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Home My WebLink About181-143Nolan 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: 4/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250402 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 3/20/2025 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 3/16/2025 YELLOWJACKET PLUG BRU 212-26 50283201820000 220058 3/21/2025 AK E-LINE Perf BRU 212-26 50283201820000 220058 3/15/2025 AK E-LINE Perf CLU 7 50133205310000 203191 1/22/2025 YELLOWJACKET PLUG IRU 11-06 50283201300000 208184 3/20/2025 AK E-LINE Perf KALOTSA 10 50133207320000 224147 3/1/2025 YELLOWJACKET GPT-PLUG-PERF KBU 22-06Y 50133206500000 215044 1/25/2025 YELLOWJACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP MPE-20A 50029225610100 204054 3/13/2025 READ CaliperSurvey MPI 1-39A 50029218270100 206187 3/4/2025 YELLOWJACKET PERF MPU C-01 50029206630000 181143 1/30/2025 YELLOWJACKET PERF MPU K-17 50029226470000 196028 2/7/2025 AK E-LINE Caliper MPU S-53 50029238110000 224159 3/7/2025 YELLOWJACKET SCBL MRU A-15RD2 50733201050200 202019 3/10/2025 AK E-LINE TubingCut PBU 18-27E 50029223210500 212131 3/15/2025 YELLOWJACKET RCT PBU B-30A 50029215420100 201105 3/7/2025 READ CaliperSurvey PBU S-10A 50029207650100 191123 11/18/2024 YELLOWJACKET CBL-TEMP PBU W-220A 50029234320100 224161 2/22/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40256 T40256 T40257 T40257 T40258 T40259 T40260 T40261 T40262 T40263 T40264 T40265 T40266 T40267 T40268 T40269 T40270 T40271 T40272 MPU C-01 50029206630000 181143 1/30/2025 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.02 12:55:27 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,442'7,287' Casing Collapse Conductor N/A Surface 2,670psi Production 4,760psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT C-01 MILNE POINT KUPARUK RIVER OIL N/A 10,430' 7,287' 7,277' 1,008 7,287, 8,852, 9,075 & 9,185 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/21/2025 Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 181-143 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-20663-00-00 Hilcorp Alaska LLC C.O. 816 Length Size Proposed Pools: 110' 110' 12.6 / L-80 / IBT TVD Burst 6,782' MD N/A 4,930psi 6,870psi 2,338' 9,791' 2,338' 9,802' 81' 20" 13-5/8" 9-5/8" 2,310' 9,775' Erik.Nelson@hilcorp.com 907-564-5277 See Schematic See Schematic 4-1/2" N/A and N/A N/A and N/A Erik Nelson No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:40 am, Jan 14, 2025 325-013 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.01.14 10:41:09 - 09'00' Taylor Wellman (2143) 10-404 Witnessed BOP and Annular Test to 2500 psi. Production casing test with test packer set at ~ 6900'MD to 1800 psi per CO 390A SFD 1/17/2025 DSR-1/16/25 X JJL 1/21/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.21 14:10:41 -09'00'01/21/25 RBDMS JSB 012425 ®ôīīϙbÍıôϡ aϙϱ͏͐IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͑͏͕͕͒ϱ͏͏ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ IϙŘĺîŪèôŘ ĖČϡ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͕ϙ"ÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͐͗͐ϱ͓͐͒ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ @ôĺīĺČĖŜťϡ ®Ėīīϙbôôīƅ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͏͗͑ϙϼiϽ ϼ͘͏͒Ͻϙ͗͑͐ϙϳϙ͖͓͐͐ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ͕͐͗͑ϙŕŜĖϙЬϙ͕͖͔͏ϱċťϙa"ϙϼ͕͖͓͐ϱċťϙ«"Ͻϙ(ϙ"Fϙ @ÍŪČô ͏͘ϙbĺŽϙ͑͏͓͑ϙиϙ͓ϟ͗ϙ(a®ϙϼ͗ϟ͔ϙX®>ϙϳϙĺŪŘèôϙ®ťŘϽ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͐͏͏͗ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϙϼôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͖ϟ͖еϙЬϙ͕͒͏͏ϱċťϙa" aÍƄϙ"ĺČīôČϙϼôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͐ϟ͓еϯ͐͏͏ϱċťϙЬϙ͕͔͏͏ϱċťϙa" aĖĲϙI"ϙϼôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ bi(ϡϙϙ"г"ϟæČϟťĺŕϟÍĲîϟÍèħĺƯϟŜťÍŘťϟÍťϟ͛͛͞͞Ϸċťϟ a"ϟĖĲϟťēôϟťæČ ͒ϟ͗͒͒ϱĖĲϙI"ϙϼ"ŘĖċťϙĺċϙæĺťēϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙťæČϙÍĲîϙX@ϱ͑ϙ @[aϽϙϙbi(ϡϙϙ@[aŜϟÍŘôϟĖĲèĺŘŘôèťīƅϟīĖŜťôîϟÍŜϟ XaaϟſēôĲϟťēôƅϟÍŘôϟX@Ϸ͗ϟÍèèĺŘîĖĲČϟťĺϟťæČϟ ťÍīīƅϟċŘĺıϟ"ĺƅĺĲϟ͖͛ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙϱ͏͐ϙſÍŜϙĖĲĖťĖÍīīƅϙîŘĖīīôîϙÍĲîϙèĺıŕīôťôîϙĖĲϙ͐͗͑͘ϟϙϙċťôŘϙĖĲĖťĖÍīϙ"ŘĖīīϙťôıϙôŜťϙôŽÍīŪÍťĖĺĲϠϙťēôϙſôīīϙſÍŜϙ ŜŪŜŕôĲîôîϙŪĲťĖīϙĖťϙſÍŜϙæŘĺŪČēťϙĺĲϙÍŜϙÍϙŜĖĲČīôϱŜôīôèťĖŽôϙČÍŜϙīĖċťôîϙŕŘĺîŪèôŘϙċĺŘıϙťēôϙaĖîîīôϙÍĲîϙ[ĺſôŘϙ XŪŕÍŘŪħϙĖĲϙ͔͐͗͘ϟϙϙēôϙſôīīϙſÍŜϙŜēŪťϱĖĲϙċŘĺıϙ͖͐͗͘ϙťĺϙ͐͗͘͘ϙÍīĺĲČϙſĖťēϙťēôϙŘôŜťϙĺċϙaϟϙϙIťϙſÍŜϙæŘĺŪČēťϙæÍèħϙ ĺĲϙĖĲϙ͐͗͘͘ϙÍŜϙÍϙČÍŜϙīĖċťϙŕŘĺîŪèôŘϙŪĲťĖīϠϙĖĲϙ"ôèôıæôŘϙ͓͐͘͘ϠϙbÍæĺŘŜϙ͓(ϙŕôŘċĺŘıôîϙÍĲϙÍæÍĲîĺĲıôĲťϙĺċϙťēôϙ ĺŘĖČĖĲÍīϙèĺıŕīôťĖĺĲϙÍĲîϙŘôϱèĺıŕīôťôîϯŜťĖıŪīÍťôîϙťēôϙſôīīϙĖĲϙťēôϙXŪŕÍŘŪħϙϯϙŜÍĲîŜϟϙϙĲϙ(ϙèĺıŕīôťĖĺĲϙ ſÍŜϙŘŪĲϙÍĲîϙťēôϙſôīīϙēÍîϙıŪīťĖŕīôϙ(ϙèēÍĲČôĺŪťŜϙŪĲťĖīϙÍϙϱ(ϙſÍŜϙŘŪĲϙĖĲϙťēôϙſôīīϙæƅϙ"ĺƅĺĲϙ͕͐ϙĖĲϙ͑͏͐͒ϟϙϙ ĖĲèôϙťēôĲϠϙťēôϙ(ϙıĺťĺŘϙēÍŜϙæôôĲϙĺĲīĖĲôϙſĖťēϙťēôϙťēŘŪϱťŪæĖĲČϙŕŪıŕŜϙæôĖĲČϙèēÍĲČôîϙĺŪťϙÍŜϙŘôŗŪĖŘôîϟϙϙIĲϙ bĺŽôıæôŘϙ͑͏͓͑ϙťēôϙ(ϙıĺťĺŘϙČŘĺŪĲîôîϙĺŪťϙÍĲîϙťēôϙſôīīϙēÍŜϙæôôĲϙŜēŪťϱĖĲϙŜĖĲèôϟ bĺťôŜϙôČÍŘîĖĲČϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -Iϙ>[ϙЬϙ͔͔͔͑ϱċťϙa"ϙϯϙæČϙ>[ϙЬϙ͑͘͏͔ϱċťϙa"ϙϼ͓͐ϙbĺŽϙ͑͏͓͑Ͻ -bĺϙ>ϙĖĲϙſôīī ®ôīīϡ aϙϱ͏͐ "ϡ ͐͗͐ϱ͓͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͏͕͕͒ϱ͏͏ϱ͏͏ "Íťôϡ ͏͗ϙVÍĲϙ͑͏͔͑ iæĤôèťĖŽôϡ ®ĖťēϙťēĖŜϙŕŕīĖèÍťĖĺĲϙċĺŘϙŪĲîŘƅϙŕŕŘĺŽÍīϙſôϙÍŘôϙŘôŗŪôŜťĖĲČϙťĺϙŕŪťϙϙϭ͐ϙĺĲϙťēĖŜϙſôīīϙĖĲϙĺŘîôŘϙťĺϙŜſÍŕϙťēôϙ (ϙĖĲϙĺŘîôŘϙťĺϙæŘĖĲČϙťēĖŜϙſôīīϙæÍèħϙĺĲϙŕŘĺîŪèťĖĺĲϟϙϙIĲϙÍîîĖťĖĺĲϠϙſēĖīôϙťēôϙôƄĖŜťĖĲČϙèĺıŕīôťĖĺĲϙĖŜϙĺŪťϙĺċϙťēôϙ ſÍƅϙſôϙſĺŪīîϙīĖħôϙťĺϙÍîîϙŜĺıôϙŕôŘċĺŘÍťĖĺĲŜϙĖĲťĺϙťēôϙXŪŕÍŘŪħϙϱĖīťϟ ēĖŜϙŕŘĺèôîŪŘôϙîôťÍĖīŜϙťēôϙæôīĺſϙĺŪťīĖĲôϙĺċϙťēôϙŜèĺŕôϙĺċϙťēĖŜϙŕŘĺĤôèťϡ -Ūīīϙϱ(ϙϼŘôϱĖČϽ -ŪīīϙôƄĖŜťĖĲČϙ(ϙèĺıŕīôťĖĺĲ -îîϙŕôŘċĺŘÍťĖĺĲŜϙĖĲϙťēôϙXŪŕÍŘŪħϙϱĖīť -ŪĲϙĲôſϙèĺĲŽôĲťĖĺĲÍīϙ(ϙèĺıŕīôťĖĺĲ -i ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ ͐Ͻ īĖèħīĖĲô ÍϽ Ūīīϙ"Э"ϙæČϙťĺŕ æϽ Ūīīϙ"Э"ϙÍèħĺƯϙŜŜƅ èϽ Ūīīϙϱ(ϙϼƄ͑Ͻ ͑Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ īôôîϙťæČϯIϙťĺϙ͏ϙŕŜĖϟϙϙĺĲƱŘıϙĲĺϙƲĺſϟ bi(ϡϙϙIċϙŘôŗЍîϠϙèÍīīϙĺŪťϙ>ŪīīæĺŘôϙťĺϙæŪīīēôÍîϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙťĺϙħĖīīϙſôīī æϽ ēĺĺťϙťæČϙÍĲîϙIϙ>[ èϽ īôÍŘϙÍĲîϙīôŽôīϙŕÍîϙÍŘôÍϙĖĲϙċŘĺĲťϙĺċϙſôīīϟϙϙŕĺťϙŘĖČϙıÍťŜϠϙ͔͏͏ϙææīϙťÍĲħϠϙÍĲîϙèĺĲťÍĖĲıôĲťϟ îϽ "ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜϟϙϙīôÍŘϙÍĲîϙīôŽôīϙÍŘôÍϙÍŘĺŪĲîϙſôīīϟ ôϽ aIϙèŘÍĲôϟϙϙôťϙ«ϟϙϙb"ϙťŘôôϙÍĲîϙbϙ͐͐Ћϙi(ϟϙϙbϙi(ϙēĺŪŜôϟϙϙŕĺťϙıŪîϙæĺÍťϟ bi(ϡϙϙ«ϙŕŘĺƱīôϙĖŜϙ͓ЋϙI®ϙFϱŜťƅīô ®iϙŘĺèôîŪŘôϙϼŪĲîŘĖôîϙ®ĺŘħϽϡ aIϙϯϙôŜťϙi(ϡ ͐Ͻ aIϙFĖīèĺŘŕϙϠϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲťϠϙÍĲîϙīĖĲôŜϙťĺϙ͔͏͏ϙææīϙŘôťŪŘĲϙťÍĲħ ͑Ͻ ēôèħϙċĺŘϙŕŘôŜŜŪŘôϙÍĲîϙĖċϙ͏ϙŕŜĖϠϙŜôťϙϙŕīŪČϟϙϙIċϙĲôôîôîϠϙæīôôîϙÍĲƅϙŘôŜĖîŪÍīϙŕŘôŜŜŪŘôϙĺƯϙťæČϙÍĲîϙ èŜČϟϙϙŪīīēôÍîϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙîĺſĲϙťæČϙϼѷ͐͏͏ϙææīŜϽϙÍĲîϙIϙϼѷ͖͔͒ϙææīŜϽϙŕŘĖĺŘϙťĺϙŜôťťĖĲČϙϙ ĖĲϙĺŘîôŘϙťĺϙèīôÍĲŪŕϙťæČϟ bi(ϡϙϙ>īŪĖîϙīôŽôīϙŜēĺťϙĺĲϙ͓͐ϙbĺŽϙ͑͏͓͑ϙĖĲîĖèÍťôŜϙIϙ>[ϙЬϙ͔͔͔͑ϱċťϙa"ϙϯϙæČϙ>[ϙЬϙ͑͘͏͔ϱċťϙa" ͒Ͻ ôŜťϙi(ϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϠϙÍĲĲŪīÍŘϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϙϼēĺīîϙôÍèēϙ ŘÍıϯŽÍīŽôϙċĺŘϙ͔ϱıĖĲϽϟϙϙôèĺŘîϙÍèèŪıŪīÍťĺŘϙŕŘôϱèēÍŘČôϙŕŘôŜŜŪŘôŜϙÍĲîϙèēÍŘťϙťôŜťŜϟ ÍϽ bĺťĖċƅϙi@ϙ͓͑ϱēŘŜϙĖĲϙÍîŽÍĲèôϙĺċϙi(ϙťôŜťĖĲČ æϽ ĺĲƱŘıϙťôŜťϙŕŘôŜŜŪŘôϙŕôŘϙťēôϙŪĲîŘƅϙĺĲîĖťĖĺĲŜϙĺċϙŕŕŘĺŽÍī èϽ ôŘċĺŘıϙťôŜťŜϙÍŜϙŕôŘϙϙ͐ϙi(ϙôŜťϙŘĺèôîŪŘô îϽ ôŜťϙ«ŜϙĺĲϙ͓ϱΫЋϙϼôƄĖŜťĖĲČϙèĺıŕīôťĖĺĲϽϙÍĲîϙ͑ϱ͖ϯ͗ЋϙϼĲôſϙèĺıŕīôťĖĺĲϽϙťôŜťϙĤťŜ ôϽ ŪæıĖťϙèĺıŕīôťôîϙ͐͏ϱ͓͓͑ϙċĺŘıϙťĺϙi@ϙſĖťēĖĲϙϼ͔ϽϙîÍƅŜϙĺċϙi(ϙťôŜť ®ôīīϡ aϙϱ͏͐ "ϡ ͐͗͐ϱ͓͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͏͕͕͒ϱ͏͏ϱ͏͏ "Íťôϡ ͏͗ϙVÍĲϙ͑͏͔͑ ͓Ͻ ŪīīϙϙīŪČϟϙϙīôôîϙÍĲƅϙŕŘôŜŜŪŘôϙĺƯϙťæČϯIϙťĺϙťēôϙŘôťŪŘĲŜϙťÍĲħϟϙϙIċϙŘôŗЍîϠϙæŪīīēôÍîϙÍîîĖťĖĺĲÍīϙ͗ϟ͔ϙ īæϯČÍīϙŜĺŪŘèôϙſťŘϟϙϙŪīīϙ«ϟϙϙ[ŪæŘĖèÍťôϙĖċϙŕŘôŜŜŪŘôϙĖŜϙôƄŕôèťôîϟ Ūīīϙ(ƄĖŜťĖĲČϙĺıŕīôťĖĺĲϡ ͔Ͻ aIϙ(ϙÍæīôϙŜŕĺĺīôŘϙťĺϙŕŪīīϙϭ͐ϙ([>ϙƲÍťϙèÍæīôϙ ͕Ͻ aϙīÍĲîĖĲČϙĤťϙĺŘϙŜŕôÍŘϙťæČϙēČŘϟϙϙi["ϟϙϙĲīÍĲîϙťæČϙēČŘϟ bi(ϡϙϙ"ĺƅĺĲϙ͕͐ϙĲĺťôîϙ®ϙĺċϙ͔͐͑XϙīæŜϙÍĲîϙi®ϙĺċϙ͐͒͒XϙīæŜϙſĖťēϙÍĲϙĖĲèīŪîôîϙĺŕϙ"ŘĖŽôϙ®ťϙĺċϙ ͓͏XϙīæŜ ͖Ͻ ĺĲƱŘıϙťæČϙēČŘϙċŘôôϟϙϙôèĺŽôŘϙťæČϙēČŘϟ ͗Ͻ iiFϙīÍƅĖĲČϙîĺſĲϙťēôϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙIϱaϙťæČϠϙ(ϙèĺıŕĺĲôĲťŜϠϙÍĲîϙŜŕĺĺīĖĲČϙ(ϙƲÍťϙèÍæīô bi(ϡϙϙϱ(ϙŕŪıŕŜϙϼ͑ϙƄϙѷ͑͏ϱċťϯôÍϽϙŜēĺŪīîϙēÍŽôϙæôôĲϙŕŪīīôîϙŽĖÍϙŜīĖèħīĖĲôϙæôċĺŘôϙťēôϙŘĖČŜϙ ÍŘŘĖŽÍīϙæŪťϙĖċϙťēĺŜôϙôƯĺŘťŜϙÍŘôϙŪĲŜŪèèôŜŜċŪīϠϙŕīÍĲϙĺĲϙîĖŜèŪŜŜĖĲČϙīÍƅϙîĺſĲϙŕŘĺèôîŪŘôŜϙċĺŘϙťēôϙ(ϙ ÍŜŜƅϙſϯϙi(ϟϙϙēĖŜϙ(ϙÍŜŜƅϙÍīŜĺϙēÍŜϙÍϙŜēŘĺŪîϙæĺīťôîϙĺĲϙĤŪŜťϙÍæĺŽôϙťēôϙϙ"ŘĖīīôîϙæČϙ³ϱĺŽôŘϟϙϙ[Íƅϙ îĺſĲϙŕŘĺèôîŪŘôŜϙċĺŘϙťēôŜôϙèĺıŕĺĲôĲťŜϙſĖīīϙÍīŜĺϙĲôôîϙťĺϙæôϙîĖŜèŪŜŜôîϙſϯϙi(ϟ (ŗŕťϙ"ĖŜŕĺŜĖťĖĺĲϡ æČϙFČŘ IĲŜŕôèťϙÍĲîϙôϱŪŜô ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙIϱaϙƄϙFƅîϙ͔͑͐ϙϼϙƄϙϽϙŕŪŕϙæôīĺſϙ ťæČϙēČŘ VŪĲħ ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙIϱaϙťæČ VŪĲħ ϼ͑ϽϙÍıèĺϙX@ϱ͑ϙ@[a VŪĲħ ϼ͖͕͐ϽϙŘĺŜŜϙĺīīÍŘϙÍĲĲĺĲϙīÍıŕŜ IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ ϼ͒ϽϙŘĺťôèťĺīĖƏôŘϙīÍıŕŜ IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ (ϙaĺťĺŘϙēŘĺŪî VŪĲħ ϙ"ŘĖīīôîϙæČϙ³i VŪĲħ ÍĲîôıϙôÍīŜ VŪĲħ (ϙaĺťĺŘ VŪĲħ ®ôīī[I>ϙôĲŜĺŘ VŪĲħ ôĲťŘÍīĖƏôŘ VŪĲħ (ϙēŘĺŪîϙIĲċĺŘıÍťĖĺĲϡ (ϙĖĲŜĖîôϙĺċϙēŘĺŪîϙѱϙ͒͘ϟ͕͏ϱċť ēŘĺŪîϙôèťĖĺĲŜϙÍŘôϙ͓͐ϟ͕͘ϱċťϙÍĲîϙ͒͏ϟ͔͗ϱċťϙſϯϙi[ϙѱϙ͓͔ϟ͔͓ϱċť i"ϙĺċϙēŘĺŪîϙĺīīÍŘϙĖŜϙīĖŜťôîϙÍťϙ͖ϱ͔ϯ͗ЋϙĺĲϙťēôϙťæČϙťÍīīƅϙæŪťϙÍħôŘϙôĲťŘĖīĖċťϙîŘÍſĖĲČŜϙĖĲîĖèÍťôϙĖťϙĖŜϙ ͖ϟ͏͏͏ϱĖĲϙi"ϟ ťıϙĺċϙ(ϙôĲťŘÍīĖƏôŘϙĖŜϙ͔ϟ͓͘ϱċťϙŪŕϙĖĲŜĖîôϙæťıϙĺċϙēŘĺŪî ôŜťϙŜČϙϼ͗ϱƅŘϙŘĺîϙŜČϙôŜťϙŕôŘϙi@ϙiϙ͒͘͏Ͻϡ ͘Ͻ aϙÍĲîϙIFϙſϯϙèŘÍŕôŘϯϱĺŪťϙFϡ ÍϽ ôŽôŘŜôϙèĖŘèŪīÍťĖĲČϙĤŪĲħϙıĖīī ®ôīīϡ aϙϱ͏͐ "ϡ ͐͗͐ϱ͓͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͏͕͕͒ϱ͏͏ϱ͏͏ "Íťôϡ ͏͗ϙVÍĲϙ͑͏͔͑ æϽ ͘ϱ͔ϯ͗ЋϙèŜČϙŜèŘÍŕôŘ èϽ ͘ϱ͔ϯ͗ЋϙťôŜťϙŕħŘ îϽ ϼƄ͑Ͻϙ͖ϱĖĲϙĺĺťϙÍŜħôť ôϽ ͒ϱΫЋϙb͒͐ϙſĺŘħŜťŘĖĲČϙťĺϙŜŪŘċÍèôϙÍŜϙŘôŗЍî ͐͏Ͻ IFϙťĺϙ͕͘͏͏ϱċťϙa"ϟϙϙĖŘèŪīÍťôϙƄ͐ϙϙťēôϙīĺĲČϙſÍƅϙÍťϙıÍƄϙŘÍťôϟ ͐͐Ͻ ôťϙťôŜťϙŕħŘϟϙϙĖŘèŪīÍťôϙæÍèħŜĖîôϙċŪīīϙſϯϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙÍèŘĺŜŜϙťēôϙťĺŕϙĖċϙĲôèôŜŜÍŘƅϙťĺϙƲŪĖîϙ ŕÍèħϙſĺŘħŜťŘĖĲČϙƄϙIϙÍĲĲŪīŪŜϟϙϙôŜťϙ͘ϱ͔ϯ͗ЋϠϙ͓͖ϭϙ[ϱ͗͏ϙèŜČϙťĺϙ͐͗͏͏ϙŕŜĖϙϼ͒͏ϙıĖĲϙèēÍŘťôîϽ bi(ϡϙϙ͘ϱ͔ϯ͗ЋϙťôŜťϙŕħŘϙÍťϙ͕͘͏͏ϱċťϙa"ϙϼ͕͗͘͏ϱċťϙ«"Ͻϟϙϙ͕͗͘͏ϱċťϙ«"ϙƄϙ͏ϟ͔͑ϙŕŜĖϙѱϙ͖͐͑͒ϙŕŜĖϙϼaĖĲϙŘôŗЍîϽ ͐͑Ͻ ŕĺĲϙèĺıŕīôťĖĺĲϙĺċϙŜŪèèôŜŜċŪīϙťôŜťϠϙæīôôîϙĺƯϙťôŜťϙŕŘôŜŜŪŘôϙċŘĺıϙſĺŘħŜťŘĖĲČϙƄϙŕŘĺîϙèŜČϙÍĲĲŪīŪŜϟϙϙ ôīôÍŜôϙťôŜťϙŕħŘϙÍĲîϙiiFϙīÍƅĖĲČϙîĺſĲϙſĺŘħŜťŘĖĲČϟ ͐͒Ͻ īôÍĲϙÍĲîϙèīôÍŘϙŘĖČϙƲĺĺŘϙċĺŘϙ(ϱ[ĖĲôϙĺŕŜ (ϱ[ĖĲôϙîîϙôŘċϙϼXŪŕÍŘŪħϙϱĖīťϽ ͓͐Ͻ aIϯŕĺťϙ(ϱ[ĖĲôϙťŘŪèħ ͔͐Ͻ aϙēĺĺťĖĲČϙ>īÍĲČôϙĺĲϙťĺŕϙĺċϙĲĲŪīÍŘ ͕͐Ͻ ϙ(ϱ[ĖĲôϙſϯϙÍŕŕŘĺŕŘĖÍťôϙŘĖČϙ(ϙſĖťēϙſôīīϙŜôèŪŘôîϙÍŜϙÍŕŕŘĺŕŘĖÍťôϟϙϙôŜťϙ(ϙťĺϙ͔͑͏ϯ͔͑͏͏ϙŕŜĖϟϙϙ ͖͐Ͻ aϙôŘċϙ@ŪĲŜϙĖĲťĺϙ(ϱ[ĖĲôϙīŪæŘĖèÍťĺŘϙÍĲîϙēĺĖŜťϙťĺϙŘĖČϙƲĺĺŘϟϙϙôŜťϙæŘôÍħϙ͔͑͏ϯ͔͑͏͏ϙŕŜĖϟ ͐͗Ͻ iŕôĲϙſôīīϙÍĲîϙIFϙťĺϙŕôŘċϙ͘ϱ͔ϯ͗ЋϠϙ͓͖ϭϙ[͗͏ϙèŜČϙÍèèĺŘîĖĲČϙťĺϙæôīĺſϙîîϙôŘċϙŘĺŕĺŜÍīϡ bi(ϡϙϙĺĲťÍèťϙaϙ@ôĺīĺČĖŜťϙ®ĖīīϙbôôīƅϙċĺŘϙĖôϱIĲϙ[ĺČϙÍĲîϙôŘċϙ"ôŕťēϙĺĲƱŘıÍťĖĺĲ ®Ėīīϙbôôīƅ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͏͗͑ϙϼiϽ ϼ͘͏͒Ͻϙ͗͑͐ϙϳϙ͖͓͐͐ϙϼϽ ͐͘Ͻ iiFϠϙıĺĲĖťĺŘϙſôīīϙċĺŘϙƲĺſϟϙϙŪīīēôÍîϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙÍŜϙŘôŗЍîϟϙϙŘôÍħϙÍťϙŘĖČϙƲĺĺŘϙÍĲîϙ"ϙ ČŪĲŜϟ ͑͏Ͻ ôŕôÍťϙťôŕŜϙ͖͐ϙϳϙ͐͘ϙŪĲťĖīϙÍīīϙŘôŗŪôŜťôîϙîîϙôŘċŜϙēÍŽôϙæôôĲϙŜēĺť ͑͐Ͻ ŕĺĲϙèĺıŕīôťĖĺĲϙĺċϙŜŪèèôŜŜċŪīϙČŪĲϙŘŪĲŜϠϙıĺĲĖťĺŘϙſôīīϙċĺŘϙƲĺſϟϙϙŪīīēôÍîϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙ ÍŜϙŘôŗЍîϟ ͑͑Ͻ "ϙŘĖČϙ(ϙÍĲîϙ"aiϙ(ϱ[ĖĲôϙťŘŪèħ ͑ϱ͖ϯ͗Ћϙ(ϙĺıŕīôťĖĺĲϡ ͑͒Ͻ īôÍĲϙÍĲîϙèīôÍŘϙŘĖČϙƲĺĺŘϙċĺŘϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗Řîϙ(ϙèĺıŕīôťĖĺĲϙŘŪĲ ͓͑Ͻ ϙÍĲîϙaϙĲôſϙ(ϙÍŜŜƅϡ ÍϽ aĺťĺŘϙôĲťŘÍīĖƏôŘϙϳϙÍŘČôťϙŜôťϙîôŕťēϙÍťϙ͕͗͏͏ϱċťϙa" æϽ ¾ôĲĖťēϙ(͖ϙ@ÍŪČô èϽ ͔͕͑³ϙ(ŜŕϙaťŘ îϽ [ĺſôŘϙôÍī ôϽ ŕŕôŘϙôÍī ċϽ IĲťÍħô ŘĺŕĺŜôîϙôŘċĺŘÍťĖĺĲŜ ®ôīī >ĺŘıÍťĖĺĲ ĺŕϙēĺťϙϼa"Ͻ ÍŜôϙēĺťϙϼa"Ͻ IĲťôŘŽÍīϙϼċťϽ aϱ͏͐ XϙϱŜĖīťŜ ͕Ϡ͖͘͏Д ͖Ϡ͏͔͐Д ͓͔Д aϱ͏͐XϙϱŜĖīťŜ ͖Ϡ͏͔͑Д ͖Ϡ͏͕͏Д ͔͒Д ®ôīīϡ aϙϱ͏͐ "ϡ ͐͗͐ϱ͓͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͏͕͕͒ϱ͏͏ϱ͏͏ "Íťôϡ ͏͗ϙVÍĲϙ͑͏͔͑ bi(ϡϙϙ(ϙſĖīīϙēÍŽôϙÍϙ͖ЋϙŜēŘĺŪîϙťēÍťϙſĖīīϙŘŪĲϙċŘĺıϙæôīĺſϙťēôϙ@ÍŜϙôŕÍŘÍťĺŘϙťĺϙťēôϙôĲťŘÍīĖƏôŘϙťĺϙ ÍŜŜĖŜťϙèĺĺīĖĲČϙťēôϙ(ϙıĺťĺŘŜϙæƅϙĖĲèŘôÍŜĖĲČϙťēôϙƲŪĖîϙŽôīĺèĖťƅϙÍèŘĺŜŜϙťēôıϙ ČϽ @ÍŜϙôŕÍŘÍťĺŘ ēϽ îÍŕťôŘ ĖϽ ͓͏͏ϙ(ϙŕŪıŕŜ ĤϽ ĺŘťôîϙ"ĖŜèēÍŘČôϙFôÍî ħϽ ĺīťϱĺĲϙ"ĖŜèēÍŘČôϙēôÍîϙſϯϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗ŘîϙæĺƄϙŪŕ īϽ ϼ͑ϽϙĤťŜϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗ŘîϙťæČ ıϽ ϼ͐Ͻϙ͑ϱ͖ϯ͗Ћϙ[͗͏ϙ͑ϟ͒͐͒Ћϯ͑ϟ͑͏͔Ћϙ³bϙbĖŕŕīôϙſϯϙ͐͏ϱċťϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗ŘîϙēÍĲîīĖĲČϙŕŪŕŜ ĲϽ ϼ͐ϽϙĤťϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗Řî ĺϽ ϼ͐Ͻϙ@[aϙ͑ϱ͖ϯ͗Ћϙ[͗͏ϙ((ϙ͗ŘîϙƄϙϼſϯϙ"«ϙĖĲŜťÍīīôîϽϙÍĲîϙ͐͏ϱċťϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗ŘîϙēÍĲîīĖĲČϙ ŕŪŕŜ ŕϽ ³³³ϙĤťŜϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗ŘîϙťæČ ŗϽ ϼ͐Ͻϙ@[aϙ͑ϱ͖ϯ͗Ћϙ[͗͏ϙ((ϙ͗ŘîϙƄϙϼſϯϙ"ϱi«ϙĖĲŜťÍīīôîϽϙÍĲîϙ͐͏ϱċťϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗Řîϙ ēÍĲîīĖĲČϙŕŪŕŜϙϳϙÍŘČôťϙŜôťϙîôŕťēϙÍťϙ͔͐͏ϱċťϙa" ŘϽ ³ϙĤťŜϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗ŘîϙťæČ ŜϽ ³ϱĺŽôŘϙťĺϙæČϙFČŘϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗ŘîϙϼĖĲϽϙƄϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙôĲÍŘĖŜϙFƅîŘĖīϙ®ôîČôϙ͔͑͐ϙϼĺƄϽ ͔͑Ͻ ϙÍĲîϙaϙťēôϙ͓ϱΫЋϙťæČϙēČŘϟϙϙaÍħôϙƱĲÍīϙŜŕīĖèôϙĺċϙťēôϙ(ϙèÍæīôϙťĺϙťēôϙŕôĲôťŘÍťĺŘϠϙaϙèĺĲťŘĺīϙ īĖĲôϙťĺϙťēôϙťæČϙēČŘϙÍĲîϙîŪııƅϙĺƯϙÍĲƅϙÍîîĖťĖĺĲÍīϙèĺĲťŘĺīϙīĖĲôϙŕĺŘťŜϙĖċϙĲôèôŜŜÍŘƅϟ bi(ϡϙϙŜôϙèÍŪťĖĺĲϙſēôĲϙīÍĲîĖĲČϙťēôϙťæČϙēČŘϙŜĺϙÍŜϙťĺϙÍŽĺĖîϙîÍıÍČĖĲČϙťēôϙ(ϙèÍæīôϙĺŘϙŕôĲôťŘÍťĺŘϟ ͕͑Ͻ I["ϟϙϙôèĺŘîϙ®ϙÍĲîϙi®ϙĺĲϙťæČϙťÍīīƅϟ ͖͑Ͻ ôťϙ«ϟϙϙb"ϙi(ϟϙϙôťϙϙīŪČϟ ͑͗Ͻ bϙ͓ϱ͐ϯ͕͐Ћϙ͔aϙťŘôô ͑͘Ͻ ϙťæČϙēČŘϙŽĺĖîϙťĺϙ͔͏͏ϯ͔͏͏͏ϙŕŜĖϟϙϙϙťŘôôϙ͔͏͏ϯ͔͏͏͏ϙŕŜĖϟ ͒͏Ͻ ŪīīϙϙŕīŪČϙÍĲîϙ« ͒͐Ͻ ôŕīÍèôϙČÍŪČôŜϟϙϙôèŪŘôϙťŘôôϙÍĲîϙèôīīÍŘϟ ͒͑Ͻ "aiϙ ĺŜťϱĖČϙŘĺèôîŪŘôϡ ͐Ͻ ŪŘĲϙſôīīϙĺŽôŘϙťĺϙiŕŜϙŽĖÍϙēÍĲîĺŽôŘϙċĺŘı ͑Ͻ ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜ ͒Ͻ iϙŕôŘϙÍħôŘϙôĲťŘĖīĖċťϙťÍŘťŪŕϙŘĺèôîŪŘô ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè ͒Ͻ i(ϙèēôıÍťĖè REF LOG: 2/23/82 CBL, 2/5/82 DIL 12/94 Perforation summary squeezed open open squeezed squeezed open 9134' - 9143' 8904' - 8934' 7142' - 7167' 7120' - 7133' 7109' - 7111' 6970' 6959' - 6968' 12 12 12 12 12 4 4 4" 4" 4" 4" 4" 4" 4" Size SPF Interval open / sqz’d Original perforation summary the centralizer (46’ long, including the shroud head) 7” 26# L-80 shroud extends from the seperator intake to 8.43‘ below Centrilift WellLift MGU w/ Centrilift Motor KMHG/114 2330 V / 30 Amp Centrilift Tandem Seal Section TTC Drilled Tubing XO Centrilift TTC-ESP Top Top Pump 20.5', Btm Pump 20.5' D&D Packoff Assy Top w/ Kobe Knockout D&D Tubing Stop 9-5/8" 47 ppf, L-80, Btrs. casing (cap. = 0.0732 bpf, drift ID = 8.525”) 4 1/2”, 12.6 ppf, L-80, IBT-M tubing (cap. = 0.0152 bpf, drift = 3.833”) (cap w/ 4 1/2" Tbg inside = 0.0536 bpf) sidepocket KBMM GLM Camco 4 1/2" x 1" 9 5/8" cement divert valve @ 2219'MD 166'sidepocket KBMM GLM Camco 4 1/2" x 1" Orig. GL. Elev. = 28' 2338' md13-5/8", 72 ppf, L-80 btrs. max. hole angle = 7 deg KOP = none 110'20" 94 ppf H-40 btrs. w/4.5“ FMC tubing hanger, Hyd 521 top and btm. thrds. 4” CIW BPV WELLHEAD: 13-5/8“ 5M FMC TREE: 4 1/16“ - 5M, Cameron Tree Orig. KB. Elev. = 48' (Nabors 17)MPU C-01 4/25/09 REH ESP Changeout - Nabors 3S 12/15/04 JRC ESP Changeout 4-ES (w/ shroud) DATE REV. BY COMMENTS MILNE POINT UNIT WELL C-01 API NO: 50-029-20663 HILCORP ALASKA LLC 9-5/8" 47 ppf, L-80, Btrs.9,802' md 9 5/8” EZSV Retainer 9,075' md 9,185' md FISH: Milled out Otis "WD" pkr. w/: seal bore extension, 6 1/8" X 3 1/2" x.o., two 3.5" pup joints, Otis ‘X’ and ‘XN’ npls. overall length = 23' DBR3/18/82 Initial completionDBR12/17/94 RWO 9 5/8” EZSV Retainer 95/8”EZSVRetainer 09/08/98 JBF ESP Changeout by Nabors 4ES 10/22/00 MDO ESP Changeout / add Shroud 4-es02/12/01 BMH ESP Changeout 4-ES (w/ shroud) squeezed FISH: Junk basket / gauge ring 8,852' md 3-3/8" 6 7142' - 7167' 3-3/8" 6 7120' - 7133' 6959' - 6968'63-3/8" open open open FISH: 9' toolstring w/ 1-10' 0.092 slickline 9 5/8" Baker N-1 bridge plug, set 12/94 7287' md FISH: Milled out Otis 9 5/8" WD pkr, 4'-3.5" pup, 3.5" Otis ‘X’ npl, 5'-3.5" pup, 3.5" ‘XN’, 3.5" WLEG. Top is at 7423 MD. Ref. 12/94 RWO Size SPF Interval open / sqz’d centralizer 6,497‘ 6,780’ 6,767’ 6,753‘ 6,743’ 10/10/09 REH ESP Changeout - Nabors 4ES01/06/13 B. Bixby ESP Changeout TTC ESP Doyon 16 05/17/13 Pump eye C/O to new modified versionB.Kruskie11/09/13 B. Kruskie Pulled ESP Braided Line 6,707' 6,701' 6,699' 12/24/13 B. Bixby Installed TTC ESP With Slickline _____________________________________________________________________________________ Created By: TDF 1/9/2025 PROPOSED Milne Point Unit Well: MPU C-01 Last Completed: 1/5/2013 PTD: 181-143 TD =10,442 (MD) / TD =10,430’(TVD) 20” Multiple Fish, Review History Orig. KB Elev.: 46/ GL Elev.:17.4’ (N22E) RT to 7” Hgr = 30.12’ (N 22E) 2 3 12 &13 14 9 9-5/8” 1 MIN ID= 2.250” @ ±X,XXX’ PBTD =7,287’ (MD) / PBTD = 7,277’(TVD) 6, 7, 8 & 9 4& 5 10 & 11 15 13-3/8” 16 17 18 19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / BTRS 19.124 Surface 110' 0.3553 13-3/8" Surface 72 / L-80 / BTRC 12.347 Surface 2,338’ 0.1481 9-5/8" Production 47 / L-80 / BTRC 8.681 Surface 9,802’ 0.0732 TUBING DETAIL 2-7/8”" Tubing 6.4 / L-80 / EUE 8rd 2.441 Surface ±6,700’ 0.0058 JEWELRY DETAIL No Depth Item 1 ±150’ST 2: 4-1/2” GLM w/ DP-OV Installed 2 ±X,XXX’ST 1: GLM w/ DP Installed 3 ±X,XXX’ 2-7/8” XN-Nipple 2.313 ID packing bore (2.25” No-go ID) 4 ±X,XXX’ Bolt-on Discharge head: 5 ±X,XXX’ Ported Discharge Head: 6 ±X,XXX’ Pump #4: 7 ±X,XXX’ Pump #3: 8 ±X,XXX’ Pump #2: 9 ±X,XXX’ Pump #1: 10 ±X,XXX’ Gas Separator: 11 ±X,XXX’ Intake: 12 ±X,XXX’ Upper Tandem Seal : 13 ±X,XXX’ Lower Tandem Seal : 14 ±X,XXX’ Motor: 15 ±X,XXX’ Sensor & Centralizer: Bottom @ ±6,700’ 16 7,287’ 9-5/8” Baker N-1 Bridge Plug 17 8,852’ 9-5/8” EZSV Retainer 18 9,075’ 9-5/8” EZSV Retainer 19 9,185’ 9-5/8” EZSV Retainer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status KUPARUK 6,959’ 6,968’ 6,950’ 6,958’ 9 3-3/8” 12/94 Open 6,959’ 6,968’ 6,950’ 6,958’ 9 4” 3/9/82 Open 6,970’ - 6,960’ - 1 4” 3/8/82 SQZ’d ±6,970’ ±7,015’ 6,960’ 7,005’ 45 TBD Future Future ±7,025’ ±7,060’ 7,010 7,050’ 35 TBD Future Future 7,109’ 7,111’ 7,099’ 7,101’ 2 4” 3/1/82 SQZ’d 7,120’ 7,133’ 7,110’ 7,123’ 13 3-3/8” 12/94 Open 7,120’ 7,133’ 7,110’ 7,123’ 13 4” 3/4/82 Open 7,142’ 7,167’ 7,132’ 7,157’ 25 3-3/8” 12/94 Open 7,142’ 7,167’ 7,132’ 7,157’ 25 4” 3/4/82 Open 8,904’ 8,934’ 8,893’ 8,923’ 30 4” 2/27/82 SQZ’d 9,134’ 9,143’ 9,123’ 9,132’ 9 4” 2/24/82 SQZ’d Ref Log: 2/23/86 CBL, 2/5/82 DIL –2-1/2” OPEN HOLE / CEMENT DETAIL 20" Cement to Surface in a 26” Hole 13-3/8" 3,800 sx Arctic Set II in a 17-1/2” Hole 9-5/8"2,000 sx Class ‘G’, 150 sx Arctic Set I & 200 bbl Arctic Pack in a 12-1/4” Hole WELL INCLINATION DETAIL KOP @ N/A Max Hole Angle = 7 Deg. TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 13-5/8” 5M FMC w/ 4.5” FMC Tbg. Hngr., Hyd. 521 Top & Btm thrds 4” CIW BPV GENERAL WELL INFO API: 50-029-20663-00-00 Drilled, Cased and Completed by Nabors 17- 3/18/82 Set BP, ESP Swap and Perf by Nabors 4ES – 12/18/94 ESP Swap Nabors 4ES –9/7/98, 10/16/00, 2/11/01, 12/14/04 ESP Swap Nabors 3S – 4/25/09 & By Nabors 4ES- 10/9/09 ESP Swap Doyon 16 – 1/6/13 Installed TTC ESP w/ Slickline – 12/24/13 Milne Point ASR Rig 1 BOPE 2025 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 Blin d11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION CISSION REPORT OF SUNDRY WELL OPERATIONS JAN 3 1 2013 1. Operations Performed: AOGGC ❑ Abando ❑ Repair ❑ Plug ❑ Perforat ❑ Re -Enter Suspended ❑ Alter Casing ® Pull ❑ Stimulate - ❑ Waive El Othe Change out ESP ❑ Change Approved ❑ Operation ❑ Stimulate - ❑ Time 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: hic 181 -143 Explorator ❑ Stratigraphic BP Exploration (Alaska) Inc. ❑ p g p 3. Address: ® Developme ❑ Servic 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50029 20663 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 047434 MPC -01 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary: feet Plugs:(measured) Total depth: measured 10442' 9 :measured) 7287, 8852, 9075, 9185' feet ( d feet Junk: (measured) Below Bridge Plug 7287' feet true vertical 10430' ( ) Effective depth: measured 7287' feet Packer: (measured) None feet true vertical 7277 feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 110' 110' 1530 520 Surface 2310' 13 -5/8" 2338' 2338' 4930 2670 Intermediate Production 9775' 9 -5/8" 9802' 9791' 6870 4760 Liner Perforation Depth: Measured Depth: 6959' - 7167' feet True Vertical Depth: 6950' - 7157' feet Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# L - 6782' 6773' Packers and SSSV (type, measured and true vertical depth): None None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1 Treatment description including volumes used and final pressure: SCAN APR 1 9 2013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 167 153 294 260 187 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: ❑ Copies of Logs and Surveys ❑ Explorator ❑ Stratigraphic -I Developme ❑ Servic ® Daily Report of Well 16. Well Status after work: ® Oil ❑ Gas ❑ WDSP ® Well Schematic ❑ GSTOR ❑ WINJ ❑ WA ❑ GINJ ❑ SUSP ❑ SPLU 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: NIA Contact3 David Bjork, 564 - 5683 Email: David.Bjork@bp.com Joe a ufka Title: Drilling Technologist Signatur Phone: 564 -4091 Date: � 1 /50 /IS Form 10 -404 Revised 10 /2012 DMS FEB 0 7013, iFLe 4-1 13 ✓`� 4/P Submit Original Only • • ,- , , g 0 /5v/1 / 0- , gyz 16.1,i57:,"0,(nto a a Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/28/2012 18:00 - 19:00 1.00 MOB P PRE PJSM, WELL TO WELL RIG MOVE - NOTIFY DRILL SITE OPERATOR OF RIG MOVE - FUNCTION TEST MOVING SYSTEM HYDRAULICS SYSTEM AND "E" STOP - RAISE CELLAR DOORS, REMOVE SHIMS 19:00 - 22:00 3.00 MOB P PRE MOVE RIG OFF MPC -13 MOVE RIG DOWN PAD AND POSITION TO PULL OVER WELL - SPOT RIG OVER MPC-01 - POSITION MATS AND SHIM SUB BASE - CLOSE CELLAR DOORS, SECURE STAIRS AND LANDINGS 22:00 - 00:00 2.00 MOB P PRE SPOT SMALL CUTTINGS TANK - SPOT CHANGE TRAILER AND PIPE SHED RAMPS - SPOT FLOW BACK TANK - WELL SUPPORT R/U AND TEST HARDLINE 12/29/2012 00:00 - 02:30 2.50 WHSUR P DECOMP PJSM, R/U TO KILL WELL - R/U WELL KILL MANIFOLD IN CELLAR - R/U ALL CIRCULATING LINES TO TREE AND KILL MANIFOLD - R/U SSV REMOTE PANEL AND FUNCTION TEST - TEST HIGH LEVEL ALARM ON FLOW BACK TANK - RIG ACCEPTED AT 00:00 HRS 02:30 - 06:30 4.00 WHSUR P DECOMP LOAD PITS WITH 120 DEGREE 8.5 PPG SEA WATER - TEST ALL CIRCULATING LINES AND WELL KILL MANIFOLD WITH DIESEL - TEST HARD LINE TO FLOW BACK TANK - IDENTIFY LEAK THRU #1 CHECK VALVE ON WELL KILL MANIFOLD - BLOW ALL LINES DOWN AND REMOVE #1 CHECK VALVE FROM SERVICE - ATTEMPT TO LOCATE REPLACEMENT CHECK VALVE - IA = 720 PSI -OA =0 PSI - TUBING = 200 PSI (BPV INSTALLED) 06:30 - 07:00 0.50 WHSUR P DECOMP RIG EVACUATION DRILL, FIRE IN THE BOILER ROOM. - ALARM SOUNDED, MILNE PT AND DRILL SITE OPERATOR NOTIFIED. - ALL HAND MUSTERED TO THE WELL SITE LEADER SHACK. - LITTLE RED, TRUCK DRIVERS AND RIG HANDS, ALL ACCOUNTED FOR. - GOOD RESPONSE TIME, TWO PEOPLE DONNED AIR PACKS AND WELL SECURED. �\ 07:00 - 09:30 2.50 WHSUR P DECOMP PJSM. PICK UP LUBRICATOR. - PRESSURE TEST_@ 250 / 3500uI / 5 MIN EACH. - PULL BPV, SITP = 700 PSI, LID LUBRICATOR. - SITP 700 PSI, VA = 720 PSI, 0/A = 0 PSI. Printed 1/14/2013 1:48:10PM Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 11:30 2.00 KILLW P DECOMP PRE WELL KILL MEETING WITH ALL HANDS. - EMPHASIS ON SIGNING OFF ON VALVE ALIGNMENTS. - GOOD COMMUNICATION AND FLUIDS MANAGEMENT. - LINE UP VA THRU CHOKE TO FLOW BACK TANK. BLEED GAS FOR (10) MINUTES, DID NOT SEE FLUID. - BLED VA DOWN TO 220 PSI, TUBING WENT T O 200 PSI. LINE UP TO CIRC DOWN TUBING, TAKING RETURNS THRU CHOKE TO FLOW BACK TANK. - CIRCULATE @ 4 BPM, ICP = 430 PSI, PUMP 40 BBLS, FCP = 480 PSI. - CLOSE CHOKE, BRING RATE UP TO 5 BPM AND BULLHEAD 60 BBLS. - FINAL BULLHEAD PRESSURE = 1500 PSI @ 5 BPM. - OPEN CHOKE AND CONTINUE PUMPING 100 BBLS @ 4 BPM / 950 - 1100 PSI. 11:30 - 12:00 0.50 KILLW P DECOMP TAKE ON MORE FLUID, SHUT DOWN AND SHUT IN WELL. - BLOW DOWN LINE TO FLOW BACK TANK. - STRAP FLOW BACK TANK, 63 BBLS RETURNED. 12:00 - 13:00 1.00 KILLW P DECOMP PJSM. FINISH LOADING PITS W/ 8.5 PPG HEATED BRINE. - CHECK EQUIPMENT AND VALVE ALIGNMENTS. - CHECK TUBING, TUBING ON A STRONG VACUUM. 13:00 - 17:00 4.00 KILLW P DECOMP PRE WELL KILL MEETING WITH NEW CREW. - EMPHASIS ON GOOD COMMUNICATION AND FLUIDS MANAGEMENT. CIRCULATE ANOTHER 507 BBLS DOWN TUBING, TAKING RETURNS THRU CHOKE _ �\ AND TO FLOW BACK TANK. KEEPING BACK ,, PRESSURE ON VA CONSTANT TO DETERMINE KILL RATE PRESSURES. - 3 BPM @ 300 PSI AND 4 BPM @ 610 PSI. - SEE 8.5 RETURNS AFTER PUMPING A TQTALOF 550 BBLS AFTER BULL HEADIN_Q, PUMPED ANOTHER 50 BBLS AND SHUT DOWN, SHUT IN. - PUMPED 707 BBLS IN, INCLUDING 60 BBLS BUILLHEADED, RETURNED 405 BBLS OUT DURING WELL KILL OPERATIONS. 0/A = 40 PSI. Printed 1/14/2013 1:48:10PM i i ii �� i /- � ��e ,' ,, %% v , � i �� i o � , �� ,, „./..x.—„,,,,, //, ;,,,,,,,, / '.."P"'5",,:// ' ,',„'1///:///' ,,,/ , ,,,I.' '' //// , ',/ ,„ , ,,,,' dio ii • - t • r i Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- O0WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 18:30 1.50 KILLW P DECOMP MONITOR WELL 30 MINUTES - TUBING IS ON A STRONG VAC, IA IS VENTING AIR - USE CHARGE PUMP TO FILL IA, TOOK 15 BBLS TO FILL - ALLOW IA TO VENT TO FLOW BACK TANK 5 MINUTES MONITOR 20 MINUTES - WSL VERIFY IA ON SLIGHT VAC, TUBING STILL ON STRONG VAC - CHU O W AIVED ST ON 18:30 - 20:00 1.50 WHSUR P DECOMP STATE S RIGH SCHEVE T TO W ITN AOGCC ESS BOP TEST MPC 01 AT 17:00 ()-• B LOW DOWN AND R/D ALL CELLAR k CIRCULATING N AIL MD �� V R/U IRC AUX KILL LINE TOI FIL L IA L AT —20 ANIFOL BPH . ` l 1.00 20:00 - 21:00 WHSUR P DECOMP PJSM, L R/U TI DSM LUBRICATOR K - TEST LUBRICAT R TO 250 PSI, 3500 PSI, 5 MIN, TE - INSTALL TWC - R/D DSM LUBRICATOR 21:00 - 22:30 1.50 WHSUR P DECOMP PERFOR R D OLLING TEST FROM BELOW TWC.500 PSI, 10 MIN, CHARTED y FCP 2.5 BPM = 500 PSI, 20 BBLS TO CATCH FLUID, 68 AR BBLS TOTAL PUMPED - TEST TWC FROM ABOVE 250 PSI, 3500 PSI, 5 CHARTED TEST IAISONVAC - WILL MAIAIN CONN FLT TO IA WHILE N/D TREE AND STAT N/U I BOP 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM WITH FMC HAND - BLEED ADAPTER NT FLANGE VOID L OFF BPH - E () OA N/D =O PSI AND ADAPTER `J 24 HOUR LOSSES TO WELL = 4I : K E D: :: 12/30/2012 00:00 - 01:00 1.00 WHSUR P DECOMP PJ) TREE - CHECK HANGER T AND x RUN WITH LANDING JOINT - 8 TURNS RH WITH 31/2" NSCT JOINT BOPSUR P 01:00 - 04:00 3.00 DECOMP N/U 13 X 13 ADAPTER SPOOL ON n N/U SM 133/8" 4 PREVENTOR BOP STACK Q`( TOP BOTTOM = ANNULAR, 2 VARIABLE PIPE RAM S, BLIND -SHEAR 7/8X RAMS , MUD CROSS , 2 7/8" X 5" VARIABLE PIPE RAMS - M CONUL TO IA BPH 04:00 - 06:00 2.00 BOPSUR P DECOMP M/U AINTAIN FLOOR VALVES TIN AND OUS TEST FIL JOINTS AT FOR 20 BOP TEST - R/U - FILL STACK TEST EQUIPMENT WITH FRESH WATER Printed 1/14/2013 1:48:10PM Common Well Name: MPC 01 AFE No Event Type: WORKOVER (WO) Stt e: 2/28/2012 End 1/6/2013 X4- O OWTW -E : (2,300 ) Project: Milne Point Site: ar M Dat Pt Pad Rig Name /No.: DOYON 16 Spud Date/Time: 0 12:00:00AM Date: Rig R eleas e: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @1 7.Oft (above Mean Sea 2/4/2 Lev el) Date From - To Hrs Task Code NPT NPT e De of Opera (hr) (ft ) 06:00 - 12:00 6.00 BOPSUR P DECOMP PJSM. TEST BOPS UIREMENTS ACCORDING TO AOGCC AND BP REQ. TEST @ 250/ 3500 PSI WITH 2 7/8" AND 4 1/ TEST JTS ON VBRS. - TEST ANNULAR WIT CO 2 7/8" TEST JT. - CHOKE IFLD VALVES FLOOR VALVES AND MAN IBOP'S TO 250 / 3500 PSI, 5 MIN - SOME PROBLEMS WITH AIR O AND TWO WY CHECK VALVE. - REMARKS ENTERED ON CHARTS, TEST UNTIL PASS. LOSSES TO WELL LAST HRS = 221 , )( BBLS. 5 12:00 - 18:00 6.00 BOPSUR P DECOMP PJSM. TEST CONTINUE_TO TEST (12) 13 5/8" X 5M R BOPE. 0 TOP TO BOTTOM, ANNULAR PREVENTOR, 2 1u 7/8" X 5" VBRS. - BLIND ARS, MUD CR A 2 7/8" X 5" yi VBRS. - CHASE DOWN SYSTEM LEAKS p DRYER , (HSE), CAME OSS OUT AND PERFORMED AN AUDIT ON THE SAA / RAA AREAS AND ASSOCIATED DOCUMENTATION, ALL WAS IN ORDER. 18:00 - 00:00 6.00 BOPSUR P DECOMP STILL EXPERIENCING INCONSISTENT PROBLEMS, SUSPECT TWC VALVE - PULL TEST JOINT, VAC OUT BOP STACK FILL IA, OBSERVE WASH THRU TWC THEN SEE TWC CLOSE FROM BELOW WASH AND VAC OUT TOP OF TWC - INSTALL 2 7/8" TEST JOINT, FILL BOP AND CHOKE MANIFOLD AND BLEED ALL AIR OUT - RE -TEST LOWER AND UPPER VBR PIPE RAMS AND ANNULAR, GOOD TESTS - INSTALL 4 1/2" TEST JOINT, TEST LOWER AND UPPER VBR PIPE RAMS, GOOD TESTS - ET - PERFORM TE ACCUMULA - CHUCK SCHEVE OF TES AOGCC WAIVED A STATES RIGHT TO WITNESS TOR BOP TEST TEST T 13:30 HRS 12/29/12 BOP I -OA =20 PSI - 24 HOUR LOSSES TO SPCC WELL = 400 BBLS 12/31/2012 00:00 - 01:00 1.00 BOPSUR P DECOMP PJSM, PERFORM AND EQUIPMENT CHECKS - BLOW DOWN ALL LINES - RID TEST EQUIPMENT i SB MA INTAIN EN CONTINUOUS IONS FILL TO IA AT PH 01:00 - 12:00 11.00 BOPSUR N RREP DECOMP USPD OPERAT DUE TO TOP DRIVE REPAIRS - 8.5 SEAWATER LOST TO WELL LAST RS = 252 BBLS. Printed 1/14/2013 1:48:10PM Common Well Name: MPC 01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 00:00 12.00 BOPSUR N RREP DECOMP SUSPEND OPERATIONS - DUE TO TOP DRIVE REPAIRS - 24 HOUR FLUID LOSS = 481 BBLS - MAINTAIN CONTINUOUS FILL TO IA AT 20 BPH 1/1/2013 00:00 - 12:00 12.00 BOPSUR N RREP DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SUSPEND OPERATIONS - DUE TO TOP DRIVE REPAIRS -OA =0 PSI - MAINTAIN CONTINUOUS FILL TO IA AT 20 BPH, (HOLE STAYING FULL) 12:00 - 00:00 12.00 BOPSUR N DECOMP PJSM, STRESS HAZARD RECOGNITION DURING NON - ROUTINE TASKS - SUSPEND OPERATIONS - DUE TO TOP DRIVE REPAIRS - OA =0PSI - MAINTAIN CONTINUOUS FILL TO IA - FLUID LOSS = 16 BPH - 24 HOUR FLUID LOSS = 405 BBLS 1/2/2013 00:00 - 02:00 2.00 BOPSUR N RREP DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SUSPEND OPERATIONS - DUE TO TOP DRIVE REPAIRS - MAINTAIN CONTINUOUS FILL TO IA WITH 8.5 PPG SEA WATER - FLUID LOSS = 16 BPH 02:00 - 05:00 3.00 WHSUR P DECOMP PJSM, RIG REPAIRS COMPLETE - M/U OFF -SET LUBRICATOR TO HANGER, CLOSE ANNULAR - R/U DSM LUBRICATOR AND PULLING TOOLS - WAIT ON DSM SUPERVISOR FROM PRUDHOE BEFORE PULLING TWC - TEST LUBRICATOR, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - PULL TWC, WELL IS ON LOSSES - R/D DSM LUBRICATOR AND EQUIP Printed 1/14/2013 1:48:10PM t h America - ALASKA - BP /, ; ""' • WpIr , e ,; rati on Summary; Report Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 05:00 - 09:00 4.00 WHSUR P (ft) DECOMP PJSM, PULL HANGER TO RIG FLOOR � - M/U LANDING JOINT TO HANG r� - WSL VERIFY NO PRESSURE UNDER HANGER ON IA - FMC REP BACK OUT LOCK DOWN SCREWS AO - PULL HANGER OFF SEAT AT 90K, PUW = 85K. SOW = 83K (INCLUDES 40K TOP DRIVE - INT) - PULL HANGER AND FIRST FULL JOINT TO RIG FLOOR - CUT ESP CABLE AT CLAMP AT BOTTOM OF FIRST JOINT - RIH TO PLACE SLICK PIPE ACROSS BOP -1../D HANGER AND. LANDING JOINT CLOSE ANNULAR AND CIRCULATE A TUBING VOLUME THRU GAS BUSTER. - CONTINUE TO CIRCULATE A BOTTOMS UP. MONITOR F/ 10 MIN. - WSL / DRILLER VERIFY TBG AND IA ON A • SLIGHT VACUUM. - - BLOW DOWN LINES. 09:00 - 19:00 10.00 PULL P DECOMP " PJSM PULL ESP COMPLETION. PULL 2 - 7/8" 6.5# EUE,1 BG ESP - -- COMPLETION FROM 6790' MD. - LID 2 -7/8" TBG T/ PIPE SHED. (SENT IN FOR ° J INSPECTION) - 1' LASSALE CLAMPS = 113 - 2' CANNON CLAMPS = 10 - HALF CANNON CLAMPS = 2 - PROTECTOLIZERS = 2 - MAINTAIN CONTINUOUS HOLE FILL AT —16 BPH LOSS RATE. 8.5 PPG SEAWATER. 19:00 - 21:00 2.00 PULL P DECOMP PJSM, UD ESP MOTOR AND PUMP ASSY - LID 7" CASING SHROUD 21:00 - 22:30 1.50 PULL P DECOMP SPOOL REMAINING ESP CABLE TO SPOOLING UNIT - R/D ESP SHEAVE AND TRUNK ASSY - CLEAR RIG FLOOR OF ALL CENTRILIFT EQUIPMENT - CLEAN AND CLEAR RIG FLOOR - CHANGE OUT ELEVATORS 22:30 - 00:00 1.50 CASING P DECOMP PJSM, RIH WITH RBP ON DRILL PIPE - MOBILIZE HES EQUIPMENT TO PIPE SHED AND RIG FLOOR - M/U 95/8" RBP PER HALIBURTON REP - RIH WITH RBP ON 4" DRILL PIPE FROM SURFACE TO 480' - 24 HOUR FLUID LOSS = 406 BBLS - MAINTAIN CONTINUOUS HOLE FILL AT —16 BPH LOSS RATE. 8.5 PPG SEAWATER 1/3/2013 00:00 - 06:00 6.00 CASING P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - RIH WITH 9 5/8" RBP ON 4" DRILL PIPE 1X1 FROM 408' TO 5200' (AT 6:00) - MAINTAIN CONTINUOUS HOLE FILL AT —16 BPH LOSS RATE. 8.5 PPG SEAWATER Printed 1/14/2013 1:48:10PM )5 , ',, %t Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table ©17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 08:30 2.50 CASING P DECOMP CONTINUE RIH WITH 9 5/8" RBP ON 4" DRILL PIPE 1X1 - FROM 5200' TO —6707' MD. - POW / 134K, SOW / 140K. 08:30 - 09:30 1.00 CASING P DECOMP BREAK CIRCULATION AT 4 BPM / 210 PSI - HES REP SET 9 -5/8" RBP AT 6707' MD. - RELEASE FROM TOOL AND POH 5 STAND TO DERRICK - TO 6225' MD. 09:30 - 10:30 1.00 CASING P DECOMP PJSM, MIT -IA, 9-5/8" CSG - SET 9 -5/8" RBP AT 6707' MD - WSL CONFIRMED S " TING DEPTH. - WSL / TP VERIFY VALVE ALIGNMENT. - PRESSURE TEST CSG TO 3000 PSI FOR 30 MIN. - PUMPED 62 STK (5.1 BBLS) T/ 3000 PSI FOR 30 CHARTED MINUTES. - DISCUSS WITH RWO WTL.(PASSED TEST) - MIT -IA TEST, MEETS BP STP CRT -AK-1 - RECEIVED PERMISSION TO PROCEED FROM RWO WTL. - SEE ATTACHMENTS X WSL/TP VERIFY NO TRAPPED PRESSURE i _C - R/U TEST EQUIPMENT. 10:30 - 11:30 1.00 CASING P DECOMP PJSM, P/U 9 -5/8" (HES) STORM PACKER - M/U 9 -5/8" STORM PACKER AND XO. - RIH ON STAND FROM DERRICK. - M/U FOSV. - SET AT 102' MD. 11:30 - 12:00 0.50 CASING P DECOMP PJSM, TEST STORM PACKER. - WSL / TP VERIY VALVE ALINGMENT. - 9 -5/8" STORM PACKER TESTED AGAINST BLIND RAMS. - TO 250 PSI / 3000 PSI, BOTH TEST CHARTED 5 MIN. PASSED. 12:00 - 15:30 3.50 BOPSUR P DECOMP RWO WTL AND RWO SUPERINTENDENT VISITED BOTH RIG CREWS. PJSM, N/D BOPE AND CHANGE OUT 11" 5M FMC GEN 1 1 BG SPOOL AND PACK -OFF. - SLOWDOWN I LL LINES LOTO KOOMEY UNIT. - VACUUM OUT BOP STACK. - N/D RISER, 13 -5/8" x 11" ADAPTOR SPOOL AND BOPE STACK 15:30 - 18:30 3.00 WHSUR P DECOMP CHANGE OUT TUBING SPOOL AND PACK OFF - TEST SECONDARY PACK -OFF, 250 PSI, 3500 PSI, 30 MINUTES, CHARTED, GOOD TEST 18:30 - 22:00 3.50 WHSUR P DECOMP PJSM, PLACE NEW TREE IN CELLAR - BLOW DOWN AND R/D OA LINE TO FLOW BACK TANK - INSTALL 13" X 11" ADAPTER FLANGE - INSTALL OUTER FLANGE ON IA - N/U BOPE, RISER, MOUSE HOLE, TURNBUCKLES, ETC. 22:00 - 22:30 0.50 BOPSUR P DECOMP INSTALL TEST PLUG AND R/U TEST EQUIPMENT - TEST BOP BREAKS TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - PULL TEST PLUG Printed 1/14/2013 1:48:10PM • ion , Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 23:00 0.50 WHSUR P DECOMP INSTALL 9" ID WEAR BUSHING - RUN IN 4 LOCK DOWN SCREWS - R/D RUNNING TOOL, LID TEST JOINT 23:00 - 00:00 1.00 CASING P DECOMP PJSM, M/U STORM PACKER RETRIEVING TOOL Ril-tAND STOP ABOVE STORM PACKER - M/U FOSV VALVE, HEAD PIN AND CEMENT HOSE - 24 HOUR FLUID LOSS = 84 BBLS - OA ON SLIGHT VAC 1/4/2013 00:00 - 01:00 1.00 CASING P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - ENGAGE STORM PACKER WITH RETRIEVING TOOL - EQUALIZE PRESSURE THROUGH TOOL, WSL VERIFY NO PRESSURE - CLOSE ANNULAR, P/U AND RELEASE STORM PACKER, ALLOW PACKER TO RELAX - WSL VERIFY NO PRESSURE ON DP OR ANNULUS - OPEN ANNULAR, MONITOR WELL - R/D FOSV, PUMP IN SUB AND CEMENT HOSE - POOH 1 STAND AND LID STORM PACKER 01:00 - 02:00 1.00 CASING P DECOMP PJSM, RIH 5 STANDS, FROM 6225' TO 6707' - PUWT = 134K, SOWT = 140K - SPR'S, 30 SPM = 70 PSI, 40 SPM = 120 PSI - LATCH ON TO RBP AND EQUALIZE PSI - PICK UP AND RELEASE RBP - CLOSE ANNULAR 02:00 - 02:30 0.50 KILLW P DECOMP BULLHEAD 40 BBLS OF 8.5 PPG SEA WATER DOWN BOTH DRILL PIPE AND IA FORMATION - 9 BPM, INITIAL BULLHEAD PRESSURE = 1290 PSI, FINAL BULLHEAD PRESSURE = 1740 PSI - SHUT PUMPS DOWN, RECORD PSI DROP IN ONE MINUTE INTERVALS FOR 10 MINUTES - 1740 PSI, 950, 670, 520, 410, 340, 280, 230, 200, 170, 150 PSI - BLEED REMAINING 150 PSI BACK TO PITS = 1 BBL RETURNED 02:30 - 04:00 1.50 CASING P DECOMP CBU THRU GAS BUSTER 1X - 6 BPM = 430 PSI - TRACE OF OIL PRIOR TO BOTTOMS UP - WSL VERIFY WELL IS ON VAC - OPEN ANNULAR - MONITOR WELL 10 MIN - WELL IS ON LOSSES - BLOW DOWN TOP DRIVE AND ALL CIRC LINES 04:00 - 12:00 8.00 CASING P DECOMP PJSM, POOH WITH RBP FROM 6707' - L/D DOWN DRILL PIPE 1X1 - TO/ 1000' MD. - 14 -16 BPH LOSS RATE WITH CONTINUOUS HOLE FILL, 8.5# SEAWATER. Printed 1/14/2013 1:48:10PM '9 �ls '6• ."