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Home My WebLink About201-2217. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 05-26A Mill CIBPS, Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-221 50-029-21984-01-00 ADL 0028326 12475 Conductor Surface Intermediate Liner Liner 8809 79 3922 10346 2691 636 10500 20" 10-3/4" 7-5/8" 3-1/2" 5-1/2" 8444 32 - 111 33 - 3914 30 - 10376 9784 - 12475 10067 - 10699 32 - 111 31 - 3726 30 - 8353 7915 - 8809 8123 - 8592 none 520 2090 4790 10530 6280 10500 , 10999 1530 3580 6890 10160 7740 10330 - 12375 4-1/2" 12.6# x 3-1/2" 9.3# Cr13 x L-80 19 - 98038319 - 8809 Structural 4.5" HES TNT , 4-1/2" Baker S-3 Perm (2) No SSSV 8885 , 9034 , 9746 7252 , 7362 , 7886 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 9-18/24 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 2470 By Grace Christianson at 1:56 pm, Aug 30, 2024 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2024.08.29 13:06:37 - 08'00' Aras Worthington (4643) 324-499 DSR-9/5/24 SFD 9/10/2024 10-404 MGR12AUG24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.13 21:05:50 -04'00'09/13/24 RBDMS JSB 091624 aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ ®ôīīϙbÍıôϡ ͏͔ϱ͕͑IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͓͑͐͗͘ϱ͏͐ ŪŘŘôĲťϙťÍťŪŜϡ iƯīĖĲôϙĲèĺıŕôťĖťĖŽô ĖČϡ (ŜťĖıÍťôîϙťÍŘť "Íťôϡ ͏͘ϯ͐͗ϯ͑͏͓͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͒îÍƅŜ ôČŪīÍťĺŘƅ ĺĲťÍèťϡ ÍŘŘĖôϙVÍĲĺſŜħĖ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͑͏͐ϱ͑͑͐ >ĖŘŜťÍīīϙ(ĲČĖĲôôŘϡ aÍƄϙ"ĖèħôŘıÍĲ ϼ͒͏͖Ͻϙ͔͑͏ϱ͖͗͗͑ ϼèϽ ôèĺĲîϙÍīī (ĲČĖĲôôŘϡ "ÍŽĖîϙĤĺŘħ ϼ͘͏͖Ͻ͓͓͏ϱ͏͒͒͐ϙϼèϽ >(ϙbŪıæôŘϡ ͓͑͑ϱ͏͐͏͓͖Ii͔͐͏ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϡ ͒Ϡ͔͒͏ ŕŜĖϙЬϙ͗Ϡ͗͏͏Ѝϙ«"͖ϟ͒ @( aÍƄϟϙĲťĖèĖŕÍťôîϙŪŘċÍèôŘôŜŜŪŘôϡ ͑Ϡ͓͖͏ŕŜĖ ϼÍŜôîϙĺĲϙ͏ϟ͐ϙŕŜĖϯċťϟϙČÍŜϙČŘÍîĖôĲťϽ [ÍŜťϙIϙ®Fϡ ͔͗͏ ŕŜĖ ϼÍħôĲϙĺĲ ͏͗ϯ͐͗ϯ͓͑ ®FϽ aĖĲϙI"ϡ ͑ϟ͖͔Ћ³b͖͔͑͘Ѝa" aÍƄϙĲČīôϡ ͓͘ "ôČϙЬ ͐͐Ϡ͔͓͑Ѝ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ ͏͔ϱ͕͑ϙĖŜϙÍϙēĺŘĖƏĺĲťÍīϙ¾͐ϙČŘÍŽĖťƅϙîŘÍĖĲÍČôϙŕŘĺîŪèôŘϙîŘĖīīôîϙĖĲϙ͑͏͏͑ϙīĺèÍťôîϙĲĺŘťēϙĺċϙťēôϙČŘÍææôĲ ĲôÍŘϙťēôϙ"͐͗ϙæĺŪĲîÍŘƅϟ ēôϙſôīīϙŜÍſϙŜĖČĲĖƱèÍĲťϙĺĲϱťĖıôϙťēŘĺŪČēĺŪťϙĖťŜϙīĖċôϙŪĲťĖīϙťēôϙèēĺħôϙæŘĺħô ĖĲϙôŕťôıæôŘϙ͑͏͔͐ϙŘôŜŪīťĖĲČϙĖĲϙťēôϙſôīīϙæôĖĲČϙIϙċĺŘϙÍϙƅôÍŘϙÍĲîϙÍϙēÍīċϟϙϙēôϙèēĺħôϙſÍŜ ŘôŕÍĖŘôîϠÍĲî ťēôϙſôīīϙſÍŜϙiДîϙVŪĲôϙ͑͏͖͐Ϡ ĖĲĖťĖÍīŘÍťôŜϙŜēĺſôîϙČĺĺîϙ@iϠϙēĺſôŽôŘϙĺŽôŘϙťēôϙèĺŪŘŜôϙĺċϙÍϙèĺŪŕīô ſôôħŜϙťēôϙ@iϙĖĲèŘôÍŜôîϙēĖČēôŘϙťēÍĲϙôŽôŘŕŘôŽĖĺŪŜīƅŕŘĺîŪèôîϟϙϙċťôŘϙıŪīťĖŕīôϙſôīīϙťôŜťŜ èĺĲƱŘıĖĲČϙťēôϙF@iϙťēôϙſôīīϙſÍŜϙIϟ IťϙſÍŜϙèĺĲŽôŘťôîϙťĺϙ@ϙĺĲīƅϙĖĲϙ͑͏͖͐ϟϙϙ®ôϙſĺŪīîϙīĖħôϙťĺϙÍîî ôƄťôĲîôîϙÍîîϙŕôŘċŜϙĖĲϙ¾͐ϙſēôŘôϙČÍŜϙèÍŕϙſÍťôŘϙĖĲĤôèťĖĺĲϙıÍƅϙēÍŽôϙŜŪŕŕŘôŜŜôîϙČÍŜϙŕŘĺîŪèťĖĺĲ ÍĲî ŕÍťèēϙĺŽôŘϙťēôϙÍČϙŘĖŽôŘϟ iæĤôèťĖŽôŜϡ ēôϙĺæĤôèťĖŽôϙĺċϙťēĖŜϙŕŘĺèôîŪŘôϙĖŜ ťĺϙıĖīīϙŪŕϙťēôϙôƄĖŜťĖĲČϙæŘĖîČôϙŕīŪČŜϠϙÍîî ͒͏͏ċťϙĺċϙôƄťôĲîôîϙÍîî ŕôŘċŜϙťēôĲϙŕÍťèēϙĺŽôŘϙťēôϙÍČϙŘĖŽôŘϙŕôŘċŜϟ ŘĺèôîŪŘôϡ ĺĖīôîϙŪæĖĲČ ͐ϟ aIϙŜôŘŽĖèôϙèĺĖīϙŪĲĖťϙÍĲîϙŜŕĺťϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲťϟ ͑ϟ IFϙſĖťē ͑ϟ͖͑ЋϙıĖīīĖĲČϙFϠϙÍČϙIϙÍťϙ͐͏Ϡ͔͏͏ċťϙÍĲîϙŕŪŜēϙťĺϙŜôèĺĲîϙæŘĖîČôϙŕīŪČϙÍť ͐͏Ϡ͘͘͘ċťϟϙϙaĖīīϙŪŕϙŜôèĺĲîϙæŘĖîČôϙŕīŪČϙÍĲîϙŕŪŜēϙŕÍŜťϙŕôŘċŜϙÍťϙ͐͑Ϡ͖͔͒ċťϟ ŪĲîŘĖôîϟÍèťĖŽĖťƅϟæôīĺſ bĺťôŜϧ x ôıĺťôϟ ČÍŜ ıĺĲĖťĺŘĖĲČϟ ċĺŘϟ F͗ϟ ÍĲîϟ [([Ŝϟ ÍŘôϟ ŘôŗŪĖŘôîϟ ċĺŘϟ iŕôĲϟ Fĺīôϟ "ôŕīĺƅıôĲť iŕôŘÍťĖĺĲŜ x "ŪôϟťĺϟťēôϟĲôèôŜŜÍŘƅϟĺŕôĲϟēĺīôϟîôŕīĺƅıôĲťϟĺċϟ(ƄťôĲîôîϟôŘċĺŘÍťĖĲČϟĤĺæŜϦϟ͙͗ϷēĺŪŘϟèŘôſ ÍĲîϟ®ϟèĺŽôŘÍČôϟĖŜϟŘôŗŪĖŘôîϥ aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ x ēôϟſôīīϟſĖīīϟæôϟħĖīīôîϟÍĲîϟıĺĲĖťĺŘôîϟæôċĺŘôϟıÍħĖĲČϟŪŕϟťēôϟĖĲĖťĖÍīϟŕôŘċŜϟČŪĲŜϥϟϟēĖŜϟĖŜ ČôĲôŘÍīīƅϟîĺĲôϟîŪŘĖĲČϟťēôϟîŘĖċťϵīĺČČĖĲČϟŘŪĲϥ ēĖŜϟſĖīīϟŕŘĺŽĖîôϟČ ŪĖîÍĲèôϟÍŜϟťĺϟſēôťēôŘϟťēô ſôīīϟſĖīīϟæôϟħĖīīôîϟæƅϟæŪīīēôÍîĖĲČϟĺŘϟèĖŘèŪīÍťĖĲČϟæĺťťĺıŜϟŪŕϟťēŘĺŪČēĺŪťϟťēôϟĤĺæϥ IċϟŕŘôŜŜŪŘô ĖŜϟŜôôĲϟĖııôîĖÍťôīƅϟÍċťôŘϟŕôŘċĺŘÍťĖĲČϦϟĖťϟſĖīīϟôĖťēôŘϟæôϟħĖīīôî ϟæƅϟæŪīīēôÍîĖĲČϟſēĖīôϟiiFϟĺŘ èĖŘèŪīÍťĖĲČϟæĺťťĺıŜϟŪŕϟťēŘĺŪČēϟťēôϟŜÍıôϟŕĺŘťϟťēÍťϟĺŕôĲôîϟťĺϟŜēô ÍŘϟťēôϟƱŘĖĲČϟēôÍîϥ ͒ϟ ċťôŘϙaϙaFϙÍĲîϙŕŪīīϙťôŜťĖĲČϙťēôϙϠϙťÍČϱŪŕϙĺĲϙťēôϙϙŜťŘĖŕŕôŘϙťĺϙôĲŜŪŘôϙFϙèÍĲĲĺť ŕŪīīϙťēŘĺŪČēϙťēôϙæŘÍŜŜϙŪŕĺĲϙiiFϙſĖťēϙČŪĲŜϟ ͓ϟ ŪīīēôÍîϙѹ͑͑͏ ææīŜϙ͐҇ϙX[ϯ®ϙîĺſĲϙťŪæĖĲČϟϙϙaÍƄϙťŪæĖĲČϙŕŘôŜŜŪŘôϙ͔͑͏͏ϙŕŜĖϟϙϙϼēĖŜϙŜťôŕ èÍĲϙæôϙŕôŘċĺŘıôîϙÍĲƅϙťĖıôϙŕŘĖĺŘϙťĺϙĺŕôĲϱēĺīôϙîôŕīĺƅıôĲťϙĺċϙťēôϙŕôŘċϙČŪĲŜϟϙϙĖıĖĲČϙĺċϙťēô ſôīīϙħĖīīϙĖŜϙÍťϙťēôϙîĖŜèŘôťĖĺĲϙĺċϙťēôϙ®ϟϽ Íϟ ®ôīīæĺŘôϙŽĺīŪıôϙťĺϙťĺŕϙŕôŘċϙѱ͓͐͘ ææīŜ æϟ ͓ϱ͐ϯ͑ЋϙŪæĖĲČϳ͖͓͗͘Ѝϙ³ϙ͏ϟ͏͔͐͑ϙѱ ͖͐͒ ææī èϟ ͒ϱ͐ϯ͑Ћ ŪæĖĲČϳ͗͒͒Ѝϙ³ϙϟ͏͏͖͗æŕċϙѱ ͖ϟ͒ ææī îϟ 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ťϟťēôϟæôČĖĲĲĖĲČϟĺċϟôÍèēϟĤĺæϦϟťēôϟèŘĺŜŜĺŽôŘϵŜÍċôťƅϟĤĺĖĲťϟıŪŜťϟæ ôϟŕēƅŜĖèÍīīƅϟaϟťĺϟťēô ŕôŘċϟČŪĲŜϟĺĲôϟťĖıôϟťĺϟèĺĲƱŘıϟťēôϟťēŘôÍîŜϟÍŘôϟèĺıŕÍťĖæīôϥ ͖͖ϥ ŘôÍħϙīŪæŘĖèÍťĺŘϙèĺĲĲôèťĖĺĲϙÍťϙϙÍĲîϙæôČĖĲϙıÍħôŪŕϙĺċϙϙČŪĲŜϙŕôŘϙŜèēôîŪīôϙæôīĺſϟ ĺĲŜťÍĲťīƅϙıĺĲĖťĺŘϙƲŪĖîϙŘÍťôŜϙŕŪıŕôîϙĖĲϙÍĲîϙƲŪĖîϙŘôťŪŘĲŜϙĺŪťϙĺċϙťēôϙſôīīϟϙϙ>īŪĖîŜϙıÍĲϱ ſÍťèēϙıŪŜťϙæôϙŕôŘċĺŘıôîϙſēĖīôϙîôŕīĺƅĖĲČϙŕôŘċϙČŪĲŜϙťĺϙôĲŜŪŘôϙťēôϙſôīīϙŘôıÍĖĲŜϙħĖīīôîϙÍĲî ťēôŘôϙĖŜϙĲĺϙôƄèôŜŜϙƲĺſϟ ôŘċϙèēôîŪīô ϰ͗ϥ͕͕ГГaÍƄ>ĺŘèôČŪĲŜϟſôŘôϟŪŜôîϟťĺϟôŜťĖıÍťôϟċĺŘϟťēĖŜϟĤĺæϟÍĲîϟèÍīè ŪīÍťôϟČŪĲϟſôĖČēťŜϥ ôŘċϙIĲťôŘŽÍī ôŘċϙ[ôĲČťē @ŪĲϙ[ôĲČťē ®ôĖČēťϙĺċ @ŪĲϙϼīæŜϽ aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ ͐͐Ϡ͏͕͏Ѝϳ͕͐͐͒͏Ѝ ͒͏͏Ѝ ͒͏͏Ѝ ͕͖͓͐ īæŜ ϼ͔ϟ͔͗ŕŕċϽ ͐͑ϟ aÍħôϙŪŕϙ(ϙÍĲîϙťôŜťϟ ͐͒ϟ IFϙſĖťēϙŕôŘċϙČŪĲϙÍĲîϙťĖôϱĖĲϙťĺϙèĺĖīϙƲÍČϙèĺŘŘôīÍťĖĺĲϟϙϙĖèħŪŕϙÍĲîϙŕôŘċĺŘÍťôϙĖĲťôŘŽÍīϙŕôŘϙôŘċ èēôîŪīôϙÍæĺŽôϟ Íϟ bĺťôϙÍĲƅϙťŪæĖĲČϙŕŘôŜŜŪŘôϙèēÍĲČôϙĖĲϙ®ϟ ͓͐ϟ ċťôŘϙŕôŘċĺŘÍťĖĲČϠϙFϙťĺϙťĺŕϙĺċϙīĖĲôŘϙĺŘϙĖĲťĺϙťŪæĖĲČϙťÍĖīϙťĺϙôĲŜŪŘôϙîôæŘĖŜϙîĺôŜĲЍťϙċÍīīϙĖĲϙĺĲϙťēô ČŪĲŜϙÍĲîϙŜťĖèħϙťēôϙFϟϙϙĺĲƱŘıϙſôīīϙĖŜϙîôÍîϙÍĲîϙŘôϱħĖīīϙĖċ ĲôèôŜŜÍŘƅϠ æôċĺŘôϙŕŪīīĖĲČϙťĺ ŜŪŘċÍèôϟ ͔͐ϟ ŪıŕϙŕĖŕôϙîĖŜŕīÍèôıôĲťϙſēĖīôϙiiFϟϙϙťĺŕϙÍťϙŜŪŘċÍèôϙťĺϙŘôèĺĲƱŘıϙſôīīϙĖŜϙîôÍîϟϙϙXĖīīϙſôīīϙĖċ ĲôèôŜŜÍŘƅϟ ͕͐ϟ ôŽĖôſϙ ſôīīϙ èĺĲťŘĺīϙ ŜťôŕŜϙ ÍĲîϙ ťÍĲîĖĲČϙ iŘîôŘŜϙ ſĖťēϙ èŘôſϙ ŕŘĖĺŘϙ ťĺϙ æŘôÍħĖĲČϙ īŪæŘĖèÍťĺŘ èĺĲĲôèťĖĺĲϙÍĲîϙèĺııôĲèĖĲČϙæŘôÍħîĺſĲϙĺċϙϙČŪĲϙŜťŘĖĲČϟ Íϟ (ĲŜŪŘôϙŜÍċôťƅϙĤĺĖĲťϙÍĲîϙI®ϙŽÍīŽôϙÍŜŜôıæīƅϙÍŘôϙĺĲϱēÍĲîϙæôċĺŘôϙæŘôÍħĖĲČϙĺƯϙīŪæŘĖèÍťĺŘ ťĺϙ["ϙČŪĲϙFϟ ͖͐ϟ "aiϙϟ ͐͗ϟ >ϙſôīīÍŜϙĲôèôŜŜÍŘƅϟ (ĲîϟĺċϟŜŪĲîŘĖôîϟÍèťĖŽĖťƅ ͐͘ϟ ϙôϱīĖĲôϙÍĲî Ŝôťϙ͒ϱ͐ϯ͑Ћ ϼ[ϱ͗͏ϽbϙıĺĲĺÍħÍťϙ͐͏Ϡ͕͔͒ċťϟ ͑͏ϟ ϙīĖèħīĖĲôϙÍĲîϙŜôťϙŪŕŕôŘϙ͒ϱ͐ϯ͑Ћϙϼ[ϱ͗͏ϽϙbϙaĺĲĺÍħ ϼ͐͏Ϡ͔͒͑ċťϽϙſĖťēϙŜīĖîĖĲČϙŜīôôŽôϙϼèīĺŜôîϽ ÍĲîϙϙŜôÍīϙÍŜŜôıæīƅϟ ťťÍèēıôĲťŜϡ ͐ϟ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑ϟ ŘĺŕĺŜôîϙèēôıÍťĖè ͒ϟ ĺĖīϙŪæĖĲČϙi(ϙèēôıÍťĖè ͓ϟ ťÍĲîĖĲČϙiŘîôŘŜϙċĺŘϙiŕôĲϙFĺīôϙ®ôīīϙĺĲťŘĺīϙîŪŘĖĲČϙôŘċϙ@ŪĲϙ"ôŕīĺƅıôĲť ͔ϟ (ŗŪĖŕıôĲťϙ[ÍƅĺŪťϙ"ĖÍČŘÍı ͕ϟ ĖôϙIĲϙ[ĺČϯôŘċϙēôôť ͖ϟ ŪĲîŘƅϙèēÍĲČôϙċĺŘı aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ ĺĖīôîϙŪæĖĲČϙiŜ aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ ťÍĲîĖĲČϙiŘîôŘŜϙċĺŘϙiŕôĲϙFĺīôϙ®ôīīϙĺĲťŘĺīϙîŪŘĖĲČϙôŘċϙ@ŪĲϙ"ôŕī ĺƅıôĲť aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ (ŗŪĖŕıôĲťϙ[ÍƅĺŪťϙ"ĖÍČŘÍı aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ Tie In: 5/5/2015 aĖīīϙŕīŪČŜϠ(ƄťôĲîôîϙôŘċ ŘĺèôîŪŘôϠϙÍťèē ͏͔ϱ͕͑ "ϡϙ͑͏͐ϱ͑͑͐ Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 05-26A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-221 50-029-21984-01-00 12475 Conductor Surface Intermediate Liner Liner 8809 79 3922 10346 2691 636 10500 20" 10-3/4" 7-5/8" 3-1/2" 5-1/2" 8444 32 - 111 33 - 3914 30 - 10376 9784 - 12475 10067 - 10699 32 - 111 31 - 3726 30 - 8353 7915 - 8809 8123 - 8592 none 520 2090 4790 10530 6280 10999 1530 3580 6890 10160 7740 10330 - 12375 4-1/2" 12.6# x 3-1/2" 9.3# Cr13 x L-80 19 - 9803 8319 - 8809 Structural 4-1/2" HES TNT , 8885 , 7252 No SSSV 8885 , 9036 , 9749 7252 , 7363 , 7888 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028326 19 - 7929 544 455 48365 40441 86 18 0 0 909 946 322-170 13b. Pools active after work:PRUDHOE OIL 4-1/2" BKR S-3 Perm, 9036 , 7363 4-1/2" BKR S-3 Perm , 9749 , 7888 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 10500 , By Grace Christianson at 2:41 pm, Dec 28, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.12.28 11:19:09 - 09'00' Bo York (1248) RBDMS JSB 010324 WCB 5-10-2024 DSR-1/26/24 ACTIVITYDATE SUMMARY 12/4/2023 ***WELL SHUT IN ON ARRIVAL*** SPOT IN/RIG UP PT PCE 200LP - 3000HP RIH WITH 1 7/16" CABLE HEAD, 2" WEIGHT BAR, 1 11/16" WEIGHT BAR, 1 11/16" GR/CCL, 1 11/16 OWENS LONG STROKE SETTING TOOL, 2.5" PLUG (MAX OD = 2.5" , MAX LENTH = 30') CORRALATE TO REF LOG SLB PERFORATION RECORD 24- OCT-17 PLUG SET DEPTH = 10,500' , CCL OFFSET = 13.8' , CCL STOP DEPTH = 10,486.2' RIG DOWN/MOVE OFF ***WELL SHUT IN ON DEPARTURE*** Daily Report of Well Operations PBU 05-26A PLUG SET DEPTH = 10,500' 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: 12/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-8 50133203040000 177029 11/15/2023 HALLIBURTON EPX NCIU A-17 50883201880000 223031 11/28/2023 HALLIBURTON RBT PBU 04-46A 50029224340100 223082 11/1/2023 HALLIBURTON RBT PBU 05-26A 50029219840100 201221 11/24/2023 HALLIBURTON PPROF PBU 06-20B 50029207990200 223075 10/18/2023 BAKER MRPM PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT PBU N-07A 50029201370100 204105 10/7/2023 BAKER SPN PBU P1-08A 50029223840100 202199 9/22/2023 BAKER SPN PBU P2-56 50029226100000 195162 11/14/2023 BAKER SPN PBU P2-57A 50029221830100 202214 11/1/2023 BAKER SPN Please include current contact information if different from above. T38205 T38206 T38207 T38208 T38209 T38210 T38211 T38212 T38213 T38214 12/6/2023 PBU 05-26A 50029219840100 201221 11/24/2023 HALLIBURTON PPROF Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.06 14:25:58 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer 05-26A (PTD #2012210) RWO complete Date:Friday, August 12, 2022 8:51:51 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, August 11, 2022 4:55 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Producer 05-26A (PTD #2012210) RWO complete Mr. Regg, Producer 05-26A (PTD # 2012210) recently had a RWO to replace the production tubing in accordance with approved Sundry 322-170. Upon completion, the well passed an MIT-T to 3500 psi and MIT-IA to 3000 psi. The passing MITs confirm two competent barriers and the well is now classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, January 9, 2022 4:30 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Producer 05-26A (PTD #2012210) secured with plug Mr. Regg, Slickline secured the well with a tubing plug on 01/08/22 and performed a passing CMIT-TxIA to 2455 psi. The well will be classified as NOT OPERABLE and will remain secured until the primary well barrier is restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, January 4, 2022 4:14 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Understood about leaving the well online. 7 days is acceptable and willing to extend beyond if necessary. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 4, 2022 3:48 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: FW: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Mr. Regg, Sorry to bother you again, but I just wanted to make sure you are okay with a 7-day extension to get the plug set and tested. We can shut the well in today (day 28), but the failing TIFL indicates the IA pressure will climb above MOASP when shut-in and I would like to get a fullbore truck to load the tubing with fluid if it is going to be shut-in without a plug. Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Tuesday, January 4, 2022 10:58 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: RE: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days The TIFL failed on 12/12/21. I apologize for not making that clear. This was the next job scheduled before this current cold streak shut down operations, so I am not anticipating needing 14 days to complete the work. The intent of the 14-day extension was to buffer anymore weather and/or equipment delays, but I agree with you, 14 days is not justified. Would a 7-day extension be agreeable? The wells foreman is aware of the urgency of setting the TTP and getting it tested. Thanks, Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, January 4, 2022 9:57 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days When did the subsequent TIFL fail? The recent weather certainly been challenging but I am not convinced an additional 14 days is justified. Getting the TTP set and tested should be done ASAP. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 4, 2022 6:36 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Subject: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Mr. Regg, Slickline set DGLVs on 12/11/21, but the well subsequently failed another TIFL. Slickline has been scheduled to set a tubing tail plug and perform MITs but are currently delayed due to inclement weather. The Under Evaluation clock will be extended 14 days to perform the MITs. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 7, 2021 7:27 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 05-26A (PTD #2012210) sustained IA casing pressure above MOASP Mr. Regg, Producer 05-26A (PTD # 2012210) was reported to have sustained Inner Annulus casing pressure above MOASP on 12/06/21 after the well was shut-in. DHD performed a failing TIFL indicating a failure of the primary well barrier. The well is now classified as Under Evaluation and is on the 28- day clock for diagnostics. Plan forward: 1. Slickline: Replace GLVs 2. DHD: re-TIFL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. By Anne Prysunka at 8:37 am, Sep 01, 2022 5HJJ-DPHV%2*& )URP$ODVND16$65:HOO6LWH0DQDJHUV$ODVND16$65:HOO6LWH0DQDJHUV#KLOFRUSFRP! 6HQW7KXUVGD\$XJXVW30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F$ODVND16$65:HOO6LWH0DQDJHUV 6XEMHFW%23(7HVW3%8$ $WWDFKPHQWV+LOFRUS$65[OV[ ZĞŐĂƌĚƐ͕ ^Z^D͛Ɛ ,ŝůĐŽƌƉ^D͗ϵϬϳͲϲϴϱͲϭϮϲϲ ,ŝůĐŽƌƉůĂƐŬĂ͕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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 8/3/22 Rig Rep.: Rig Phone: 685-1266 Operator: Op. Phone:685-1266 Rep.: E-Mail Well Name: PTD #22012210 Sundry #322-170 Operation: Drilling: Workover: x Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/2500 Valves:250/3000 MASP:2499 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16"P Inside Reel valves 0NA HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3100 P CHOKE MANIFOLD:Pressure After Closure (psi)1800 P Quantity Test Result 200 psi Attained (sec)5 P No. Valves 16 P Full Pressure Attained (sec)48 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4X 2250 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/2/2022 00:00 Waived By Test Start Date/Time:8/3/2022 4:30 (date) (time)Witness Test Finish Date/Time:8/3/2022 10:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Tested with both 3.5" and 4.5" test joints . Annular closing time = 26 sec D. Schulze / C. Greub Hilcorp Alaska A. Haberthur/ C. Huntington PBU 05-26A Test Pressure (psi): skaNS-ASR-Well Site Managers@hilcorp.c Form 10-424 (Revised 02/2022) 2022-0803_BOP_Hilcorp_ASR1_PBU_05-26A 9 9 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ Annular closing time = 26 sec CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:David Bjork (david.bjork@hilcorp.com) Cc:DOA AOGCC Prudhoe Bay Subject:20220705 0933 APPROVAL for ASR to perform RWO PBU 05-26A RWO PTD 201-221 sundry 322-170 Date:Tuesday, July 5, 2022 9:36:40 AM Attachments:BOP Schematic Hilcorp ASR.pdf David, Hilcorp has AOGCC approval for ASR to perform PBU 05-26A RWO instead of Thunderbird utilizing 11” BOPE stack. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). Cc, AOGCC Inspectors From: David Bjork <David.Bjork@hilcorp.com> Sent: Thursday, June 30, 2022 10:17 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 05-26 RWO PTD 201-221 sundry 322-170 Mel, I would like to revise the sundry 322-170. We would like to perform this RWO with the Hilcorp ASR instead of the Thunderbird#1. The BOP stack will change to an 11”. The test pressures, VBR sizes, test joints and operational detail will not change. Dave Bjork FS1 OE 564-4672o 440-0331c The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220422 1400 APPROVAL Tubing Size Change 05-26A RWO PTD 201-221 sundry #322-170 Date:Friday, April 22, 2022 2:05:38 PM Attachments:05-26A proposed.pdf From: Rixse, Melvin G (OGC) Sent: Friday, April 22, 2022 2:04 PM To: David Bjork (david.bjork@hilcorp.com) <david.bjork@hilcorp.com> Cc: aogcc.inspectors@alaska.gov Subject: 20220422 1400 APPROVAL Tubing Size Change 05-26A RWO PTD 201-221 sundry #322-170 David, Approved to alter Sundry 322-170 to complete with 4-1/2” tubing. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: David Bjork <David.Bjork@hilcorp.com> Sent: Friday, April 22, 2022 1:31 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 05-26A RWO PTD 201-221 sundry #322-170 Mel, Upon further review we would like to upsize the tubing in this well. No other changes to the scope of work outlined in the sundry application. Attached is a new proposed schematic. We will also test the 2-7/8” x 5” VBR’s with a 4-1/2” and 3-1/2” test joint. Let me know if you have any questions. Regards, Dave Bjork FS1 OE 564-4672o 440-0331c The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Date:Tuesday, January 4, 2022 4:15:41 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Tuesday, January 4, 2022 4:14 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Understood about leaving the well online. 7 days is acceptable and willing to extend beyond if necessary. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 4, 2022 3:48 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: FW: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Mr. Regg, Sorry to bother you again, but I just wanted to make sure you are okay with a 7-day extension to get the plug set and tested. We can shut the well in today (day 28), but the failing TIFL indicates the IA pressure will climb above MOASP when shut-in and I would like to get a fullbore truck to load the tubing with fluid if it is going to be shut-in without a plug. Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Tuesday, January 4, 2022 10:58 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: RE: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days The TIFL failed on 12/12/21. I apologize for not making that clear. This was the next job scheduled before this current cold streak shut down operations, so I am not anticipating needing 14 days to complete the work. The intent of the 14-day extension was to buffer anymore weather and/or equipment delays, but I agree with you, 14 days is not justified. Would a 7-day extension be agreeable? The wells foreman is aware of the urgency of setting the TTP and getting it tested. Thanks, Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, January 4, 2022 9:57 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days When did the subsequent TIFL fail? The recent weather certainly been challenging but I am not convinced an additional 14 days is justified. Getting the TTP set and tested should be done ASAP. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 4, 2022 6:36 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Mr. Regg, Slickline set DGLVs on 12/11/21, but the well subsequently failed another TIFL. Slickline has been scheduled to set a tubing tail plug and perform MITs but are currently delayed due to inclement weather. The Under Evaluation clock will be extended 14 days to perform the MITs. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 7, 2021 7:27 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 05-26A (PTD #2012210) sustained IA casing pressure above MOASP Mr. Regg, Producer 05-26A (PTD # 2012210) was reported to have sustained Inner Annulus casing pressure above MOASP on 12/06/21 after the well was shut-in. DHD performed a failing TIFL indicating a failure of the primary well barrier. The well is now classified as Under Evaluation and is on the 28- day clock for diagnostics. Plan forward: 1. Slickline: Replace GLVs 2. DHD: re-TIFL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Producer 05-26A (PTD #2012210) secured with plug Date:Monday, January 10, 2022 9:55:54 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, January 9, 2022 4:30 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Producer 05-26A (PTD #2012210) secured with plug Mr. Regg, Slickline secured the well with a tubing plug on 01/08/22 and performed a passing CMIT-TxIA to 2455 psi. The well will be classified as NOT OPERABLE and will remain secured until the primary well barrier is restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, January 4, 2022 4:14 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Understood about leaving the well online. 7 days is acceptable and willing to extend beyond if necessary. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 4, 2022 3:48 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: FW: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Mr. Regg, Sorry to bother you again, but I just wanted to make sure you are okay with a 7-day extension to get the plug set and tested. We can shut the well in today (day 28), but the failing TIFL indicates the IA pressure will climb above MOASP when shut-in and I would like to get a fullbore truck to load the tubing with fluid if it is going to be shut-in without a plug. Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Tuesday, January 4, 2022 10:58 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: RE: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days The TIFL failed on 12/12/21. I apologize for not making that clear. This was the next job scheduled before this current cold streak shut down operations, so I am not anticipating needing 14 days to complete the work. The intent of the 14-day extension was to buffer anymore weather and/or equipment delays, but I agree with you, 14 days is not justified. Would a 7-day extension be agreeable? The wells foreman is aware of the urgency of setting the TTP and getting it tested. Thanks, Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, January 4, 2022 9:57 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: [EXTERNAL] RE: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days When did the subsequent TIFL fail? The recent weather certainly been challenging but I am not convinced an additional 14 days is justified. Getting the TTP set and tested should be done ASAP. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 4, 2022 6:36 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer 05-26A (PTD #2012210) Under Eval clock extended 14 days Mr. Regg, Slickline set DGLVs on 12/11/21, but the well subsequently failed another TIFL. Slickline has been scheduled to set a tubing tail plug and perform MITs but are currently delayed due to inclement weather. The Under Evaluation clock will be extended 14 days to perform the MITs. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 7, 2021 7:27 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 05-26A (PTD #2012210) sustained IA casing pressure above MOASP Mr. Regg, Producer 05-26A (PTD # 2012210) was reported to have sustained Inner Annulus casing pressure above MOASP on 12/06/21 after the well was shut-in. DHD performed a failing TIFL indicating a failure of the primary well barrier. The well is now classified as Under Evaluation and is on the 28- day clock for diagnostics. Plan forward: 1. Slickline: Replace GLVs 2. DHD: re-TIFL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. 1 Carlisle, Samantha J (OGC) From:Regg, James B (OGC) Sent:Tuesday, December 7, 2021 8:50 AM To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer 05-26A (PTD #2012210) sustained IA casing pressure above MOASP Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 7, 2021 7:27 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 05‐26A (PTD #2012210) sustained IA casing pressure above MOASP Mr. Regg, Producer 05‐26A (PTD # 2012210) was reported to have sustained Inner Annulus casing pressure above MOASP on 12/06/21 after the well was shut‐in. DHD performed a failing TIFL indicating a failure of the primary well barrier. The well is now classified as Under Evaluation and is on the 28‐day clock for diagnostics. Plan forward: 1.Slickline: Replace GLVs 2.DHD: re‐TIFL 3.Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 STATE OF ALASKA II RECEIVED *ALASKA OIL AND GAS CONSERVATION COMMISSIONNOV lt�� REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed �, y Abandon 0 Plug Perforations Fracture Stimulate D Pull Tubing ❑ Operatiohs� 0 Suspend 0 Perforate E1 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set CIBP WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 201-221 3. Address: P.O.Box 196612 Anchorage, Development IJ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21984-01-00 7. Property Designation(Lease Number): ADL 0028326 8. Well Name and Number: PBU 05-26A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12475 feet Plugs measured 10999 feet true vertical 8809 feet Junk measured feet Effective Depth: measured 10999 feet Packer measured See Attachment feet true vertical 8807 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"94#H-40 32-111 32-111 1530 520 Surface 3922 10-3/4"45.5#J-55 31-3953 31-3756 3580 2090 Intermediate 10346 7-5/8"29.7#L-80 30-10376 30-8353 6890 4790 Production Liner 2691 3-1/2"9.2#L-80 9785-12476 7915-8809 10160 10530 Liner 636 5-1/2"17#L-80 10064-10700 8123-8592 7740 6280 Perforation Depth: Measured depth: 10330-10360 feet 11380-11460 feet 11515-11915 feet 12095-12155 feet 12200-12375 feet True vertical depth: 8319-8341 feet feet 8820-8816 feet 8813-8799 feet 8798-8801 feet 8805-8809 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#13Cr80 27-9804 27-7929 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: sockta�� r 2 by1 D L. 6� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 349 29815 23 1440 968 Subsequent to operation: 796 26523 0 500 968 14.Attachments:(required per 20 AAC 25.070.25 071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development IZI' Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil H Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 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: N/A Authorized Name: Oestgaard,Finn Contact Name: Oestgaard,Finn Authorized Title: Production Engineer Challenger Contact Email: Finn.Oestgaard@bp.com Authorized Signature: C 414fa' Date: II/07(17 Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 Vi—t 1 Z"-I 17-itet2 /1r .3 U\1 t - 2 7017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary November 17, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Cast Iron Bridge Plug and Addition of Perforations for Well 05-26A, PTD # 201-221. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Packers and SSV's Attachment PBU 05-26A SW Name Type MD TVD Depscription 05-26A TBG PACKER 9033.65 7361.77 4-1/2" Baker S-3 Perm Packer 05-26A TBG PACKER 9745.55 7885.58 4-1/2" Baker S-3 Perm Packer 05-26A PACKER 9792.07 7920.06 5-1/2" BAKER ZXP PACKER • S I aLa U ❑ O ❑ a W • 0 io ❑ u) c,-; w LC) J N Q ri U o � U _ O W 00 2 O J F II Z d z Ua H u) 00 LL H w 00- RK = J H W 0 w a w J Q a W 0 ' ❑ Ucn N 02 83 co 0 � iu C 0 H 0 oL� v, O a as O } J = H 'Th w > D E as Q H w 0 @eco it w fl CD 2cwn o jj0 � < coI- O QuZ w o aOcnm 0 5 — -Zi > o W Z a J z W TD N w OF_ Ocn go m (n H a w F' 0 d "' o Ci) a Of2 LU OH 0 J U) o nm. Ja50 0 ZOO < U_ C. Q 0 - 0 H a - J W co d CL Ems - W Lj ❑ t0 a' J woZ _ fn = orx of >+ Qom ;n a _ .- O o Zo ri w 0 N 1 cosW .O CI 0to-- F- H x o 0 v Lij W Q M M 0 Z N 2 o W N ,- O `" a E W II - = w _ . a = Q0 O0 a J J ❑ ("1_. ❑ 0 10 w Q 2 g 0 N u_ = J m 7� Z H o 0 Z � 0 M Q O it 3 ❑ Wv- Q ❑ W0E. t o * Zc CO II HTaaNLL ; Z W I- Q r O N W H 5 m N O 0 Q TREE= 4-1/16"CIW • • WELLHEAD= RNC 05-26A SAFETY NOTES: WELL ANGLE>700 ilA 11035'. ACTUATOR= BAKER INITIAL KB.ELE 66' BF EL.EV= 37.3' KOP= 2300' ' ' 2206' --13-1/7 HES X NEI',D=2.813" Max Angle= 94'©11254' Datum MD= NA Datum ND= 8800'SS GAS LFT MAMDFRELS 10-3/4"CSG,45.5#,J-55,D=9.950" — 3914' ST ND DEI/ TYRE VLV LATCH PORT DATE Al 4 3399 3318 32 MNG DOME RK 16 02/01/02 J 3 5622 4953 45 MNG S/0 RK 20 02/01/02 2 7577 63(6 44 MNG DMY RK 0 01/23/02 1 8958 7306 42 MMG DMY RK 0 01/23/02 Minimum ID =2.75" @ 9725' 1 1 9010' —I3-1/T HESX ria I)=2.813' 3-1/2" HES XN NIPPLE X >c ! X36' H 7-518"X 3-1/2"BKR S-3 PKR,13=3.875" /� 9069' —I 3-1/2"I X NP,D=2.813" CASING LEAK H 9096"-9127' I 1 9725' —3-1/2'HES XN NP,D"2.75" 3-1/2'TBG,9.3#,L-80,.0087 bpf,D=2.992" H 9736' 9741' —I BKR OVERSHOT SEAL ASSY X9749° —7-5/8"X 3-1/2"BKR S-3 PKR,D=3.875' ' 9771' —3.1/2"HES XNP,D=2.813" 7-518"X 5-1/2"BKR TACK SLV,D=5.75" —i 9784' � ' 9792' —3-1/2'HES XN NP,13=2.75' 7-5/8"X 5-1/2'BKR ZXP RCF,ID=4.94" — 9797' 7-5/8"X 5-1/2"BKR LAR HGR;,D=4.89" 979r - ' 9803' H 3-1/2"WLEG,I)=2.997 9807" —15-1/2.X 3-1/2'XO,ID=2.992" TC ''OF5-1/2"LNR-ARC —I 10067' 7-5/8"CSG,29.7#,L-80,D=6.875" H 10379' a k 5-1/2'MLLO4JT WINDOW(05-26A) 10699'-10711' 5.1/2"NIPS—TOOK --I 10699' 5-1/2"LNR, 17#,L-80. D=4.892' H —10699 10999' —4-1/2"WFT CEP(10/24/17) PERFORATION SUM 1RY // REF LOG: SWS MI3AORY GR CN_ON 01/14/02 ANGLE AT TCP PERF: 43"@ 10330' , ` Note:Refer to Production DB for historical perf data SIZE SPF WITERVAL Opn/Sgz SHOT SQZ 2" 6 10330-10360 0 10/24/17 2" 4 11380- 11460 C 01/14/02 2" 4 11515-11915 C 01/14/02 i/�000 2" 4 12095-12155 C 01/14/02 PBTD -- 12381' "0"2' 4 12200- 12375 C 01/14/02 - 3-1/2"UR,9.2#,L-80,.0087 bpf,D=2.992' I— 12476' DATE REV BY C OMENTS3 CATE REV BY (X BITS PRUDHOE BAY UNIT 11/28/89 IMTTAL COMPLETION 03/19113 COMM) BF ELEV (03/10/13) WELL: 05-26A 01/17(90 RING ' 11/00/13 PJC KB ELEVATION COMECTION PERMIT No:'2012210 01/23102 SIDETRACK(05-26A) 10/25117 NXVIMJM1✓SET CBP/ADFEFFS(10/24/17) AR No: 50-029-21984-01 08/18/03 CMO/TLP DATUM M)CORRECTION SEC 31,T11 N,R15E,1678'FNL&11'FEL 06/24/04 JIYKAK CASING LEAK 02/04/09 WWSV TREE CD BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg pL`G 2 E CQ 2 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 a O 1" a a, Subject: Corrosion Inhibitor Treatments of GPB DS -05 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 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, off. Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-05 Date: 01/10/2012 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 05-01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -05B 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05 -11A 1960970 50029202520100 Sealed conductor NA NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -13B 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A N/A NA 05 -15B 1960230 50029202550200 Sealed conductor NA NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA N/A N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 Split conductor NA NA N/A N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A 5.1 4/18/2011 05 -21A 1981180 50029219690100 Dust Cover NA NA N/A N/A N/A 05 -22B 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -23B 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA 6.0 N/A 44.2 4/18/2011 -9 05 -26A 2012210 50029219840100 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -27B 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A 05 -28B 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA 1.3 N/A 6.8 4/12/2011 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -338 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 05 -35A 2081340 50029221720100 2.7 NA 2.7 N/A 18.7 4/18/2011 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A 10.2 4/10/2011 05-40 1961590 50029227070000 1.6 N/A 1.6 N/A 16.2 1/10/2012 05-41A 2031700 50029226960100 5.0 NA 5.0 N/A 58.7 1/8/2012 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well /cr54l. 0.5. 07 -03A .JOJ -1'f:fK-10B 11b-CJ.{7 0.5. 02-15A 1-1?-22:~- 0.5. 18-13A Î ~.(L/l-G-12B ~_ V( ...0.5. 05-26A ,~ :::-:3. \\ tf-15-04A rGf5-tYjb 18-02A -7">/_O~.....c18-04B ì}5-055 L 1-01 (':1S-(7j-L5-17 J '.') _.,' ,.~H-18 ~ ~ - -!'" 2-62/Q-17 18¿../t· 8 L5-15 \~ L5-15 _~q; L5-15 \ L5-15 ið()-Cl/&- E-17 '~J-t'lll- G-15A ['J :n Job # 10715406 10715402 10715404 10715395 10715391 10715420 10715374 10621764 10708056 10913000 10900124 10703975 10900129 10708050 10563129 10672368 10913848 10703983 10679055 MCNL MCNL MCNL MCNL MCNL MCNL MCNL RsT RsT UslT USIT RsT RsT RsT RsT RsT RsT RsT RsT ~_¡" P"t".; G'\¿o n; SCANNED JUN ,...J Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: .-fý t ~ Date 06/03/04 05/16/04 05/18/04 04/16/04 03/21/04 08/19/04 01/14/04 02/23/64 03/05/04 12/25/04 11/30/04 02/17/04 12/24/04 02/07/04 11/15/03 04/16/04 09/26/04 04/09/04 02/02/04 Blueline ~8 / '- 22-/ 02/28/05 NO. 3354 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints -- CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 / - 1 1 1 1 1 1 1 1 1 1 1 1 1 J Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99Z03-2. .38 ;dl ATTN: Bñ iJ- '1 " Receive~lJ~--: . .;/~....a~ if j 3 ~~¿, ^ rj ~ '1 DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2012210 Well Name/No. PRUDHOE BAY UNIT 05-26A Operator BP EXPLORATION (ALASKA) INC SP4¿ G.J~~ API No. 50-029-21984-01-00 ,--- Completion Date 1/23/2002 r Completion Status 1-01L Current Status 1-01L UICW MD 12475'" lVD 8809 ~-"------------- --- REQUIRED INFORMATION -------.---------. -- '-'----~'-------'---------'-------'-----'-"~- Directional s_urve~_____--- Mud Log No Samples No -------'------"'----- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset ~ ___Med/F_~~~ Number LI~:;íficatiOI1. (data taken from Logs Portion of Master Well Data Maint) ( Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments -_._-----_.~"_.,-_._-------,------_.---_..,._--_._.__.----_._,----.._--,--_.--,--..,,------,~,._. -....- - 1 10695 12422 Case 12/13/2002 1 10569 22040 Case 3/5/2002 1 0695 12422 Case 12/13/2002 0 Pdf 1 0625N~u~r-óh 11386 IJISVØtifi(¡;åt[òo. 117 48 t$\(ß:rifi~atíd~ ...... . . ... . ... 117 48~ât~:ôt PêOètfâfiPn" ... 10695 12475 Case 12/13/2002 10699 12475 Case 12/13/2002 ROP, NGP C D 0 Asc --"'-----'.---.--.-----...--- - ------- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y / f!) Chips Receíve~ Daily History Received? M, N @N ( Formation Tops Analysis Received? ~ ------.---.------------------.-.---.----..---.--.---.------'------_.- -"-----.------. FÑE~~ ~~ v(l~ ~Ù>~:~ n-=- ~ '0 L- ~ ~ lU I ï t1. \ JIM..-)JJVt"1- ')-q Y. -- Cf, ¡ ( "l ~ t L ~\ry \ \.. ~=--::::=:--=-=-~~-== ~=-=--=-~--=---====---===--:::~ ~13r-~~,r= ( ( d-D / - ,?,?-- J WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COtnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage, Alaska 99501 May 09, 2003 RE: MWD Formation Evaluation Logs: 05-26A, AK-MW-11212 05-26A: Digital Log Images 50-029-21984-01 1 CD Rom I Jl4-ß PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed:~ ~ Date: lo, ,Q. [).3 f~ECEIVED MAY 13 2003 Alaska OH & Gas Cons, Commiseion Anchomga '~, :', é)o¡.-cJa I 113't0 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 12, 2002 RE: MWD Formation Evaluation Logs 05-26A, AK-:MM-11212 1 LDWG formatted Disc with verification listing. API#: 50-029-21984-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~¿ Qf~ Date: 'T r. 'J:'". ~ , ",,,,-,. h. 11' "'~/' ',8,: ~ '"~,,b' ~f::; .V.l;:/J DEC 7 ',> I) '~IJ 0 (00.19 til§'ial~~i(~ ......,..\. " . VI¡ ~ Gas c.,., : 0118. I"~ . AnChortage \4JmmllfJign 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1678' SNL, 11' WEL, SEC. 31, T11 N, R15E, UM :~i~.P N°~Lr~g~~~i~~~~e~:6. 29, T11 N, R15E, UM f .L¡::?L;_Çl4 At total depth ; ("F'~;.: ;~,..! ;, 3939' NSL, 3474' EWL, SEC. 29, T11N, R15E, UM L~,,-~ "',~..:...~ ¡ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 63.70' ADL 028326 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/6/2002 1/12/2002 1/23/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12475 8809 FT 12381 8809 FT 1m Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, Memory CNL, USIT 23. CASING SIZE 20" 10-3/4" 7-5/8" 5-1/2" 3-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 11380' - 11460' 88201 - 8816' 11515'-11915' 8813'-8799' 12095' - 12155' 8798' - 8801' 12200' - 12375' 8805' - 8809' WT. PER FT. 94# 45.5# 29.7# I 29.9# 17# 9.20# 27. Date First Production February 12, 2002 Date of Test Hours Tested (' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well \'.