASE COMP Circulate at min. rate and WO bleach. Getting 1'1 -- no losses. 05:00 - 05:45 0.75 CASE COMP Clean out to 11440'. Circulate out bleach to tiger tank. 05:45 - 08:00 2.25 CASE COMP TOH to 1 1/4" CSH tubing pumping at 1.2 bpm / 75 fpm. 08:00 - 09:00 1.00 CASE COMP Unstab. Finish filling coil with methanol. LD GS spear and MHA. 09:00 - 09:30 0.50 CASE COMP Safety meeting. 09:30 - 12:30 3.00 CASE COMP LD 75 jts 1-1/4" CSH. 12:30-13:00 0.50 CASE COMP RU on lA and PT to 2100 psi with diesel. Bled to 2050 psi in 15 minutes. Bleed to zero. 13:00 - 15:00 2.00 RIGD COMP Bring inj to floor. Install nozzle. Blow down ROC with N2. Leaving methanol down to 100'. Bleed-off. 15:00 - 16:00 1.00 RIGD COMP Pull inj to deck. Unstab ROC. 16:00 - 17:00 1.00 RIGD COMP Set BPV. 17:00 - 18:00 1.00 RIGD COMP Stab E-line coil in inj. 18:00 - 22:00 4.00 RIGD COMP R/D Dowell ROC unit and move off.. Clean 3S rig mud tanks. RID Dowell unit #4 take to Deadhorse for routine maintainence. 22:00 - 23:30 1.50 RIGD COMP I N/D BOP stack. Install wellhead cap and test to 3400 psi - okay. Nabors rig #3S released at 2300 hrs 4-20-01. Last report. Printed: 5/1/2001 10:29:37AM BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 5/25/2001 Time: 12:13:42 Page: I Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (TVD) Reference: 18' 08 1/8/2000 03:00 65.7 Well: MPH-08 Section (VS) Reference: Well (0.00N,0.00E,152.05Azi) Wellpath: MPH-08B Sur~ey Calculation Method: Minimum Curvature Db: Oracle .... : ...... :'~ ~--~': ' ....... . - -.~: _-_-_~' - :-~ :' 7- - ~ "- - - ~_-~ .... .... ~_ -:-~-~ ': ~ .- - ---- ~---_- :-~-_-~- ~ ---_- -:~_--_-~ --- ~ ~ - ~ -- ~-~ - ~--~ - _-~ ~_~- ~,~?-_~77:- -, --. ~-, ~.~- ~ ~ ~,~ ~-.-. -.~..-: ~ ~-~,~ :~.~. .... ~ ....... ......................... Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Gee Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: _ Site: M Pt H Pad TR-13-10 UNITED STATES - North Slope Site Position: Northing: 6008971.91 ft Latitude: 70 26 6.665 N From: Map Easting: 555404.91 ft Longitude: 149 32 53.895 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.43 dog Well: MPH-08 Slot Name: 08 MPH-08 Well Position: +N/-S 938.18 ft Northing: 6009918.79 ft Latitude: 70 26 15.891 N +E/-W 1186.61 ft Easting: 556584.40 ft Longitude: 149 32 19.068 W Position Uncertainty: 0.00 ff Wellpath: MPH-08B Drilled From: MPH-08BPB1 500292280802 Tie-on Depth: 9800.00 ft Current Datum: 18 · 08 1/8/2000 03:00 Height 65.68 ff Above System Datum: Mean Sea Level Magnetic Data: 4/4/2001 Declination: 26.31 de9 Field Strength: 57441 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ft ............. deg 0.00 0.00 0.00 152.05 Survey: MWD Start Date: 4/10/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 9800.00 4183.20 KOP 11445.00 4196.41 Projected to TD Survey MD lncl: ,,Azim: TVD,: .SSTVD.; N/S:, EfW; .' ' MapN MapE. : DLS ,VS . 9980.00 89.60 157.40 4195.91 4130.23 -4208.00 6720.89 6005762.31 563336.38 14.63 6867.25 10010.00 89.70 161.50 4196.09 4130.41 -4236.08 6731.42 6005734.31 563347.12 13.67 6896.99 10040.00 88.50 163.00 4196.56 4130.88 -4264.65 6740.56 6005705.81 563356.48 6.40 6926.52 10070.00 91.30 167.10 4196.62 4130.94 -4293.63 6748.30 6005676.90 563364.43 16.55 6955.74 10100.00 91.00 170.80 4196.01 4130.33 -4323.06 6754.05 6005647.51 563370.40 12.37 6984.43 10130.00 94.50 175.70 4194.57 4128.89 -4352.80 6757.57 6005617.80 563374.15 20.05 7012.36 10160.00 95.20 178.40 4192.04 4126.36 -4382.65 6759.11 6005587.96 563375.91 9.27 7039.45 10190.00 95.20 182.80 4189.32 4123.64 -4412.52 6758.80 6005558.10 563375.83 14.61 7065.68 10220.00 94.70 192.60 4186.72 4121.04 -4442.10 6754.79 6005528.49 563372.05 32.59 7089.94 10250.00 91.20 193.00 4185.18 4119.50 -4471.31 6748.16 6005499.23 563365.64 11.74 7112.63 10280.00 88.90 198.60 4185.15 4119.47 -4500.17 6739.99 6005470.32 563357.69 20.18 7134.29 10310.00 89.80 201.50 4185.49 4119.81 -4528.34 6729.71 6005442.07 563347.62 10.12 7154.36 10340.00 90.00 205.00 4185.55 4119.87 -4555.90 6717.87 6005414.42 563336.00 11.69 7173.16 9800.00 89.20 141.10 4183.20 4117.52 -4060.47 6620.61 6005909.06 563234.99 0.00 6689.93 9830.00 83.20 137.20 4185.19 4119.51 -4083.10 6640.17 6005886.58 563254.72 23.83 6719.09 9860.00 83.00 140.80 4188.79 4123.11 -4105.57 6659.71 6005864.25 563274.43 11.93 6748.10 9890.00 84.20 145.40 4192.14 4126.46 -4129.41 6677.60 6005840.56 563292.50 15.75 6777.54 9920.00 87.40 148.90 4194.34 4128.66 -4154.54 6693.83 6005815.56 563308.91 15.78 6807.34 BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 5/25/2001 Time: 12:13:42 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (TVD) Reference: 18: 08 1/8/2000 03:00 65.7 Well: MPH-08 Section (VS) Reference: Well (0.00N,0.00E,152.05Azi) Wellpath: MPH-08B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE DLS VS ft deg deg ff ft ft ft ft ff deg/100ff ft 10370.00 91.48 198.14 4185.16 4119.48 -4583.78 6706.85 6005386.46 563325.19 23.39 7192.62 10400.00 91.76 192.77 4184.31 4118.63 -4612.67 6698.86 6005357.51 563317.42 17.92 7214.40 10430.00 94.27 190.35 4182.73 4117.05 -4642.02 6692.86 6005328.13 563311.64 11.61 7237.51 10461.00 95.80 185.15 4180.01 4114.33 -4672.61 6688.69 6005297.51 563307.71 17.42 7262.57 10492.00 92.85 183.64 4177.67 4111.99 -4703.42 6686.27 6005266.69 563305.52 10.41 7288.66 10520.00 93.00 178.50 4176.24 4110.56 -4731.37 6685.70 6005238.74 563305.16 19.05 7313.08 10550.00 94.10 175.70 4174.38 4108.70 -4761.27 6687.21 6005208.85 563306.90 10.01 7340.20 10580.00 93.50 170.40 4172.39 4106.71 -4790.97 6690.83 6005179.18 563310.75 17.74 7368.14 10610.00 93.90 162.30 4170.45 4104.77 -4820.04 6697.89 6005150.17 563318.03 26.98 7397.12 10640.00 93.30 158.00 4168.57 4102.89 -4848.19 6708.06 6005122.09 563328.40 14.44 7426.76 10670.00 91.80 155.00 4167.23 4101.55 -4875.67 6720.01 6005094,71 563340.56 11.17 7456.63 10700.00 91.80 150.30 4166.29 4100.61 -4902.30 6733.78 6005068.19 563354,53 15.66 7486.61 10730.00 91.80 142.30 4165.35 4099.67 -4927.22 6750.40 6005043.39 563371.34 26.65 7516.42 10760.00 91.80 137.10 4164.41 4098.73 -4950.09 6769.79 6005020.68 563390.90 17.32 7545.70 10790.00 91.10 133.15 4163.65 4097.97 -4971.33 6790.95 6004999.60 563412.21 13.37 7574.38 10820.00 89.20 135.00 4163.57 4097.89 -4992.20 6812.50 6004978.90 563433.92 8.84 7602.92 10851.00 88.70 137.42 4164.14 4098.46 -5014.57 6833.94 6004956.69 563455.54 7.97 7632.73 10880.00 89.70 145.93 4164.54 4098.86 -5037.30 6851.91 6004934.10 563473.67 29.54 7661.23 10910.00 88.50 152.25 4165.01 4099.33 -5063.02 6867.31 6004908.50 563489.26 21.44 7691.17 10940.00 87.75 157.10 4165.99 4100.31 -5090.12 6880.13 6004881.51 563502.29 16.35 7721.11 10970.00 89.25 160.35 4166.78 4101.10 -5118.06 6891.01 6004853.65 563513.38 11.93 7750.90 11002.00 89.40 162.60 4167.16 4101.48 -5148.40 6901.18 6004823.39 563523.78 7.05 7782.46 11030.00 89.70 163.50 4167.38 4101.70 -5175.18 6909.34 6004796.68 563532.14 3.39 7809.94 11060.00 89.30 161.40 4167.64 4101.96 -5203.78 6918.39 6004768.15 563541.40 7.13 7839.45 11090.00 87.90 155.00 4168.37 4102.69 -5231.61 6929.52 6004740.41 563552.74 21.83 7869.25 11120.00 88.60 150.60 4169.29 4103.61 -5258.27 6943.22 6004713.85 563566.65 14.84 7899.23 11150.00 86.70 147.10 4170.52 4104.84 -5283.92 6958.72 6004688.32 563582.34 13.27 7929.15 11180.00 85.70 143.20 4172.51 4106.83 -5308.48 6975.82 6004663.89 563599.63 13.39 7958.86 11210.00 84.50 137.30 4175.07 4109.39 -5331.45 6994.93 6004641.07 563618.90 20.00 7988.10 11240.00 84.20 131.50 4178.03 4112.35 -5352.33 7016.25 6004620.36 563640.38 19.27 8016.54 11270.00 86.90 130.50 4180.36 4114.68 -5371.95 7038.82 6004600.91 563663.09 9.59 8044.45 11300.00 85.90 134.70 4182.24 4116.56 -5392.21 7060.85 6004580.82 563685.28 14.36 8072.68 11331.00 84.50 137,50 4184.84 4119.16 -5414.47 7082.27 6004558.73 563706.86 10.07 8102.37 11360.00 83.95 143.50 4187.76 4122.08 -5436.72 7100.61 6004536.62 563725.37 20.67 8130.63 11390.00 84.20 148.35 4190.86 4125.18 -5461.43 7117.33 6004512.04 563742.27 16.10 8160.29 11445.00 84.20 148.35 4196.41 4130.73 -5508.01 7146.04 6004465.68 563771.34 0.00 8214.89 BP Amoco Parent Wellpath: Tie on MD: Rig: Ref. Datum: V.Section Angle 152.05° WELLPATH DETAILS MPH-08BL1 500292280860 MPH-08A 9063.00 18: 08 1/812000 03:00 65.68ft Origin Origin Starting +N/-S +FJ.W From TVD 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: MPH-08, True North Vertical ('I-VD) Reference: System: Mean Sea Level Section (VS) Reference: User Defined (0.00N,0.00E) Measured Depth Reference: 18: 08 1/8/2000 03:00 65.68 Calculation Method: Minimum Curvature ANNOTATIONS T~.'~C~T TVD MD Annotation M~H~.~E~_I TlO. 1 ~4~_1T 102 .no. o^ ~ ~v~p L~:~H-O~L-1TI03 4~00 ~voq.~ ~.vv~ i~l~(~_1T104 41~0C0 ~47718 67504~ 4187.40 11510.00 Projo~edtoTD ~P,-o~l T~O 8~TD 4185 O0 2900 ~ ....... 