� ..6 P i Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 12:30 0.50 CASING N DECOMP 9 -5/8" RBP SET WHILE LAYING DOWN DP. - ATTEMPT TO SCREW INTO DP WITH TOP DRIVE TO UN -SEAT RBP - TOP DRIVE FAILED TO OPERATE CORRECTLY. - PJSM, WSL, TOOLPUSHER, HES REP AND CREW. HES REP PRESENT TO RELEASE RBP WITH ROTARY TABLE. 12:30 - 13:00 0.50 CASING P DECOMP SERVICE RIG - CHANGE OUT IRON ROUGHNECK DIE'S. - RIG ELECTRICIAN MONITORING TOP DRIVE READINGS. 13:00 - 14:30 1.50 CASING P DECOMP CONTINUE TO POH F/ 1000' MD TO 9 -5/8" RBP. - UD 9 -5/8" RBP WITH HES REP. 14:30 - 15:00 0.50 WHSUR P DECOMP PJSM, PULL WEAR RING - M/U RUNNING TOOL ON 4" DP. - PULL WEAR RING. - UD RUNNING TOOL. - CLEAN AND CLEAR RIG FLOOR. 15:00 - 16:30 1.50 RUNCOM P RUNCMP PJSM, R/U TO RUN ESP COMPLETION ON 4 -1/2" TBG. - MOBILIZE CABLE CLAMPS AND ASSORTED CENTRILIFT TOOLS TO RIG FLOOR - BRING TOOLS TO THE RIG FLOOR BY WAY OF PIPE SHED. - NO ACCESS TO RIG FLOOR ELEVATOR DUE TO WELL MPC -21. - HANG ESP SHEAVE, C/O ELEVATORS - R/U 4 1/2" POWER TONGS 16:30 - 20:30 4.00 RUNCOM P RUNCMP PJSM, M/U 7" ESP MOTOR SHROUD - M/U AND INSERT ESP MOTOR ASSY INTO SHROUD - STRING ESP CABLE THRU SHEAVE AND CONNECT TO MOTOR - M/U REMAINING ESP ASSEMBLY - CHECK ESP CABLE CONDUCTIVITY 20:30 - 00:00 3.50 RUNCOM P RUNCMP RIH WITH 4 1/2" 12.6# L -80 IBT -M ESP ,COMPLETION - RIH FROM ESP ASSY TO 1640' - RUN WITH FLAT CABLE AND FULL CANNON CLAMS ON EVERY COLLAR - CHECK CONDUCTIVITY EVERY 1000' - FILL / FLUSH PIPE WITH 5 BBLS AT 1 BPM EVERY 2000' BECAUSE OF RUST - MAINTAIN CONTINUOUS HOLE FILL, LOSSES = 12 BPH - 24 HOUR FLUID LOSS = 353 BBLS - OA =0PSI 1/5/2013 00:00 - 03:30 3.50 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - RIH WITH 4 1/2" 12.6# L -80 IBT -M ESP COMPLETION - RIH FROM 1640' TO 3400' - RUN WITH FLAT CABLE AND FULL CANNON CLAMS ON EVERY COLLAR - CHECK CONDUCTIVITY EVERY 1000' - FILL / FLUSH PIPE WITH 5 BBLS AT 1 BPM EVERY 2000' BECAUSE OF RUST / CORROSION IN PIPE Printed 1/14/2013 1:48:10PM Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 06:30 3.00 RUNCOM P RUNCMP MAKE ESP CABLE SPLICE AT -3100' - FLUSH PIPE WITH 5 BBLS AT 1 BPM = 40 PSI - ESP CABLE SPLICE ON JT# 87 RIH. 06:30 - 12:00 5.50 RUNCOM P RUNCMP CONTINUE RUN ESP COMPLETION - P/U 4 -1/2" TBG 1X1 FROM PIPE SHED. - F/ 3400' MD TO 6750' MD. - P/U TBG HANGER AND TERMINATE ESP CABLE PER CENTRILIFT REP. - PU WT. = 125K INCLUDING 40K TOP DRIVE / BLK WT. - SO WT. = 133K - 176 FULL CANNON CLAMPS RUN AND 3 PROTECTOLIZER CLAMPS. - LOSSES TO WELL 125 BBLS LAST 12 HRS. 12:00 - 14:30 2.50 RUNCOM P RUNCMP PJSM, TERMINATE ESP CABLE TO HANGER / PENETRATOR. - CLEAR RIG FLOOR. - CONDUCT PHASE TO PHASE GROUND CHECK PRIOR TO LANDING TBG HANGER. 14:30 - 15:00 0.50 RUNCOM _ P RUNCMP LAND TBG HANGER WITH FMC REP AND WSL _ PRESENT. - INSTALLED BRASS SHIPPING CAP T/ PENETRATOR. - FMC REP RILDS ON TBG HANGER. 15:00 - 15:30 0.50 RUNCOM P RUNCMP R/U TO REVERSE CIRCULATE TO CLEAR TUBING - PUMPED 60 BBLS @ 4 BPM = 260 PSI DOWN IA AND UP TBG - TAKING RETURNS THRU CHOKE AND GAS BUSTER TO PITS - WSL PRESENT. - RIG DN ESP SHEAVE FROM DERRICK. 15:30 - 16:00 0.50 RUNCOM P RUNCMP R/D TEST EQUIPMENT, UD LANDING JOINT - BLOW DOWN SUFACE LINES, RIG CHOKE, AND DRAIN GAS BUSTER. 16:00 - 18:30 2.50 WHSUR P RUNCMP PJSM, R/U DSM LUBRICATOR - TEST LUBRICATOR TO 250 3500 PSI, 5 MIN, CHARTED - INSTALL TWC - PERFORM TEST F/ BELOW @ 2 BPM = 500 PSI, 10 MIN, CHARTED - 27 BBLS PUMPED, BLEED BACK 3.7 BBLS - TEST FROM ABOVE 250 / 3500 PSI AND CHART FOR 5 MIN. EACH. - BLOW DN AND R/D TEST LINES, DRAIN BOP 18:30 - 19:30 1.00 BOPSUR P RUNCMP PJSM, N/D BOP - PULL MOUSE HOLE AND RISER, REMOVE TURNBUCKLES - REMOVE ADAPTER FLANGE FROM PEDESTAL 19:30 - 22:00 2.50 WHSUR P RUNCMP PJSM, N/U TREE AND ADAPTER FLANGE_ e - FMC REP CLEAN AND INSPECT TOP OF HANGER - INSTALL ADAPTER FLANGE - INSTALL 4 1/16" 5M CAMERON PRODUCTION TREE - WELL SUPPORT TECH PRESENT TO ORIENT TREE TO DESIRED LOCATION - CENTRILIFT REP CONDUCT FINAL PHASE TO PHASE CONDUCTIVITY TEST Printed 1/14/2013 1:48:10PM „ �r e Common Well Name: MPC -01 AFE No Event Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- 00WTW -E: (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:00 1.00 WHSUR P RUNCMP FMC HAND TEST ADAPTER VOID SEAL - 250 PSI, 5000 PSI, 30 MINUTES, CHARTED 23:00 - 00:00 1.00 WHSUR P RUNCMP COMPLETE N/U TREE FLANGES - R/U TEST EQUIPMENT TO TEST TREE WITH DIESEL - 24 HOUR FLUID LOSS = 253 BBLS OA =OPSI 1/6/2013 00:00 - 01:30 1.50 WHSUR P RUNCMP PJSM, CONTINUE N/U 4 5M CAMERON PRODUCTION TREE - TEST TREE WITH DIESEL, 250 PSI, 5000 PSI, 5 MIN CHARTED 01:30 - 04:00 2.50 WHSUR P RUNCMP M/U DSM LUBRICATOR TO TREE - TEST LUBRICATOR, 250 PSI, 3500 PSI, 5 MIN CHARTED - PULL TWC - TEST LUBRICATOR, 250 PSI, 3500 PSI, 5 MIN CHARTED - INSTALL BPV - R/D DSM LUBRICATOR 04:00 - 05:00 1.00 WHSUR P RUNCMP PERFORM ROLLING TEST FROM BELOW BPV INITIAL PUMP RATE OF 3.5 BPM FINAL - 15 BPM, 500 PSI, 10 MIN, CHARTED - PUMPS OFF, OBSERVED PRESSURE DECREASE FROM 500 PSI TO 150 PSI IN 5 MINUTES - BLEED REMAINING PRESSURE BACK TO PITS - PUMPED TOTAL OF 30 BBLS, 4 BBLS RETURNED 05:00 - 06:00 1.00 WHSUR P RUNCMP BLOW DOWN AND R/D CIRCULATING LINES FROM TREE - R/U LRS HOT OIL TO FREEZE PROTECT - LRS TESTED LINE 3500 PSI F /30 MIN. PASSED. - PUMP 38 BBLS DIESEL DOWN TBG. - 1.5 BPM / 500 PSI. 06:00 - 08:30 2.50 WHSUR P RUNCMP LRS HOT OIL, SEND TRUCK FOR A LOAD OF DEAD CRUDE. - SECURE TREE VALVES 08:30 - 10:30 2.00 WHSUR P RUNCMP LRS R/U TO IA AND TEST LINES - 3500 PSI F/ 30 MIN. PASSED. - PUMP 125 BBLS DEAD CRUDE DOWN THE 7" BY 4 -1/2" ANNULUS. - 2 BPM / 1100 PSI. - R/D LRS. 10:30 - 11:00 0.50 WHSUR P RUNCMP SECURE ALL TREE VALVES AND GAUGES. - WHP'S IA = 80 PSI, OA = '0' PSI. 11:00 - 14:00 3.00 WHSUR P RUNCMP WAIT ON WIND SPEED TO SUBSIDE TO LAY DERRICK OVER. - RIG ELECTRICIAN CONTINUES WORK ON TOP DRIVE ENCODER. DAY CREW, SUPPORT CREW HELD WEEKLY SAFETY MEETING. - DDI HSE REP, DDI RIG SUPT, WSL AND T.P. PRESENT. - DISCUSSED TIMELY REPORTING OF ALL INCIDENTS. - REVIEW 'HAND SAFETY VIDEO' Printed 1/14/2013 1:48:10PM AF No E Type: WORKOVER (WO) Start Date: 12/28/2012 End Date: 1/6/2013 X4- OOWTW -E: Common Well Name: MPC -01 (2,300,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/4/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @17.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 17:00 3.00 WHSUR N RUNCMP RIG ELECTRICIAN CONTINUE TO REPLACE ENCODER IN TOP DRIVE. - INSTALL BLOWER MOTOR. COMPLETE REPAIRS ON TOP DRIVE AND FUNCTION CHECK, GOOD 17:00 19:00 2.00 RIGD P POST PJSM, RIG UP FLOOR TO DERRICK DOWN AND MOVE OFF OF MPC-01 SECURE TOP DRIVE IN TARY TABL - RID TOP DRIVE RAIL /I TORQUE RO TUBE E - LOWER CATTLE CHUTE BRIDLE UP TRAVELING BLOCKS - PREP FLOOR AND MUD MANIFOLD TO DERRICK OVER - LAY DERRICK OVER AND SECURE ON DERRICK STAND - MOVE WSL OFFICE TO L -PAD - RELEASE RIG AT 19:00 HOURS Printed 1/14/2013 1:48:10PM TREE: 4 1/16" - 5M, Ca Tree M P U C-01 Orig. KB. = 48' (Nabors 17) WELLHEAD: 13 -5/8" 5M Orig. GL. = 28' w/4.5" FMC tubing hanger, Hyd 521 top and btm. thrds. 4" CIW BPV 20" 94 ppf H -40 btrs. 110' Camco 2 7/8" x 1" I 166' I sidepocket KBMM GLM KOP = none max. hole angle = 7 deg 0 m 9 5/8" cement divert valve @ 2219'MD 13 -5/8 ", 72 ppf, L -80 btrs. 1 2338' mdl 1 I I 9 -5/8" 47 ppf, L-80, Btrs. casing (cap. = 0.0732 bpf, drift ID = 8.525 ") Camco 2 7/8" x 1" a sidepocket KBMM GLM ( 6,497' 4 1/2 ", 12.6 ppf, L -80, IBT -M tubing "' (cap. = 0.0152 bpf, drift = 3.833 ") (cap w/ 4 1/2" Tbg inside = 0.0536 bpf) D &D Tubing Stop I ? ? ?? I D &D PackoffAssy Top I ? ? ? ?' I 1 IF Centrilift TTC -ESP Top I ? ? ? ?' Original perforation summary Size SPF Interval open / sqz'd I ,. 4" 12 9134' - 9143' squeezed •,, TTC Drilled Tubing XO I 6,743' u •fir 4" 12 8904' - 8934' squeezed ' • 4" 12 7142' - 7167' open ;� ' 'MEM 4" 12 7120' - 7133' open . , „h Centrilift I 6,753' I 4” 12 7109' - 7111' squeezed ;r gg, T andem Seal Section 4" 4 6970' squeezed i'®_' F E ., F t Centrilift Motor 4" 4 6959' - 6968' open ;.- L KMHG /114 2330 V / 30 Amp I 6,767' r, r Centrilift WellLift MGU w/ I 6,780' 12/94 Perforation summary EE centralizer Ek ;E REF LOG: 2/23/82 CBL, 2/5/82 DIL =E. Size SPF Interval open /sgz'd n d� 7' 26#L-80 shroud extends from the seperator intake to 8.43' below the centralizer (46' long, including the shroud head) 3 -3/8" 6 7142' - 7167' open H t, J 3 -3/8" 6 7120' - 7133' open J 3 -3/8" 6 6959' - 6968' open 9 5/8" Baker N -1 bridge 7287' and V >..cg plug, set 12/94 / -3.•g FISH: 9' toolstring w/ 1 -10' 0.092 FISH: Milled out Otis 9 5/8" WD pkr, ...a' slickline 4' -3.5" pup, 3.5" Otis 'X' npl, 5' -3.5" pup, 3.5" 'XN', 3.5" WLEG. Top is at 7423 MD. U •q FISH: Junk basket / gauge ring Ref. 12/94 RWO I FISH: Milled out Otis "WD" pkr. w/: .o•-- ----"■ 9 5/8" EZSV Retainer 8,852' and I seal bore extension, 6 1/8" X 3 1/2" x.o., _ 9 5/8" EZSV Retainer (9,075' and two 3.5" pup joints, Otis 'X' and `XN' npls. overall length = 23' 1 9,185' and I 9 5/8" EZSV Retainer A 9 -5/8" 47 ppf, L -80, Btrs. 1 9,802' and I DATE REV. BY COMMENTS MILNE POINT UNIT 3/18/82 DBR Initial completion 12/17/94 DBR RWO WELL C -01 09/08/98 JBF ESP Changeout by Nabors 4ES 10/22/00 MDO ESP Changeout / add Shroud 4 -es API NO: 50- 029 -20663 02/12/01 BMH ESP Changeout 4 -ES (w/ shroud) 12/15/04 JRC ESP Changeout 4 -ES (w/ shroud) 4/25/09 REH ESP Changeout - Nabors 3S 10/10/09 REH ESP Changeout- Nabors 4ES BP EXPLORATION (AK) 01/06/13 B. Bixby ESP Changeout TTC ESP Doyon 16 ~~~~~ STATE OF ALASKA • ALASKA IL AND GAS CONSERVATION COMMISSION ~1AR RT OF SUNDRY WELL OPERATIONS 1. Operations a ^ Plug Perforations ^ Stimulate ^ Other Q ACIDIZE ESP Performed: ~ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program prat. Shutdown ^ Perforate ^ Re-enter. Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: ~. Permit to Drill Number: Name: Development 0 Exploratory ^ , ~ 181-1430 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 't'~API Number: Anchorage, AK 99519-6612 50-029-20663-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number.. ADLO-04/434 ` MPC-01 10. Field/Pool(s): MILNE PO INT FIELD`7.KUPARUKRlVER OIL POOL 11. Present Well Condition Summary: 7287' 8852' Total Depth measured 10442 feet Plugs (measured) 9075' 9185' feet true vertical 10430.17 feet Junk (measured) BELOW 7287' feet Effective Depth measured 7287 feet Packer (measured) true vertical 7277 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 94# H-40 SURFACE - 110 SURFACE - 110 1530 520 Surface 2310 13-5/8" 72# L-80 SURFACE - 2338 SURFACE - 2338 4930 2670 Intermediate Production 9775 9-5/8"47# L-80 SURFACE - 9802 SURFACE - 9791 6870 4760 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ - = True Vertical depth: _ _ _ - = Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 24 - 6786 24 - 6777 Packers and SSSV (type, measured and true vertical depth) NONE ~y~~~~~~ ~p~ ~I '~ ~~~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 165 36 26 180 Subsequent to operation: 173 37 24 184 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run t Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 6~. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble~"~' Title Data Management Engineer Signature Phone 564-4944 Date 3/26/2010 MPC-01 181-143 DFRF ATTA~_I-IMFNT LJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-01 3/18/82 PER 6,959. 6,968. 6,949.51 6,958.48 MPC-01 3/18/82 PER 7,120. 7,133. 7,110.08 7,123.06 MPC-01 3/18/82 PER 7,142. 7,167. 7,132.05 7,157.01 MPC-01 3/18/82 PER 8,904. 8,934. 8,893.05 8,923.03 MPC-01 3/18/82 PER 9,134. 9,143. 9,122.92 9,131.91 MPC-01 12!16/94 BPS 7,287. 8,904. 7,276.92 8,893.05 M PC-01 12/17/94 RPF 6,959. 6,968. 6,949.51 6,958.48 MPC-01 12/17/94 RPF 7,120. 7,133. 7,110.08 7,123.06 MPC-01 12/17/94 RPF 7,142. 7,167. 7,132.05 7,157.01 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE l~ J • • MPC-O1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/6/2010;.CTU #9 w/1.50" OD CT. Job scope -MIRU, Acidize ESP. «< Interact publishing ~ »> MIRU. RIH w/2" OD JSN. Continued on WSR 03/07/2010. 3/7/2010 CTU #9 w/1.50" OD CT Job scope Acidize ESP. «< Interact publishing»> Continued from WSR 03/06/2010. RIH w/2" OD JSN. Tagged @ 6699' CTM. Washed off top of ESP @ 6669' CTM. Inj 5 bbls acid through ESP, wait 1 hr. Inj 15 bbls acid through ESP while running pump. POOH w/ESP running. Flow well to tank. 255 bbls to return tank and PH is at 7 for 3 readings. Swap well to production and RDMO **"Job Complete*** FLUIDS PUMPED BBLS 20 10% DAD ACID 62.5 Diesel 82.5 Total TREE: 3-1/8" - 5M, Cameron Tr McEvoy SSV with Baker Actuat WELLHEAD: 13-5/8" 5M FMC w/3.5" FMC tubing hanger, NSCT top and btm. thrds. 3" CIW BPVT 20" 94 ppf H-40 btrs. 110' KOP =none max, hole angle = 7 deg 13-5/8", 72 ppf, L-80 btrs. 2338' and ~ 9-5/8" 47 ppf, L-80, Btrs. casing (cap. = 0.0732 bpf, drift ID = 8.525") 2 7/8", 6.5 ppf, L-80, EUE 8rd tubing (cap. = 0.0058 bpf, drift = 2.347") Original perforation summary M P U C-0 1 Orig. KB. Elev. (Nabors 17) Orig. GL. Elev. 8' Camco 2 7/8" x 1" 140' sidepocket KBMM GLM 9 5/8" cement divert valve @ 2219'MD Camco 2 7/8" x 1" 6,529' sidepocket KBMM GLM 2 7/8" `XN' nipple " 6,669' (w/ 2.25 no go) Centrilift WeIILift DGU 6,710' Centrilift ESP 715' 6 PMSXD 49P12 , PMSXD 140P12 PMSSD 63G12 Centrilift GRSFTXARH6 751' 6 Tandem Gas Separator , w/ Adaptor kit Centrilift 756` 6 Tandem Seal Section , Size SPF Interval open / sgz'd 4" 12 9134' - 9143' squeezed 4" 12 8904' - 8934' squeezed 4" 12 7142' - 7167' open 4" 12 7120' - 7133' open 4" 12 7109' - 7111' squeezed 4" 4 6970' squeezed 4" 4 6959' - 6968' open 12/94 Perforation summary REF LOG: 2123/82 CBL. 2/5/82 DIL Size SPF Interval open / sgz'd 3-3/8" 6 7142' - 7167' open 3-3/8" 6 7120' - 7133' open 3-3/8" 6 6959' - 6968' open FISH: Milled out Otis 9 5/8" WD pkr, 4'-3.5" pup, 3.5" Otis `X' npl, 5'-3.5" pup, 3.5" 'XN', 3.5" WLEG. Top is at 7423 MD. Ref. 12/94 RWO FISH: Milled out Otis "WD" pkr. w/: / seal bore extension, 6 1/8" X 3 1/2" x.o., two 3.5" pup joints, Otis 'X' and `XN' npls. overall length = 23' Centrilift Motor M$P /147 hp 2175 v. / 42 a. 6,770' Centrilift WeIILift MGU w/ 6,784' centralizer 7" 26# L-80 shroud extends from the separator intake to 8.43' below I the centralizer (40.46' long, including the shroud head) 9 518" Baker N-1 bridge 728Z' and ~~ plug, set 12/94 ~~ FISH: 9' toolstring w/ 1-10' 0.092 ~~ slickline DATE REV. BY COMMENTS 3/18!82 12/17194 DBR DBR Initial completion RWO 09108/98 10/22/00 JBF MDO ESP Changeout by Nabors 4ES ESP Chan eout I add Shroud 4-es 02/12/01 12/15/04 BMH JRC ESP Changeout 4-ES (w/ shroud) ESP Chan eout 4-ES w/ shroud 4/25/09 REH ESP Changeout -Nabors 3S 10/10/09 REH ESP Changeout -Nabors 4ES FISH: Junk basket /gauge ring 9 5/8" EZSV Retainer 8,852' and 9 5/8" EZSV Retainer 9,075' and 9,185' and 9 5(8" EZSV Retainer 9-5/8" 47 ppf, L-80, Btrs. g,g02' and MILNE POINT UNIT WELL C-01 API NO: 50-029-20663 BP EXPLORATION (AK) ~ STATE OF ALASKA ALA~ OIL AND GAS CONSERVA710N COM~ION ..\ ~~~E~~l~~ REPORT OF SUNDRY WELL OPERATIONS ~~V a~~c~~9 ~Ilaska Oil & Gas Cons. Commissi~~ Operations PeAormed: tl~ AfB~Q ^ Abandon ~ Repair Well ^ Plug Per~orations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension C nge out ESP 2. Operator Name: 4. Well Class Before Work: . Permft To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Expioratory 181-143 3. Address: ^ Service ^ Stratigraphic API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20663-00-00 . Property Designation: Well Name and Number: ADL 047434 MPC-01 . Field / Pool(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 10442' feet true vertical ~ 10430' feet Plugs (measured} na~~, 8esr, so~s, s~as~ Effective depth: measured 72$7' feet Junk (measured) ~1ON' Bridge Plug 7287~ true vertical 7277' feet Casing Length Size MD ND Burst Collapse ...... . ..... ....., ,.. ....:. .. . . Structural Conductor 81' 20" 110' 110' 1530 520 Surface 2310' 13-5/8" 2338' 2338' 4930 2670 Intermediate Production 9775' 9-5/8" 9802' 9791' 6870 4760 Liner ~~~~~~a 1 ~~`,l ~ ~~ 2009 Perforation Depth: Measured Depth: 6959' - 7167' True Vertical Depth: 6950' - 715T Tubing (siae, grade, measured and true veRical dtpth): 2-7/8", 6.5# L-80 6786' 6777' Padcers artd SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and flnal pressure: ~ 2. Reprs~ntative Daily Average Produdion or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Preasure Prior to w~ll operation: 212 54 270 220 177 Subsequent to operation: 2gg 222 566 220 181 13. AttacMments: ~ Copies of Logs and Surveys run • Well Class aRer work: ^ Exploratory ~ Development ^ Service ~ Dail RepoR of Well O erations y p ~ Well Schematic Diagram • Well Status aft~r work: ~ Qil ^ Gaa ^ WDSPL. ^ C~STOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 1 hereby certify that the foregoing is hue and coRec~ to the best of my knowledge. Sundry Nurnber or WA if C.O. Facempt: ContaG Hank Baca, 564-5444 N/q Printed Name Teme Hubble Tdle Drillin Technolo ist , Prepareo er +~/~xs~er: Signature Phone 564-4628 Date Terrie Hubbb 564-4628 5~ Form 10~04 Revised 07/2009 ` ~Q ~,~ C I r~l ~ ~~~ ~o ~Onginal Only v.SL/ ~ v ~ • • BP' EXPLORATION Page 1 of 3 - Operations Surnmary Rep~ort Legal Well Name: MPC-01 Common Well Name: MPC-01 Spud Date: 2/4/2001 Event Name: WORKOVER Start: 9/17/2009 End: 10/9/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/9/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date' From - To Hours Task Code NPT Phase ' Description of Operations 10/6/2009 12:00 - 14:00 2.00 MOB P PRE R/D FOR MOVE. SCOPE IN DERRICK AND LOWER ONTO SUB. BLOWDOWN AND UNHOOK LINES. PREP UNITS FOR MOVE TO MPC-01. 14:00 - 15:00 1.00 MOB P PRE MOVE PIPE SHED, PITS AND SUB OFF MPC-23 WITH NABORS TOOLPUSHER, WSL AND PAD OPERATOR PRESENT. 15:00 - 16:00 1.00 MOB P PRE MOVE RIG AROUND PAD TO MPC-01. 16:00 - 21:00 5.00 MOB P PRE SPOT SUB OVER MPC-01 WITH NABORS TOOLPUSHER, WSL AND PAD OPERATOR PRESENT. RAISE DERRICK OFF OF SUB AND SCOPE UP INTO POSITION, R/U FLOOR AND DERRICK. CALL OUT W ELL SUPPORT TECHS TO REMOVE CELLAR FOUNDATION BOARDS FROM MPC-21 WHILE RAfSING DERRICK, TO ALLOW ROOM TO SPOT PITS IN TIGHT CLEARANCE TO WELLHEAD. NABORS TOOLPUSHER, WSL AND PAD OPERA70R PRESENT. 21:00 - 23:00 2.00 KILL P DECOMP BEGAN TAKING ON 110 DEGREE 8.5 PPG SEAWATER INTO PITS. RIG UP FLANGE TO TOP OF TREE. HOOK UP LINE TO TIGER TANK. " ACCEPTED RIG ~ 21:00 HRS ON 10/06/2009 '" 23:00 - 00:00 1.00 KILL P DECOMP RIG UP WELL SUPPORT LUBRICATIOR AND TESTED TO 500 PSI WITH DIESEL. 10/7/2009 00:00 - 00:30 0.50 KILL P DECOMP CONTINUE TAKING ON 110 DEGREE 8.45 PPG, 1% KCL WATER INTO PITS. -PULL BPV AND LAY DOWN WELL SUPPORT LUBRICATOR. 00:30 - 01:00 0.50 KILL P DECOMP FINISH TAKING ON 110 DEGREE 8.45 PPG, 1% KCL WATER INTO PITS. -HELD PJSM WITH CREW ON WELL KILL PROCEDURE. -PRESSURE TESTED CIRCULATING LINES TO 3,500 PSI 01:00 - 06:00 5.00 KILL P DECOMP ATTEMPTED TO CIRCULATE OUT THE DIESEL FREEZE PROTECTION. -CIRCULATE 1 TBG VOLUME, NO RETURNS. -BULLHEAD 50 BBLS DOWN TBG @ 4 BPM / 1,870 PSI. -BULL HEAD DOWN IA 575 BBLS. -ICP - 3 BPM / 160 PSI. STAGE UP RATE TO 4 BPM / 1260 PSI. -FCP - 4.5 BPM / 2100 PSI. 06:00 - 07:00 1.00 KILL P DECOMP CREW CHANGE AND PERFORM PRE-TOUR CHECKS. -SERVICE RIG. CHECK ALARMS. INSPECT OERRICK. -TUBING AND IA ON A VACUUM. 07:00 - 08:30 1.50 WHSUR P DECOMP FMC WELLHEAD TECH, DRY ROD TWC. -PERFORM ROLLING TEST FROM BELOW ON CHART. -INJECT INTO THE FORMATION TO MAINTAIN 1,000 PSI. -PUMP RATE 2.4 - 2.7 BPM. BLOW DOWN LINES. 08:30 - 09:30 1.00 WHSUR P DECOMP N/D 3 1/8" 5M CAMERON TREE. 09:30 - 10:45 1.25 BOPSU P DECOMP NU BOPE. NU CHOKE & KILL LINE. 10:45 - 11:30 0.75 BOPSU P DECOMP AFTER ACTION REVIEW OF WELL MPC-23. -DfSCUSS: HIGH POINTS, LOW POINTS & LESSONS ' LEARNED. 11:30 - 17:30 6.00 BOPSU P DECOMP MU TEST JT. TEST BOPE PER BP & AOGCC -BOP CONFIGURATION: Printed: 10/19/2009 11:05:01 AM ~ • BP EXPLORATION' Page 2 of 3 Oper~tions Summary Report Legal Well Name: MPC-01 Common Well Name: MPC-01 Spud Date: 2/4/2001 Event Name: WORKOVER Start: 9/17/2009 End: 10/9/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/9/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Gode NPT Phase Descriptian o# Operations 10/7/2009 11:30 - 17:30 6.00 BOPSU P DECOMP -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. -2 7/8" X 5" VARIABLE BORE RAMS. TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -USED 2 7/8" TEST JOINT ON RAMS & ANNULAR. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. 17:30 - 18:00 0.50 BOPSU P 18:00 - 19:00 1.00 BOPSU P 19:00 - 19:30 0.50 BOPSU P 19:30 - 21:00 1.50 PULL P 21:00 - 22:00 I 1.001 PULL I P 22:00 - 23:00 I 1.00 I PULL I P 23:00 - 00:00 1.00 PULL P 10/8/2009 00:00 - 06:00 6.00 PULL P 06:00 - 11:00 I 5.00 I PULL I P 11:00 - 12:00 1.00 PULL P 12:00 - 14:30 2.50 CLEAN P 14:30 - 15:30 I 1.001 CLEAN I P 15:30 - 16:30 I 1.001 C~EAN I P 16:30 - 20:00 I 3.50I CLEAN I P 20:00 - 23:00 I 3.001 RUN 23:00 - 00:00 I 1.001 RU 10/9/2009 I00:00 - 02:00 I 2.00 I RU -JEFF JONES AOGCC WAIVED WITNESS OF TEST. -TEST WAS WITNESSED BY WSL & TP. y DECOMP RU DUTCH SYSTEM. PU LUBRICATOR. DECOMP MU LUBRICATOR. TEST LUBRICATOR TO 500 PSI - PASS. -PULL TWC. LD SAME. DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. DECOMP PU LANDING JT. MU UP JT IN TBG HANGER. -PULL TBG HANGER TO RIG FLOOR W/ 63K UP WT. -LD SAME. DECOMP MU CIRCULATING HEADPIN. -PUMP 1 TBG VOLUME 2 4 BPM / 520 PSI. -PUMPED 8 BBLS (1,390' MD) TO CATCH FLUID. DECOMP - / " TBG, ESP & CABLE. -ATTACH CABLE TO SPOOLER. -TEST ESP CABLE CONDUCTIVITY DECOMP POH W/ 2-7/8" TBG, ESP & CABLE. -STANDING BACK 2-7/8" TBG IN DERRICK. DECOMP CONTINUE TO POH W/ 2-7/8" TBG, ESP & CABLE. -STANDING BACK 2-7/8" TBG IN DERRICK. DECOMP HANDLE ESP ASSEMBLY: -BO/LD ESP ASSEMBLY AND SHROUD DECOMP RD ESP CABLE TRUNK FROM DERRICK. -CLEAR & CLEAN FLOOR. DECOMP RIH W/ 2-7/8" TBG FROM DERRICK FOR CLEANOUT. -RIH 69 STDS TO 6,443.91' MD. DECOMP PU 24 JTS OF 2-7/8" TBG FROM 6,445' T0 7,190' MD. -PUW 43K, SOW 43K. NO FILL. DECOMP CIRCULATE: -PUMP 1 TBG VOLUME, 4 BPM / 500 PSI. NO RETURNS. DECOMP LD 24 JTS OF 2-7/8" TBG TO PIPE SHED. -POH W/ 2-7/8" TBG. STAND BACK 69 STDS IN DERRICK. -FILL HOI.E 20 BPH PLUS DISPLACEMENT. -CLEAR & CLEAN RIG FLOOR. RUNCMP PU PUMP & MOTOR. SERVICE SAME. - LL LE OVER HEAVE & ATTACH TO MOTOR. RUNCMP ATTACH I-WIRE. INSTALL CANNON CLAMPS. PLUG IN I-W IRE. -TEST ESP & I-WIRE. RUNCMP CONTINUE TO ATTACH I-WIRE. INSTALL CANNON CLAMPS. PLUG IN I-WIRE. -TEST ESP & I-WIRE. Printed: 10/79/2009 11:05:01 AM ~ • BP EXPLORATION Page 3 of 3< Operations Summary Repart Legal Well Name: MPC-01 Common Well Name: MPC-01 Spud Date: 2/4/2001 Event Name: WORKOVER Start: 9/17/2009 End: 10/9/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/9/2009 Rig Name: NABORS 4ES Rig Number: 4ES "" Date From - To Hours Task Code NPT RRhase Description of Operations 10/9/2009 02:00 - 08:30 6.50 RUNCO RUNCMP RUN ESP COMPLETION ASSEMBLY ON 2-7/8" TBG -MAINTAIN 20 BPH HOLE FILL WHILE RIH. -CHECK CONDUCTIVITY EVERY 2,000'. -PUMP 5 BBLS OF 1% KCL TO FLUSH PUMP EVERY 2,000'. 08:30 - 09:00 0.50 RUNCO RUNCMP TUBING HANGER. -PU/MU TIW VALVE ON LANDING JOINT. -MU TUBING HANGER. -INSTALL ESP PENETRATOR. 09:00 - 10:30 1.50 RUNCO RUNCMP ESP SPLICE. -CENTRILIFT REP PERFORM PENITRATOR SPLICE. 10:30 - 11:30 1.00 RUNCO P RUNCMP LAND TUBING. ~ -FMC / RILDS. -UD LANDING JOINT. -PUW AND SOW = 53K 11:30 - 12:00 0.50 RUNCO P RUNCMP WEEKLY CREW CHANGE. -SERVICE RIG. -PRE-TOUR CHECKS, INSPECT DERRICK. 12:00 - 13:00 1.00 RUNCO RUNCMP TEST TWC. -3500 PSI FROM ABOVE. -FROM BELOW PUMP 67 BBLS AND GOT RETURNS. -INJECT INTO FORMATION AT 2-3 BPM TO MAINTAIN -700 PSI FOR 10 CHARTED MINUTES. 13:00 - 15:00 2.00 WHSUR P WHDTRE ND BOP STACK. -SET BACK BOP STACK. 15:00 - 18:00 3.00 WHSUR P WHDTRE NU TREE 18:00 - 18:30 0.50 WHSUR P WHDTRE TO 3,500 PSI FOR 30 CHARTED MINUTES. -CENTRILIFT FINAL CHECK - GOOD. 18:30 - 20:00 1.50 WHSUR P WHDTRE RU & TEST LUBRICATOR TO 500 PSI - GOOD. -PULL TWC. INSTALL BPV. FILL IA W/ 64 BBLS OF 1% KCL. -TEST BPV F/ BELOW 41 SPM / 500 PSI. 20:00 - 21:00 1.00 WHSUR P WHDTRE RD LINES. SECURE WELL. T/I/O = 0/0/0 RELEASE RIG FROM C-01 ~ 21:00 HRS ON 10/09/2009 Printed: 10/19/2009 11:05:07 AM . TREE: 3-1/8" - 5M, Cameron ~ McEvoy SSV with Baker Actu M P U C~~ 7 Orig. KB. EI~ 48' (Nabors 17) ' " Orig. GL. Ele 28 WELLHEAD: 13-5/8 5M FMC w/3.5" FMC tubing hanger, NSCT top and btm. thrds. 3" CIW BPVT ,,,,,~ 20" 94 ppf H-40 btrs. ~ ~ p~ ~~ Camco 2 7/8" x 1" 140' ocket KBMM GLM ide p s ,~~i. KOP = none max. hole angle = 7 deg 9 5/8" cement divert valve @ 2219'MD 13-5/8", 72 ppf, L-80 btrs. 2338' md 9-5/8" 47 ppf, L-80, Btrs. casing (cap. = 0.0732 bpf, drift ID = 8.525") 2 7/8", 6.5 ppf, L-80, EUE 8rd tubing (cap. = 0.0058 bpf, drift = 2.347") Original perforation summary Size SPF Interval open / sqz'd 4" 12 9134' - 9143' squeezed 4" ~2 8904' - 8934' squeezed 4" 12 7142' - 7167' apen 4" 12 7120' - 7133' open 4" 12 7109' - 7111' squeezed 4" 4 6970' squeezed 4" 4 6959' - 6968' open 12/94 Perforation summary REF LOG: 2/23/82 CBL, 2/5/82 DIL Size SPF Interval open / sqz'd 3-3/8" 6 7142' - 7167' open 3-3/8" 6 7120' - 7133' open 3-3/8" 6 6959' - 6968' open FISH: Milled out Otis 9 5/8" WD pkr, 4'-3.5" pup, 3.5" Otis 'X' npl, 5'-3.5" pup, 3.5" 'XN', 3.5" WLEG. Top is at 7423 MD. Ref. 12/94 RWO / FISH: Milled out Otis "WD" pkr. w/: seal bore extension, 6 1/8" X 3 1/2" x.o., two 3.5" pup joints, Otis 'X' and 'XN' npls. overall length = 23' Camco 2 7/8" x 1" 6,529' sidepocket KBMM GLM 2 7/8" 'XN' nipple " 6,669' (w/ 2.25 no go) Centrilift WeilLift DGU 6,710' Centrilift ESP 715' 6 PMSXD 49P12 , PMSXD 140P12 PMSSD 63G12 Centrilift GRSFTXARH6 751' 6 Tandem Gas Separator , w/ Adaptor kit Centrilift 756' 6 Tandem Seal Section , Centrilift Motor 6,770' MSP /147 hp 2175 v. I 42 a. Centrilift WeIILift MGU w/ 6,784' centralizer 7" 26# L-80 shroud exlends from Ihe seperator in~ake ta 8.43' below the centrelizer (40.46' long, including ihe shroud head) 9 5/8" Baker N-1 bridge 72g7~ md ~~ plug, set 12/94 `~~ FISH: 9' toolstring w/ 1-10' Q.092 0~ slickline DATE REV. BY COMMENTS 3/18/82 DBR Initial complatioa 12~17/94 DBR RWO 02/12/01 12/15I04 BMH JRC ESP Changeout 4-ES (w/ shroud) ESP Chan eout 4-ES w/ shroud 4/25/09 REH ESP Changeout - Nabors 3S 10/10/09 REH ESP Changeout - Nabors 4ES FISH: Junk basket / gauge ring 9 5/8" EZSV Retainer 8,852' md 9 5/8" EZSV Retainer 9,075' md " 9,185' md EZSV Retainer 9 5/8 9-5/8" 47 ppf, L-80, Btrs. g,g02' md MILNE POINT UNIT - WELL C-01 API NO: 50-029-20663 BP EXPLORATION (AK) ~ STATE OF ALASKA ~v~aio7 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Sutamit to: Contractor: Nabors Rig Rep.: G.Sweatt / R.Bjorhus Operator: BP Rep.: D.Rhodes/O. Coyne Field/Unit & Wel! No.: MPC-01 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/3500 Rig No.: 3S DATE: 4/23/2009 Rig Phone: 659-4487 Rig Fax: 659-4486 Op. Phone: 659-4485 Op. Fax: 659-4628 PTD # 1811430 Workover: X Explor.: Weekly: Bi-Weekly Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantrty Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Balt Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13 5/8 5000 P Quantity Test Result Pipe Rams 1 2 7/8 X 5 P No. Valves 13 FP Lower Pipe Rams 0 NA Manual Chokes 1 P Blind Rams 1 Blind P Hydraulic Chokes 1 P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8-21/16" P ACCUMULATOR SYSTEM: Kill Line Valves 1 21 /16" 5000 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3000 P Pressure After Closure 1800 P MUD SYSTEM: V'~sual Test Alarm Test 200 psi Attained 30 sec P Trip Tank P P Full Pressure Attained 2 min 35 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 2050 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 Test Time: 6 Hours Comuonerrts tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Test A ainst 2 Wa Check valve / Test w/ 2 7/8" test ' Choke Valle #2 leaked reased and worked valve tested good. 24 HOUR NOTICE GIVEN YES x NO Waived By Ghuck Sheave Date 04/21/09 Time 7:30 Witness O.Govne/Rick Blot Test start 15:30 Finish BOP Test {for rigs) BFL 11/14/07 ''I~ ~ ~ A~~: ~ `i~ ~~`~`~ ;cr Nabors 3s BOP Test MPG-01 4-23-2009 .xls '\ STATE OF ALASKA ..) E... ~VED ALASKA viL AND GAS CONSERVATION COI\lIN1ISSION ,,-. m< ... .. REPORT OF SUNDRY WELL OPERATIONSJt\N 272005 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 48' 8. Property Designation: ADL 047434 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): Al3~ka & Cons. ChangAfitfuM§e IBI Other 0 Time Extension IBI Repair Well 0 Plug Perforations 0 Stimulate IBI Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 10442 10430 7287 7277 81' 2310' 9775' 4. Current Well Class: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 181-143 6. API Number: 50-029-20663-00-00 99519-6612 9. Well Name and Number: MPC-01 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) 7287',8852',9075',9185' feet Junk (measured) Below Bridge Plug 7287' feet Size MD TVD Burst Collapse 20" 110' 110' 1530 520 13-5/8" 2338' 2338' 4930 2670 9-5/8" 9802' 9791' 6870 4760 5CANN rES {} 22.QQ5 6959' - 7167' 6950' - 7157' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# L-80 6799' Treatment description including volumes used and final pressure: RBDMS BFl JAN 3 1 Z005 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 191 54 0 136 260 Tubinq Pressure 284 260 Oil-Bbl Prior to well operation: 102 Subsequent to operation: 246 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman ~~ (/7~~ ~nature~~ ~~u ';( /'- Form 10-404 Revised 04/2004 Title Technical Assistant 0 rnb \ N~\::o 0' Prepared By Name/Number: Date l-2. ({-(f) Sondra Stewman, 564-4750 Submit Original Only t... TREE: 3-1/8" - 5M, Came' . '''{ree, McEvoy SSV with Baker f ,ltor. WELLHEAD: 13-5/8" 5M FMC w/3.5" FMC tubing hanger, NSCT top and bottom threads, 3.0" CIW BPVT. 110' I ~ 20" 94 ppf H-40 btrs. KOP = none max. hole angle = 7 deg 13-5/8", 72 ppf, L-80 btrs. I 2338' mdl ~ 9-5/8" 47 ppf, L-80, Btrs. casing (cap. = 0.0732 bpf, drift 10 = 8.525") 27/8",6.5 ppf, L-80, EUE 8rd tubing (cap. = 0.0058 bpf, drift = 2.347') Original perforation summary Size SPF Interval open I sqz'd 4" 12 9134' - 9143' squeezed 4" 12 8904' - 8934' squeezed 4" 12 7142' - 7167' open 4" 12 7120' - 7133' open 4" 12 7109' - 7111' squeezed 4" 4 6970' squeezed 4" 4 6959' - 6968' open 12/94 Perforation summary REF LOG: 2/23/82 CBL, 2/5/82 OIL Size SPF Interval open I sqz'd MPU C-01 '- ~ ::. , ---..... -) , '", D . "," ,'t) ) Orig. KB. 1::16V. = 48' (Nabors 17) Orig. GL. Elev. = 28' ) ,I Cameo2718"x1" I 140' I sidepoeket KBMM GLM ~~ '~) ,:: ) : :::::J ~' ) : .::J ,;: ) '- - Cameo 2 718" x 1" slrJepocket KBMM GLM I 2001' I Cameo 2718" x 1" I 3398' I slcepocket KBMM GLM 0 9 5/8" cement divert valve @ 2219'MD , CaMCO 27/8" x 1" I side pocket KBMM GLM 4513' Camco 2 7/8" x 1" sld~poeket KBMM GLM 5038" C3meo 2 7/8" x 1" I s;ce~oeket KBMM GLM 6062' C¡;~;':o 2 7/8" x 1" I sldepoeket KBMM GLM 6558' 27/8" 'XN' npl. I (wi 2.5" no go) Centrilift Tapered ESP wI I 214 stg FC925 and 12 stg. FCNPSH (both GPMTAR 1:1) Centrilift GRSFTX AR H6 tandem gas separator Centrilift 513 series GSB3 I DB UT/L T HL H6 AFLAS/HSN tandem seal section 6,698' 6,739' 6,763' 6,768' Centrilift KMH, 114 hp motor, 2330 v./30 a. 6,782' Centrilift Pump Mate wI 6-fin I 6,793' centralizer '-........ T â5~ solid shroud extends from the seperator intake to 9,13' beiow the centralizer (4123' long, including the shroud head) . 3-3/8" 6 7142' - 7167' open B E 3-3/8" 6 7120' - 7133' open r- 95/8" Baker N-1 bridge 6959' - 6968' open 3-3/8" 6 Co~>I::>€, plug, set 12/94 / C":'ID€, - FI.SH.: 9' toolstring w/ 1-10' 0.092 FISH: Milled out Otis 9 5/8" WD pkr, <::P~;D€, shckhne 4'-3.5" pup, 3.5" Otis 'X' npl, 5'.3.5" pup~ FISH: Milled out Otis "WD" pkr. wI: ' , seal bore extension, 6 1/8" X 31/2" X.o., .".".. .'...'. 95/8" EZSV Retainer I 9,075' md I two 3.5" pup joints, Otis 'X' and 'XN' npls. , . ' '. . 19,185' md I overall length = 23' 9 5/8" EZSV Retainer ~ 9-5/8" 47 ppf, L-80, Btrs. I 9,802' md I I 7287' mdl DATE REV, BY COMMENTS MILNE POINT UNIT 3118/82 DBR Initiai completion WELL C-01 12117/94 DBR RWO 09/08/98 JBF ESP Changeout by Nabors 4ES API NO: 50-029-20663 10/22/00 MOO ESP Changeout I add Shroud 4-es 02/12/01 BMH ESP Changeout 4-ES (wI shroud) BP EXPLORATION (AK) 12/15/04 JRC ESP Changeout 4-ES (wi shroud) '> ) BPEXPLORA TION .Qþ~tijti;pn$Summary ..Rep.ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-01 MPC-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/10/2004 Rig Release: 12/15/2004 Rig Number: Spud Date: 2/4/2001 End: 12/15/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/10/2004 13:00 - 15:00 2.00 MOB P PRE PJSM. RD. Lower & scope down derrick. 15:00 - 17:00 2.00 MOB P PRE Rig down components & prepare for move to MPC-01. 17:00 - 19:00 2.00 MOB P PRE PJSM. Move rig & rig componenets to MPC-01. 19:00 - 20:00 1.00 MOB P PRE Spot rig sub over well. Berm around rig sub. 20:00 - 21 :00 1.00 MOB P PRE Raise derrick. 21 :00 - 22:00 1.00 MOB P PRE Spot in pipe shed & pits. Pits interfering wI adjacent well. 22:00 - 22:30 0.50 MOB P PRE Scope up derrick. 22:30 - 00:00 1.50 RIGU P PRE R/U lines lines to tree. Pull pits back out. Remove Stairs & landing. spot pits back in. 12/11/2004 00:00 - 01 :00 1.00 RIGU P DECOMP RIG ACCEPTED @ 0000 Hrs. Finish removing stairs & landing from pits. Re-spot pits & R/U lines. 01 :00 - 02:30 1.50 RIGU P DECOMP R/U lines to tiger tank.. Take on seawater. 02:30 - 03:00 0.50 WHSUR P DECOMP P/U lubricator & pull BPV. UD lubricator. 03:00 - 04:00 1.00 WHSUR P DECOMP R/U lines to tree & pressure test to 3500 psi, OK. 04:00 - 04:30 0.50 KILL P DECOMP Hold PJSM & Pre-spud meeting wi all hands. 04:30 - 06:00 1.50 KILL P DECOMP Open well. SITP 1600 psi. SICP 540 psi. Bled off tbg & annulus to 60 psi. Pump down tubing & kill well. Pumped 5 BPM. Pressure increased from 200 psi to 500 psi. no returns to surfave after 180 bbls pumped. 06:00 - 08:30 2.50 KILL P DECOMP Continue to circulate hot seawater down tubing @ 5 bpm I 800 psi, taking returns thru choke to tiger tank, seeing very gassy oil in returns. WI 750 bbls pumped, still heavily gassified oil returns. @ 750 bbls pumped start seeing some sewater in returns. Bring pump rate up to 6 bpm I 1300 psi and pump 850 bbls total. Bullhead 30 bbls down tubing. 08:30 - 09:00 0.50 KILL P DECOMP Monitor well. Tubing & IIA on vacuum. 09:00 . 09:30 0.50 WHSUR P DECOMP Set two way check valve. 09:30 - 11 :00 1.50 WHSUR P DECOMP PJSM. NID wellhead. 11 :00 - 13:00 2.00 BOPSUP P DECOMP PJSM. N/U 13 5/8" x 5M BOPE. 13:00 - 17:00 4.00 BOPSUP P DECOMP PJSM. Conduct full test on BOPE & choke manifold @ 250 I 3500 psi. Witnessing of test waived by AOGCC State rep John Crisp. 17:00 - 17:30 0.50 WHSUR P DECOMP P/U lubricator & pull TWC. UD lubricator 17:30 - 20:30 3.00 WHSUR P DECOMP Attempt to BOLDS. 3 screws were frozen. Heat wellhead & spray wI penetrating oil. Con't to work screws free. got 2 screws out 41/2+" Last out about 4". 20:30 - 21 :30 1.00 PULL P DECOMP P/U & pull hanger. Hanger came free wI 58K. Pulled hanger to floor. Unplug ESP cable & meg same. UD hanger & landing jt. 21 :30 - 00:00 2.50 PULL P DECOMP POOH & stand back 2 7/8" tubing. Joint connections are tight. 12/12/2004 00:00 - 03:30 3.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" tubing. 2nd GLM @ 4025' needs to be replaced due to damage on lower pup jt of assy. Recovered 117 LaSalle Clamps, 2 Protectolizers & 10 Flat guards. 03:30 - 07:00 3.50 PULL P DECOMP Inspect, break out & UD ESP & shroud. Both pumps locked up. ESP cable has gas damage UD pump & motor. 