- ~ 7. Permit Number 201-221 8. API Number 50- 029-21984-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 05-26A 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2205' MD 1900' (Approx.) GRADE H-40 J-55 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD ETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 30" 84 sx PF Cement Surface 3914' 13-1/2" 1000 sx CS III, 350 SX 'GI, To Surface 10379' 9-7/8" 300 sx Class 'G' 225 sx CS I 10067' 10699' 6-3/4" 160 sx Class 'G' 9784' 12475' 4-3/4" 29 sx Class 'GI Job wi 34 Bbls CS II AMOUNT PULLED 25. TUBING RECORD DEPTH SET (MD) 9803' PACKER SET (MD) 9033' & 9745' SIZE 3-1/2", 9.3#, 13Cr80 MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect with 100 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD CHOKE SIZE GAS-OIL RATIO GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL OIL GRAVITy-API (CORR) GAs-McF WATER-BBL 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. Form 10-407 Rev. 07-01-80 R B D M S B F l Cß 1:'" >¡:'.~;-3~3~ubmit In Duplicate MAR I 4 2002 (' (' 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 23S8 10791' 8664' 22TS 10825' 8691' 21TS 10887' 8736' Zone 1 B 10950' 8778' 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 Terrie Hubble Title Technical Assistant Date 3,,07.0 05-26A Well Number 201-221 Permit No. / A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 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 Legal Name: 05-26A Common Name: 05-26A Test Date 1/5/2002 Test Depth (TMD) 11,725.0 (ft) Test Type FIT BP EXPLORATION leak-Off Test Summary Test Depth (TVD) 8,615.0 (ft) AMW 8.40 (ppg) Surface 720 (psi) LeåkOff Pressure (BHP) 4,479 (psi) Page 1of1 EMW 10.01 (ppg) ~ ~ Printed: 3/6/2002 3:00:39 PM ( (I I, Page'\~:Öf 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: 12/22/2001 16:30 - 00:00 7.50 MOB P PRE MOVE RIG. PREPARE MODUES FOR MOVE FROM DRILL SITE 04-19A TO DRILL SITE 05-26A. HOLD PJSM WITH RIG CREWS, TRUCK DRIVERS AND SECURITY. START ROLLONG WORK SHOP, CAMP AND PUMP MODULE AT 21:15 HRS. 12/23/2001 00:00 - 06:00 6.00 RIGU P PRE PREPARE RIG FOR MOVE. JACK RIG AND REMOVE MATS. WORK RIG OFF TIGHT LOCATION. REMOVED DERRICK PINS AND LID DERRICK. 06:00 - 15:00 9.00 RIGU P PRE MOVED RIG FROM DS 4 TO OS 5. 15:00 - 19:00 4.00 RIGU P PRE LAY HERCULlTE. SPOTTED SUB COMPLEX. SET PITS. 19:00 - 20:00 1.00 RIGU P PRE R/U AND RAISED DERRICK. 20:00 - 00:00 4.00 RIGU P PRE RU ON RIG FLOOR. BRIDAL DOWN. BERM AROUND PITS. 12/24/2001 00:00 - 01 :30 1.50 RIGU P PRE Hang bridal lines. R/U on rig floor. Seawater in pits. Rig Accepted 0000 hrs 12/24/01. 01 :30 - 02:00 0.50 RIGU P PRE Held pre-spud safety meeting. Reviewed pre-spud checklist. 02:00 - 03:00 1.00 RIGU P PRE Installed 2nd annular valve. R/U hoses to displace diesel from well. 03:00 - 04:30 1.50 RIGU P PRE R/U DSM and pulled BPV. 04:30 - 11 :00 6.50 RIGU P PRE Displace diesel freeze protect from well with seawater. 2 bpm, 90 psi. 1/2 gal of diesel spray on ground, deflected from ice chunk in cuttings tank. Cleaned up immediately. Hole taking some fluid. 11 :00 - 12:00 1.00 RIGU P PRE Set BPV, press test from below. Leakoff from below. 12:00 - 14:30 2.50 WHSUR P DECOMP ND tree. 14:30 - 17:30 3.00 WHSUR P DECOMP N/U BOP's. 17:30 - 00:00 6.50 WHSUR P DECOMP R/U and test BOP's. Witness of test waived by J. Spaulding AOGCC. 12/25/2001 00:00 - 01 :00 1.00 WHSUR P DECOMP Finished BOP test. Unable to test lower pipe rams, XO in way. LID test jt. 01 :00 - 03:00 2.00 WHSUR P DECOMP Pulled blanking plug. Pulled BPV w/ lubricator. Filled hole, 60 bbls. 03:00 - 04:30 1.50 WHSUR P DECOMP M/U landing jt. BOLDS. R/U to pull tubing. 04:30 - 13:00 8.50 PULL P DECOMP Attempt to pull tubing from seal assembly. Pulled max 230K, no go. Work pipe. Set pipe in slips w/ 120K. 13:00 - 15:30 2.50 PULL P DECOMP R/U Schlumberger. Prepare for string shot and chemical cut above seal assembly. 15:30 - 20:00 4.50 PULL P DECOMP PJSM. R/U and RIH w/ CCLlstring shot. Worked thru GLM's and shot in middle of tubing jt @ 9807'. POH. Tool string hung up in SSSV flapper @ 2187'. Attempted to pull E-line while pumping to open flapper, no progress. 20:00 - 00:00 4.00 PULL N DECOMP Wait on Baker Machine Shop, fabricate lock open tool to drop into SSSV. 12/26/2001 00:00 - 08:00 8.00 PULL N DPRB DECOMP CONT. WO MACHINE SHOP TO FABRICATE SLEEVE TO HOLD SSSV FLAPPER OPEN. 08:00 - 10:30 2.50 PULL N DPRB DECOMP SET SLEEVE IN SSSV AND ATTEMPT TO WORK WL TOOL THROUGH SSSV FLAPPER. PUMP DOWN TBG AT 320 PSI AND 2,000 PSI. 10:30 - 12:00 1.50 PULL P DECOMP PULL TOOL FREE THRU SSSV. POOH W/ WL STRING SHOT. BOTTOM RIGID CENTRALIZER LEFT IN HOLE. (LENGTH = 4.0", MAX OD = 1.76"). RD WL TOOLS. 12:00 - 12:30 0.50 PULL P DECOMP PTSM. LD WL TOOLS, CLEAR RIG FLOOR. 12:30 - 15:00 2.50 PULL P DECOMP MONITOR WELL, WAIT ON SLlCKLlNE UNIT FOR TOOL RUNS AND POSSIBLE FISHING. CONTINUE TO WORK Printed: 1/29/2002 8:18:23 AM ( ( Legal Well Name: 05-26A Common Well Name: 05-26A Spud Date: 11/9/1989 Event Name: REENTER+COMPLETE Start: 12/24/2001 End: Contractor Name: NABORS Rig Release: 1/23/2002 Rig Name: NABORS 2ES Rig Number: Date Fr()m....~T 0 tigqr~ ActiVitýCqdé 12/26/2001 12:30 - 15:00 2.50 PULL P DECOMP PIPE TO 230K - NO-GO. 15:00 - 17:00 2.00 PULL P DECOMP PJSM. RU SLlCKLlNE EQUIPMENT. 17:00 - 19:30 2.50 PULL P DECOMP RIH AND RETREIVE SLEEVE FROM SSSV. 19:30 - 20:30 1.00 PULL P DECOMP RIH AND CHECK SSSV INTEGRITY AND FLAPPER OPENING - OKAY. 20:30 - 21 :30 1.00 PULL P DECOMP SET HOLE OPENING SLEEVE THRU SSSV. 21 :30 - 22:00 0.50 PULL P DECOMP RIH WI 2.77" GUAGE RING. STACKED UP ON OBSTRUCTION AT 2,573'. POOH. 22:00 - 23:00 1.00 PULL P DECOMP RIH WI IMPRESSION BLOCK. INDICATION WAS THAT CENT WAS JAMMED AT AN ANGLE. 23:00 - 00:00 1.00 PULL P DECOMP PU MULE SHOE (2.77" OD) ON SLlCKLlNE, RIH AND KNOCK FISH FREE, CONT. RIH. 12/27/2001 00:00 - 02:00 2.00 PULL P DECOMP POOH WI SL. RD SL TOOLS AND CLEAR FLOOR. 02:00 - 04:30 2.50 PULL P DECOMP RU EL, MU 2-3/8" CHEM CUTTER WI 2 EA 2"X48" CHEM TUBES AND 14.5 GRAIN CHARGE. 04:30 - 07:00 2.50 PULL P DECOMP PJSM. PU CHEM CUTTER, RIH. 07:00 - 07:30 0.50 PULL P DECOMP CORRELATE TO DEPTH, CUT TBG AT 9,807' WLD, W/155K OF TENSION IN STRING. 07:30 - 09:00 1.50 PULL P DECOMP POOH WI EL AND CHEM CUTTER. LD CUTTER. PULL 135K ON TBG, TBG FREE. 09:00 - 09:30 0.50 PULL P DECOMP RD E-LlNE. 09:30 - 10:00 0.50 PULL P DECOMP STAB IN, PULL HNGR TO FLOOR, AND LD. 10:00 - 11 :00 1.00 PULL P DECOMP RU CASING EQUIP., RU CONTROL LINE SPOOLING EQUIP. . 11 :00 - 16:30 5.50 PULL P DECOMP PJSM. PULL 4-1/2" TBG, CONTROL LINES AND INJ LINE. LD 73 JTS OF 4-1/2" TBG, SSSV. 16:30 - 17:00 0.50 PULL P DECOMP CIO TO 3-1/2" HANDLING EQUIP. 17:00 - 00:00 7.00 PULL P DECOMP LD 3-1/2" TBG. 12/28/2001 00:00 - 08:00 8.00 PULL P DECOMP CONT. TO PULL AND LD 3-1/2" TBG. 08:00 - 09:30 1.50 PULL P DECOMP LD CSG EQUIPMENT, CLEAR FLOOR. 09:30 - 10:00 0.50 BOPSU P DECOMP RU BOP TEST EQUIPMENT. 10:00 - 11 :00 1.00 BOPSU P DECOMP TEST LOWER PIPE RAM, 4" TIW & DART VALVES 250 I 3500 PSI- OK. 11 :00 - 11 :30 0.50 PULL P DECOMP SET WB. 11 :30 - 12:00 0.50 FISH P DECOMP PU FISHING BHA #1. 12:00 - 13:00 1.00 FISH P DECOMP MU BHA #1. 13:00 - 16:00 3.00 FISH P DECOMP PJSM. PU 4" DP FROM PIPESHED, RIH TO 2,572'. 16:00 - 17:00 1.00 FISH P DECOMP CUT AND SLIP 136' OF DRILL LINE. 17:00 - 18:00 1.00 FISH P DECOMP SERVICE TOP DRIVE I CROWN. CLEAN RIG FLOOR. 18:00 - 00:00 6.00 FISH P DECOMP CONT. PU DP AND RIH TO 8,619'. 12/29/2001 00:00 - 01 :00 1.00 FISH P DECOMP CONT. TO PU 4" DP FROM PIPE SHED. TAG UP ON FISH AT 9,807'. 01 :00 - 01 :30 0.50 FISH P DECOMP OBTAIN PARAMETERS FOR FISHING: UP WT = 205K, OWN WT=135K, ROT=170K, TRQ 7K FT-LB AT 50 SPM AND 125 PUMP PSI. ENGAGE SEAL ASSEMBLY FISH AT 9,807'. JAR FREE AT 250K. 01 :30 - 02:30 1.00 FISH P DECOMP PUMP HI-VIS SWEEP, AT 216 SPM, 526 GPM. 02:30 - 07:30 5.00 FISH P DECOMP POOH TO BHA. 07:30 - 10:00 2.50 FISH P DECOMP POOH WI BHA, LD FISHING TOOLS AND FISH. FULL RECOVERY OF SEAL ASSEMBLY 10:00 - 11 :30 1.50 FISH P DECOMP PU MILLING BHA#2 AND RIH. 11 :30 - 15:30 4.00 FISH P DECOMP RIH TO 9,819', TAG PACKER. 193K-UP, 138K-DWN, 165K-ROT. 15:30 - 16:00 0.50 FISH P DECOMP HOOK UP BLOWER HOSE AND REMOVE AIR SLIPS. Printed: 1/29/2002 8:18:23 AM (" ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES 12/29/2001 16:00 - 19:30 3.50 FISH P tloLJrs ActivityÇode NPT Phase 12/30/2001 12/31/2001 1/1/2002 19:30 - 21 :30 2.00 FISH P 21 :30 - 22:30 1.00 FISH P 22:30 - 00:00 1.50 FISH P 00:00 - 03:00 3.00 FISH P 03:00 - 04:30 1.50 FISH P 04:30 - 06:00 1.50 FISH P 06:00 - 07:00 1.00 FISH P 07:00 - 08:00 1.00 FISH P 08:00 - 10:00 2.00 FISH P 10:00 - 10:30 0.50 FISH P 10:30 - 11 :00 0.50 FISH P 11 :00 - 15:30 4.50 FISH P 15:30 - 16:30 1.00 FISH P 16:30 - 18:30 2.00 FISH P 18:30 - 20:00 1.50 FISH P 20:00 - 20:30 0.50 FISH P 20:30 - 21 :30 1.00 FISH P 21 :30 - 22:00 0.50 FISH P 22:00 - 00:00 2.00 FISH P 00:00 - 00:30 0.50 STWHIP P 00:30 - 01 :30 1.00 STWHIP P 01 :30 - 04:00 2.50 STWHIP P 04:00 - 04:30 0.50 STWHIP P 04:30 - 05:00 0.50 STWHIP P 05:00 - 06:00 1.00 STWHIP P 06:00 - 10:00 4.00 STWHIP P 10:00 - 11 :30 1.50 STWHIP P 11 :30 - 17:30 6.00 STWHIP P 17:30 - 20:00 2.50 STWHIP P 20:00 - 20:30 0.50 STWHIP P 20:30 - 22:00 1.50 STWHIP P 22:00 - 00:00 2.00 STWHIP P 00:00 - 01 :00 1.00 STWHIP P 01 :00 - 03:00 2.00 STWHIP P 03:00 - 13:00 10.00 STWHIP P Pagé3 of 13 Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: Descriptiooof Operations DECOMP MILL PKR FROM 9,819' TO 9,822'. TRQ ROTATING FREE ABOVE PKR = 11K FT-LB, TRQ WHILE MILLING = 12-15K FT-LB. DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PUMP HI-VIS SWEEP AT 230 GPM AND 1,200 PSI. PULL FIRST 3 STDS WORKING PIPE TO 250K-275K. CONT. POOH STDS 4-38 W/ MINIMAL OVERPULL. POOH TO BHA. LD BHA, LD 7-5/8" PKR, TBG PUP + 15.44' CUTOFF. CLEAR FLOOR, PUlMU OVERSHOT BHA FOR TBG ASSEMBLY FISH. RIH TO 2,638'. SERVICE TOP DRIVE. RIH TO 9,830', ABOVE TBG STUB. OBTAIN FISHING PARAMATERS: UP WT+186K, DN WT=143K, ROT=163K, 50 SPM @ 160 PSI. TAG FISH AT 9,865'. DRESS OFF FISH TO 9,867'. PU UP WT = 190K MONITOR WELL - OK. POOH TO BHA. STAND BACK BHA, LD OVERSHOT IN PIPE SHED. CLEAR FLOOR, PU CSG TOOLS AND RU. LD FISH - 2 GLM, 3 JTS OF 3-1/2" TBG, 24 JTS OF 2-7/8" TBG PLUS 28.2' CUTOFF JT. RD CSG TOOLS. PU OVERSHOT AND LD. PU MILLS FOR GAUGE RUN. RIH WI 4-3/4" DC. LD SAME. CONT. LD 4-3/4" DC. CLEAR RIG FLOOR, RU 2-7/8" HANDLING EQUIP. PUIMU BHA #4 FOR GAUGE RUN. PU 21 JTS OF 2-7/8" DP. RD 2-7/8" HANDLING EQUIP. RIH WI 4" DP TO 1,382'. CUT AND SLIP 96' OF DRILL LINE. RIH, WASH THRU LINER TOP AREA FROM 10,034-10,097' WITH 98 SPM AND 1,100 PSI. CONT. RIH TO 10,800'. PUMP SWEEP AND AND CHANGE WELL FLUID OVER TO 8.4 PPG MILLING FLUID. MONITOR WELL, POOH TO 2-7/8" DP. CIO HANDLING EQUIP. LD BHA. CLEAR RIG FLOOR. PJSM, RU WL AND 5.5" EZSV. RIH WI EZSV, CORRELATE, SET AT 10,730' WLD, POOH. CO NT. POOH, WI WL, RD SAME. RIH WI 4" DP, SET STORM PKR, 10' BELOW 7-5/8" CSG PACKOFF. PULL WB, MU PACKOFF RETREIVING TOOL, CHK ANNULUS PRESSURE (0 PSI), COULD NOT PULL PACKOFF, STEAM WELLHEAD, UNABLE TO PULL FREE WITH 80K LB OF OVERPULL. MU BUMPER SUB AND BUMPED FREE WI 80K PULL. PACKOFF PULLING TOOLS HIGHLY FATIGUED, AND C/O. MU NEW PACKOFF RUNNING TOOL, SET PACKOFF AND RUN IN LDS. Printed: 1/29/2002 8:18:23 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/1/2002 03:00 - 13:00 ( BPEXPLORATION Operations<Summary.Report 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES Hql.Jr§.AçtivityÇod.~ NPT Phase 10.00 STWHIP P WEXIT 13:00 -14:30 1.50 STWHIP P WEXIT 14:30 - 15:30 1.00 STWHIP P WEXIT 15:30 - 16:00 0.50 STWHIP P WEXIT 16:00 - 20:00 4.00 STWHIP P WEXIT 20:00 - 20:30 0.50 STWHIP P WEXIT 20:30 - 21 :30 1.00 STWHIP P WEXIT 21 :30 - 22:00 0.50 STWHIP P WEXIT 22:00 - 23:00 1.00 STWHIP N DPRB WEXIT 23:00 - 00:00 1.00 STWHIP N DPRB WEXIT 1/2/2002 00:00 - 05:00 5.00 STWHIP N DPRB WEXIT 05:00 - 05:30 0.50 STWHIP N DPRB WEXIT 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30 - 07:00 0.50 STWHIP P WEXIT 07:00 - 07:30 0.50 STWHIP P WEXIT 07:30 - 08:00 0.50 STWHIP P WEXIT 08:00 - 08:30 0.50 STWHIP P WEXIT 08:30 - 09:00 0.50 STWHIP P WEXIT 09:00 - 09:30 0.50 STWHIP P WEXIT 09:30 - 10:00 0.50 STWHIP P WEXIT 10:00 - 15:00 5.00 STWHIP P WEXIT 15:00 - 15:30 0.50 STWHIP P WEXIT 15:30 - 16:00 0.50 STWHIP P WEXIT 16:00 - 20:00 4.00 STWHIP P WEXIT 20:00 - 00:00 4.00 STWHIP P WEXIT 1/3/2002 00:00 - 05:30 5.50 STWHIP P WEXIT 05:30 - 07:30 2.00 STWHIP P WEXIT 07:30 - 08:30 1.00 STWHIP P WEXIT 08:30 - 10:30 2.00 STWHIP N DPRB WEXIT 10:30 - 12:00 1.50 STWHIP N DPRB WEXIT Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: [)esçriptiqn.qfÇ)peratiöns TEST PACKOFF TO 5,000 PSI FOR 10 MIN - OKAY. TEST CHOKE MANIFOLD, MANUAL, HYD CHOKES TO 250/3,500 PSI- OKAY. RD PACKOFF RUNNING TOOLS. RIH AND RETREIVE STORM PKR, LD SAME. POOH WI 4" DP. PJSM, RUN TEST PLUG, RU TO TEST BOPE. PRESSURE TEST BLIND, PIPE RAMS, ANNULAR TO 250/3500 PSI- OKAY. TEST FLOOR SAFETY VALVES TO 250/3,500 PSI- OKAY. RD TEST EQUIP, INSTALL WB. TEST 7-5/8" CSG, AD 5-1/2" LINER TO 3,500 PSI. PRESSURE BLED DOWN 600 PSI IN 5 MIN. CHK ALL SURFACE SI EQUIP. REPRESSURE TO 3,600 PSI, BLED DOWN TO 2,850 PSI IN 5 MIN. SERVICE TOP DRIVE. PUlMU 7-5/8" RTS PKR. RIH WI RTTS PKR. PTSM, CHK CROWN-O-MATIC. CONT RIH WI RTTS PKR. UP WT = 175K, DWT = 145K. SET PKR AT 10,051' (16' ABOVE LINER LAP). PRESSURE TEST 7-5/8" CSG TO 3,500 PSI- OKAY. PRESSURE TEST LINER LAP AND 5-1/2" LINER TO 3,500 PSI - OKAY. RELEASE PKR. POOH TO 9,983', SET PKR. PRESSURE TEST 7-5/8" CSG TO 3,500 PSI- OKAY. PRESSURE TEST LINER LAP AND 5-1/2" LINER TO 3,500 PSI - OKAY. RELEASE PKR. BLOW DOWN SURFACE EQUIPMENT. PULL WET STRING. (MECHANICS WORKING ON IRON ROUGHNECK HYDRAULIC LEAKS). LD PKR, CLEAR RIG FLOOR. PRESSURE TEST 5-1/2"X7-5/8" CSG TO 3,500 PSI FI 10 MIN - OKAY. MU WHIPSTOCK + WINDOW MILLING ASSEMBLY, AND MWD. SURFACE TEST MWD - OK, RIH, SHALLOW TEST MWD - OK. CIO HANDLING EQUIP, RIH WI 4" DP TO 4,016. NOTE: UNABLE TO TORQUE-UP WI IR, HAVE TO SPIN WI IR, TORQUE UP WI TONGS. CALLED NABORS CHIEF MECHANIC. PTSM. RIH WI WHIPSTOCK TO 10,643'. ORIENT WHIPSTOCK 85 DEG RHS. RIH TO 10743', DID NOT TAG UP SOLID ON EZSV. RIH SLOWLY TO 10,766', DID NOT TAG EZSV. POOH LOGGING WI GR FROM 10,745' TO 10580' - ON DEPTH. RIH SLOWLY FROM 10,580' TO 10,811'. DID NOT TAG UP Printed: 1/29/2002 8:18:23 AM ( ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: Date From- To Hours» Ac:tivityÇqg(3 NPT Phasé Dt3sçriptipo ...ofqpØrêtion~ 1/3/2002 10:30 - 12:00 1.50 STWHIP N DPRB WEXIT ON EZSV. 12:00 - 18:00 6.00 STWHIP N DPRB WEXIT PTSM, POOH WI WHIPSTOCK. 18:00 - 20:30 2.50 STWHIP N DPRB WEXIT LD WHIPSTOCK AND WINDOW MILLING BHA ASSEMBLY. 20:30 - 21 :30 1.00 STWHIP N DPRB WEXIT CIO HANDLING EQUIPMENT. 21 :30 - 22:30 1.00 STWHIP N DPRB WEXIT PU BULLNOSE AND 3 JTS OF 2-7/8" TBG. MU WHIPSTOCK AND WINDOW MILLING BHA. 22:30 - 00:00 1.50 STWHIP N DPRD WEXIT RIH WI WHIPSTOCK AND WINDOW MILLING BHA. 1/4/2002 00:00 - 02:30 2.50 STWHIP N DPRD WEXIT CO NT. IN HOLE TO 842'. 02:30 - 08:30 6.00 STWHIP N DPRD WEXIT CIO HANDLING TOOLS, RIH TO 7,467'. 08:30 - 09:30 1.00 STWHIP N SFAL WEXIT REPAIR TOP DRIVE. (OIL FILTER SEAL LEAK). 09:30 - 11 :00 1.50 STWHIP N DPRB WEXIT CO NT. RIH TO 10,766'. 11 :00 - 12:00 1.00 STWHIP P WEXIT ORIENT WHIPSTOCK 81 DEG RHS. 12:00 - 13:00 1.00 STWHIP P WEXIT RIH TO 10,814' AND TAG EZSV. SET ANCHOR (SHEARED WI 25K OWN). 13:00 - 19:30 6.50 STWHIP P WEXIT MILL WINDOW FROM 10,699' TO 10,711 ' AT 2-3 FT/HR. DRILL CEMENT AND NEW FM TO 10,716' AT 1.0 - 0.5 FTIHR. 19:30 - 20:30 1.00 STWHIP P WEXIT WORK PILOT MILL AND LOWER-STRING MILL THRU WINDOW AND REAM BACK TO BTM. 20:30 - 21 :00 0.50 STWHIP P WEXIT DRILL 0.1' IN HALF AN HOUR, WITH VARYING DRILLING PARAMETERS. NO PROGRESS. 21 :00 - 23:00 2.00 STWHIP P WEXIT DROP DART, OPEN PUMP OUT SUB. PUMP SWEEP. 23:00 - 00:00 1.00 STWHIP P WEXIT POOH TO 10,061', (6' ABOVE LINER LAP). 1/5/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT RECIPROCATE AND ROTATE PIPE FROM 10, 061', PUMP HI-VIS SWEEP AND WASH LINER LAP. CIRC BOTTOMS UP. PUMP SLUG. 01 :30 - 02:30 1.00 STWHIP P WEXIT CUT AND SLIP DRILL LINE. 02:30 - 03:00 0.50 STWHIP P WEXIT SERVICE TOP DRIVE. 03:00 - 07:00 4.00 STWHIP P WEXIT POOH TO BHA. 07:00 - 08:00 1.00 STWHIP P WEXIT RU HANDLING EQUIP FOR 2-7/8'.' DP. 08:00 - 11 :00 3.00 STWHIP P WEXIT LD MWD. (LOWER STRING MILL 1/4" OUT OF GAUGE, PILOT MILL WORN FLAT). 11 :00 - 11 :30 0.50 STWHIP P WEXIT CLEAR RIG FLOOR. 11 :30 - 15:00 3.50 STWHIP P WEXIT MU MILLING BHA 15:00 - 16:30 1.50 STWHIP P WEXIT RIH TO 5,000' 16:30 - 17:00 0.50 STWHIP P WEXIT BREAK CIRC., BLOW DOWN TO. 17:00 - 18:30 1.50 STWHIP P WEXIT CONT. RIH TO 10,000'. 18:30 - 19:00 0.50 STWHIP P WEXIT BREAK CIRC., BLOW DOWN TO. 19:00 - 19:30 0.50 STWHIP P WEXIT CONT. RIH TO 10,709'. UP=185K,DWN=145K. 19:30 - 22:30 3.00 STWHIP P WEXIT REAM TO BTM AT 10,716'. DRILL AHEAD TO 10,725'. FIRST FOOT DRILLED AT 8'/HR, NEXT TWO FEET DRILLED AT 6'/HR, REMAINING 6' DRILLED AT RATE DECREASING TO LESS THAN 2'/HR. 22:30 - 23:00 0.50 STWHIP P WEXIT POOH TO ABOVE WHIPSTOCK AT 10,695'. PERFORM FIT, PUMPING 1.2 BBL OF 8.4 MUD, AT 1/4BBL/MIN, TO A SURFACE PRESSURE OF 720 PSI. EMW=10.0 PPG AT 8,615' lVD. SHUT DOWN PUMP, SHUT IN AND MONITOR FOR 10 MIN, WITH STABLE SI PRESS. 23:00 - 00:00 1.00 STWHIP P WEXIT PUMP SLUG, POOH TO 9,599'. 1/6/2002 00:00 - 03:00 3.00 STWHIP P WEXIT CO NT. POOH TO BHA. 03:00 - 03:30 0.50 STWHIP P WEXIT RU 2-7/8" HANDLING EQUIP. 03:30 - 05:00 1.50 STWHIP P WEXIT LD WINDOW MILLING BHA. 05:00 - 05:30 0.50 STWHIP P LNR1 CLEAR RIG FLOOR. Printed: 1/29/2002 8:18:23 AM ( ( BPEXPI.i.ORATION Operations Summary Report Legal Well Name: 05-26A Common Well Name: 05-26A Spud Date: 11/9/1989 Event Name: REENTER+COMPLETE Start: 12/24/2001 End: Contractor Name: NABORS Rig Release: 1/23/2002 Rig Name: NABORS 2ES Rig Number: H(:>4 r$!:\c:~ivity .. ç()ct~ NPT 1/6/2002 05:30 - 08:30 3.00 STWHIP P LNR1 PJSM, MU ANGLE BUILD DRILLING ASSEMBLY. 08:30 - 09:00 0.50 STWHIP P LNR1 SHALLOW TEST MWD - OKAY. 09:00 - 11 :30 2.50 STWHIP P LNR1 PU 39 JTS OF 2-7/8" AOH DP FROM THE PIPE SHED, FILL PIPE, SHALLOW TEST MWD AT 1,104' AND 1,419' - OK. RD 2-7/8 HANDLING EQUIP, RU 4" EQUIP. 11 :30 - 13:00 1.50 STWHIP P LNR1 RIH TO 5,000'. 13:00 - 13:30 0.50 STWHIP P LNR1 BREAK CIRC. AND TEST MWD - OK. 13:30 - 14:30 1.00 STWHIP P LNR1 CONT. RIH TO 10,000'. 