3200 ;3300 13500 -,,3700 -2800 -3000 Azimuths to True North Magnetic North: 26.30' Magnetic Field Strength: 57442nT Dip Angle: 80.77° Date: 4/12/2001 Model: -3600 ,~.~-3800 o4000 .~.4200 ~O-4600 ~%~-4800 -5200' -5400 ....... '~.~"~-.~"% j MPH-O8 (MPH-OS) -560O -6200 Wellpath: (MPH-OSIMPH-OSBL1) Created By: Bdj Potnis Date: 5/2512001 Contact Information Direr: (907) 267-6613 E-mail. bdj potni$@inteq (;om Baker Hughes INTEQ: (907) 267-6600 ~4000~ '"-~,, ~ MPH-08 (MPH-08BPB1) MPH-08 (MPH-08APB 1). 4200 :: J: ~- '~ : Projected to 'rD j . 4300 ' ! MPH-OSBL1 i ' · . . Z MPH-O8 (MPH-O8)~ 4400 .... :_-M~_F~H_ _:0 8 {MP~-08A~ 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 6700 8800 8900 9000 9100 9200 9300 9400 Vertical Section at ~52,05° [~OOft/in] 5/25/2001 12:38 PM BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 5/2512001 Time: 12:09:02 Page: ! Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (T'v~) Reference: 18 · 08 1/8/2000 03:00 65.7 Well: MPH-08 Section (VS) Reference: Well (0.OON,0.00E,152.05Azi) Wellpath: MPH-08BPB1 Sur~ey Calculation Method: Minimum Curvature Db: Oracle ..... ~ ': -."'- ~: 77.~'- ' z--_'-"--:.:C~.-:::7'~:~:7~-: -- ' 7'--": 7; ---~-'_z~' -~'7-7.-'- :-~'" z~.~-~ ~.7 7-:'~ ~:7'c'" ~_" ZL '-' --:-':~ ~-~2;.'-- 7' ~ .'~- '7".- ---"7"~--~-_~-; ~'7-_7~'c~ '--~:-~7 -L: ..... : 7.~:.'- ' .-.: .... ~ ~7:' -:~- 7_ 7'-7 7' ~. ..... ~ ....... ~-: ....... Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Z~ne: Alaska, Zone 4 Ceo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: Site: M Pt H Pad TR-13-10 UNITED STATES · North Slope Site Position: Northing: 6008971.91 ft Latitude: 70 26 6.665 N From: Map Easting: 555404.91 ft Longitude: 149 32 53.895 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.43 deg Well: MPH-08 Slot Name: 08 MPH-08 Well Position: +N/-S 938.18 ft Northing: 6009918.79 ft Latitude: 70 26 15.891 N +E/-W 1186.61 ft Easting: 556584.40 ft Longitude: 149 32 19.068 W Position Uncertainty: 0.00 ft Wellpath: MPH-08BPB1 Drilled From: MPH-08A 500292280871 Tie-on Depth: 9084.00 ft Current Datum: 18 ' 08 1/8/2000 03:00 Height 65.68 ft Above System Datum: Mean Sea Level Magnetic Data: 4/4/2001 Declination: 26.31 deg Field Strength: 57441 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 152.05 Company: Baker Hughes INTEQ Engineer: Tool MWD MWD Standard Tied to. From Defintt~ve' Pat~ ~ ~. ~ : ' ' · : "'."i!., ',7~' i~' ...... ,:7 t'il/!~ i'"' ................................................................................................ ~ ...... :~' ........ ~ i" ~' :L...~, !, Annotat,on t~ ~ ~ .... fi' f: '; ' : ..... ' : :" ...... ': ? ,:i]: [;fl % "1, ~ , i,r' ~'{,}* ~ : ...... ........ ' 8'P .................... .......... .................... ' 10180 oo 4165 91Projected to TD ' Survey 9084.00 74.83 142.87 4156.08 4090.40 -3652.69 6050.61 6006312.46 562661.97 0.00 6062.56 9156.89 83.98 138.00 4169.47 4103.79 -3707.82 6096.22 6006257.68 562707.99 14.17 6132.63 9193.62 90.07 135.58 4171.38 4105.70 -3734.54 6121.32 6006231.16 562733.29 17.84 6168.00 9225.00 88.90 137.85 4171.66 4105.98 -3757.38 6142.83 6006208.48 562754.97 8.14 6198.26 9256.10 90.50 136.90 4171.82 4106.14 -3780.26 6163.89 6006185.76 562776.20 5.98 6228.34 9286.50 94.00 133.50 4170.63 4104.95 -3801.81 6185.29 6006164.38 562797.76 16.04 6257.41 9316.50 94.50 127.50 4168.41 4102.73 -3821.23 6208.03 6006145.13 562820.64 20.01 6285.22 9347.10 92.20 123.60 4166.62 4100.94 -3838.99 6232.88 6006127.57 562845.62 14.78 6312.55 9378.20 91.20 120.90 4165.69 4100.01 -3855.57 6259.16 6006111.18 562872.03 9.25 6339.52 9404.00 86.00 115.40 4166.32 4100.64 -3867.74 6281.89 6006099.20 562894.85 29.33 6360.92 9437.50 87.60 110.40 4168.20 4102.52 -3880.75 6312.69 6006086.42 562925.74 15.65 6386.85 9467.00 89.70 107.60 4168.89 4103.21 -3890.35 6340.57 6006077.03 562953.69 11.86 6408.39 9497.00 88.90 109.70 4169.26 4103.58 -3899.94 6368.99 6006067.66 562982.18 7.49 6430.19 9528.00 86.50 112.10 4170.50 4104.82 -3910.99 6397.92 6006056.83 563011.20 10.94 6453.51 9559.00 81.80 113.00 4173.66 4107.98 -3922.81 6426.40 6006045.23 563039.76 15.43 6477.30 9588.00 81.60 116.00 4177.85 4112.17 -3934.71 6452.51 6006033.53 563065.95 10.26 6500.04 9618.00 85.00 118.20 4181.35 4115.67 -3948.28 6479.02 6006020.16 563092.57 13.47 6524.46 9647.00 87.30 120.20 4183.29 4117.61 -3962.39 6504.28 6006006.24 563117.93 10.50 6548.77 BP Amoco Baker Hughes INTEQ Survey Report Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (TVD) Reference: 18: 08 1/8/2000 03:00 65.7 Well: MPH-08 Section (VS) Reference: Well (0.00N,0.00E,152.05Azi) Wellpath: MPH-08BPB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE DLS VS ff deg deg ff ff ff ff ff ff deg/lOOft ft 9677.00 90.80 123.50 4183.79 4118.11 -3978.22 6529.75 6005990.61 563143.52 16.03 6574.69 9709.00 91.40 128.40 4183.18 4117.50 -3996.99 6555.64 6005972.03 563169.55 15.42 6603.41 9737.00 89.30 132.30 4183.01 4117.33 -4015.12 6576.98 6005954.07 563191.02 15.82 6629.42 9767.00 90.40 135.30 4183.08 4117.40 -4035.88 6598.63 6005933.48 563212.82 10.65 6657.90 9800.00 89.20 141.10 4183.20 4117.52 -4060.47 6620.61 6005909.06 563234.99 17.95 6689.93 9828.00 90.30 142.90 4183.32 4117.64 -4082.53 6637.85 6005887.13 563252.39 7.53 6717.50 9857.00 91.50 145.50 4182.87 4117.19 -4106.05 6654.81 6005863.74 563269.53 9.87 6746.22 9887.00 89.20 147.30 4182.68 4117.00 -4131.03 6671.41 6005838.89 563286.32 9.74 6776.07 9918.00 89.40 151.10 4183.06 4117.38 -4157.65 6687.28 6005812.39 563302.39 12.27 6807.02 9947.00 92.00 152.90 4182.71 4117.03 -4183.25 6700.89 6005786.90 563316.19 10.90 6836.02 9981.00 95.12 157.00 4180.60 4114.92 -4213.98 6715.25 6005756.28 563330.79 15.13 6869.90 10007.00 94.60 160.20 4178.39 4112.71 -4238.10 6724.71 6005732.24 563340.42 12.43 6895.63 10038.00 94.20 161.80 4176.01 4110.33 -4267.33 6734.77 6005703.09 563350.70 5.31 6926.16 10068.00 94.50 167.00 4173.74 4108.06 -4296.13 6742.81 6005674.36 563358.96 17.31 6955.37 10097.00 94.10 170.00 4171.56 4105.88 -4324.46 6748.57 6005646.07 563364.94 10.41 6983.11 10127.00 93.80 173.30 4169.50 4103.82 -4354.07 6752.92 6005616.50 563369.51 11.02 7011.30 10147.00 93.90 173.20 4168.15 4102.47 -4373.89 6755.27 6005596.70 563372.01 0.71 7029.90 10180.00 93.90 173.20 4165.91 4100.23 -4406.58 6759.16 6005564.04 563376.15 0.00 7060.61 BP Amoco Parent Wellpath: Tie on MD: WELLPATH DETAILS MPH.-08BL1 500292280860 MPH-08A 90~3.00 18: 08 tl812000 03:00 65.68ft Origin Origin Starting +N/-S +E/-W From TVD 0.00 0.00 0.0~ REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: MPH-08, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: User Defined (0.OON,O.OOE) Measured Depth Reference: 18: 08 1/8/2000 03:00 65.68 Calculation Method: Minimum Curvature MPHA)8 (MPH-08) I J~ ~4 Azimuths to True North Magnetic North: 26.30° Magnetic Field Strength: 57442nT Dip Angle: 80.77° Date: 4/12/2001 Model: Wellpath: (MPH-081MPH-08BL1) Created By: Brij PotnisDa{e: 5/25/2001 Contact Information Direct: (907) 267-6613 E-mail: brij.polnisC~.~icteq corn Baker Hughes INTEQ (907) 267-6600 Rig: -2800 ~.. _ ~ _ . . Ref. Datum: ~ ' V.Secfion -3000 Angle _ 152'05° -3200- ~ 7 .... -3600 ':~- ANNOTATIONS T~-r ~[~'~,~ LS 'rvD MD Annotation ~W~.~.1TI01 4~7~ce-,370~4e ~Om~ F'-,~ -4000 1~17102 4!~3~-38T~41 ~ ~ ~1~104 41~0~ ~1~ ~ ~ 4187.40 11510.~ Pr~to~ ~T~o~ 4~ ~ ~ ~ ~IT~0~TD41~m ~21 71~70 ~ , ~-4~0 , :-:~ : 2900 -5200: ~ ....... 30~ ~; 2-: .... '~. , - ~...~ 31~[~. ....... : :::7::: -. . ........ - _ / 32~ ~ '. Pr~ to S ~200 .... ~ / ' 5~ I :: ......... ~ 46~ 4800 5~ 52~ ~o~- West(-)~ast(+) [200fflin] ~39~ ', - :~. .... . 42~ " - MPH~ 4300 j . . . ', ~ MP~8 (MP~), ~ ' ' ' 44~ ~ ....... - ..... 55~ ~00 5700 ~ 5~ ~00 6100 6200 6300 ~00 65~ ~ 67~ ~0 69~ 7~0 7100 7200 7300 74~ 75~ 7~ 7700 78~ 79~ 8~ 81~ 82~ 8300 Vedical Section at ~S2,0S' [~O~in] 5/25/200~ 12:38 PM ALASKA OIL AND GAS CONSERVA~I~ION COMPreSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark O Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 9951-6612 Re: Milne Point Unit MPH-08B BP Exploration (Alaska) Inc. Permit No' 201-047 Sur Loc: 2767'NSL, 4061'WEL, Sec. 34, T13N, R10E, UM Btmhole Loc. 1047'NSL, 1811'WEL, Sec. 01, T12N, R10E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / _~ ~4 day of March, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. A(. STATE OF ALASKA _~ ALASK ~IL AND GAS CONSERVATION COMIC.,. ,SION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Ddll [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone [] Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65.68' AMSL Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2767' NSL, 4061' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 4404' NSL, 3301' WEL, SEC. 01, T12N, R10E, UM MPH-08B Number 2S100302630-277 At total depth 9. Approximate spud date 1047' NSL, 1811' WEL, SEC. 01, T12N, R10E, UM 03/15/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well ;14. Number of acres in property 15. Proposed depth (MD and 'I-VD) ADL 380110, 1811' MDI No Close Approach 2560 13000' MD / 4127' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9110' MD Maximum Hole Angle 91 ° Maximum surface 1400 psig, At total depth (TVD) 4000'/1800 psig 18. Casing Program Specifications Setting Depih Size Top Bottom ..... Quantity of Cement Hole Casin,(] ' weight, Grade ,,cobplin,q L.en.