07:00 - 08:30 1.50 CLEAN P DECOMP Clear I clean rig floor. Load scraper BHA. 08:30 - 09:30 1.00 CLEAN P DECOMP PJSM. P/U bit, scraper, bit sub, bumper sub, oil jars & (6) 4 3/4" drill collars. 09:30 - 13:00 3.50 CLEAN P DECOMP PJSM. RIH wi cleanout BHA on 31/2" DP 1 x 1. 151 jts total to 5002' DPM. 13:00 - 14:00 1.00 CLEAN P DECOMP PJSM. Attempt to fill hole, (100 bbls), no fill. POOH & stand back DP, triple displacement. 14:00 - 15:00 1.00 CLEAN P DECOMP PJSM. UD BHA. Printed: 12/16/2004 3:59:48 PM \) -----Ii ) BPEXPLORA TION Ç1ä)~~ÇÎ~løl1$$ummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-01 MPC-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code NPT Phase 12/12/2004 15:00 - 17:00 2.00 CLEAN P DECOMP 17:00 - 20:00 20:00 - 22:30 3.00 CLEAN P 2.50 CLEAN P DECOMP DECOMP 22:30 - 23:00 0.50 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 12/13/2004 00:00 - 00:30 0.50 CLEAN N DFAL DECOMP 00:30 - 02:00 1.50 CLEAN N DFAL DECOMP 02:00 - 03:00 1.00 CLEAN N DFAL DECOMP 03:00 - 04:30 1.50 CLEAN N DFAL DECOMP 04:30 - 07:00 2.50 CLEAN N DFAL DECOMP 07:00 - 08:00 1.00 DHB N DFAL DECOMP 08:00 - 10:30 2.50 DHB N DFAL DECOMP 10:30 - 12:00 1.50 DHB DFAL DECOMP N 12:00 - 13:30 1.50 DHB DECOMP P 13:30 - 16:00 2.50 BOPSUP P DECOMP 16:00 - 18:00 2.00 WHSUR P DECOMP 18:00 - 19:30 1.50 WHSUR P DECOMP 19:30 - 20:30 1.00 BOPSUR P DECOMP 20:30 - 21 :30 1.00 BOPSUR P DECOMP 21 :30 - 22:00 0.50 DHEQP P DECOMP 22:30 - 23:00 0.50 DHEQP P DECOMP 23:00 - 00:00 1.00 DHEQP P DECOMP 12/14/2004 00:00 - 03:30 3,50 DHEQP P DECOMP 03:30 - 04:30 1.00 DHEQP N DFAL DECOMP 04:30 - 10:00 5.50 DHEQP N DFAL DECOMP 10:00 - 11 :00 1.00 DHEQP N DFAL DECOMP Start: 12/10/2004 Rig Release: 12/15/2004 Rig Number: Spud Date: 2/4/2001 End: 12/15/2004 Description of Operations Clear & clean rig floor. Shoot fluid level in 9 518" fA. Static fluid level @ 1500'. P/U RBP & TIH. to 4941'. Space out & Set RBP @ 4941' wi 20K. P/U & S/O 83K. Pull 2 stands. attempt to fill hole & test. Pump 316 bbls of seawater to fill hole & lines. Closed in well. Attempt to test, pumped up @ 3 BPM wI 250 psi. RIH 2 stands latch up on RBP & unset same. allow to equalize. POOH wI RBP. Con't to POOH to 2100'. Set RBP @ 2095' w/20K. Wait on seawater. Clear & clean rig floor. UD elephant trunk. Drain line. Take on seawater & attempt to fill hole. Pumped 170 bbls wlo filling hole. Unset RBP & equalize. POOH & inspect RBP. No damage to RBP. Rubbers 100%. Run back inhole wi RBP to 1000'. Fill hole. Hole not full after pumping (100) bbls. PJSM. Stack all weight on Halliburton RBP. Fill hole, OK. Close pipe rams & pressure up 31/2" x 95/8" annulkus to 2000 psi, holding solid. Bleed pressure & Release from RBP. Fill hole, OK. Close annular preventor & pressure up to 2000 psi as before, holding solid. Bleed pressure & relatch bridge plug & release same. PJSM. Break off circ head & RIH wi Halliburton RBP on 31/2" DP. 50 stnds total. 80K up wt, 80K down. PJSM. Set RBP @ 4951' DPM & release from same. P/U 5' & attempt to fill hole. 220 bbls pumped & observe fluid falling in 9 5/8". Stack out 40K on RBP & fill hole wi 5 bbls. Close pipe rams & test @ 2000 psi, holding solid. Release from RBP & pick up 5'. Close annular preventor & Pressure test against RBP @ 2500 psi I 20 minutes, charted, solid test. PJSM. Pull 3 stands, M/U Halliburton Storm Packer & RIH 5 - 10' below wellhead & set. Release from Storm Packer & UD DP. Close blind rams & test @ 1000 psi I 15 minutes, chjarted, solid test. Bleed off pressure. PJSM. NID BOPE. N/D old tubing spool. Replace OA 3" valve. N/U new Tubing spool & finish installing OA valve. N/U BOPE. Install test plug & perform body test on BOP. LP 250 psi, HP 3500 psi. RID test equip. Pull test plug. Drain BOP stack. Install wear bushing. P/U DP, RIH, unset & pull storm packer. UD storm packer. RIH wI RBP retreiving 2 stands. Latch on to RBP, Unset & push down 10'. Con't to RIH wi retreiving tool to recover RBP. POH & UD 3 1/2" DP & 4 3/4" DCs. RBP was not on retreiving tool. M/U retreiving tool for 27/8" tubing. R/U tubing tools. RIH wI retreiving tool on 27/8" tbg, running stands out of the derrick, going in hole slowly so as not to spud out on the bridge plug. RIH picking up single out of the pipeshed. 228 jts 2 7/8" tbg Printed: 12/16/2004 3:59:48 PM ) -) BPEXPLOBATION ()Peràt.i.pg§:~QmP:aary Report Page 3 ot~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-01 MPC-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/10/2004 Rig Release: 12/15/2004 Rig Number: Spud Date: 2/4/2001 End: 12/15/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/14/2004 10:00 - 11 :00 1.00 DHEOP N DFAL DECOMP picked up plus 15' of 229. 11 :00 - 11 :30 0.50 DHEQP N DFAL DECOMP With retrieving tool @ 7082', opt to check for bridge plug prior to entering perfs. 46K up st, 46K down. Pick up & rotate to the left using chain tongs, (2) rotations. Slack off & take weight. Pick up & rotate to the right. 11 :30 - 14:30 3.00 DHEOP N DFAL DECOMP PJSM wI regard to POOH wi RBP. POOH & lay down 28 singles, stand back (25) stands. Perform funciton test of RBP, (still there). Continue to POOH. 14:30 - 15:30 1.00 DHEOP P DECOMP PJSM. Break out & lay down Halliburton Retrievable Bridge Plug. 15:30 - 17:00 1.50 RUNCOMP RUNCMP Clear I Clean rig floor. Prep to pick up ESP assembly. 17:00 - 21 :00 4.00 RUNCOMP RUNCMP P/U and service ESP Pump and Motor. Install ESP assembly into shroud. Shroud anchor had to be modified to allow shroud to mate up to the anchor bolts. 21 :00 - 00:00 3.00 RUNCOMP RUNCMP RIH ESP assembly on 2-7/8",6.5#, L-80, EUE 8RD tubing from Derrick, 7-GLMs from Pipe Shed, 12/15/2004 00:00 - 04:00 4.00 RUNCOMP RUNCMP PJSM. RIH wI ESP assembly on 27/8",6.5#, L-80, EUE 8 rnd tbg. checking conductivity of cable and breaking circulation @ 2 bpm I 100 psi every 2000'. 04:00 - 05:00 1.00 RUNCOMP RUNCMP M/U Headpin and Landing Jt to Tbg hanger. Make field connection. Plug into penetrator & test connection. Land hanger. 05:00 - 06:00 1.00 RUNCOrvP RUNCMP Land and test Tubing Hanger. P/U 56K, SIO 56K. 06:00 - 06:30 0.50 RUNCOMP RUNCMP PJSM. LID landing joint. Set & test two way check valve. 06:30 - 07:30 1.00 BOPSUPP RUNCMP PJSM. N/D BOPE. 07:30 - 10:00 2.50 WHSUR P RUNCMP PJSM. N/U tree. Test tree & void to 5000 psi, OK. Make final check on ESP cable, OK. 10:00 - 11 :00 1.00 WHSUR P RUNCMP P/U lubricator. Pull 2 way check, set BPV. Secure well. Rig released @ 11 :00 hrs, 12/15/2004. Printed: 12/16/2004 3:59:48 PM ) ) BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 ~> . -~.,~, :ti.-,l¡~?:../ '~..',' . /yW"\ ~ ,~ .$ì¡;;;.....,...., .;$¡> . '~'.. .' ~\ Ai ,.., ,:~. ~~¿J!!\,">!~ VV""!f .. December 20,2004 RECEIVED DEC 2 1 2004 Alaska Oi\ & Gas Cons. Commission Anchorage Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: MPC-01 i (PTD 1811430) Application to cancel Sundry #304-060 Dear Mr. Aubert: Attached is Application to Cancel Sundry form 10-404 for Sundry #304-060. This request is to cancel the current sundry for permission to gas-lift Milne Point production well MPC-01 with a packerless completion (failed ESP). The well has recently been worked over and new ESP run on 12/15/04. Start-up of the new ESP is expected to take place within the next seven days. If you require any additional information or clarification, please contact me at 564-4660 or John Cubbon at (907) 670-3387. Sincerely, "'7 ~. ~ ~.. .1/ ¿/ ~( ...o-z---<-- Mark Sauve Milne Point Production Coordinator Attachment: 1) Application for Sundry Cancellation form 10-404 SCANNED DEC 2 7 2004 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): , ~ECEIVED ) STATE OF ALASKA) DEC 21 2004 ALASKA OIL AND GAS CONSERVATION COMMISSION I REPORT OF SUNDRY WELL OPERATIO~kaOjl&GasCons.colllllisl Anchor~fJe 1. Operations Performed: Abandon 0 Repair Well 0 PluQ PerforationsD Stimulate 0 OtherŒJ Cancel Sundry Alter CasingD Pull TubingO Perforate New PoolD WaiverD Time ExtensionO Change Approved ProgramD Operation ShutdownO Perforate D Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: Development [!] ExploratoryD 181-1430 6. API Number 50-029-20663-00-00 Stratigraphic D 9. Well Name and Number: MPC-01 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool Service D 48.00 8. Property Designation: ADL-047434 11. Present Well Condition Summary: Total Depth measured 10442 feet true vertical 10430.2 feet Plugs (measured) 7287 Effective Depth measured 7287 feet true vertical 7276.9 feet Junk (measured) 7614, 7601, 7582, 7423 Casing Conductor Production Surface Length 81 9775 2310 Size 20" 94# H-40 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD 29 - 110 29.0 110.0 27 - 9802 27.0 - 9790.5 28 - 2338 28.0 - 2337.9 Burst 1530 6870 4930 Collapse 520 4760 2670 Perforation deDth: Measured depth: 6959 - 6968, 7120 -7133, 7142 -7167 True vertical depth: 6949.51 - 6958.48, 7110.08 - 7123.06, 7132.05 - 7157.01 Tubing (size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 34 6739 Packers & SSSV (type & measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 13 Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: Copies of Logs and Surveys run - Daily Report of Well Operations. ~ 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: Oil[!] GasD DevelopmentŒ) ServiceD 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve .--\ Signature /0~ _d4~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-060 Title Milne Point Production Coordinator Phone 564-4660 Date 12/20/04 RBDMS 8FL DEC 2 2 2DD4 Form 10-404 Revised 4/2004 ~~~;~;i~~ ~1~B~~:~~,_)~~1 WELLHEAO:13~5/8". 5M FMC w/35~FMC tubing' hanger, NSCT. top and bottôiTl threads; 3~O" CIWBPVT. 110'1 . 20" 94 ppf H-40 btrs. KOP = none max. hole angle = 7 deg 13.SI8",72ppf, l.J¡O btrs. 12338' mdl j 9-5/8" 47 ppf, L-80, Btrs. casing (cap. = 0.0732 bpf, drift 10 = 8.525") 27/8",6.5 ppf, L-80, EUE 8rd tubing (cap. = 0.0058 bpf, drift = 2.347") Orig inalperforation summary Size SPF Interval open / sqz'd 4" squeezed squeezed open open squeezed squeezed open 4" 12 12 12 12 12 4 4 9134' - 9143' 8904' - 8934' 7142' - 7167' 7120' -7133' 7109' - 7111' 6970' 6959' - 6968' 4" 4" 4" 4" 4" 12/94 Perforation summary REFLOG: 2/23/82GBL, 2/5182 DIL Size SPF Interval open/ sqz'd MPU C-01 !ill ) Orig.KB.E:lev.= 48' (Nabors 17) Orig~GLElev. = 28' . k Camco27/8"x1" I 140' I sidepoeket KBMM GLM Cameo 2 7/8" x 1" sidepoeket KBMM GLM I 2001' I Cameo 2 7/8" x 1" I 3398' I sidepoeket KBMM GLM II 9 5/8" cement divert valve @ 2219'MD , eameo 2 7/8" x 1" I sidepoeket KBMM GLM 4513' Cameo 2 7/8" x 1" I sidepocket KBMM GLM 5038" Cameo 2 7/8" x 1" I sidepocket KBMM GLM 6062' Cameo 2 7/8" x 1" I sidepocket KBMM GLM 6558' 27/8" 'XN' npl. I (wi 2.5" no go) Centrilift Tapered ESP wI I 214 stg FC925 and 12 stg. FCNPSH (both GPMTAR 1:1) Centrilift GRSFTX AR H6 I tandem gas separator Centrìlift 513 series GSB3 I OB UT/L T HL H6 AFLAS/HSN tandem seal section 6,698' 6,739' 6,763' 6,768' Centrilift KMH, 114 hp motor, 2330 v./30 a. 6,782' Centrilift Pump Mate wi 6-fin 1 6,793' centralizer 7" 26# solid shroud extends from the seperator intake to 9.13' below the centralizer (41.23' long, including the shroud head) , 3-3/8" 6 7142' - 7167' open B ~ 3-3/8" 6 7120' - 7133' open 95/8" Baker N-1 bridge 6959' - 6968' open 3-3/8" 6 @3\}iliE>(t plug, set 12/94 / @['jTiliE>(t-FI.SH.: 9' toolstring w/1-10' 0.092 FISH: Milled out Otis 9 5/8" WO pkr, <RcïSi«>(t sllckhne r~'~~E::~~~~~~X';:~ i;':';~~~P/S~~:- :::~ ~::b::~:~e:auge 1'::S2' md I FISH: Milled out Otis "WOn pkr. wi: 9 £1 seal bore extension, 61/8" X 31/2" X.o., r., . A 95/8" EZSV Retainer 19,075' md 1 two 3.5" pup joints, Otis 'X' and 'XN' npls. 19 185' md I overall length = 23' 9 5/8" EZSV Retainer ' ~ ~ 9-5/8" 47 ppf, L-80, Btrs. 1 9,802' md 1 I 7287' mdl DATE REV. BY COMMENTS MILNE POINT UNIT 3/18/82 OBR Initial completion WELL C-01 12/17/94 OBR RWO 09/08/98 JBF ESP Changeout by Nabors 4ES API NO: 50-029-20663 10/22/00 MOO ESP Changeout I add Shroud 4-es 02/12/01 BMH ESP Changeout 4-ES (wi shroud) BP EXPLORATION (AK) 12/15/04 JRC ESP Changeout 4-ES (wi shroud) FW: MPC-01--181-143 Subject: FW: MPC-01--181-143 From: "Hubble, Teme L" <HubbleTL@BP.com> Date: Wed, 03 Mar 2004 15:36:38 -0900 To: tom_maunder@admin.state.ak.us Hi Tom, I have printed the Daily Drilling Reports for these 6 days that this RWO was performed in 2000 and will be sending them in an envelope over to you tomorrow (2 sets). I am unable to get you a Drilling Summary for this period of time, so hopefully the complete Daily Reports will be acceptable. Terrie -----Original Message----- From: Pratt, DeWayne E (Landmark) Sent: Tuesday, March 02, 2004 8:51 AM To: Hubble, Terrie L Subject: RE: MPC-01--181-143 Terrie, Short version; There are reports I just put into the web Historic Reports area. You'll actually see two for the 16th - 19th, I can't delete them. It's lost in DIMS and there will be no data in DIMS unless someone re-enters it. Longer version: This was before all the rigs worked on the same (Oracle) database in PBOC, what's know as Ora Anchorage DIMS. This was actually before I came over here. The rig had their own Access databases and were required to transfer data files into the main database in Anchorage, also know as Ora Anchorage DIMS at the time... It just got moved to PBOC and never was renamed. The computers on 4ES I know for a fact have changed at least twice, so rescuing the data is most likely a mute point. I did however by stroke of pure luck find some reports, that were backed up of that well, and placed them under the Historic Reports location. DeWayne -----Original Message----- From: Hubble, Terrie L Sent: Monday, March 01, 2004 3:20 PM To: Pratt, DeWayne E (Landmark) Subject: FW: MPC-01--181-143 Hi DeWayne, Apparently there are some missing reports for this well for a October 2000 workover. I have checked Dims and they are there from 10/16 to 10/18/00, but this well wasn't released until 10/21/00. Any ideas on where the missing days are? Terrie -----Original Message----- From: Hubble, Terrie L Sent: Monday, March 01, 2004 3:09 PM To: 'Thomas Maunder' lof3 3/4/2004 12:27 PM FW: MPC-01--181-143 Subject: RE: MPC-Ol--lSl-143 Hmmm.... I have printed it again from Dims, but you are correct there are only three days there and there should be 6 days. I'll have to do some more digging. Terrie -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] S en t: Monda y, Ma r c h 0 1 ~"'-'2Õ-04--'2"'-;-'55--PM'-"--'---""--'-"""""""'-''''''''...............................................--..-........... To: Hubble, Terrie L Subject: Re: MPC-Ol--lSl-143 Terrie, Sorry to bother you again. The report you sent for 2/04/01 to 2/11/01 is just fine, but I still don't have a complete report for the work that started 10/16/00. Could you send that as well?? An email would be fine if that works for you. Tom Thomas Maunder wrote: Got it. Thomas Maunder wrote: Hi Terrie, I will check. don't mind my files for one it only makes Thanks much for sending the summary over. Hope you requesting messages. It is just as I go through the thing or another, if I find something missing I think sense to get the correct information there. It is just a matter of having the "knowing" eyeballs look over the report. Take care, Tom Hubble, Terrie L wrote: Hi Tom, I looked this well up and found that Nabors 4ES worked on the well from 02/04/01 to 02/11/01. I sent you two copies of this summary just before lunch today. I'm guessing we must have had a computer glitch at the time this report was done, because the Operations Summary Report printed just fine today. Did you get it yet? If you need anything else, just let me know. Sorry for the incomplete data. Terrie -----Original Message----- From: Thomas Maunder [mai.lto:torn rna.under@adrnin.sta.te.a.k.u.s] S en t: Fr i da y , F ebruary"""2"7'''~'''''''''2''Õ'Õ'4''''''7'';'''5''4''''''AM''''''''''''''''''''''''"'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' To: Hubble, Terrie L; Stewman, Sondra D Subject: MPC-Ol--lSl-143 Terrie and Sondra, I am not sure which of you would handle this question. I have a new sundry from John Cubbon and Mark Sauve at Milne for this well. I was looking in the file. According to John/Mark the last work on 20f3 3/4/2004 12:27 PM FW: MPC-01--181-143 the well was to replace a failed ESP in February 2001. In the file, I have found 2 404s with the same incomplete attachment. The initial 404 was submitted 11/1/2000 for an ESP replacement started 10/16/2000. The 2nd 404 was submitted 2/26/01. Both 404s have the same 2 days of 4ES work attached. The well work report is not complete. In comparing the 404 sheets, the most recent includes information on squeezed perforations but I could not find any other difference. Could you please check your files for MPC-01 and send the complete work summary for the workover started 10/16/2000?? Has there been any other ESP workover since then?? Thanks in advance for your help on this. Tom Maunder, PE AOGCC 30f3 3/4/2004 12:27 PM RE: MPC-01 (PTD #1811430) 10-403 .lication to pr... e Subject: RE: MPC-01 (PTD #1811430) 10-403 application to produce ESP completion with gas lift From: "MPU, Wells Ops Coord" <MPUWellsOpsCoord@BP.com> Date: Fri, 27 Feb 2004 13:58:31 -0900 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> CC: "Sauve, Mark A" <mark.sauve@BP.com>, "MPU, Well Operations Supervisor" <welloperationssupervisor@BP.com> Tom, Looking back on the drilling reports it was noted the lock down screws were extremely difficult to screw out and in. Not much detail on the morning report. I'm researching a well head report from FMC. The well head tested good after it was landed and I'm sure that's when it was noted on the diagram. We sometime use the diagram to remind us of issues to handle on the next work over, it just raises a flag. I'll continue to search for the FMC report, If they are unable to come with a report I'll have them retest the hanger and inspect the lock down screws. I will get back to you with the original report or after the inspection. As for our gas lift capability, B&C pads are our only two pads with lift gas. We only have a handful of wells on gas due to our plants limitations. Mark O'Malley ACT! MPU Well Ops Coord. Office: 670-3387 Cell: 659-0560 e-mail: omallemd@bp.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, February 27, 2004 7:33 AM To: MPU, Wells Ops Coord Cc: Sauve, Mark A Subject: Re: MPC-01 (PTD #1811430) 10-403 application to produce ESP completion with gas lift John and Mark, I am looking at lift. On the drawing tubing spool. bent/twisted?? the MPC-01 sundry with regard to producing on gas it is noted that the lockdown screws are bad on the What is IIbadll?? Are there any leaks or are they On a larger scale, where in the field can you employ gas lift?? As I understand, there are few gas lift capable pads. 10f2 2/27/2004 2:58 PM RE: MPC-01 (PTD #1811430) 10-403 ilication to pr... e Thanks, Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Hi Tom, Attached is our sundry application for the conversion of MPC-01 from ESP production to gas lift. A hard copy will be mailed to you later today. If you have any questions, please contact Mark Sauve. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 «Sundry Cover MPC-01 02-21-04.doc» «MPC-01 (2-24-04) Waiver. ZIP» «MPC-01 10-403 Discussion 02-21-04.doc» «MPC-01 2-12-01.ZIP» 2 of2 2/27/20042:58 PM ) ) bp o / BP Exploration (Alaska) Inc. Post Office Box 196612 Mail Stop MB-4-2 Anchorage, Alaska 99519-6612 February 23, 2004 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: MPC-01 (prO 1811430) Request for permission to produce ESP completion with gas lift. Dear Mr. Maunder: Attached is an Application for Sundry Approval form 10-403 outlining our request to produce MPC-01 with gas lift. A des~ription summary of the proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact Mark Sauve (907) 564-4660. sincer~ t.{!CUbbon Well Operations Coordinator ~~CA,NNEO JUL 1 2 2.0D5 Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Well bore Schematic RE'CEl\/£~.[) FEB 2 6 2004 A'a~kô Oil & Ga" C ..... C . . , ~ on~. ()rrmis~'cn Arrchon1fF~ ~tANNEr" W~AR 1 5 2004 o q , h 1 t\I A l~ ' ) STATE OF ALASKA ) ALASKA OIL.. AND GAS CONSERVATION COMMISSJO~ ' APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 kJ 1~'1 07S <2' /2% R 1. Type of Request: Suspend 0 RepairWell 0 Pull Tubing 0 Operation Shutdown 0 Plu¡; Perforations 0 Perforate New Pool D 4. Current Well Class: Development ŒI PerforateD WaiverŒ} StimulateD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Nu~: 181-1430 " Annular DisposalD OtherD Abandon D Alter Casin: 0 Change Approved Program 0 2. Operator Name: BP Exploration (Alaska), Inc. Exploratory 0 6. API Number / 50-029-20663-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 48.00 KB 8. Property Designation: ADL-047434 3. Address: 11. Total Depth MD (ft): . / 10442 v Casing StratigraphicD Service 0 9. Well Name and Number: M PC-01 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Total Depth 1VD (ft): Effective Depth MD (ft): Effective Depth 1VD (ft): 10430.2 7624 7565.8 Size MD TVD Plugs (md): 7287 Burst Junk (md): See Attachment COllapse Length Conductor 81 Production 9775 Surface 2310 Perforation Depth MD (ft): I 6959 - 6968 7120 - 7133 7142 - 7167 Packers and SSSV Type: 9-5/8" DV Packer 12. Attachments: Description Summary of Proposal D Detailed Operations Program D BOP Sketch D top bottom top bottom 20" 94# H·40 29 110 29.0 110.0 1530 520 9-5/8" 47# L-80 27 9802 27.0 9790.5 6870 4760 13-3/8" 72# L-80 28 2338 28.0 2337.9 4930 2670 Perforation Depth 1VD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6950 6958.5 2.875 .. 6.5 # L-80 24 6698 7110 7123.1 7 .. 26 # L-80 6698 6771 7132 7157.0 Packers and SSSV MD (ft): 2219 13. Well Class after proposed work: ExploratoryD Development[&J ServiceD 14. Estimated Date for Commencing Operation_: ". 16. Verbal Approval: Commission Representative: Date: 15. Well Status after proposed work: Oil[[l GasD PluggedD AbandonedD WAG 0 GINJD WINJD WDSPLD ' Prepared by Garry Catron 564-4657. February 24, 2004 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Cubbon Printed Name Signature I ~~ubbon . ~~;W.., r Title Phone MPU Well Operations Coordinator 670-3387 2/23/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ "9 r7I- L:J ¿, tJ Mechanciallntegrity Test D Location Clearance 0 S; ~o.'l'ox ~"<2::.~~ Appro BY ORDER OF THE COMMISSION Dare: ~, ~d IØ)MS Bfl ~~~ {) ?O~~ :'" ,:i:~~~)~I.~~~I~.' c3'; i'~" _1\\))2 ~_I ORIGINAL Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE ) ) MPC..01 Description Summary of Proposal 02/23/04 This application for Sundry approval for well MPC-O 1 (PTD 1811430) is to document that the AOGCC and BP concur the well may be produced with gaslift due to a failed Electric Submersible Pump (ESP). A new ESP was installed in the well dwing a workover in February 2001. The ESP then failed in January 2003. Due to the configuration of the completion, the well does not have an isolãtion packer between the tubing and annulus. The current plans for MPC-O 1 include producing with conventional gas lift, injecting gas into the inner annulus and producing up the tubing using the gas lift mandrels located in the tubing string at 4025' and 6545' MD. All produced fluids will enter the tubing through the inactive pump. The applied gaslift will prevent annular flow of produced liquids. The well is equipped with a wellhead Safety Valve System as per AOGCC regulations. Recent well test data shows the following results: Date BOPD BWPD MCFPD lAP (psi) GLG (MCFD) 12/31/03 405 99 340 1137 745 02/ 10/04 353 83 478 1275 773 As per this request, BP is requesting pennission to continue to produce the MPC-O 1 well with gas Ii ft. - 9518" Baker N-1 bridge c:::!L::::>.sg plug, set 12/94 / ~~-FISH: 9' toolstring w/1-10' 0.092 FISH: Miled out Otis 95/8" WO pkr, ~Jd slickline 4'-3.5" pup, 3.5" Otis 'X' npl, 5'-3.5" puP,~ ~ 3.5" 'XN', 3.5" WLEG. Top is at 7423 MD. ~~- FISH: Junk basket / gauge ring Ref. 12/94 RWO X ~ 9 5IS" EZSV Retainer IS,s52' md I FISH: Miled out Otis "WO" pkr. wI: seal bore extension, 6 1/S" X 31/2" x.o., '. 9 5IS" EZSV Retainer 19,075' md I two 3.5" pup joints, Otis 'X' and 'XN' npls. 19,185' md I overalllangth = 23' 9 5/8" EZSV Retainer ~ ~ 9-5/8" 47 ppf, l-80, Btrs. I 9,802' md I TREE: 31/8" - 5M WKM WELLHEAD: 13-5/8" 5M FMC (Gen 2) wI 3.5" FMC Tubing Hanger, NSCT top and bottom threads, 3.0" CIW 'H' BPV profile. and x.o. to 27/8" EUE 8 rd. ~ 20· 94 ppf H-40 btrs. 110' I KOP = none max. hole angle = 7 deg 13"5/S", 72 ppf, L-80 bbs. 2338'md J 9-5/8" 47 ppf, L-80, Btrs. casing (cap, = 0.0732 bpf, drift ID = 8.525") 2 7/8", 6.5 ppf, L-BO, EUE 8rd tubing (cap. = 0.0058 bpf, drift = 2.347") Note: 9 oversized lasalle clamps were mistakenly run on top stands of compo Decided to place two good clam ps just below the lower pigtail. Original perforation summary Size SPF Interval open I sqz'd 4" 12 9134' - 9143' squeezed 4" 12 8904' - 8934' squeezed 4" 12 7142' -7167' open 4" 12 7120'·7133' open 4" 12 7109'·7111' squeezed 4" 4 6970' squeezed 4" 4 6959' - 6968' open 12/94 Perforation sum mary REF LOG: 2/23/82 CBl, 2/5/82 DIL Size SPF Interval open I sqz'd 3-3(8" 3-3/8" 6 6 6 7142' - 7167' 7120' - 7133' 6959' - 6968' open open open 3-3/8" ) MPU C-01 1 l' I ~, :1) ï F t ., Orig. KB. Elev. = 48' (Nabors 17) Orig. GL. Elev. = 28' Cameo 2 7/8" x 1" I 140' I sidepoeket KBMM GLM , ' o 9 518" cement divert valve @ 2219'MD o B , Cameo 2 7/8" x 1" I sidepocket KBMM GLM 4.025' Note: Next RWO the tubing spool will need to be changed out. Bad Lockdown screws. 02/11/01 Cameo 2 718" x 1" sidepoeket KBMM GLM 6,545' -.......... 27/8" 'XN' npl. 6,684' (wi 2.5" no go) Centrillft Tapered ESP wi I 6,698' 122 stg GC2200 and 16 5t9. GCNPSH (both GPMTAR 1:1) Centrilift GRSXTBARH6 6,727' d\~' tandem gas separator Centrllift 513 series GSB3 I DB UT/l T HL AFlASIHSN 6,732' tandem seal sections Centrilift KMH, 171 hp 6,745' motor, 2390 v. /44 a. Centrilift PHD wIG-fin 6,761' I' ..... centralizer -............ 7" 26# solid shroud extends from the sep intake to 10' below the PHD (37' long) [ I 7287' md DATE REV. BY COMMENTS MILNE POINT UNIT 3/18/82 OBR Initial completion WELL C-01 12/17/94 DBR RWO API NO: 50-029-20663 09/08198 JBF ESP Changeout by Nabors 4ES 10/22/00 MDO ESP Changeout 1 add Shroud 4-es BP EXPLORATION (AK) 02/12/01 BMH ESP Changeout 4-ES (w/ shroud) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, ~/~,~~ P. I. Supervisor~'~ DATE: May 19, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne point Unit C Pad MaY 19. 2001: I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12198 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy Supplement, I told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells ~4,6 & 14 were shut in for repairs. .S,..,U.MMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-GONFIDENT!AL SVS MPU C Pad 5-19-01jc Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Milne Point Unit C Pad Separator psi: LPS 140 HPS 5a9/o~ Weg Pemit Separ Set ~ Test Test T~t Date o~ WA~, Number Number PS! PSI Trip ~, Code Code. Code Passed, G~ ~r,~VCLr , C-01 i811430 140 "100: 110 P P OiL' C-02 1821940 C-03 ' 1820500 '140 '100 ' ' '95 P ~ ...... 0IL C-04 1821260 140 100 110 P 4 OIL C'~05A 1842'430:'" 140 100 " 100 P P .......... 0IL C-0'6 .... i'84241"0 ..... 43'00 ' 2~0 'i950 p 4 ..... WAG C-07 ' 1850020 'i40 i00 ' 95 P 4 OIL ~-08 .... 1850140 '4300 2006 1900 'P ~ ...... WAG ,c.09 ' ~8503~0 ...... ~40 i'00 "' ~05e e........ oi~ ~C_~3 i85'6~70 .......... c-i4 1850880 ' 140 ' 100 100 P 4 ' 'OIL C-15 1851030 C-17 1852630 C.20 ' 189,0i50 .............. c-21 1940800 c-22A' ' 1951980 140 100 '95 P P .... ' ...... 0IL c-23 1960160~ C-25A 1960210~ 4300 2000 "1900 P 4 ' ' ' W~G c-26 1952060 C-:8 ~9'~0:~ ' :c-3~ ~9800i0 C-39 1972480 C-40 2002130 C-10 1850150 4300 2000 1850 P P ....... WAG Wells: 12 Components: 24 Failures: 6 Failure Rate: 25.00~[~] ,90Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc STATE Of ALASKA ALASK/ '~..'" AND GAS CONSERVATION COMk )~ION' REPORT OF SUNDRY WELL OPERATIONS 1. bPerafic~ns'perfo~ed: i-i operation Sl~utdown "' I-I' sti'muiate ........... i-i Piuggi'ng i-:1 Perforate ................................................. lla Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name 'of Operator ................. 5. Ty'~e' of well:' ' ~ 6. Datum Elevation (DF or KB)"' BP Exploration (Alaska) Inc. [] Development KBE = 48' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1168' NSL, 2256' WEL, SEC. 10, T13N, R10E, UM MPC-01 At top of productive'interval 9. Permit Number / Approval No. 181-143 958' NSL, 2168' WEL, SEC. 10, T13N, R10E, UM 10. APl Number At effective depth 50- 029-20663-00 932' NSL, 2167' WEL, SEC. 10, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 947' NSL, 2268' WEL, SEC. 10, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 10442 feet Plugs (measured) EZSV Retainers set at 8852', 9075' & 9185' true vertical 10430 feet Bridge Plug at 7287' Effective depth: measured 7287 feet Junk (measured) Multiple fish below 9-5/8" Baker N-1 Bridge Plug at 7287' true vertical 7277 feet (12/94) Casing Length Size Cemented MD TVD Structural Conductor 80' 16" To Surface 115' 115' Surface 2302' 13-3/8" 3800 sx AS II 2338' 2338' Intermediate Production 9768' 9-5/8" 2000 sx Class 'G', 150 sx AS I 9802' 9791' Liner Perforation depth: measured Open: 6959' - 6968', 7120' - 7133', 7142' - 7167' Sqzd: 8904'-8934', 9134'-9143' FE~ 2 7 true vertical Open: 6950' - 6958', 7110' - 7123', 7132' - 7157' Sqzd: 8893' - 8923', 9123' - 9132' Alaska Oil 8, Gas Cons. Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 TO 6763' Anchorage Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Ave'rage Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: , 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerdeHubble .~.~_ ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicate~). RECEIVED MAR 0 1 2UÜ4 BP AMOCO Page 1 of 3 AllillCI.Gllc-.fll TTrm Operations Summary Report MlLllJl Legal Well Name: MPC-01 Common- Well Name: MPC-01 Spud Date: 2/4/2001 Event Name: WORKOVER Start: 2/4/2001 End: 2/12/2001 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/11/2001 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/412001 03:00 - 12:00 9.00 CONS P POST MOVE RIG FROM MPF-05--TO MPC-01 & RIG UP SAME. RIG ACCEPT @ 1200 HRS. 2/4/2001 12:00 - 14:00 2.00 KILL P DECaMP RIG UP TO KILL WELL & CLEAN OUT SUCTION LINES IN PITS. 14:00 - 15:00 1.00 KILL P DECOMP RIG LUBRICATOR & PULL BPV. TBG. = 1650 PSI. ANNULUS ==1650 PSI. 15:00 - 16:30 1.50 KILL P DECOMP CONTINUE TO RIG UP TO TIGER TANK & TREE & TAKE ON 9.5 PPG. BRINE & TEST SAME TO 3500 PSI. 16:30 - 18:30 2.00 KILL P DECOMP HAVE WELL KILL MEETING & CIRC INFLUX OUT OF WELL BORE WITH 9.5 PPG. BRINE. SHUT DN & MONITOR TBG. =0 & VACUMN. & ANNULUS FLUIDS OILY & 70 PSI. " 18:30 - 20:00 1.50 KILL P DECOMP CONTINUE TO CIRC TO CLEAN OIL & GAS FROM ANNULAS WELL BORE TAKING 3-BBL. EVERY 5-MINUTES. SHUT DN & MONITOR TBG.==O ANNULUS==SLlGHT BLOW NO FLUID. 20:00 - 21 :00 1.00 WHSUR P DECOMP SET TWC. & TEST TO 3500 PSI. 21 :00 - 22:00 1.00 WHSUR P DECOMP NIPPLE DOWN TREE. 22:00 - 00:00 2.00 BOPSUF P DECOMP NIPPLE UP BOP. 2/5/2001 00:00 - 03:00 3.00 BOPSUF P DECOMP Pressure test bop's bop's to 250 low & 3500 high. test waived by John Crisp wI aogc. 03:00 - 04:00 1.00 BOPSUF P DECaMP rig lubricator & pull twc. ( tbg. vacumn) 04:00 - 06:00 2.00 PULL P DECOMP Make up landing jt. & attempt to pull hanger Note RILDS hard to back out. decision to prepare. 06:00 - 11 :00 5.00 PULL N SFAL DECOMP Circ. well bore & spot salt size pill while working on RILDS. 11 :00 - 13:30 2.50 PULL N DECOMP Back out RILDS except one was unable to back out. 13:30 - 14:00 0.50 BOPSUF N DECOMP back out landing jt. & set twc & test same to 3500 psi. 14:00 - 15:30 1.50 BOPSUF N DECOMP nipple down bop's 15:30 - 16:00 0.50 BOPSUF N DECOMP cut end off of RILDS. 16:00 - 17:30 1.50 BOPSUF N DECOMP nipple up bop & test Fig. break to 3500 psi. 17:30 - 18:00 0.50 BOPSUF N DECOMP Rig lubricator & Pull twc. 18:00 - 18:30 0.50 PULL P DECOMP hold pjsm with crew & BOLDS. 18:30 - 19:00 0.50 PULL P DECOMP pull hanger to floor & lay dn same & test penetrator. 19:00 - 22:00 3.00 PULL P DECOMP eirc. bottoms up & Prepare to pull esp compo 22:00 - 00:00 2.00 PULL P DECOMP pooh with esp compo 2/6/2001 00:00 - 04:30 4.50 PULL P DECOMP pooh with esp completion & lay dn same. 04:30 - 06:00 1.50 FISH P DECOMP clean floor & mu bha # 1 -5/8" os w1-3/4" grapple. 06:00 - 08:30 2.50 FISH P DECOMP rih with same to 6766' 08:30 - 10:30 2.00 FISH P DECOMP circ. bottoms up. 10:30 - 13:30 3.00 FISH P DECOMP circ dn to 6859' & tag prong. (Note: packer top was seen as entering screen)& latch same work pipe to limits was unable to makeany progress on pulling prong release overshot. 13:30 - 16:30 3.00 FISH P DECOMP pooh & lay dn bha # 1 16:30 - 22:00 5.50 FISH X WAIT DECaMP wait on paker milling tools & 3.5" drill pipe & unload same & strap & prep to rih. 22:00 - 23:30 1.50 FISH C DECOMP mu bha #28-1/2" shoe+1-jt. 8-1/8" wash pipe+boot basket+bumpersub+jars+9-6-1/4" dc +xo 23:30 - 00:00 0.50 FISH C DECaMP rih with bha #2 picking 3.5" from shed. 2/7/2001 00:00 - 06:30 6.50 FISH C DECOMP continue to rih with BHA # 2 tag packer @ 6823' 06:30 - 08:30 2.00 FISH C DECOMP eirc bottoms up 08:30 - 19:00 10.50 FISH C DECOMP Mill on Pack 6823' to 6825' Unable to make any forward progress. monitor well bore 1/2 hrs. & prep for trip. 19:00 - 22:30 3.50 FISH C DECOMP POH & lay dn bha #2 (wash over shoe did not show any wear) 22:30 - 23:30 1.00 FISH C DECOMP make up bha # 3 Packer mill +3-boot basket +bumper jars I Printed: 3/1/2004 11 :30:22 AM RECEIVED MAR 0 1 ¿U~~~ BP AMOCO Page 2 of 3 AIIiIIœ&Gllc..~ Operations Summary Report Atdt.,e Legal Well Name: MPC-01 Common Well Name: MPC-01 Spud Date: 2/4/2001 Event Name: WORKOVER Start: 2/4/2001 End: 2/12/2001 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/11/2001 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Code NPT Phase Description of Operations 2/712001 22:30 - 23:30 1.00 FISH C DECaMP +jars+9-dc 23:30 - 00:00 0.50 FISH C DECOMP rih with bha # 3 2/8/2001 00:00 - 01 :00 1.00 FISH C DECaMP rih with packer mill 01 :00 - 02:00 1.00 FISH P DECaMP cut drlg line 02:00 - 05:00 3.00 FISH C DECaMP rih with packer mill to 6823' & tag packer. 05:00 - 07:00 2.00 FISH C DECOMP mill on packer 6823' to 6828' packer fell free & push same to 7018' with singles from shed. 07:00 - 09:00 2.00 FISH C DECaMP eirc bottoms up & monitor well bore 09:00 - 11 :00 2.00 FISH C DECaMP pull out of hole. 11 :00 - 12:30 1.50 FISH C DECaMP lay dn bha #3 12:30 - 13:30 1.00 FISH C DECaMP make up bha # 4 4" spear wI 4.805" grapple & bumper sub +jars+9-dc 13:30 - 15:30 2.00 FISH C DECOMP tih with bha # 4 15:30 - 17:00 1.50 FISH C DECaMP circ bottoms up 17:00 - 18:30 1.50 FISH C DECaMP Attempt to latch fish with spear (unable to get any true signal that fish is latched. ) 18:30 - 21 :30 3.00 FISH C DECOMP pooh with bha # 4 21 :30 - 22:30 1.00 FISH C DECOMP No Recovery lay dn bha No. # 4( Diagnosis of tools were that debri was preventing grapple from getting far enough into fish to allow latcht bull nose had indication that it was getting a 3.5" I.D. impression on it Decision to run smaller catch that will allow entry and catch in screen. 