14:30 - 15:00 0.50 STWHIP P LNR1 BREAK CIRC. AND TEST MWD - OK. 15:00 - 15:30 0.50 STWHIP P LNR1 CONT. RIH TO 10,649'. 15:30 - 16:00 0.50 STWHIP P LNR1 ORIENT MWD AT 10,649', 50' ABOVE THE WINDOW, TO 81 DEG RHS. 16:00 - 16:30 0.50 STWHIP P LNR1 CONT. RIH TO 10,725'. 16:30 - 00:00 7.50 STWHIP P LNR1 SLIDE DRILL WI 2.38 DEG MOTOR FROM 10,725' TO 10,823'. UP=170K, DWN=140K. LWD WI GR. 1/7/2002 00:00 - 08:30 8.50 DRILL P LNR1 CONT. TO DRILL 4-3/4" HOLE TO 10, 992'. 08:30 - 11 :00 2.50 DRILL P LNR1 CHK SHOT SURVEYS FOR CAZANDRA SURVEY CORECTIONS. 11 :00 - 12:00 1.00 DRILL P LNR1 POOH TO ABOVE LINER LAP, DROP DART, OPEN PUMP OUT SUB. 12:00 - 13:30 1.50 DRILL P LNR1 CIRC SWEEP WHILE RECIPROCATING. PUMP SLUG. 13:30 - 16:00 2.50 DRILL P LNR1 CONT. POOH TO 3,005'. 16:00 - 17:00 1.00 DRILL P LNR1 SERVICE TOP DRIVE. 17:00 - 18:00 1.00 DRILL P LNR1 CONT. POOH TO 2-7/8" DP/BHA. 18:00 - 18:30 0.50 DRILL P LNR1 CIO ELEVATORS AND TONGS FOR HANDLING BHA. 18:30 - 20:30 2.00 DRILL P LNR1 LD BHA. 20:30 - 21 :00 0.50 DRILL P LNR1 CLEAR RIG FLOOR. 21 :00 - 22:00 1.00 DRILL P LNR1 MU BHA WI 2.89 DEG MOTOR HOUSING. 22:00 - 23:00 1.00 DRILL P LNR1 SURFACE TEST MWD - OKAY. 23:00 - 23:30 0.50 DRILL P LNR1 RIH TO 1,404'. 23:30 - 00:00 0.50 DRILL P LNR1 CIO ELEVATORS AND TONGS TO 4" HANDLING EQUIP. 1/8/2002 00:00 - 01 :00 1.00 DRILL P LNR1 RIH WITH 4" DRILL PIPE FROM 1404' TO 5000' 01 :00 - 01 :30 0.50 DRILL P LNR1 BREAK CIRCULATION. TEST MWD TOOLS 01 :30 - 03:00 1.50 DRILL P LNR1 RIH FROM 5000' TO 9990' 03:00 - 03:30 0.50 DRILL P LNR1 BREAK CIRCULATION. TEST MWD TOOLS 03:30 - 04:30 1.00 DRILL P LNR1 CUT AND SLIP 92' OF 1 1/4" DRILLING LINE 04:30 - 05:30 1.00 DRILL P LNR1 RIH FROM 9990' TO 10646'. ORIENT TOOL FACE AT 10646'. RIH TO 10992' 05:30 - 06:00 0.50 DRILL P LNR1 LOG HOLE FROM 10972' TO 10992' DUE TO SENSOR SPACING DIFFERENCE ON BHA 06:00 - 12:00 6.00 DRILL P LNR1 DRILL 4 3/4" HOLE FROM 10992' TO 11110' 12:00 - 12:30 0.50 DRILL P LNR1 CIRCULATE AT 11110' 12:30 - 13:00 0.50 DRILL P LNR1 POH TO 10067' TOP OF 5 1/2" LINER. DROP DART TO OPEN CIRCULATING SUB. 13:00 - 14:00 1.00 DRILL P LNR1 CIRCULATE AT 300 GPM AND RECIPROCATE PIPE AT TOP OF 51/2" LINER 14:00 - 17:00 3.00 DRILL P LNR1 POH TO 1404' 17:00 - 17:30 0.50 DRILL P LNR1 CHANGE OUT ELEVATORS AND RIG UP POWER TONGS 17:30 - 18:00 0.50 DRILL P LNR1 POH TO 174', TOP OF BHA 18:00 - 19:30 1.50 DRILL P LNR1 LAY DOWN BHA #6 19:30 - 20:00 0.50 DRILL P LNR1 CLEAR RIG FLOOR 20:00 - 20:30 0.50 DRILL P LNR1 PULL WEAR BUSHING 20:30 - 00:00 3.50 DRILL P LNR1 TEST BOP AND ALL RELATED VALVES TO 250 PSI LOW Printed: 1/29/2002 8:18:23 AM f ( BP EXPLORATION Operations Summary Repo.rt Legal Well Name: 05-26A Common Well Name: 05-26A Spud Date: 11/9/1989 Event Name: REENTER+COMPLETE Start: 12/24/2001 End: Contractor Name: NABORS Rig Release: 1/23/2002 Rig Name: NABORS 2ES Rig Number: tlours i\ctiyitYGqd(9 NPT p(9~çdþ~iÞnþfQpør~~ioO$ 1/8/2002 20:30 - 00:00 3.50 DRILL P LNR1 AND 3500 PSI HIGH FOR 10 MINUTES. NOTE: JOHN CRISP OF AOGCC WITNESSED TEST. 1/9/2002 00:00 - 01 :00 1.00 DRILL P LNR1 TEST BOP AND ALL RELATED VALVES TO 250 PSI LOW AND 3500 PSI HIGH FOR 10 MINUTES. NOTE: JOHN CRISP OF AOGCC WITNESSED TEST. 01 :00 - 02:30 1.50 DRILL P LNR1 MAKE UP BHA AND NEW PDC BIT 02:30 - 03:00 0.50 DRILL P LNR1 TEST MWD. OK. 03:00 - 04:00 1.00 DRILL P LNR1 RIH. PICK UP 2 7/8" DRILL PIPE FROM PIPE SHED. 04:00 - 04:30 0.50 DRILL P LNR1 BREAK CIRCULATION AND TEST MWD. OK 04:30 - 05:00 0.50 DRILL P LNR1 RIH TO 1607'. PICK UP 27/8" DRILL PIPE FROM PIPE SHED. 05:00 - 05:30 0.50 DRILL P LNR1 BREAK CIRCULATION AND TEST MWD. OK 05:30 - 06:00 0.50 DRILL P LNR1 RIH WITH 2 7/8" DRILL PIPE TO 2836'. CHANGE OUT HANDLING TOOLS FROM 2 7/8" TO 4". 06:00 - 07:00 1.00 DRILL P LNR1 RIH WITH 4" DRILL PIPE TO 6568' 07:00 - 07:30 0.50 DRILL P LNR1 BREAK CIRCULATION AND TEST MWD. OK 07:30 - 09:00 1.50 DRILL P LNR1 RIH TO 10640'. STRING WEIGHT UP 170,000, DOWN 140,000 AND ROTATING 150,000, TORQUE 5,000 FT/LBS. 09:00 - 09:30 0.50 DRILL P LNR1 ORIENT TOOL FACE. 09:30 - 10:00 0.50 DRILL P LNR1 RIH TO 10968' 10:00 - 10:30 0.50 DRILL P LNR1 BENCH MARK SURVEY AT 10968'. OK. 10:30 - 13:00 2.50 DRILL P LNR1 DRILL 43/4" HOLE FROM 11110' TO 11174'. AST 0.8. ART 1.0 13:00 - 17:30 4.50 DRILL N DPRB LNR1 SURVEY CHECK SHOTS DUE TO INCONSISTENT SURVEY DATA. COMMUNICATE WITH ANCHORAGE DRILLING OFFICE. 17:30 - 00:00 6.50 DRILL N LNR1 DRI LL 4 3/4" HOLE FROM 11174' TO 11257'. ART=0.5 HRS AST=4.8 HRS 1/10/2002 00:00 - 00:00 24.00 DRILL P PROD1 DRILL 43/4" HOLE FROM 11257' TO 11715'. ROTATE AND SLIDE TO CONTROL DIRECTION AND ANGLE ART=5.6 HRS AST=6.9 HRS 1/11/2002 00:00 - 03:00 3.00 DRILL P PROD1 DRILL 4 3/4" HOLE FROM 11715' TO 11797' . ROTATE AND SLIDE TO CONTROL DIRECTION AND ANGLE ART=0.6 HRS AST=1.6 HRS 03:00 - 04:00 1.00 DRILL N DPRB PROD1 DIRECTIONAL SURVEY AT 11797'. PROBLEMS READING SURVEY DUE TO NOISE CAUSED BY DOWN HOLE TOOL VIBERATION 04:00 - 06:00 2.00 DRILL P PROD1 DRILL 43/4" HOLE FROM 11797' TO 11860'. ROTATE AND SLIDE TO CONTROL DIRECTION AND ANGLE ART=0.9 HRS AST=0.5 HRS 06:00 - 06:30 0.50 DRILL N DPRB PROD1 DIRECTIONAL SURVEY AT 11860'. PROBLEMS READING SURVEY DUE TO NOISE CAUSED BY DOWN HOLE TOOL VIBERATION 06:30 - 00:00 17.50 DRILL P PROD1 DRILL 43/4" HOLE FROM 11860' TO 12170'. ROTATE AND SLIDE TO CONTROL DIRECTION AND ANGLE ART=8.1 HRS AST=6.3 HRS 1/12/2002 00:00 - 14:00 14.00 DRILL P PROD1 DRILL 43/4" HOLE FROM 12170' TO 12475'. ROTATE AND Printed: 1/29/2002 8:18:23 AM ( (' BP EXPLORATION Operations SlImmaryReport Page80f 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: . Date Ftom ~To Hour~ Acliyily.Codè NPT Phase PÉ!scriptiqn....ofOperatioþ~ 1/12/2002 00:00 - 14:00 14.00 DRILL P PROD1 SLIDE TO CONTROL DIRECTION AND ANGLE ART=5.2 HRS AST=5.7 HRS 14:00 - 14:30 0.50 DRILL P PROD1 CIRCULATE 4 3/4" OPEN HOLE, 5 1/2" LINER AND 1000' OF 7 5/8" ANNULUS VOLUME. MONITOR WELL, STATIC. 14:30 - 15:30 1.00 DRILL P PROD1 POHT010675'. 51/2"WINDOWAT10711'. NO PROBLEMS. 15:30 - 16:30 1.00 DRILL P PROD1 SLIP AND CUT DRILLING LINE 16:30 - 17:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE 17:00 - 18:00 1.00 DRILL P PROD1 RIH TO BOTTOM AT 12475'. NO PROBLEMS. 18:00 - 19:00 1.00 DRILL P PROD1 CIRCULATE 4 3/4" OPEN HOLE, 5 1/2" LINER AND 1000' OF 7 5/8" ANNULUS VOLUME. MONITOR WELL, STATIC. 19:00 - 20:00 1.00 DRILL P PROD1 POH TO 10067'. SLM. NO PROBLEMS 20:00 - 21 :30 1.50 DRILL P PROD1 OPEN PUMP OUT SUB WITH 3700 PSI. CIRCULATE HIGH VIS SWEEP. SLUG PIPE. MONITOR WELL, STATIC. DROP DRILLPIPE DRIFT. 21 :30 - 00:00 2.50 DRILL P PROD1 POH TO 2836'. SLM. 1/13/2002 00:00 - 04:00 4.00 DRILL P PROD1 POH. SLM. LAY DOWN BHA. 04:00 - 04:30 0.50 CASE P COMP RIG UP TO RUN 31/2" LINER. HOLD PJSM WITH DRILLING CREW. 04:30 - 05:00 0.50 CASE P COMP RUN 31/2" LINER FLOAT EQUIPMENT AND CHECK SAME. OK. 05:00 - 08:30 3.50 CASE P COMP RUN 89 JTS 3 1/2" 9.2# NSCT L-80 LINER. FILL EVERY 5 JOINTS. 08:30 - 09:00 0.50 CASE P COMP CHANGE OUT HANDLING TOOLS. PICK UP BAKER 7 5/8" X 51/2" FLEXLOCK HYDRAULIC LINER HANGER. 09:00 - 09:30 0.50 CASE P COMP CIRCULATE LINER VOLUME AT 5 BPM WITH 630 PSI. 09:30 - 14:30 5.00 CASE P COMP RIH WITH 31/2" LINER ON 4" DRILL PIPE TO 10600'. FILL PIPE EVERY 1 0 STANDS. 14:30 - 15:00 0.50 CASE P COMP MAKE UP CEMENT HEAD AND LAY DOWN ON PIPE SKATE. 15:00 - 15:30 0.50 CASE P COMP CIRCULATE DRILL PIPE AND LINER VOLUME. AT 5 BPM. 15:30 - 17:00 1.50 CASE P COMP RIH WITH LINER ON 4" DRILL PIPE TO 12475' NO PROBLEMS. 17:00 - 17:30 0.50 CASE P COMP MAKE UP CEMENT HEAD AND LINES 17:30 - 19:30 2.00 CEMT P COMP CIRCULATE AND CONDITION MUD. 3 BPM WITH 1325 PSI. PJSM WITH CEMENTERS AND RIG CREWS. 19:30 - 21 :00 1.50 CEMT P COMP TEST LINES TO 4000 PSI. PUMP 30 BBL ALPHA SPACER AT 9.5 PPG. MIX AND PUMP 47 BBL (230 SX) PREMIUM CEMENT AT 15.8 PPG WITH 0.2% CFR-3, 0.6% HALAD 344, 0.35% HR-5 AND 0.25 PPS SUPER CBL. PUMP AT 2 BPM WITH 1300 PSI. 21 :00 - 21 :30 0.50 CEMT P COMP DISPLACE CEMENT WITH 120 BBL 8.5 PPG MUD AT 3 BPM WITH 1600 PSI. GOOD INDICATION WHEN DART LATCHED INTO WIPER PLUG. BUMPED PLUG WITH 3500 PSI. 21 :30 - 22:00 0.50 CEMT P COMP SET LINER HANGER, RELEASE FROM HANGER. SET ZXP LINER TOP PACKER WITH 75,000 LBS WEIGHT. TOP OF LINER AT 9784', LANDING COLLAR AT 12381' 22:00 - 22:30 0.50 CEMT P COMP CIRCULATE BOTTOMS UP AT 10 BPM WITH 2000 PSI. 10 BBL SPACER RETURN, NO CEMENT RETURNS. 22:30 - 23:00 0.50 CEMT P COMP RIG DOWN CEMENT HEAD AND LINES 23:00 - 00:00 1.00 CEMT P COMP PUMP 30 BBL SPACER AND DISPLACE 8.5 PPG MUD WITH Printed: 1/29/2002 8:18:23 AM ( ( BPEXPLORATION Operations... Summary Re po r1 Legal Well Name: 05-26A Common Well Name: 05-26A Spud Date: 11/9/1989 Event Name: REENTER+COMPLETE Start: 12/24/2001 End: Contractor Name: NABORS Rig Release: 1/23/2002 Rig Name: NABORS 2ES Rig Number: Hpqr$8c;tivityÇode NPT 1/13/2002 23:00 - 00:00 1.00 CEMT P COMP SEA WATER. 1/14/2002 00:00 - 00:30 0.50 CEMT P COMP DISPLACE 8.5 PPG MUD WITH SEA WATER. 00:30 - 04:30 4.00 CEMT P COMP POH WITH 4" DRILL PIPE. LAY DOWN LINER RUNNINGISETTING TOOL. 04:30 - 06:00 1.50 EVAL P COMP RIG UP HALLIBURTON SLICK LINE UNIT. PJSM WITH HALLIBURTON SLICK LINE, SCHLUMBERGER AND RIG CREWS. 06:00 - 09:30 3.50 EVAL P COMP RUN SCHLUMBERGER MEMORY CNL TOOL ON HALLIBURTON SLICK LINE TO 11060'. LOG FROM 11060' TO 10600' TWICE. POH. DOWN LOAD LOGS. 09:30 - 10:00 0.50 EVAL P COMP TEST 75/8" CASING, 3 1/2" LINER AND LINER TOP ZXP PACKER TO 3500 PSI FOR 30 MINUTES. 10:00 - 10:30 0.50 EVAL P COMP RIG DOWN SLICK LINE UNIT. 10:30 - 11 :00 0.50 PERF P COMP RIG UP TO RUN 2" PERF GUNS. PJSM WITH HALLIBURTON AND RIG CREWS. 11 :00 - 13:30 2.50 PERF P COMP PICK UP TOTAL OF 1004' 2" SCALLOP PERF GUNS (715' OF SHOTS) 4 SPF. 13:30 - 14:00 0.50 PERF P COMP RIG UP TO RUN 21/16 TUBING. 14:00 - 16:00 2.00 PERF P COMP PICK UP 21/16" TUBING AND RIH WITH 2" GUNS TO 2625' 16:00 - 16:30 0.50 PERF P COMP MAKE UP SAFETY JOINT, 7 5/8" CHAMP PACKER AND JARS. 16:30 - 17:00 0.50 PERF P COMP RIG DOWN 21/16" TUBING RUNNING TOOLS. 17:00 - 21 :30 4.50 PERF P COMP RIH WITH 4" DRILL PIPE TO 12381' AND TAG UP ON 3 1/2" LANDING COLLAR. 21 :30 - 22:00 0.50 PERF P COMP SET CHAMP PACKER AT 9750' WITH TOP SHOT AT 11380' AND BOTTOM SHOT AT 12375'. PJSM WITH CREWS. 22:00 - 22:30 0.50 PERF P COMP PRESSURE UP ANNULUS TO 2500 PSI HOLD FOR 1 MINUTE. BLEED OFF PRESSURE. GUNS FIRE AFTER 12 MINUTES. NO PRESSURE AT SURFACE. NO FLOW. NO LOSSES. PRESSURE UP ANNULUS TO 500 PSI, PICK UP AND OPEN BYPASS. WELL DEAD. UNSET CHAMP PACKER. 22:30 - 23:30 1.00 PERF P COMP REVERSE CIRCULATE 2 TIMES DRILL PIPE VOLUME THROUGH THE CHOKE TO CLEAN SEA WATER AT 4 BPM WITH 350 PSI. LOST 10 BBLS WATER TO FORMATION DURING CIRCULATION. MONITOR WELL, STATIC. 23:30 - 00:00 0.50 PERF P COMP PUMP DRY JOB, BLOW DOWN TOP DRIVE, PREP TO POH. 1/15/2002 00:00 - 01 :30 1.50 PERF P COMP POH WITH PERF GUNS. STAND BACK 4" DRILL PIPE. 01 :30 - 02:30 1.00 PERF P COMP CUT AND SLIP DRILLING LINE 02:30 - 03:00 0.50 PERF P COMP SERVICE TOP DRIVE 03:00 - 06:00 3.00 PERF P COMP POH. LAY DOWN 4" DRILL PIPE. 06:00 - 06:30 0.50 PERF P COMP LAY DOWN CHAMP PACKER ASSEMBLY 06:30 - 07:00 0.50 PERF P COMP CHANGE HANDLING TOOLS FROM 4" TO 21/16" 07:00 - 09:00 2.00 PERF P COMP POH. LAY DOWN 52 JTS 2 1/16" TUBING. 09:00 - 09:30 0.50 PERF P COMP PJSM WITH CREW. CHANGE OUT HANDLING TOOL TO LAY DOWN PERF GUNS. 09:30 - 12:30 3.00 PERF P COMP LAY DOWN 51 SECTIONS OF 2" PERF GUNS. ALL GUNS FIRED. 12:30 - 13:00 0.50 PERF P COMP CLEAR RIG FLOOR. 13:00 - 13:30 0.50 RUNCO COMP PULL WEAR BUSHING 13:30 - 15:00 1.50 RUNCO COMP RIG UP TOOLS TO RUN 31/2" CHROME TUBING. PJSM WITH RIG CREW, TONG CREW AND BAKER TECH. Printed: 1/29/2002 8:18:23 AM ( (' . . BPEXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES HQurs,L\çtivityÇøde NPT Phase 1/15/2002 15:00 - 23:00 COMP 23:00 - 00:00 SFAL COMP 1/16/2002 00:00 - 01 :00 SFAL COMP 01 :00 - 09:00 COMP 09:00 - 11 :30 COMP 11 :30 - 12:00 COMP 12:00 - 12:30 COMP 12:30 - 16:00 COMP 16:00 - 17:00 COMP 17:00 - 20:00 DFAL COMP 20:00 - 20:30 DFAL COMP 20:30 - 21 :00 COMP 21 :00 - 22:00 COMP 22:00 - 00:00 DFAL COMP 1/17/2002 00:00 - 01 :00 DFAL COMP 01 :00 - 05:30 DFAL COMP 05:30 - 06:30 DFAL COMP 06:30 - 07:00 DFAL COMP 07:00 - 07:30 DFAL COMP 07:30 - 14:30 DFAL COMP 14:30 - 16:30 DFAL COMP 16:30 - 18:30 DFAL COMP 18:30 - 00:00 DFAL COMP 1/18/2002 00:00 - 00:30 DFAL COMP Page 'to of 13 Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: PICK UP TAIL PIPE ASSEMBLY AND BAKER S3 PRODUCTION PACKER. RIH WITH 3 1/2" 9.2# VAM ACE 13CR-80 TUBING. CHANGE OUT PUP JOINT ON BOTTOM OF GAS LIFT MANDREL #4 AND COLLAR ON TUBING JOINT #135 CHANGE OUT PUP JOINT ON BOTTOM OF GAS LIFT MANDREL #4 AND COLLAR ON TUBING JOINT #135 RIH WITH 3 1/2" 9.2# VAM ACE 13CR-80 TUBING TO 9811'. TAG UP AT 9811' AND SPACE OUT COMPLETION WITH PUP JOINTS. INSTALL FMC TUBING HANGER AND LAND TUBING. RUN IN LOCK DOWN SCREWS. RIG DOWN TUBING RUNNING TOOLS AND CLEAR RIG FLOOR. RIG UP LINES TO REVERSE CIRCULATE. REVERSE CIRCULATE WELL WITH CLEAN SEA WATER. SPOT 228 BBL CORROSION INHIBITOR TREATED SEA WATER IN ANNULUS. DROP 1 5/16" ROD AND BALL ASSEMBLY WITH 1.375" FISHING NECK. SET BAKER S-3 PACKER AND TEST TO 3500 PSI FOR 30 MINUTES. BLEED TUBING PRESSURE TO 1500 PSI. PRESSURE ANNULUS TO 3000 PSI, PRESSURE DROPPING. REPEAT TEST SEVERAL TIMES. PRESSURE DROPPING 700 PSI IN 10 MINUTES. PRESSURED TUBING TO 4000 PSI, REPEAT ANNULAR TEST, SAME RESULTS. BLEED OFF PRESSURE. RIG DOWN LINES SERVICE TOP DRIVE SLIP AND CUT DRILLING LINE PJSM WITH HALLIBURTON SLICK LINE AND RIG CREWS. RIG UP SLICK LINE. RIG UP HALLIBURTON SLICK LINE UNIT. INSTALL 7" LUBRICATOR IN BOP AND SECURE WITH ANNULAR PREVENTOR RIH TO 9804'. RETRIEVE 1 5/16" BALL AND ROD ASSEMBLY FROM XN NIPPLE. RIH AND RETRIEVE RHC-M NO SHEAR SEAT FROM XN NIPPLE. RIG DOWN HALLIBURTON SLICK LINE UNIT. PRESSURE ANNULUS TO 1500 PSI FOR 15 MINUTES WITH TUBING OPEN, NO LEAK. RIG UP TO TEST BOP. INSTALL TWO WAY CHECK IN TUBING HANGER. TEST BOP AND RELATED VALVES 250 LOW AND 3500 HIGH. NOTE: CHUCK SCHEEVE OF AODCC WAIVED WITNESSING TEST. DRILL SITE MAINTENANCE PULLED TWO WAY CHECK WITH LUBRICATOR. PJSM WITH RIG AND SLICK LINE CREWS. RIG UP HALLIBURTON SLICK LINE UNIT. INSTALL 7" LUBRICATOR IN BOP AND SECURE WITH ANNULAR PREVENTOR. RIH WITH XXN PLUG TO 9804'. PLUG NOT SET. POH AND CHANGE "NO-GO" AND GASKETS ON PLUG. RIH. RIH WITH XXN PLUG TO 9804' AND SET SAME. ' POH. Printed: 1/29/2002 8:18:23 AM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Frbm- To 1/18/2002 00:30 - 07:00 ( BPEXPLORATION Operations Summary Report 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES 6.50 RUNCO 07:00 - 08:00 1.00 RUNCO DFAL COMP 08:00 - 09:00 1.00 RUNCO DFAL COMP 09:00 - 10:00 1.00 RUNCO DFAL COMP 10:00 - 12:30 2.50 RUNCO DFAL COMP 12:30 - 13:30 1.00 RUNCO DFAL COMP 13:30 - 15:00 1.50 RUNCO DFAL COMP 15:00 - 16:00 1.00 RUNCO DFAL COMP 16:00 - 17:30 1.50 RUNCO DFAL COMP 17:30 - 21 :30 DFAL COMP 21 :30 - 00:00 DFAL COMP 1/19/2002 00:00 - 01 :00 DFAL COMP 01 :00 - 05:30 DFAL COMP 05:30 - 06:30 DFAL COMP 06:30 - 07:30 DFAL COMP 07:30 - 08:00 DFAL COMP 08:00 - 09:00 DFAL COMP 09:00 - 00:00 DFAL COMP 1/20/2002 00:00 - 03:00 DFAL COMP 03:00 - 04:00 04:00 - 05:30 05:30 - 08:00 DFAL COMP DFAL COMP DFAL COMP Pagef 1 tof13 Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: [)~$cripti9rtofQperatiOns RIH WITH SLICK LINE TO RETRIEVE RP SHEAR VALVE AT 3359'. 