(:lt'h' ' MD , TvD' MD TVD (inclu, de ~ta§e data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 4099' 9100' 4095' 13000; 4127' Uncemented Slotted Liner REr.;E!VFD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summaryM/]iR 0 1 Z 0 01 Total depth: measured 12164 feet Plugs (measured) true vertical 4235 feet Alaska 0il & Gas Cons. Commission Effective depth: measured 12164 feet Junk (measured) AnchOrage true vertical 4235 feet Casing Length Size Cemented MD 'TVD Structural Conductor 110' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 9222' 7" 2047 sx PF 'E', 263 sx 'G', 191 sx PF 'C' 9253' 4376' Intermediate Production Liner 981' 4-1/2" 46 sx Class 'G' 8436' - 9417' 3799' - 4183' Perforation depth: measured 4-1/2" Slotted Liner: 9047' - 9373' 6" Open Hole Completion: 9417' - 12164' true vertical 4-1/2" Slotted Liner: 4147' - 4184' 6" Open Hole Completion: 4183' - 4235' ~0. Attachments [] Filing Fee I-I Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie Hubble, 564'4628 21. I hereby certify that the foregoing, is true,a'i'r~ correct to the best of my knowledge / _/' Signed Mark Johnson :2/~/~'~.~, ~ ['".~~,.,~->.----"TitTe CT Drilling Engineer Date '~-/?_..z~/dJ fermit'~um~'r .... '"" ' I AP'I"Nun~'~ "" '"' .... '"'" .... ' ..... "" ' ..... i' 'ApproVal D~t~" 'l Seeco'~/er I I for other requirements Conditions of Approval: Samples Required [] Yes ~,No Mud Log Required [] Yes Hydrogen Sulfide Measures [] Yes 'l~l, No Directional Survey Required .~[[~,,Yes [] No Required Working Pressure for BOPE1~I2K [] 3K [] 4K [] 5K [] 10K [] 15K '~3.5K psi for OTU Other: by order of O~tG~A[.' SIGNED BY Commissioner the commission Date~-/,~T-_.-. ~/ Approved By ,'" Ii ,?T,~,",i,-,', r, ...... Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX Milne Point MPH-O8B & L1 Sidetracks - Coiled Tubing Drilling Summary of Operations: MPH-08A will be sidetracked with two horizontal wellbores (MPH-08B and MPH-08B L1) to target Schrader Bluff CA and OB reserves respectively. Coiled Tubing Ddlling (CTD) will perform the sidetracks. Backqround In February 2001, Nabors 4ES was unable to regain access to the existing horizontal wellbore (MPH-08A) below 9126' DPM due to apparently collapsed 4 %" slotted liner. As such, the plan is to set a cement plug to abandon the MPH-08A (sundry form 10-403 submitted) and then CTD drill MPH-08B in the CA sand (replace MPH-08A) and MPH-08B L1 in the OB sand. Procedures ~~2._ P&A Procedure {sundry form 10-403 already submitted) a) Set whipstock at 9110' in 4 %" slotted liner. - service coil ~.~,~--~, .~ _,. b) P&A MPH-08A by bullheading ~10 Bbls of 15.8 ppg class G cement from just above whipstock. L (The cement serves to plug off MPH-08A in the heel area to reduce mud losses while drilling and to further anchor the whipstock). - service coil CTD Drill and Complete MPH-08B pro,qram: Planned for March 15, 2001 1) MIRU CTD rig. Mill window through 4 %" and mill 5' of openhole 2) Drill horizontal sidetrack MPH-08B from window to TD (13,000') targeting Schrader Bluff CA / sand interval as per attached directional plan. "'Y" 3) Complete with slotted liner from TD (13000') to -10' inside of 4 %" casing at 9100'. CTD Drill and Complete MPH-08B L1 Lateral pro.qram: Planned for March 21, 2001 4) CTD set flowthrough whipstock at 9075' (in 4 %" casing at ~74° wellbore inclination) 5) Mill window through 4 ~" and mill 5' of openhole 6) Drill horizontal lateral MPH-08B L1 from window to TD targeting Schrader Bluff OB sand interval as per attached directional plan. 7) Complete with slotted liner from TD (13000') to --10' inside of 4 %" casing at 9065'. Mud Program: · Steps 1: Seawater · Steps 2-7: FIo-Pro (8.6-9.4 ppg) RECEIVED Disposal: · No annular injection on this well. · Class II liquids to KRU 1R Pad Class II disposal well · Class II drill solids to PBU DS-4 Grind & Inject · Class I wastes will go to Pad 3 for disposal. MAR 0 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Casing Program MPH-08B: · 2 7/8", 6.16#, L-80, STL slotted/pre perforated liner will be run from TD (13000') to approximately 9100'. Casing Program MPH-08B LI: · 2 7/8", 6.16#, L-80, STL slotted/pre perforated liner will be run from TD (13000') to approximately 9065'. Well Control: ° BOP diagram is attached. ° Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plans · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Resistivity logging in sections of the openhole Hazards Several small faults are expected to be crossed, but lost circulation risk is Iow based on MPH-08A drilling history. Res. pressure is 8.7 ppg. The latest H2S reading (April 2000) on MPH-08a was <2ppm. Highest H2S on the pad is 2.4 ppm (H-6i). Reservoir Pressure Res. pressure is approx. 1800psi @ 4000ss (8.7 ppg). Max. surface pressure with gas (0.1 psi/fi) to surface is 1400 psi. RECEIVED MAR 0'1 ZOOt Alaska Oil & Gas Cons. Commission Anchorage MPH-08B & L1 Potential Drilling Hazards Post on Rig . . . . . Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Aisc, if things don't feel right shut down the operation and discuss the situation before making the next operational move. SAFETY FIRST. H2S is not expected on this well. The latest H2S test on MPH-08a was <2ppm. Maximum H2S measured on the pad was from well H-6i at 2.4 ppm. MPH-08B sidetrack - BHP is expected to be less than 1788psi (8.6ppg) @ 4000'ss. The 4ES remedial work in 2~00 used 8.6 ppg fluid which maintained overbalance on the Schrader CA formation. As such, an 8.6 ppg FIo Pro system should be satisfactory for the MPH-08B horizontal (CA formation). MPH-08B sidetrack- close approach. As indicated in the directional plan, MPH-08B will come within 10' of intersecting MPH-08A at 10150' and MPH- 08APB1 at 10300' MD. Potential intersection is not expected to cause any problems. Both are barefoot holes (no steel) and will be at the same reservoir pressure. MPH-08B L1 sidetrack - BHP is expected to be approx. 1800psi (8.7ppg) @ 4000'ss as it has not been depleted in this area. Mud weight should be 9.2 ppg for this hole section based on the expected pressure. 6. Maximum anticipated well head pressure w/full column of gas is 1400psi. . Several faults (<15' throw) are expected to be crossed in the horizontal sections. However, lost circulation was not a problem when several similar faults were crossed during the drilling of MPH-08A (January 2000). However, be aware of the potential for lost circulation and maintain at least 600 lbs of Liquid Casing on location. RECEIVED ~q~R 0'1 2001 Alaska Oil & Gas Cons. Commission Anchorage BP Amoco WEL. LPATH DETAIL.S Plan#2 MPH-08B 500292280802 Parent Wellpath: MPH-08A Tie on MD: 9110.00 Vertical Section Origin: Slot- 08 (0.00,0.00) Vertical Section Angle: 152.05° Rig: Depth Reference: 18: 08 1/8/2000 03:00 65.68ft REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: MPH-08, True North Vertical ('rVD) Reference: System: Mean Se~ Levd Section (VS) Reference: Slot - 08 (0.00,0.00) Measured Depth Reference: 18: 08 1/8/2000 03:00 65.7 Calculation Method: Minimum Curvature ANNOTATIONS No. TVD MD ArmotalJo~ 1~4094.98 9102.00 T~e-h Poin~ 4096.93 9110.00 I~c~-off Point 3 4107.00 9193.14 1 4 4107.00 9343.14 2 654104.31 10183.14 ,~ 4102.71 10763.14 Z 4103.59 11163.14 5 8 4107.32 11663.14 6 g 4116.29 12363.14 7 104126.90 130~0.40 TD O I Weapelh: IVlPH-OS~) Azimuths to True North Magnetic North: 26.34° I C~a~ed ~. I~ Polnis Dale: 2./28/~X)1 Magnetic FieldJC¢m!3cl ~rdol~n.~liOn: Slrength: 57441nT DipAngle: 80.77°1 D;~J¢I: [90Y 267.6613 Date: 2r28/2001 J E-maih'hrij.Pomi~,-.,~,m.!ecl., om Model: BGGM2000 -36oo-~ 4 42 .. 4400 4600 4800 5000 5200 5400 5600 5800 6(~00 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 ~00 ~il~0 8800 9000 9200 6400 9600 West(-)/East(+) [20Oft/in] .... - ........ : ..... · .. : ........ ~ ..... .?~.:--!. ......... ! ............ i ............. ~ .......... t · :: -::-!.J .: / ....... ~, ........ i ..... '?,,.".\',h~':~-tO · ..... ' ...... . : ............ ::!:---:----..i.+.i ....... ~ , , .,...:........,,.......:....~ ! ........ ~ .......... ; ........ ), .......... ,..,~ ......... ' ' ' ' ' ........ :::!:::!:T::':~: ' 'rrrr[-r~TqTrnTrrrr[,,, ,J,,t, j ,, :'r!?.::'F'rrq..., ,,,j,, 'il/, "i'" 'i'''~ t'i' 'i ~/"l '~' 6000 6100 6200 6300 64~00 65~]0 660~ 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 6400 8500 8600 8700 8800 8900 Vertical Section at 152.05' [lOOft/in] 2/28/2001 12:02 PM BP Amoco ( Baker Hughes INTEQ Planning Report ComPany: IBP Amoco Field: Milne Point site: MPt H~Pad' Well: MPH-08 Wellpath: Plan#2 MPH-08B cO'Ordinate(NE) Reference: Well: MPH,08, TrUe North vertieal(TVD) Referenee: ~ SYStem:Mean: SeaLevel Section (VS) Reference: Well (0.00E,0.00N,152.05Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1866) Sys Datam: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: M Pt H Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008971.91 ft Latitude: 70 26 6.665 N 555404.91 ft Longitude: 149 32 53.895 W North Reference: True Grid Convergence: 0.43 deg Well: MPH-08 Slot Name: 08 MPH-08 Well Position: +NAS 938.18 ft Northing: 6009918.79 ft Latitude: 70 26 15.891 N +E/-W 1186.61 ff Easting: 556584.40 ft Longitude: 149 32 19.068 W Position Uncertainty: 0.00 ft LM ~: I WellPath: Plan#2 MPH-08B Drilled From: MPH-08A 500292280802 Tie-on Depth: 9110.00 ft Cnrrent Datum: 18: 08 1/8/2000 03:00 Height 65.68 ft Above System Datum: Mean Sea Level Magnetic Data: 2/28/2001 Declination: 26.34 deg Field Strength: 57441 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 152.05 Plan: Plan #2 Date Composed: 2/2812001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude -~> · <-- Longitude ---> Name Description TVD +N/-S +Et-W Northing Easting Dog Min Sec fl ff ft ft ff MPH-08B Polygon 2.1 0.00 -3325.19 5787.62 6006637.92 562396.52 70 25 43.166 -Polygon 1 0.00 -3325.19 5787.62 6006637.92 562396.52 70 25 43.166 -Polygon 2 0.00 -3303.40 6220.64 6006663.00 562829.32 70 25 43.377 -Polygon 3 0.00 -4206.76 7060.63 6005766.12 563676.06 70 25 34.486 -Polygon 4 0.00 -5093.15 7367.78 6004882.17 563989.90 70 25 25.765 -Polygon 5 0.00 -6219.63 7817.27 6003759.25 564447.88 70 25 14.682 -Polygon 6 0.00 -7082.57 7794.96 6002896.24 564432.12 70 25 6.195 -Polygon 7 0.00 -7282.71 7137.39 6002691.14 563776.15 70 25 4.234 -Polygon 8 0.00 -4754.46 6473.29 6005214.04 563092.95 70 25 29.104 -Polygon 9 0.00 -3549.76 5591.53 6006411.90 562202.16 70 25 40.959 MPH-08B T2.1 4100.00 -3642.13 6044.30 6006322.97 562655.57 70 25 40.047 Dog Min Sec N 149 29 29.278 W N 149 29 29.278 W N 149 29 16.574 W N 149 28 51.956 W N 149 28 42.972 W N 149 28 29.823 W N 149 28 30.503 W N 149 28 49.790 W N 149 29 9.198 W N 149 29 35.035 W N 149 29 21.755 W MPH-08B T2.3 4103.00 -4763.99 6814.06 6005207.09 563433.75 70 25 29.008 N 149 28 59.203 W MPH-08B T2.2 4107.00 -3830.28 6195.92 6006135.99 562808.60 70 25 38.196 N 149 29 17.312 W MPH-08B T2.4@TD 4127.00 -6906.15 7567.61 6003070.91 564203,46 70 25 7.933 N 149 28 37.165 W Annotation MD TVD ft ft 9102.00 4094.98 9110.00 4096.93 9193.14 4107.00 9343.14 4107.00 Tie-in Point Kick-off Point 1 2 BP Amoco ( Baker Hughes INTEQ Planning Repo~ i'~:i:i:~ ............................ .COmPany: Bp AMOCO Date: 2/28/2001 Time: 11:07i52 page: 2 Field: Milne Point Co-ordinate(NE)Reference: . Well: MPH~08, True North :site: M Pt:H Pad Vertical (TVD)'Reference: System: Mean.sea Level Well: MPH-08 Section ~¢S) Reference: Well (0.00E,0.OON,152.05Azi) Wellpath: Plan~2 MPH-OSB Snr~ey CalCutatinn Method: Minimum Curvature Db: Oracle Annotation 10183.14 4104.31 3 10763.14 4102.71 4 11163.14 4103.60 5 11663.14 4107.35 6 12363.14 4116.34 7 13000.40 4126.96 TD Plan Section Information MD Incl Azim TVD +N/-S +E/-W ff deg deg ff ff DLS Build Turn TFO Target ft degll00ft deglq 00ft degll00ft deg ....... ~J:i;~ ....... ~760- ..... 8-.0~ ........... -8.% ................. 9102.00 75.68 141.80 4094.98 -3666.47 6061.25 9110.00 76.14 141.33 4096.93 -3672.55 6066.07 8.10 5.75 -5.87 315.20 [=[J ~ 9193.14 90.00 125.00 4107.00 -3728.55 6126.04 25.61 16.67 -19.64 309.27 9343.14 90.00 110.00 4107.00 -3797.62 6258.71 10.00 0.00 -10.00 -90.00 Lr== 10183.14 90.30 194.00 4104.31 -4474.63 6618.69 10.00 0.04 10.00 89.70 10763.14 89.99 136.00 4102.72 -5011.25 6762.47 10,00 -0.05 -10.00 -90.20 11163.14 89.77 176.00 4103.62 -5369.29 6921.88 10.00 -0.06 10.00 90.35 11663.14 89.43 126.00 4107.37 -5792.84 7156.66 10.00 -0.07 -10.00 -90.55 12363.14 89.29 196.00 4116.36 -6414.25 7370.61 10.00 -0.02 10.00 90.55 13000.40 89.00 132.25 4127.00 -6996.00 7536.00 10.00 -0.05 -10.00 -90.76 Survey MD lncl A~m SSTVD N/S E~V MapN MapE DLS VS TFO Tool ff deg. deg ff ff ff ff ff degllOOff ff deg 9102.00 75.68 141.80 4094.98 -3666.47 6061.25 6006298.76 562672.71 0.00 6079.71 0.00 Tie-in 9110.00 76.14 141.33 4096,93 -3672,55 6066.07 6006292.72 562677.58 8.10 6087.34 315.20 Kick-o 9125.00 78.59 138.30 4100.21 -3683.73 6075.51 6006281.61 562687.10 25.61 6101.65 309.27 MWD 9150.00 82.74 133.35 4104.27 -3701.41 6092.70 6006264.07 562704A2 25.61 6125.32 309.93 MWD 9175.00 86.94 128.50 4106.52 -3717.71 6111.50 6006247.91 562723.35 25.61 6148.53 310.74 MWD 9193.14 90.00 125.00 4107.00 -3728.55 6126.04 6006237.18 562737.96 25.63 6164.92 311.17 1 9200.00 90.00 124.31 4107.00 -3732.45 6131.68 6006233.32 562743.63 10.00 6171.01 270.00 MWD 9225.00 90.00 121.81 4107.00 -3746.09 6152.63 6006219.85 562764.69 10.00 6192.88 270.00 MWD 9250.00 90.00 119.31 4107.00 -3758.80 6174.16 6006207.30 562786.30 10.00 6214.20 270.00 MWD 9275.00 90.00 116.81 4107.00 -3770.56 6196.22 60'06195.71 562808.45 10.00 6234.92 270.00 MWD 9300.00 90.00 114.31 4107.00 -3781.35 6218.77 6006185.09 562831.08 10.00 6255.02 270.00 MWD 9325.00 90.00 111.81 4107.00 -3791.14 6241.77 6006175.48 562854.15 10.00 6274.45 270.00 MWD 9343.14 90.00 110.00 4107.00 -3797.62 6258.71 6006169.13 562871.14 10.00 6288.12 270.00 2 9350.00 90.00 110.69 4107.00 -3800.00 6265.14 6006166.79 562877.59 10.00 6293.24 89.70 MWD 9375.00 90.02 113.19 4107.00 -3809.34 6288.33 6006157.63 562900.85 10.00 6312.36 89.70 MWD 9400.00 90.03 115.69 4106.99 -3819.68 6311.09 6006147.46 562923.68 10.00 6332.16 89.70 MWD 9425.00 90.04 118.19 4106.97 -3831.01 6333.38 6006136.31 562946.05 10.00 6352.61 89.70 MWD 9450.00 90.06 120.69 4106.95 -3843.29 6355.15 6006124.19 562967.91 10.00 6373.66 89.70 MWD 9475.00 90.07 123.19 4106.92 -3856.52 6376.36 6006111.13 562989.22 10.00 6395.29 89.71 MWD 9500.00 90.08 125.69 4106.89 -3870.65 6396.98 6006097.15 563009.94 10.00 6417.44 89.71 MWD 9525.00 90.09 128.19 4106.85 -3885.67 6416.96 6006082.28 563030.04 10.00 6440.07 89.71 MWD 9556.00 90.11 130.69 4106.81 -3901.55 6436.27 6006066.55 563049.46 10.00 6463.15 89.71 MWD 9575.00 90.12 133.19 4106.76 -3918.26 6454.86 6006049.99 563068.18 10.00 6486.62 89.72 MWD 9600.00 90.13 135.69 4106.70 -3935.76 6472.71 6006032.63 563086.16 10.00 6510.45 89.72 MWD 9625.00 90.14 138.19 4106.64 -3954.02 6489.78 6006014.50 563103.37 10.00 6534.58 89.73 MWD 9650.00 90.15 140.69 4106.58 -3973.01 6506.04 6005995.63 563119.77 10.00 6558.97 89.74 MWD 9675.00 90.16 143.19 4106.51 -3992.70 6521.45 6005976.07 563135.33 10.00 6583.58 89.74 MWD 9700.00 90.18 145.69 4106.44 -4013.03 6535.99 6005955.85 563150.02 10.00 6608.36 89.75 MWD 9725.00 90.19 148.19 4106.36 -4033.98 6549.63 6005935.00 563163.81 10.00 6633.26 89.76 MWD 9750.00 90.20 150.69 4106.27 -4055.50 6562.34 6005913.58 563176.69 10.00 6658.23 89.76 MWD 9775.00 90.21 153.19 4106.19 -4077.56 6574.10 6005891.61 563188.61 10.00 6683.23 89.77 MWD 9800.00 90.21 155.69 4106.10 -4100.11 6584.89 6005869.15 563199.57 10.00 6708.21 89.78 MWD BP Amoco ', '~'" R~~l~ INTEQ Planning Report ])ate: 2j28/200t Thn¢: 11:07:52 eage:i 3 CompaaY:Field: BPMilneAm~Opoint MAR 0 1 Z001 C~rS~a~NE) Referent: Well: MPH-~, Tree Noah Site: : · M Pt H Pad Ve~a~l (~)Referen~t System: M~n sea LeVel W~: ~H-~ Section ~/S) Referent: W~l (0.00E,0.00N,152.05~) Wellpath: Pla~2 MPH-~B Alaska 0il ~ ~as C~s, ~mmi~si0n survey Ca~U~n Me~: Minimum Cu~amre 9b: Or~e Survey MI) lncl Azim SsTVD NIS E/W MapN MapE DLS' VS TFO Tool fi: ' deg ~ idegi.' :: : ft: 'ft ft ' ft ft deg/100ft:: ft deg 9825.00 90.22 158.19 4106.00 -4123.11 6594.68 6005846.22 563209.54 10.00 6733.11 89.79 MWD 9850.00 90.23 160.69 4105.90 -4146.52 6603.46 6005822.89 563218.49 10.00 6757.90 89.80 MWD 9875.00 90.24 163.19 4105.80 -4170.28 6611.21 6005799.18 563226.42 10.00 6782.53 89.81 MWD 9900.00 90.25 165.69 4105.69 -4194.37 6617.92 6005775.16 563233.31 10.00 6806.95 89.82 MWD 9925.00 90.25 168.19 4105.58 -4218.72 6623.57 6005750.85 563239.15 10.00 6831.10 89,83 MWD 9950.00 90.26 170.69 4105.47 -4243.29 6628.15 6005726.32 563243.92 10.00 6854.96 89.84 MWD 9975.00 90.27 173.19 4105.35 -4268.04 6631.66 6005701.59 563247.61 10.00 6878.47 89.85 MWD 10000.00 90.27 175.69 4105.24 -4292.92 6634.08 6005676.74 563250.22 10.00 6901.58 89.86 MWD 10025.00 90.28 178.19 4105.11 .4317.88 6635.42 6005651.79 563251.75 10.00 6924.26 89.88 MWD 10050.00 90.28 180.69 41 04.99 .4342.88 6635.67 6005626.80 563252.19 10.00 6946.45 89.89 MWD 10075.00 90.29 183.19 4104.87 .4367.86 6634.82 6005601.81 563251.53 10.00 6968.13 89.90 MWD 10100.00 90.29 185.69 4104.74 -4392.79 6632.89 6005576.87 563249.79 10.00 6989.24 89.91 MWD 10125.00 90.29 188.19 