22:30 - 23:30 1.00 FISH C DECOMP Make up bha #5 3-3/8" grapple 23:30 - 00:00 0.50 FISH C DECOMP rih with bha # 5 2/9/2001 00:00 - 01 :30 1.50 FISH C DECOMP continue to rih wit bha #5 to 7020' 01 :30 - 04:30 3.00 FISH C DECaMP tag fish & engage fish (Note: it is unclear as to whether we have fish latched or not. 04:30 - 07:30 3.00 FISH C DECaMP Pooh with BHA # 5 (Recoverd Fish Packer & screens) 07:30 - 09:00 1.50 FISH C DECaMP lay down recovered fish. 09:00 - 09:30 0.50 FISH C DECaMP clean rig floor. 09:30 - 10:30 1.00 FISH C DECOMP Make up bha # 6 Mill + 2- junk basket +bumper sub +Jars+6-dc. for cln-out & milll iron from packer. 10:30 - 13:30 3.00 CLEAN C DECOMP rih with Bha #6 to 3500' 13:30 - 14:30 1.00 CLEAN C DECaMP circ gas from drill pipe & spot viscuous weighted pill in pipe 14:30 - 16:30 2.00 CLEAN C DECaMP continue to rih to 7039' 16:30 - 17:00 0.50 CLEAN C DECaMP wash & ream 7039' to 7063' 17:00 - 19:00 2.00 CLEAN C DECaMP circ gas out of wellbore through choke & condo fluids. 19:00 - 22:00 3.00 CLEAN C DECaMP wash & ream frac sd. from well bore 7039' to 7264' rotation 104 & pump at 6-bpm. 22:00 - 00:00 2.00 CLEAN C DECaMP circ. viscuous fluid & rotate & reciprocate pipe rpm 104--& pump 6-bpm 2/10/2001 00:00 - 04:00 4.00 CLEAN P DECOMP circ & reciprocate & rotate & cln well bore of sand. 04:00 - 07:30 3.50 CLEAN P DECOMP displace clean out fluid with clean filtered 9.2 ppg. brine. 07:30 - 11 :00 3.50 CLEAN P DECOMP lay down 3.5" drill pipe 11 :00 - 14:30 3.50 CLEAN P DECOMP incorrect hole fill circ. well bore & mix fluids to 9.7 ppg. 14:30 - 19:00 4.50 CLEAN P DECOMP continue to pooh laying dn drill pipe. 19:00 - 20:30 1.50 CLEAN P DECOMP lay dn bha # 6 20:30 - 22:00 1.50 CLEAN P DECOMP clean flloor & rig up to run esp completion. 22:00 - 00:00 2.00 RUN cor ~ COMP make up pump & motor esp equipment. 2/11/2001 00:00 - 05:00 5.00 RUNCOr ~ COMP rih with esp completion to 6763' 05:00 - 08:30 3.50 RUNCOr fp CaMP pu landing jt. & make up hanger to same & install penetrator & make splice in esp cable 08:30 - 09:00 0.50 RUNCOr ~ COMP land tubing hanger, RILDS. Pick Up weight 59 K Slack off Printed: 3/1/2004 11 :30:22 AM BP AMOCO Page 3 of 3 Operations Summary Report Legal Well Name: MPC-01 Common Well Name: MPC-01 Spud Date: 2/4/2001 Event Name: WORKOVER Start: 2/4/2001 End: 2/12/2001 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/11/2001 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/11/2001 08:30 - 09:00 0.50 RUNcor /p COMP weight 59 K 09:00 - 11 :00 2.00 RUNCO~ ~ COMP install TWCV and test to 2,500 psi continue to RILDS, Laydown landing joint. 11 :00 - 13:30 2.50 RUNCO~ rP COMP nipple down BOPE. 13:30 - 15:00 1.50 RUNCO~ ~ COMP nipple up tree 15:00 - 16:00 1.00 RUNCO~ ~ COMP test hanger void & tree 5,000 psi 16:00 - 18:00 2.00 RUNCO~ ~ COMP pull TWCV and install BPV wllubricator & secure well. Rig released at 18:00 HRS 02-11-01 RECEIVED MAR 0 1 t. AllillQI'GllCø.~) APOJWl! Printed: 3/1/2004 11 :30:22 AM (' (' 1 8 (( L{30 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, tJN\'\(' Commissioner ¿P - DATE: November 18, 2000 THRU: Blair Wondzell, ~ P. I. Supervisor \<{ '2ð[cÐ Lou Grimai, ~ G-. Petroleum Inspector SUBJECT: SVS tests BPX C-pad Milne Point Unit Kuparuk River Field FROM: Saturdav.November 18. 2000: I witnessed the SVS tests on BPX C pad in the Milne Point of the Kuparuk River Field. This was the three-month test for this pad due to a 26% fail rate witnessed by Inspector Jeff Jones on 7/9/00. The wells did somewhat better this time although the fail rate of 13.6°/Ó was still above the 10% expectable limit. Again, the gas injectors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV. The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spool adapter, Larry Niles (MPU 01 advisor) will pursue this with the wellhead manufacturer as to proper repair and report back tome. The wellhouses were all very clean and it appears to be a high priority in the Milne facility. SUMMARY: I witnessed the SVS test on BPX C pad in the Milne Point Unit. 1 pad, 11 wells, 22 components, 3 failures. Well house Inspections; 14 well houses, 1 failure (leaking T.S.A.) Attachments: SVS MPU C pad 11-18-00 LG.XLS cc: Niles/Shipley (MPU 01 advisers) NON-CONFIDENTIAL SVS MPU C pad 11-18-00 LG.doc .. " (:- ( Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi FieldlUnit/Pad: K.R.F ./M.P. U.lC pad Separator psi: LPS 140 Date: 11/18/00 HPS Well Permit Separ Set LIP Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-01 1811430 140 100 120 P P OIL C-02 1821940 C-03 1820500 140 100 105 P P OIL C-04 1821260 140 100 105 P 4 OIL C-05A 1842430 140 100 105 P P C-06 1842410 C-07 1850020 140 100 110 P P OIL C-08 1850140 C-09 1850360 140 100 80 P P OIL C-13 1850670 C-14 1850880 140 100 105 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 110 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P P WAG C-36 1980010 C-39 1972480 C-19i 1852960 4000 2000 2000 P 4 WAG 11 Components: .22 Failures: 3 Failure Rate: 13.6%090 Day Wells: Remarks: C-03 has gas leak on Tubing Spool adapter, Develop plan for repair and report back. 11/20/00 Page 1 of 1 VOk1trl6.xls --- STATE OF ALASKA ALASKA )AND GAS CONSERVATION COMM ~ION REPORT OF SUNDRY WELL OPERATIONt~ 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 48' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1168' NSL, 2256' WEL, SEC. 10, T13N, R10E, UM MPC-01 At top of productive interval 9. Permit Number / Approval No. 181-143 958' NSL, 2168' WEL, SEC. 10, T13N, R10E, UM 10. APl Number At effective depth 50-029-20663 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 947' NSL, 2268' WEL, SEC. 10, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 10442 feet Plugs (measured) EZSV at 8852' & 9075' & 9185' true vertical 10430 feet Bridge Plug at 7287' Effective depth: measured feet Junk (measured) See attached true vertical feet Casing Length Size Cemented MD TVD Structural Conductor 80' 16" To Surface 115' 115' Surface 2302' 13-3/8" 3800 sx AS II 2338' 2338' Intermediate Production 9768' 9-5/8" 2000 sx Class 'G', 150 sx AS I 9802' 9791' Liner RECEIVED Perforation depth: measured 6959' - 6968', 7142' - 7167', 7120' - 7133' true vertical 6950' - 6958', 7132' - 7157', 7110' - 7123' ~A~aska 0il & Gas Cons. C0mmissio. Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 TO 6739' Packers and SSSV (type and measured depth) 9-5/8" packer with 20 gauge screen and tailpipe at 6828' 13. Stimulation or cement squeeze summary ~ ~X. \ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble .~~ ~ Title TechnicalAssistantlll Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Depth MD Est. TVD Progress Auth Depth Hole Size DOUDFS/Target II Geologist Engineer Supervisor (ft) (ft) (ft) (ft) Casing Size Casing (MD) Next Casing Size (in) Next Casing (MD) (ft) Next Casing (TVD) (ft) Liner (MD) Liner Top (MD) BP AMOCO Daily Operations Report Event WORKOVER Field MILNE POINT Well Type: OTHER Rig: NABORS 4ES Current Well Status Costs in AFE No. AFE Cost Daily Mud Cum. Mud Daily Well Cum. Well Page 1 of 2 Report 1 Date: 10/16/2000 Operator BP AMOCO Well: MPC-01 339620 Rig Accept Rig Release Spud Date Elev Ref 10/16/2000 GROUND LEVEL 60,287 60,287 KB Elev 28.00 (ft) LAULE Myers I Owen Program Tot. Personnel 0 Cost Ahead 0 Days Ahead 0.00 Current Status: NIPPLE UP BOP 24hr Summary: MOVE RIG FROM MPC-14 TO MPC-011 R U KILL WELL W/8.8 PPG BRINEIND TREE 24hr Forecast: NU AND TEST BOPEI PULL ESP COMPLETION Comments: NO ACCIDENTSI NO SPILLSI 1 LCIR PRESENTLY NON RECORDABLE- PERSONAL ILLNESS HSE & Well Control All free Days Days since Last DAFWC Details TasfCsg-Prèss. TesCm--------- - -------______m______m__--Casf"Þlre--i5ï-m-_m_----g79i200Cf"--- --- - Last BOP Press. Test 10/11/2000 Next BOP Press. Test 1945 0 .-.-."-"'-.- . _...~~,.. '--''''---,---,,-,'____n.._._....'___n____.,---.-.-----.-.------.-..-- Last Safety Meet. No. Stop Cards TVD (ft) EMW (ppg) MAASSP (psi) Test Pressure: (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) I Regulatory Agency Insp. N Non-compliance Issued N Pump I Slow Pump Rates (Circ) I Slow Pump Rates (Choke) I Slow Pump Rates (Kill) Stroke Rate I PressureO Stroke Rate I PressureO Stroke Rate I PressureO ROP Daily ROP Cum. WOB (min) WOB (max) RPM at Surface RPM at Bottom Torq. on Bottom Torq. oft Bottom 1- ..-.- --.. From-To Hrs Phase Task hh:mm (hr) 00:00-01 :30 1.50 POST RIGD Rotating Weight Pick Up Wt. Slack Oft Wt. Circ. Rate Riser Circ. Rate Hole Circ. Oft Bottom Circ. On Bottom OperationalParametérs Rotating Hours (hr) Cum. Bit Hours -. Pump Status Pump Eft. Stroke Rate Liner Size Circ. Rate 0 0 0 0 - ...- --- --- Ann. Vel. Riser (ft/min) Ann. Vel. DC (ft/min) Ann. Vel. DP (ft/min) Activity Opendions$l.Immary Code NPT - .--- ...-.-...-. - Operation RD P RIG DOWN RIG 4ES ON MPC-14. SCOPE DOWN AND LOWER DERRICK MOVE RIG FROM MPC-14 TO MPC-01 01 :30-02:30 1.00 POST RIGD MOB P 02:30-09:00 6.50 POST RIGD RU P SPOT SUB, PITS AND PIPE SHED, BERM AND HOOK UP MODULES, RAISE AND SCOPE DERRICK, FINISH RIG UP HOOK UP HCR VALVE ON ANNULAR, SPOT AND BERM TIGER TANK, PICK UP LUBRICATOR AND PULL BPV. 600 PSI ON TBG AND 1500 PSI ON CASING. HOOK UP TO TREE TO KILL WELL. TEST LINES TO 2500 PSI. HELD PJSM TO KILL WELL. CIRCULATE WELL WITH SEAWATER,CLOSED CHOKE AND BULLHEAD 20 BBLS OF SEAWATER. PUMPED A TOTAL OF 700 BBLS WHILE CIRCULATING THROUGH THE CHOKE AT 5 BPM AT 1500 PSI. SHUT WELL IN TO MONITOR PRESSURE. AFTER 30 MINUTES SITP 170 PSI. WEIGHT UP TO 8.8 PPG AND CIRCULATE HOLE WITH 8.8 PPG BRINE AT 5 BPM WI 1250 PSI. SWI AND MONITOR PRESSURE. SITP 80 PSI AND SICP 120 PSI AFTER 30 MINUTES. RELEASED PRESSURE AND CIRCULATED WELL AROUND AGAIN AT 5 BPM AT 1200 PSI. CIRCULATED OUT REMAINING GAS AND OIL. SHUT DOWN AND MONITOR WELL. WELL STATIC. SET TWCV AND TEST TO 3,500 PSI. 09:00-11 :30 2.50 DECOM WHSU RU P 11:30-14:30 3.00 DECOM WHSU WELKIL P 14:30-22:00 7.50 DECOM WHSU WELKIL P 22":00-22:30 0:50 DECOM WHSU SETOTR P -- - Printed: 10/17/2000 6:15:40 AM From-To Hrs Phase Task hh:mm (hr) 22:30-00:00 1.50 DECOM WHSU BP AMOCO Dai Iy Operations Report Event WORKOVER Field MILNE POINT Well Type: OTHER Rig: NABORS 4ES 0 erations Summa Code N PT Page 2 of 2 Report 1 Date: 10/16/2000 Operator BP AMOCO Well: MPC-01 Activity Operation ND P BLEED PRESSURE ON HANGER. NIPPLE DOWN TREE AND HCR VALVE. 06:00 Update: 00:00-06:00 NIPPLE UP BOP EQUIPMENT Remarks Phase DECOMP POST TOTALS Cumulative Phase Breakdown Planned Change of Scope Prod % Total NPT % Total WOW % Total Prod % Total NPT % Total 15.00 100.0% 9.00 100.0% 24.00 100.0% Total Cost WOW % Total Printed: 10/17/2000 6:15:40 AM BP AMOCO Daily Operations Report Page 1 of 2 Operator BP AMOCO Event WORKOVER Field MILNE POINT Report 2 Well: MPC-01 Well Type: OTHER Rig: NABORS 4ES Date: 10/17/2000 Current Well Status Depth MD (ft) Casing Size Costs in Rig Accept Est. TVD (ft) Casing (MD) AFE No. 339620 Rig Release Progress (ft) Next Casing Size (in) AFE Cost Spud Date 10/16/2000 Auth Depth (ft) Next Casing (MD) (ft) Daily Mud Elev Ref GROUND LEVEL Hole Size Next Casing (TVD) (ft) Cum. Mud DOUDFS/Target II Liner (MD) Daily Well 52,695 KB Elev 28.00 (ft) Geologist Liner Top (MD) Cum. Well 112,982 Engineer LAULE Tot. Personnel 0 Supervisor Myers I Owen Program Cost Ahead 0 Days Ahead 0.00 Current Status: Circulating 9.6 ppg kill fluid 24hr Summary: NU BOPI PULLED TWCI SPOT BRIDGESAL PILU CIRCULATED 9.1 PPG KILL FLUID 24hr Forecast: KILL WELL I PULL ESP I RUN ESP Comments: NO ACCIDENTSI NO SPILLSI NO HSE INCIDENTS HSE& Well Control Days since Last DAFWC 1946 All free Days 0 Details Last Csg Press. Test Last Fire Drill 9/9/2000 Last BOP Press. Test 10/11/2000 Next BOP Press. Test Last Safety Meet. Last Divertor Drill (D3) 10/17/2000 Last Spill Drill 10/17/2000 No. Stop Cards Regulatory Agency Insp. N Non-compliance Issued N TVD (ft) I Pump 1 Slow Pump Rates (Circ) I Slow Pump Rates (Choke) 1 Slow Pump Rates (Kill) EMW (ppg) Stroke Rate I PressureO Stroke Rate I PressureO Stroke Rate I PressureO MAASSP (psi) Test Pressure: (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) .....,. ..'......'." '.".. Operational Pàrameters .. ,.... ..:.:. ... .:.. .:... :: '.:..:: ROP Daily Rotating Weight Rotating Hours (hr) Pump Status ROP Cum. Pick Up Wt. Cum. Bit Hours Pump Eff. Stroke Rate Liner Size Circ. Rate WOB (min) Slack Off Wt. 0 0 0 0 WOB (max) Circ. Rate Riser RPM at Surface Circ. Rate Hole Ann. Vel. Riser (ft/min) RPM at Bottom Circ. Off Bottom Ann. Vel. DC (ft/min) Torq. on Bottom Circ. On Bottom Ann. Vel. DP (ft/min) Torq. off Bottom .....:.:........::.....::. .., ....: <> i ( ~Deråtión$SÙmfua..y. ::: : ... : .:.: ....,...: ::: From-To Hrs Phase Task Activity Code NPT Operation hh:mm (hr) 00:00-06:00 6.00 DECOM WHSU NU P NIPPLE UP 133/8" BOP EQUIPMENT 06:00-08:30 2.50 DECOM WHSU TSTPRS P TEST BOP EQUIPMENT TO 250 PSI 13500 PSII ANNULAR 250 PSI 12500 PSI. TEST KOOMY. DRAIN STACK 08:30-09:30 1.00 DECOM WHSU BULLHD P 600 PSI ANNULAR PRESSURE. LUBRICATE AND BLEED 68 BBLS. DOWN ANNULUS. ANNULUS 0 PSI 09:30-10:30 1.00 DECOM WHSU PUL P PICK UP LUBRICATOR AND EXTENSION. PULL TWCV TUBING STATIC. LAID DOWN LUBRICATOR EXTENSION AND TWCV. 10:30-11 :00 0.50 DE COM WHSU CIR P MAKE UP LANDING JOINT AND RIG UP TO CIRCULATE THROUGH CHOKE. 11:00-12:30 1.50 DECOM WHSU CIR P CIRCULATE 320 BBLS AT 4 BPM AT 700 PSI DOWN TUBING AND OUT 9 5/8" CASING VALVE THROUGH CHOKE. RETURNS CLEANING UP. 12:30-14:30 2.00 DE COM WHSU CIR P SHUT DOWN AND BACKED OUT LOCKDOWN SCREWS. PICKED UP HANGER 2' AND STARTED TO CIRCULATE WELL DOWN FLOWLINE. 14:30-18:00 3.50 DECOM KILL CIR P CONTINUED TO CIRCULATE DOWN FLOWLINE AT 4 BPM RATE HANGER BRIDGED OFF AND FLOW STOPPED AT FLOWLINE. DIVERTED FLOW THROUGH CASING VALVE THROUGH CHOKE. SHUT DOWN AND ALLOWED PRESSURE TO BLEED TO 0 PSI. PICKED UP ON COMPLETION STRING AND WATER AND OIL ~ . co. Printed: 10/18/2000 6:05:15 AM From-To Hrs Phase Task hh:mm (hr) 14:30-18:00 3.50 DECOM KILL BP AMOCO Daily Operations Report Event WORKOVER Field MILNE POINT Well Type: OTHER Rig: NABORS 4ES 0 erations Summar Code N PT Page 2 of 2 Report 2 Date: 10/17/2000 Operator BP AMOCO Well: MPC-01 Activity Operation CIR P 18:00-20:30 2.50 DECOM KILL CIR P ANNULAR. HAD APPROX 1 BBL.OF 8.8 PPG BRINE AND OIL ON RIG FLOOR THAT DRAINED INTO RIG DRIP PANS AND ON TOP OF BOP INTO CELLER AREA ON HURCULlTE. INSPECTION MADE BY MILNE POINT ACS. NOT A SPILL AT THIS POINT. CONTINUED TO CIRCULATE THROUGH CHOKE AT4 BPM AT 700 PSI .LOSING FLUID AT 1 BPM. MONITORED WELL AND CONTINUED TO CIRCULATE. RAISED MUD WEIGHT IN PIT FROM 8.8 PPG TO 9.1 PPG. MIXED BRIDGESAL KILL PILL. 10 BBLS OF 10# BRINE 1 CAN OF BARABRINE DEFOAMER 1 PPB FL-7 30 PPB BRIDGESAL 30 PPB PLUGSAL 30 PPB PLUGSAL X 22:30-00:00 1.50 DECOM KILL P PUMPED 10 BBLS OF 10 PPG 10 PPG BRINE FOLLOWED BY 10 BBL OF BRIDGESAL KILL PILL FOLLOWED BY 10 BBLS OF 10 PPG BRINE. DISPLACED WITH 9 BBLS OF 9.1 PPG FLUID TO SPOT PILL AT GLM @ 6714'. CLOSED CHOKE AND BULLHEADED PILL OUT THE END OF TUBING STRING WITH 29 BBLS 9.1 PPG FLUID AT 1500 PSI AT 4 BBUMIN AND REDUCED RATE TO 1 BBL/MIN AT 1900 PSI ON TUBING. 2500 PSI ON CASING. INITIAL SI TUBING PRESSURE 1800 PSI. INITIAL SI CASING PRESSURE 2250 PSI CONTINUE TO CIRCULATE 9.1 PPG FLUID THROUGH CHOKE AT 4 BPM AT 600 PSI. INCREASED RATE TO 4.5 BBPM AT 850 PSI. LOSSES TO THE WELL AT 3 BPH.SHUT DOWN AND MONITOR WELL. OPENED ANNULAR. WELL GASING AND PRODUCING SMALL AMOUNTS OF OIL OIL RAISED WEIGHT FROM 91. PPG TO 9.3 PPG IN SUCTION PIT 20:30-22:30 2.00 DECOM KILL CIR P 06:00 Update: 00:00-01:30. CONT. TO CIRC. 9.3 PPG FLUID AT 4 BPM AT 500 PSI. LOSS TO THE HOLE AT 7 BPH 01 :30-06:00 RAISED WT TO 9.6 PPG AND CIRCULATED AROUND A T6.5 BPM AT 1500 PSI WINO LOSS TO THE HOLE. 0.00 Printed: 10/18/2000 6:05:15 AM BP AMOCO Dai Iy Operations Report Page 1 of 2 Operator BP AMOCO Event WORKOVER Job Number Report 3 Well MPC-01 Objective ESP resize Acct Proj No Date 10/18/2000 Field MILNE POINT Well Type OTHER Rig NABORS 4ES Current Well Status Depth MD (ft) Casing Size AFE No. 339620 Rig Accept Est. TVD (ft) Casing (MD) AFE Cost Rig Release PBTMD (ft) Liner (MD) Daily Mud Spud Date 10/16/2000 Liner Top Cum. Mud Elev Ref GROUND LEVEL Hole Size Daily Well 66,080 Cum. Well 179,062 KB Elev 28.00 (ft) Engineer LAULE Supervisor Myers I Owen Program Cost Ahead 0 Days Ahead 0.00 Current Status: CIRCULATE WELL WITH 10.6 PPG FLUID 24hr Summary:WEIGHT UP FROM 9.3 PPG TO 10.6 PPG 24hr Forecast: KILL WELL AND PULL ESP Comments: NO ACCIDENTS I NO SPILLS I NO HSE INCIDENTS HSE & Well Control Days since Last DAFWC 1947 All free Days 0 Details Last Csg Press. Test Last Fire Drill 9/9/2000 Non-compliance Issued N Last BOP Press. Test 10/11/2000 Regulatory Agency Insp. N Next BOP Press. Test Pump I Slow Pump Rates (Circ) I Slow Pump Rates (Choke) Slow Pump Rates (Kill) Operational Parameters Avg. ROP Circ. Rate Riser Pump Status Avg. WOB 0.0 Circ. Rate Hole Pump Eff. Stroke Rate Liner Size Cire. Rate Avg. RPM 0 Circ. Pressure * 0 0 0 () Avg. Torq. 0 Pick Up Wt. Cum. Bit Hours Slack Off Wt. Rotating Weight ... ..... . Operations Summary ... .. .... , .... .. From-To Hrs Unit Phase Task Activity Code NPT Operation 00:00-01 :30 1.50 RIG DECOM KILL CIR P CO NT. TO CIRC. 9.3 PPG FLUID AT 4 BPM AT 500 PSI. LOSS TO THE HOLE AT 7 BPH 01 :30-04:00 2.50 RIG DECOM KILL CIR P CONTINUE TO CIRCULATE AND WEIGHT UP FROM 9.3 PPG TO 9.5 PPG @ 4 BPM @ 600 PSI. MONITOR WELL WITH NO LOSS TO THE HOLE. 04:00-06:00 2.00 RIG DECOM KILL CIR P CONTINUE TO CIRCULATE WELL AND WEIGHT UP FROM 9.5 PPG TO 9.6 PPG AT 6.5 BPM RATE WITH 1500 PSI. 06:00-07:30 1.50 RIG DECOM KILL CIR P CONTINUE TO CIRCULATE WELL AND WEIGHT UP TO 9.8 PPG AT 6.5 BPM WITH 1500 PSI TUBING PRESSURE. NO LOSS TO THE WELL. WELL GASSING ON THE ANNULUS. 07:30-13:30 6.00 RIG DECOM KILL CIR P CONTINUE TO CIRCULATE WELL AND WEIGHT UP TO TO 10.0 PPG AT 6112 BPM AT 1550 PSI. MONITOR WELL NO FLUID LOST TO THE HOLE. WELL GASSING ON ANNULUS. liNED UP ON CHOKE AND CIRCULATED BOTTOMS UP @4BPM @ 800 PSI. HOLDING 110 PSI BACK PRESSURE. MONITOR WELL 13:30-16:30 3.00 RIG DECOM KILL CIR P WEIGHT UP TO 10.2 PPB AND CIRCULATE 4 BPM AT 700 PSI. HELD 70 PSI BACK PRESSURE. LOST 7 BBLS TO THE WELL. MONITOR WELL. WELL GASSING AT THE ANNULUS. 16:30-18:00 1.50 RIG DECOM KILL CIR P WEIGHT WELL UP TO 10.3 + PPG AND CIRCULATE 4 BPM AT 750 PSI. THROUGH CHOKE. HELD 100 PSI BACK PRESSURE 18:00-20:30 2.50 RIG DECOM KILL CIR P CIRCULATE AND WEIGHT UP FROM 10.3 PPG TO 10.4 PPG @ 4 BPM @ 800 PSI. LOSS 11 BBLS TO THE WELL. SHUT WELL IN AND MONITOR PRESSURE FOR 1 HOUR. . ... ... .. Printed: 10/19/2000 6:03:05 AM From-To Hrs Unit Phase Task 18:00-20:30 2.50 RIG DECOM KILL BP AMOCO Daily Operations Report Event WORKOVER Job Number Objective ESP resize Acct Proj No Well Type OTHER Rig 0 erations Summa Code NPT P Page 2 of 2 Report 3 Date 10/18/2000 Operator BP AMOCO Well MPC-01 Field MILNE POINT NABORS 4ES Activity CIR Operation SITP 20 PSI AND ANNULAR PRESSURE 40 PSI. 20:30-21 :00 0.50 RIG DECOM KILL CIR P RELEASED PRESSURE AND CONTINUED TO CIRCULATE AT 6 BPM @ 1500 PSI. WEIGHTED UP PIT TO 10.6 PPG FROM 10.4 PPG IN PIT WITH SODIUM BROMIDE. CONTINUED TO CIRCULATE AND RAISE WEIGHT IN SYSTEM TO 10.6 PPG 21 :00-00:00 3.00 RIG DECOM KILL CIR P Comments: 00:00-02:00 CONTINUE TO CIRCULATE WELL AT 2 BPM AT 200 PSI WITH 30 PSI BACK PRESSURE. 11 BBLS LOST TO THE HOLE 02:00- 06:00 CIRCULATE 10.6 PPG AT 5 BPM @ 1200 PSI12 BBLS LOST TO HOLE Remarks Printed: 10/19/2000 6:03:05 AM BP AMOCO Daily Operations Report Page 1 of 2 Operator BP AMOCO Event WORKOVER Job Number Report 4 Well MPC-01 Objective ESP resize Acct Proj No Date 1 0/19/2000 Field MILNE POINT Well Type OTHER Rig NABORS 4ES Current Well Status Depth MD (ft) Casing Size AFE No. 339620 Rig Accept Est. TVD (ft) Casing (MD) AFE Cost Rig Release PBTMD (ft) Liner (MD) Daily Mud Spud Date 10/16/2000 Liner Top Cum. Mud Elev Ref GROUND LEVEL Hole Size Daily Well 127,195 Cum. Well 306,257 KB Elev 28.00 (ft) Engineer LAULE Supervisor Myers I Owen Program Current Status: INCREASING WEIGHT FROM 11.2 PPG TO 11.4 PPG 24hr Summary: INCREASED WEIGHT FROM 10.6 PPG TO 11.2 PPG 24hr Forecast: INCREASE WEIGHT FROM 11.2 PPG TO 11.4 PPGI PULL ESP Comments: NO ACCIDENTS I NO SPILLS I NO HSE INCIDENTS HSE & Well Control All free Days Days since Last DAFWC Details Last Csg Press. Test Last BOP Press. Test Next BOP Press. Test Pump 1948 10/11/2000 Last Fire Drill 9/912000 Regulatory Agency Insp. N Cost Ahead 0 Days Ahead 0.00 0 Non-compliance Issued N Slow Pump Rates (Choke) erational.Parameters Operation CONTINUE TO CIRCULATE WELL AT 2 BPM AT 200 PSI WITH 30 PSI BACK PRESSURE. 11 BBLS LOST TO THE HOLE CIRCULATE BOTTOMS UP AT 5 BPM @ 1200 PSI. WITH 70 PSI ON CASING .12 BBLS LOST TO HOLE CIRCULATE 10.6 PPG AT 5 BPM @ 1200 PSI SHUT WELL IN FOR PRESSURE BUILD UP. HELD MEETING WITH RICHARD CAMPBELL I MILNE POINT PRODUCTION GROUP I BP REPS AND NABORS CREWS. DISCUSSED SAFETY ON RIG 4 ES AND CONGRADTULA TED CREWS FOR 5 SAFE YEARS. SITP 10 PSI AND SICP 30 PSI. RELEASED PRESSURE PULLED HANGER TO THE RIG FLOOR AND REDRESSED. RAN BACK IN THE HOLE BELOW ANNULAR PREVENTER. ------.----. C-IRCÜLÄfË-WËL"[-WITH-10.6 PPG BROMIDË-FLUlOAt-j-- 1/2 BPM @ 500 PSI. WELL GASSING ON TE ANNULUS CLEANED NUMBER 2 PIT AND BEGAN TO DISCPLACE WELL TO 11.2 PPG BROMIDE FLUID Avg. ROP Avg. WOB Avg. RPM Avg. Torq. Pick Up Wt. Slack Off Wt. Rotating Weight 0.0 0 0 Cum. Bit Hours erationsSummar Code NPT P 02:00-06:00 4.00 RIG DECOM KILL CIR P 06:00-13:00 7.00 RIG DECOM KILL CIR P 13:00-14:00 1.00 RIG DECOM KILL WEL TST P 14:00-14:30 0.50 RIG DECOM KILL MU P 14:'3Õ:'-23:0Õ- --8:50-. ---RfCf-' DE-COM --Ki[[--- '-----CfFC-- ... .0.. --'""--".-"""-"'.'---- P 23:00-00:00 1.00 RIG DECOM KILL WELKIL P Pump Status Pump Eff. Stroke Rate Liner Size Cire. Rate 0 0 0 0 Comments: 00:00-01:30 CONTINUETO DISCPLACE WELL TO 11.2 PPG BROMIDE FLUID FROM 10.6 PPG 01:30- 06:00 MONITOR WELL WITH SLIGHT GAS BREAKING OUT IN ANNULUS. WELL TAKING FLUID AT 14 BBLSIHOUR RATE. Printed: 10/20/2000 5:57:41 AM Operator BP AMOCO Well MPC-01 Field MILNE POINT BP AMOCO Daily Operations Report Event WORKOVER Job Number Objective ESP resize Acct Proj No Well Type OTHER Rig Page 2 of 2 Report 4 Date 10/19/2000 NABORS 4ES Remarks TOTAL FLUID LOST TO THE WELL 317 BBLS. Printed: 10/20/2000 5;57:41 AM BP AMOCO Daily Operations Report Page 1 of 2 Operator BP AMOCO Event WORKOVER Job Number Report 5 Well MPC-01 Objective ESP resize Acct proj No Date 10/20/2000 Field MILNE POINT Well Type OTHER Rig NABORS 4ES Current Well Status Depth MD (ft) Casing Size AFE No. 339620 Rig Accept Est. TVD (ft) Casing (MD) AFE Cost Rig Release PBTMD (ft) Liner (MD) Daily Mud Spud Date 10/16/2000 Liner Top Cum. Mud Elev Ref GROUND LEVEL Hole Size Daily Well 129,126 Cum. Well 435,383 KB Elev 28.00 (ft) Engineer LAULE Supervisor Myers I Owen Program Cost Ahead 0 Days Ahead 0.00 Current Status: RUNNING IN THE HOLE WITH ESP 24hr Summary: WEIGHT UP TO 11.4 PPG I SPOT BRIDGESEAL PILL! PULL ESP 24hr Forecast: RIH WITH ESPI ND BOPE INU TREE AND MOVE TO MPJ-05 Comments: NO ACCIDENTSI NO SPILLSI NO HSE INCIDENTS HSE & Well Control Days since Last DAFWC 1949 All free Days 0 Details Last Csg Press. Test Last Fire Drill 9/9/2000 Non-compliance Issued N Last BOP Press. Test 10111/2000 Regulatory Agency Insp. N Next BOP Press. Test Pump I Slow Pump Rates (Circ) I Slow Pump Rates (Choke) Slow Pump Rates (Kill) Operational. Parameters Avg. ROP Circ. Rate Riser Pump Status Avg. WOB 0.0 Circ. Rate Hole Pump Eff. Stroke Rate Liner Size Cire. Rate Avg. RPM 0 Circ. Pressure * 0 0 0 () Avg. Torq. 0 Pick Up Wt. Cum. Bit Hours Slack Off Wt. Rotating Weight ... .. ... OperationsSurrim~ry .... ... ... ... ..... ... ......... ..... .. ... From-To Hrs Unit Phase Task Activity Code NPT Operation 00:00-01 :30 1.50 RIG DECOM KILL WELKIL P CONTINUE TO DISCPLACE WELL TO 11.2 PPG BROMIDE FLUID FROM 10.6 PPg 01 :30-06:00 4.50 RIG DECOM KILL WELKIL P MONITOR WELL WITH SLIGHT GAS BREAKING OUT IN ANNULUS. WELL TAKING FLUID AT 14 BBLSI HOUR RATE. WEIGHT UP FROM 11.2 PPG TO 11.4 PPG IN PITS 06:00-10:00 4.00 RIG DECOM KILL WELKIL P CIRCULATE AND WEIGHT UP FROM 11.2 PPG TO 11.4 PPG AT 2 BPM AT 150 PSI. 10:00-11 :00 1.00 RIG DECOM KILL BULLHD P MONITOR WELL, SPOT BRIDGESAL KILL PILL. 20 BBLS OF 11.4# BRINE 1 CAN OF BARABRINE DEFOAMER 1 PPB FL-7 30 PPB BRIDGESAL 30 PPB PLUGSAL 30 PPB PLUGSAL X BULLHEADED AT 2 BPM AT 500 PSI @ 1300 PSI. 11:00-13:30 2.50 RIG DECOM KILL CIR P BLEED TUBING AND ANNULAR PRESSURE. CLOSE ANNULAR, CHOKE AND MONITOR PRESURE. 13:30-16:30 3.00 RIG DE COM KILL CIR P FILL HOLE THROUGH TUBING TOOK 40 BBLS TO FI LL HOLE. PULLED HANGER TO THE FLOOR. PICK UP WEIGHT 54 K FILL HOLE THROUGH TUBING AND CIRCULATE. ESTABLISH LOSS RATE WHILE CIRCULATING BOTTOMS UP AT 4 BPM. LOSS RATE AT 44 PBH 16:30-18:30 2.00 RIG DECOM KILL CIR P SPOT BRIDGESAL KILL PILL. . ... ... ... ..... ... ... I Printed: 10/21/2000 6:35:44 AM From-To Hrs Unit Phase Task 16:30-18:30 2.00 RIG DECOM KILL BP AMOCO Daily Operations Report Event WORKOVER Job Number Objective ESP resize Acct Proj No Well Type OTHER Rig 0 erations Summa Code NPT P Page 2 of 2 Report 5 Date 10/20/2000 Operator BP AMOCO Well MPC-01 Field MILNE POINT NABORS 4ES Activity CIR Operation 25 BBLS OF 11.4# BRINE 1 CAN OF BARABRINE DEFOAMER 1 PPB FL-7 30 PPB BRIDGESAL 30 PPB PLUGSAL 30 PPB PLUGSAL X 18:30-00:00 5.50 RIG DECOM KILL PTOH P CIRCULATE ACCROSS THE TOP OF THE HOLE AND MONITORED WELL FOR LOSSES. WELL LOSING AT 6 BPH RATE LAYDOWN HANGER, PUP JOINTS, XO AND LANDING JOINT RIG UP AND PULL OUT OF THE HOLE WITH 27/8" TUBING AND ESP CABLE Comments: 00:00-0130 LAY DOWN CENTRIUFT PUMP ASSEMBLY 01 :30-03:00 REMOVE SPOOL FROM UNIT/CLEAR FLOOR! RU TO RUN NEW PUMP 03:00-06:00 P U 7" SHROUD AND PUMPI MAKE UP AND SERVICE Remarks Printed: 10/21/2000 6:35:44 AM BP AMOCO Daily Operations Report Page 1 of 2 Operator BP AMOCO Event WORKOVER Job Number Report 6 Well MPC-01 Objective ESP resize Acct Proj No Date 10/21/2000 Field MILNE POINT Well Type OTHER Rig NABORS 4ES Current Well Status Depth MD (ft) Casing Size AFE No. 339620 Rig Accept Est. TVD (ft) Casing (MD) AFE Cost Rig Release PBTMD (ft) Liner (MD) Daily Mud Spud Date 10/16/2000 Liner Top Cum. Mud Elev Ref GROUND LEVEL Hole Size Daily Well 37,195 Cum. Well 472,578 KB Elev 28.00 (ft) Engineer LAULE Supervisor Myers I Owen Current Status: RIG RELEASED 24hr Summary: RUN ESPI NIPPLE DOWN BOPEI NIPPLE UP TREE AND SET BPV 24hr Forecast: Comments: NO ACCIDENTSI NO SPILLS I NO HSE INCIDENTS HSE & Well Control All free Days Program Cost Ahead 0 Days Ahead 0.00 Days since Last DAFWC Details Last Csg Press. Test Last BOP Press. Test Next BOP Press. Test Pump I 1950 0 10/11/2000 Last Fire Drill 9/9/2000 Regulatory Agency Insp. Non-compliance Issued 0.0 0 0 Slow Pump Rates (Circ) I Slow Pump Rates (Choke) ... Operational Parameters Circ. Rate Riser Circ. Rate Hole Circ. Pressure * Slow Pump Rates (Kill) .. Avg. ROP Avg. WOB Avg. RPM Avg. Torq. Pick Up Wt. Slack Off Wt. Rotating Weight . ... ... Pump Status Pump Eff. Stroke Rate Liner Size Circ. Rate 0 0 0 0 Cum. Bit Hours Activity LD Operations$ummarv Code NPT P ... , .... ... From-To Hrs Unit Phase Task 00:00-01 :30 1.50 RIG DECOM PULL Operation LAY DOWN CENTRILlFT PUMP ASSEMBLY REMOVE SPOOL FROM UNITICLEAR FLOOR! RU TO RUN NEW PUMP -03:0Õ~6:00 "3~öÖ-_mRiG---C(fMï:) RONCO ---pU------- _m____p_----- -.----.--------- -FIU-ii'SHR"6ÛÖÄï,mmÞUMPTíÇ;fAKEÜPÃI\fö'-s-Ë-RVicË---'- 01 :30-03:00 1.50 RIG COMP RUNCO CLNRIG P 06:00-10:00 4.00 RIG COMP RUNCO RTIH P MAKE UP 10' PUP, XN NIPPLE, 2' PUP AND RUN 27/8" ESP COMPLETION ASSEMBLY. 10:00-12:00 2.00 RIG COMP RUNCO MU P MAKE UP LANDING JOINT, HANGER AND XO. MAKE UP CONNECTOR AND INSTALL PENETRATOR. TESTED OK 12:00-13:00 1.00 RIG COMP RUNCO LANDTH P LAND HANGER. PICK UP WEIGHT 55 K SLACK OF WEIGHT 55 K. RUN IN LOCK DOWN SCREWS. 13:00-13:30 0.50 RIG COMP RUNCO TSTPRS P INSTALL TWCV AND TEST TO 2,500 PSI. 13:30-16:30 3.00 RIG COMP WHSU ND P NIPPLE DOWN BOP EQUIPMENT 16:30-18:30 2.00 RIG COMP WHSU NU P NIPPLE UP TREE AND TEST HANGER VOID TO 5,000 PSI 18:30-21 :00 2.50 RIG COMP WHSU RD P RIG DOWN TEST LINES, PICK UP LUBRICATOR, PULL TWCV AND SET BPV. LAY DOWN LUBRICATOR. SECURE TREE AND CELLAR. RIG RELEASED AT 21 :00 HRS Comments: RIG RELEASED AT 21:00 HRS . Printed: 10/22/2000 5:59:03 AM Operator BP AMOCO Well MPC-01 Field MILNE POINT BP AMOCO Dai Iy Operations Report Event WORKOVER Job Number Objective ESP resize Acct Proj No Well Type OTHER Rig Remarks Page 2 of 2 Report 6 Date 10/21 12000 NABORS 4ES Printed: 10/22/2000 5:59:03 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Dan Seamount, Commissioner ~'///~//~ Blair Wondzell, P. I. Supervisor · FROM: Jeff J°nes~, ~ ./~'- SUBJECT: PetrOleum Ihsp~.c~r DATE: July 12, 2000 S.afety Valve Tests Milne" Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads: MPU B Pad, ~9 wells, 18 components tested,*. 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc AlaSka Oil and Gas Conservation CommisSion Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones SUbmitted BY: Date: Field/Unit/Pad: Kupamk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/0O Well Permit Separ Set L/P Test ' Test Test Oil, WAG, GIN J, Number Number PSI PSI TAp Code Code Code GAS or CYCLE ~ : 1811430 1.4._9_0- 100 95 P P OIL C-03 :1820500 140 1001 95..P P OIL C-04 1821260 140 100! 100 P 4 OIL C-05A "1842430 140 100 100 P 4 OIL C-07 1:850020 140 '100 100 p P OIL C-08 1850140 C-09 .1850360 140 100 120 P 4 OIL C-13 1850670 .~ C-14 1850880 140 100 100 p P OIL , C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 i C-22A 1951980. 140! 100 95: p p OIL C-23 1960160 · C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 · C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 p p WAG C-06 1842410 4000, 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%W19o var Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 V lv7irqm.xls 1. Operations performed: [-] Operation Shutdown [~ Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. ALASKA ,. , DsT^TE°F^L sK ' RECEIVED GAS CONSERVATION COM ,. SION ~.4 REPORT OF SUNDRY WELL OPERATIONS · FEB ~999 ~ Stimulate ~ Plugging ~ Pe~ora~ ~C~0[ag6 ~Alter Casing ~Repair Well ~ Other Change Out ESP 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface J5. Type of well: [~ Development ~--~ Exploratory [--] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE -- 59' 7. Unit or Property Name Milne Point Unit 8. Well Number 1168' NSL, 2256' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 4329' SNL, 2167' WEL, SEC. 10, T13N, R10E, UM At effective depth At total depth 913' NSL, 2168' WEL, SEC. 10, T13N, R10E, UM MPC-01 9. Permit Number / Approval No. 81-143 10. APl Number 50-029-20663 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing EZSV at 8852' & 9075' & 9185' 10442 feet Plugs (measured) Bridge Plug at 7287' 10442 feet feet Junk (measured) See attached feet Length Size Cemented M D Structural Conductor 80' 16" To Surface 115' Surface 2302' 13-3/8" 3800 sx AS II 2338' Intermediate Production 9768' 9-5/8" 2000 sx Class 'G', 150 sx AS I 9802' Liner TVD 115' 2338' 9791' Perforation depth: measured true vertical 6959'-6968', 7142'-7167', 7120'-7133' 6950'-6958', 7132'-7157', 7110'-7123' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd tubing to 6789' Packers and SSSV (type and measured depth) 9-5/8" packer with 20 gauge screen and tailpipe at 6828' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments I-1 Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [~ Oil [--I Gas r--I Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed e~~ ~ Terde Hubbl ..... Title Technical Assistant III Prepared By Name/Number: Date ~'¢~'~-~ '(~ Terrie Hubble, 564-4628 Submit In Duplicate~ Form 10-404 Rev. 06/15/88 Facility M Pt C Pad Progress Report Well MPC-01 Rig Nabors 4ES Page Date 1 10 February 99 Date/Time 05 Sep 98 06 Sep 98 07 Seg98 08:00-15:00 15:00-19:30 19:30-02:30 02:30-03:30 03:30-05:30 05:30-06:00 06:00-09:00 09:00-11:30 11:30-14:00 14:00-23:30 23:30-01:00 01:00-02:30 02:30-05:30 05:30-06:00 06:00-12:00 12:00-15:00 15:00-17:00 17:00-20:00 20:00-21:00 21:00-00:00 Duration 7hr 4-1/2 hr 7hr lhr 2 hr 1/2 hr 3hr 2-1/2 hr 2-1/2 hr 9-1/2 hr 1-1/2 hr 1-1/2 hr 3hr 1/2 hr 6hr 3hr 2hr 3hr 1 hr 3hr Activity Rig moved 100.00 % Fill pits with Fresh water Circulated closed in well at 6660.0 ft Removed Xmas tree Installed BOP stack Tested BOP stack Tested BOP stack Circulated at 6600.0 ft Removed Tubing hanger Laid down 6600.0 ft of Tubing Rigged down sub-surface equipment - ESP Installed Completion string handling equipment Functioned ESP Ran Tubing to 250.0 ft (2-7/8in OD) Ran Tubing to 6788.0 ft (2-7/8in OD) Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 135.000 bbl of Diesel WELLHEAD: 13-5/8" 5M F~ ... n 2) Orig. KB. Elev, 8' (Nabors 17) w/3.5" FMC Tubing Hanger, NSCT top ~ Orig. GL. Elev. = 28' and bottom threads, 3.0" CIW 'H' BPV nrnfil~.. ~nd ~.n. tn ~) 7/R" FI, IF FI rd. ~" ~3.5" X 2 7/8" EUE x.o. below hanger 20" 94ppfH-40btrs. I 110' I Camco 2 7/8" x 1" I 1 1 9' md I ~ sidepocket KBMM GLM KOP = none max. hole angle = 7 deg II I ! 9 5/8" cement divert valve @ 2219'MD ppf, L-80, Btrs. casing 9-5/8" 47 (cap. = 0.0732 bpf, drift ID = 8.525") 2 7/8", 6.5 ppf, L-80, EUE 8rd tubing (cap. = 0.0058 bpf, drift = 2.347") ~ Camco 2 7/8" x 1" 2 7/8" 'XN' npl. (w/2.313" no go)116731' md - Centrilift FC925 ESP, Original perforation summary Centrilift GRSTXBARH6 16760' md Size SPF Interval open/sqz'd i tandem gas separator 4" 12 9134' - 9143' squeezei Centrilift GSB3 tandem I 6766' md 4" 12 8904'- 8934' d seal sections I 4" 12 7142'- 7167' squeeze ~ Centrilift KME1,82 hp 16779' md 4" 12 7120'- 7133' d~ motor, 1230 v. / 38 a. I 4" 12 7109'- 7111' open 4" 4 6970' open ~,, A 6959' - 6968' squeeze 12/94 Perforation summary ~"~11~~'' screen9'5/8" pkr.andW/tailpipe20' 20 gauge 6828' md REF LOG: 2/23/82 CBL, 2/5/82 DIL 3.5" 'XN' npl. w/'PXN' plug 6854' md Size SPF Interval open / sqz'd (2.75" ID) 6859' md 3.5" WLEG 3-3/8" 6 7142'-7167' open 3~3/8" 6 7120' - 7133' open 3-3/8" 6 6959'- 6968' open ~ plug, set 12/94 f ~- -FISH: 9' toolstring w/1-10' 0.092 FISH: Milled out Otis 9 5/8" WD pkr, slickline 4'-3.5" pup, 3.5" Otis 'X' npl, 5'-3.5" pup,/' 3.5" 'XN', 3.5" WLEG. Top is at 7423 MD. ,,/1 ~ FISH: Junk basket / gauge ring Ref. 12/94 RWO ~' 9 5/8" EZSV Retainer FISH M~lled out Ot~s WD pkr w/ ' seal bore extension, 6 1/8" X 3 1/2" x.o., I 9 5/8" EZSV Retainer 9,O75' md two 3.5" pup joints, Otis 'X' and 'XN' npls. I overall lenath = 23' 9 5/8" EZSV Retainer DATE REV. BY COMMENTS MILNE POINT UNIT 3/18/82 DBR Initial completion WELL C-01 12/17/94 DBR RWO APl NO: 50-029-20663 09/08/98 JBF ESP Changeout by Nabors 4ES BP EXPLORATION {Al{) A " OILAND GAS CONSERVATION COMMIS~;I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate x Plugging Pull tubing x Alter casing . Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1168' NSL, 2256' WEL, SEC. 10, T13N, RIOE At top of productive interval 4329' SNL, 2167' WEL, SEC. 10, T13N, RIOE At effective depth At total depth 913' NSL, 2168' WEL, SEC. 10, T13N, RIOE 5. Type of Well: Development x Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 59' feet 7. Unit or Property name Milne Point Unit 8. Well number MPC-01' 9. Permit number/approval number 81-143/Cons. order #347 10. APl number 50- 029-20663 11. Field/Pool Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10442 feet Plugs (measured) 10442 feet feet Junk (measured) feet Length Size Cemented 80' 16" To Surface 2302' 13-3/8" 3800 sx AS II 9768' 9-5/8" 2000 sx "G'Y150 sx AS I measured 7142'-7167', 7120'-7133', 6959'-6968' EZSV @ 8852'& 9075'& 9185' MD Bridge Plug @ 7287' MD true vertical vertical Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 6859' MD Packers and SSSV (type and measured depth) see attached Measured depth 115' 2338' Gas Cons, Commission Anch0r~iie 9-5/8" packer w/20 gage screen & tailpipe @ 6828' MD True vertical depth 115' 2338' 9802' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well C~perations x Oil x Gas Suspended 17. I hereby certify t~t~got~ ~q.