4 ATTEMPTS. RIH WITH LEAD IMPRESSION BLOCK AND DETERMINED RP VALVE FELL DOWN THE HOLE. RIH WITH RETRIEVING TOOL AND RECOVER RP VALVE. RIH WITH SLICK LINE AND SET 1.5" DUMMY IN MANDREL AT 3359' TEST TUBING TO 3500 PSI. PRESURE DROPPED 400 PSI IN 15 MINUTES. REPEAT TEST. NO FLOW ON ANNULUS. TEST ANNULUS TO 3000 PSI. PRESSURE DROPPED 800 PSI IN 25 MINUTES. NO FLOW ON TUBING. RIG DOWN LINES. SLICK LINE RETRIEVE XXN PLUG FROM XN NIPPLE AT 9804' RIG DOWN HALLIBURTON SLICK LINE UNIT. TEST ANNULUS TO 3000 PSI. PRESSURE DROPPED 800 PSI IN 30 MINUTES. REPEAT TEST, SAME RESULTS. NO FLOW ON TUBING. RIG DOWN LINES. CHANGE SAVER SUB AND MANUAL "I" BOP ON TOP DRIVE. MAKE UP LANDING JOINT AND CROSS OVER TO TUBING HANGER. BACK OUT LOCK DOWN SCREWS. PICK UP STRING TO 170,000 LBS TENSION. SET IN SLIPS WITH 125,000 LBS TENSION. RIG UP SCHLUMBERGER LOGGING UNIT. PHASE 2 CONDITIONS. PJSM WITH CREWS ON CONNECTING AND RUNNING CHEMICAL CUTTER. CONNECT 2.625" CHEMICAL CUTTER. SCHLUMBERGER UNIT SHUT DOWN. AIR INTAKE TO MAIN ENGINE BLOCKED WITH SNOW. WORK ON SCHLUMBERGER UNIT. SHUT DOWN DUE TO AIR INTAKE TO MAIN ENGINE BLOCKED WITH SNOW. INSTALL PORTABLE HEATER. RIH WITH 2.625" CHEMICAL CUTTER. CUT 31/2" TUBING AT 9721' (WLM) IN PUP JOUNT ABOVE S-3 PACKER. POH AND LAY DOWN CUTTER AND TOOLS. RIG DOWN LOGGING UNIT. PICK UP TO CONFIRM TUBING CUT. CLEAR RIG FLOOR. RIG UP POWER TONGS AND COMPENSATOR TO PULL 13CR-80 TUBING. POH AND LAY DOWN TUBING HANGER. CIRCULATE OUT CORROSION INHIBITED SEA WATER AND DISLPACE WELL TO CLEAN SEA WATER. POH. LAY DOWN 31/2" 9.2# 13CR-80 VAM ACE TUBING. TUBOSCOPE INSPECT ALL JOINTS IN THE PIPE SHED. POH. LAY DOWN 3 1/2" 9.2# 13CR-80 VAM ACE TUBING. TUBOSCOPE INSPECT ALL JOINTS IN THE PIPE SHED. RECOVER CUT TUBING JOINT. TOP OF 3 1/2 STUB AT 9736' RIG DOWN TUBING TONGS AND TOOLS. TEST LOWER RAMS 250 PSI LOW, 3500 PSI HIGH. INSTALL WEAR BUSHNG. PICK UP 7 5/8" RTTS PACKER AND RIH TO 4200' ON 4" DRILL PIPE FROM THE DERRICK. Printed: 1/29/2002 8:18:23 AM ( ( BPEXPLORATION OperationsSurnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/20/2002 08:00 - 09:00 09:00 - 14:00 14:00 - 18:30 1 121 12002 18:30 - 19:00 19:00 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 06:30 06:30 - 07:30 07:30 - 11 :00 11 :00 - 11 :30 11 :30 - 14:00 14:00 -15:00 15:00 - 19:00 19:00 - 19:30 19:30 - 21 :30 21 :30 - 00:00 1/22/2002 00:00 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 18:30 18:30 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 1/23/2002 00:00 - 02:00 02:00 - 02:30 02:30 - 04:30 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES 0.50 RUNCO 4.00 RUNCO 0.50 RUNCO 0.50 RUNCO 1.00 RUNCO 0.50 RUNCO 2.50 RUNCO 1.00 RUNCO 4.00 RUNCO 0.50 RUNCO 2.00 RUNCO 0.50 WHSUR P 1.00 WHSUR P 2.00 WHSUR P 0.50 WHSUR P 2.00 WHSUR P Phase DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: [)e~criptipn pfOperatiÒns SET RTTS AT 4200'. TEST CASING TO 3000 PSI FOR 30 MINUTES. OK. PICK UP SINGLES, RIH WITH RTTS ON 4" DRILL PIPE TO 9700' SET RTTS AT 9700' AND TEST CASING TO 3000 PSI. PRESSURE LEAKED OFF. POH TESTING EVERY 5 STANDS. LOCATED LEAK BETWEEN 9096' AND 9127' RIG DOWN LINES AND BLOW DOWN TOP DRIVE. POH WITH RTTS AND LAY DOWN SAME. SERVICE TOP DRIVE RIG UP SCHLUMBERGER LOGGING UNIT. RIG UP SCHLUMBERGER LOGGING UNIT. PJSM WITH RIG AND LOGGING CREWS. RUN USIT LOG FROM 9720' TO 7500' TOOL FAILED. POH TO CHECK TOOLS. LAY DOWN LOGGING TOOLS AND CHECK SAME. RUN USIT LOG, LOGGING DOWN TO 9720'. CASING DAMAGE AT 9116' WLM. CASING ACCEPTABLE. RIG DOWN LOGGING UNIT. RIH WITH 4" DRILL PIPE TO 5512' CUT AND SLIP 64' DRILLING LINE POH LAY DOWN DRILL PIPE PULL WEAR BUSHING. CLEAR RIG FLOOR RIG UP POWER TONGS AND COMPENSATOR TO RUN 3 1/2" 13CR TUBING. RIH WITH 3 1/2" 13CR COMPLETION. PICK UP BAKER 6 112" 00 OVER SHOT WITH HIGH PRESSURE PACK-OFF. CONT. RIH WI 3-1/2" 9.2 LB/FT, 13CR TBG TO 9,718'. UWT=105K, DWT=87K. CIRC AT 3 BPM, 150 PSI, AND VERIFY TBG STUMP AT 9,736'. SHUT DOWN PUMP, BLEED OFF PRESSURE, TAG UP AT 9,742'. PRESSURE UP ANNULUS TO 500 PSI, AND CHK OVERSHOT SEALS - OKAY . REVERSE CIRCULATE AND SPOT CORROSION INHIB., AT 3 BPM AND 250 PSI. SPACE OUT AND LAND TBG HNGR. RU LINES FOR PRESSURE TESTING. PRESSURE UP ANNULUS TO 500 PSI, AND CHK OVERSHOT SEALS - OKAY DROP 1-5/16" BALL +ROD. RD LANDING JT AND XO. PRESSURE UP TBG. PKR SET INDICATION WAS AT 2,100 PSI. CONT. PRESSURE UP TO 3,500 PSI AND HELD FOR 30 MIN - OKAY. BLED TBG PRESS. TO 1,500 PSI. PRESSURE ANNULUS TO 3,000 PSI, FI 30 MIN - OKAY. BLED TBG PRESSURE, RP SHEARED AT +/- 1,200 PSI. INSTALL TWC, TEST TO 1,000 PSI- OKAY. BLOW DOWN ALL SURFACE EQUIP., RID CIRC LINES, AND NO BOPE. NO BOPE. OPEN RIG CELLAR DOOR, AND SPOT TREE. NU ADAPTER FLANGE AND PRESSURE TEST TO 5,000 Printed: 1/29/2002 8:18:23 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( BPEXPLORATION Operations Summary Report 05-26A 05-26A REENTER+COMPLETE NABORS NABORS 2ES Start: 12/24/2001 Rig Release: 1/23/2002 Rig Number: Spud Date: 11/9/1989 End: Frorn~To H()ur~AçtivityCode NPT Phase 1/23/2002 02:30 - 04:30 2.00 WHSUR P 04:30 - 05:30 1.00 WHSUR P 05:30 - 06:00 0.50 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 08:00 1.50 WHSUR P 08:00 - 09:00 1.00 WHSUR P 09:00 - 09:30 0.50 WHSUR P 09:30 - 10:00 0.50 WHSUR P 10:00 - 11 :00 1.00 WHSUR P COMP COMP COMP COMP COMP COMP COMP COMP COMP DE3$þriptiþnqf Operations PSI FOR 15 MIN. - OKAY. NU TREE AND PRESSURE TEST TO 5,000 PSI FOR 15 MIN. - OKAY. PULL TWC. RU HOSES FOR PUMPING DIESEL FREEZE PROTECTION. PRESSURE TEST LINES, FREEZE PROTECT ANNULUS BY PUMPING 100 BBL OF DIESEL, AT 2 BPM AND 300 PSI. U-TUBE DIESEL. INSTALL BPV AND TEST FROM BELOW TO 1,000 PSI. - OKAY. SECURE TREE. REMOVE SECONDARY ANNULUS VALVE, FINISH CLEANING PITS. RIG RELEASED AT 11 :00 HRS, 1/23/02 Printed: 1/29/2002 8:18:23 AM (,. 'I ( " :?í,rt%\?-'j,,>" . ~r":':~:i:¥Ø'~J" 06-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 5-26A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,654.94' MD Window / Kickoff Survey 10,698.00' MD (if applicable) Projected Survey: 12,475.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED FEB 0 ., 2002 AJaakaOi\ & Gas Cons. eommiBion AncbOf89l Attachment(s) t~';.'..~'.".;.~.:.:....;.. ' 1.1 , " , . , ' ~. ( North Slope Alaska Alaska Drilling & Wells PBU_EOA DS OS, Slot 05-26 05-26 - 5-26A Job No. AKZZ-11212, Surveyed: 12 January, 2002 SURVEY REPORT ( 5 February, 2002 Your Ref: 500292198401 Surface Coordinates: 5949763.07 N, 697035.39 E (700 16' 00.9518" N, 148024' 23.9220" W) Surface Coordinates relatIve to Project H Reference: 949763.07 N, 197035.39 E (Grid) Surface Coordinates relatIve to Structure Reference: 2568.58 N, 328.90 W (True) Kelly Bushing: 63. 70ft above Mean Sea Level E5l=1e",,-,y-sul! DRILLING SEiRVICS5\ A Halliburton Company DEFINITIVE Survey Ref: svy11 079 Sperry-Sun Drilling Services . Survey Report for 05-26 - 5-26A Your Ref: 500292198401 Job No. AKZZ-11212, Surveyed: 12 January, 2002 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10654.94 41 .450 15.248 8494.85 8558.55 5070.61 N 1900.40 E 5954881.68 N 698802.42 E 5313.43 Tie-on Point AK-6 BP _IFR-AK 10694.49 40.980 14.770 8524.60 8588.30 5095.78 N 1907.15 E 5954907.02 N 698808.51 E 1 .430 5338.39 ( 10698.00 40.940 14.740 8527.25 8590.95 5098.00 N 1907.74 E 5954909.26 N 698809.04 E 1.270 5340.59 Window Point 10737.07 38.700 24.990 8557.29 8620.99 5121.48 N 1916.16 E 5954932.95 N 698816.85 E 17.734 5365.00 10767.71 35.910 33.980 8581. 68 8645.38 5137.63 N 1925.24 E 5954949.33 N 698825.50 E 19.958 5383.51 10799.63 35.800 43.790 8607.57 8671.27 5152.15 N 1936.94 E 5954964.15 N 698836.82 E 17.990 5402.01 1 0831 .65 41.910 52.570 8632.51 8696.21 5165.43 N 1951 .94 E 5954977.82 N 698851.46 E 25.654 5421 . 1 9 10862.83 45.000 56.820 8655.15 8718.85 5177.80 N 1969.45 E 5954990.64 N 698868.64 E 13.638 5440.90 10893.04 48.670 65.520 8675.83 8739.53 5188.36 N 1988.74 E 5955001.70 N 698887.64 E 24.246 5460.01 10924.97 47.260 69.870 8697.22 8760.92 5197.36 N 2010.66 E 5955011.28 N 698909.33 E 11.039 5479.19 10943.93 46.460 74.450 8710.19 8773.89 5201.60 N 2023.82 E 5955015.86 N 698922.37 E 18.122 5489.71 10963.66 50.710 75.960 8723.23 8786.93 5205.37 N 2038.13 E 5955020.01 N 698936.57 E 22.291 5500.42 1 09B9.54 bö.B50 74.510 8738.52 8802.22 5210.70 N 2058.30 E 5955025.86 N 698956.60 E 24.151 5515.55 11 021 .30 65.270 74.280 8753.87 8817.57 5218.17 N 2085.05 E 5955034.03 N 698983.14 E 26.519 5535.95 11051.70 74.130 75.840 8764.41 8828.11 5225.51 N 2112.57 E 5955042.08 N 699010.46 E 29.538 5556.64 11077.33 82.530 76.570 8769.59 8833.29 5231.48 N 2136.93 E 5955048.69 N 699034.65 E 32.892 5574.51 11097.60 89.600 80.410 8770.98 8834.68 5235.51 N 2156.72 E 5955053.24 N 699054.34 E 39.665 5588.33 11128.95 93.450 86.780 8770.15 8833.85 5239.01 N 2187.85 E 5955057.55 N 699085.36 E 23.732 5607.64 11158.66 94.120 92.230 8768.18 8831.88 5239.26 N 2217.48 E 5955058.58 N 699114.98 E 18.442 5623.41 11192.26 93.740 91.4 70 8765.88 8829.58 5238.18 N 2250.98 E 5955058.37 N 699148.50 E 2.524 5640.08 ( 11224.35 92.740 88.670 8764.07 8827.77 5238.14 N 2283.02 E 5955059.17 N 699180.52 E 9.252 5656.86 11254.45 94.210 84.940 8762.24 8825.94 5239.82 N 2313.01 E 5955061.63 N 699210.46 E 13.298 5674.03 11284.19 94.090 83.210 8760.09 8823.79 5242.88 N 2342.51 E 5955065.46 N 699239.87 E 5.816 5692.12 11316.56 92.000 82.590 8758.37 8822.07 5246.87 N 2374.59 E 5955070.30 N 699271.83 E 6.734 5712.36 11347.45 91.670 81 .260 8757.38 8821.08 5251.21 N 2405.15 E 5955075.43 N 699302.27 E 4.434 5732.09 11376.78 92.760 78.640 8756.25 8819.95 5256.32 N 2434.01 E 5955081.30 N 699330.99 E 9.669 5751.59 11409.47 92.530 79.790 8754.74 8818.44 5262.43 N 2466.09 E 5"955088.25 N 699362.89 E 3.584 5773.63 11439.09 92.580 81.190 8753.42 8817.12 5267.32 N 2495.27 E 5955093.90 N 699391.94 E 4.725 5793.11 11501.62 93.810 77.400 8749.93 8813.63 5278.92 N 2556.60 E 5955107.09 N 699452.95 E 6.363 5835.18 11535.07 93.730 79.010 8747.73 8811.43 5285.74 N 2589.28 E 5955114.77 N 699485.43 E 4.809 5858.13 \ - "'"-'~''-''''''~.''''''' ,..,-_.'-- , --'.'. -'---'----'-.----'''-'-- - _".h"-'''~--'"---'--~ 5 February, 2002 - 16:37 Psge20f4 ~- DrillQuest 2.00.09.008 ( Sperry-Sun Drilling Services . Survey Report for 05-26 - 5-26A Your Ref: 500292198401 Job No. AKZZ-11212, Surveyed: 12 January, 2002 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (It) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11564.09 92.220 77.430 8746.23 8809.93 5291.66 N 2617.64 E 5955121.43 N 699513.63 E 7.526 5878.06 11595.47 91 .480 76.500 8745.21 8808.91 5298.73 N 2648.20 E 5955129.30 N 699543.99 E 3.786 5900.12 11626.02 92.380 73.520 8744.18 8807.88 5306.63 N 2677.69 E 5955137.96 N 699573.27 E 10.184 5922.32 11657.42 93.220 71.560 8742.65 8806.35 5316.04 N 2707.60 E 5955148.15 N 699602.93 E 6.784 5946.03 11690.00 91 .820 71.210 8741.22 8804.92 5326.42 N 2738.45 E 5955159.35 N 699633.49 E 4.429 5971.07 11750.55 88.31 0 70.970 8741 .15 8804.85 5346.04 N 2795.72 E 5955180.46 N 699690.23 E 5.810 6017.83 11783.30 90.530 71.480 8741.48 8805.18 5356.58 N 2826.73 E 5955191.81 N 699720.94 E 6.955 6043.07 11815.40 93.080 70.720 8740.47 8804.17 5366.98 N 2857.08 E 5955202.99 N 699751.01 E 8.289 6067.85 11843.47 93.330 71.170 8738.90 8802.60 5376.13 N 2883.57 E 5955212.83 N 699777.26 E 1.832 6089.54 11888.32 92.810 69.180 8736.50 8800.20 5391.31 N 2925.70 E 5955229.11 N 699818.97 E 4.580 6124.58 11937.02 93.510 69.100 8733.81 8797.51 5408.63 N 2971.14 E 5955247.61 N 699863.94 E 1 .447 6163.17 11975.92 92.450 69.770 8731.79 8795.49 5422.27 N 3007.51 E 5955262.20 N 699899.94 E 3.222 6193.88 12030. 18 88.760 63.770 8731 .22 8794.92 5443.66 N 3057.33 E 5955284.89 N 699949.19 E 12.980 6238.24 12064.32 87.210 67.810 8732.42 8796.12 5457.65 N 3088.44 E 5955299.69 N 699979.93 E 12.668 6266.48 12092.18 86.950 66.630 8733.84 8797.54 5468.42 N 3114.10E 5955311.13 N 700005.29 E 4.332 6289.11 12123.29 86.450 64.350 8735.63 8799.33 5481.31 N 3142.35 E 5955324.75 N 700033.20 E 7.491 6314.91 12168.12 85.670 67.490 8738.71 8802.41 5499.55 N 3183.18E 5955344.06 N 700073.54 E 7.201 6351.87 12218.49 85.220 66.620 8742.71 8806.41 5519.13 N 3229.42 E 5955364.83 N 700119.24 E 1.940 6392.80 12269.23 87.910 65.770 8745.75 8809.45 5539.57 N 3275.75 E 5955386.48 N 700165.03 E 5.559 6434.52 12294.48 89.440 66.230 8746.33 8810.03 5549.84 N 3298.81 E 5955397.35 N 700187.81 E 6.327 6455.37 12344.43 91 .110 67.960 8746.09 8809.79 5569.28 N 3344.82 E 5955417.98 N 700233.30 E 4.814 6496.06 12429.58 89.880 67.260 8745.36 8809.06 5601.71 N 3423.55 E 5955452.47 N 700311 .15 E 1.662 6564.99 12475.00 89.880 67.260 8745.45 8809.15 5619.26 N 3465.44 E 5955471.11 N 700352.56 E 0.000 6601.92 Projected Survey All data is in Feet (US) unless otherwi~e stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.574° (28-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 31.662° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12475.00f1., The Bottom Hole Displacement is 6601.92f1., in the Direction of 31.662° (True). ( " -....."".....----.--- -----_._~_._~_...._._--,_.. --'--'--'-'''."'-'''-'--~'-'_.'''''._-'-~' ---""-"-. "'-'---.-.-------.-.-.-----,-.--- 5 February, 2002 - 16:37 Page 3 014 DrlllQuest 2.00.09.008 North Slope Alaska Comments Measured Depth (ft) ( 10654.94 10698.00 12475.00 Sperry-Sun Drilling Services Survey Report for 05-26 - 5-26A Your Ref: 500292198401 Job No. AKZZ-11212, Surveyed: 12 January, 2002 Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 8558.55 8590.95 8809.15 5070.61 N 5098.00 N 5619.26 N Survey tool program for 05-26 - 5-26A Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 10654.94 c 5 February, 2002 - 16:37 To Measured Vertical Depth Depth (ft) (ft) Comment 1900.40 E 1907.74 E 3465.44 E Tie-on Point Window Point Projected Survey Survey Tool Description 0.00 10654.94 8558.55 12475.00 8558.55 Good Gyro (05-26) 8809.15 AK-6 BP _IFR-AK (5-26A) Page 4 of4 . Alaska Drilling & Wells PBU_EOA DS 05 ---"-,,-,-'-'-----..-...--,..,.-....-...._u,.,--.-..-,.,,,-~_._--,_._"'--".._,_...__._._------- Dri/lQuest 2.00.09.008 ( {' \ ;,.~"!J:¡¡'~\".~'\ì""';:' """:".~.' .... ., .....J""'}' ,1,::,:::,:,,::~~,~~\;:'~ít~t;)C 06-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 5-26A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,654.94' MD Window / Kickoff Survey 10,698.00' MD (if applicable) Projected Survey: 12,475.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, RECEIVED William T. Allen Survey Manager FEB 0 7 2002 AlaakaOil& Gas Cons. Commilion Ancborage Attachment(s) '--" ( North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 05, Slot 05-26 05-26 - 5-26A MWD Job No. AKMM-11212, Surveyed: 12 January, 2002 SUR V E Y REP. 0 R T 5 February, 2002 ( Your Ref: 500292198401 Surface Coordinates: 5949763.07 N, 697035.39 E (700 16' 00.9518" H, 148024' 23.9220" W) Surface Coordinates relstlve to Project H Reference: 949763.07 N, 197035.39 E (Grid) Surface Coordinates relative to Structure Reference: 2568.58 N, 328.90 W (True) Kelly Bushing: 63. 70ft above Mean Sea Level spa"",v-sul! DRILLING SIiiRVICe& A Halliburton Company Survey Ref: svy110BO .""" . Spèrry-Sun Drilling Services Survey Report for 05.26 . 5.26A MWD Your Ref: 500292198401 Job No. AKMM-11212, Surveyed: 12 January, 2002 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10654.94 4 1 .450 15.248 8494.85 8558.55 5070.61 N 1900.40 E 5954881.68 N 698802.42 E 5309.87 Tie-on Point MWD Magnetic 10694.49 40.980 14.770 8524.60 8588.30 5095.78 N 1907.15 E 5954907.02 N 698808.51 E 1 .430 5334.81 10698.00 40.940 14.740 8527.25 8590.95 5098.00 N 1907.74 E 5954909.26 N 698809.04 E 1.270 5337.01 Window Point ( 10737.07 38.700 24.990 8557.29 8620.99 5121.48 N 1916.16E 5954932.95 N 698816.85 E 17.734 5361.40 10767.71 35.910 7.630 8581.73 8645.43 5139.12 N 1921.42 E 5954950.72 N 698821.64 E 35.424 5379.15 10799.63 35.800 44.880 8607.91 8671.61 5155.21 N 1929.34 E 5954967.01 N 698829.14 E 67.556 5397.00 10831.65 41.910 53.210 8632.85 8696.55 5168.27 N 1944.54 E 5954980.47 N 698843.99 E 25.075 5416.11 10862.83 45.000 57.110 8655.48 8719.18 5180.50 N 1962.15 E 5954993.15 N 698861.27 E 13.120 5435.79 10893.04 48.670 65.760 8676.17 8739.87 5190.97 N 1981 .48 E 5955004.12 N 698880.33 E 24.141 5454.89 10924.97 47.260 69.960 8697.55 8761.25 5199.91 N 2003.44 E 5955013.64 N 698902.04 E 10.720 5474.07 10943.93 46.460 74.210 8710.52 8774.22 5204.17 N 2016.59 E 5955018.24 N 698915.08 E 16.890 5484.63 10963.66 50.710 75.480 8723.57 8787.27 5208.03 N 2030.87 E 5955022.47 N 698929.25 E 22.074 5495.45 10989.54 56.850 73.470 8738.85 8802.55 5213.63 N 2050.97 E 5955028.60 N 698949.20 E 24.536 5510.81 11021.30 65.270 73.740 8754.21 8817.91 5221.46 N 2077.62 E 5955037.13 N 698975.63 E 26.522 5531.53 11051.70 74.130 75.480 8764.75 8828.45 5229.01 N 2105.08 E 5955045.39 N 699002.88 E 29.634 5552.43 11077.33 82.530 76.570 8769.93 8833.63 5235.06 N 2129.42 E 5955052.08 N 699027.05 E 33.037 5570.42 11097.60 89.600 77.830 8771.32 8835.02 5239.54 N 2149.12 E 5955057.07 N 699046.64 E 35.425 5584.62 11128.95 93.450 84.820 8770.48 8834.18 5244.27 N 2180.08 E 5955062.60 N 699077.46 E 25.444 5604.97 11158.66 94.120 96.800 8768.51 8832.21 5243.85 N 2209.67 E 5955062.96 N 699107.05 E 40.298 5620.23 11192.26 93.740 87.750 8766.21 8829.91 5242.52 N 2243.12 E 5955062.50 N 699140.53 E 26.895 5636.77 11224.35 92.740 90.490 8764.39 8828.09 5243.01 N 2275.16 E 5955063.83 N 699172.54 E 9.076 5654.09 ( 11254.45 94.210 86.030 8762.57 8826.27 5243.92 N 2305.18 E 5955065.53 N 699202.52 E 15.575 5670.71 11284.19 94.090 84.690 8760.41 8824.11 5246.32 N 2334.74 E 5955068.70 N 699232.02 E 4.512 5688.35 11316.56 92.000 84.190 8758.69 8822.39 5249.45 N 2366.91 E 5955072.68 N 699264.09 E 6.638 5707.99 11347.45 91.670 82.640 8757.71 8821.41 5252.99 N 2397.58 E 5955077.02 N 699294.66 E 5.128 5727.18 11376.78 92.760 80.270 8756.57 8820.27 5257.35 N 2426.56 E 5955082.13 N 699323.52 E 8.889 5746.18 11409.47 92.530 80.140 8755.06 8818.76 5262.90 N 2458.74 E 5955088.53 N 699355.54 E 0.808 5767.88 11439.09 92.580 81 .730 8753.74 8817.44 5267.57 N 2487.96 E 5955093.95 N 699384.63 E 5.365 5787.26 11501.62 93.810 78.690 8750.26 8813.96 5278.18 N 2549.48 E 5955106.17 N 699445.84 E 5.237 5828.74 11535.07 93.730 80.420 8748.06 8811.76 5284.23 N 2582.30 E 5955113.08 N 699478.50 E 5.166 5851.21 . ~.. ~""" .~..., w"",'""'_.,,~ -'-."'-'W'-'-- . ~ - ..-.. ...._,- ".... 5 February, 2002 - 16:36 Page2of4 DrlllQuest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for 05-26 - 5-26A MWD Your Ref: 500292198401 Job No. AKMM-11212, Surveyed: 12 January, 2002 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11564.09 92.220 79.610 8746.55 8810.25 5289.25 N 2610.84 E 5955118.85 N 699506.90 E 5.903 5870.54 11595.47 91.480 78.560 8745.54 8809.24 5295.19 N 2641.64 E 5955125.59 N 699537.53 E 4.092 5891.84 11626.02 92.380 75.230 8744.51 8808.21 5302.11 N 2671.37 E 5955133.29 N 699567.07 E 11.285 5913.41 11657.42 93.220 73.990 8742.97 8806.67 5310.44 N 2701.61 E 5955142.40 N 699597.08 E 4.766 5936.44 11690.00 91.820 76.560 8741.54 8805.24 5318.71 N 2733.08 E 5955151.49 N 699628.32 E 8.976 5960.07 ( '-- 11750.55 88.310 72.700 8741.47 8805.17 5334.75 N 2791.45 E 5955169.06 N 699686.25 E 8.616 6004.50 11783.30 90.530 73.010 8741.80 8805.50 5344.41 N 2822.74 E 5955179.53 N 699717.28 E 6.844 6029.22 11815.40 93.080 72.310 8740.79 8804.49 5353.97 N 2853.36 E 5955189.89 N 699747.64 E 8.237 6053.50 11843.47 93.330 72.860 8739.22 8802.92 5362.36 N 2880.10 E 5955198.97 N 699774.15 E 2.150 6074.74 11888.32 92.810 70.860 8736.82 8800.52 5376.30 N 2922.66 E 5955214.02 N 699816.33 E 4.601 6109.05 11937.02 93.510 70.440 8734.14 8797.84 5392.41 N 2968.54 E 5955231.33 N 699861.77 E 1.676 6146.94 11975.92 92.450 71.480 8732.12 8795.82 5405.08 N 3005.26 E 5955244.96 N 699898.15 E 3.815 6177.09 12030.18 88.760 65.900 8731.54 8795.24 5424.79 N 3055.78 E 5955265.98 N 699948.13 E 12.327 6220.49 12064.32 87.210 70.580 8732.74 8796.44 5437.44 N 3087.46 E 5955279.45 N 699979.47 E 14.432 6247.95 12092.18 86.950 69.750 8734.16 8797.86 5446.88 N 3113.63 E 5955289.58 N 700005.39 E 3.118 6269.78 12123.29 86.450 68.940 8735.95 8799.65 5457.83 N 3142.69 E 5955301.29 N 700034.15 E 3.056 6294.43 12168.12 85.670 69.710 8739.03 8802.73 5473.62 N 3184.53 E 5955318.17 N 700075.57 E 2.442 6329.92 12218.49 85.220 68.250 8743.03 8806.73 5491.63 N 3231.40 E 5955337.40 N 700121.95 E 3.024 6369.96 12269.23 87.910 67.360 8746.07 8809.77 5510.76 N 3278.29 E 5955357.75 N 700168.32 E 5.583 6410.95 12294.48 89.440 67.770 8746.66 8810.36 5520.40 N 3301.62 E 5955367.99 N 700191.39 E 6.273 6431.45 12344.43 91.110 69.450 8746.42 8810.12 5538.61 N 3348.13 E 5955387.42 N 700237.41 E 4.742 6471.47 ( 12429.58 89.880 69.230 8745.68 8809.38 5568.65 N 3427.80 E 5955419.54 N 700316.26 E 1.467 6539.03 12475.00 89.880 69.230 8745.78 8809.48 5584.76 N 3470.27 E 5955436.75 N 700358.29 E 0.000 6575.13 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.574° (28-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 31.856° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12475.0Oft., The Bottom Hole Displacement is 6575.13ft., in the Direction of 31.856° (True). . _. _.. .,~_.