4104.61 -4417.60 6629.87 6005552.04 563246.96 10.00 7009.74 89.93 MWD 10150.00 90.30 190.69 4104.49 .4442.26 6625.77 6005527.35 563243.05 10.00 7029.61 89.94 MWD 10175.00 90.30 193.19 4104.36 -4466.72 6620.60 6005502.86 563238.06 10.00 7048.79 89.92 MWD 10183.14 90.30 194.00 4104.31 -4474.63 6618.69 6005494.93 563236.21 10.00 7054.88 89.94 3 10200.00 90.29 192.31 4104.22 -4491.05 6614.85 6005478.49 563232.50 10.00 7067.58 269.80 MWD 10225.00 90.28 189.81 4104.10 .4515.58 6610.06 6005453.92 563227.89 10.00 7087.01 269.79 MWD 10250.00 90.27 187.31 4103.97 .4540.30 6606.33 6005429.18 563224.35 10.00 7107.10 269.78 MWD 10275.00 90.26 184.81 4103.86 -4565.16 6603.69 6005404.30 563221.90 10.08 7127.82 269.77 MWD 10300.00 90.25 182.31 4103.74 -4590.11 6602.14 6005379.35 563220.54 10.00 7149.13 269.75 MWD 10325.00 90.24 179.81 4103.64 -4615.10 6601.67 6005354.35 563220.26 10.00 7170.99 269.74 MWD 10350.00 90.23 177.31 4103.53 .4640.09 6602.30 6005329.37 563221.08 10.00 7193.36 269.73 MWD 10375.00 90.22 174.81 4103.44 .4665.03 6604.02 60,05304.45 563222.98 10.00 7216.19 269.72 MWD 10400.00 90.20 172.31 4103.34 -4689.87 6606.82 6005279.63 563225.97 10.00 7239.45 269.71 MWD 10425.00 90.19 169.81 4103.26 -4714.56 6610.70 6005254.97 563230.04 10.00 7263.08 269.70 MWD 10450.00 90.18 167.31 4103.18 -4739.06 6615.66 6005230.51 563235.19 10.00 7287.05 269.69 MWD 10475.00 90.16 164.81 4103.10 -4763.33 6621.68 6005206.29 563241.39 10.00 7311.30 269.69 MWD 10500.00 90.15 162.31 4103.03 -4787.30 6628.75 6005182.38 563248.64 10.00 7335.80 269.68 M WD 10525.00 90.14 159.81 4102.97 -4810.95 6636.86 6005158.79 563256.93 10.00 7360.49 269.67 MWD 10550.00 90.12 157.31 4102.91 -4834.22 6646.00 6005135.60 563266.25 10.00 7385.32 269.67 MWD 10575.00 90.11 154.81 4102.86 -4857.07 6656.14 6005112.83 563276.56 10.00 7410.26 269.66 MWD 10600.00 90.09 152.31 4102.82 -4879.45 6667.27 6005090.53 563287.86 10.00 7435.25 269.66 MWD 10625.00 90.08 149.81 4102.78 -4901.33 6679.36 6005068.75 563300.12 10.00 7460.25 269.65 MWD 10650.00 90.06 147.31 4102.76 -4922.66 6692.40 6005047.52 563313.31 10.00 7485.20 269.65 MWD 10675.00 90.04 144.81 4102.73 -4943.40 6706.36 6005026.89 563327.42 10.00 7510.06 269.64 MWD 10700.00 90.03 142.31 4102.72 -4963.51 6721.20 6005006.89 563342.42 10.00 7534.78 269.64 MWD 10725.00 90.01 139.81 4102.71 -4982.95 6736.91 6004987.57 563358.28 10.00 7559.32 269.64 MWD 10750.00 90.00 137.31 4102.70 -5001.69 6753.46 6004968.96 563374.96 10.00 7583.63 269.64 MWD 10763.14 89.99 136.00 4102.72 -5011.25 6762.47 6004959.47 563384.04 10.00 7596.30 269.67 4 10775.00 89.98 137.19 4102.72 -5019.87 6770.62 6004950.92 563392.26 10.00 7607.73 90.35 MWD 10800.00 89.97 139.69 4102.73 -5038.57 6787.20 6004932.34 563408.98 10.00 7632.02 90.35 MWD 10825.00 89.95 142.19 4102.75 -5057.98 6802.96 6004913.05 563424.88 10.00 7656.55 90.35 MWD 10850.00 89.94 144.69 4102.78 -5078.06 6817.85 6004893.09 563439.93 10.00 7681.27 90.35 MWD 10875.00 89.92 147.19 4102.81 -5098.77 6831.85 6004872.49 563454.08 10.00 7706.13 90.34 MWD 10900.00 89.91 149.69 4102.84 -5120.07 6844.94 6004851.29 563467.33 10.00 7731.07 90.34 MWD 10925.00 89.89 152.19 4102.89 -5141.92 6857.08 6004829.54 563479.64 10.00 7756.07 90.34 MWD 10950.00 89.88 154.69 4102.94 -5164.27 6868.26 6004807.27 563490.98 10.00 7781.06 90.33 MWD 10975.00 89.86 157.19 4102.99 -5187.10 6878.45 6004764.52 563501.35 10.00 7806.00 90.33 MWD 11000.00 89.85 159.69 4103.06 -5210.35 6887.64 6004761.35 563510.71 10.00 7830.84 90.32 MWD 11025.00 89.84 162.19 4103.12 -5233.98 6895.81 6004737.78 563519.05 10.00 7855.54 90.32 MWD 11050.00 89.82 164.69 4103.20 -5257.94 6902.93 6004713.88 563526.36 10.00 7880.05 90.31 MWD 11075.00 89.81 167.19 4103.28 -5282.18 6909.01 6004689.68 563532.62 10.00 7904.31 90.30 MWD BP Amoco ~' ;:" Baker Hughes INTEQ Planning Report ~.~.~.:~:~ CompanY:BP Amoco: Date:: 2/28/200! ' Timel 11:07;52 Page: 4 Field: Milne Point Co-ordinate~NE) Reference:: Well: MPH.08, TrueNorth: site: : M :Pt H'Pad : VertiCal (TVD)Reference: SYstem:::Mean sea'LeVel Well: MPH-08 SeeOon (VS) Reference: Well (0~00E,0.00N,152205Azi) Weilpath: Plarff~2 MPH,08B Snrvey Calcalafien Mettmd: .MinimUm Curvature: Db: Oracle Survey MI) lnCl Azim SSTVD NIS E/W MapN:: MapE DLS VS TF0 , · ft ::deg : ft : ' :ft . ft ' ft ft' deg/100ft deg 11100.00 89.80 169.69 4103.36 -5306.67 6914.02 6004665.23 563537.82 10.00 7928.29 00.20 MWD 11125.00 89.79 172.19 4103.45 -5331.36 6917.96 6004640.58 563541.94 10.00 7951.95 90.29 MWD 11150.00 89.77 174.69 4103.55 -5356.19 6920.82 6004615.77 563544.99 10.00 7975.22 90.28 MWD 11163.14 89.77 176.00 4103.62 -5369.29 6921.88 6004602.69 563546.15 10.00 7987.29 90.15 5 11175.00 89.76 174.81 4103.67 -5381.11 6922.83 6004590.87 563547.19 10.00 7998.18 269.45 MWD 11200.00 89.74 172.31 4103.78 -5405.95 6925.63 6004566.06 563550.18 10.00 8021.43 269.45 MWD 11225.00 89.71 169.81 4103.90 -5430.65 6929.51 6004541.39 563554.25 10.00 8045.07 269.47 MWD 11250.00 89.69 167.31 4104.03 -5455.15 6934.47 6004516.93 563559.39 10.00 8069.04 269.48 MWD 11275.00 89.67 164.81 4104.17 -5479.41 6940.49 6004492.72 563565.60 10.00 8093.29 269.49 MWD 11300.00 89.65 162.31 4104.32 -5503.39 6947.56 6004468.80 563572.85 10.00 8117.78 269.51 MWD 11325.00 89.63 159.81 4104.48 -5527.03 6955.68 6004445.22 563581.14 10.00 8142.47 269.52 MWD 11350.00 89.61 157.31 4104.65 -5550.30 6964.81 6004422.02 563590.45 10.00 8167.31 269.54 MWD 11375.00 89.59 154.81 4104.82 -5573.15 6974.95 6004399.26 563600.76 10.00 8192.24 269.55 MWD 11400.00 89.57 152.31 4105.01 -5595.53 6986.08 6004376.96 563612.06 10.00 8217.23 269.57 MWD 11425.00 89.55 149.81 4105.20 -5617.41 6998.18 6004355.18 563624.32 10.00 8242.23 269.59 MWD 11450.00 89.53 147.31 4105.40 -5638.73 7011.21 6004333.95 563637.52 10.00 8267.18 269.61 MWD 11475.00 89.52 144.81 4105.61 -5659.47 7025.17 6004313.32 563651.63 10.00 8292.04 269.63 MWD 11500.00 89.50 142.31 4105.82 -5679.58 7040.01 6004293.33 563666.62 10.00 8316.76 269.65 MWD 11525.00 89.49 139.81 4106.04 -5699.03 7055.72 6004274.00 563682.48 10.00 8341.30 269.67 MWD 11550.00 89.48 137.31 4106.26 ~5717.77 7072.27 6004255.39 563699.16 10.00 8365.61 269.69 MWD 11575.00 89.46 134.81 4106.50 -5735.77 7089.61 6004237.52 563716.64 10.00 8389.64 269.71 MWD 11600.00 89.45 132,31 4106.73 -5753.00 7107.72 6004220.44 563734,88 10,00 8413.35 269.74 MWD 11625.00 89.44 129.81 4106.97 -5769.42 7126.57 6004204.16 563753.85 10.00 8436.68 269.76 MWD 11650.00 89.44 127.31 4107.22 -5785.00 7146.12 6004188.73 563773.51 10.00 8459.61 269.79 MWD 11663.14 89,43 126.00 4107.37 -5792.64 7156.66 6004180.97 563784.12 10.00 8471.48 269.77 6 11675.00 89.42 127.19 4107.49 -5799.91 7166.18 6004173.97 563793.69 10.00 8482.19 90.55 MWD 11700.00 89.40 129.69 4107.75 -5815.45 7185.76 6004158.58 563813.38 10.00 8505.09 90.54 MWD 11725.00 89.37 132.19 4108.02 -5831.83 7204.65 6004142.35 563832.39 10.00 8528.41 90.51 MWD 11750.00 89.35 134.69 4108.29 -5849.01 7222.80 6004125.31 563850.67 10.00 8552.10 90.49 MWD 11775.00 89.33 137.19 4108.58 -5866.97 7240.18 6004107.48 563868.19 10.00 8576.11 90.46 MWD 11800.00 89.32 139.69 4108.87 -5885.68 7256.76 6004088.90 563884.91 10.00 8600.41 90.43 MWD 11825.00 89.30 142.19 4109.18 -5905,09 7272.52 6004069.62 563900.81 10.00 8624,93 90.40 MWD 11850.00 89.28 144.69 4109.49 -5925.16 7287.41 6004049.66 563915.85 10.00 8649.65 90.37 MWD 11875.00 89.27 147,19 4109.80 -5945.87 7301.41 6004029.06 563930.01 10.00 8674.50 90.34 MWD 11900,00 89.26 149.69 4110,12 -5967.17 7314.49 6004007.86 563943.25 10.00 8699.45 90.31 MWD 11925.00 89.25 152.19 4110.45 -5989.02 7326.63 6003986.11 563955.56 10.00 8724.44 90.27 MWD 11950.00 89.24 154,69 4110.78 -6011.37 7337.81 6003963.84 563966.90 10.00 8749.43 90.24 MWD 11975.00 89.23 157.19 4111.12 -6034.20 7348.00 6003941.09 563977.26 10.00 8774.37 90.21 MWD 12000.00 89.22 159.69 4111.45 -6057.44 7357.19 6003917.92 563986.63 10.00 8799.21 90.18 MWD 12025.00 89.22 162.19 4111.80 -6081.07 7365.35 6003894.36 563994.97 10.00 8823.90 90.14 MWD 12050.00 89.21 164.69 4112.14 -6105.03 7372.48 6003870.46 564002.27 10.00 8848.40 90.11 MWD 12075,00 89.21 167.19 4112.48 -6129.27 7378.55 6003846.26 564008.53 10.00 8872.67 90.07 MWD 12100.00 89.21 169.69 4112.83 -6153.76 7383.56 6003821.81 564013.73 10.00 8896.65 90.04 MWD 12125.00 89.21 172.19 4113.18 -6178.45 7387.50 6003797.16 564017.85 10.00 8920.30 90.00 MWD 12150.00 89.21 174.69 4113.52 -6203.28 . 