~,an~c~ t to the best of my knowledge. Signed ./~/ ~ ~.-.~- vL Form 10-404 Rev 06/15~B8 Title On'lling Engineer Supervisor Service SUBMIT IN DUF/LIdATE i TREE: 3, '-5M WKM MP C-01 WELLHEAD: 13-5/8' 5M FMC (Gen 2) w/3.5' FMC Tubing Hanger, NSCT top ORIG. KB. ELEV -- 48' (Nabors 17) and bottom threads ORIG. GL ELEV = 28' and 3.0'ClW 'H' BPV profile ,,0. I-i ,i ;[''--ii NOTE: GLM AT 215 MD HAS 2.371' ID KOP = none MAX HOLE Angle = 7 BEG ~, I H 9-5/8' DV @ 2219 MD L-80 BTS ~'o,~o GAS LIFT MANDRELS (2-7/8' XI' KMBG w/BK LATCH) 3-1/2' 9.3#, L-80 DSS-HT maE 2.992' ID, 2.857' DRIFT _ NO. i MD I TVDss VALVE TYPE CAPACITY: 0.00870 BBL/FT 2 215 166 I 6622 6563 I #2 ESP POWER CABLE ~- -- CL-350 ORIGINAL PERFORATION SUMMARY . .. 4' 12 7142' - 7167' OPEN / TANDEM SEALS . 6757' 4' 12 7109"7111° SQZ'D ~ CENTRILIFTMOTOR 6770' 4' 4 6970' SQZ'D ~__ ~ KME-1 I 4' 4 6959'-6968' t3P~N ~ ~ -- CENTRILIFT PHD I 6783' 12/94 PERFORATION SUMMARY :2~¢ L"--- ~ 9-5/8' PACKER W/20' 20 GAGE REF LOG: 2/23/82 CBL, 2/5/82 DIL ~ = ~ SCREEN AND TAILPIPE ~ 6828' SIZE SPF INTERVAL OPEN/SQZ'D ~ 3-1/2' XN NIPPLE w/PXNI PLUG (2.75' ID) 6854' 3-3/8' S 7120' - 7133' OPEN 9 5/8' BAKER N-1 OPEN ~L BRIDGE PLUG [" ~;_ FISH: 9'TOOLSTRINGW/1-10' 0.092 WlRELINE. FISH: MILLED OUT OTIS 9 5/8' WD PKR, 4'-3.5' PUP, 3.5' OTIS X NIPPLE, 5'-3.5' PUP, j ~ ; 3.5' XN, 3.5' WLEG. TOP AT 7423 MD. ! ~ : FISH: JUNK BASKET AND FROM 12/94 RWO ~ ~,~.~.~-~m ~ GAUGE RING EZSV RETAINER I 8,852' EZSV RETAINER 9,075' FISH: MILLED OUT OTiS 'WD' PACKER SEAL BORE EXTENSION, 6 1/8' X 3 1/2' J ~Iil;;=~i~t' EZSV RETAINER i 9,185' CROSSOVER, 2 - 3-1/2' PUP JOINTS, ~ ~ OTiS X AND XN NIPPLES, LENGTH = 23' '~[ ~ 9-5/8' 47#, L-80, BTS DATE REV. BY COMMENTS MILNE POINT UNIT 3/18/82 DBR INITIAL COMPLETION WELL C-01 12/17/94 DBR RWO APl NO: 50-029-20663 BP EXPLORATION (AK) BP/ALI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP C-01 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 4ES WO/C RIG: NABORS 4ES 12/02/94 (1) TD: 9502 PB: 7260 12/03/94 (2) TD: 9502 PB: 7260 12/04/94 (3) TD: 9502 PB: 7260 12/05/94 (4) TD: 9502 PB: 7260 RUN LINK T/KILL TANK MW: 0.0 ACCEPTANCE OF THE RIG IS BEING NEGOCIATED DUE T/ THE DIFFICULT MOVE & POSSIBLE MODIFICATIONS THAT MIGHT BE DONE T/SOME LINES & WALKWAY. MOVE RIG F/C-3 T/C-1. BERM HERCULITE. RIG UP SFTY EQUIP. RAISE & SCOPE DERRICK, BRIDAL DOWN. FILL PITS W/KILL FLUID. RE-RUN MUD & GAS BUSTER LINES. SPOT TIGER TANK & RUN LINES T/KILL WELL. NIPPLE UP BOPE MW: 0.0 BUILD BERM. SPOT TIGER TANK. HOOK UP CHOKE LINE, KILL LINE & LINE TO TIGER TANK. TEST CHOKE & KILL LINES W/3000 PSI. LINE TO TIGER TANK W/500 PSI. ATTEMPT TO RIG UP LUBRICATOR. CHANGE OUT TREE CAPE FLANGE. MAKE UP LUBRICATOR & TEST W/1000 PSI. PULL BPV. 900 PSI ON TBG & ANNULUS. BLEED TBG & ANNULUS TO 0 PSI. DISPLACE WELL W/8.4# SW. SWAB VALVE LEAKING ON TREE. CHANGE OUT ADAPTOR. MAKE UP TREE CAP. CONTINUE TO DISPLACE WELL, TAKING RETURNS TO TIGER TANK. MONITOR WELL. CIRC TO PITS. MONITOR WELL. SET BPV & TEST W/750 PSI. TEST SSSV W/1000 PSI. ND TREE & ADAPTOR FLANGE. INSTALL TEST PLUG IN HGR OVER BPV. PLUG OFF CL PORT. NIPPLE UP BOPE. MU BHA#i MW: 0.0 RIG UP & TEST BOPE, SAFETY VALVES AND CHOKE MANIFOLD. DRILL #1. PULL BLANKING PLUG. RIG UP LUBRICATOR & PULL BPV. LD LUBRICATOR. MU LDG JT. RIG UP TO PUMP DOWN TBG. SHEAR PUMP OPEN PLUG W/2200 PSI. FLUID LOSS 12 BPH. BOLDS. PULL HGR TO FLOOR. OPEN SSSV. PUMP & SPOT 4T BBL XANVIS PILL @ TBG TAIL. MONITOR WELL. 0 LOSS. TOH W/3-1/2" TBG. L/D EVERY 10TH JT. INSTALL WEAR RING. RIG UP FLOOR TO PICK UP DP. STRAP & MU BHA #1. TEST STORM PKR W/1000 PSI MW: 0.0 MU BHA #1. STARP, DRIFT & PICK UP 3-1/2" DP. SERVICE RIG. TROUBLE SHOOT ELECTRICAL PROBLEM. PICK UP 3-1/2" DP. FLUID RETURNS 30 DGR, CBU. PICK UP 3-1/2" DP. DISPLACE WELL W/140 DGR SW. FREEZE PROTECT TO 180'. MU BAKER STORM PKR, SET @ 746. POOH 8 STANDS. TEST STORM PKR & CSG W/500 & 1000 PSI. RECEIVED FEB -5 1995 Alaska Oil & Gas Cons. Commission Anchors ~, WELL : MP C-01 OPERATION: RIG : NABORS 4ES PAGE: 2 12/06/94 (5) TD: 9502 PB: 7260 12/07/94 (6) TD: 9502 PB: 7260 12/08/94 (7) TD: 9502 PB: 7260 12/09/94 (8) TD: 9502 PB: 7287 MILL ON PACKER MW: 0.0 SET BRIDGE PLUG @ 593', TEST W/ 1000 PSI. PULL WEAR RING. BLOW OUT LINES. ND BOPE. ND TBG SPOOL. NO 9 5/8" PACKOFF. INSTALL BUSHING AND PACKOFF IN TBG SPOOL. CUT 2" OFF 9 5/8" STUB. NU TBG SPOOL. CHANGE OUT ANNULUS VALVE. TEST PACKOFF. NU BOPE. TEST BOPE. PULL TEST PLUG, SET WEAR RING. RIH, RELEASE BRIDGE PLUG. MONIOTR WELL. POH LD BRIDGE PLUG. RIH, RELEASE, RELEASE STORM PKR. MONIOTR WELL. CIRCULATE OUT METHANOL TO VAC TRUCK. POH, LD STORM PKR. RIH, TAG OTIS WD PKR @ 6891'. MILL PKR F/ 6891 - 6893'. RUN GAGE RING/JUNK BSKT MW: 0.0 CIRCULATE OUT GAS. MONITOR WELL. PU PKR TO BOTTOM. BOTTOM OF TAIL ASSY @ 7377' TOP OF PKR @ 7355'. POH, SLM, LAY DOWN PKR MILL. CLEAN J6NK BASKETS. MAKE UP 5002 SPEAR, RIH TI 6500'. SERVICE RIG. SLIP DRLG LINE. RIH, PUSHED PKR TO 7423'_ CIRCULATED AND CONDITION HOLE @ 7423'. ATTEMPT TO REVERSE CIRCULATE, PLUGING OFF. PUMPED 40 BBL XANVIS SWEEP. CIRCULATE TILL CLEANED UP. MONIOTR WELL. WELL STABLE. POH W/ BHA #2. LAY DOWN BHA. NO FISH. NU PERF FLANGE. RU ATLAS WL. RUN 8.50 WL/GR. TROUBLE SHOOT ATLAS MW: 0.0 RIG ATLS WIRELINE AND RIH W/ GR/CCL. MAKE UP BAKER N-1 BRIDGE PLUG AND TEST LUBRICATOR ATLAS PACKOFF LEAKING. TROUBLE SHOOT PACKOFF RIG DOWN PACKOFF AND RE-RIG TEST. RIH WITH BAKER N-1 BRIDGE PLUG AND GET ON DEPTH AND SET AT 7287' WLM. RIG UP ATLAS GUN #1 AND RIH TO 1400' FOUND E-LINE DAMAGED. POH. REPAIR E-LINE CUT OFF 1500', RE-WIRE HEAD. RIH W/ GUN S BIG HOLE 3 3/8" GUN. GET ON DEPTH PERF. ATLAS TROUBLE SHOOTING PERF GUN AND SYSTEM. PICKLE TBG W/ ACID MW: 0.0 RIH W/ GUN #4. POH RIG DOWN ATLAS. NIPPLE DOWN SHOOTING FLANGE AND NIPPLE UP FLOW NIPPLE. SERVICE RIG. MAKE UP MULE SHOE AND PICK UP 3 1/2" TBG TO 7290', TAG. REVERSE CIRC 40 BBL XANVIS SWEEP AND CONDITION HOLE. RIG BJ, TEST LINES. PUMP 30 BBL 16/20 CARBO-LITE POH TO 6903' WAIT ON SD TO FALL. RIH AND TAG SD PLUG @ 7224' POH TO %091'. BJ , MIX AND PUMP 15 BBL SLURRY, 16/20 CARBO-LITE. POH TO 6903'_ WAIT ON SD TO FALL. RIH AND TAG SD @ 7171'. RIG ACID TRUCK TO PUMP 18 BBL ON SHOT ACID TO PICKLE WORK STRING. RECEIVED FE'I3 - 3 ]99,5 Alaska Oil & Gas Cons. Commission Anchor~. ~ PAGE: 3 WELL : MP C-01 OPERATION: RIG : NABORS 4ES 12/10/94 ( 9) TD: 9502 PB: 7287 12/11/94 (10) TD: 9502 PB: 7287 12/12/94 (11) TD: 9502 PB: 7287 RIH W/ GS TO PULL PXN PLUG MW: 0.0 CONTINUE TO PUMP ACID TO PICKLE TO TBG. DISPOSE TO SLOP TANK. POH W/ TBG AND CHANGE SEAL RINGS. LAY DOWN 6" DC FROM DERRICK. PU BAKER RETRIEVEAMATIC PKR AND X-NIPPLE PROFILE AND RIH TO 6985'. RIG CAMCO WIRELINE TRK AND RIH AND SET PXN PLUG IN X-NIPPLE. TEST. RIG UP BJ AND TEST TBG. RIG DOWN BJ FRAC MANIFOLD. RIG CAMCO AND RIH TO RETRIEVE PLUG. UNABLE TO LATCH PLUG. POH AND INSPECT GS PULLING TOOL. RE-RUN TOOL AND STILL UNABLE TO LATCH PLUG. POH AND CHG OUT PULLING TOOL AND ALSO ADD KNUCKLE JT TO TOOL STRING. RIH TO RETRIEVE PLUG. TEST TBG MW: 0.0 RIH W/ IMP AND POH W/ SAME IMPRESSION OF LOCKS. RIH W/ 2.25" BAILER AND POH W/ SAME. RIH W/ 2.25" BALL TYPE BAILER. RIH W/ TYPE GS PULLER FOR PLUG. RIH W/ TYPE GR PULLER AND REC FROM LOCK UP ON XX PLUG. RIH W/ 2.5" IMP SHOWED LOCKS ON TOP OF PLUG. WAIT ON CENTER SPEAR AND MAGNET. RIH W/ 2.25" MAGNET AND POH AND REC 2 LOCKS. RE-RUN MAGNET NO RECOVERY. RIH W/ 1.73' CNTER SPEAR GET FRICTION BITES ON PLUG NO REC. RIG DOWN CAMCO. RIG UP TO POH. POH W/ TBG AND PKR. WET CHG X-LINE NIPPLE TO XN NIPPLE AND RIH TO 6988'. RIG CAMCO AND RIH AND SET PLUG IN XN NIPPLE. RIG BJ AND TEST TBG, OK. POH TO 6500' MW: 0.0 CONTINUE TO TEST BJ EQUIP AND TEST TBG, RIG DOWN. RIG CAMCO AND RIH AND RETRIEVE PLUG FROM XN NIPPLE. SPACE OUT AND SET BAKER RETRIEVATIC AT 6986' RIG BJ AND DISCUSS FRAC PLAN, DECIDE TO CHG PKR SETTING PROCSDURE. RIG DOWN BJ LINES. RELEASE PKR, INSTALL WEAR RING PULLER IN STRING AND PULL SAME. PICK UP TBG HANGER AND INSTALL IN TBG STRING. LAND TBG HANGER ON PKR. RILDS. RIG BJ EQUIPMENT AND APPLY 1500 PSI TO 9 5/8" X 3 1/2" ANNULUS. PERFORM INJECTIVITY TEST AND DATA FRAC. FRAC A SANDS WITH 123000# 16420 CARBOLITE PUT 119000# BEHIND PIPE. AFTER RIGGING BJ DOWN AND RIGGING TO RIG MANIFOLD FOR MONITOR. WAIT ON GELS TO BREAK. RIG CAMCO AND RIH FOR TAG @ 6989'_ POH AND RIG DOWN CAMCO. RIG UP TO REVERSE CIRC. APPLY 1500 PSI TO ANNULUS AND OPEN PKR. BYPASS REVERSE CIRC 1 TBG VOLUME AND UNSEAT PKR AND PULL HGR TO FLOOR. CONTINUE TO REVERSE CIRC AND MONITOR WELL BORE FLUIDS AND RIG DOWN HGR TO PULL PKR UP HOLE FOR C SAND FRAC. RECEIVED FEB - Alaska Oil & Gas Cons. Commission WELL · MP C-01 OPERATION: RIG : NABORS 4ES PAGE: 4 12/13/94 (12) TD: 9502 PB: 7287 12/14/94 (13) TD: 9502 PB: 7287 12/15/94 (14) TD: 9502 PB: 7287 12/16/94 (15) TD: 9502 PB: 7287 TEST BOPS MW: 0.0 LAY DOWN 15 JTS TBG. PICK UP 9 5/8" HGR SET PKR. LAND TBG HGR. RILDS. HGR LEAKING. BOLDS. PULL HGR TO FLOOR AND REPAIR SEALS. RE-SET PKR LAND HGR ON PKR. RILDS. PKR SET @ 6499'. RIG BJ AND TEST LINES PERFORM INJECTIVITY TEST AND DATA FRAC AND FRAC C SAND W/ 22000# 16/20 SD AT 20 BPM. SCREENED OUT WITH TBG FULL OF FRAC SD AT 6700 PSI. RIG DOWN BJ AND RIG UP OPEN BY PASS ON PKR AND REVERSE OUT FRAC SD. STARTING SD MOVEMENT WITH 1 SPM AND INCREASING AS FRAC SD BEGAN UNLOADING DURING PUMP OUT. POH LAYING DOWN 3 1/2" TBG. WORK STRING. SET PLUG AND TESTING BOPS. RUN 8.5" GR/JB MW: 0.0 CONTINUE W/ BOP TEST, PULL TEST PLUG AND SET WEAR RING. RIH WITH MULE SHOE AND 3 1/2" DP TO 6710' TAG CARBO-LITE. REVERSE CARBOLITE OUT OF 9 5/8" CSG TO 72~0' @ 6 BPM. REVERSE XANVIS SWEEP @ 6 BPM @ 7280'. HOLE CLEAN. POH FOR GR/JB RUN AND PKR SCREEN ASSY. RIG CAMCO AND RIH W/ 8.5" O.D. GR/JB. REV CIRC/CLEAN SOURCE H20 MW: 0.0 RIH W/ 8.5" GR/JB TO 6925' WLM. POH. RD CAMCO. PU AND RIH W/ 9 5/8" BAKER MODEL 'D' PKR AND SCREEN ASSY TO 6859'. BREAK CIRC. DROP 1 7/16" BALL. PUMP DP VOLUME. BALL DID NOT SEAL. DROP 2ND BALL. PUMP DP VOLUME. DID NOT SEAT. REVERSE CIRC. REVERSED 2 BALLS TO SURFACE. DROP 1 7/16" KIRTSITE BALL. PUMPED DP VOLUME. DID NOT SEAT. POH. BALL NOT IN SEAT. INSPECT PKR AND SETTING TOOL. RIH DRIFTING DP. RECOVERED PIECE OF STEEL, LARGE PIECE OF HYDRIL RUBBER, AND BALL IN STD #9. CONTINUE IN HOLE DRIFTING PIPE. BREAK CIRC. DROP 1 7/16" BALL. PUMP DOWN. PRESSURE UP. SET AMD RELEASE F/ PKR @ 6828'_ BOTTOM OF SCREEN ASSY @6859' REVERSE CIRC XANVIS SWEEP. FINISH CLEANING PITS. LO~D FILTERED SOURCE WATER. REVERSE CIRC WELL. POH RABBITING TBG MW: 0.0 FINISH REVERSE CIRC WELL TO CLEAN FLUID. MIX AND SPOT 20 BBL XANVIS PILL ON BOTTOM. POH 4 STDS. CIRC DOWN DP AND WARM FLUID TO 90 DEGREE'S COMING OUT W/ HOT OILER. SLIP 42' AND CUT 84' DRLG LINE. LD DP AND PACKER SETTING TOOL. PULL WEAR RING. RU TO RUN ESP COMPLETION. MU AND TEST ESP. RUNNING ESP ON 3.5" DSS-HT. CHANGING SEAL RINGS OUT. 18 STDS IN HOLE. DROPPED PIECE OF RUBBER HOSE AND ROPE DOWN TUBING. TRY TO REVERSE OUT, NO LUCK. POH RABBITING EACH STAND. RECEIVED F£~ -3 ]995 Ai~ska 0il & (~s Cons. Commission Anchor~ -~ WELL : MP C-01 OPERATION: RIG : NABORS 4ES PAGE: 5 12/17/94 (16) TD: 9502 PB: 7287 12/18/94 (17) TD: 9502 PB: 7287 S I GNATURE: CHANGING OUT HYDRIL RUBBER MW: 0.0 SERVICE RIG. CONTINUE POH DRIFTING TUBING. FOUND FISH IN 2ND STAND. FINISH RUNNING ESP COMPLETION ON 3.5" DSS-HT, CHANGING SEAL RINGS ON EACH JT. MAKE SPLICE @ HANGER. LAND HANGER. RILDS. SET BPV. BOTTOM OF PUMP @ 6783' ND FLOW NIPPLE, KILL AND CHOKE LINES. ND ANNULAR BAG. RELEASE RIG MW: 0.0 ND BOPE. BOLDS. THREADS GALLED. RETAP THREADS AND INSTALL NEW LOCK DOWN SCREWS AND PACKING. NU ADAPTER FLANGE. TEST, OK. NU TREE. PULL BPV. SET TWC. TEST TREE, OK. PULL TWC. FREEZE PROTECT W/ 123 BBLS DIESEL DOWN ANNULUS AND 18 BBLS BULLHEADED DOWN TUBING. SET BPV. RD LINES AND CELLAR. SECURE WELL. FINISH CLEANING PITS. RELEASE RIG @ 2100 HRS ON 12/17/94. i~~ ~. DATE: (drill' superintendent) RECEIVED FEE) t995 Aiaska Oil & Gas Cons. Commission LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 13 December 1994 Transmittal of Data ECC #: 6329.00 Sent by: MAIL Data: GR/CCL Dear Sir/Madam, Reference: BP BP EXPLORATION (ALASKA) INC MPC-01 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: i PFC/GR FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. P~ Atlas Wirelil 5600 B Su 201 Received by: )rage, AK 99518 Or- to (907) 563-7803 Date WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 28, 1994 Hal Stevens/John Hendrix Production Supervisor, Wells BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX MPU well No. C-1 Dear Mr. Stevens/Hendrix: On November 6, 1994, oUr Inspector Je~¥.~_~__~ring witnessed a no-flow test on BPX's MPU well No. C-l, PTD~i~'~ This gas lift well had been shut in and was bled down; it was essentially dead, venting a very small amount of gas from the tubing. The Inspector concluded that subject well was not capable of unassisted flow of hydrocarbons. The above well meets the criteria of a no-flow performance test and as such is considered incapable of flow to the surface. Under the authority of Conservation Order 173, Rule 5, this well is not required to have a fail safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition and, if for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, CC: Larry Niles/John Ketchum Jerry Herring bew/bpmpc 1 ,,,~ prinled on I~cycl~'d pap~, b v C :1 MEMORAND TO: THRU: David Johnst ,~'~ Chairm~ State Alaska Alaska Oil and Gas Conservation Commission DATE: November 6, 1994 Blair Wondzell, P. I. Supervisor ~/~ FROM: Jee~7o Huermri,ng, ~{'~ SUBJECT: P le ~nsPector FILE NO: lw9kkfbd, doc No Flow Test BPX, Milne Point unit Well C-1, PTD 81-143 Sunday. November 6, 1994: I traveled to BPX's Milne Point Unit to witness a no flow test on well C-1. The well was shut-in and depressurized upon my arrival. The well demonstrated good no-flow characteristics. The well had been on gas lift and traces of gas vented from the tubing throughout the day as the lift gas worked out of the system. This well is scheduled for a work over in the near future. I am concerned about the timing of this no-flow test prior to completion of a workover of the well, for the workover may cause a change in the well flowing characteristics. As with the no flow tests completed on wells C-3 and L-5, which I witnessed on July 25, 1994, a workover of those wells were completed after the no flow test. In my opinion, it would be appropriate to complete the no flow test after the workover to determine if the SSSV should be installed. I fear that approval of the no flow test prior to the workover gives BPX the message that the SSSV nipple is not required therefore making it impossible to install a SSSV in the future if the well performance changes due to stimulation work or a frac job. The SSSV nipple should still be installed during the workover unless use of SSSV's are deemed unnecessary field wide by policy. Summary: I witnessed a no flow test on MPU well C-1. C: Larry Niles, BPX Milne Point ~1 No__'. F,.(3--029--21~.66 LAST WORKOVER: 1/11/86 NOTES: 1. ALL MEASUREMENTS ARE FROM KDB OF NABORS RIG NO. 17 KDB-SL = 48' KDB-GL = 20' 2. MAX. /_ = VERTICAL 3, K.O.P. = VERTICAL 4. SLANT HOLE: N/A 5. MIN. Z. = N/A 6. TREE TYPE: FMC 3 1/8', APl 5000# WITH 3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS 2.635 O 6921' 8. COMPLETION FLUID: 10.2 PPG NaCI-NoBr 13 5/8" FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE ~3 1/2', 9.3 Ib/ft L-80 DSS-HT TUBING 1840' CAMCO TRDP-IA-SSA-SSSV (2.812" ID) ~ 2171' GLM 2867' GLM ~442' GLM GLM ¢599' GLM ~ 5178' GLM 5759' GLM 6336' GLM ~ 6881' GLM ,. CAMCO 5 1/2" KBUG GLM OTIS 9 5/8" TYPE 'WD' PACKER PERFORATION DATA SADLEROCHIT... 9134'-9145' SAG RIVER .... 8904'-8934' LOWER KUP (2).. 7142;-7167' LOWER KUP (1).. 7120'- 713~' MIDDLE KUP .... 6959'-6968' SQZ PERFS .... 7109'-7111' 6970' CONOCO INC. ANCHORAGE DIV1SION 6912' --- 4'x3 1/2" PUP ,JO. INT _ _., ,,, ~, ~ i~ 6916' --- OTIS 'X-NIPPLE g~?,,,7'~J'~D_ ) ~ · ~;~' ~ 6917' 5'x3 1/2" PU.P JOINT (W/ 4 P. ERFORA.TIONS ~6921' OTIS 'XN' W/ 2.635" NO-GO (2.75' ID) 6922' OTIS RE-ENTRY GUIDE · 7240' TOP OF FISH FiSH 9' LONG W/1'-10' 0,092" WIRE 7260' (OR DEEPER) MILLED-OUT OTIS 'WD' PACKER & ASSEMBLY JUNK BASKET (GAUGE RING) 8852' F7SV RETAINER EZSV RETAINER EZSV RETAINER 9802' 9 5/8' 47# L 80 BTRS APPROVED BY: HDS DRAFTED BY: SdN DATE: 11/50/92 CAD FILE: WCOC1 Telecopy No. (907) 276-7542 January 14, 1987 Mr. T. R. Painter Division Manager Conoco Inc. 3201 "C" Street, Suite 200 Anchorage,.AK 99503 Dear Mr. Painter: The enclosed Administrative Approval (AA) No. 173.8 dated~ December 30, 1986 is a corrected copy that should replace the Administrative Approval No. 173.1, also dated December 30, 1986, which was recently sent to you. Please destroy all copies of AA No. 173.1 of that date. Sorry for this inconvenience, and please call me at 279-1433 should you have any questions, Lonnie C. Smith Commissioner Enclosure LCS: j ob December 30, 1986 Telecopy No. (907) 276-7.542 ADMINISTRATIVE APPROVAL NO. 173.8 Re.. Exemptions from Conservation Order No. 17.3, Rule 9(a), requiring production surveys. Mr. T, R. Painter Division Manager Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Dear Mr. Painter.. We have received your letter of December 12, 1986, in which you requested exemptions to the resuirement8 of ConserVation Order No. 173, Rule 9(a), for Conoco s Milne Point Unit wells B-10, C-I, C-2 and C~7. Due to impending shutdown of production and injection operations at Milne Point Unit (MPU), the Commission agrees that production profiles at this point would not provide data essential for monitoring reservoir depletion. Therefore, the production surveys required by Rule 9(a) of Conservation Order No. 173 for MPU wells B-10, C-I, C-2.and C-7 are suspended. When production operations resume at MPU, then the production surveys for these wells will be required within twelve (12) months after regular production, begins. Lonnie C. Smith Commissioner BY ORDER OF THE COMMISSION jo/3.AA173.8 B-8, B-12, B'14, B-17, B-18 C-8, C-il, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPYs will be set and the SCSSVs and all wellhead valves will be closed. The m]tatic injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. %hough only one well is active at any given time, all wells are capable of produc- ing. A- 2A; B-'i; CFP- 1 Water source wells will be freeze protected by displacing the tubing to at' least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. If you have any questions on the shutdo~ procedure please contact Don Girdler at 564-7637. Yours very truly, Painter ~~R//z~ z"D~ i~s~.°n Manager cOnoco ' Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001PorcupineDrive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There' are 19 active and 5 inactive production wells at Milne Point. ACTIVE: B-3, B-4A, B-6, B-9, B-10, B-il, B-13, B-15, B-16, C-I, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: B-20, B-21, B-22 C-17, C-18 All active production wells will be freeze protected by displacing the top 3000~ of the tubing with a 1:3 diesel;oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil ~ixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSYs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive wate: injection wells in the Milne Point Unit. .... ': ': '2 2- fi. i(' STATE OF ALASKA i~,~ ALAS OIL AND GAS CONSERVATION COM _;ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend S Operation Shutdown Re-enter suspended well [] Alter casing ~ Time extension ,._. Change approved program F- Plugging [] Stimulate Iq., Pull tubing- Amend order Fl.. Perforate C} Other.l~~ 2. Name of Operator 5. Dat~jr~,el~.~ation (DF or KB) Cortoco inc. - feet 3. Add~z~1 C Street, Ste. 200, Anchorage, Alaska 99503 6. Uni~t~reop~rot~nntan~enit 4. Location of well at surface 1168' FSL, 2256' FEL, Sec. At t~p3 ~)productive interval ' FNL, 2167' FEL, Sec. At effective depth N/A At totclt~ePti~L, 2168' FEL, Sec. 10, T13N, RiOE, U.M. 10, T13N, R10E, U.M. 10, T13N, R10E, U.M. 7. Well number C-1 8. Permit number 81-143 9. APl numt~9_20663 50-- 10, .POO~uparuk River 11. Present well condition summary Total depth' measured 10442 true vertical 10442 feet Plugs (measured) feet Effective depth: measured N/A true vertical feet Junk (measured) feet Casing Structural Conductor 'Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth 80' 16" To Surface 115' 115' 2302' 13 3/8" 404 bbls 2338' 2338' 9768' 9 5/8" 232 bbls 9802' 9802' measure~ 7142'-7167'; 6904'-6964' true vertical (vertical) Tubing (size, grade and measured depth) 3½", L-80, 6922' T.R.'SCSSV La 1840'; Ret. Pkr. ¢.. 6900' Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal,~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereb,¥,c.e, rtify that the for~ego~ng is true and correct to the best of my knowledge Signed %~ _~l.?,__ Title Sr. Prorh~ctinn Eng'in~_~_'r Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity i-q BOP Test [] Location clearanceI ~ ~ ~ Approved by J~' LO'Jljl~' g, il/fl Form 10-403 Rev 12-1-85 A:,.o~.oved ,~eturne~ ,. Commissioner by order of the commission Date Submit in triplicate Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 12, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: conservation Order No. 173 Rule 9 Conoco requests exemption from Conservation Order No. 173 Rule 9 for .~M~m~i~Pe~tnt Unit wells B-10, C?I, C-2, and C-7. These wells are currently being supported by water injection but production and offset injection will be suspended in early 1987. Considering the circumstances, production profiles in these wells can not be justified. If you should have any questions please contact Don Girdler at 564-7637. Division Manager DRG/vv 500.~4 STATE OF ALASKA'~'' ~r ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator COMPLETED WELL ,~~ OTHER [] 7. Permit No. X 81-143 Conoco [nc. 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 99503 4. Location of Well 1167' FSL, 2256' FEL, Sec. 10, T13N, RIOE, U.M, 5. Eleva~ql in~t (indicate KB, DF, etc.) 6. Lea~eTD4e~i~nation and Serial No. 8. APl Number s0- 029-20663 9. Unit or Lease Name Milne Pnint Unit. 10. Well Number C-1 11. Field and Pool Kuparuk R~ vet 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 12-11-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ hoen; :t~:: sb el~o~ A P ;rro vC~ ~n: SnS iY°: n u se __ Title ~~_.~ Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA~L~- .L AND GAS CONSERVATION C(' ,MISSION SUNDRY NOTICES AND REPORTS ON IIIEl:L' /cn 1. DRILLING WELL [] COMPLETED WELL JAN 0 2 19~HER [] 2. Name of Operator 3. Address 4. Location of Well Conoco, Inc. 3201C Street, Suite 200, Anchoraqe AK 99503 980' FSL, 2195' FEL, SEC. 10, T13, RIOE U.M. 5. Elevation in feet (indicate KB, DF, etc.) KBE=48' GL=20' , 6. Lease Designation and Serial No. ADL 47434 Al~f~& Gas Con~. Commt~ion 81-143 Ar~hamg_~ 8. APl Number 5o-029-20663 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-I 11. Field and Pool Kuparuk Fi eld 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well ~ Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that a completion rig be moved onto the subject well to replace an inoperable subsurface safety valve. Once the SCSSV is replaced the well is to be .placed back on production. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_~_~~L,~:l~L~z~ Title Sr. Production Engr. The space below for Commission use Date 12/27/85 Conditions of APproval, if any: Approved by COMMISSIONER Approved Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SCALE IN MILES CONOCO . MILNE POINT UNIT EXISTING DEVELOPMENT HOTES: I. STATE PLANE CO. ORDINATES ARE ~0.NE 4. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 19Z7. OFFSETS TO SECTION LINES ARE COMPUTED BASED-ON PROTRACTED VALUES OF TI~iE SECTION CORNER POSITIONS. 4. LOCATED WITHIN SECT. 10, T I;3 N, RIOE, U.M.,AK. t I -------C----- __ LOCATION IN SECTION STATE PLANE CO-ORDS. GEODETIC POSITION C FROMm. L.IN4 F'~OM E. UNE NORTHINGS EASTINGS LATITUDE LONGITUDE 0ArE ICttECNEI:~ FI/LO BOOK i ' i . 1168' 2256' 6,029,450.20 558,Z0~.57 70°29' 27.868"N. 149° SI' 27.056"W' 6. I, aS J.B.S. 22 -85 ~ ,22,' ~,,,' ,.02,,,09.9~ ,,T,99,.,, ~'2,' 28.~,*,. ,4¢ ~':%0~*,. ,0.~., ~,,.~ ;;! . , , ~ .... ., ,,- ...~-~ ,,o~,,..~ ,,,,... ~,~,.,..,. ,.o,,,~;,.o,~. ~..~_.. . ~~ -,... ~-,. ~,o~,,,,.,o~ ~,,,,,.,, '"'"'~"-~'*-- ~%9'~ .[2s~ .... ~,oo,. ;,,,' 6.o~,.~,o.~ ,,~.,,.;, ~ i " 0029, 26.30~'N 149e 31' 31. 162 "W. ?~'.. .~a~2, ~,0~,,~2.~ ~'~.'~'.~ ;0~2~'a4.0~,~. ,~¢~,'a~.oso"~... " - ' . . ~.,,~,,. ' ., CERTIFICATE OF SURVEYOR : LOCATION ~URV[Y MADE ~Y ~E OR UNDER 4E N~N E E r~s Cofls."'l~mmissio 'C' PA D AS- BUILT WELL LOCATION Surveyed foe CONOCO SCALE : j SFIEET : · 400' J I OF 2 CO~IUENTS; STATE OF ALASKA ALASKA C~i-AND GAS CONSERVATION COlt: 'ISSION SUNDRY NOTICES AND REPORTSUN WELLS .............. DRILLING WELL [] COMPLETED WELL ~ '7. Permit81_143No. OTHE~ [] ~~ 2. Name of Operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-20663 4. Location of Well SURFACE: 10. Well Number 1168' FSL, 2256' FEL, Sec 10, T13N, R10E C-1 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. 48' KB I ADL 47434 Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 9. Unit or Lease Name Milne Point Unit NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: ~ (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well j~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pul!lng Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state, all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-1 well was originally completed in the Middle and Lower Kuparuk Formations as a co-mingled single completion. We now propose re-completing the well as a single selective with the Lower Kuparuk as the primary and the Middle Kuparuk as the selective. (Prior to re-running production tubing the productive formations will be re-perforated.) After the completion rig is released the Lower Kuparuk Formation will be fracture stimulated. C-1 will then be temporarily suspended pending the installation of production facilities. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sr. Production Engineer Signed e'~,~ --~ k~--- Title The space below for Commission use Date 6-17-85 Conditions of APproval, if any: 6RIGIIIAL SI&NEB I~Y i.~)H~llE C. SMITH Approved by COMM ISS ION ER Approved Copy Returped the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MILNE POINT UNIT C NO. ! CASING DIAGRAU OPERATOR: CONOCO, INC. SURFACE LOCATION: il6B' FSL, Y_Y. SG' BOTTOUHOLE LOCATION: 913' FSL, SPUD DATE: 12/?_4/81 FEL, SIO, TI3N, RIOE, U.B. ZI6B' FEL, $10, TI3N, RIOE, g. U. OROUNO LEVEL EL:: 20' MSL KELLY BUSHIH$ EL.= 45' MSt Cas~n~: 20", 94 lb/fl, H-40, BTRS, 0'--+110' m 13-3/8", 72 lb/ft, L-80, BTRS, 0'-2338' · . g4mlll, N4QI,.S. cm9-5/8", 47 lb/fi. L-80, BTRS, 0'-9802' · · '-'-~Q- c~. ~ Cement: Primary 13-3/8" - 2438 sks. Arctic Set II w/0.2% D-46 Recemented with 3800 sks. Arctic Set II. 9-5/8" - 825 sks. class G w/0.75% D-65, 0.75% D-59, 0.3% D-13, 0.2% D-46, 20~/sk D-30, 3?. KC1 Second stage - 1175 sks. class G wi0.5% D-65, 0.5% ", 7~ lb/fi, T-IQ, ITIIS. D-59, 0.2% D-46, 3% KC1 Third stage - 200 bbls. of Arctic Pack / J ., mi.. ~-,o. ,,R,~ csG. TI2~ T t42' ~ 7620' *t I ~. ~lS i IN0 X-R WIPPL[$, 7690' ~ UNKNOWN ~ Secondary Sqz. No. I at 9134'-9143' with 100 sks. class G ~/0.75% D-65, 0.75% D-59, 0.2% D-46. 20 sks. of additional cement spotted on top of retainer. Sqz. No. 2 at 8904'-8934' with 100 sks. of class G w/0.75% D-65, 0.75 D-59, 0.2% D-46. 50 sks. of additional cement spotted on top of retainer. Sqz. No. 3 at 7109'-7111' with 100 sks. of class G w/0.5% D-59, 0.5% D-65, 0.1% D-13, 0.2% D-46. 25 sks. of additional cement spotted on top of retainer. Sqz. No. 4 at 7109'-7111' with 200 sks. of class G w/0.5% D-59, 0.5% 9-65, 0.1% D-13, 0.2% D-46. 25 sks. of additional cement was spotted on top of the retainer. Sqz. No. 5 at 6970' with 193 sks. class O w/0.5% D-59, 0.5% D-65, 0.1% 9-13, 0.2% D-46. 32 sks. of additional cement was spotted on top of the retainer. Abandonment plug One abandonment plug was spotted across the 9-5/8" casing shoe with 200 sks. of Columbia class G w/0.752 D-65, 0.2% D-46, 0.2% D~28. Perforations: Production 9134'-9143', 12 JSPF, Schlum. 4" Hollow Carrier, 90~ phasing 8904'-8934', 12 JSPF, Schlum. 4" Hollow Carrier, j FI$#: MI~LEO On1 OTiS lO 90° phasing 7167'-7142', 12 JSPF, Dresser Atlas ~" Hollow 3~Z'PUPS iJq,~QX. L~nG~:Z3' Carrier, 120° phasing 7120'-7133', 12 JSPF, Dresser Atlas 4" Hollow Carrier, 120~ phasing I ? o.v. $~A~ cou.~ 012~ 6959'-6968' JSPF, Dresser Atlas 4" Hollow --FI'~H: o.~.ss~ IT~t$ ~u~ ~l~G&~[ ~ Carrier, {2 phasing ' ~ ' ~ .... S~ueeze: 165~~ [~V CEMENT RETiIWE{ 7109'-7111', 4 JSPF, Schlumberger Imu4,~ 6970', 4 JSPF, Dresser Atlas I tO.S .G UnO J Well Test Results: ~00~, I ' ~ '~ ~{ Test Inly. BOPD ~0TS'~~ [ZSV C[~mT RETAmE~ No Date Fo~. (°API) BWPD MCFPD Pwh Pw~ 2/21/82 10290'-442' 0 0 0 Lisburn 2/25/82 9134'-43 0 Ivishak 2/28/82 8904'-34' 0 0 0 Sag. R.' 3/5/82 7120'-33' 1229 0 367 LK-1 (20°) 7142'-67' LK-2 N/A 980 Pa NA 2580 57 190 3992 4491 N/A 543 NA 130 1880 3541 3/10182 6959'-68' 500 0 173 &00 2580 3507 MK-1 (22°) Dtrectiona] Highlights: The hole angle at 10,000' is 2°. A maximum hole angle of 7° 40' was measured at Alaska Oil & Gas Cons.CommJs~mn' ~oo,. Anchorage POINT UNIT C NO. I - COMPLETION DIAGRAM ~ '-oP~R~¥O-R :~c--d~bcO. ~,qC. · '- -- ~ .... - SURFACE LOCATION:1167' FSL, 22.56' FEL,SEC !0, TI3N, RIOE, U.M. BOTTOMHOLE LOCATION: 913'FSL,2_I68'FEL, SEC IO, TISN, RIOE,U.M. RIGK.B. TOTHE TOP OF THE TUBING HANGER =i= 1700' · .. 2094' 2219' = 24' DESC=¥~TiCN LENGTH 0 D ! D DEPTH 3 I/2" FMC TUBING HANGER w/BPV INSTALLED 3.29' 13 5" 3_5" 24' 3 I/2" BTRS.._x 3 I/Z" DSSTHT CROSS-OVER 1.18' 3.90" 2.992" Z7' 3 I/2", 9.3LB/FT, DSS-.~T PUP JOINT 3.75' 3.90" 2.992" 28' OTIS 3 .... DW" PLUG ~ 2992" N/A 962' 3 I/2'; 9 3LB/FT, DSS-HT TUBING 2054.80' 3.90" 2992" 32' -- I/4" SAFETY VALVE CCNTROL LINE 4-2100' -- -- -- . DIESEL/PACKER FLUID INTERFACE ~ FLOW COUPLING 6.25' ~ ~ 2088' I CAMCO 3 I/2" TRDP - ! AE 't SUBSURFACE SAFETY VALVE 11.2B' 5.9:~7" 2.812" 2094' ~ FLOW COUPLING :5.72 ~ ~ 2106' 5/8" D.V. PACKER :5 I/2", 9.:SLB/FT, DSS-HT TUBING 281.72' :5.90" 2.992" 2109' 5/8", 47LB/FT, L-80 5TRS. CASING 9-$ I/2" CAMCO KBUG GAS LIFT MANDRELS SPACED OuT WITH .3 I/2", 9. SLB/FT, DSS-HT TUBING AND PUP JOINTS. ALL MANDRELS WERE RUN WITH TYPE "E" DUMMY VALVES. No.I 6.07' 5.313" 2.875" 2391' No.Z 6.17' 5.315" 2.875" 3309' No. 3 6.17' 5.:513" 2.875" :. 4107' No.4 6.18' 5.31:5" 2.875 4810' No. 5 6.17' 5.:513" 2.875" 5387' No. 6 6.15' $.313" 2.875" 5899' No. 7 6.15' 5.313" 2.875" 6345' No. 8 6.1:5' 5. $13" 2.875" 6728' No. 9 6.18' 5.:51:5" 2.875" 6861' 3 I/Z", 9.$LB/FT, DSS-HT TUBING JOINT OTIS CROSS-OVER AND LANDING SUB W/OTIS SEAL UNIT (4 SECTIONS) AND MULESHOE 31.65' 3.90" 2.992" 6867' 0.90' 6899' 10.70' 5.00" 6900' 6918' .. 6921' 692:5' 7620' OR DEEPER UNKNOWN '. 885 Z' , 8904'- 89:54'~ ~ 9009' 9075' 9134'- ¢~ 43'-...-.-~- 9185' 9549' 9674' 9715'~ 9802'~ 98Z 5'---.--.- ~ I0,442'------ ~ OTIS 9 5/8" TYPE "WO" PACKER OTIS SEAL BORE EXTENSION 6 I/8"x :5 I/2" BTRS CROSS-OVER :5 I/2", 9.$LB/FT, N-80 BTRS PUP JOINT OTIS,Z.75" X-NIPPLE W~ 3 I/2",93LB/FT, N-BO BTRS PUP JOINT WITH 4 PERFORATIONS (6918'- 6920') 0TIS,2.635"X--N N~PPLE WITH "X-X" PLUG IN PLACE OTIS WIRELINE GUIDE PERFORATIONS (MIDDLE KUPARUK) SQUEEZE PERFORATIONS LK 'k PERFORATIONS (LOWER KUPARUK) LK 21 FISH: MILLED OUT OTIS "WO" PACKER. SEAL BORE EXTENSION, 6 I/8"x 3 I/2~ CROSS-OVER, 2 - :5 I/2" PUP JOINTS, OTIS, "X"AND "X-N" NIPPLES. LENGTH = 23' D.V. STAGE COLLAR FISH: DRESSER ATLAS JUNK BASKET .. ANO GAUGE raNG PS.T.D. EZSV RETAINER -~- ~ PERFORATIONS (SAG. RIVER) ~o! _ I EZSV RETAINER or,, b o ~c~ oj 0 ~> D~ ~ PERFORATIONS (SADLEROCHIT-IVISHAK) PPG Muo;-JI BRIDGEPLUG ~Ao ~ .o Al ~ 0 b o I HALLIBURTON LANDING BAFFLE ~o ~ o ~L e ~ w ~LO~T COL~. b o ~,o~B ~ W FLOAT SHOE ~* O~ o~,o~ 15.8 ~G EMW ~ ~ %%~ ~ m ~/~" .o~ PPG MUO ~ e I/Z" HOLE ~ '" TOTAL DEPTH 3.45' 8.86" 5.00' 6900' 7.40' 6.25" 5.00" 6905' 0.8:5' 8.00" $.00" 6911' 4.06' 3.90" 2.992" 6912' 0.75' :5.90" 2.75" 6916' 4.84' :5.90" 2.992" 6916.5' 0.90' :5.90" N/A(NO-GO 2635") 6921' 0.69' 8.00" 2.99~" 6922' BOTTOM OF PACKER ASSEMBLY = 692~' -X-PACKER FLUID: 9.6 PPG NaCI BRINE W/0.25 LB/BBL PARAFORMA LDEHYDE~ I0 Gel/lO0 BBLS LD8585~ 0.5 Gels/BBL A$05, -~W AN UNSUCCESSFUL ATTEMPT '~'0 SET AN OTIS "PXN" PLUG IN THE "X-NIPPLE" AT 6916' ON 4/26/8:5. THE BOTTOM OF THE PLUG INDICATED THAT THE X-NIPPLE WAS DAMAGED. RE,CEIVED JUN 2 0 1985 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL: JBF~ 5-83 REVISIONS: November 6, 1984 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Jim Trimble Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-I, B-2, B-3, B-4A, B-5, C-l, C-2, C-3, D-I, L-l, M-lA, N-lB, and Gwydyr Bay State 2A. Ail of the above are classified suspended well. s. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questions. You_rs very truly,~ /anager of Alaskan Oper J[TD/ks Attachments RECEIVED NOV 0 91 4 Alaska Oil & Gas Cons. Commission Anchorage SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 81-143 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 s0- 029-20663 4. Location of Well 1167' FSL, 2256' FEL, Section 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) GL=20' KB=48' 12. I 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-1 11. Field and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well will be utilized in the Phase I development of the Milne Point Unit. Work to re-activate this well will begin prior to production in early 1986. 14. I here~e.~i~hd iorrect to the best of my knowledge. Manager of Alaskan Operations Sig.ed ~_~///bzfv/~_. ~J~-'~Zt~7_.--~ Tit~e The sp for Commission use / Condi~or~of APproval, if anY: Date AFpreved ~ By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate M EMORA iq DUM TO: THRU: Sta e of Alaska FROM: 22, 1984 SUBJECT: Inspect Suspended Wells and Locations at Conoco Sites. ALAS~?~ANDGASCONSERVATIONCO~ISSION C.V.l~terton DATE: August Chair~~ Lonnie C. Smith~'~%/ FILE NO: D.31.52 Comis s loner~ TELEPHONE NO: Bobby Foste;"~ {, Petroleum Inspector Thursday., August 16, 1984: I traveled this date to Prudhoe Bay and met with Jerry Fritch and Jim Dosch, Conoco representatives, to inspect the suspended drill sites and wells listed below. Gwyder Bay 2A Milne Point NmlB Milne Point M-IA Milne Point L-1 Milne Point Pad A (4 wells) Milne Point Pad C (4 wells) Milne Point Pad B Milne Point Pad D I recommend to the Commission that these wells and drill sites be accepted as suspended. Pictures attached. 02-00IA(Rev. 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFO~ATION:~~~ Operator ~ · Date Suspended Address Surface Location of-~'~ell - - ' Sec.~, T/~ ~, R~ ~,-.