~_._,--------_.. .. __'_'_0."......- ...--. 5 February, 2002 - 16:36 Page 3 of4 DrlllQuest 2.00.09.008 ,-\,' .--'.1. ."'~. 'Spèrry-Sun Drilling Services:~;~~"'" Survey Report for 05-26 - 5-26A MWD Your Ref: 500292198401 Job No. AKMM-11212, Surveyed: 12 January, 2002 .:.- ~ Ü] North Slope Alaska Alaska Drilling & Wells PBU__EOA DS 05 Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 10654.94 10698.00 12475.00 8558.55 8590.95 8809.48 5070.61 N 5098.00 N 5584.76 N 1900.40 E 1907.74 E 3470.27 E Tie-on Point Window Point Projected Survey ( Survey tool program for 05-26 - 5-26A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 10654.94 0.00 10654.94 8558.55 12475.00 8558.55 Good Gyro (05-26) 8809.48 MWD Magnetic (5-26A MWD) ( .... ,-...- --_.._..__.-~. ....--...---- ..--..- . 5 February, 2002 - 16:36 Page 4 of 4 DrlllQuest 2.00.09.008 02/21 /02 Scblunlbepger NO. 1836 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay t Well Job # Log Description Date Bluellne Sepia Color Prints CD ~ ~~J 8-07 J ì ~- DO;:). PRODUCTION PROFILE 02109/02 1 1 MPF-33A :- );:¿:>l.~Ðl,pw\ STATIC PRESSURE SURVEY 02114/02 1 1 NK-19A r: ~{,I-D ID STATIC PRESSURE SURVEY 02110/02 1 1 K-02C d 0/- ~} in 22064 MCNL (PDC) 01121/02 1 1 1 D.S.5-26A ;¡ (») -.;JcJ. 22048 MCNL (PDC) 01/14/02 1 1 1 NK-22A ~Ol-dd~ 22060 SCMT (PDC) 01/08/02 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrle f-1AR 0 5 2002 Alaska Oil & Gas CoM CommÌ88iÐ Anchorage ft ReceiV~<)r:\' fA QQ€y:>. ) Date Delivered: ( ( 02/07/02 Seb1umbOI'D11' NO. 1794 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Well Job# Log Description Date Color Sepia BL CD r6 ~ lò \ -.. 0 c-o V-201 22001 FMI DIP ANALYSIS 12/29/01 4 V-201 22002 PROCESSED CMR 12/29/01 2 V-201 22003 BEST DT, FRACADE & ELAN 12/29/01 6 V-201 22049 USIT 12/31/01 2 V-201 22004 PEX,AIT,CMR,DSI,FMI 12/29/01 1 V-201 22004 PEX-AIT-GR 12/29/01 1 1 V-201 22004 PEX-SSTVD AIT -GR 12/29/01 1 1 V-201 22004 PEX-INDUCTION DEN/NEUTRON 12/29/01 1 1 V-201 22004 PEX-SSTVD INDUCTION DEN/NEUTRON 12/29/01 1 1 V-201 22004 PEX-DEN/NEUTRON POROSITY 12/29/01 1 1 V-201 22004 PEX-SSTVD DEN/NEUTON POROSITY 12/29/01 1 1 V-201 22004 PEX-CALlPER-CEMENT VOLUME 12/29/01 1 1 V-201 22004 CHRONOLOGICAL SAMPLE TAKER 12/29/01 1 1 V-201 22004 CMR 12/29/01 1 1 V-201 22004 DSI 12/29/01 1 1 V-201 22004 FMI 12/29/01 1 1 V-201 22050 CDR,ARC 12/29/01 1 V-201 22050 MD ARRAY-RESISTIVITY 12/29/01 1 1 V-201 22050 TVD ARRAY-RESISTIVITY 12/29/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Sherrie Date Delivered: FEB 0 8 2002 Alaska Oil & Gas Cons. CommÎIIÎÐR Anchorage Received~ ~ 02/04/02 Scblumbepgep NO. 1778 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date Bluellne Sepia Color Prints CD . { D.S.7-19A JCjÇ?- na 1:.1 22032 MCNL 12/24/01 1 1 1 D.S.15-36A dD/-'/(PrJ 22018 MCNL 12/18/01 1 1 1 D.S. 5-26A ;:JOJ- "":1. î \ 22047 USIT 01121/02 2 - ( PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATIN: Sherrie ~~ ~ Received: . 0 f')C-.-J Date Delivered: FEB 0 ~ 2002 AIa8ka Oil & Gas Cons. COmmission Anchorage Customer Well No Installation/Rig Data Su rveys Received By: ( MWD/LWD Log Product Delivery BP Exploration (Alaska) Inc. V-201 Nabors 9ES LWD Log Delivery V1.1 , Dec '97 Dispatched To: Date Dispatche Dispatched By: ( ~ O}..~~~ Lisa Weepie 9-Jan-02 Nate Rose No Of Prints No of Flo ies 2 R ~\fED . Jmmission ~I : :.::.:~ \:. Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 ALASKA OIL AND GAS CONSERVATION COMMISSION ( / / TONY KNOWLES, GOVERNOR ( ~1ffÆ1fŒ (ID~ ~~~~~~ 333 W. ""fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer . BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 05-26A BP Exploration (Alaska) Inc. Permit No: 201-221 Sur Loc: 1678' SNL, 11' WEL, Sec. 31, TIIN, RI5E, UM Btmhole Loc. 1285' SNL, 1826' WEL, Sec. 29, TI1N, RI5E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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 detenninations are made. Annular disposal has not been requef'ted as part of the Pennit to Drill application for Prudhoe Bay Unit 05-26A. 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, Úv ~.~ camm~chsli Taylor Chair . BY ORDER OF THE COMMISSION DATED this 30th day of November, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA 0(. STATE OF ALASKA ND GAS CONSERVATION COMMIS(' PERMIT TO DRILL 20 AAC 25.005 N ~\\ )\ . "\ .() L jC)' ,\ \ ') h'j +t .. 1 a. Type of work 0 Drill II Redrill 11 b. Type of well 0 Exploratory D,Stratigraphic Test II Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas GJ Single Zone)b 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 28.5' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028326 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1678' SNL, 11' WEL, SEC. 31, T11 N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1661' SNL, 3103' WEL, SEC. 29, T11N, R15E, UM 05-26A Number 2S1 00302630-277 At total depth 9. Approximate spud date 1285' SNL, 1826' WEL, SEC. 29, T11N, R15E, UM 12/17/01 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 TVD) ADL 028321,1285' MD OS-30A isS67'away at 11934'MD 2560 12506' MD /8789' TVD 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10710' MD Maximum Hole Angle 93 Maximum surface 2428 psig, At total depth (TVD) 8800' / 3318 psig 18. Casing Program Specifications Setting Depth Quantitv of Cement C ,j7 p. Tc ID Rnttnm Hole Casinn Weinht Grade CouDlina Lenath MD TVD MD TVD (include staae data) 4-3/4" 3-1/2" 8.81# L-80 ST/L 2706' 9800' 7926' 12506' 8789' 22 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11195 feet Plugs (measured) true vertical 8974 feet Effective depth: measured 111 01 feet Junk (measured) true vertical 8902 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 284 sx Permafrost 110' 110' Surface 3914' 10-3/4" 1000 sx CS III, 350 sx Class 'G' with 3914' 3726' Intermediate Top Job of 34 Bbls CS II Production 10379' 7-5/8" 300 sx Class 'G', 225 sx CS I 10379' 8356' Liner 1116' 5-1/2" 160 sx Class 'G' 1ffEÖ~I\li§j965' Perforation depth: measured 10896' - 10904', 10990' - 10996', 11000' - 11026' NOV 1 6 2001 true vertical 8743' - 8750', 8816' - 8821', 8824' - 8844' AlallkaOH & Gas Cons. CcmniI8Ion AnchoI8ge 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Dave Wesley, 564-5773 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing iSI1l'e.;wct to the best of my knowledge. ,/, Signed Brian Robertson ~r}U" ,. Trtle Senior Drilling EngIneer Date I(J,f:, 01 "'''''''" ii' "'''''''' ~ ~~"""'!''''''.: Permit Number API Number App v I D te See cover letter 2-(;"/- 2. Z I 50- 029-21984-01 I Y/~h)Þ~&1 for other reauirements Conditions of Approval: Samples Required DYes gNo Mud Log'Rsquiréd ' DYes ~No Hydrogen Sulfide Measures ria Yes DNo Directional Survey Required Is:I Yes DNo Required Working Pressure for BOPE D2K D3K D4K D5K D10K D15K ~3.5K psi f~ Other: J / híJlfJ I Original Signed B~ -. I " I 1\ I ^ Commissioner by order of Aooroved Bv the commission Date Form 10-401 Rev. 12-01UBmmy OechsliU K , lJ I 1\1 A L SUbmit I~ Triplicate (" ( I Well Name: I DS5-26A Drill and Complete Plan Summary I Type of Well (service I producer I injector)-=-J Sidetrack Horizontal Producer Surface Location: X = 697,035.39 Y = 5,949,763.07 Estimated 16781 FNL, 11' FEL Sec. 31, T11 N, R15E Umiat Target Location: X = 699,065.00 Y = 5,955,115.00 TVDss 8765 Sadlerochit Zone 1 A 1661'FNL,3103'FEL Sec. 29, T11N, R15E Umiat Bottom Hole Location: X = 700,330.27 Y = 5,955,525.00 TVDss 8725 12851 FNL , 1826' FEL Sec. 29, T11 N, R15E Umiat I AFE Number: 14J0498 I Estimated Start Date: 112/17/2001 I ~ 12,506' I I TVD: 18789' 1 I Rig: I Nabors 2ES I Operating days to complete: 120.5 I BF/MS: 135.2' I I RKB: 128.5' I Well Design (conventional, slim hole, etco)i.J Horizontal Sidetrack out of 5-1/2" liner ~ective: I Zone 1 A, Sadlerochit c IT bO P aSing, u Ing rogram Hole Size Csgl WtlFt Grade Conn Length Top 8tm TbQ O.D. MDfTVD MDfTVD 4%" 3 Y2" 8.81# L-80 ST/L -2706' 9800' 1 7926' 12,506' 18789' TubinQ 4-1/2" 12.6# L-80 BTC-Mod -9770' GL 9800' /7926' Directional KOP: 110,710' MD Maximum Hole Angle: -480 In original wellbore at 7000' MD -92.50 ThrouQh reservoir section of planned sidetrack Close Approach Well: Two wells in the area may be considered for close approach analysis: DS18-21A with a center-center distance of 569' and allowable deviation of 88' at the planned depth of 11,479'; and DS5-30A at 567' center-center with 324' of allowable deviation at 11,934' MD. Both wells pass major risk criteria and will not be shut in while drilling. See Tolerable Collision Worksheet Attached. Survey ProQram: Standard MWD Surveys from kick-off to TD. DS5-26A Sidetrack Page 1 (' (, 4 3,4" hole section tauO 5-8 Lo Pro ram 4 3,4" Production: Sample Catchers - None Drilling: MWD /GR - Real time over entire interval. Open Hole: None Cased Hole: Memor CNL, with ri on DP Cement Pro ram Casin Size 3 1/2" Production Liner Basis: Lead: None Tail: Based on 82' of 3-1/2" shoe track, 1710' of open hole with 40% excess, 643' of 3 V2" x 5Y2" liner lap, 267' of 3 V2" x 7 5/8" liner lap, and 200' of 7 5/8" x 4" DP annulus volume. Tail TOC: -9800' /' MD 7927'TVD.- Liner to . Fluid Sequence & Volumes: Pre 5 Bbls Water Flush Spacer Lead Tail 40 bbls Alpha Spacer at 9.8 ppg None 47 bbl /265 ft /222 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 1950 TT = Batch Mix + 4 to 4.5 hrs Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3318 psi @ 8800' TVDss - Ivishak . Maximum surface pressure: 2428 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater /7.2 ppg Diesel . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . DS5-26A Sidetrack Page 2 ( (" Formation Markers Formation Tops (wp8) MD TVDss Comments KINGAK Above casing window T JFrrOp KINGAK F " " T JDrrOp KINGAK D " " T JAlTOP KINGAK A " " SAG RIVER SS -8242 " " WD-TSHU/SHUBLlK -8277 " " WD-TEIL -8331 " " WD- TSADrrZ4B -8334 " " WD-TCGL -8449 " " WD BCGL -8530 " " KICK OFF ZONE: TZ2C 10,710' -8536 7.3 ppg EMW expected pore pressure TZ2B 10,764' -8578 WD-23SB 10,789' -8598 WD-22TS 10,824' -8626 WD-TZ1B 10,956' -8715 TARGET ZONE: WD-TZ1A 11 ,033' -8748 BSAD -8775 Not penetrated TD Criteria: Target polygon Sidetrack and Complete Procedure Summary Ria Operations: 1. MIRU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull seals from upper production packer at 9829' MD. POOH laying down 4Y2" x 3Ÿ2" completion. 5. Make-up packer mill with packer retrieving tool. RIH and mill 7-5/8" packer. Catch packer with packer retrieving tool via mill out extension. POOH with packer and completion equipment down to top tubing cut at 9872'. 6. RIH with overshot and recover completion equipment down to lower tubing cut at 10,820'. POOH. 7. RU E-line and make GR/JB run to top of tubing cut. MU bridge plug. RIH and set at 10,727'. 8. Test wellbore to 3500 psi for 30 minutes. 9. RIH with 5-1/2" Baker whipstock assembly. Orient whipstock as desired and set on bridge plug. Mill window in 5-1/2" casing at 10,710' MD. POOH. 10. MU 4-3/4" drilling assembly with MWD/GR only and RIH. Kick-off and drill the 4-3/4" production interval, building at -20°/100' to horizontal, targeting the Zone 1 sands. Drill ahead to an estimated total depth of 12,506' MD (8789' TVD). 11. Run and cement a 3-1/2", 8.81 # solid production liner throughout the 4-3/4" well bore and back into the 5-1/2" and 7-5/8" casing to the liner top at -9,800'. Displace well to seawater above liner top. POOH. 12. Test the 3-1/2" and 7-5/8" casing from the 3-1/2" landing collar to surface to 3500 psi for 30 minutes. 13. PU Schlumberger memory CNL and RIH on DP. Run log through build section of well. POOH and download log to identify GOC prior to perforating. 14. PU Halliburton 2Ÿ2" perf guns and RIH on DP. Perforate -1000' of Zone 1 in the horizontal section POOH LD DP. 15. Run 3-1/2",9.3# 13Cr-80 completion tying into the 3-1/2" liner top. 16. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. DS5-26A Sidetrack Page 3 (' ( 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure the well. 19. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the production packer and install gas lift valves. Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move to DS5-26. The wells either side are on 60' centers alLo~9 ample room for the move. ~ ~s not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: 5-23 No recorded H2S 5-31 A No recorded H2S Closest BHL Wells 5-30 No recorded H2S 5-14 No recorded H2S The maximum recorded level of H2S on the pad was 27 ppm. >- Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Job 2: DecomDlete Well Hazards and Contingencies ~ The perforations and bottom section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. Job 3: Run WhiDstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Job 7: Drill 4 3/4" Production Hole Hazards and Contingencies ~ All lines are hardlines as this well lies in a small graben surrounded by faults. The northern line is critical because of the proximity of well 18-21 A. The southern line is critical due to the proximity of a fault running parallel to the planned well bore. ~ A minor fault «15' vertical throw) crosses the well perpendicularly at :1:11,400' MD. There is a low to medium risk of experiencing fluid losses at or near this fault. An additional minor fault «10' throw) lies approximately 150' beyond the planned TO of the well. ~ In zone 1, only DS5-15B has experienced losses while drilling (70 bbls). The Sag River and Shublik appear to be the only serious lost circulation zones on DS-5. DS5-26A will be kicking off significantly deeper at the base of Zone 3. >- Drilling Close Approach: All wells BP Close Approach guidelines. See the "Directional" section for a description of the two nearest wells. DS5-26A Sidetrack Page 4 (' ( }- Stuck pipe (presumed differential sticking) has been an issue on DS-5 as well as lost circulation. Review the pad data sheet for details. Though most of the incidents occurred above Zone 2, lower zones are not immune to these problems. Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. The 8.5 ppg Quickdril will be -600 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 10: DPC Perforate Hazards and Contingencies ~ The well will be perforated overbalanced after running DPC cased hole logs. Ensure all personnel are well-briefed on Halliburton's perforating procedures and that all responsibilities are understood. Essentially personnel only should be present on the rig floor while making up ope guns. ~ Expect to lose fluid to the formation after perforating. Have ample sea water on location and be prepared with LCM if necessary. Job 12: Run ComDletion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Job 13: ND/NU/Release RiCl Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. DS5-26A Sidetrack Page 5 (' .iT THIS NOTICE IN THE DOGHOUSE ( 5-26A Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. Very little recent data on H28 on 08-5 exists. The highest concentration currently on record is on 085-05 @ 27 ppm, (November 1990). ./ NORM test all retrieved well head and completion equipment. ./ All wells pass major risk criteria. However, Two wells in the area may be considered for close approach analysis: D818-21A with a center-center distance of 569' and allowable deviation of 88' at the planned depth of 11,479'; and 085- 30A at 567' center-center with 324' of allowable deviation at 11,934' MD. Both wells pass major risk criteria and will not be shut in while drilling. -/' Lost circulation may also be experienced while drilling, especially through the fault crossing at :t11 ,400' MD. The 880 lost circulation tree should be followed if lost fluid returns are encountered. ./ Differential sticking is of great concern in this depleted reservoir. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Follow all service company rules and regulations while handling perf guns and ensure only the necessary people are on the rig floor during make up and RIH. ./ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ,.., 0.1 psia at 100° F. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. DS5-26A TREE = , 4-1/16" FMC WELLHEAD = FMC ...... .. ..,..... ,. ... . ..... '.""" ... A CTUA TOR = AXELSON "KEt"êCê.I"";;;.'''''"'''''''.....''''''''.'..'''"'.-.''''''''.'"'''...S-6^" ï3F:'ELE\i;;."'.. u, .... .. ..,. KOP ;;-~_u"""'-"uu,_.,,-'u,~'_u- 2300';' .Mãx-Ängïë-;",mm',^'.-4S'@"¿OOQ'ì' DatumMD';-"""""""''''''''''''''''''''''''-:riõs''¡; ..........~...... ... ..... ..''''''''''''' .. . ". . '"'''''''''' '" -.". ,....."