7390.35 6003772.36 564020.89 10.00 8943.57 89.97 MWD 12175,00 89.21 177.19 4113.86 -6228.21 7392.12 6003747.44 564022.85 10.00 8966.43 89.93 MWD 12200,00 89.22 179.69 4114.21 .6253.20 7392.80 6003722.46 564023.72 10.00 8988.82 89.90 MWD 12225.00 89.23 182.19 4114.54 -6278.19 7392.39 6003697.47 564023.50 10.00 9010.70 89.87 MWD 12250.00 89.23 184.69 4114,88 -6303.14 7390.89 6003672.51 564022.19 10.00 9032.04 89.83 MWD 12275.00 89.24 187,19 4115.21 -6328.00 7388.31 6003647.63 564019.79 10.00 9052.79 89.80 MWD 12300.00 89.25 189.69 4115.54 -6352.73 7364.64 6003622.88 564016.31 10.00 9072.91 89.77 MWD 12325.00 89.27 192.19 4115.86 -6377.27 7379.89 6003598.31 564011.75 10.00 9092.37 89.73 MWD RECEIVED MAR 0"1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage ( BP Amoco Baker Hughes INTEQ Planning Report CompanY: BP Amoco Field: Milne Point site: · M Pt H pad Well: MPH-08 Wellpath: Plardf2 MPH-08B Dale: 2/28/2001 Time: 11:07:52 Page: 5 Co-ordinate(NE): Reference: Well: MPH-08, TrUe North VertiCal (TVl))Referefice: SYstei~! Mean sea Level Section (VS) Reference: Well (0.00E,0.00N, 152.05Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim SSTVD NIS EfW MapN MapE DLS VS: TFO Tool ft degl des ff . ft. : fi: ff ft :' ' deg/lOOff ft . d~ 12350.00 89.28 194.69 4116.18 -6401.58 7374.08 6003573.95 564006.13 10.00 9111.12 89.70 MWD 12363.14 89.29 196.00 4116.36 -6414.25 7370.61 6003561.26 564002.75 9.96 9120.68 89.59 7 12375.00 89.27 194.81 4116.51 -6425.68 7367.46 6003549.81 563999.69 10.00 9129.31 269.24 MWD 12400.00 89.24 192.31 4116.83 -6449.98 7361.60 6003525.47 563994.01 10.00 9148.02 269.25 MWD 12425.00 89.21 189.81 4117.17 -6474.51 7356.80 6003500.90 563989.40 10.00 9167.44 269.29 MWD 12450.00 89.18 187.31 4117.52 -6499.23 7353.08 6003476.16 563985.87 10.00 9187.53 269.32 MWD 12475.00 89.16 184.81 4117.68 -6524.09 7350.44 6003451.29 563983.42 10.00 9208.25 269.36 MWD 12500.00 89.13 182.31 4118.26 -6549.03 7348.88 6003426.33 563982.05 10.00 9229.56 269.39 MWD 12525.00 89.11 179.81 4118.64 .6574.02 7348.42 6003401.34 563981.78 10.00 9251.42 269.43 MWD 12550.00 89.08 177.31 4119.04 -6599.01 7349.05 6003376.36 563982.59 10.00 9273.79 269.47 MWD 12575.00 89.06 174.81 4119.44 -6623.95 7350.76 6003351.44 563984.50 10.00 9296.62 269.51 MWD 12600.00 89.04 172.31 4119.85 -6648.78 7353.57 6003326.63 563987.49 10.00 9319.87 269.55 MWD 12625.00 89.03 169,81 4120.27 -6673.47 7357.45 6003301.97 563991.56 10.00 9343.50 269.59 MWD 12650.00 89.01 167.31 4120.70 -6697.97 7362.40 6003277.51 563996.70 10.00 9367.47 269.63 MWD 12675.00 89.00 164.81 4121.13 -6722.23 7368.43 6003253.30 564002.91 10.00 9391.72 269.67 MWD 12700.00 88.99 162.31 4121.57 -6746.20 7375.50 6003229.39 564010.16 10.00 9416.21 269.72 MWD 12725.00 88.98 159.81 4122.02 -6769.84 7383.61 6003205.81 564018A5 10.00 9440.89 269.76 MWD 12750.00 88.97 157.31 4122.47 -6793.11 7392.75 6003182.62 564027.76 10.00 9465.73 269.81 MWD 12775.00 88.97 154.81 4122.92 -6815.95 7402.89 6003159.85 564038.07 10.00 9490.66 269.85 MWD 12800.00 88.96 152.31 4123.37 -6838.33 7414.02 6003137.56 564049.37 10.00 9515.64 269.90 MWD 12825.00 88.96 149.81 4t23.82 -6860.20 7426.11 6003115.78 564061.63 10.00 9540.63 269.94 MWD 12850.00 88.96 147.31 4124.28 -6881.53 7439.15 6003094.56 564074.83 10.00 9565.58 269.99 MWD 12875.00 88.96 144.81 4124.73 -6902.26 7453.10 6003073.93 564088.94 10.00 9590.44 270.03 MWD 12900.00 88.97 142.31 4125.18 -6922.37 7467.95 6003053.94 564103.94 10.00 9615.16 270.08 MWD 12925.00 88.97 139.81 4125.63 -6941.81 7483.66 6003034.62 564119.79 10.00 9639.69 270.12 MWD 12950.00 88.98 137.31 4126.08 -6960.55 7500.20 6003016.02 564136.47 10.00 9664.00 270.17 MWD 12975.00 88.99 134.80 4126.52 -6978.54 7517.55 6002998.15 564153.95 10.03 9688.02 270.16 MWD 13000.00 89.00 132.29 4126.96 -6995.76 7535.66 6002981.07 564172.20 10.03 9711.73 270.21 MWD RECEIVED MAR 0 1 2001 Alaska Oil & Gas Cons. Commission Anchorage 25 g MPH~08B L1) i i i i 9000 9500 10000 10500 11000 11500 12000 12500 13000 Measured Depth [fi] ~ MPH-08 (Plan#8 MPH-08BL1) ] ,, MPH-08 (MPH-08A) MPH-08 (MPH-08APB1) I ii Tree: 4.5" 5MM P U H 08a o,,. ~ ~,~v._- ..~, <, Wellhead: 11" 5M FMC Gen 6 " Orig. GL Elev. = 36.0' 4.5" 8rd. EUE bottom and top, """ '"- ' '"-- "' "' RT To Tbg. Spool = 30.6' (N 22E) 4.5" ClW BPV profile. 20"91.1ppf, H-40 I 115' Ij i ! KOP @ 300' Max. hole angle = 78 to 80 deg. . fl 3600' to 7450' i Hole angle thru' perfs = Hofizonta~l. 4.5" 12.6 ppf,L-80 IBT mod tubing ( ddft ID = 3.958", cap = 0.0152 bpf) 7" 26 ppf, L-80, BTC mod production csg. ( drift ID -- 6.276", cap. = 0.0383 bpf) i : 4.5" Baker S-3 packer I 0308' ' i 4.5"HESXNnipple3.725"idl 8421'I BakerZXP Linertop packer i 8421' ,,,e~ ~-~,~" ,~n~ow at ~'-~00' <~ ~'~ Iw,~, tie back (5.25" ID) '.. ' ..-- ~i' ' Baker5x7 HMCliner I" 8436' I · hanger (4.375" ID) I I 4.5"12.6#,L-801BT !;::=i SakerHMCVcementvalve I 8961' I TD 13000' ~, . "p nhole ~~ · -~_......---. T J I~ [~ 3.75" Openhole. TD 13000' Co. ilC_ADE estimated TD ]/ ~~ ~~ I ......... i / ~ 4.5" Baker drillable I" ' -11800' b°m n°riz°ma's ' L~,,,~O ~ind ~o~he~ 121~ DATE REV. BY COMMENTS MILNE POINT UNIT 10-01-97 JBF Drilled and Cased by Nabors 22E WELL No: H-08A 6/20/98 M. Linder Frac and completion by Nabors 4-ES APl: 50-029-22808-01 '12/19/99 M. Linder P&A well for sidetrack 4-E$ 1/19/00 M. Linder Sidetrack completion for iet pump 2/25/01 MOJ Proposed H-08B & L1 (Post CTD) BP EXPLORATION {AK! RECEIVED MAR 0" 1 ZOO1 Alaska Oil & Gas Cons. Commission, Anchorage Tree: 4.5" 5M Wellhead: 11" 5M FMC Gen 6 4.5" 8rd. EUE bottom and top, 4.5" CIW BPV profile. 20" 91.1 ppf, H-40 KOP @ 300' Max. hole angle = 78 to 80 deg. f/3600' to 7450' Hole angle thru' perfs = Horizontal MPU H-08a Orig. KB Elev. = 64.9' (N 22E) Orig. GL Elev. = 36.0' RT To Tbg. Spool = 30.6' (N 22E) 4.5" 12.6 ppf, L-80 IBT mod tubing ( ddft ID = 3.958", cap = 0.0152 bpf ) 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) Stimulation Summary Milled 6-1/8" window at 8588'-8600' (12') 4.5" HES 'XD' sliding sleeve 3.813"1D shifts down to open 8330' 4.5"Baker S-3 packer I 8398' 4.5" HESXN nipple 3.725" id I 8421' WLEG I 8433' Baker ZXP Liner top packer w/6' tie back (5.25" ID) I 8421' Baker 5'x7" HMC liner I 8436' hanger (4.375" ID) Baker HMCV cement valve I 8961' BakerCTC 20' PZP ECP I 8979' 14its of 4.5", 12.6~ L-801BT Solid liner. RECEIVE MAR 0" 1 ZOO Alaska Oil & Gas Cons, Anohm'~xje 8 jts of 4.5' 12.6#, L-80 IBT Slotted liner from 9047'-9373' 4.5" Baker drillable pack off bushing I 9373' 4.5" Baker drillable guide shoe I 9417' DATE 10-01-97 REV. BY JBF Open hole to 12164' COMMENTS Drilled and Cased by Nabors 22E 6/20/98 M. Linder Frac and completion by Nabors 4-ES 12/19/99 M. Linder P&A well for sidetrack 4-ES 1/19/00 M. Under Sidetrack completion for jet pump MILNE POINT UNIT WELL No · H-08A APl: 50-029-22808-01 i i , BP EXPLORATION IAK~ 3S CTD BOP Detail Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol injection ~T~ I- 7''Riser otis 7" WLA Quick Connect ~ 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure IBlindlShear 1 2 318" Combi PipelSli~ Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpip~ manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE [ 0.[. Manual over Hydraulic T 2" Side outlets I, 2 7/8" Combi Pipe/Slip 2 318" Combi Pipe/Slip XO Spool as necessary Single Manual Master Valve 2 flanged gate valves MOJ 12/29/00 Tubing Spool 7" Annulus 9 5/8" Annulus RECEIVED r~/~R 0,i 2001 Alaska Oil & Gas Cons. Commission Anchorage I DATE I I CHECK NO. H1._82852 I I VENDOR ALAS½AO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 3'12901 CKO129OlC 1OO. OO 1OO. OO PYMT (OMMENTS: Pe~'~it To D~-ill Fee HANDLING INST: S/H - Te~'~'ie Hubt le X4&A8 IE AWACHED CHECK IS IN PAYME~ FOR ~ DE~RI~EO A~VE. mKe]fil~ ] 1OO. OO 1OO. OO IIm~285211' m'-Ok~ 20:;8~5m". O0~.kt,&q,' , , WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION ENGINEERING GEOLOGY AP. PR I~A~TE COMPANY ~_ _P,)( WELL NAM F~,J~'*~ ¢~ INIT CLASS ~,~/.,~ Y-,m,? Gl 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available' in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... PROGRAM:exp~ -~L AREA N YIN dev ? redrll ,,.'~ serv~ <~'? ~:) UNIT# wellbore seg ~ ann. disposal para req ~ ON/OFF SHORE C~ Y Y Y Y Y Y Y Y Y Y ¥ Y Y N N N N N. N N N N N N N 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ Yj~ N~/,%~::::~.%-~ ~,~ 18. CMT will cover all known productive horizons .......... ~"--~.~-' 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. ~ N 21. If a re-drill, has a 10-403 for abandonment been approved... ~..~N ..... 22. Adequate wellbore separation proposed .............. 'Yd~N . . 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate .... . ~ ~ ~ ~__ _ 25. BOPEs, do they meet regulation ...... :......,~.. ..... 26. BOPE press rating appropriate; test to _.4,~,,._~ Dsig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... ,'~ 29. ,, presence of H2S gas probable ................. Yy N~" ~". "~ / 30. Permit can be issued w/o hydrogen sulfide measures ...... 31. Data presented on potential overpressure zones ....... ~NY I~/ 32. Seismic analysis of shallow gas zones .............