~ M. Unit or Lease - Well No. ~ '~- Field & Pool Condition of Pad Condition' of Pi ts . ~~ ~._ ~ Well head - Ail outlets plugged Wel 1 sign - Attached to well Attached to well Attached to head guard Information correct ~ No Ye s No No No Cellar - Opened Fil led Covered WaterWell - Plugged off Yes No Rat Hole No Capped Ope n Exp la na ti on Open Fi 1 led Covered Ye s No Ye s No ~ ~o Photographs taken to verify above conditionsO No Explanaton Work to be done to be acceptable ~~_~ This well and location is (unacceptablq) to be suspended for the period of ~-~'~ l~thru /~-/~ Inspec ed b . -._ .~ ._--~1)-_ classified as Revised 8/24/82 Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION:/~ Address ~"_~_%- ~_~ _~-~_.~_., ,,~/~_.. Surface Location of Well Ft. F L, Ft. F Sec.__, T , R , M. Date Suspended /~-2.~-~ Permi t No. L API No. 50.~~]~~~ Unit or Lease Name Well No. '~~ Field & Pool ~'/~f[~, ~- ' Condition of Pad ._ _ Condition' of Pits Well head - Ail outlets plugged ~ No Well sign - Attached to well head Attached to well guard Attached'to Ye s No · ~[~ No Information correct No Cellar - Opened Yes Fil led Yes Covered ~ WaterWell - Plugged off No No No Capped Ope n Rat Hole Open Yes N° Fi 1 led Ye s No Covered ~ No Exp la na ti on ~///~ This well and location is (.~) (unaqceptable) to be ,.or Date: ' classified as ReviSed 8/24/82 Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFOrmATION-_ ~-~~~AP~ _d/C> __ ~ '~ Date Suspended Address ~"~ ~ .~, _~~~ ~~'~ ~ ~ ~ ---- Surface n~tiOn -of ~.~e~l - '~~ N0~- ./~~ Ft. F ~ L, ~Ft. F ~- L API No. 50 ~~--~~_~ Seci/O , T~ ~, R ~~, ~ M. Un,t-or Lease Wel 1 No. Field & Pool ~y~-_~/. - - ..... Condition of Pad ~)S _ _ . Condition of Pi ts ~ _ ~__ Well head - Ail outlets plugged ~ No Well sign - Attached to well head Attached to well guard Attached to Ye s No ~ ~o Information correct No Cellar - Opened Yes Fi 1 led Ye s Covered ~ WaterWell - Plugged off No No No Rat Hole Open Yes N° Fi 1 led Ye s No Covered ~ No Capped Open Expla nation__ ~/~ n io~ns~ ~No~ P~og~~__s ta, k~o_ ~//~< ~' _~._veri f~ abov~ con~/ _ ~__dit~:-/_ _ ~~' _ E xplanaton' Work to be done to be acceptable This well and lOcation is ~cqeptable_~ .(unacceptab~le) t,o suspended for the per~d ~-~7~~_~19~th~ru _~/& Inspected by:_'~_~ ~_ ~~~~ - _.__ - -· I be classified as Revised 8/24/82 Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: z~ ~--~~-- /~3/CJ_ ~)~) . ~ _ _~_ ~ Date Suspended Address ~~~ ~ ~ ~~ /~ ~~.~~' .... Location of Well 'Permit N6. S~rfa~ / Ft. L, F 'L API No. 50 ~ec.~, T_/~ ~"" R~~,- ~ M. ~ Unit or Lease Name Well No. ~' Field & Pool ~,f~ Condition of Pad ~' Condition of Pits . ~~ ! Well head - All outlets plugged No Well sign - Attached to well head Yes No Attached to well guard '~ No Attached to Information correct No Cellar - Opened Yes Fil led Ye s Covered ~ WaterWell - Plugged off Capped No Rat Hole O[>en No Fi 1 led No Covered Open Explanation, ~/~ Ye s No Ye s No Phot~ograp~ taken to verifv above.~onditions ~ No ~Explanaton ~~ WJ~ to ~ done to ~ acceptable ~~ ....... This well and location is ~epta~(unac.~ceptable) to. suspended for the ..period of ~ ~th~u ~ ~/~ Inspected by~_.i~ . · .. Date' ~f/~ i'-~~ . : ' .... be classified as Revised 8/24/82 H. D. Haley Manager of Alaskah Operations Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 October 17, 1983 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-i, B-2, B-3, B-4A,"C~~ C-2, C-3, C-4, D-I, and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells, and Conoco will be contacting one of your representatives to conduct an inspection of these wells each year as long as the wells remain under this status. Also attached is a completed 10-407 form requesting a change in status for Milne Point B-5 from plugged and abandoned to suspended. You will also find photographs enclosed covering the cleanup operations that took place subsequent to this year's inspection of Gwydyr Bay State #1 and #2A. Photographs are also included that show the new signs mounted on Milne Point C-4 and D-2A. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. H. D. Haley Manager of Alaskan Operations JTD/kp cc: A. E. Hastings, Anchorage A(~U STATE OF ALASKA C~,~1 ALASK IL AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX] OTHER [] 2. Name of Operator 7. Permit No. Conoco :Inc. 8:1-143 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-20663 4. Location of Well 1167' FSL, 2256' FEL, Sec. 10, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) KBE=48' GL=20' 12. I 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-1 1 1. Field and Pool Kuparuk Field Ch'eck Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [X]X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your repr'esentati¥.~sto conduct an inspection each year until the well has a plugged and abandoned status. 14. I hereb~,t~y thatJJ;;~e foregoing,, is true and correct to the best of my knowledge. Signed ~ ~~~ -~ Tit~eManagor of Alaskan Operations The space below for Commission use H. D. Hal ey Conditions of Approval, if any: Approved by ORIGINAL SIGN£B BY LONNIE C. SMITB Date 10-19-83 Approved Returned COMMISSIONER By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate H. D. Haley Conoco lnc. Manager of Alaskan Operations October 1, 1982 2525 C Street Suite 100 Anchorage, AK 99503 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble' Attached are com eted 10-403 forms for: Milne Point A-l, B-l, B-2, B-3, B-4A, ., D-l, Kavearak Point 32-25; and Gwydyr Bay State #2A. All of the above are classified as suspended wells and Conoco will be contacting one of your representatives to conduct an inspection each year until the wells have a plugged and abandoned status. Also attached is a completed 10-407 form requesting a change in status for Gwydyr Bay State #1 from suspended to plugged and abandoned. You will also find the photographs you requested concerning the recent inspections of Gwydyr Bay State #1, #2A, and Milne Point A-1. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. Yours very truly, H. D. Ha ley Manager of Alaskan Operations JTD/tt cc- G. A. Merriman - w/o attachments A. E. Hastings - w/o attachments £ STATE OF ALASKA ALASKA'~,',L AND GAS CONSERVATION~C~..MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I)(-I OTHER [] 2. Name of Operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well 1167' FSL, 2256' FEL, Sec. 10, T13N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) KBE=48' GL=20' 12. I 6. Lease Designation and Serial No. 7. Permit No. 81-143 8. APl Number 50-029-20663 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-1 11. Field and Pool ADL 47434 Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well Conoco will contact one of your representatives to. conduct an inspection each year until the well has a plugged and abandoned status. 14. I hereby certify that tJ~'fo~q~g is true and correct to the best of my knowledge. Signed ~,~~~~ Tit,eManager of Alaskan Operations The space below for Commission use % Conditions of Approval, if any: Approved Copy An inspection will be necessary by August 1983.. Returned By Order of Approvedby BY l]~RR'f W.ttUGL£R COMMISSIONER the Commission Date 10-6-82 Date Form 10-403 Rev. 7-1-80 Submit "lntentions"t~'r~ Triplicate and "Subsequent Reports" in Duplicate MEMORAI DUM Stat of Alaska TO: ALASKA OIL AND GAS CONSERVATION COMMISSION C. V/~,~e~on DATE: Ch a ~F~h ~---- THRU: Lonnie C. Smith Commissioner FILE NO: TELEPHONE NO: September 2, 1983 10SA:J10 FROM: Harold R. Hawkins Petroleum Inspector SUBJECT: Cleanup Inspection for Extension of Suspended Status, Conoco, Milne Point C-i, Surf. Loc. 980' FSL, 2195 ' FEL, Sec. 10, T13N,R10E, UM, Permit No. 81-143. W.edne..sda¥, .August 17,_1983: ~ile I was on the slope inspecting other locations for suspensions, I inspected Conoco's ~lne Point C-1. I found location clean and free of debris, and all require- ments of A.O.G.C.C. regulations were met. I filled out an A.C.G.C.C. field report which is attached. In summary, I inspcted Conoco's Milne Point C-1 .and found all requirements of A.O.G.C.C. regulations were met. I recommend approval of extension of suspension. Attachments Suspended Well and Location Report 20 LAC 25, ARTICLE 2 FILE INFORMATION: Operator ._ _~-O ~/~E~ _ Date Suspended Addre s s Surface Location of Well Permit No...~ ,~~ Ft. F_~____L, ~7 ~· Ft. F L-~ n SPI No. 50 Sec. /D ' T,~ ~, R~_~ ~- , CPM. Unit or Lease Name Well No. /~ -_ Field & Pool Condition of Pad ....... 7~- ~ ~ ~P Condition of Pits Well head - Ail outlets plugged No Well sign - Attached to well ~-a~ Attached to wel Attached to Ye s No Information correct No Cellar - Opened Yes Fi 1 led Ye s WaterWell - Plugged off No No No Capped Ope n Rat Hole Open Yes No Ye s No Explanation Photographs~ taken to verify above conditions Yes No Explanaton / Work to be done to be acceptable ._,,?:t..~-.~. ,,~!~.~_ ~" ..... ,~ This well and location is (unacceptable) to be classified as suspended for the period o 19 thru 3-I~ 19 ~. Inspected by: Date Revised 8/24/82 N O R T H . . . . · · 0 0 . Z;.! PAD C SECTION IO, TI:~N, RIDE C~ UMIAT MERIDIAN Alaska 0il & Gas Cons: VICINITY 'MAP . LOCATION IN SECTION ' .C,'.:: I 168' ; 2256' i$44' I PLANE COORDINATES JELL ~ NORTHIN~$ ...e......~...-- e .... e........ : : ' . I : 6 029 450.18 ~ [ 6 029 677.~5 ~ 558 1~1.12 4 : e 029625.19 · ~ ZONE 4 : ]. -"- 4 ~ 70029' 29.607" J 1490~1'34.086 · ! ' RSSI]I], O'F ii 3340 Arctic Boulevard, Suite 201, Anchorage, Alaska 99503 SCALE ~JOB NO. SURVEYOR : I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~ID THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRE~. ...... _ _ _ __ SURVEYED FOR: ~ ~ ~ ~ ~ ~~ ~ ~' DRAWN DL %~ v · i v ~V / ~ECKED RM --- FIELD B~K 10-82 I" = 2~' 82024 April 27, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Bill Van Alen Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill' Enclosed are the original Well Completion Report forms on and D-1 with original signatures. If I can be of further assistance, please call me at 279-0611. Yours very truly, ' Gary ~. Merriman Supervising Engineer kp cc' Correspondence file, Milne Point C-l, D-1 APR 91982 Alaska 011 & 13as ~ons. Commi~ion Anchorage ". \ STATE OF ALASKA { ALASKÁír , ." AND GAS CONSERVATION î ' IV~ .w1lSSION WELL COMPLETION OR RECOMPLETIOI\, REPORT AND LOG 22. Type Electric or Other Logs Run SP/GR/DIL/SFL/BHCS~ FDC/CNL/GR/NGT; ML/PROX.; HDT; RFT; SWC 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM O' 1101 01 2342. 01 98021 1. Status of Well OIL 0 SUSPENDED KJ SERVICE 0 GAS 0 ABANDONED 0 2. Name of Operator Conoco Inc. 3. Address 2525 C St., Suite 100, Anchorage, AK 99503 4, Location of well at surface 11671 FSL, 22561 FEL, Sec. 10, T13N, Rl0E, UM At Top Producing Interval Same At Total Depth Same 5. Elevation in feet (indicate KB, DF, etc.) 16 Lease Designation and Senal No KBE=48. G.L.=20. 'ADL 47'43; .' . :12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ',>~..~~ 12/24/81 2/17/82 3/18/82 P. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 104421 MD&TVD 7624 YES 0 NO::O: CASING SIZE WT. PER FT. GRADE 20" 94#/ft H-40 13 3/8" 72#/ft L-80 9 5/8"' 47#/ft L-80 ".; l .':it , 24. Perforations open to Production (I\7ID+TVD of Top and Bottom and interval, size and number) (See page 2 - Test Perforations) 71201-71331 (13 ) . 12 Spf @ 1200 Phasing: 71421-71671 (251) HOLE SIZE 26" 17}" 12i" 25. SIZE 3}" Classification of Service Well 7. Permit Number 81-143 8. API Number 50-029- 20663 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point No. C-l 11. Field and Pool Kuparuk River Field Kuparuk River Pool 15, Water Depth, if offshore \16. No. of Completions N/A feetMSL One 20. Depth where SSSV set 121. Thickness of Permafrost N/A feetMD 1,800':t CEMENTING RECORD Cement to slJrfac:e 3800sx Arctic Set II 2000sx Class G 150sx Arctic Set (I 200bbl Arctic Pack TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 69001 f)qoo. AMOUNT PULLED O. .. O. 01 O. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Sèe page 2 - Cement Squeezes . . . , PRODUCTION TEST Method .o(Qperation (Flow.ing, gas lift, etc.) 27. Date F,irst Production See pg." 3 Test Data .. . Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GA$-MCF TEST PERIOD to. " . CALCULATED. OIL,-BBL GAS-MCF 24-HOUR BATE, " CORE DATA F low Tubing Press., 28. C'Âsing p,ressure '. WATER-BBL CHOKE SIZE GAS-OIL RATIO" , WATER.-BBL OIL GRAVITY-API (corr) See pg. 4 - Core Data' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , Form 10-407 Rev. 7-1-80 CONTI NUED ON REVERSE SI DE RECEIVED APR 2 91982 Alaska Oil & Gas Cons. CommiSSIon' Anchorage Submit in duplicate 29. NAME chrader Bluff iddle Kup ower Kup ingak ag River hublik Sadlerochit Grp. Ivi shak Ka vi k Echooka isburne Kayak 31. LIST OF ATTACHMENTS _. - - ~- '} ') ""-'-1;' 30. GEOLOGIC MARKERS FORMATION TESTS MEAS. DEPTH Include interval tested, pressure data, all fluids recovered and gravit~, GOR, and time of each phase. ' TRUE VERT. DEPTH 37181 69581 71201 75761 89051 89571 (See pg. DST #5 DST #4 DST #3 for details) Same as measured Idepth 91331 97441 98971 99651 104101 DST #2 DST #1 (OH) .1 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .' s¡gnedAæ ~ Title SlJpv. Prod Eng Date A1ril lq, lqR? 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: I ndicate 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. Subm it 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 April 27, 1982 Ms. Elaine Johnson Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ~_~_.J STAT TEC- 1i .... t FILF: . Dear Ms. Johnson: SUBJECT: COMPLETION REPORTS FILED BOTTOMHOLE~~---gc~q~s TO THE As you noted in our telephone conversation on March 22, 1982, location of the top of the producing zone and the bottomhOle location for Milne Point C-1 should be as follows: Top of Producing Zone Location (@6959'MD) - 951' FSL, 2167' FEL Sec. 10, T13N, R10E, UM Bottomhole Location (@10,442' MD) - 913' FSL, 2168' FEL Sec. 10, T13N, R10E, UM As we also discussed, the bottomhole location for Milne Point D-1 should be as follows: 1564' FNL, 914' FEL Sec. 12, T13N, R10E, UM Thank you for bringing these errors to my attention and I apologize fo:r any inconvenience. If you have any additional questions, please call me at 279-0611. Very truly yours, Supervising Engineer kr cc: A. E. Hastings, Production, Anchorage G. A. Merriman, Production, Anchorage Working Interest Owners Milne Point C-i, D-1 Well Files RECEIVED APR 2 81982 Alaska Oil & Gas Cons. Commission Anchorage Cc n, Under Separate Cover Quantity Contents I co?~ Enclosed /'3o. C-I ~.ecord of Shipment of ~- ,~onfidential Information 3ue~ctee. ~-o q¥ 50'. Transm.~tta, Approved By (a,/~, i~e.,'r-i¢~,~, Date Instructions: Please acknowledge receipt promptly by signing and returning carbon copy. Received By Date Remarks · Transmittal Copy Only To 13-98 PCX1 7-79 NORICK OKLA. CITY · PF~INTED IN U.S.A. (conocO) o.oao Ina. -1 Under Separate Cover [~-Enclosed :)uantity Contents C.o("e... ~'~_ecord of Shipment of '~-' ./onfidential Information 5" 25o0 Transmittal Approved By ~. A. ~em ~ Date 4' ~' ~ Z ~ ~ f~.~' -- ~~ Instructions: Please acknowledge receipt promptly by signing and returning carbon copy. ~eceivedBy Date APR 2 1 1987 ~emarks ~as~ Oil a Gas 6u[l~, fransmittal Copy Only To 13-98 PCX1, 7-79 NORICK OKLA. CITY PRINTED IN U.S.A. April 20, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. C. ¥. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE- Milne Point C-1 -API No. 50-029-20663 Well Completion Report Dear Mr. Chatterton' Enclosed are two copies of the Well Completion Report for Milne Point C-1. Also enclosed are two copies of a transmittal letter listing data and mat- erials being submitted to your office as per AOGCC regulation 20 ACC 25.070 and as outlined in the AOGCC Permit to Drill approval letter of September 25, 1981. Upon receipt of these data and materials, please sign and return to this office one copy of the transmittal letter. If you have any questions about the information you have recei~.ved, please contact either Jim Fox or myself at 279-0611. Yours very truly, G. A. Merriman Supervising Production Engineer kp cc' Milne Point C-1 file, w/Attachments RECEIVED APR 2 1 1982 Oil & Gas Cons. Commission Anchorag~ ~ STATE OF ALASKA '¢'~)~~.~,i~J ALASKA (..,. AND GAS CONSERVATION CC,..NllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~Xi ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 81-143 .. 3. Address 8. APl Number 2525 C St., Suite 100, Anchorage, AK 99503 5o-029-2066.3 ,, 4. Location of well at surface 9. Unit o[ Lease Name 1167' FSL, 2256' FEL, Sec. 10, T13N, RIOE, UM Milne. Point Unit At Top Producing Interval 10. Well Number · Same Milne Point No. C-1 At Total Depth 11. Field and Pool Same -Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver Pool KBE=48' G.L.=20' ADL 47434 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., ~Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/24/81 2/17/82 3/18/82] N/A feetMSL I One 17. Total Depth (MD+TVD)18.PlugBackDepth(MD+TVD)19. DirectionalSur,veY10442, MD&TVD 7624. .. YES [] NoX~ [ 20' Depth where SSSV set I 21"l:'hickness°fPermafr°stN/A feet MD 1,8001+ 22. Type Electric or Other Logs Run SP/GR/DIL/SFL/BHCS; FDC/CNL/GR/NGT~ ML/PROX.; HUT; RFT; SWC 23. CASING, LINER AND CEMENTING RECORD · SETTING DEPTH MD CASING SIZE: WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" ~94#/ft H-40 O' IlO' 26"' Cement to surface O;" _ 13 3/8" 72#/ft L-80 O' 2342' 17~" 3800sx Arctic Set II O' 9 5/8" 47#/ft L-80 O, 9802, 12~" 2000sx Class G O' 150sx ArCtic 'Se.l~ [ I O' , 200bbl Arctic Pack .... ' , , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD · , interval, size and number) " SIZE DEPTH SET (MD) PACKER SET (MD) (See page 2 - Test Perforations) 3~" 6900, 6900' 7120'-7133' (13') 7142'-7167 (25) 12 spf @ 120° phasing ' ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ', 'i~ D,EPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · " See page 2 , Cement Squeezes · . .. 27, PRODUCTION TEST` . Date F.i.rst Production I Method of Operation (Flowing, gas lift, etc.) See pg. 3 Test Data 'I · , Date of T~st Hc;ursTested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO . . TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. : 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See pg. 4 - Core Data i~ ~ [ ~ I V APR 2 i i,9°82 ~J~.s!<a 0]1 & Ga'; Cons, C0mrn]ssiu~ ,'~nch0ra[m ,-, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and'gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Schrader Bluff 3718' Same (See pg. "' for details) qiddle Kup 6958' as measured DST #5 _ower Kup 7120' depth DST #4 <ingak 7576' Sag River 8905' DST #3 · 5hubl i k 8957' Sadlerochit Grp. Ivishak 9133' DST #2 Kav i k 9744' Echooka 9897' Lisburne 9965' DST #1 (OH) Kayafk 10410' ....... ~u Uons C°~n~issio~l 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed · TitleSU.DV, Prod. Eng. Date April lq: 1982 .. 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 cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. I'tem 28: If no cores taken, indicate "none". Form 10-407 Milne Point No. C-1 'Well Completion Report an( ~g (continued) 24. Test Perforations DST # 1 - was an open hole DST at 10290'- 10442') DST # 2 - 9134' to 9143' (9'), 12 spf at 90° phasing DST # 3 - 8904' to 8934' (30'), 12 spf at 90° phasing DST # 4- 7142' to 7167' (25'), 12 spf at 120° phasing 7120' to 7133' (13'), 12 spf at 120° phasing DST # 5 - 6959' to 6968' (9'), 12 spf at 120° phasing 26. Cement Squeeze Squeeze # 1 - P & A open hole from 9802' to 10442' with 200 sx Columbia "G" 0.75% D65, 0.20% D46, 0.20% D28. Test with 20,000 # WOB and 1000 psi. Top of cement at 9548'. Squeeze # 2 - Abandon perforations from 9134' to 9143'. Squeeze 100 sx Class "G" cement with 0.75% D65, 0.75% D59, 0.20% D46 into perforations. Spot 20 sx cement on top of retainer. Set at 9075'. Squeeze # 3 - Abandon perforations from 8904' to 8934'. Squeeze..lO0 sx Class "G" cement with 0.75% D65, 0.75% D59,0.20% D46 (mixed to 14.6 ppg.) into per- forations below retainer set at 8852'. Spot 50 sx on top of retainer. Squeeze #~n4 40sPf from 7109'.to 7111'. Squeeze with 100 sx Class "G" cement with 0.5% 5~, 5% D65, 0.1% D13, 0.2% D46 (mixed to 15.8 ppg.) into perfor' ations below retainer set at 7059'. Spot 25 sx on top of retainer. Top of cement at 7002'. Drill out retainer and cement to 7290. Test squeeze job to 1 300 psi. Squeeze # 5 - 200 sx Class "G" cement with 0.5% D59, 0.5% D65 0.1% D13, 0.2% D46 below retainer set at 7028' Spot 25 sx cement on top of retainer. Drill out cement and retainer from 70~6' to 7111' and test to 1325 psi. Squeeze # 6 - 4 holes at 6970'. Set bridge plug at 7100'. Squeeze with 193 sx Class "G" cement with 0.5% D59, 0.5% D65, 0.1% D-13, 0.2% D46 below retainer set at 6900'. Spot 32 sx of cement on top of retainer. Drill out retainer and cement from 6900' to 6970'. Tag bridge plug at 7100' and test squeeze job to 1500 psi. Mille Point No. ~-I )og Well Completion eport an~ _ (continued) 27. Test Data Date o~ 'Test Method of Operation Hours Tested Flowing Tubing Pressure, psig Casing Pressure psig PrOduced Oil, bbl Produced Gas, MCF Produced Water, bbl Choke Size 1 2/21/82 O.H. DST 2h, 15m N/A 0 2 2/25/82 C.H. DST 6h, 15m 550 w/20/64" 10-190 w/40/64" 0 .,. Test Number 3 2/28/82 C.H. DST 2h,.OSm N/A 0 0 0 0 0 10 0 0 221 0 Full open 20/64 Full open GOR N/A N/A Flowing BHP, psig 721-9804240_4030 Final Buildup 1436 4475 Pressure, psig Maximum Rates: BOPD 0 0 BWPD 0 2995 Gas, MCFD 0 72 Oil gravity N/A N/A °API 4 3/5/82 to 3/6/82 C.H. DST 22h 15m 0-130 0 5 3/10/82 to 3/11/82 C.H. DST 39h 55m 10-400 0 N/A 561-543 3590 0 0 0 N/A 445 125 4 Ful 1 6pen 300 2704-1878 3518 1230 0 388 20° 209 97 0 12/64" to Full open 460 1470-2653 ~674 922 0 380 22° Oil & Gas Cons. CornmissM~ :-',,nchoragg 'Milne Point No. C-1 Well Completion Report and Log (continued) ONF DE AL 28. Core Data Core No. 1 (6900'-6923') Core No. 2 (6923'-6983') Core No. 3 (6983'-7043') Core No. 4 (8711'-8730') Core No. 5 (8900;-8954') Core No. 6 (9125'-9185') Li thol ogy Shale (100%) Shale (71%) Sandstone (19%) Interlam. Ss& shale. (10%) I nterl ami nated sand & shale (100%) Shale (100%) Sands tone (100%) Shale (17%) Sandstone & Cong 1 omera te (83%) Porosits... Fractures & Apparent Dips Pressure of O,G,or W poor common 30-45° frac None planes; no apparent dip. good Some 30-45° fracs in Good shows in shale,~2horiz, dips sandstone' increase to 10°-25° in interlaminated zone. fair O-lO° dip, lenticular bedding. fair to good shows in sand stringers. poor no apparent dip None fair fair no apparent dip O-lO° apparent dip Minor fracturing at 45o-60° from vertical. Scattered bleeding of O&G. poor to fair shows in sandstone. Oil & Gas Cons, ARLEN EHM GEOLOGICAL CONSULTANT SIDEWALL CORE )PERATOR CONOCO IELL NAME_ ~II..HE PT IUN NO._.__L_--_TOTAL DEPTH 9~2G' REMARKS DESCRIPTION ,, ,DATE ~ NO. SHOT -- ~ AMT PROB NO DEPTH REC ~ FORM 0 S C F CF DESCRIPTION . , , , ~ ~.~ ~' . , , ~ , 4 ?5?? ~" vp " - - sf - ~.~ ' ~'~ ~ ~1~ · ' . ¢~ ~1~ ~ ~ ' ' ~ II' ,, Y ,,, ,, , ,, , ~ , ,, , cr~M , ...... , J"C~,-~ " s~,,~ a.~ ~; "' 4,' ,~L ' ~ f ~~' "'% k ."~ , ,, blw ,, , ' ~ " I~"t''*"~' ~ I " , **-- ' b.k. I ¢ Y ....... i Yr" ~5 7141 ~. je-~ ,, r., ~.**-*v~ ~-- , ARI, EN EHM GEOLOGICAL CONSULTANT SIDEWALL CORE DESCRIPTION PERATOR C ELL NAME ~ ! 1NE PT UN NO. t TOTAL DEPTH REMARKS DATE 2 /, B / 19 ~?._ _ NO. SHOT Y4 NO. RECOVERED ~'~ - AMT PROB NO D[PTH ! REC ~ FORM O S C F CF DESCRIPTION , ~ , , , , ~ , ,, 54 T/SZ ;. , , ~ ' · ~ ,~.~ ~'. , , J Y4" i - . _ ~iddl~ bl~ ~; ~;1 ~a¢ ~r ~ ~l~~ · ,, _ ..... ,, ., p4 G ~ r ,',' ,, ~ t~7'1~i',. ~ ~.~. ~,,~,~ ~ , , ) AR LEN EHM ') GEOLOGICAL CONSULTANT '~ SIDEWALL CORE DESCRIPTION PERATOR . CONOCO DATE ,, 'ELL NAME,, ,~IL~' FT C-I, NO. SHOT, ~'~ , NO. RECOVERED.~'} UN NO. I -TOTAL DEPTH ?~1~ REMARKS AMT PROB ' NO DEPTH REC ~) FORM O $ C F CF DESCRIPTION . , , , , -- c~ ~ / ' , 55 4850 , , , ,, ,, ,, , ,, , , , , ,,, , , . , , , ,,, ,, , , ,,, ,,, _ , , ,,, , DEPTH LITHOLOGY DESCRIPTION 1 BEDDING ANGLE SED. STRUCTURES SHOWS BASIN' )[/. 5 Io]p~, DEPTH: CORE DESCRIPTION REPORT. AREA' ~"[~ ~' ~~' . DESCRIBED BY: ~~'~ ~~~~,,. RECOVERY' DATE' _ I/I.~_/~ PAGE' , III I I ]11 I ~ , I I DEPTH LITHOLOGY DESCRIPTION ' BEDDING ANGLE SED. STRUCTURES SHOWS WELL' BASIN- AREA' DEPTH ~~.1 MIJ~,.y CORE DESCRIPTION REPORT - ~DESCRIBED BY' ~S['~/~ut~5, LITHOLOGY DESCRIPTION DATE BEDDING ANGLE CORE NO: DEPTH' RECOVERY' _1~0~, PAGE: ~ OF ~,~__. SED. STRUCTURES SHOWS ~~' ~.' ~-' .... ,ili II ~o.~.o. AREA: ~t'/~ ~ ~o/4~ O~ CORE DESCRIPTION REPORT &-~ ¢ ....... . DESPISED BY' ~~'~ /~~~. RECOVERY' ,, , ' ..... DEPTH LITHOLOGY DESCRIPTION BEDDING ANGLE SED. STRUCTURES SHOWS' ' ,'; I I II I I ¢ ,-~-- I I II I II ~~ ~ II I I '1 Il -~ .-~-~ ' ~ ~ ' ' J ~ ..... DEPTH LITHOLOGY DESCRIPTION CORE DESCRIPTION REPORT DESCRIBED BY:..~U,~S /~c~]~tO.4~ DATE' ~ RECOVERY' BEDDING ANGLE PAGE' 2 OF ~' SED. STRUCTURES r~k ~ ~ rom k. i~'~'~-I,~-~. SHOWS AREA' ,'q,'/.~ ~,~!-/L /_~1;-/-- CORE DESCRIPTION REPORT / ' DESCRIBED BY: ,..~¢x.o ,~.~//J~r'o.-~S/U::L~.~'"" RECOVERY' , DATE: I / ~ / ~~ PAGE' ~OF DEPTH LITHOLOGY DESCRIPTION BEDDING ANGLE SED. STRUCTURES SHOWS ~/Io~. , WELL' BASIN' AREA: DEPTH LITHOLOGY DESCRIPTION CORE DESCRIPTION REPORT / DESCRIBED BY: ,. ~0 DATE: ~ BEDDING ANGLE CORE NO: _ OE.T.. _ RECOVERY'_ SED. STRUCTURES SHOWS Fl ctor: ~"3 : ~r~ (,~t JFl~or:--- ~i lai ~3 ~+. CZ.L+.. v. slo~ -p~l~ U ~t lo ,-o ~,...e,,_,~ ,'~ DEPTH LITHOLOGY DESCRIPTION CORE DESCRIPTION REPORT / DESCRIBED aY: ..~o~ut'~_x~ DATE: BEDDING ANGLE RECOVERY' _ ~'~- ? SED. STRUCTURES SHOWS SMOHS S31:IN£ONLIIS 'OqS : 3DVd : Al::i~l^Og~t:l :Hid=la · ON dUO~) 3-1DNV DNlOO38 NOIldlLI:DS::iO ADO'IOHII-I Hld3O 'NISV8 ' -1'13M CORE DESCRIPTION REPORT DESCRIBED BY' ,~.K, DATE' DEPTH Cll'~ LITHOLOGY DESCRIPTION BEDDING ANGLE CORE NO: DEPTH' RECOVERY' GO~ PAGE' .._J.._ OF_.~ SED. STRUCTURES SHOWS DEPTH: cl BASIN: Id. ~k~¢,. DEPTH' clt;kS-~t6r'.;)'~ AREA: l'~i~L"-~q k,~Nt"~ CORE DESCRIPTION REPORT ' ' DESCRIBED BY: ~.~~~ RECOVERY: ~01 , DATE: _?~,~ PAGE' , ~ OF_5 J ~ II I I ~ I II DEPTH ~ LITHOLOGY DESCRIPTION BEDDING ANGLE SED. STRUCTURES SHOWS I I il _ I I I I Il Ill Il , _ ..,. , ~ i ' ~c ~ ~ ~ . WELL' M.,~ t,}.. C--! BASIN- _ I,,3. ~L~,~ AREA: _I~i'L~~ k)09~. CORE DESCRIPTION REPORT DESCRIBED BY: ,va~.lS'~t~.SHA59 DATE' DEPTH ~lS~.~ qlSq ~ LITHOLOGY DESCRIPTION BEDDING ANGLE CORE NO: _~.. , DEPTH' _c}J2..5- ~',!85 = (oO RECOVERY' ,, ~::)~ , PAGE' ~ OF.aS__. SED. STRUCTURES SHOWS I I lit I ~ I ~,~ ~ F ~1 I I BASIN' , ~. ~~ il I DEPTH: ~1~5-~i~5=60' _ AREA' ~[~+ ~ CORE DESCRIPTION REPORT - ' - DESCRIBED BY' ~g~~%~ RECOVERY' _ ~ , . I I II .......... I I ' ' DEPTH' LITHOLOGY DESCRIPTION BEDDING ANGLE SED. STRUCTURES SHOWS II I I I I I I I I II ...... ~ ~r I I L II L .... .. I I Il ~ ,~ ' ". ...... IH ] I ~ II I II Il ~ / '1 II "" ." "1 _11 ~ I ]11 I I BASIN' ~, ~~ ~ DEPTH' ,~1~5-~ lSS=~o' _ AREA: ~i~~. O~1~ CORE DESCRIPTION REPORT - . DESCRIBED BY' ~.~~~H~ RECOVERY' GOI . , DEPTH LITHOLOGY DESCRIPTION ' BEDDING ANGLE SED. STRUCTURES SHOWS .,-- "- .... .., I J , .~" .............. , II I " ,, ,. ., ~ . ......... qt8+ Go~ ~ " , ,, " ' I I III II I I I ~ ~ ,-, ...... Il i, ~,~..~ ~~ i ,~ i~ ~ ~o~o:,i ...... . , .... DEPTH: ,~-~3 = 2~ cone D~SCn~PT~OH REPORT AREA' . ~i~U~~ ..O~,~ , . DES~IBED BY: N.~. ~~H~ RECOVERY' 2~ ..... ~~ ~ ~ c~Bo~ ~o~, DATE' t/[~/~ PAGE' ,, I OF, I I I I II III I I I I I II '"' """ DEPTH LITHOLOGY DESCRIPTION BEDOING ANGLE SED. STRUCTURES SHOWS I I I I I J ~ I III II - ~ s.[.~.. ,~ ~t~.> i~:~ ~,~~-~, II I I I II I I I . I III I I I II II I ' ' ' id I~ DEPTH: ,.~.ct2d~ - AREA: ~?~iL.U~- ~1:~- L~H ~1- ~[~"I-II~IN CORE DESCRIPTION REPORT RECOVERY' !oo°//o ( - ' . ~ DESCRIBED BY: ~,:b<~-i~vJ/:b/~JtF_.~ ' - - - / DATE: I / I"/c/~;:L PAGE', I II I I I I I I I I ~ I I I I I I DEPTH LITHOLOGY DESCRIPTION BEDDING ANGLE SED. STRUCTURES SHOWS II I I III1 i I II I ill I I I I II I I Il I III I I III I III II I I WELL' ~_..,' I BASIN' IG. $ L, ol:'~: AREA' DEPTH ~l~¢-LtJ~tl~ll~{~,y CORE DESCRIPTION REPORT, "----DESCRIBED BY: DATE: LITHOLOGY DESCRIPTION BEDDING ANGLE CORE NO: , ~ DEPTH' _~ci2.~,- ~jl~ = (oc~' .~cov~.¥. ~o~'¢o. ('_~.a') PAGE' ~ OF ~,.~., SED. STRUCTURES SHOWS WELL' BASIN: AREA' DEPTH CORE DESCRIPTIO~I REPORT/ DESCRIBED BY: //' DATE: LITHOLOGY DESCRIPTION BEDDING ANGLE CORE NO' DEPTH· RECOVERY' PAGE' 3 OF_ ~ SED. STRUCTURES SHOWS 'P~.-A-o I- AREA' Ht,gt,,l~ 'PT ~-3,u,.."'r- CORE DESCRIPTION REPORT RECOVERY: _Icj' ( - ' ....... DESCRIBED BY: .~SH~N/.]:~d!L:'~ ,. I~. ~c~4 i~ ~ boX~ ~ 5' ~. DATE: ,-z~-~ PAGE' J OF~ _ DEPTH LITHOLOGY DESCRIPTION ' BEDDING ANGLE SED. STRUCTURES SHOWS ~_ '= " - .... ~ ~ I I '. II II I I =, I II , ...... ~ ~ ~ _ _ I I .I ~. H I ~_ '. _ II ..... ~ .......... ~ _ ~ , ~ , . I I I [ m 1~ I I I I II ...... 'D CONFrDE L Well History MILNE POINT NO. C-1 - CONOCO, ET AL. AP1 NO. 50-029-20663 Date Operations 12-14-81 to 12-12-81 12-24-81 Move in and rig up drilling rig and support facili- ties. Set conductor pipe (20",94#/f~t) @ 110' KB. Spud well at 1800 hours. 12-24-81 to 12-27-81 12-28-81 to 1-1-82 Drill 17%" hole from conductor shoe to 2344'. Run the following logs: SP/GR/Dual Induction/SFL from 2325' to 110' and GR/BHCS from 2291' to 110' Run 13-3/8", 72#/ft., L-80, Btrs surface pipe to 2342' and cement with 2"538 sks. (420 bb.) of Dowell Arctic Set cement. Cement bridged off and set up from the float col{ar to the surface. Cement was drilled out and circulation established. 1-2-82 to 1-5-82 Cement retainer set at 2233', pumped 3800 sks. (630 bb~,.) of Arctic Set II, circulated to surface, and displaced drill pipe with full returns throughout. 1-6-82 to 1-14-82 Drill 12¼" hole from 2343' to 6800'. Run GR/SP/DIL from 6800' to 2338'. 1-15-82 Drill 12~" hole from 6800' to 6900'. 1-16-82 to 1-17-82 Core No. 1 - Core from 6900' to 6923' (jammed barrel); recovered 20' of 4" diameter core. Core No. 2 - Core from 6923' to 6983'; recovered 60' of 4"~diameter core. Core No. 3 - Core from 6983' to 7043'; recovered 59' of 4" diameter core. 1-18-82 to 1-26-82 Ream 8%" core_hole to 12¼" from 6900' to 7043' and drill 12¼" hole from 7043' to 8716'. Run SP/GR/DIL/SFL from 8693' to 5700'. 1-27-82 to 1-28-82 Core No. 4 - Core from 8710' to 8730' (jammed barrel); recovered 20' of 4" diameter core. Ream 8%' core hole to 12¼" from 8710' to 8730' and drill 12¼" hole from 8730' to 8900'. 2 t , Sz Core No. 5 - Core from 8900' to 8954' )jammed barrel); recovered 54' of 4" diameter core. ........ ~'~" Ream core hole to 12¼" from 8900' to 8954' and ,.~,lc~0~a[~ drill 12¼" hole from 8954' to 9125'. Well History Milne Point C-1 Page 2 CONFIDENTIAL 1-30-82 1-31-82 to 2-4-82 2-5-82 to 2-6-82 2-7-82 2-8-82 to 2-9-82 2-10-82 to 2-13-82 2-14-82 to 2-17-82 2-18-82 to 2-20-82 Core No. 6 - Core from 9125' to 9185'; recovered 60' of 4" diameter core. Ream 8~" core hole to 12¼" from 9125' to 9t85' and drill 12¼" hole from 9185' to 9825'. Run the following logs from T.D. (9816') to Surface casing (2338'): SP/GR/DIL/SFL/BHCS - misrun SP/OR/DIL/SFL SP/CR/DIL/LL8 FDC / CNL/NGT SP/GR/DIL/SFL/BHCS ML/Prox. HDT (dipmeter) - tool failed on surface - LL8 affected by borehole size. Make a wiper trip and ream bottom 120'. Run Repeat Formation Tester for 35 pressure setting and 2-seven gallon fluid samples (7152' and 7125'). Shoot 54 sidewall cores, recover 53 cores. Stage 1 Run 9-5/8", 47#/ft., L-80, Btrs casing with shoe at 9802'. Cement around shoe with 825 sks. (232~bbls.) Class G cement (14.9 ppg.) with 0.75% D-65, 0.75% D-59, 0.3% D-13, 0.2% D-46, 20 lbs/sk D-30, and 3% KC1. Displace with 710 bbls. mud, with 15 bbls. of returns to surface. Stage 2 Open D.V. collar 7690' and pump 1175 sks. (24]. bbls.) Class G cement (15.8 ppg.) with 0.5% D-65, 0.5% D-59, 0.2% D-46, and 3% KC1. Displace with 564 bbls. of water and close D.V. collar. Stage 3 Set D.V. packer at 2219' and ouen D.V. collar, pump 220 bbls. of Arctic Pack followed by 150 sks. (25 bbl.) of Arctic Set I cement, displace with 165 bbls. mud and close D.V. collar. Drill 8~" hole from 9825' to 10,442'. Run the following 10gs from T.D. (10,442') to 9-5/8" casing shoe (9802'): SP/GR/Dual Induction/SFL FDC / CNL/NGT BHC/GR HDT Well History Milne Point C-1 Page 3 CONFIDENTIAL 2-21-82 2-22-82 2-23-82 2-24-82 to 2-25-82 2-26-82 2-27-82 2-28-82 3-1-82 to 3-2-82 Run CBL-VDL-CCL-GR from 9802' to 2330'. CBL showed poor to no bonding over entire interval logged. Run Sperry Sun Gyro-Survey from 9750' to surface. Run open hole DST_~I - Lisb_. ,-- .... / '_-- Packers set at 10,290', 2000' diesel cushion. Open tool at 15:15 (2-21). Close tool @ 17:30 (2-21). Reverse out drill string. P&A open hole - pump 20 bbls water, 200 sks. Columbia "G" 0.75% D65, 0.20% D-46, 0.20% D-28, followed by 3 bbls. water & displace with. 168 bbls. of mud. Cement in place at 14:30 (2-22). Tag top of cement at 9548' with 20,000# W.O.B. and 1000 psi. Run CBL-VDL-CCL-GR.under 1000 psi pressure from 9450' to 2330'. Rig up Schlumberger and set bridge plug.at 9185'. Perforate 9134' to 9143' with 12 spf. R~n DST f/2~ Packer at 9085', bottom of tail-pipe at 9'118', 5250' diesel cushion. Open tool at 15:00 (2-25), close tool at 2i:15 (2-25). Reverse out. Set EZSV at 9075'. Establish injection rate at 3 bpm @ 1750 psi and squeeze 100 sks. Class "G" with 0.75% D-65, 0.75% D-59, 0.20% D-46 below EZSV. Initial squeeze pressure 3½ bpm @ 2100 psi. Final squeeze pressure 1 bpm @ 2400 psi. Cmt. mixed @ 14.6 ppg. Spot 20 sks. cement on top of retainer. Perforate w/Schlumberger 8905'-8934' @ 12 spf. Rig up for DST #3 and wait on daylight. R~Set packer at 8868'. Open tool at 05:55. Close tool at 08:00. Reverse out. Set EZSV at 8852'. Establish injection rate of 3% bpm @ 1100 psi. Squeeze 100 sks. Class "G" cmt.~with 0.75% D-65, 0.75% D-59, 0.20% D-46 (mixed to 14.6 ppg.) below EZSV. Initial squeeze pressure 3 bpm @ 1000 psi, final squeeze pressure 2 bpm @ 1500 psi. Spot 50 sks. on top of EZSV. Perforate with Schlumberger 7109'-7111' @ 4 spf. Set EZSV @ 7059' and squeeze 100 sks. Class "G" w/0.5% D-59, 0.5% D-65, 0.1% D-13, 0.2% D-46 (mixed to 15.8 ppg.) below EZSV. Initial squeeze pressure 3 bpm @ 1100 psi, final squeeze pressure % bpm @ 1500 psi. Spot 25 sks. on top of EZSV. Top of cement at 7002'. :i~:~ E ~i ~ i~ ~ Well History Milne Point C-1 Page 4 CONFIDE AS Drill out cement and EZSV from 7002' to 7290'. Test squeeze job to 1300 psi. Set EZSV at 7028' and squeeze 200 sks. Class "G" cement w/ 0.5% D-59, 0.5% D-65, 0.1% D-13, 0.2% D-46 below retainer followed by 3 bbls. HAO and 61 bbls. mud. Initial squeeze pressure 1~ bp~ @ 1450 psi, final squeeze pressure 1/8 bpm @ 1900 psi. Spot 25 sks. cement on top of retainer. 3-3-82 Drill out EZSV and-cement from 7026' to 7111' and test to ~1325 psi. 3-4-82 Perforate w/Dresser @ 12 spf: 7167'-7142' and 7133'-7120'. 3-5-82 to 3-7-82 DST_~j. Packer set at 7069', tail at 7100', 6600' diesel cushion. O~en tool at 09:15 (3-5-82)· Shut-fn well at 07:30 (3-6-82). Obtain 3 downhole samples with wireline. Reverse out drill string 10:30 (3-7-82). 3-8-82 set'=Ez drill bridge plug at 7100'. Perforate 4 holes at 6970'. Set EZ drill cement retainer at 6900' and squeeze 193 sks. Class "G" cement w/0.5% D-59, 0.5% D-65, 0.1% D-13, 0.2% D-46 below retainer followed by 3 bbls. water. Initial squeeze at 2 bpm and 1300 psi. Final squeeze at 1/8 bpm and 3200 psi. Spot 32 sks. on top of retainer. 3-9-82 Drill retainer at 6900' and cement 6903' to 6970'. TIH to bridge plug at 7100' and test squeeze to 1500 psi. Perforate with 12 spf from 6959' to 6968'. 3-10-82 to 3-11-82 DST #5. P~_cker set at 6913'; tail at 6944' with 3900' diesel cushion. Open tool at 06:03 hrs. (3-10-82). Close tool for final build-up at 21:58 hrs. (3-11-82). Reverse out drill string.