..." Datum ìV D = 8800' SS 14-1/2" TBG-IPG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I ITOP OF 3-1/2" TBG-IPG 1 ost¿s Planned Pre(Rig 8 110-3/4" CSG, 45.5#, J-55, ID = 9.950" I Open GLM at 9619' MD 13-1/2" BKR GBH LOC/SEAL ASSY, ID = 2.985" I 9828' Tubing Cut at 9872' MD 13-1/2" TBG-IPG, 9.3#, L-80, .00870 bpf, ID = 2.992" I TOPOF 2-7/8" TBG-IPG I 4-1/2" AVA SC TRSV SSSV NIP, 10 = 3.812" 4-1/2" X 3-1/2" XO, ID = 2.992" PORT DA TE -17-5/8" X 3-112" BKR SB-3A PKR I -1XO 3-1/2" BKR MILLOUT EXTENSION I -1TE-TGPD PROD. MAN., TG LTCH I -1 TE- TGPD PROD. MAN., TG L TCH I -13-1/2" OTIS XN NO-GO NIP, ID = 2.75" I -13-112" X 2-7/8" XO, ID = 2.38" I Tubing Cut at 10,820' MD I 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 1 ÆRFORA TION SUMMARY REF LOG: BHCS on 11/25/89 ANGLEAT TOP ÆRF: 39 @ 10896' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 4" 2 10896-10904 S 04/17/95 2-1/8" 2 10990-10996 S 04/17/95 4" 8 11000-11026 S 06/12/95 4" 8 11004-11026 C 01/16/01 12-718" TBG-IPG, 6.5#, L-80, .00579 bpf, ID= 2.441" I -12-7/8" BLAST JOINTS (20') I -12-7/8" BKR GBH LOG/SEAL ASSY, ID = 2.406" I 1-15-1/2" X 2-7/8" BKR FB-1 PKR, ID = 3.00" 1 -I BTM OF BKR SEAL ASSY 1 -12-7/8" OTIS XN NO-GO NIP, ID = 2.25" I -12-7/8" WLEG 1 10942' 1-1 ELMD TT LOGGED 02/28/90 1 IPBTD 1 15-1/2" LNR - ARC, 17#, L-80, 0.0232 bpf, ID = 4.892" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/28/89 ORIGINAL COMPLETION 11108/01 WSI Planned P&A - Pre-Rig Work 01/17/90 LAST WORKOVER 11/27100 SIS-SL T CONVERTED TO CANVAS, REVIEWED BY BRIAN CARLSON 01/09/01 SIS-LG REVISION II 1 0106/01 CH/KAK CORRECTIONS II I PRUDHOE SA Y UNIT WELL: 05-26 ÆRMIT No: 89-113 API No: 50-029-21984-00 Sec. 31, T11N, R15E, 1678' FNL & 11' FEL BP Exploration (Alaska) TREE: 4-1/16" - 5M FMC L-SO WELLHEAD: 11" - 5M FMC Gen IV SH 10-3/4",45.5 lIft, J-55, BTC 3914' 5-1/2" Liner Top at 110,067' I 7-5/S", 29.7 lIft, LSD, BTC 110,379' Window Milled from Whipstock Top of Window at +1-10,710' MD Bridge Plug set at +/-10,727' MD Zone 2 Perfs Cement Plug to P&A Zone 1 Perfs Zone 1 Perfs 5-1/2",17 lIft, L-SO, FL-4S I 11,183' I 5-26A Proposed Completion 3-1/2" 'X' Landing Nipple with 2.S13" seal bore. I 2200' Cellar Elevation = 34.0' Nabors 2ES RKB = 64.0' 3-1/2" x 1-1/2" Camco 'MMG' Gas Lift Mandrels with handling pups installed above and below. -~-~---~------------'--------'----- GAS LIFT MANDRELS --'-'--'-- .,.._---------- --- IvD Size ---,,-,,--'--"----"'---.--...--- ._-- .. TBD 1-1/2" TBD 1-1/2" TBD 1-1/2" TBD 1-1/2" (ljt above 1-1/2" packer) 1 2 3 4 5 ---- -~- 3-1/2" 9.3# 13Cr-SO, Yam ACE Tubing 3-1/2" 'X' Landing Nipple with 2.S13" seal bore. 7-5/S" Baker 'S-3' Production Packer crossed over to 3-1/2". 3-1/2" 'X' Landing Nipple with 2.S13" seal bore. 3-1/2" 'XN' Landing Nipple with 2.813" seal bore and 2.75" No-Go. 3-1/2" WireLine Entry Guide spaced-out into liner top. I +1-9800' I BAKER 5-1/2" x 7-5/8" Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger Crossover to 3-1/2" ST-L - - y'~_e Ty'~_- RP Shear DV DV DV DV -------- Horizontal Sidetrack into Zone 1 Sands Date S/23/01 Rev By WSI Proposed Completion Comments 3-1/2" S.S1 lIft, L-SO, ST-L I +/-12,506' I Plug Back Depth I +1-12,420' I PRUDHOE BAY UNIT WELL: 5-26A API NO: 50-029-21984-01 Alaska Drilling & Wells 7800 8000 8200 - <? c§ 8400 '" & .<= P. [) ¥ ]! ~ " (-- 8600 8800 9000 I I I .I I I I' I ; ;I ,I " ~ ,," '<q, # ~.....:l'I'" ~ , ,~' /' .# .,.' " '" '~ Start Dir 12/100': 10710' MD. 8600.I'TVD Start Dir 20.5/100' : 10730' MD. 8615.21 'TVD 10767.73' MD, 8644.78' TVD ,--, ,-, FORMATION TOP DETAILS No. TVDPa,h MDPath Formation 10764.29 TZ213 10788.97 WD-23SB 8690.00 WD-22TS 8779.00 WD-TZIB 8812.00 11033.42 WD-TZIA SI"'V¡YI'RO""A", O\-2"A, Der,b """ ("""" "",""', "'W" Ii" '" n",-ked "a" Ibi"H'" """ -, I)! ,^II S N.""" , .S ¡n"s,""" SIn' "'RO"'>J 'AI" N"'>R IVD N .S I-W N,,"""" ""'I': SECTION DETAILS 2e MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSee Target I 10710.00 40.79 14.65 8600.10 1909.91 0.00 0.00 5355.27 2 10730.00 41.06 18.29 8615.21 51 1913.63 12.00 85.00 5367.93 3 10767.73 27.49 8644.78 5139.54 1922.63 20.50 135.95 5391.07 4 10805.93 27.49 0.00 0.00 5413.38 5 11138.34 78.00 20.50 56.25 5653.35 5-26A Land a 6 I 92.47 89.85 8826.82 5307.50 12.00 78.14 5714.37 7 I 92.47 89.85 8809.82 2663.39 0.00 0.00 5919.94 8 I 92.00 75.00 8804.00 2810.00 10.00 -91.51 6012.70 5-26A Mid-poiDt A 9 11934.20 91.09 59.84 8799.88 2949.72 10.00 -93.21 6134.88 12506.33 91.(19 59.84 8789.00 3444.31 0.00 0.00 6637.21 5-26A TD CASING DETAILS No. TVD Name Size MD All TVD depths are ssTVD plus 64' for RKBE. 20.5/100': 10805.93' MD, 8675.75'TVD Starl Dir 12/1 00' : End Dir TVD : 11633.94' MD. 8809,82'TVD End Dir : 119.J4.2' MD. 8799.88' TVD 5600 6000 8789.00 12506.32 31(2" 3.500 ,--~-, 3 1/2" 6600 ¡ 7000 6800 Vertical Secti"n aI 3 J .26" [20011!in] 6000" 5800 . 5 & .<= Õ ~ '5 Q V) 5600 . 5400- 5200 . 5000 . , 1800 iNlOliMA 11011' No. TVD FORMATION TOP DETAILS No. TVDPath MDPalh Forl11atioD I 2 3 4 5 8642.00 8662.00 8690.00 8779.00 8812.00 11033.42 TZ2B WD-23SB WD-22TS WD-TZII3 WD-TZIA CASINCi DETAILS MD Name 8789.00 12506.32 3 1/2" D,'I"" Ikl"" ", Size 3.500 1'1100""1 I't", ,1I1.lI,'P"", OI.)"A! "'"I I)"" '1\I'!J1I" MS nail' ""¡,,,ed Ihlr ,~----- W1tl1)11AOS Im,I>"k rA""1! I>I!AIIS ]VD ~.S ""'I" SECTION DETAILS MD Inc Azi TVD IN/.S +E/-W DLeg TFace VSec Target 10710.00 40.79 14,65 8600,10 5105,39 1909.91 0.00 0.00 5355.27 10730.00 41.06 18.29 8615.21 5117.95 1913,63 12,00 85,00 10767,73 8644,78 5139.54 20.50 135,95 10805.93 8675.75 000 0.00 11138.34 78.00 8829.00 20,50 56.25 5-26A Land a 11239.16 89.85 8826,82 12.00 78,14 11633,94 92.47 89,85 8809.82 0,00 0,00 11782.38 92,00 75,00 8804,00 2810.00 10.00 -91.51 5-26.A Mid-poinl A 11934.20 91.09 59.84 8799,88 2949,72 10,00 .93,21 12506.33 91.09 59.84 8789.00 5673.56 3444.31 0.00 0,00 5-26A TD 1'2" All TVD depths are ssTVD plus 64' for RKBE. : 1.l239.16'MD,8826.82'TVD SJali Dir 20,5/100' 10805.93' MD, 8675.75'TVD nd Dir : 10767.73' MD, 8644.78' TVD StaI1Dir20.5/100': 10730'MD,8615,21'TVD 2000 2200 138.34' MD, 8829'TVD 5-26.A TD Total Depth: 12506.33' MD, 8789' TVD End Dir : 11934,2' MD, 8799.88' TVD Star] Dir 101100': 11633.94' MD, 8809.82'TVD 2600 Wes]('I/East(+) [200ft;;n] 3000 3600 3400 1'....-..-...-'--"-....-..'-.-.-.-'-.'--.-..'.--.--'-...- ... ....-. -.-.--.-----.-.--.--.---------...--.--.--..------------.--------------.------.-.------.-----..--.------ II' Company: BP Amoco Date: 8/23/2001 Time: 09:23:32 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-26, True North \ Site: PB DS 05 Vertical (TVD) Reference: 16: 07 5/12/197700:0064.0 Well: 05-26 Section (VS) Reference: Well (0.00N.0.00E.31.26Azi) t. ~~.IIp'~!~~- . Plan 05-26A Plan: 05.26a wp05 [ Fie.ld ~ . ... .. . ..:-.P.~.dh~;-B~-~:" ~:.:::.:-:-:.: ..-:-- --- ..- -.-c.--." -:--:=:=.::::::::.C::-::::':::::-':':C:::.::-::-':::.:::="-:-:-::::::-.:..":.-':':.::=::::.:C'=.:::-:::==:.C=-=.:::.:::-::-::::=---:::-:::::::::::C:::-C:::-==::::-:::':':=::.:-:::::::-::::..-:::.:.c.:::..:.c:==:-:.:== .::::::: ---:C::::::::':':. :.=r I North Slope UNITED STATES I Map System:US State Plane Coordinate System 1927 [' Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level ( BP Amoco Planning Report - Geographic Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 -" ."--.- -..--.-- --. -,-,.._-_...-._..._".__."h_._,,_,~ .-.-..--,"..",-,.-",.---.-- . . ----...---"" - - -------. ._~. "-'---'.-'-----.-".,-.-.-" ..--"",,,.._.-.,,~.._-_._--_._-'-'----'-'------'-"'--"----.-<.----- .--..---.-.".---- "-.- -~- .... . __'n"'-n- - - -. -.--"- 5947204.70 ft Latitude: 70 15 35.696 N 697428.91 ft Longitude: 148 24 14.424 W North Reference: True Grid Convergence: 1.50 deg " ...., ... ..-..., - '--""-'.'~'''-''~--_.'-"'--'-''--'' .-..,~_....._---,_.,-,-_.."_..- ...,-.--.,. -------"'.'.''''-'---.'---'-- ....._-. .-..-.-,. . 70 16 0.955 N 148 24 23.910 W 0.00 deg 0.00 deg . -~._._-,- ......... -. __n_.___..'"'"-,'-----'--'---'''''',-"-,-,.".,-,.,,,,-,-.------...'---------------.---"----''''.'-'''. -----"-,..--,.-,,..,_._. n-" --, .,,"" .' ..."..-..-....."- ~._~._"...~.- ._u. - . -.- PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: I Position Uncertainty: 0.00 ft I Gr~~~~- ~~~!!~..__._._...... .... --.. ....~,o.° ..~ ...-...--.....--..........-..--..... Site: 05-26 05-26 Surface Position: +N/-S 2568.28 ft +E/-W -325.92 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 2568.28 ft +E/-W -325.92 ft Well: Slot Name: Northing: 5949763.41 ft Latitude: Easting : 697035.80 ft Longitude: Northing: 5949763.41 ft Latitude: Easting : 697035.80 ftLongitude: Measured Depth: 30.00 ft Inclination: Vertical Depth: 30.00 ft Azimuth: "_., ._,_.-..~. .-' -"..~..__.. . - -""--"--""-""-'"'-'~'" Wellpath: Plan 05-26A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 16: 07 5/12/1977 00:00 8/2/2001 57507 nT Depth From (TVD) ft 0.00 31.26 Height 64.00 ft +N/.S ft 0.00 .. _...."..-..-.._,.,~.."_..,"..._",."._".__._-_...- ".--.."..".-..""""--''''''''- 26 70 16 0.955 N 148 24 23.910 W 05-26 10710.00 ft Mean Sea Level 26.74 deg 80.80 deg Direction Plan: 05-26a wp05 Date Composed: Version: Tied-to: 8/8/2001 1 From: Definitive Path Principal: Yes . .-.- -- _..-- -_.- .. -- - .. . ---'.'''I'''.''~'''--''''-''-'''~'-'~''''-''~~'-' "..,- Plan Section Information .-...-----'-'- ..- ._..~---- _.--------.-----. --___.__n_-'.,- -"__n__"-- --_.- -,'--'-"----'-------'-- MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO .. . ..t.t......... ".,.......:~~~."_..__..,-~~g_._._...,....,.__..._c_-~"- _._._-- -~,,~.,_...J!:_,..._._-_._..__.,_.:...,~,....:,.,,_...,._".:~.~~L~..9Ef!:.~~,-~11~~_~.~~~t1PP!t:~_,.._._~~.~_....: ... 10710.00 40.79 14.65 8600.10 5105.39 1909.91 0.00 0.00 0.00 0.00 10730.00 41.06 18.29 8615.21 5117.95 1913.63 12.00 1.33 18.21 85.00 10767.73 35.83 27.49 8644.78 5139.54 1922.63 20.50 -13.85 24.38 135.95 10805.93 35.83 27.49 8675.75 5159.38 1932.95 0.00 0.00 0.00 0.00 11138.34 90.00 78.00 8829.00 5296.85 2168.93 20.50 16.30 15.20 56.25 11239.16 92.47 89.85 8826.82 5307.50 2268.97 12.00 2.45 11.75 78.14 11633.94 92.47 89.85 8809.82 5308.55 2663.39 0.00 0.00 0.00 0.00 11782.38 92.00 75.00 8804.00 5328.05 2810.00 10.00 -0.32 -10.00 -91.51 11934.20 91.09 59.84 8799.88 5386.16 2949.72 10.00 -0.60 -9.99 -93.21 12506.33 91.09 59.84 8789.00 5673.56 3444.31 0.00 0.00 0.00 0.00 - ---------..---.- ..--..--- .-..- --- Target , ' , ."-'.'''-'~''-'' ,.~.. .M,_,'" ,~,- ..'"-''''''''''' .-.. ...~ ._" ,.-.. ..,_.......""."~."..',",, ."",,.'.. 5-26A Land a 5-26A Mid-point A 5-26A TO ~. "-,,,---,-,,-,,-,--,,-,-,-"'.._--"--'~-'...._.....'" ~- ..w.._-,_..__...~.~"- . .... -.--"'-"-'---' --, '''''''-' ". -" " .. '--"-"''''"---'''.'. .-..-..--......"...---..." "."h._"-"'''''-'''.'''-- .. Section 1: Start 10710.00 10725.00 10730.00 14.65 8600.10 17.38 8611.44 18.29 8615.21 0.00 12.00 11.99 5105.39 1909.91 5355.27 5114.82 1912.62 5364.74 5117.95 1913.63 5367.94 40.79 40.98 41.06 Section 2: Start 0.00 1.26 1.61 0.00 85.00 82.60 0.00 18.23 18.10 . '.""""'":'.'" ,- """'''''.'''', '.T"" ~-"-"'~._''"'-'' "'." ,....'- 'W_'-"-~"-""-'"''-'''\''''"'~'",,"'-''' - ..~" .,-.,...,-., ---."" "'-".~'~''''''.~''''-~-'''f''''--''"~'''~-'--'-'~--'''''--'-'-'T''-""'_."'--'-"---'-;'-'--'''''''-'.''._--'-':'''-~-'''''':~-:-'~~-''-'-...,.~~~~_.-.......~---_..~---...,...-.--_.";""'"----.,.-,-..-~-;-._.~-~..-----~:.----;---....--,-------:~...,.~""--- ." --,_.~. . ... ----.":.,;",-~":,-,,-,,,.',.,"'"''_R'''''"''' . . MD. ft . . ~",,'" . ... . ~,,,,,~.,, ........ 10750.00 10767.73 lncl, deg . ,_.,,,-,",,,,..~.....,,",,..~.,,,, 38.20 35.83 . Adm . TVD +NJ~S +E/';;W VS DI.;S Build Turn TFO . .?"~~..c,~-"......c._-~.".....~..."-"~;.._~-,..._.....~~L.---~,._._-_.!t...~,.__..._.--..:---lt_,..~~._..__~r~(~..c~~~_:~"~~[~,~-~~~~~!-,~gp~..._."._.1~_~..,...~..._- ... 22.90 8630.62 5129.89 1918.10 5380.46 20.50 -14.30 23.05 135.95 27.49 8644.78 5139.54 1922.63 5391.06 20.53 -13.37 25.88 132.45 I( (' BP Amoco Planning Report - Geographic i.~:r~;:-~~=~-------------------~:i=~=~~~~~~~e No:--~~-i I Site: PB DS 05 Vertical (fVD) Reference: 16: 075/12/197700:0064.0 I l.. ;;:;~.a_~:__~!~~~~~~-_._-- ----.-.... - -..-.---.-.--..---.--. -_._.._---_._--_.__._--------;;~:_~~-~~:~~::.~.~----~~3~~'~~~.5~~~~~-~~~~~~~~----_._-- ----- -- ..---- -_..___1 Section 2: Start r..---.---.---..--.----...----.--.---..-----.-..'---..------------------------.-.----.-----.--..---------.---------------.-------..---.---. I MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO I-==--===~-~=====-==-=------=====-===:=~====-=~::-:==:---:=====-~-:==:::=:-::===:~=::-::- Section 3: Start MD Incl tt deg 10805.93 35.83 Section 4: Start Azim TVD +N/-S +E/-W VS deg ft ft ft ft 27.49 8675.75 5159.38 1932.95 5413.38 ._'-""--"_.'~''''''-''--''~''-"- - .,- -"-,,-,,.-._.._- --... n__- __'h_"- '-"''''~'--'_.-.~.".,,---_...,......_,_._"..- ,--- -.__. n. -,,-_. ._--'.-, -.-. '--"-'~-,"'-.n"-_"_~"."'.._~.,--,__.-..n..,_~._._,,---.. --- . DLS Build Turn TFO deg/100ftdeg/100ft deg/10Oft deg 0.00 0.00 0.00 180.00 ..,-_.,."...~..,-".,~'-:--"_._w~..,...._-"--~.~-~~~-,-_.-'-'---'--"--'~'''''-''''-~~''-~'-'',----'~"''.'--~'---~-..~-~_.._4__'_'_'~''''~'''-~-'''-..'''-~-'-'-'--''-~'''--'-'--,---",,,,,,.,~-,--~,,,-_._~--~,,~,--,,--~,,--~,,-,_.,,,,,--,,~---'~"~---'~-'''''.___4'_~_'~''''._'~-''-''--'~'''~,' MD Incl Azim TVD +N/;.S +E/-W .VS DLS Build Turn TFO _._-"."_._._..!~._...._-,--~._~~~--~".._'"...._~.~~._---_......._....,..__._~--..,-"..;.,-_.__...~.c..~-,~c._--~,-_.~~-~_.._~--,-~-~~._~---, de~:~_~ft._~~~~~!~~~.._~~~~.?~._-~~~-_._-,._.,---~-~"..~.__... 10825.00 38.12 32.76 8690.99 5169.29 1938.71 5424.84 20.50 12.02 27.63 56.25 10850.00 41.44 38.87 8710.20 5182.22 1948.09 5440.76 20.50 13.28 24.43 52.04 10875.00 45.04 44.19 8728.42 5195.02 1959.45 5457.59 20.50 14.41 21.31 47.34 10900.00 48.86 48.87 8745.49 5207.56 1972.72 5475.20 20.50 15.28 18.72 43.46 10925.00 52.85 53.03 8761.27 5219.75 1987.78 5493.44 20.50 15.95 16.61 40.26 10950.00 56.97 56.76 8775.64 5231.50 2004.52 5512.16 20.50 16.47 14.92 37.64 10975.00 61.19 60.15 8788.49 5242.70 2022.79 5531.22 20.50 16.88 13.57 35.49 11000.00 65.49 63.28 8799.70 5253.27 2042.46 5550.47 20.50 17.19 12.51 33.74 11025.00 69.84 66.19 8809.21 5263.13 2063.37 5569.75 20.50 17.43 11.67 32.34 11050.00 74.25 68.95 8816.91 5272.19 2085.35 5588.90 20.50 17.61 11.03 31.23 11075.00 78.68 71.59 8822.76 5280.39 2108.22 5607.77 20.50 17.74 10.56 30.38 11100.00 83.14 74.15 8826.71 5287.65 2131.81 5626.22 20.50 17.83 10.24 29.76 11125.00 87.61 76.67 8828.73 5293.93 2155.92 5644.10 20.50 17.89 10.05 29.36 L~ ~H~_~'~~~~ ._._..~.~.:~~..__.__.!.~~~~_. ._-_.~~~.~:~9._-_. . ... ~,~~~_:~~--_..._.~-~~~:~-~_. .....~~-~~:.~~-_._._--_._~~.:.?.~_.__._._-~~~-~......_-~~~~~.... -_..~~~~~--.. .-.--_. ..... . Section 5: Start . ---'~'....-MJ)_...._'.-"--I;~i7~'..~C-A¡Ï';~~--~-~-'_.-T--VD.~."--c---.;N/~S. .._-'.--~-+Ei~w7'.._.~._.'.'-VS~7.._'.'~~DLS~.---'~B;iIcr'----Tfu:;-.~.~..~-.._.TFO:--."';'~'.__._-~_..'---"._.:._.-,.C-;'..C-. _._.;_..,.c..!~....,_....~..c.~~~-";~..,........__.~~!_.._-~.,.:~._..;"_.,~..~.~,_._.:_~.,.."~.._,..._.,~:::,._~,_..,..;-;"-..;,..~,...L~...;.__c.~!~."-:_~.~.~""~~.!P-9!t~eg/~.g_~~:Æ.!~!:22~__~~_~~g,~c.,~,.__._-_.__...c,._c-"'~._:_--;. 11150.00 90.29 79.37 8828.97 5299.14 2180.36 5661.24 12.00 2.47 11.74 78.14 11175.00 90.90 82.31 8828.71 5303.12 2205.04 5677.44 12.00 2.46 11.75 78.14 11200.00 91.52 85.24 8828.18 5305.83 2229.88 5692.65 12.00 2.45 11.75 78.17 11225.00 92.13 88.18 8827.39 5307.26 2254.83 5706.82 12.00 2.44 11.76 78.24 11239.16 92.47 89.85 8826.82 5307.50 2268.97 5714.37 12.02 2.43 11.78 78.31 Section 6: Start -- - ------ ._----_._.,..-_......_.__.,~-"_._-_........_~... .,.,,~..... ..-...-...,.,.-..---.-.. ..,., - ---._""_".---"._..~.._..,~-,.,-"...",,,~...,,~.,...~_..,,....- '--"'"-"'''-'''u_''-''~-'''''''--''' ,--.. ",-". .,,- ,... """,.".,.~"_,__.,,,~~-,..,,_-,,_,,_---,,,,-'~",--~"--......-_."'".._._._._..._...._~ -'..~."~'.-"".'----'-'."..'-~"-"-" .-- ._".__._....".~,~.."...- -.--........"..... - -.,,-.--.- .... .-.. _.- ,,_.... .-".-. 11300.00 92.47 11400.00 92.47 11500.00 92.47 11600.00 92.47 11633.94 92.47 Section 7: Start 89.85 8824.20 5307.66 2329.75 5746.05 89.85 8819.89 5307.92 2429.66 5798.11 89.85 8815.58 5308.18 2529.57 5850.18 89.85 8811.27 5308.44 2629.47 5902.25 89.85 8809.82 5308.55 2663.39 5919.94 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11650.00 92.43 11700.00 92.28 11750.00 92.12 11782.38 92.00 88.24 8809.13 5308.82 2679.43 5928.50 83.24 8807.08 5312.53 2729.24 5957.51 78.24 8805.16 5320.56 2778.53 5989.96 75.00 8804.00 5328.05 2810.00 6012.70 10.00 -0.27 -10.01 10.00 -0.29 -10.00 10.00 -0.33 -10.00 10.01 -0.36 -10.01 -91.51 -91.58 -91.78 -91.99 Section 8: Start .. ,.. "'."7'..~""'~"~"'.'~~''''I.'''~'''~''-~.''"''~'-'''''''~'''.,,..~.~.~.:.:._..,,,,..,,--,.~,'~..-...-~~,,.._.~,,...:,:,,,,,-,,,.,,,,-,---'~'-"'.'-:'-"".-"'~-~''''';- . --- .. . -.--.-- ...- .,.... ._~._,,- -"-.'- - - - . --. --.. -. -~.... -~ .- ..~- .¡-- ..., - - - .._.n -. -.-... - ~.. -. --. .- .. ~ -. . - - -- -. .. MD Illcl Adm TVD +N/-S +E/-W VS .. D.LS .. BuildT~rll. TFO " . .- ... _!~.... ......... _.,_._.,.:~~~,_..__c..._..~-~~._... ..-".-, -_.._,._~,._--~._,.._.,._....,......c~._-_...;._:.~_..~.....~._._-,_."..~_.....!~-_._." ._....._..~~~~~.~?~.:9~~~,?~~~,~~{~e..~._--_.....~~~~....."..-. ....-.-'.."-'..'.-.-.-..'.-..--' . 11800.00 91.90 73.24 8803.40 5332.87 2826.94 6025.60 10.00 -0.57 -9.99 -93.21 11850.00 91.61 68.25 8801.87 5349.35 2874.10 6064.16 10.00 -0.58 -9.99 -93.27 11900.00 91.30 63.25 8800.60 5369.87 2919.66 6105.35 10.00 -0.61 -9.98 -93.42 11934.20 91.09 59.84 8799.88 5386.16 2949.72 6134.87 10.00 -0.63 -9.98 -93.55 ( BP Amoco Planning Report - Geographic ( 100.- .. . . . --.-.. - .-- I Company: BP Amoco Date: 8/23/2001 Time: 09:23:32 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-26. True North , Site: PB DS 05 Vertical (TVD) Reference: 16: 075/12/197700:0064.0 i Well: 05-26 Section (VS) Reference: Well (0.00N.0.00E,31.26Azi) 1.._~~!I~.!~b:__.~!~~~~.3.6_~__._--_._-_._-_.._---- ----..--------..-----.-----. ---_._---_._._-~~~~_._._..._---_.._--_._._-----~~~~-~~~----_...--. ---..---.-------.- --..--.---.--. ---. ._1 Section 8: Start Page: 3 '-'_'_-_._-_._--,----_.u,,--.-.~---,-_.__._-----_..~---"-'----,---------,-----,----------,-----,--~_.,------,-,-----_.~--"~-_."",,,,-_._,----, I=...~~~-=~~~=~m~~~~~-.. ~=;/~~~~~~=~-;==;~~;~=--~~~=~~=~~~~===-=~~ Section 9: Start ,_.. ._-_.MD_.._.n-I;~ì--.-----A;i~._.-----_._.TVD-_._---+Ñ-¡'S--"+Ei.w .----..-..vs-.---. ..DLS--~B~iïd-----1)'-;:;.-----TFO'--._.__._---------_.- I ft deg deg. ft .. . ft. ft ...ft deg/100ft deg/100ft degl100ft deg "'-'~"~-"'.'_._.""'."-"--""'-"-'-"-_.---""'-~......_-_._~--~._..~---.__.~_.'-_.,._--_.~..."'--'~'~-_"-_..~._,_...._.._-------..~_...~~-~~-~._.-.....__._----~--.~-~--,-,--.._.._-_._.."._....._-..~-,..-_..","_.~'-'''--'_.~--'--'~'-"--'--_..'~"-~.'._-'-_._.~_..