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory onl/y] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G. EOLOG.Y:. ENGINEERING: UlC/Annular COMMISSION: 8 s, JMH ~ 5ji~, )01 ' Comments/Instructions: 0 Z 0 c:\msoffice\wordian\diana\checklist (rev. 11101//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well permitting Process but is part of the history file. To improve the readability, of the Well History file and to simplify finding information, information, of this. nature is accumulated at the end of the file under APPE'NDIXi ., No Special'effort has been made to chronologically' ':.: organize this category of information. **** REEL HEADER MWD 01/09/13 BHI 01 LIS Customer Format Tape **** TAPE HEADER MWD 01/09/10 131661 01 1.75" NaviGamma - Gamma Ray tapescan.tbl.txt *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!'!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las ~version Information VERS. 1.20: WRAP. NO: ~well Information Block #MNEM.UNIT STRT FT STOP FT STEP FT NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL DATE API Data Type 8699.0000: 11445.0000 0.5000: -999.2500: COMPAN',': WELL: FIELD: LOCATION: COUNTY: STATE: SERVICE COMPANY: TOOL NAME & TYPE: LOG DATE; API NYUMBER: CWLS log ASCII standard -VERSION 1.20 One line per frame Information Starting Depth : Ending Depth Level Spacing Absent value BP Exp'!oration, ]:nc. MPH-08B1 Prudhoe Bay unit 2767' NSL, 4061' WEL North slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 10-Apr-00 500292280802 ~Parameter Information Block #MNEM.UNIT Value SECT TOWN N RANG PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE f OS1 Description 34 : Section TI 3N : Township Ri 0E : Range MSL .' Permanent Datum 0 : Elevation of Perm. Datum RKB : Log Measured from 65.68 : Feet Above Perm. Datum KB : Drilling Measured From 65.68 : Elevation of Kelly Bushing N/A : Elevation of Derrick Floor N/A : Elevation of Ground Level N/A : Cas/ng Depth DIRECTIONAL :, Other Services Line 1 ~COMMENTS (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX, RPCHX, RACHX,RPCLX) presented is realtime datai (4) Baker Hughes INTEQ Runs 1-2 utilized the Orient Express service to mill the casing window and drill formation from 9097' to 9198' MO (4093' to 4095' SSl~/D). (5) Baker Hughes INTEQ Runs 3-4 utilized the orient Express with ultra Slim Multiple Propagation Resistivity (USMPR) services from 9108' to 9800' MD (4095' to 4118' SSTVD). Page 1 tapescan, tbl .txt (6) Baker Hughes INTEQ Run 5 utilized the orient Express with ultra slim Multiple Propagation Resistivity (USMPR) services to perform a open hole sidetrack off well MPH-08B-PB1 from 9800' MO (4118' SSTVO) and drill formation to 10200' MD (4123' SSTVO). (7) Baker Hughes INTEQ Runs 6-8 utilized the orient Express with ultra Slim Multiple Propagation Resistivity (USMPR) services from 10200' to 1144S' MO (4123' to 4131' SSTVO). (8) The data presented here is final. Gamma Ray MWO is the POC (Primary Depth control) curve for this borehole, as per BPX instructions. (9) A Magnetic oeclination correction of 26.31 degrees has been applied to tnb Directional Surveys. ~REMARKS (1) Well MPH-08B1 was drilled as an open hole sidetrack off well MPH-08BPB1. (2) The sidetrack was drilled from a milled window in the 4-1/2" casing. Top of window:9084' MO (4090' SSTVO) BOttOm of window:9097' MO (4093' SSTVO) (3)well MPH-08B1 was drilled to TO @ 11445' MO (4131' SSTVO) on Run 8. (4)Th ei nterval from 11420' (4128' SSTVO) tO 11445' MO (4131' SSTVD) was not logged due to sensor to bit offset at well TD. logged due to sensor to bit offset at wel~, TD MNEMONICS: GRAX ROPS TVD RACLX RPCLX RACHX RPCHX = Gamma Ray MWD-API [MWD] (MWD-API units) : Rate of Penetration, feet/hour = subsea True Vertical Depth (SSTVD), (feet) = Resistivity compensated 400 kHz Attenuation ReSistivity Borehole corrected [MWO], (ohm-m) = Resistivity compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity compensated 2 MHz Attenuation Resistivity .Borehol,e corrected [MWD].,' (ohm-m) = Resi stivity compensated 2 MHz Phase Difference Resi stivity Borehole Corrected [MWO], (ohm-m) Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA DIRECTIONAL N/A N/A N/A N/A N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, I N/A NO Depth shift applied. Gamma Ray MWO is the Poc for borehole of MPH-08B1. Tape subfile: 1 97 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWO .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf Page 2 tapescan.tbl.txt LCC CN WN FN COUN STAT 150 BP Exploration, Inc. MPH-OSB1 Milne Point Unit North slope A1 aska LIS COMMENT RECORD !!!!!!!!!!!!!!!!!!! Remark File version 1.000 . The data presented is the field raw data, · The data has been not depth shifted. 3, Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX 0.0 2 ROP ROPS 0.0 3 RACH RACHX 0.0 4 RACL RACLX 0.0 5 RPCH RPCHX 0.0 6 RPCL RPCLX 0,0 * FORMAT .RECORD (TYPE#6.4) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optlca! Log Depth scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= O) Datum Specification Block sub-type is: FRAME SPACE : 0.500 * F ONE DEPTH PER FRAME Tape depth ID: f 6 Curves: Name Tool I GR MWD 2 ROP MWD 3 RACH COMP 4 RACL COMP 5 RPCH COMP 6 RPCL COMP code samples units size 68 1 API 4 68 1 F/HR 4 68 1 4 68 1 4 68 1 4 68 1 4 Length 24 Total Data Records: 153 Tape File Start Depth = 8699·000000 Tape File End Depth : 11445.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet FILE TRAILER **** Page 3 Tape subfile: 2 Minimum record length: Maximum record length **** TAPE TRAILER MWD Ol/O9/lO 131661 01 166 records... 54 bytes 4124 bytes tapescan.tbl.txt **** REEL TRAILER MWD 01/09/13 8HI O1 Tape subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Page 4 Tape Subfile 1 is type: LIS Tape Subfile 2 DEPTH RPCH 8699.0000 -999.2500 8699.5000 -999.2500 8700.0000 -999.2500 8800.0000 -999.2500 8900.0000 -999.2500 9000.0000 -999.2500 9100.0000 -999.2500 9200.0000 30.1080 9300.0000 56.8330 9400.0000 32.9800 9500.0000 !3.~580 9600.0000 61.6140 9700.0000 51.8650 9800.O00O -999.2500 9900.0000 25.2320 10000.0000 21.8950 10100.0000 21.6840 10200.0000 40.6020 10300.0000 36.1980 10400.0000 7.0730 10500.0000 -999.2500 10600.0000 -999.2500 10700.0000 -999.2500 10800.0000 is type: LIS GR RPCL 54.1970 -999.2500 57.6340 -999.2500 58.1170 -999.2500 50.5080 -999.2500 -999.2500 -999.2500 71.1480 -999.2500 65.3150 -999.2500 77.7480 28.2580 59.9610 44.5910 91.3320 25.4640 108.1990 14,1000 -999.2500 48.3890 77.8680 43.8170 -999.2500 -999.2500 82.8750 29.3180 87.5250 25.1000 79.2000 24.8740 60.6750 39.3840 76.9500 29.2390 94.7620 8.1280 68.7590 -999.2500 75.0580 -999.2500 83.8640 -999.2500 78.5830 ROP -999.2500 -999 2500 -999 2500 0 0000 -999 2500 0 0000 0 0000 0 0000 0 0000 82 0210 21 5410 117 5230 102 2600 -999 2500 39 6470 124 3270 117 5230 12 8680 87 1660 71 5820 91 5580 111 8120 102 2600 43 5740 RACH -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 21 3860 26 6430 17 1300 13 9690 29 7190 29.9940 -999 2500 36 8580 32 6110 27 9670 44 4240 24 7550 8 8170 -999 2500 -999.2500 -999.2500 -999.2500 RACL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 20 5540 23 9460 16 2750 15 3270 24 9710 25 0710 -999 2500 37 3430 33 7460 32 9580 31 4330 21 0780 11 1040 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 10900.0000 68.2460 -999.2500 -999.2500 11000.0000 76.4080 -999.2500 -999.2500 11100.0000 75.5080 -999.2500 -999.2500 11200.0000 76.7930 -999.2500 -999.2500 11300.0000 73.2580 -999.2500 -999.2500 11400.0000 77.4580 -999.2500 -999.2500 11445.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = 149 5070 146 4180 107 0490 65 8910 75 8550 81 455C -999 2500 8699.000000 11445.000000 0.500000 feet -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 **** REEL HEADER **** MWD 0~/09/16 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD Ol/O9/16 131661 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!111!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las ~Version Information VERS. WRAP. 1.20: CWLS log ASCII Standard -VERSION 1.20 NO: One line per frame ~Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8699.0000: Starting Depth STOP.FT 11445.