· 3-12-82 to 3-14-82 Drill bridge plug at 7100' and push to bottom. Run in hole with junk basket and guage ring. Stuck at 6920'. Pull 2000# on tool and pull out of rope socket. Tool fell to bottom. Run second junk '~'~. ~j{~ ill ~'~ basket and guage ring to 7000'. Make up Otis packer ~ and tail assembly and run in hole. Packer set at ~,~,~ 2210' - operator pulled out of rope socket. Attempt a~ ~ ~ ~0 to fish packer with overshot· Could not work fish ~..~.~&~Cc~.C~i~!is~i0~¥P or down Mill on fish at 2216 Milled slips ~/~ ?~i~h~;a§9 and packer assembly, fell down hole. 3-15-82 Run in hole with fishing tools to 7624', could ~ot wemi ~story -Milne Point C-1 Page 5 3-16-82 3-17-82 3-18-82 CONFIDENTIAL spear fish. Run in hole with bit and casing scraper. Ream across DV collar at 2219' and work scraper from 6900' to 7200'. Run junk basket and guage ring to 7000'. Run Otis "WD" packer and tail assembly. Set packer at 6900'. Displace mud with fresh water. Displace fresh water with 9.6 ppg. NaC1 water with 0.25 lbs. per barrel Paraformaldehyde; 10 gal. per 100 bbls. LD8585, 0.5 gal. per barrel A303. Displace hole with diesel 2000' to surface. Nipple down BOP. Install temporary abandonment cap. Release rig at 10:00 hrs. 3-18-82. Place on standby. 4-8-82 to 4-11-82 Activate rig at '06:00 hrs. Nipple down'work Gray tubing spool and nipple up FMC tubing spool, mud cross, BOP's and choke and kill lines, and pressure test. Run Otis seal assembly on 3%" 9.3# DSS-HT tubing with Camco gas lift mandrels and Cameo subsurface safety valve. Space out tubing string and make up 13½" x 3½" tubing hanger. Pump 135 bbls. diesel down tubing string and attempt to land tubing~ hanger. Hanger would not land in head right. Machine 0.050" off O.D. of hanger and install new seal rubbers. Land tubing hanger in tubing head, run in lock screws and test Seals to 5000 psi. Rig up to 3%" tubing and test tubing and seal assembly. Nipple down BOP stack. Nipple up tree and test to 5000 psi. Release rig to standby at 1600 hrs, 4-11-82. Status of well - SUSPENDED February 22, 1982 Mr. Terry Lucht Conoco, Inc. Suite 411 Calais Building Anchorage, Alaska 99503 Dear Mr. Lucht: Please find enclosed the Re: Our Boss Gyroscopic Survey Job No. Boss-16973 Well: C-1 Milne P6int Unit (SECl0 T13N R10E) Kuparuk RiVer Field. North Slope, Alaska~~ Date of 19, Operato Boss Gyroscopic Mult Thank you for ,r~Urvey: is~ ' i:~..~'~~'~6~opies of our '.~~y~n the above well. g' ' . , ~... ity to be service ~.~~ " Sincerel~y., NL SPERRY-SUN, INC. 1982 Ken Brous/sard District Manager. KB/pr Enclosures '-'1 ~~'11 ' :--:F'ERRY-oJN WELL .:._RVEYING COMPANY ANCHORAGE ALAc, KA ......................... (SECiO TI~,N RIOE · CONOCO IIqC. C-1 MILNE POINT LINIT KUF'ARLIK RIVER FIELD ALASKA VERTIr:AL SECTION C:ALL-:ULATED ALONG CLOSURE TRUE SUB-SEA COURSE ,.T,; MEA.. LIRED VERT I CAL . VERT I CAL .. I NCL I NAT I ON DEPTH DEPTH DEPTH BEG M I N (') 0 0 0.00 -48,00 100 100.00 52.00 200 199.99 151.99 300 299.98 251.98 400 399.97 351.97 500 499.96 4.51.96 600 599.96 551.96 700 699.95 651.95 800 799.95 751.95 900 899.95 851.95 1000 99?.94 951.94 1100 1099.93 1051.93 1200 1199.92 1151.92 1300 1299.90 ' 1251.90 1400 1399.88 1351.88 1500 1499.87 1451.87 164)0 1599.87 1551.87 1700 1699.87 1651.87 1000 1799.87 1751.07 1900 1899.86 1851.86 0 0 0 54 1 12 1 6 0 52 0 34 0 24 0 17 0 21 0 46 COMPLITAT I ON ~ DATE FEBRUARY DATE OF SURVEY FEBRUARY BOSS GYROSCOPIC SLIRVEY :dOBNUMBER BOSS-16973 .... KELLY BUSHING ELEV. = OPERATOR-MILAM PAGE 1- 19, 1 t782'~ 4© o0 F T L. uUR._E DIRECTION DEGREES DOG-LEG ' '. --TOTAL ' ' -' I-'1 ~ .... _SEVERI.FY...~ REL. TAN~LLAR._ COORDINATES ..... VERTICAL DEG/IO0 NORTH/SOUTH EAST/WEST SECTION N · -, 4.39 W 0.60 O. :z; 1~.39 W 0 '-"" . ..... :~, ':' S Q"- ~.y, I t~. W O, S 24.69 W 0.39 5.29 S 40, 0 W 0 t4 6 01 10,19 E 0,37 6,64 S 6, 3'~/ E 0 16 7 '-'":' . . = .~,,~i S :..60 E ~'- '" 97 '-' L~Y E 0.11 ,Z, · E O. 34 ................ 9. 6.4._.S.. 0.15 9 o~, S 0, "'~ = 17 E ,:,~ I 0. ~" O. 37 .......... :.l_O..~PS.._ S m' 6..22_.E :~_ 0.27 11 .62 ._,c. 6 .72 E N 0.59 11.94 S 6.60 E ............... N 37; '-"- '~' '" _ ~,~. i 1 .................... ;,. _1 ~, _.E .... o N 30. 73 10.,_,4 S 6.'~]¢,c E . O. O_ E ........... 0.00. 0.00 ..................... 0.00 ................ 0.04 W 0.26 W .- .... 0.67 .'W 1.37 W 2.03 W .......... 2. ~8 .W . 2.70 W' 2.52 W _2.08...W 1.43 W 0.32 W 1 ..51 ..E 3.52 E 0.00 O. 4'.-? 1.71 · " 8'7 .. :3.72 4.4.7' 5.03 5.57 6.33 7.26 .:.. 17 :-__: · · ':?. 66 10.4:_:: 1 1 ':'Pi 1 '.--' 2'-? 1'--' (:)7 1:_'-:. 2:4 1 .- . 'T//-, · .-. 21 2000 1999.85 1951.85 0 2100 2099.85 2051.85 0 2200 2199.85 2151.85 0 2300 2299.84 '2251.84 0 2400 2399.:33 2351.83 0 2500 24.99.82 2451.82 0 2600 2599.81 2551.81 0 270(I 2699.80 2651.80 0 2800 2799.7? 2751.79 0 2900 2899.78 2851.78 0 · :-, ,., 1.8' 25 ..... S 63.69. 26 S 77.19 E 51 S 73.60 E 52 . .S.36.19 E 53 S 45.50 E 43 S 39.69 E 48 ~S.34.60 E 51 S 41.60 E 43 S 47.50 E 0.15: 13.06 S 11.10 E 0.19 14.09 S 12.05 E 0.112 .......... 15.16 S ..... 12.85 E O. 12 16. :30 S 1:3.75 E 0.15 17.29 S 14.72 E 11. 12. 12. 13. 14. 15. 16. 18. 10.~. 20. :31 58 1:3 73 24 60 8:3 CONOCO INC. C-1 MILNE POINT UNIT KUPARUK RIVER FIELD ALASKA "" ' "' '" I '-;I F"' '~'YING I"FINF'ANY ~:,F- ERRY-~=,L N WELL .= _ nv~= _-_ (SECiO T13N RiOE ANCHORAGE ALASKA I':C, MPI_iTAT I ON DATE FEBRUARY 22, 1':/;:"-~...~.,.~ F'AOE= DATE OF SURVEY FEBRUARY 19, BOSS GYROSCOPIC SURVEY dOB..NUMBER. BOSS-16973_ KELLY BUSHING ELEV. = 48.00 OPERATOR-MILAM- VERTIC:AL SECTION CALCULATED ALONG CLOSLIRE TRUE ._.UB--oEA MEASIJRED VERTICAL VERTICAL DEPTH DEF'TH DEPTH ON COURSE DOG-LEG 'T'OI"AL DIRECT_ION .... SEVERITY.__ REC.'[ANGULAR CO()RDINATES ._ DEGREES BEG/100 NURTH/.. UUTH EAST/WEST VERT I CAL SEC:T 1CIN ..... · .' .'.~ .'.;' Y, 77 .." 9._, 1 · 77 :2100 :3099.77 3051.77 ""-" 1 ....., 7/.* 151 76 .z, ..' (.I 0 '--' '-? '"-') ~I .":I (] ('! .-., --., ,2 ,.-. ..... -....~?. 75 :3251 75 :':I 4 ('l (7) .-., .-, ,2 ,.T/ ", .... .:,.-; . 74 :1 74 3500 :34'F¢'..]. 73 3451.72: 36A0 '" = ¢/"--¢ .:,.., ~..-.. 73 1 73 . .... '-' 3700_ _ :_::A'.]C/, 72 ..:,6~. 1 380i:~~°~ ::-:7'..]?. 70 3751 ],...~¢") 3S.,'00 ¢ c, .-......, .'--'"-'°'-"/_-,9 ~,'--"-'= ",=,,.., ·. 6? · 4F~O0 '"'- '-'-' '- .=, :-/~ ff, 68 '--"---'= ..:, 4100w 407~'.-T~./.-,7 4051.67(.~ 4200'~"~ 41'..]'?. 66 4151.66 4~,00 - 42:.]9 65 4251./.-,5 440~aq;~. ~"-":'¢'~, .,..- ] 64 4351 . 64 4500 44.'.-.??. 62 4451./_-,2 4~, .~ Y. 60 4551.60 4700 46'P?. 57 46.51.57 4,=,¢J 0 479'.~. 52 4751.._,='-'..- -~o;-.. 46 1.46 · . '"1' ~.,;I ._1 5000 4'~;-~';?. 40 4'.:)51,4¢) 5 ! 00 50'P?.,."..'-' 52(')('~ ._ 1W'?. ~.1 5151 21 5:.W~O 52'~.?'..]. 05 5251.05 5400 53'.~8. ... M o~0 55 5450 55 5.=,A A ._ 4 .. c,. . ~,X_-,O( ~-=¢"-' 26 5550 26 57(')(') 56?7 ,-,o ~/-,4 '--,' 5800 .-, / ..="'"~"'/. 42 ..,74 .~ .42 0 0 0 0 0 0 0 0 0 0 0 I l 1 1 2 2 2 2 3 4 4 4 5 5 42 %.1 ....! .~1 ' -- 41 4? 52 5 2? .. 4 51 34 13 3/_-, ~'.-4 48 ,-...~o. 19 E · .~, -_ '..,. ....... 52, 39 E 48.50 E 50 E ._ i'.~ E E E ..... E E 2i, 16.32 E 22. 17.20 E 23. 18.14__E .................. 24. 17.). 14 E 25. 20.19 E 27. 21. I.?_..E ........ 28. 22.34 E 2'P. 23.46 E 30. S S 2! _ ~..:~, S 1 ._ - S 21. S 15.30 S 18....1 ? S 11;87 S 15~50 E $ 17_.67_ E .. _ 1,.-,. 30 E S 20. 0 E 0 · (');.] '- _.],z '.":('l ,--. .T., ........................ - ~ c,.._c._.,.._..~.. _ .......... ..-.~_.. 28_.E .... 0.06 27 71 '-' '-'~- . ;=, ..'._,. 04 E 0,36 28, ?8 S 25,4.~ E ~:, 7 '-' ' · ~:,¢J, 17 '-' .. ....,,97 E ............. · _'"l O, 1,=, ~, ,.-.. .-,/. ,:~ ~1.44 .., ..,¢...,,~...:, E 0 06 ~"--' 'F-:'=' · .-*."-..-1--, 27, 20 E -. O. 24 ........... 34.'. 41__ S ................ 27,._80__E __ 36 3./',, 49 .., '=' -'-"'-',_-,, .5,"=, E ,15 2:8. ?3 :_=; 27.35 E :~'---~ 41.73 '--' 30.21 E ,_ ,,. ..... ,.i O. 27 45.02 .'-] 31 .~,_~o'---' E - ~I ':-/4 E 0.14 48 5"-' ':: 0,:-':2 · -': ~ ., .~...~.._,_ S '-"-' '} ~ .............................. ,:,.:,, _(: .., _ F-- 0.47 ~-F.. 34.4.7 E: ._,.-i /-',1 :-=; 0,72 61·70 S 36.~2 E: S...I:~. .O._.E ............ 0.60 .....· 68.26.S ............ 38,57 E S 22.69 E - 0.28 75.0? S 41.17 E S 22.8:-] E 0.38 82.18 S 44.15 E ..... S 24._80 E ....... O. 56 .......... 8'~.."].4 S ............. 47.5?. E S 26.10 E 0.85 98.6? S 51.76 E S 24,50 E 0,85 106',76 S 5,/.-,.51E --.-- , 571 ... 09 ._ 26 65 · ' .-i. .';i .'~l · .:'~.~. · -'._, :--::'::. 80 .':.E~ 36. 37 ""-' · ,'", ._-, 3'-.? ":' 1 · · ._, 41. ...... 45.7'P ,_-,. 55.71 .5'P.61 . . 64. 6'.:.'~. 76 P'~'-' ,:., .'L', ,--, .--~, ,~, ...., ,, ,---' 'P1.4~ ~-,'?. 'PO £)'.::.'/. 48 ',"0. CONOCO INC. C-1 MILNE POINT UNIT KLIPARLIK RI VER FIELD ALASKA SPERRY-SUN WELL SURVEYING COMPANY .... ANCHORAGE.. ALASKA ,, (SEClO T13N RIOE COMPUTATION DATE FEBRUARY,..22, 1982 VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE 3 DATE OF SURVEY FEBRUARY 19, 1982 BOSS GYROSCOPIC SURVEY -dOB NUMBER 80SS--16973 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR-MILAM TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE COURSE INCLINATION..-DIRECTION DEG MIN DEGREES DOG-LEG SEVERITY DEG/100 TOTAL RECTANGULAR .... COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION 6000 599/.,.05 5948.05 6100 6095.25 6047.25 6200 6194.41 6146.41 6300 6293.53 6245. 6400 63?2.64 6344. 6500 6491.90 6443.90 6600 6591.40 6543.40 67(10 6691.05 6643.05 6800 6790.81 6742.81 6900 6890.59 6842.59 7000 6990.31 6942.31 7100 7090.05 7042.05 7200 7189.89 7141.89 7300 728?.82 7241.82 7400 7389.7? 7341.79 7500 748?.75 7441.75 7600 758?.70 7541.70 6~, 7641.65 7700 7689.'~ 7800 7789.61 7741.61 7?00 788?.56 7841.56 8000 798?.52 7941.52 8100 808?.46 8041.46 8200 8189.41 8141.41 ,:'-:"'.~, U'c3 8289.37 824.1.37 , 8400 8389.33 8341.33 8500 848?.30 8441.30 8600 8589.2~ 8541.29 8700 8689.28 8641.28 8800 8789.27 8741.27 8900 888~.2~ 8841.26 7 7 7 4 3 2 1 1 1 1 1 1 1 1 1-. 1 1 1 1 0 0 0 1 11 ......$_ 24 .... O,.E 20 S 19.80 E 31 S 16..39 E ,40 S 15.30.. E S 14.39 E S 17.19 E S S 16.39 E S 10.69 E 6.69 E.. 5.69 E .80 E 10 W~. W W 22 43 56 40 45 37 49 53 48 34 78 79 83.19 85.39 83.69' 0.40 0.55 0.48. 143.90 S 70.24 E .0.22 ......... 156..63.S ....... 73.86 E 0.13 169.49 S 77.27 E 1.40 181.12 S 80.53 E 1.12 ..... 190.63 S ............... 83.41.E 0.81 198.55 S 85.74 E 0.79 205.30 S 87.39 E 0.41 ............ 21L. 85_.S ..................... 88.39 E 0.59 219.23 S 89.18 E 0.78 226.45 S 89.91E 1.62 ....... 231..81.S ............ 89.79 E ...... 119..88 S ......... 61.52-E .......... 132. 131.62 S 66.23 E 145. 158. .. 171. 184. 196. 206. 214. 221. · ], '-.o 235. 242. 247. 60 20 12 34. 65 72 65 ?1 85 41 70 81 .91 0.73 1.01 1.02 -. 0.36 0.38 O. 20 ...... 0.13 20 235.37 S 88.73 E 237,51S 87.12 E 238.13_S ................ 84.63 E 237.74 S 81.45 E 236.?4 S 78.40 E ..... 236.12_.S .......... 75..53 E 235.50 S 72.65 E 234.~4 S 69.68 E .0..14 ............... 234.46_S ..............66.4.7 E 0.12 234.13 S 63.25 E 0.25 233.86 S 60.31E 251.01 252.5? 252.45 251.15 249.50 247. '-"-' 24/-,. 45 245.05 243.6~'., 242.41 241.2? 25 ..... S 88.30._W ....... 0.25. : .... 233. Z4.. S ..... 57.70 E 11 S 82. 0 W 0.28 233.92 S 55.43 E 40 N 61. 0 W 0.77 233.78 S 53.88 E 38 ...N _23.69 E... O. 89 ................ 232. ~8. S ........... 53.5'.-.". E 42 N 71.60 E 0.55 232.28:3 54.40 E 3 S 74.30 E 0.61 232.33 S 55.87 E 240. 239. 239. 238. 238. 238. ?3 34 4? .. 05 53 CONOCO INC. C-1MILNE POINT UNIT KUPAI~UK RIVER FIELD ALASKA · :,FERRY-.:,UN WELL '-' "' · :,UhVEYINb COMF'ANY (SEC10 T13N R10E VERTICAL SECTION CALCULATED ALONG CLOSURE FALE ANCHORAGE ALASKA · . ~ DATE OF '.SURVEY FEBRUARY I'F~, ~':~'~"-.' COMPUTATION DATE BOSS; GYROSCOPIC. o'-'IJRVEY' ' FEBRUARY ~,. 1':'="~' '' ..~ ............ JOB NUMBER BOSS-16973 KELLY BUSHING ELEV.. = 48.00 FT. OPERATOR-M I LAM TRUE SUB-SEA MEASURED VERT I CAL VERT I CAL DEPTH DEPTH DEPTH ~000 8787.24 8~41.24 ~100 ~08~.22 ~041.22 ?200 ~189.20 ~141.20 ~00 ~28~.15 ~241.15 ~400 9389.11 ~341,11 ~500 ~489.07 ~441.07 ?600 ~58~.04 ~541.04 ~700 9689.01 9641.01 9750 9738.99 9690.99 COURSE COURSE DOG-LEG TOTAL INCLINATION .... -DIRECTION__SEVERITY._ RECTANGULAR .... COORDINATES BEG MIN BEG/lO0 NORTH/SOUTH EAST/WEST - VERT I CAL :-';ECT I ON oo ~..:,,:,..L) y. S ..... 57 ,.,._,,z,.-~ _E .:,.z,,z~ :::~- - ........... . ..... · ...... ~ ~,..i o, · 0 E 0.40~.,~,"":":,. 95 ._,':' 59. · 68 E 241 . 1 'F~ 1 2'3 E 0 45 234 96 S; 61 47 E .-,~i.:, ~,-, I 51 .E 0,47 ~.:,6.51 ':' ; '" '-'~ ..... , ............... :,o ._.o._, E _.244 o~ 0 4:3 237 91 S' 66.45 E 246 GO O. 14 23'~. 07 S 68.88 E ~4,:,. 77 I 28 0 44 '240 62. S 70 ':~'~ ~ 25(] 1 18 S 0 36 242.12 S 72 87 E 's'~-' 1 34 S; 0.62 242.84 ~=,'-' 73.90 E ~._'-,~'-'o. 84 HORIZONTAL DI'"' ·- :,FLACEMENT - 253.84 FEET A' THE CALCULATION F'ROCEDURES ARE BASED ON THE USE O~'R:~- ONAL RADIL:_~ .UF CURVATURE METHOD. ERRY-oUN WELL SURVEYING COMPANY ANCHORAGE ALASKA CONOCO INC. C-1MILNE POINT UNIT (SECIO T13N RiOE KLIPARUK RIVER FIELD ALASKA ~ PAGE "',., COMPUTATION DATE FEBRLIARY <'~ .~, I DATE OF 5JRVEY FEBRUARY 19 UOB NUMBER BU~,o.16~73 _. KELLY BUSHING ELEV. = 48.00 FT. OPERATOR-MILAM INTERPOLATED VALUES FOR 'EVEN 1000 FEET OF MEA.:,LRED'D~'~H'-' TRUE SUB-SEA r-.. .TOTAL ..................................... _. ................... MEASLIRED VERT I CAR VERT I CAL RECTANGLILAR COORD I NATES MD-TVD VERT I CAL DEF'TH DEPTH DEPTH NOR~OI. ITH EAST/WEST B I FFERENCE CORRECT I ON o o. oo -4E:, 0'0 ~i--~'. '?~'~' ....... :'i 6.'6,) ............... o]-00 ...... y'-:T, ............................ - ........... ~ 000 ,.--,,.-.-,,.,?. ,;74 ,.--/.5 ~. ,~4 ~Y,. -.--~L.~.~ .,,,'s . ~. 4~ w '.o, 06.' o. 06 ~,:,,:,,.', ~ .,~ ~.-..,. ,;:._~, ~..~-,._~, 1. ~,s ~. ~'~'. ~ ,... ~ i ~ ,:,. 1 ~, o. ,:,..-.? 3000 2';???~, 77 2'~51,77~' ' --'~'~ ' ~'= ~ '""--' ' ' '~' ' ' ' .:,"'~" ~ '~' ..:,"~"~ ='~' '" -" ' .,..._ .'--'~ ' u.' ...,~":' '?.' O. 1 u' ~ ' ' ,..-/,' ,-_',, ..,uOc~ 4.. · "N ,--~'"~- -.-,.-, ~ ~ ~ · ,'i'_,.~/,, ~ ~ ' 7000 6~/90.31 /_'.~42.31 ~1 ~. ~? c,~.. 18 E 7. ~....~' .- 5.74 ,-, ' ' ' ~ ,~,- I~.'~, ,:,uou 7 .,~,_, .~/...,,~ 7~41.5..- ,..:,4. ,.-,. -. .:..._-,,:,,- ; (.ll.lI.I ~.,; ,.', '- ' '" '-"'D '-'- ~ ' ' ~'~ 242· ;-';4 ~!II~.:~C :-'~_:-~0 E 11.01 O. 25 .,~750 .,~7..,~,..'.~ ? Y6 PU, B~./ . · . ~.c-:~_ .-,"-~ , ............... _: .............................. ' P ' 'I HE _.ALCULATICN FRUCEDJRE._ ARE ' -' ! ] "' n - '-" ' " ...... METHUD.- RADI LI~, UF L. URVATURE .... _: .... ...... : ............. ............ ,~ - - ................. ......................... ............................................ CONOCO INC. C-1MILNE POINT UNIT KLIPARUK RIVER FIELD ALASKA .-.FERRY-:=.LN WELL .=.L kVEYIN_, COMPANY (SEC10 T13N RIOE PAGE ANCHORAGE.ALASKA DATE OF SURVEY FEBRUARY 17, 1982 COMPUTATION BATE FEBRUARY 22, 1982 .................... dOB_NUMBER ._BOSSc16~73 KELLY BUSHING ELEV. = 48.00 Fl'. OPERATOR-MILAM INTERPOLATED VALUES FOR EVEN 100 FEET OF oLB-~EA DEPTH MEASLIREB DEF'TH 0 4.8 148 24.8 348 448 548 648 748 848 ?48 104.8 1148 1248 1348 14.48 1548 1648 1748 TRLIE VERT I C:AL BEF'TH 0.00 48.00 148. O0 24.8. O0 348.00 448.00 5'48.00 648. O0 748.00 84.8. O0 948. O0 1048.00 1148.00 1248.00 1348.00 14.48.00 1548.00 1648. O0 1748.00 SUB-SEA VERTICAL DEPTH -4e; oo 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700. O0 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOIJTH EAST/WEST DIFFERENCE CORRECTION 04 S ~:~:¥"~ sS . 9. 9. 9.70 ?.97 10.60 11.27 11.71 11.91 0.00 0.00 0.00 W 0.00 0.00 0.09 W 0.01 0.01 0.44. W 0.02 0.01 0.91 W 0.03 0.01 1 :-'{ . .=,J W 0.04 0 01 2.'21 W 0.04 0.00 · 2.72 W 0.04 0.00 2.64 W ............... 0,.05 ........................................ 0.00 2.38 W 0.05 0.00 1.78 W 0.06 0.01 1.07 W 0.06 0.00 .45 E 0.07 0.01 52 E O. 09 O. 02 2 E 0.11 0.02 E 0.12 0.01 E 0.13 0.01 ................... o._.1.3 ................................ 0.__o0 ................ O. 13 0.00 C 0 NIDCO I N L-:. C-1 MILNE F'OINT UNIT KUF'ARLIK RIVER FIELD ALASKA .:,FERRY-.:,JN WELL .:,JRVEYING COMPANY (SECIO T13N RiOE PAGE 7 ANCHORAGE ALA::,KA .............................. [fATE OF S~.~RVEY FEBRUARY 19, 1".~,:,"-"-'.. COMF'UTATION DATE FEBRUARY :."':', . c.,..-- "~.- 19'-''~' ............. ,.IDB NUMBER - BOSS- 16'~7:--: KELLY BUSHING ELEV. = 48.00 FT. OPERATOR-MI LAM ... INTERPOLATED VALUE:S FOR EVEN 100 FEET OF SUB-SEA DEPTH MEA:_qURED DEF'TH 184:_-': 1948 2048 2148 2248 2348 2448 2548 2648 274.8 2848 2948 3048 3148 3248 · .3 .J, 4 ,--, :Z-:448 3548 3648 TRUE VERT I C:AL DEF'TH 1848.00 1948.00 2048.00. 2148.00 2248.00 2348.00 244:3.00 2548.00 2648.00 2748.00 2848.00 2948.00 3048.00 3148.00 3248.00 3348.00 8448.00 3548.00 3648.00 SUB-SEA VERTICAL DEPTH 1800.00 1900.00 2000.00 2100,00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2~00.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 TOTAL ............................................ 'ANGULAR C:OORD I NATE:_-'; MD-TVD VERTICAL 'H/SOUTH EAST/WEST D I FFERENCE C:ORRERT I ON 1 S 6.01 E 0.14 0.00 S 6.61 E 0.14 0.01 .............. 6...79 E .... 0...15 .......................... 0. O0 7.44 E 0.15 0.00 ,:..21 E 0.15 0.00 9.59 E ....... --.. 0.16 ...................... 0.01 .......... O. 17 0. O1 O. 1~ O. O1 0.20 O. 01 0.21 0.01 ................ O. 22 ............. O. 01 ..... 0.23 O. O1 0.24 0.01 O. 24 ....... O. 01 ............ 0.25 O. O1 0.26 0.01 0.27 ................. 0.0.1 ........ 0.28 0.01 CONOCO INC. C-1 MILNE POINT UNIT KUPAR_IK RIVER FIELD ALASKA TRUE MEASLIRED VERT I E:AL DEF'TH DEPTH 3748 3748. O0 384::: 384.8. O0 '-~'" '" '~"--"~ '~ 0 () ._', ,',/4 ,_-, · -"' .;' "'r 4048 4048. O0 4148 4148.00 4248 424.8.00 4348 4348.00 4448 444.8.00 4548 4548. O0 4648 4648.00 4748 4748. O0 4848 4.848.00 4948 4948.00 504.8 5048.00 514::: 5148.00 5248 5248. O0 5:34'.-.? 5348.00 54.4'.-.? 5448.00 5549 5548. O0 SF'ERRY-SUN WELL SLIRVEYING COMF'ANY (SECIO Ti:3N RiOE PAGE' ANCHORAGE ALASKA .... DATE OF SURVEY FEBRUARY 19, bUMFLFA]ION :DATE FEBRUARY 22, 1982_ _ i '" RI .dOB N 3MBER.. 16:::¢73 ........ ~...,;.~ KELLY BUSHINO ELEV, = OF'ERATOR-M I LAM 48.00 F T. INTERPOLATED VALLEo FOR EVEN 100 FEE]' OF SLIB-SEA DEPTH SUB-SEA TOTAl ......... VERT I CAI_ REL.] ANUL LAR COORD I NATES MD-TVD VERT I F:AL DEF'TH EAST/WEST D I FFERENCE CORRECT I ON s,700.0,:,t s E o. '.---':-.-, 3:::00 00 ~ ~'=' 23 '~":"' · ,:,o E 0. '-'¢ . .:, J 0 01 ..:,.,.,.,.,,',or~('~ .......... el(') 24 /--,5 E 0.3'-':',~ .................. 0 · 01 ............... 4000 00 ~'=' ""-- .... · =..,..~,:,E O..:,:3 0.01 4100.00 25.59 E 0.34 0.01 4200.00 26.35 E 4300 00 26.°'-~ 0 01 ,-,;/ E 0 '~'~ 4400.00 27.4~] E O. 37 O. 01 4500 00 '--': '- . ._,._,. b: 11 E_ 4. 600 ...... 00 :2:7 · 6 ':/~E 0 · 42 0. (.._-,'~ '-' 4700 · 00 40 · 17' 70 E 0 · 45 0 · 0.3 4800 00 '" 6~.n E 0 ~0 ......... 0.05 · .1~'--! ¢ · -- - . ................. 4.9(]0 00 46. -"-' '-'~' ~' "- ~ .... /,~ o %:::- -.-- E 0, 57 O. 07 .=,- - - =- ".-,/i .c; %~ .' ._uO0 00 E 0,64 0 07 . ,..¢9 -"-, ,.~..~_" .-~ - · · _4! E · 5100 00 .=, o._~ ,= ~' - '~-":' ' 0 ~'-'"'(') 00 ~,--, ,.?'7 ¢. '--~-'~- O, ._1 ..' ~..I . · .- .-,; ..,.-' , · .~'-.' .n -"-.. · 5300.00 64 82 S 'V~, 1.04 O. 1 540(]. 00 71 /_-,._, o . _ ~24';~. ........ 1 · 31 ..................... 0._27. .......... · ~ u,~ 0 27 ==¢'¢' 00 78 · 49 S ~,. ,~,. ¢ 1. ='- CONOCO INC. C-1 MILNE POINT UNIT I-:..L F AR .IK R I VER F I ELD ALASKA SPERRY-SUN WELL SURVEYING COMPANY (SECIO T13N RIOE PAGE 9 ANCHORAOE ALASKA COMPUTATION DATE FEBRUARY 22, 1982._ DATE OF SURVEY FEBRUARY 19, 1982 dOB NUMBER._BOSS-16973_ KELLY BUSHING ELEV. = OPERATOR-MiLAM 48.00 FT. MEASLIRED DEPTH 5649 5750 5850 5951 6052 6153 6254 6354 6455 6556 6656 6757 6857 6?57 7057 71..,:, 7258 7358 74.58 INTERPOLATED VALLE:_~ FOR Ev~N"'IO0'"FE~'I: OF SUB-SEA DEPTH TRUE VERTICAL DEPTH 5648.00 5748.00 5848.00 5948.00 6048.00 6148.00 6248.00 6348.00 64.48.00 6548.00 6648.00 /:,748.00 6848.00 6948.00 7048.00 7148.00 7248.00 7348.00 7448.00 SUB-SEA VERTICAL DEPTH · . 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 · '6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 TOTAL RECTAN'~ ~.. AR COORDINATES M['-T,,VD VE, R,T I":AL NEIRTH/]$'C~ITH EAST/WEST D I FFERENE:E CORRECT I ON ~8;o. :..t?:~... 4..,. 74 E . · 1... i . U. oz. [~-~?~i'~ ,-" -? ' 4 _ ..... 1~;:,6] ..~% o~'. 06 E .:,...,7 L. 71 · -, ' ]-.~_'I. ~ ' L--' -- ~" 1 ~~ ;:, ~.-,~ 64.14 E · 4. c.-~/:, o. 7. · -,'"''-,~,~r,~-- - .:.,x.i".-~- I lsr,: 72. =::: E '6.06 1/:,..:,. ~. :~e:.- ::~ 7._,. 70 E /:,...,6 o..~u 17/:.. ~, e_,(.gB · ,"",....~..................~?-. SPERRY-~--;UN WELL :=':LIRVEYllm3 COMPANY · ANCHORAGE ALASKA CONOCO INC. C-1 MILNE POINT UNIT (SECiO Ti3N RiOE COMPUTATION DATE KUPARUK RIVER FIELD . FEBRUARY 22, .1";-,82 ALASKA ( PAGE 10 DATE OF SURVEY FEBRUARY 19, lC./~,°'-'~ ..... ,_lOB NUMBER.. KELLY BUSHING ELEV. = 4,S'.00 FT. OPERATOR-MILAM. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED DEPTH 7558 7658 7758 7858 7958 8058 8158 8258 8358 8458 8558 8658 875:3 8858 8958 9058 9158 9258 9358 TRUE VER T I C:AL DEPTH 7548.00 7648.00 7748.00 7848.00 7948.00 8048.00 8148.00 8248.00 8348.00 8448.00 8548.00 8648.00 8748.00 8848.00 8948.00 ~048.00 9148.00 ~248.00. 9348.00 SLIB-SEA .. TOTAL .............................................................................. VERT I CAL RECI'ANGLILAR COORD I NATES MB-TVD VER'r I CAL DEF"TH NORTH/SOUTH EAST/WEST D I FFERENCE CORRECT I ON 0 06 7700" ' ":~<:'/- ' '-' '~?'' " .... ........... ................ ':-"~ ..................... ' - : 0.05 . . . · =.PERRY-..=._ N WELL '--;[ IRVEY I NIl COMF'ANY F'AOE 11 ANL. HURAOE ALASKA .......................................... · [[ATE AF SLIRVEY FEBRL[ARY 1'-.?,. 1.~o.~-, ~.~ COMPUTATION DATE FEBRUARY 22, .. 1°-~"--' ..dOB NUMBER BOSS- 16'.-.773 '-' 48 00 FT. ~ KELLY BUoHINO ELEV. = . OPERATOR-M I LAM INTERPOLATED VAI_LEo FOR EVEN 100 FEET OF SUB-SEA DEPTH CONOCC~ INC. C-1 MILNE POINT UNIT (SEC10 T13N R10E KUPARUK RIVER FIELD ALASKA TRUE SUB-SEA MEASURED VERT I C:AL VERT I CAL DEPTH DEPTH DEPTH ~458 ~448.00 9400,00 9558 9548.00 ~500.00 ~658 ~648.00 ~600,00 9750 97~8.99 9690.99 TOTAL .... RECTA~AR COORDINATES MD-TVD VERTICAL N~R',,H/~.ITH~',.. EAST/WEST DIFFERENCE CORRECTION . ......................................................................... 67.90 E 10.91 0.04 70.23 E 10.75 0.04 ._. 72.08 E ....... 1.0,98 .............. 0.03 .... 73.90 E 11.01 0.03 THE CALCLILATION PROCEDLIRES USE ALI THE NEAREST 20 FOOT MD (FROM RADIUS BETWEEN ............ .r ' '---' ) Fr-,IN];=. \1);\ . . SuggesteKi 'form to be insorted in each "Active" wcll folder to check fortiffiGly compliancewithourrGgl.lléltions. '. ~~.þ.....: ...Mll~71J.i~~~êl#;~ Ol~rq.,to.r, \~ellNarre andN~r' ' '. "", '. _Samples Mud Log ~'.' Inclination SUrvey Direct~onal Survey Drill StErn Test Reports -.1-8~ k, 4.fe, ~f'€-: Lt?<-+e. Ltt¡-e, ~;i~~~~. proouction Tes t RCfOrts e:r" ~,-~,...8¿~ . -:J.I-f~ If-¡'I, t~ i'- ~ I ~~;¿ Logs Run Yes Digitized Data D tp " -e-~r \} ~Æ. 'f~ ~ STATE OF ALASKA ALASKA Oi ~ND GAS CONSERVATION COIV ~SSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well i-X 2. Name of operator Conoco Inc. Workover operation [] 3. Address 2525 C Street, Suite lO0 Anchorage, AK 99503 4. Location of Well at surface 11 67' FSL, 2256' FEL, Sec. 10, T13N, R1 0E 5. Eleva~ij~r] i n~[et (indicate KB, DF, etc.)I 6. Lease Designation and serialADL 47434 No. 7. Permit No. 81-143 8. APl Number 50- 029-20663 9. Unit or Lease Name Milne Point 10. Well No. ¢-1 11. FieJd and Popl ~uparuK River Field Kuparuk River Pool For the Month of. March ,19 82 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Installed abandonment cap on 3/18. Total depth - 10,442' Corrects Feb. Report - PBTD - 9548' DST results to follow on final report 13. Casing or liner run and quantities of cement, results of pressure tests Cement Sqz. EZSV Set @ Cmt. below tool Spot on top of tool 8852' 100 sks. Class G 50 sks. 7059' 100 sks. Class G 25 sks. 7028' 200 sks. Class G 25 sks. 6900' !93 sks. C!ass G 32 sks. 14. Coring resume and brief description None 15. Logs run and depth where run None APR 1 21982 Alaska Oil & Gas Cons. Con~rniS$ior ~c.~orage 16. DST data, perforating data, shows of H2S, miscellaneous data Perf- SPF From To 4 7109' 7111' 12 7167' 7142' 12 7133' 7120' 4 shots @ 6970' (cont.)SPF From To 12 6959' 6968' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / u,erv s n,,ro,. ,n,. ~is form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form lO~04 AFE 1741 AO & GCC (2) WIO Rev. 7-1-80 Submit in duplicate 400' CENTERLINE '"'--ACCESS ROAD . . LOCATION IN SECTION WELL FSL FEL NO I I 167 2Z56 FSL= FROM SOUTH .INE El_ = ,F~OM EAST .INE DRILL SITE "C" WELL LOCATIONS · · LOCATED WITHIN SECTION I0, TISN, RIOE, U.M. A~ASi~A PREPARED BY BOMHOFF ~ ASSOClATES~INC. ANCHORAGE, ALASKA C, L. F, R.R.K, ~- ..... STATE OF ALASKA ~, ~ ALASKA ~., AND GAS CONSERVATION C_O~r_ 41SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well I'~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 81-143 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-20663 9. Unit or Lease Name Milne Point 4. Location of Well at surface 1167' FSL, 2256' FEL, Sec. 10, T13N, RIOE 6. Lease Designation and Serial No. ADL 47434 For the Month of. February ,19 82 5. Elevation in feet (indicate KB, DF, etc.) 20' GL 10. Well No. C-1 11, Field and Pool Kuparuk River Field Kuparuk River Po01 q 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks TD 10,442'. PBTD ( 9009' ) Squeezed perfs indicated below w/100 sks. class "G" cmt. Running DST's, results to fol]ow on final report. 13. Casing or liner run and quantities of cement, results of pressure tests Casing' Si ze Wt. Grade 'From To Cement (1) 9 5/8" 47# L-80 O' 9802' (1) (2) DV collar @ 7690' (2) (3) DV packer @ 2219' (3) 825 sks. class "G" 1175 sks. class "G" 150 sks. Arctic Set I 14. Coring resume and brief description Run sidewall core gun. RECEI VEfl MAR 1 $1982 Alaska Oil & fas Cons. c,,,,,,... ~r, borage ;'-"""~o~ 15. Logs run and depth where run Logs- FDC-CNL-NGT DIL-GR-BHC From To Logs' '-" .... Fffom SP-DIL-SFL-GR-BHCS 10,442' 9800' 2338' FDC-CNL-MICRO-DIP PrOX.HDM+Crolog, ,16. DST data, perforating data, shows of H2S, miscellaneous data To 9802' CBL-VDL-CCL-GR 9802' 2330' Add. Logs. From To Perf- SPF From To CBL-VDL-CCL-GR 9450' 6400' (sqz.) 12 9134' 9143' 12 8904' 8934' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "~_GTNEED ~~////"'~J ~~T~LE Drilling Supervisor DATE ~/~//~'~-~ ,T --Report on this form is required for each calendar month, regardless of the status of operations, must ~a~nd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed, and be filed in duplicate with the Alaska ~,10-404 Submit in duplicate ~'?-1-80 AFE 1741 A0&GCC (~Q.) ) STATE OF ALASKA '~ ALASKA oIL AND GAS CONSERVATION CC,,/M ISSIO N"--..~.,. SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL iX'l COMPLETED WELL [] 2. Name of Operator Conoco Tnc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well ~'~1!67' FSL, 2256' FEL. SEC 10, T13N, RIOE, UM. 5. Elevation in feet (indicate KB, DF, etc.) KB-48' 7. Permit No. 81-143 8. AP! Number 5o- 029-20663 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-1 1 1. Field and Pool , Kuparuk River Fi eld I 6. Lea~[~sig.n~o4n3a~d Serial No. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data I NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~1 Alter Casing E] - Perforations [] Altering Casing Stimu late [] Abandon [] Stimulation [] ' Abandonment Repair Well [] Change Plans [] Repairs Made i-'] Other Pull Tubing [] Other [] Pulling Tubing [] 12. (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This notice is being submitted for the approval of perforating the, Kuparuk River formations as described in the attached procedure. This work will commence on March 2, 1982. CO .NFE)ENT AL 'RECEIVED MAR 0 ~1 1982 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Supervisinq Engineer ./ The space 'below f~Commission use Date March 1, 1982 Conditions of Approval, if any: Approved by COMMISSIONER ., Approved Copy Returned -- By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and *'Subsequent Reports" in Duplicate --CONFIDENTIAL MILNE POINT C NO. 1 KUPARUK RIVER FORMATION TEST PROCEDURE l) Shoot 4 holes per foot from 7109' to 7111' and attempt to squeeze with 75 to 100 sacks of cement. 2) RIH the drill string and bit. Drill out cement and test the holes to 2000 psig. POOH with the drill string. Lower Kuparuk Test Objectives: Primary- Productivity (Pi, Kh, Tf, Skin) Secondary - Downhole and surface recombination formation fluid samples. 3) Perforate 7120-7133 and 7142-7167 (DIL depths) with 4" casing guns and 12 JSPF, 90° phasing. 4) RIH with a DST packer, dow.nhole shut-in valve, and pressure and temper- ature gauges. Set the packer at 7100'_+ and fill test string with a 6600' diesel cushion. 5) Open the downhole shut-in valve for 6 minutes initial flow. 6) Close the downhole shut, in valve for 60 minutes of initial buildup. 7) Open the downhole shut-in valve for a final flow period of at least 8 hours. During the first 4 hours of flow, attempt to flow at a stabil- ized rate with a minimum bottom hole flowing pressure of 2500 psig. After the rate has stabilized, attempt to obtain downhole formation fluid samples-. 8) After the downhole samples have been obtained, attempt to flow the well at a maximum stabilized rate for a period of at least 4 hours. 9) Shut-in the well for a final buildup period of 24 hours. 10) Reverse out the test string. 11) POOH with test tools. 12) RIH with a drillable retainer and set at 7100'_+. RECEIVED MAR o 1982 ' Naska Oil & ~as Cons. Commission Anchorage ~ ~. 13) Shoot 4 holes per foot from 6970'_+ and attempt to squeeze with 75 to 100 sacks of cement. 14) RIH the drill string and bit. Drill out cement and test the holes to gJO0 psig. POOH with the drill string. Middle Kuparuk Test Objectives: Primary - Productivity (Pi, Kh, Tf, Skin) Secondary - Surface recombination formation fluid samples. 15) Perforate 6959' to 6968' MD ~DIL depths) with 4" casing guns and 12 JSPF, 90° phasing. Page 2 ') 16) RIH with a DST packer, downhole shut-in valve, and pressure and temperature gauges. Set the packer at 6940'± and fill the test string with a 5500' diesel cushion. 17) Open the downhole shut-in valve for 6 minutes initial flow. 18) Close the downhole shut-in valve for 60 minutes of initial buildup. 19) Open the downhole shut-in valve for a final flow period of at least 8 hours. During the first 4 hours of flow, attempt to flow at a stabil- ized rate with a minimum bottom hole flowing pressure of 2500 psig. After the rate has stabilized, attempt to obtain surface recombination samples of formation fluid from the separator. 20) After the surface recombination samples have been obtained, attempt to flow the well at a maximum stabilized rate for a period of at least 4 hours. 21) Shut-in the well for a final buildup period of 24 hours. 22) Reverse out the test string. 23) POOH with test tools. 24) RIH with a drill string and bit, and drill out the retainer set at 7100'±. Clean"out to 7600'+ MD. POOH with the drill string. 25) RIH with production packer and assembly on wireline. Set the packer at 6900' MD. 26) RIH with the 3z''2 production tubing, stab into the packer and space out. Nipple up the Xmas tree wi th master valves. Prepare to RDMO drilling rig. March 1, 1982 Anchorage, Alaska RECEIVED MAR 0 ] ]982 Naska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA , t(_ ALASKA ~AND GAS CONSERVATION C(. )MISSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well 2. Name of operator Conoco Inc. Workover operation [] 7. Permit No. 81-143 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-20663 4. Location of Well at surface 1167' FSL, 2256' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 20' GL 10, T13N, RIOE 6. Lease Des~nation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point 10. Well No. C-1 11. Field and Pool Kuparuk River Field Kuparuk River Pool For the Month of January ,19 82 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth on 1/31 - 9330'. Drilled out cement that had plugged the 13 3/8" csg. & re-cemented csg. w/630 bbls. of Arctic Set #2 & ~irculated to surface. 13. Casing or liner run and quantities of cement, resuffs of pressur9 tests Re-cement surface casing with approximately 3800 sks - Arctic Set #2. 14. Coring resume and brief description Recovery was 100% Interval Formation 6900'7043 Kuparuk River 8900-8954 Sag River 9125-9185 Ivishak Lithology Glaucomitic sandstone sandstone: glaucomitic, abundant ized plant, frags. sandstone: Chert bearing, w/occas. conglomerate lenses. 15. Logs run and depth where run Logs From To GR-SP-DIL 6800' 2338' SP-DIL-SFL-GR 8693' 5700' 6. DST data, perforating data, shows of H2S, miscellaneous data NONE ' CcClVED FEB 1 61982 ltJaska Oil & 8as Cons. Cornr~ission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¢. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev. 7-1-80 AFE 1741 AO&GCC (2) K Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 11, 1982 Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 995013192 Dear Mr. Smith: Enclosed are three copies of our plan changes on Milne Point C-1. These changes include a modification of the 9-5/8" casing program and a change in the surface location. If you have any questions, please call Gary Merriman at 279-0611. Very truly yours, H. D. Haley Manager of Alaskan Operations GAM/kr RECEIVED JAN 1 ~ 1982 Alaska Oil & Gas Cons. CommissiOn Anchorage - STATE OF ALASKA ALASKf, ~)IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. CONOCO I NC. 81 - 143 OTHER 3. Address 2525 "C" Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well 980' FSL and 2195' FEL, Sec lO, T13N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 20' ground level 12. 8. AP! Number 50- 029-20663 "9. 'Unit or Le'as~ I~ame Milne Point Unit 10. Well Number Milne Point C-1 6. Lease Designation and Serial No. ADL 47434 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Field Kuparuk River Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] - Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). * Surface location has been changed from that shown in 4 above, and the as-built survey is as follows- 1167' FSL, 2256 FEL Sec 10, T13N, RIOE, UM The casing program has been changed to the following: 20", 94#, conductor O' to 80' 13-3/8", 72#, L-80, Btrs O' to 2300' 9-5/8", 47#, L-80 Btrs O' to 9900' 7", 29#, L-80, Btrs 9800' to 10,360' The 9-5/8" casing string will be cemented in two stages from 9900' "of cement. The 7" liner will be cemented with 100 cf of cement. to 6000'-using 1500 c. This change in the 9-5/8" casing depth from 7450' to 9900' has been made to reduce possible problems with lost circulation that may occur while drilling below 10,000'. * Verbal approval by Russ Douglass on December 23, 1981. RECEIVED s,~b~¢q,~t work r. ero~t~a ~.¢__~-JAN 1 4 1982 o~, Form No/~ ~1~ 0il & Gas Cons, 60mm~8~9~ 14. ~ hereby certify that[the foregoing is true and correct to the best of my knowledge. ~ch0[ag~ Sign~ ~ .~_~ Title Manager of Alaskan Operations Date The space below for Commission~se Conditions of Approval, if any: ' Dy Ordc.' Approved by. COMMISSIONER the Commission Date~ 1-11-82 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 400' I!0' · CENTERLINE '"'-ACCESS RO~AD STATE PLANE COORDINATES WELL NORTHINGS EASTINGS NO I 6029450 558203 , ,,, , , , , , GEODETIC POSITIONS aLI I ' WELL LATITUDE LONGITUDE NO I ' 70° 29'27.87'' 149°31'?