__A'_'" 12000.00 91.09 59.84 8798.63 5419.21 3006.60 6192.65 0.00 0.00 0.00 0.00 12100.00 91.09 59.84 8796.73 5469.45 3093.05 6280.45 0.00 0.00 0.00 0.00 12200.00 91.09 59.84 8794.82 5519.68 3179.50 6368.25 0.00 0.00 0.00 0.00 12300.00 91.09 59.84 8792.92 5569.91 3265.94 6456.05 0.00 0.00 0.00 0.00 12400.00 91.09 59.84 8791.02 5620.14 3352.39 6543.85 0.00 0.00 0.00 0.00 12506.33 91.09 59.84 8789.00 5673.56 3444.31 6637.21 0.00 0.00 0.00 0.00 -. --.,... --.. "-'-'""._'-"'~,,-'-'-..u_.- Survey - .-...,..." ,.-......."......,,-- "..._n'- ---....-,---.....,- .,... -..... ..,. ....._.._-"._~ - '-'''-----_._~.-..--... -"....-..-.---.." '~-'''--'-_...-.'-- "-""-..--"-'-"-'- .......-..".-..,,-. ,._.~. '.-"----'--"-- ..---...-..---.- .--- u_.....---,_,..'n.____...".,P' '--'-.'-'-'--.-- ..--- .-.. .... n-.._" ._.~._._.__....,'--....__...,-~,...,,_."". -,.---..-.., N__~'__'.""'--.--- ---'--:---'-'7"~_~'r"'---;----7-r--:'~.:"~'~~-:-~""'-----~77-7-~:-"--.~-T"'~""':""'''''''''':~';''"-;---'''-''''-,-'-~'''~~'-'''''~'''~'-''':'7"''';:'''';-:-'''";'--'''---"'-~.".----"í.~~-~'~"'-7~-:-:-"'~-'-~"r;",-"""-~-"'"",,~'--'~'~''''''---"'''_.'~'''.'''':~,~'''''''-'''-:---~'~'~''I~:---r._,-~-_.- . .' . .l\1ap, Map , .<~~..Låtitûdc ....~. <-~Lo..gitude"-;> MD Incl. Azhn ~VD :+N/..,s +E/"W Northi~g .. E~st1~gDeg.)\:li~~ec . J>~gM~I1...~ec.' c_..............__!~...~_......_...;. -,._~.~~._;..__.c:__...J~.~!~_...,._,-,:__c.....~~~--".._."':_.;c.-'-'-_._-'-~cc_.";;-"...","-_:;":_~--"-C_~"~._~-~~;'-~-"c'-'-"'-'-'--""--~'-';"':"-'._~._-----,c-.-"--,-c_."_..-,-..~._":"-'----'...C._._."---"C.-:".-"-'_C--'--.-_C.-'-...-'-..-.. 10710.00 40.79 14.65 8600.10 5105.39 1909.91 5954916.75 698811.32 70 16 51.164 N 148 23 28.282 W 10725.00 40.98 17.38 8611.44 5114.82 1912.62 5954926.25 698813.78 70 16 51.257 N 148 23 28.203 W 10730.00 41.06 18.29 8615.21 5117.95 1913.63 5954929.40 698814.71 70 16 51.287 N 148 23 28.174 W 10750.00 38.20 22.90 8630.62 5129.89 1918.10 5954941.46 698818.87 70 16 51.405 N 148 23 28.043 W 10767.73 35.83 27.49 8644.78 5139.54 1922.63 5954951.22 698823.14 70 16 51.500 N 148 23 27.911 W 10805.93 35.83 10825.00 38.12 10850.00 41.44 10875.00 45.04 10900.00 48.86 10925.00 52.85 10950.00 56.97 10975.00 61.19 11000.00 65.49 11025.00 69.84 11050.00 74.25 11075.00 78.68 11100.00 83.14 11125.00 87.61 11138.34 90.00 11150.00 90.29 11175.00 90.90 11200.00 91.52 11225.00 92.13 11239.16 92.47 11300.00 92.47 11400.00 92.47 11500.00 92.47 11600.00 92.47 11633.94 92.47 11650.00 92.43 11700.00 92.28 11750.00 92.12 11782.38 92.00 11800.00 91.90 11850.00 91.61 11900.00 91.30 11934.20 91.09 12000.00 91.09 27.49 8675.75 5159.38 1932.95 5954971.32 698832.94 70 16 51.695 N 148 23 27.611 W 32.76 8690.99 5169.29 1938.71 5954981.38 698838.44 70 16 51.792 N 148 23 27.443 W 38.87 8710.20 5182.22 1948.09 5954994.56 698847.47 70 16 51.920 N 148 23 27.170 W 44.19 8728.42 5195.02 1959.45 5955007.64 698858.50 70 16 52.045 N 148 23 26.838 W 48.87 8745.49 5207.56 1972.72 5955020.53 698871.43 70 16 52.169 N 148 23 26.452 W 53.03 8761.27 5219.75 1987.78 5955033.11 698886.17 70 16 52.289 N 148 23 26.013 W 56.76 8775.64 5231.50 2004.52 5955045.29 698902.59 70 16 52.404 N 148 23 25.526 W 60.15 8788.49 5242.70 2022.79 5955056.96 698920.56 70 16 52.514 N 148 23 24.993 W 63.28 8799.70 5253.27 2042.46 5955068.05 698939.95 70 16 52.618 N 148 23 24.420 W 66.19 8809.21 5263.13 2063.37 5955078.45 698960.59 70 16 52.715 N 148 23 23.811 W 68.95 8816.91 5272.19 2085.35 5955088.08 698982.33 70 16 52.804 N 148 23 23.171 W 71.59 8822.76 5280.39 2108.22 5955096.87 699004.98 70 16 52.885 N 148 23 22.505 W 74.15 8826.71 5287.65 2131.81 5955104.75 699028.36 70 16 52.956 N 148 23 21.818 W 76.67 8828.73 5293.93 2155.92 5955111.65 699052.29 70 16 53.018 N 148 23 21.115 W 78.00 8829.00 5296.85 2168.93 5955114.92 699065.23 70 16 53.046 N 148 23 20.736 W 79.37 8828.97 5299.14 2180.36 5955117.50 699076.60 70 16 53.069 N 148 23 20.403 W 82.31 8828.71 5303.12 2205.04 5955122.13 699101.16 70 16 53.108 N 148 23 19.684 W 85.24 8828.18 5305.83 2229.88 5955125.49 699125.92 70 16 53.134 N 148 23 18.961 W 88.18 8827.39 5307.26 2254.83 5955127.57 699150.82 70 16 53.148 N 148 23 18.234 W 89.85 8826.82 5307.50 2268.97 5955128.18 699164.95 70 16 53.151 N 148 23 17.822 W 89.85 8824.20 5307.66 2329.75 5955129.93 699225.70 70 16 53.152 N 148 23 16.052 W 89.85 8819.89 5307.92 2429.66 5955132.81 699325.56 70 16 53.154 N 148 23 13.142 W 89.85 8815.58 5308.18 2529.57 5955135.68 699425.42 70 16 53.157 N 148 23 10.232 W 89.85 8811.27 5308.44 2629.47 5955138.56 699525.28 70 16 53.159 N 148 23 7.322 W 89.85 8809.82 5308.55 2663.39 5955139.55 699559.18 70 16 53.160 N 148 23 6.334 W 88.24 8809.13 5308.82 2679.43 5955140.24 699575.21 70 16 53.162 N 148 23 5.867 W 83.24 8807.08 5312.53 2729.24 5955145.25 699624.90 70 16 53.199 N 148 23 4.416 W 78.24 8805.16 5320.56 2778.53 5955154.57 699673.97 70 16 53.278 N 148 23 2.980 W 75.00 8804.00 5328.05 2810.00 5955162.88 699705.22 70 16 53.351 N 148 23 2.064 W 73.24 8803.40 5332.87 2826.94 5955168.14 699722.03 70 16 53.398 N 148 23 1.570 W 68.25 8801.87 5349.35 2874.10 5955185.85 699768.74 70 16 53.560 N 148 23 0.196 W 63.25 8800.60 5369.87 2919.66 5955207.55 699813.75 70 16 53.762 N 148 22 58.869 W 59.84 8799.88 5386.16 2949.72 5955224.63 699843.37 70 16 53.922 N 148 22 57.993 W 59.84 8798.63 5419.21 3006.60 5955259.15 699899.36 70 16 54.247 N 148 22 56.336 W ( BP Amoco Planning Report - Geographic ,( \-c~~~a~y: BP -A~~co -- -- .- -- . ---_. -... --_.- ._, .- .- -Da~; 8/23/2001 Tim~: 09:23:32. ..- . - -pag~: - 4- -1 I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-26, True North I l~~____-------~-~~------_J Survey r-.-- ---.------...'---.-..-.--.--.--..--.--.-..---.-----,----..--------.--.--.-.-.---------. ----.--.-.--..--.-----.------'-..--.---.--'---.-----.-.---.-------...--- -.--...---.--- I .. Map Map <- Latitude ---> <- Longitude -> , MD loel Azim TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min See ft deg deg ft ft ft ft ft < ..- . -. ..--- ,-,.-"".'--..ø.-. -'~--_._"- ~"--_.._,.~,-,,~_. ._..~_.,_._--_.__._..._~- .-----.-..-..-----.-.-------.--..------.----...-,-,-.----.__._._---_._._.._---,_.._~..__.,-_._._---_.__._,---_.--~-~,_._..~._-,._-_._-,--_."._~"._--_..- 12100.00 91.09 59.84 8796.73 5469.45 3093.05 5955311.63 699984.46 70 16 54.741 N 148 22 53.818 W 12200.00 91.09 12300.00 91.09 12400.00 91.09 12506.33 91.09 59.84 8794.82 5519.68 3179.50 5955364.10 700069.56 70 16 55.234 N 148 22 51.299 W 59.84 8792.92 5569.91 3265.94 5955416.58 700154.66 70 16 55.728 N 148 22 48.781 W 59.84 8791.02 5620.14 3352.39 5955469.05 700239.75 70 16 56.222 N 148 22 46.262 W 59.84 8789.00 5673.56 3444.31 5955524.86 700330.24 70 16 56.747 N 148 22 43.584 W - ____'n. '------"" --. .- --,-."....,..------,--".-..--. .._-. .,".-.-...." ~'--"-""--"--'-'---'--'-----'---'-------"--'--'---~_.._-----_..~~-_..-._-_.._---_.._.._--_._"'______RR.-.-.-..--.---.-. .---.--... .~._-_._.._----- .. ~--,.-~--.. ---~,-'_._---""-'._'-'----"'-'-"--' ...--...-.".. n."._-. .....-.. ..". - : ~": ¡;....::" "'. ..... "~"""".~"'.. . H 198744 (' (' DATE 09/28/01 CHECK NO. 00198744 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALAS 092701 CK092701H PYMT OMMENTS: HANDL NG I NST: 100.00 100.00 Per it to Drill ee 5tH - Terri Hubb e X4628 OS'~ IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 198744 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00198744 PAY ONE HUNDRED ßc 00/100***if****************-'**************** lJþ DOLLAR To The ORDER Of ALASKA OIL AND GAS CON5ERVATIONCOMMISSIDN 333 WES.w 7TH AVENUE SUITE 100 ANCHORAGE ,"K 99501 DATE 09/28/01 II NOT VALID AFTER 120 DAYS Ç¿~~fiLL. AMOONT . !¡ 1 oo.~ III . g 8 7 ~ ~ III I: 0... . 2 0 :l B g 5 I: 0 0 B ~ ~ . g III ~---_".__.r.'--~ ' .. (' ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME (fia ()5 ~ 210/1 CHECK 1 STANDARD LEITER DEVELOPMENT j DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) I' ANNULAR D)S.POSAL U::::JNO ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ------' Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. .. . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,sùbject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY WELL NAME OS.- ¿~)./1 PROGRAM: exp - dev ~ redrll ~ serv - well bore seg _ann. disposal para req- FIELD & POOL ~ '/L) /t:;7) INIT CLASS ~LI I {) / L- GEOL AREA U UNIT# ('J /1 (d')'O ON/OFF SHORE D/l ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . c:Þ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . (J:) N 3. Unique well name and number. .. . . . . . . . . . . . . . . . C1S N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells. . . . . . . . . . ") N 7. Sufficient acreage available. in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator onty affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . .. . N 11. Permit can be issued without conservation order. . . . . . . . N A~R DATE 12. Permit can.be issued without administrative approval.. . . . . ~ -AJJ-- /1, If.:., ,O( 13. Gan permit be approved before 15-day wait.. . . . . . . . . . ~N . . ENGINEERING ~i: ~2;~;~~~:I~E~':I~~~~:~~i ~~rt"~g': ': : ': ': . ~ ~~C;\Ò~\~~O~\~\\"'" ,..~Ü\ . .. 17. GMT vol adequate to .tie-in long string to surf csg. . . . . . . . Y N . 18. GMT will cover all known productive horizons. . . . ... . . .. .1 N . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . N I ..~ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . ", N ~""......~ ~~ I:"e.~.....x. ~ . ~~: ~:e~~I~il~~~:':;ro~b:~:~~~I~e.e~~~p~o~~., ',: . ~ ?"~~~\~\,~c\~c,. ~~,~~ ~~\'-4Z~} . 23. If diverter required, does it meet regula~ions . . . . . . . . . . I ~ ~ \ 24. Drilling .fluid program schematic & equip list adequate. . ~ . . . N . . 25. 80PEs, do they meet regulation. . . . . . . . . À.' . . . . . N . ~- ,. ~/ A.' (. ~. E.~ ,26. 80PE pres~ rating ap~ropriate; test to -S-S'-JO psig. .. N ~~~"t=> ~ \- Q d '-\. ~.1':> . ~~ l . ... 1.:;;f::i!.A!~ '{ ;;..~ 27. Choke mamfold complies w/API RP-53 (May 84). . . . . . . . . N . ~. .' ... ~, ,. .' 28, Work will occur without operation shuldbWn. . . . . . . . . . . Y ~ "",,~ .. ~ ù.'i<-) ~\.JÃr' \\1>"'''' ~~~ . R:t-¡:¡.., "- ~~\,%-} "'{ <;~~ \o.~.".. 29. Is presence of H2S gas probable... . . . . . . . . . . . . . . Y QU 1/;....:5 ~~ ?¡-.¿S-ê-"L/ q¡ ::ÞS.-- 6- ~ (a:.u,.. . wI- VkJ¿£t5Uí~j k, CO?1..c.a.",,-Ir..t.{ "..~-¡'lo;. 30. Permit can be issued wlo hydrogen sulfide measures. . . . .. Y @2 D.h' ,-I .0 d v{(?. Y 1- 2~ itÜ!(}5 L-'r~ Z Ô . ....-z'\. - ~ S t:'P'" C., / / t..'C\z1j- 31. Data pre. sented on potential overpressure zones. . . . . . . ! ~ ,'- 32. Seismic analysis of shallow gas zones. . . . . . . . . ~. . . 0: ~. AP~ DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N ~ If ./to ,[))- 34. Contact name/phone for weekly progress reports [explo ry only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface;.. . (C) will not impair mechanical integrity pf the well used for disposal; Y N (0) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N' GEOLOGY: ENGINEERING:' UI IAnnular COMMISSION: ~ WM .8~s SF~ JM GEOLOGY APPR DATE /.: ,1, /) c 0 Z 0 (' -I :E :xl -I m Z -I :I: en :Þ :xl m ( » Y N Y N -\ Comments/lnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) it (. Well History File APPENDIX Information of detaHed nature that is not particularly gennane to the Well Pennitting 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 APPENDIX. No special effort has been made to chronologically organize this category of information. (: ( dO/-ddl J /300 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Dec 12 12:15:54 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name....... ........ . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AK-MM-11212 S LATZ BORDES/LOWE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 5 AK-MM-11212 D HAWKINS BORDES/FERGU # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 5-26A 500292198401 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 12-DEC-02 MWDRUN 3 AK-MM-11212 S LATZ BORDES/LOWE MWDRUN 4 AK-MM-11212 S LATZ BORDES/LOWE 31 11N 15E 1678 11 63.70 35.20 (" { # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 10699.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 2 - 5 COMPRISED DIRECTIONAL WITH NATURAL GAMMA PROBE (PCG) UTILIZING SCINTILLATION DETECTORS. MWD RUN 2 WAS TO SET THE WHIPSTOCK AND MILL THE WINDOW. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT ABOUT 10699'MD. 4. THERE IS A GAP IN THE SROP DATA FROM 10716.5'MD TO 10725.5'MD. THIS WAS DURING A WHIPSTOCK RUN AND NO DATA WERE ACQUIRED. AN UNEXPLAINED DATA GAP IN THE SGRD CURVE EXISTS FROM 11113'MD TO 11123.5'MD. 5. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN 5-26A ON 14 JANUARY 2002. THESE LOG DATA WERE RECEIVED FROM D. SCHNORR (BP EXPLORATION) ON 26 FEBRUARY 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 2 -5 REPRESENT WELL 5-26A WITH API#:50-029-21984-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12475'MD / 8809'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY COMBINED. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 F i 1 e Type.. . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and 1 clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ (" .5000 (' START DEPTH 10695.5 10699.5 STOP DEPTH 12422.5 12474.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --- BASELINE 10695.5 10708.5 10747.0 10764.5 10767.5 10779.0 10784.0 10789.5 10793.0 10802.0 10806.0 10817.0 10830.5 10835.0 10849.0 10854.5 10859.5 10870.5 10884.0 10889.0 10904.0 10909.0 10915.5 10917.5 10930.5 10936.5 10943.5 10945.5 10953.5 10958.5 10961.5 10965.0 10975.5 10978.5 10981.5 10990.5 10999.0 11015.5 11018.5 11027.0 12474.0 $ DEPTH # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: GR 10695.0 10708.0 10745.0 10762.0 10766.5 10779.0 10783.5 10788.5 10792.5 10801.0 10805.5 10817.0 10829.5 10833.0 10848.5 10854.0 10858.0 10868.5 10883.0 10889.0 10902.5 10907.5 10914.5 10916.5 10930.0 10936.0 10942.0 10944.5 10951.5 10958.0 10962.5 10966.0 10978.0 10980.5 10983.0 10990.5 11000.5 11016.5 11020.0 11028.0 12475.0 BIT RUN NO MERGE TOP 2 10695.0 3 10716.0 4 10992.0 5 11110.0 MERGED MAIN PASS. $ MERGE BASE 10716.0 10992.0 11110.0 12475.0 ( ( # . Data Format Specification Record Data Record Type. .................0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point...... ....... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10695.5 12474 11584.8 3558 10695.5 12474 ROP MWD FT/H 0.06 813.79 47.5991 3531 10699.5 12474 GR MWD API 12.96 185.1 55.9905 3433 10695.5 12422.5 First Reading For Entire File......... .10695.5 Last Reading For Entire File.......... .12474 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 File Type................LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/12/12 Maximum Physical Record..65535 F i 1 e Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10695.0 ROP 10699.0 2 header data for each bit run in separate files. 2 .5000 STOP DEPTH 10715.5 10716.0 ( $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (' 04-JAN-02 Insite Memory 10730.0 10699.0 10730.0 .0 .0 TOOL NUMBER 033 4.750 10699.0 Quikdrill-N 8.40 55.0 9.0 500 12.0 .000 .000 .000 .000 .0 108.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 ( ('" First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10695 10716 10705.5 43 10695 10716 ROP MWD020 FT/H 0.06 3.85 2.05886 35 10699 10716 GR MWD020 API 12.96 23.39 16.0855 42 10695 10715.5 First Reading For Entire File......... .10695 Last Reading For Entire File.......... .10716 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10716.0 ROP 10726.0 $ 3 header data for each bit run in separate files. 3 .5000 STOP DEPTH 10938.0 10992.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 07-JAN-02 Insite Memory 10995.0 10730.0 10995.0 35.8 48.7 # TOOL STRING (TOP TO BOTTOM) ( VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O TOOL NUMBER 033 4.750 10699.0 Water 8.40 65.0 9.0 500 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API Min 10716 0.3 15.2 Max 10992 83.02 148.51 First Reading For Entire File......... .10716 Last Reading For Entire File.......... .10992 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Mean Nsam 10854 553 31.5648 533 38.3386 445 ( .0 112.0 .0 .0 First Reading 10716 10726 10716 Last Reading 10992 10992 10938 (, Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 ( header data for each bit run in separate files. 4 .5000 START DEPTH 10938.5 10992.5 STOP DEPTH 11072.5 11110.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 08-JAN-02 Insite Memory 11110.0 10995.0 11110.0 56.9 82.5 TOOL NUMBER 033 4.750 10699.0 Quikdril-N 8.40 60.0 9.0 500 .0 .000 .0 '1(\ ~ 'I ( MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 112.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10938.5 11110 11024.3 344 10938.5 11110 ROP MWD040 FT/H 9.5 63.71 32.8719 236 10992.5 11110 GR MWD040 API 15.22 131.43 48.4144 269 10938.5 11072.5 First Reading For Entire File........ ..10938.5 Last Reading For Entire File......... ..11110 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 F i 1 e Type...... . . . . . . . . . . LO 1(1 ( Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 ,( header data for each bit run in separate files. 5 .5000 START DEPTH 11073.0 11110.5 STOP DEPTH 12423.5 12475.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 12-JAN-02 Insite Memory 12475.0 11110.0 12475.0 85.2 94.2 TOOL NUMBER 002 4.750 10699.0 Quikdril-N 8.40 60.0 9.0 500 .0 .000 .000 .000 .000 .0 137.0 .0 .0 I( Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.. ...... .... ." ..... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API Min 11073 0.32 23.07 Max 12475 813.79 185.1 Mean Nsam 11774 2805 52.5548 2730 60.2933 2680 First Reading For Entire File......... .11073 Last Reading For Entire File.......... .12475 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 12 / 12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing :( First Reading 11073 11110.5 11073 Last Reading 12475 12475 12423.5 Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 12 / 12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF (' t: physical EOF End Of LIS File