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration, Inc. WELL. WELL: MPH-08B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 2767' NSL, 4061' WEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 10-Apr-00 API . API NYUMBER: 500292280802 -Parameter Information Block #MNEM.UNIT Value Description SECT. 34 : Section TOWN.N T1 3N : Township RANG. R1 0E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 65.68 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 65.68 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~COMMENTS (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX,RPCHX,RACHX,RPCLX) presented is realtime data. (4) Baker Hughes INTEQ Runs 1-2 utilized the Orient Express service to mill the casing window and drill formation from 9097' MD (4093' SSTVD) to 9108' MD (4095' SSTVD) . (5) Baker Hughes INTEQ Runs 3-4 utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 9108' MD (4095' SSTVD) to 9800' MD (4118' SSTVD) . (6) Baker Hughes INTEQ Run 5 utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services to perform a open hole sidetrack off well MPH-08B-PB1 from 9800' MD (4118' SSTVD) and drill formation to 10200' MD (4123' SSTVD) . (7) Baker Hughes INTEQ Runs 6-8 utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 10200' MD (4123' SSTVD) to 11445' MD (4131' SSTVD) . (8) The data presented here is final. Gamma Ray MWD is the PDC (Primary Depth Control) curve for this borehoie, as per BPX instructions. (9) A Magnetic Declination correction of 26.31 degrees has been applied to the Directional Surveys. -REMARKS (1) Well MPH-08B was drilled as an open hole sidetrack off Well MPH-08B-PB1. (2) The sidetrack was drilled from a milled window in the 4-1/2" casing. Top of window:9084' MD (4090' SSTVD) Bottom of window:9097' MD (4093' SSTVD) (3)Well MPH-08B was drilled to TD ® 11445' MD (4131' SSTVD) on Run 8. (4)The interval from 11420' (4128' SSTVD) to 11445' MD (4131' SSTVD) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX ROPS TVD RACLX RPCLX RACHX RPCHX = Gamma Ray MWD-API [MWD] (MWD~API units) = Rate of Penetration, feet/hour = Subsea True Vertical Depth (SSTVD), (feet) = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA N/A N/A N/A N/A DIRECTIONAL N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ! N/A No Depth Shift applied. Gamma Ray MWD is the PDC for borehole of MPH-08B1. Tape Subfile: 1 97 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN WN FN COUN ST~T BP Exploration, Inc. MPH-08B Milne Point Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .................................................... 1 GR GRAX 0 0 2 ROP ROPS 0 0 3 RACH RACHX 0 0 4 RACL RACLX 0 0 5 RPCH RPCHX 0 0 6 RPCL RPCLX 0 0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 2 ROP MWD 68 1 3 RACH COMP 68 1 4 RACL COMP 68 1 5 RPCH COMP 68 1 6 RPCL COMP 68 1 API F/HR Length 4 4 4 4 4 ....... 24 Total Data Records: 153 Tape File Start Depth = 8699.000000 Tape File End Depth = 11445.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: 166 records... 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/09/16 131661 01 **** REEL TRAILER **** MWD Ol/O~/16 BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR RPCH RPCL 8699.0000 -999.2500 54.1970 -999.2500 8699.5000 -999.2500 57.6340 -999.2500 87O0.0O00 -999.2500 58.1170 -999.2500 8800.0000 -999.2500 50.5080 -999.2500 8900.0000 -999.2500 -999.2500 -999.2500 9000.0000 -999.2500 71,1480 -999.2500 9100.0000 -999.2500 65.3150 -999.2500 9200.0000 30.1080 77.7480 28.2580 9300,0000 56.8330 59.9610 44.5910 9400.0000 32.9800 91.3320 25.4640 9500.0000 13.2580 108.1990 14.1000 9600.0000 61.6140 -999.2500 48.3890 9700.0000 51.8650 77.8680 43.8170 9800.0000 -999.2500 -999.2500 -999,2500 9900.0000 25.2320 82.8750 29.3180 10000.0000 21.8950 87.5250 25.1000 10100.0000 21.6840 79.2000 24.8740 10200.0000 40.6020 60.6750 39.3840 10300.0000 36.1980 76,9500 29.2390 10400.0000 7.0730 94.7620 8.1280 10500.0000 -999.2500 68.7590 -999.2500 10600,0000 -999.2500 75.0580 -999.2500 ROP -999.2500 -999 2500 -999 2500 0 0000 -999 2500 0 0000 0 0000 0 0000 0 0000 82 0210 21.5410 117 5230 102 2600 -999 2500 39 6470 ]24 3270 117 5230 12 8680 87 1660 71 5820 91 5580 111 8120 102 2600 RACH -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 21 3860 26 6430 17 1300 13 9690 29 7190 29 9940 -999 2500 36 8580 32 6110 27 9670 44 4240 24.7550 8.8170 -999.2500 -999.2500 -999.2500 RACL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 20 5540 23 9460 16 2750 15 3270 24 9710 25 0710 -999 2500 37 3430 33 7460 32 9580 31 4330 21 0780 11 1040 -999 2500 -999.2500 -999.2500 10700.0000 83.8640 -999.2500 -999.2500 10800.0000 78.5830 -999.2500 -999.2500 10900.0000 68.2460 -999.2500 -999.2500 11000.0000 76.4080 -999.2500 -999.2500 11100.0000 75.5080 -999.2500 -999.2500 11200.0000 76.7930 -999.2500 -999.2500 11300.0000 73.2580 -999.2500 -999.2500 11400.0000 77.4580 -999.2500 -999.2500 11445.0000 -999.2500 -999.2500 -999.2500 43 5740 149 5070 146 4180 107 0490 65 8910 75 8550 81 4550 -999 2500 Tape File Start Depth = 8699.000000 Tape File End Depth = 11445.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape Subfile 3 is type: LIS **** REEL HEADER **** MWD 01/09/16 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/09/16 131661 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. WRAP. 1.20: CWLS log ASCII Standard -VERSION 1.20 NO: One line per frame -Well Information Block #MNEM.UNIT Data Type STRT.FT 8699.0000: STOP.FT 11445.0000 STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM. UNIT SECT. TOWN. N RANG. PDAT. EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 -COMMENTS Value ......................... 34 : Ti 3N : R1 0E : MSL : 0 : RKB : 65.68 : KB : 65.68 : N/A : N/A : N/A : DIRECTIONAL : Information Starting Depth : Ending Depth Level Spacing Absent Value BP Exploration, Inc. MPH-08B Prudhoe Bay Unit 2767' NSL, 4061' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 10-Apr-00 500292280802 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX,RPCHX,RACHX,RPCLX) presented is realtime data. (4) Baker Hughes INTEQ Runs 1-2 utilized the Orient Express service to mill the casing window and drill formation from 9097' MD (4093' SSTVD) to 9108' MD (4095' SSTVD) . (5) Baker Hughes INTEQ Runs 3-4 utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 9108' MD (4095' SSTVD) to 10180' MD (4100' SSTVD) . (6) The data presented here is final. Gamma Ray MWD is the PDC (Primary Depth Control) curve for this borehole, as per BPX instructions. (7) A Magnetic Declination correction of 26.31 degrees has been applied to the Directional Surveys. -REMARKS (1) Well MPH-08B-PB1 was kicked off from Well MPH-08A ® 9084' MD (4090' SSTVD). (2) The sidetrack was drilled from a milled window in the 4-1/2" casing. Top of window:9084' MD (4090' SSTVD) Bottom of window:9097' MD (4093' SSTVD) (3)Well MPH-08B-PB1 was drilled to TD @ 10180' MD (4100' SSTVD) on Run 4. (4) The interval from 8928' MD to 9320' MD was logged after being drilled, at geologist request (for correlation). (5) No Gamma data due to orientation while drilling rapidly. (6)The interval from 10150' (4102' SSTVD) to 10180' MD (4100' SSTVD) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX ROPS TVD RACLX RPCLX R2kCHX RPCHX = Gamma Ray MWD-API [MWD] (MWD-API units) = Rate of Penetration, feet/hour = Subsea True Vertical Depth (SSTVD), (feet) = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA N/A N/A N/A N/A CURVE S~IFT DATA BASELINE, MEASURED, N/A, N/A, DIRECTIONAL N/A N/A DISPLACEMENT N/A No Depth Shift applied. Gamma Ray MWD is the PDC for borehole of MPH-08B1. Tape Subfile: 1 93 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPH-08B-PB1 FN Milne Point Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .................................................... 1 GR GRAX 0 0 2 ROP ROPS 0 0 3 RACH RACHX 0 0 4 RACL RACLX 0 0 5 RPCH RPCHX 0 0 6 RPCL RPCLX 0 0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 ROP MWD 68 1 3 RACH COMP 68 1 4 RACL COMP 68 1 5 RPCH COMP 68 1 6 RPCL COMP 68 1 Size API 4 F/HR ~ Length 4 4 4 4 4 4 24 Total Data Records: 83 Tape File Start Depth = 8699.000000 Tape File End Depth = 10180.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: 96 records... 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/09/1~ 131661 01 **** REEL Ti~AILER **** MWD 01/09/16 BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS DEPTH GR RPCH RPCL 8699.0000 54.1970 -999.2500 -999.2500 8699.5000 57.6340 -999.2500 -999.2500 8700.0000 58.1170 -999.2500 -999.2500 8800.0000 50.5080 -999.2500 -999.2500 8900.0000 -999.2500 -999.2500 -999.2500 9000.0000 71.1480 -999.2500 -999.2500 9100.0000 65.3150 -999.2500 -999.2500 9200.0000 77.7480 30.1080 28.2580 9300.0000 59.9610 56.8330 44.5910 9400.0000 91.3320 32.9800 25.4640 9500.0000 108.1990 13.2580 14.1000 9600.0000 -999.2500 61.6140 48.3890 9700.0000 77.8680 51.8650 43.8170 9800.0000 76.9810 28.4940 26.8280 9900.0000 89.3370 32.4420 22.4800 10000.0000 113.2580 7.7610 8.3480 10100.0000 120.5620 8.8350 8.5390 10180.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = Tape Subfile 3 is type: LIS ROP -999.2500 -999.2500 -999.2500 0.0000 -999.2500 0.0000 0.0000 0.0000 0.0000 82.0210 21.5410 117.5230 102.2600 76.6950 51.3230 4.1800 17.4060 -999.2500 8699.000000 10180.000000 0.500000 feet RACH -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 21.3860 26.6430 17.1300 13 9690 29 7190 29 9940 21 3170 14 8030 7 9750 7 9270 -999 2500 RACL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 -999 2500 20 5540 23 9460 16 2750 15 3270 24 9710 25 0710 20 3020 14 3250 10 1430 8.1800 -999.2500