-7.07 , .. ., , LOCATION IN SECTION WELL FSL FEL NO I I 167 2Z56 , , ,, ,, · _ FSL = FROM SOUTH .INE FEL= FROM EAST LINE RECEIVED JAN ] ~ 19.82 Alaslla Oil & Gas Co~ Anchon s. CommissionDRILL ~e WELL ii i i iml ii SITE "C" LOCATIONS LOCATED WITHIN SECTION I0, TI3N~ RIOE, U.M. ALASI~A PREPARED BY (~ BOMHOFF ~ AS~X~IATES~ INC. ANCHORAGE, ALASKA DATE SCALE' I": 200' DRAWN_ C. L.F. J CHECF~ED R, R. K. STATE OF ALASKA ALASKA. ~ AND GAS CONSERVATION CE )MISSION MONTHLY REPORT DRILLING AND WOR OVER OPERATIONS 1. Drilling well ~_.X Workover operation [] 2. Name of operator 7. Permit No. Conoco :[nc. 81-143 3. Address 8. APl Number 2525 "C" Street, Suite 100, Anchorage, Alaska 99503 5o- 029-20663 4. Location of Well atsurface 1167' FSL, 2256' FEL, Sec 10, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 20' Gl ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 1 11. Field and Pool Kuparuk River Field Kuparuk River Pool For the Month of December ,19 81 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date- 12-23-81 Depth at 12-31 - 2344' Casing plugged, cement bridged off. Preparing to drill out cement in surface casing and re-cement. 13. Casing or liner run and quantities of cement, results of pressure tests Cas lng Size Wt. Grade From To Cement __ 20" 94# H40 0' 80' To Surface 13-3/8" 72# L80 0' 2342' Csg. plugged w/2538 sks. Arctic Set cement 14. Coring resume and brief description None 15. Logs run and depth where run Logs From To SP/DIL/SFL llO' 2325' GR/BHCS 11 O' 2291 ' 16. DST data, perforating data, shows of H2S, miscellaneous data None JAN 1 2 ]982 Alaska 0il & Gas Cons. Commi&sion Anchorage 17. I hereby certify that the fore§oing is true and correct to the best of my knowledge. SIGNED~~~ TITLE Drilling Supervisor DATE 1-6-82 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form lO-404 AFE 1741 AO & GCC (2) File Submit in duplicate ~, '/.1 .~os , Commissioner ALASKA OIL AND GAS CONSERVATION COMMISSION January 7, 1982 Petroleum Inspector Witness BOPE Test on Conoco's Milne Point C-1 Well Sec. 10, T13N, R10E, U.M. Permit No. 81-143 on Nabors Rig No. 17 Sunday, January 3, 1982: I traveled this date to Prudhoe Bay to WitnesS' the B0~E' test oK C~n0C6' ~ Milne point well. The"BOpE test was delayed because "?~. the ' following: The lower' Pipe rams not allow manifold pressur~ to rase ab°Ye~ 2300 PSi; there were of the two five bottle ban~s. Monday, January 4, 1982~ ~' The BOPE test commenced at 3:30 a.m. ~nd was c°%cluded at ~0:30~ai~m,"6n'Tuesda~, january 5,~1982. The above ment%oned problems W6re COrreCted'dUring the c0~rse of thi~ test. I filled out an A.0~G'C,C. BOPE test~rePOrt Which'is · attached. In summary I witnessed the~'successful BOPE test on Conoco's Milne Point well. There were ..~?nY probIe~a~eas dUring this test. Ail problems were corrected d~ing'th~'oOUrse'~of this test. 'I filled out an A.O.G.C.C. BOPE test.~rep°rt.~whiCh is attached' DA~vdl "'~ -t) ~ - ,.- c~ ....... ;c- (5 ..s '- --r- -ð .. .~ -t" L: ~ l- ~,~ (~ &,.,1\ '§ -~ of- ~ ...-0 . '~.. -fl., y !. "-r . ...Jt. CJJ ,,', , ",t) \. :S ',~ --at , 1;;. '1j '{t,""', ( ~,¡:., " ~ 161 ..~,,<I¡,. _/"ê''', G- ~ " \\ ~ C&G#4 4/80 AU\~ or L & ~:~'f~~;: ;":~~~~~lJ COHf.HstN . B.O. P. E. Inspection Report . ' Inspector DO(A~ o.~o~- Operator Ct!!)~C> Co 0 Well ~\n.e. "Þc;;>~.n ~ C-I - ~- ..- -_..- .~ -~. Representative Pe rmi t if B\ - l 4-~ þ Location: See \ l) Ti~:';~,,\ R ¡?:it:' t1 I'J~'{ I ~Casingset @ ~3=.,S ft. :~~~~::, C:::::::O r ~~ b~í~o~ Rií~1c;;~~~*F*i~~r~oLù~~=~o_~ \'lell Sign OK 1(1.111 Chargef.'Pressure ::SOC!:)C') psig . General Housekeeping O~ ii Pressurel\.fter Closure ,\?(t'7)d) . psig Reserve pit 0\(" .i200psigl\.bove precharge Attained-=---L-mi~sc(' Rig OK '¡¡Full Charge Pressurel\.ttained: 4 min~sec II, ' "",,' . 'IN,2. 270°) IßoO,Z'l-ro; .-¿-,QP. Esrg ok . ' Controls: Master' ,01<".', "" '. ' . " '" ,I ' K I' . . 1 ' "'" .'.1'[,.--.., '," ,n __~2-~~~, .~B_.lnçls__sV!ltc 1coverYp~._~. !,~"~(>1;lre:t KellY a 'ld .flQQrS.ð,~et:YV:*,f""s 00 !I Upper Kelly-LW'est Pressure ¡Lower Kelly'- Test Pressure . 'Ball Type Test Pressure c; ,Or!.JO ¡ S¡o , , h 1:1 ", ,I Inside, BOP ',"1 Test Pressure . ..... ........:I,..!rN~¡.10::I~:: UO ld ~~t Pres su re ...' I .I¡ No, flaòges. .sö I Adjustable ,Chokes '2. - --- -- -~~ "--- - "---- -- .~---- ---- - 1'~Y2r~u i call Y o!?_e5" t~d c hokù ------ ---- -- 'l'es t-- T i¡'ne --3'r-' - ï; r~.---"'-"-¿:¿'~-~'-'------' Line Valves , , /I Kill Line Valves \1 ;? \ Check valve Tè$i~e~lilt~-:---Pa-liurès'--'-----'-5--~- Repair or Replacement of failed eqUipment to be made wi tlÜn.£b days and ." ~ - 1J 1 Inspector/Commission office notified. R<>mark$:A.$f~r, Mbj~_.P.8,.~ $~, €,,~.S- -th~t('<~\ \ ~...ð: W\ 'Y\f$-P ~& Dot (:>r£-IMV1LA\0\~b6tf\~'2' ~dé\ b~Y\\r~ko.il. ~vø~" \~\at'LÞ~i\}tlhJ~" .~\}~f~;"~ ... *,ø~ .Þ0 ~ ~ tm ....~... .SP4JI C~ d VJ"t1¡\6),?>~ (Ã~~<+-~~t\J.~' '3I:M'''¿. ~""\t '1\f..S N~'-k. ~\, bLpæ-fo(>\lé>d b~fo.('e d ç',\ \, ,11~ 0 (At 1tAe ,:3 ?f~ e?3i Sl.-'\D~ f . Distribution ..) orig .'- AO&GCC cc - Operator cc - Supervisor Inspector ~o{.~~ fA ." ,,' . ~,,~.~\. n ~ N'o~~; ,AX\ (Ç\'\'\\J 'l.4# ~ . \ 1 í t. ..",' \<.< . t)..) ~)I'~ IAtt r~::q t It~~:~ .;;.~ r\ y f!~+~ f.+ C'i-4 " t-5~8Z ¿AY"'I C~\\ September 25, 1981 Mr..C~.ry A. ~erriman Supervising Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit, Milne Point C-1 Conoco Inc 0 Permit No. 81-t43 Sur. Loc.= 980'FSL, 2195~FEL, SeC 10, T13N, R10E, UM. Bottomhole Loc. ~ S A M E Dear Mr. Merriman~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are required. An-inclination survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and .Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. Gary A. Merriman -2- Milne Point Unit, Milne Point C-1 September 25, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. TO aid us in scheduling field work, we would appreciate your notifying this office at lease 4.8 hours before the well is spudded. We would like to he notified so that a representative of the Commission may be present to inspect the diverter system before the conductor shoe is drilled and also to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandor~ent, please give this office adequate advance notification so that we. may have a witness present. Very truly yours, Ho~ H. Hamilton Chairman of BY ORDER OF YH~ CO~d~SSlON Alaska Oil & Gas Conservation Commission Enclosure D~partment of Fish & Game., Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. HHH~he Ccon Conoco Inc. 3201 C Street Suite 403 Anchorage, AK 99503 September 18, .1981 Mr. Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Smith' Enclosed are the permit applications to drill Milne Point B-2, C-l, and D-1. These applications are being submitted in triplicate on form 10-401, revised 7-1-80. Please disregard any previous permit applications to drill the above mentioned wells. If you have any questions, please call me at 279-0611. Sincerely, ~.<r~ Supervis~n§ [n~neer RECEIVED 0{{ & Gas C~,~)s. Coir~,'nission Anchorage ALASKA STATE OF ALASKA AND GAS CONSERVATION CC "]MlSSlON~ I ERMIT TO DRILL 20 AAC 25.005 la. Type of work. DR ILL REDRILL [] DEEPEN [-] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [-] STRATIGRAPHIC [-! SINGLE ZONE [] MULTIPLE ZONE [~ 2. Name of operator Conoco Inc, 3. Address ~ 'C' St- Sui~_e ]_00 Anchorage, A!a_~ka 4. Location of well at surface 980 FSL, 2195 FEL, Sec. 10, T13N, RiOE, UN At top of proposed producing interval Same At total depth Same 99503 5. Elevation in feet (indicate KB, DF etc.) J 6. Lease designation and serial no. 20' Ground level I ADL 47434 9. Unit or lease name Conoco et al, Milne Point 10. Well number Milne Point C-1 11. Field and pool Kuparuk River Field 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 80~6--] ..~--_~Z~ ' 13. Distance and direction from nearest town 14, Distance to nearest property or lease'line Deadhorse; Southeast 33miles 980 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease (Vertical hole) MD: 10360 feet 2560 'AC 19. If deviated (see 20 AAC 25.050) ~ 20. Anticipated pressures KICK OFF POINT feet. MAXIMUM HOLE ANGLE oI (see 20 AAC 25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program Kuparuk River Pool Amount .~ 9(%R _ f%f~CI 15. Distance t~)-n~r~s{ ~lr]lling or completed well Milne Pt. 1/SE9975 feet 18. Approximate spud date December 1, 1981 3990' psig@ ~J' Surface 5]80' ps,g@]03601f,.TD(TVD) SIZE Hole Casing 26 20" 17¼ 13-3/8 12~ 9-5/8 8} 17" Weight 94# 72# 47# 29# CASING AND LINER Grade I Coupling I I I I 22. Describe proposed program: SETTING DEPTH Length M D TOP 80' '0 I 0 I 2000 TVD MD BOTTOM TVD 7450 0 3010 7350 ~-7350 I QUANTITY OF CEMENT (include stage data) ~998 4200 CF 7450 10360 450 CF Proposed surface and bottomhole location plat enclosed. ~ ~ [ ~ ~VE 0 As-built survey plat will be submitted after setting conductor casing. See attached Supplemental Data Sheet SEP1 8 1981 se attached wellhead and BOP sketches Alaska 0il & Gas Cons. C0mmjs t~ch0rag~ * Set 80' from ground level; other-figures are base~ on elevation of 20' 23. I hereby certify_that the foregoing is true and correct to the best of my knowledge The si)ace be~w for Cc~mis~ion use~' DATESeptember 17, Samples required Mud log required ~IYES i-]NO BYES []NO Permit number Approval date ~/-///.,~ 09/25/81 CONDITIONS OF APPROVAL IDirectional Survey required I APl number UYES I~[NO SO-- o ~? - · o (o(~ 3 SEE COVER LETTER FOR OTHER REQUIREMENTS I September 25, 1981 APPROVED BY ,COMMISSIONER by order of the Commission DATE Form 10-401 Rev. 7-1-80 Submit in triplicate · SUPPLEMENTAL DATA SHEET FOR APPLICATION FOR PERMIT TO DRILL CONOCO et al. MILNE POINT NO. C-1 CONOCO INC. 2525 "C" Street- Suite 100 Anchorage, Alaska 99503 I CEMENTING PROGRAM A. The 20" OD conductor casing will be 'cemented to the surface with perma- frost cement in 26" bucket drilled hole. B. The 13-3/8" OD casing will be cemented to the surface with permafrost cement through drillpipe stinger stabbed into float collar and through fl oat shoe. C. The 9-5/8" OD casing will be cemented through plug container head float shoe, and float collar with 590 CF Cl.ass "G" cement. Isolation of the 13-3/8"-9-5/8" casing annulus @ the 13-3/8" casing shoe will be accomplished through multi-stage cementing collar run at the 13-3/8" casing shoe with 100 CF of permafr, ost cement. Non-freezing fluid will be placed in the 13-3/8"-9-5/8" casing annulus through the permafrost utilizing multi- stage cementing collar placed at the base of the permafrost. D. The 7" OD liner will be cemented through drillpipe, liner cementing equipment, float'shoe and float collar, with 460 CF of Class "G" cement. II ANTICIPATED GEOLOGY O' - 4,650' 4,650' - 9,200' 9,200' - 9,620' Surface conglomerates, silt and sand sequences Estimated base of permafrost @ 1,800' Siltstone, shales Kuparuk River formation III FORMATION EVALUATION A. Standard mud logging equipment will be installed while drilling interval 60' to total depth'. B. Full size cores may be taken as determined by on-site geologists. C. Wireline logs including: Dual Induction Laterolog; Borehole Compensated Sonic-Gamma Ray; Formation Compensated Density with CNL and GR-Caliper. IV DRILLING FLUIDS Depth O' - 2,000' 2,000' - 8,000' 8,000' - 9,620' Type Dens i tN R E C ~ ) V ~ 0 Gel - Fresh Water 9.5 - lO.O ppg SEP 1 8 ]981 Low Solids - Nondispersed 9.5 - 10.0 ppg Low Sol i ds - Li gnosulfonate 10. 0 - 10. 5 P~$ka Oil & Gas Oons. Oommlssiorl Amchorags Milne Pt. Unit - - Preposed. Drilling ::1981 ' .- Supplement. te SPCC ..... 2195 SEP 1 8 ]gS] Alaska Oil & Gas Cons. Anchorage ~-- l ~ -.,~ -% ~ N .--v- f't Ï"'t i7'>'" Kr: tiVED SEP 1 8 1981 Alaska Oil & G ("' .. ., aù Cons C Anchoragå Ol11misSiOl1 ~~. ~wJJG PAl> PiAl MJUJ6 PO/NT C-I XAL£: 1"= 'laJ' I VATé " 9/ IS/Sf · RECEIVED SEP 1 8 1~1 & Gas Cons. Comrais~:c~., Anc.~orag~ ') SEP 1 8 1981 Alaska Oil & Gas Cons. Comrniss:c,, Anchorage CHOK'Z~ & KILL MANIFOLDS FOR '"~ ~'~ III Io/8 & 9~'OD CASING BOP STACK ~o~ ~u~ ~u~ - KILL MANIFOLD ,, REMOTE PRESSURE GUAGE SENSOR DRILLING SPOOL · ~o ~q< NOTE: 1. HYDRAULIC CONTROLLED REMOTE OPERATED o z Oi~ [ I Hydraulic Control Systen for BOP Stack g Choke Hanifo]d to include (5) T' Station Co. trol Hanifold located remotely ~.'ith 3000 psi Acc~ulator ~ 160 gaL: Re%ervoir Station Control ~anifold p!u~ variable Choke Control to be Class Eill ~'.=if~i= SLzc-~t:n~ 2"-5000 _. ~ CHOKE TO SHALE SEp 1 8 19r: .A/aska Oil & Gas Cons. ,,.~; . BOP ;,;,:,NIFOLD LAYOUT CO::OCO, INC. H. D. Haley Manager of Production Ventura Division September 2, 1981 Conoco I nc. 290 Maple Court Ventura. CA 93003 (805) 642-8154 Mr. L. C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Permit Request Milne Point/Conoco Attached is a permit request for the authority to drill three oil wells on the Milne Point Unit of the Alaskan North Slope. These wells are designated as B-2, C-1, and D-l; the letter indicating the drilling site location and the number is the sequence in which the wells will be drilled from the respective location. A map of the area is attached which designates the location of these wells. A surveyed location will be provided once the well is staked. Also attached you should find our check in the amount of $300.00 which according to the Alaskan Administrative Code is the filing fee required. Your contact relative to the permitting of this well is Gary Merriman. Gary can be reached by dialing 279-0611. Very truly yours, / H. D. Haley Division Manager of Production DLD-fes encs CC' Gary A. Merriman CHECK LIST F(~R NEW WELl, PER,MITS Company ~=> ~ ~ Lease & We] l No. /~,~',/~ ~. /'~ ~. C-I ITEM APPROVE DATE (1) Fee ., , . me 3. 4. 5. 6. 7. 8. (3) Admin ~+ g-~/ ~/&~% 9. (9/ thru 11) 10. 11.' (4) Casg~]"~t~ru ~0~-~/ t~l ~thru~ 2/4) (6) Ad, d :~ Geology: Engine~ering: HWK ~_~ ~C-SjALW_gA ~ J KT ~RADT/~/~ B EW ~ · · rev: 03/10/81 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is the permit fee attached .......................................... YES NO Is well to be located in a defined pool ................... Is well located proper distance from property line !! '![!!i ! !!'"~'~ Is well located proper distance from other'wells ...... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ..........~ .... Is operator the only affected party ........................ Can permit be approved before ten-day wait .......... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and ~surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation ploposed ..... Is a diverter system required ............ Are necessary diagrams of diverter and BOP equi ent at~ached Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78).[.' ........... Additional requirements ............................................. Additional Remarks:_ REMARKS INITIAL GEO. j UNIT iON/OFF POOL CLASS. ,STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ~ .... $CHLUMBEEGE~ .... ~ V ~IR I F IC ~'l l. Ol~-i bVP O09.;i~Ot VEI~i~'I, ChTIi3N S~BViCE NAaE : ~P_~V lC DATE :82/03/11 O~IGIN : CUN~'INUATICN ~ :01 P~EVIUU5 ~L COMMENTS ~-~. TAPE I-II~;AI3EIq SERVICE NAME :,SER~IC DATE :82/05/11 [~IGIN :10/0. TAPE NAM~ 162602 CONTINUATION ~ :{1 PREVIOUS TAPE COMM~NT5 :TAP~ CO~MENTfi ** FILE H~,ADEB *~ FILE NAME :SERV1C.O01 SERVICE NA~E : VERSION # : DATE : ~IhE T~PE : PR~¥IOUS ~ILE : ** INFORMATICN RLCORD$ ~* CN : CONOCO JNC. WN ,: ~N : Mlb~E POINT RANG: %;UWN: SECT: 10 COUN; N. SLOPE STAT: ALASKA CrRY: U.S.A. MNEM PRES; DibOO1F ,, ~ECOSD TYPE; 047 ** ~8;C©RD T~P~ 047 UNIT kNIT 000 000 000 000 000 000 000 000 000 TYPE o(o CATE 000 000 000 000 000 000 000 000' 000 CA~E 000 SIZE~ )12 0O4 012 0£3 003 002 OOB 006 006 SIZE 0C7 CODE O65 065 065 0~5 065 065 O65 065 065 KOtE Oe5 LVP 009.h03 ygR£f]CATiON LIS~'IN3 PAGE 2 ** F~ISCORD TYPE 047 ** ************************************************ COMPANY = 2DNOC~ INC W~bh :: ~]EbD : NINNE POiN~~ COUNTY : STAT& = ALASKA JOB # 1UTO/,b2602 NUN #4, LOGGfD 10-f=B-82 BOTTO~ bUG TOP bOG iNTB~VA~i CA$1NG-bUGGgR BIT TYPf ~Oh~ f'GUID D~N$1T¥ VI$CO$iT~ PH FbUID Gu86 ~C @ MgA~. ~E~P. : 10440 ~7'. = 9800 : t(,,b25 IN. : 8.5 IN, : DISPLI~6ED = 9,7 ,-'- 45,0 $ = 10.0 .-'- 7.6 : 2.360 @ 77 ;: 1.610 ~ 7,1 - 1.730 @ 77 :: 0.981 @ 21'1~ L~'P 009,h03 ¥~.RII~ICATION ].,2[STING PAGE 3 MATRIX 6AN£ S'I'O~ E DATA fORM~'I Nt, CURD ** ~NTR~ BbO~K6 T~k SIZE ~EPR CODE 4 1 66 8 4 73 9 4 65 0 1 66 DATUM 8PE MNEM SERV~(E ID DEPT $~LU OIL ILM OIL ibD ElL G~ D'I' ,EH( SP BHC NPHI RHOS FDN D~HO FDN CAbi FDN SGR ~')N Nfl~T NCN~ ~DN FCNL PSOX PRX M1NV MNOR CALI PRX POT~ THOR U RA ~ NGT SGR NGT C GR NGT OHMM CHM~ IN GAPI GAP1 AP1 API LOG T~PE CLASS NOD 0 0 0 0 7 0 0 0 7 0 0 0 7 12 45 0 7 1 0 0 7 31 32 0 60 52 32 0 6O 1 0 0 60 31 32 0 42 68 2 0 42 ~5 1 0 42 44 0 0 42 28 3 0 42 0 0 0 42 42 1 0 42 34 92 0 42 3~ ;~3 0 21 0 0 0 21 25 2 0 21 26 2 0 21 2~ 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SI ENIR¥ 1 60 . 11['~ 0 ZE PPO0~8S SAMPLE LEVEl., 4 0 I 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 4 0 1 ~ 0 '-i 0 1 4 0 4 0 4 0 1 J4 0 1 4 0 4 0 4 0 4 0 1 4 0 4 0 4 0 4 0 REPR CODE 68 68 68 68 68 68 68 68 6~ 68 68 68 68 68 68 68 68 DATA ** DEPT SP GR CALl FCNL 10469.000 -999.250 01.063 -9%9.250 -999.250 -999.250 SFLU (JR NPHI SGH PROX PO'I A -999.250 -999.250 DT -999.250 RHOB -999.250 NRAT -999,250 MIN~ -999.~50 THOR -999.250 55.594 -999.250 -999.3~0 -99).250 -9§9.250 !LD SP DRHG NCNL MNOR URtN -999.250 -39.469 -999.250 -9S9.2~0 -}99.250 -9S9.250 LVP 009.H03 VERIFiCATiON LI6TII~6 PAGE 4 DLPT SP CALl ~CNL CALl SP C~LI fCNL CALl DEPT SP CALl ~CNL CALl DEPT SP CALl ~CNL CALl SGR DEPT SP GR CALl FCNL CALl SGR DEPT SP CALl FG~L CALl SGR DkPr SP CALl ~CNb 250 10qO0.)00 -86.813 8.953 7220.00u 8.500 25.297 10300.000 8FLU -95.813 G~ 2b.~09 NBki 8.922 SGR 5708.000 PROX 8.72; PUIA 34.688 CGR 10200.000 SFLU -101.063 GR 40.688 NP~I 10.070 2140.000 8.484 POIA 54.188 C~ 10100.000 Sf'LU -101.125 GR 45.188 NPkI 10.719 SGR 1255.000 PROX 9.492 PU~A 63.2~1 CGR 9900.000 -84.375 GR 12.188 NP-kl 10.836 1925.000 9. 383 PO'IA 97.0c3 9800.000 SFLU -35.594 GR 99.025 NP~I 1118.000 P~O~ -999.2~0 119.188 2b.9~2 0.)7~ 25.2~7 18. 103 0.002 22.125 79.9~8 32.969 1.172 34.688 36.063 0.009 31.. 8'~5 11.250 47.312 1~ .377 54.1~8 6.194 0.008 35.188 5.141 69.875 15.918 63.281 3.996 0.011 49.7::0 132.8'15 ,18.234 0.439 ~]6.906 7. 900 0.003 14.773 19.594 97.000 1,2.012 97.063 3.390 0.018 73.625 8.2ll 99.625 24.365 ;42.750 1.5~3 RHOB MiNV THOR 1LM DT NRAT M1NV THOR '~T NR~T MiNV .IbM DT RHOB NRA~ N1NV THOR ILM DT RHOB MINV THOR ,ILM DT RHOB NRAT MINV iLM DT RI~OB NRAT MINV 77.500 53.B~4 2.684 1.028 2.426 4.660. 52.6~8 55%594 2.668 1.050 17.331 4.660 1).070 60.594 2.088 1.901 1.307 5.3t3 6.109 65.188 2.65~ 2.256 2.204 ~.625 51.781 2.668 1.027 15.651 2.549 10.719 69.000 2.631 1.998 -0.113 11.977 5.480 77.750 2.582 2.490 O.b18 i LD SP NCNL UR.~N 8P ~NCR ORAN ILD SP DRHO NCNL MNOR UH~N SP ORAN IDD DRHO NCNL MNO~ ORAN SP N2NL UBAN ILD SP DRHO NCNL 55.688 · ~7 1.625 -0.010 E144.000 4.332 0.414 ~47.656 -39.~69 0.008 6544.000 48.719 0.368 8.375 -91.250 0.104 ;4304.000 2.199 2.482 5.836 -69.500 0.071 3194.000 2.858 1.768 66.750 -66.063' -O.OO3 6792.0C0 11.708 0.279 9.875 -73.250 -0.010 4112.000 11.654 3.0bl 5.055 -147.125 0.028 2782.0¢0 0.905 LVP O0c.,[t03 VER£~lCATIUN LITT1NG PAGE 5 42.750 CG~ DEPT 9700.000 SFLU 8P -78.375 GR GR 39.469 CALl ,10.648 k'CNb 1464.)00 CALl 13.4(6 SGR 43.500 CG~ DEPf 9500.000 $~LU 2P -50.156 GR GR 88.750 NPHi CALl '1 ~. 858 SGia FCNL 724. 000 CALl 1].797 SGR 95 . 875 CGi~ OEPT 9400.000 SFLU SP '97.563 GR GR 29.641 C.~LI 11.61 1 5GR ~CNL 1512.000 PROX CALl 11.859 PO'iA SGR 30.703 DEPT 9]03. )00 6~LU SP -81,.6~5 G~ (~ 39. 188 NPHI CALl ~11..8)7 5G~ ~CNL 1439. 000 PROX CALl 12.0t3 PO'IA SGR 41 .--344 CG~ D~PT 9200.000 S~LU SP -Y6.563 GR GR 57.156 NPkI CALl 11.641 SGB ~CNL 824.0(0 PROX CALl 12.227 PO~A ~GF 56.625 CGR DEPT 9100.000 SP -74.375 GR GR, 81.4]~ CALl 12.969 -0.005 -24.266 10.164 39.469 19.922 :<3.500 3.190 0.0~2 4Di. 094 15.563 37.969 ,15.186 37.781 7.143 0.0.07 30.203 5.211 88.750 26.123 95.875 3.952 O.022 75.250 ~.984 29.541 18.1!5 30,703 4.771 0.004 2~.344 7.703 :39.188 21.191 ~41.344 5.977 0.010 30.156 7.789 57.156 25.635 56.625 4.868 0.009 24.688 72.500 81.438 14.697 95.438 THOR IbM D2 RHOB N~AT MINV THOR DT NRAT THOR ibm DT NHAT NINV IbM DT RHOB NRAT MINV THOR ILM D~ RHOB NRAT MINV THOR DT NBAT MINV 5T RHOB NRAT -1.503 ~.195. 71 750 21496 2.242 0,453 6.699 {. 3.7u6 65.563 2.570 1 0.500 5..715 4.125 74.750 '2.684 2.719 0.449 1~.5~4 4.8~7 7~!.375 2.428 2.154 0,499 4.945 4.887 78.188 2.369 2.357 0.514 2,852 5.723 73.I88 2.484 2.652 0,555 3.160 23.016 68.000 2.615 1.959 URAN IbD SP DRHO NCNL URAN ILL SP DRHO NCNi, ~NO~ ORAN ILD SP DRHO NCNL MNOR UR~N !LD SP N ZNI, ~!NCR URAN ill) SP DRHO NCNL MNOR URAN ~[ Ri~ 0 NCNL MNOR ORAN SP DRHO NCNL 9.492 8.664 -999.250 0.017 3396.0C0 1,172 0.473 11.117 -999.250 0.048 4024.000 i.196 1.075 4.219 -999.250 0.112 2000,0C0 O.gO0 2.775 3.945 -99).250 0.036 3476.000 0.938 0.915 4,141 -999.250 0.015 3570.000 1,168 2.000 4.570 -999.250 0.060 2266.000 1.392 4.906 24.781 -999,250 0.009 3060.000 LYP 0)9.ti0J VERIFICATION L16T1NG PAGE FCNL CaLl SGR SP CALl CALl Dk;PT SP ~'CNL CaLl OEPT SP GR CALl CALl SGR O~PT CALl CALl. DEP~ tip GR CALl ~CNb CAbi DEPT SP GR ~CNL SGR DkPT SP GR I504.000 PROR 15.580 POTa 1~5.438 CG~ 108.640 0,008 9000.000 SFLU -64,375 GR 77.125 NPH1 14.039 883.500 PROX 15.695 POTA 70.438 CGS 33.905 77.125 25.293 70.9]8 10.193 0.012 39.406 Eg00.000 SFLU -77.875 Ga 98.500 N~I 13.008 SG~ 747.0(10 PRUX 15,484 POIA 72.375 CG~ 5.863 98.500 29.492 72.375 7.224 0.011 33,312 8800. 300 SFL0 -50.6~5 GR 9'1.503 NPH1 ,! 5.558 SGI~ 422.750 PROX lb.b5~ POTA 87.938 CG~ 1.825 97.563 44.189 ~7.93~ I .544 0.022 63.438 ~700.000 -60.719 GR 99.438 lb,594 375.250 17.32~ ~8.063 CG~ 49.805 88.063 1.343 0.020 68.063 8~00.000 SFLU -61.2ui G~ ~0.312 NPHI ,17.bt~ SG~ 400.500 PROX 17.234 POTA ~'l.O00 CG~ 2.260 80.312 44.824 87.000 1.111 0.019 67.125 ~5G0.0£0 -b2.125 '~b.563 NPHI 15.706 376.750 PROX 17.203 POmA 79.500 CG~ 3.090 86,563 45.654 79.5O0 1.791 0.016 50,813 8400. 000 .5t"LU -eS. 31 2 GR 69. 875 NPt~I 3.771 e9.875 35.279 MINV IHOR RBOB NIghT MiNV ThOR DT RHOB NRA1' NINV THOR 1LM D~ RHOB NRAT' NINV THOR ILM DT NRAT MINV THOR ILM DT RHOB NRAT M.1NV THOR DT RHOB NRAT MiNV THOR ibm D3 RBOB 11.448 7.758 i ~..242 ,~8.188 2.586 2.Bt: 5 3. 072 4.1;9 81,563 2.434 2.945 1,993 5.422 1.365 118.563 2.242 3.846 0.653 9.711 1.4[9 110,375 2.322 4,188 0.978 .!1.383 2.010 94.375 2.236 3.939 1.27i 11.615 2,697 90.000 3.934 1.336 i0.227 2.898 82.3'75 2.400 ORAN 'ILD SP DRHO NCNL MNOR UR;:N ILO SP N3NI, ORAN ILD DRHO NCNL MN{OB SP N'NL MNOR ORAN ILO SP DRHO NCNL MNOR ILD SP DRHO N31qL ORAN ILD SP DRH~ 36,406 5.895 1i.~44 -999.250 0.009 2510.000 4.299 4.402 3.801 -999.250 -0.004 2278.000 3.210 5.543 1.363 -999.250 0.104 1665.0C0 1.200 3.371 1,3f5 -999,250 0.067 1617,000 1,244 2,840 1.966 -999,250 0.071 i564.0C0 1,500 2,816 2.758 -999.250 0.~2 1552,000 1.389 3.217 2.764 -999.250 0.055 CONFID L LVP 00C..H03 VEML~ICATION LISTING PAGE 7 CALl FCNb C ALI. DEPT SP GM CALl f~CNh CALl 8GR DEPT SP GR CALl FCNL C~LI 6GR DEPT GM CALl ~CNb CALl DEPT SP GH CALl ~CNL CALl SGR OkPr GM CALl FCNL CAbI SGR DkPT GR CALl FCNL CALl SGR DEPT lq.805 5GR 505.500 PRUX 17,203 POI'A ~8,~25 CG~ 8300,000 5~LU -O9,625 GR 78.250 NP~I 15.688 380,500 PRU~ 17,156 PUTA 79.125 CGB 8200.000 6FLU -71.063 GR 80.438 N~hl 14.383 SGM 495,000 PROX 17,234 .POIA 74.375 CG~ 8100, )00 SfLU -73,6~5 G~ 77.375 NPH1 16,0~3 SGH ~70.000 PRUX ' l ?. 1.56 POmA 76,625 CGH 8000.000 SFLU -71,553 GR 75,b25 NBEI 15.578 SGR 591.500 PROX 16.703 PO"IA 79.5~0 CGR '1900.000 S~'LU -75,438 GR '10.000 NPHi 16,250 SG~ 503.000 PROX 15.414 POTA 74.625 CGH ,i800,000 8FLU -78,625 GR '70.938 NBkl 15.695 MGM 591,000 PRQX 15.297 POTA 85,438 CGM 7'100.}00 6FLU -81.~25 G~ ~8,625 2.408 0.0i6 78,250 47,154 79.125 1.533 0.017 56.125 2,420 80,438 38,477 74,375 2,146 0,018 6~.0~3 2,773 77,375 31,445 70,625 2.232 0,014 59,969 2,06~ 75.625 3b.52~ 79.500 2,040 0.019 01..5~1 2.191 70,000 37,842 74.625 1,141. 0.018 58,312 9.484 76,93B 36.914 85,438 1.922 0.01) ~4.875 3.225 7~,312 N~AT N1NV THOR ibm 'ET MHOB NM~.T MIN¥ THOR DT RHOB NRAT NiNV THOR IbM DT RHOB NRAT THOM IL~ DT MHOB NRAT.. lLM DT MHOB NR~T MINV THOR ILM bT NRAT N1N¥ THOR iLM D T ],387 ~.512 R',953 2,254 l!0,375 2,223 4,047 1,4i2 9,977 1.951 91,750 2.410 3.498 0,945 10.063 2,461 90,000 2,500 3,158 1.259 11,484 1,8'65 96,750 2,453 3,422 0,784 i0,039 1,860 96,750 2,379 3,512 0,657 9.719 3,090 92.563 2.420 3,445 0.612 10,922 2,977 89.5(3 N:NL MNC~ bRAN ILL SP DMHO NCNL {] B[ SP N NNCR URAN ILD SP DRHO NCNL MNOR URAN [lii[ SP MNOR URAN 1LD SP DRHO NCNL MNOR ILL $P N."NL URAN I L [3 SP 1760.000 2.290 2.340 2.035 -999.250 0.052 1648.000 1,737 3.398 1.924 -999.250 0,134 1767.000 I .336 I .749 2,398 -999,250 0,031 2362,000 1,674 2,648 '1.817 -999.250 0.030 2094.000 1.301 2.979 1.921 -999.250 0.070 18f6.000 1.430 2,078 2.0f3 -999.250 0,071 1967.000 1,973 2,910 2,984 -9c~9.250 LVP 009.H03 VEHI~ICATIGN LISTIN~ PAGE 8 CALl FCNL CALl D~PT SP CALl CALl DEPT SP CaLl FCNL CALl $GR DEPT SP GR CALl FCNL CALI DEPT GR CALl ~'CNL CALl fOR DEPT SP G~ CALl ~CNL CALl SOB DEPT CAL£ FCNL CALl SGR 77.312 N~kl 15.852 SG~ 655.00O PROX 10.203 PU'I'A 71.503 CG~ 1000.000 SFLU -19.125 GR 67.815 NPHI 14.289 18b. O00 PHOX 16.734 POTA O3.025 CG~ ,~500.000 SFLU -79.750 OR 82.563 NgkI 18.203 SO~ 502.250 FROX i7.297 PUIA 79.813 CGR -7~.0fi3 GR 17.750 NPhI ,18.0~. 7 535.500 PROX '1 7,. 4( b PO'iA 79.438 CG~ '/300.000 $~'LU -83.063 GH 64.625 NP, F. i 16.125 SGR 1065.0~0 PROX 17.469 PDTA 64.813 CGH 7200.000 SFLU -80.063 73.125 NPH 1 664.000 PRf3~ 1'7.406 POTA 72.438 CGB 100. 000 -~4.813 Gi~ 74.5e3 NiCk I 15.1 ~3 SGR 653.500 PRL]X 16.813 POTA 80.025 CG~ 30.322 71.563 2.511 0.016 5~.43~ 3.295 67.875 27.14~' 63.025 3.$9~ 0.014 53.781 ~.471 82.563 35.547 79.B13 1.392 0.021 69.375 2.795 77.750 36.865 79.438 1 .O01 0.021 66.563 5.418 64.625 24.463 64.813 3.332 0.016 59.969 4.645 73.125 29.102 ,7 2.4.~8 0.013 50.438 3.4~0 74.563 32.813 80.625 2.514 0.018 61,.9(6 ~HOD NRAT NiNV THOR 1LF% HHOB NR2T NINV THOR iLN DT RHOB NHAT ~INV THOR DT NRAT THOR ~ILN DT N~AT NINV THOR ILM RHOB NRAT ~INV THOR ILM DT HHOB NRAT ~INV THOR 2.409 3.078 1.694 9.805 3.023 ~3.750 2.498 2.826 2.929 10.164 1.9S6 99.563 2.381 3.436 1.344 11.531 2.373 94.188 2.438 3.506 1.914 10.523 4.695 83.503 2.406 2.691 2.697 10.492 3.3~7 {~2.375 2.387 3.0¢4 ~.821 10.4(4 3.018 95.56'3 2.406 3.225 1.647 11.445 I~NCR U WA N IbP DRHO .NCNL MNUR ILD SP :[ Ri- NZNL ENCR URAN ILD SP DRHO NCNL URAN Ill~[ SP NCNL MNOR U~AN ILl) SP DRHO NCNL M.NOB IL[~ :[[{FO N3NL URAN 0,047 2112.000 2.241 2.141 2.963 -999.250 0.023 2202.000 2.874 1.912 1.938 -999.250 0.031 1762.000 1.730 1.481 2.348 -999.250 0.055 i967,000 2.049 1.823 4.285 -999.250 0.027 2864.000 5.496 0.687 3.266 -999.250 0.039 2102.0C0 4.230 2.273 2.8t5 -999.250 0.027 2154.000 1.670 2.652 CONFIDEHTiAL DI-.PT 1~03.300 5[-LU 6.625 ILI~ 5.109 ILD 4.770 LVP O0~.H03 VEH]:~ICATION LISTING PAGE 9 CALl FCNL CALl DEPI' ~P GR CALl FCNL CALl DEPT SP GR CALl fCNL CALl SGR fP CALl FCNb CALl DEPT SP CALl ~CNL CALl SGR DEPT SP CALl FCNL CALl SGR DEPT SP GR CALl ~CNL CALl -89.503 GR 73.875 NPiJl 12.9~8 5G~ 7C7.5¢0 PR©X 16. 125 PO'IA Ol~, b~ 5 COB 73.8'15 30.908 6~ .b25 7.~39 0.0!6 56.625 ~900.000 S~'LU -90.813 GR 102.0t)3 NPhl 15.555 SGI~ 454.500 PR6X 16.734 PO'IA 90.375 CG1~ 2.1~4 102.063 45.605 90.375 1.941 0.026 79.375 bS00.0(0 8FLU -90.81] GR lC3.813 NP~I 17.15~ SGB 332.250 PROX 11.641 POI~ 94.8}3 CG~ 1,404 103.813 51.953 94.813 1.553 0,019 69.500 6'100,000 8f'LO -90,000 GR 105.188 NPHI )]8.0(0 8G~ 351.500 P~UX 17,781 PUTA 95.938 CG~ 1.733 105.188 51.318 95.938 1.855 0.020 70.312 6600.000 SFLU -93.500 GR 149,'875 NP~I 18.563 371.250 PROX 17.844 POmA 144.500 CG~ 2.326 149,875 49.951 144.500 2.617 0.026 7~.3~2 65O -9 lO 1 35 '1 9 0.000 SFLU 0.5E3 GR 8. 503 mPliI 8.859 8G~ 9.500 PROX 8.3] 2 POIA 7.1 U8 CGR 2.834 f(8.563 48.291 97.188 2.094 0.024 70.375 6400.000 SFLU -Ul.312 GR 109.5~3 N~kI 14.766 5GE 353.500 PROX 18.203 POmA 94.9]~ CG~ 1.349 109.563 49.072 ,8 9..008 O.Olb 0~.5~3 DT NEAT THOR 1LM DT RHOB NRAT NiNV THOR DT < NEAT MINV DT RHOB NRAT MINV DT RHOB NEAT MINV THO~ IbM' DT RHOB NEAT NINV THO~ ]ILM DT RHOB NEAT MINV THOR 92.000 2'385 3.039 1.754 10.125 1.945 103.563 2.328 3.926 0.733 12.4~4 1.200 122.750 1.969 4.320 0,615 12.078 1.453 116,375 2.004 4.3C5 0.629 11.852 1.932 115,375 1.769 4.242 0.612 10.945 2.322 1!5.750 1,9i5 4,100 0,635 9,836 1.104 120.188 2.064 4.094 0.787 13.555 6P NCNL ORAN IbP DRHO NCNL URAN ILL SP DRHO NCNL MNOR ILL DRHO NCNL MNOR URAN SP N2NL ILL SP DRHO NCNL MNOR URAN SP :r RI- o URAN '999'250 0.023 2336.000 3.318 1.706 2.008 -999.250 0.084 1771.000 1.210 ~.5~2 1.239 -999.250 0.063 1471,000 0.947 3.590 1.464 -999.250 0.064 1558.0C0 0.969 .3.510 1.922 -999.250 0.029 1571.000 0.975 10.242 2.529 -999.250 0.062 1551.000 1.004 3.793 0.952 -999.250 0.064 1491,000 1,131 3.965 bVP 009.H03 VEt-', /E .ICAI'I(JN LI.,.%TIt~3' PAGE 10 8P -85,500 GH 174,250 CALl 13,922 FCNb 41b,250 PROX CALl 1~,000 POTA 8GR 139,875 CGB 2,848 174.~250 45.459 139,~75 2,967 O,O3O 80,125 DEPT .b2O0.000 SP -95.563 GR GR 99.813 NPHI CALl ~1},]18 6GH FCNL 520,000 PROX CALl 17,969 POmA SGR 92,000 CGR 2.432 99.813 38,037 92,000 2,557' 0,020 63,469 DEPT ,t 100.000 SFLU SP -105.0~3 GR GR 93.312 NgI~I CALl 17.016 SGH ~'CNb 518.0(0 PRGX CALl 18.26~ POmA SGR 82,063 CGR 3.5~1 93,]12 38,72!. 82,063 2.598 0,019 66,000 OEPr bO00.000 SFLU SP -104.81] GR GR 89.8{3 NPnl CALl 15,344 MGM ~'CNL 492,250 PROX CALl 17,984 POTA SGR 83,063 COB 2.717 89,813 39,893 83.063 2,507 0,021 63,750 DEPT :~900.000 SFLU SP -100.813 GR OR 79,813 NBF. I CALl 19.406 SGR FCNL 421,500 PROX C~LI 18,641 PU~A SGR 84.875 CGR 3.049 79.813 39,404 84,~75 2,230 0,021 6~.688 OEPT 5800. 300 6FLb SP -1CO,0t3 GR GR 76,000 NPHI CALl ~CNL 357,000 PROX CALl 21,500 POTA SGR 88,375 CGH 2,900 76,000 49,854 E8,375 2,357 0,023 66.938 DEPT 5700,000 SP -102.250 GR GR 82,81.3 N~kI CALl 19.953 FCNL 351.500 PHOX CALl 21.531 POmA ~OF 88.500 CGH 82.813 47.217 88.500 2.637 0.021 66,688 DT RHOB NRAT glNV THOR DT RHOB NRAT MINV THOR DT RHOB NRAT N1NV THOR ILM D~ RHOB NBAT M1NV THOR ILN. RHOB NRAT MiNV THOR ILM D7 RHOB NRAT N1NV THOR ILM DT NRAT MINV 3.020 91.000 2.178 3.875 0.924 12.430 2.205 99,563 ~.404 3.551 0,572 !0.234 2.2i9 101.188 2.377 3.582 0.640 11.070 2.414 98,000 2,289 3.6(4 0,~02 !0,406 3.814 95,750 2,389 3,684 0,670 10,203 2.791 94.000 2.303 4.289 1,354 10.477 2.809 102.188 2.297 4.129 1.109 11.633 SF N':NL URAN ILD DRHO- NCNL MNOR SP NCNL MNOB ORAN ILD SP DRHO NCNL MNOR UR~N iLD SP N:NL ORAN ILD SP DRHO NCNL UH~N ILD N ORAN 2,650 -999.250 0.050 1720.000 1.470 8.883 2.262 -999,250 O.04O 1874,0C0 1.061 3.896 2,238 -999.250 0.086 1874.000 1.043 1.951 2.545 -999.250 0.052 )18~1.000 1.305 2.738 2.916 -999.250 0.050 i705.000 1.179 3.004 3.016 -999.250 0.045 1541,.0¢0 2.151 3.041 2.951 -999.250 0.048 1537,000 2.'053 3.088 hVP O)9.~i03'VI..'IqiFICATILJlN L16TING PAGE; SP CALl CALl DEPf 2P GR CALl FCNL CALl SGR D~PT SP CALl FCNb CALl OEPT SP CALl FCNb CAbI DE;PT SP CALl FCNb C~.L1 SGR DEPT SP GR CALl FCNL CALl DEPT SP CALl ~CNL CALl 5~)(O.0( 0 6FLU -102,750 GR lC5.0~3 NPHI 17. 016 SGi~ 373,5(0 PROX 18,953 PO~'A 94,875 CGB 5500.000 5FLU -100.500 GR 79.063 NPhi 14.QS9 SGR 550,000 PROX ,15.395 POmA 73,375 CG~ Lq00.000 5~'LU -95,500 Glq 69,938 ~PHI 14.813 SGlq 476.0(0 Pt.(OX 17.625 PO'IA 67,125 CGi{ 5300,000 SFLO -97,025 GR 71.750 NPHI 17,68~ 360.500 PROX ~0.2~7 POmA 70.250 CG}~ 5200.000 S~LU -100,563 GR 87,125 NP. kI 17,025 SGR 392,750 PRO]( 19.765 POTA 74.875 CG~ 5100.000 Sfi.,u -99.563 GR 63.155 NPHI 16.391 6GR 390.000 PRUX 19,484 POTA 65,438 CG~ 5000,000 -97.000 GR 61.344 N~kl 14,742 407,'/50 PROX 18.291 POIA 2.i39 ILM 105,063 DT 48.340 RHOB 94,875 NRAT 2,104 M1NV 0.024 7'HOR 71.312 2.477 ILM 79,063 DT 37,842 RHOB 73,375 NRAT 2,930 MINV 0.016 ~HOR 55.219 2.588 ILM 69,938 DT 40,576 ~FH[B 67,125 NRAT 2,913 MINV 0.014. THOR 51.688 2.088 IbM 71.750 ET 49.072 RBOB 70,250 NRA7 2,~60 M1NV 0.019 THOR 56,156 2,434 fILM 87.125 DT 44,385 RHOB 74,875 NR.AT 2.663 MINV 0.021 THOR 56,4~8 2.506 ILM 63,156 LT 48,242 RHOB. 65,438 NR~T 2,521 MINV 0,014 THOR 47,656 .).3~6 1LM 61,]4~ DT 46,826 RHOB 50,781 NRAT 1,689 N1NV 0.014 THOR 1.872 113.750 2.320 4.i17 1.1i2 1!.063 2,344 100.750 2,330 3,453 1,184 9,617 2.318 94.563 2.332 3.625 1.420 8.977 2,070 109,563 2,287 4,172 1,322 8,719 2.408 106.000 2,309 3,912 1.598 B',367 2,459 106.000 2.291 4,0~0 1,697 7,4~8 1.354 115,563 2.232 3.973 0.996 I LD SP DRBO NCNL MNOR UR/IN ILD 6P DRHO NCNL MNOR URAN I1D[ 'SP DRHO NCNL URAN ILD SP DRHO' NCNL MNOR URAN URAN ILD SP DRHO NCNL MNOR UR~N ILL SP N3NL 1.960 -999,250 0.047 1574,000 1.508 3,619 2.361 -999.250 0,017 1978.000 2,055 2,857 2.273 -999,250 0,010 1777,000 2,1.51 2.389 2,~72 -999,250 0,028 1558.000 1.804 1.998 .2.525 -999.250 0.050 1526.000 2.160 2.613 2.590 -999.250 0.032 19~5.000 2,084 2,557 1.453 -999.250 0.036 1631.000 1.088 i.413 bVP 009,H03 VERiFICATiON SGR 55. 181 CGl. t DEPT 4900.0C0 Sf'LU Sp -108,b13 GR rjr 69.43,8 NPfll CALl 14,367 8GR FCNL 5¢1,.250 PROX CALl 17.828 PO'IA SGR bT, 188 CG~ DEPr 4800.00(} SFLU SP -101.750 GR GR 74,250 NPH1 CALl 16,234 SGR i' CNL 334,500 CALl 18,844 PO%'A SGR 74,500 CGB DEPT 47( O. O( 0 SFLU 8P ,,99.O63 GR GR 1~7.87b NBE1 C.~hi 17,188 SGR FCNL 351.500 PRO,~ CALl 19.875 PO~'A SGR 7 1 . 8 13 CGR D~PT 450D.)00 8FLU SP -113,5~3 GR GR 82.000 NPHI CALl ~CNL 328.250 PROX CALk 20.2§7 PO~~A SGR 79.000 CGH DEPT 4500.000 8FLU 8P -149.500 GR GR 60.469 N~EI CALl 14,172 ~CNL 47 1 . 750 PROX CALl 17.578 POmA SGR 54.469 CGR DEPT 4400.000 SFLU SP -118,813 GR GR B0.813 NPHi CALl 14.0U~ SGR FCNL 475.';50 PRGX CAbi 17.063 PUTA SGR 79.063 CGB DEPT 4300.000 SP -77.563 GR GR 09.375 CALl 1~.992 fCNL 458.750 LI~TING 2.230 69.438 37.402 b7.188 2.657 Oi. Ol9 57.031 2.000 74.750 5Oi. '181 74.5(0 1,911 0,018 56,000 1.809 87.875, 49.31b 77.813 1.759 0.017 5~.188 2.135 82,000 50.537 ,79.000 2,043 0.017 00,438 4.566 60.469 40.869 54.469 9.125 0.015 2.55~ 80.8i3 42.383 79.0~3 2.560 0,021 62.969 2.227 69,375 43,213 61,281 3,277 Ib~ bT ~HOB NRAT THOR 1LM DT MINV THOR ILM D~ RHOB NHAT ~INV THOR 1LM DT NHAT MINV THOR ~iLN DT RHOb NRAT NINV ~HOR ILM N~T MINV THOR DT RHOB NINV 1,866 1.06,375 2,277 3,438 1,412 9.180 1,908 125.000 2,227 4,220 1.300 8.8i8 1.667 119.188 2.I91 4.172 1.103 ~;938 2.213 118.375 2.164 4.254 1.158 9,781 3,088 111,188 2,291 3.625 1.955 7.b09 2,915 i08,000 2.283 3.709 1,478 9.078 2.447 120.563 2.277 3.752 1.606 I L 1) SP DRHO NCNL U[~AN 'iLD SP DRHO NCNL ILD SP MN£R O~AN ILD SP DRHO NCNL MNOR URAN [113[ SP NZNL ORAN ILD DRHO NCNL fiE} NZNL ~NCF~ PAGE 12 · 1,860 -999.250 0,025' 1712.000 i.950 1,444 2,129 -999.250 0.021 ~15(5.000 1,646 2.627 t.778 -999,250 0.028 1424.000 1,402' 2,922 2.496 -999,250 0,041 14~8,0C0 1,676 2,629 2,496 -999.250 0,029 1843.000 3,513 1.123 3.020 -999.250- 0.040 1869.000 1.994 1.784 2.381 -999.250 0.042 1774.000 2.411 6dP 009,H03 VERIFICATION LIST1NG PAGE: 13 C~LI DEPT SP CALl FCNL CALl SGR DEPr CALl FCNL CALl SGR DEPT GR CALI FCNL CALl SGR DEPT SP CALl FCNI, CALI SGR DEPT SP CALl FCNL CALl SGR DEPT SP GR CALl FCNL CALl SGR DEPT $P GR CALl -1 4 41 -1 4 4O j6 O0 O7 13 16 52 O0 25 4O 14 48 42 O0 98 57 13 42 16 64 3900 -96 49 ~77 16 54 38 -1 5 3'1 36 O0 14 46 12 48 15 49 O0 71, 67 12 15 73 O0 80 55 12 . Wi 8 POI'A .2Ul CGB .0(0 SFLO . ~1~ GR ,6~ NPH1 . )55 .344 .~13 .813 GR .883 SGR .8~ 3 POmA .594 CG~ .000 SF[U .312 GR .219 'NPHi .734 SGR .250 PROA ,109 PO'Iff .938 CG~ .000 8FLU .312 GR .938 NPHi .195 SGR .300 .172 .219 CGR . Ol 0 SFLU' .563 GR .938 NPBi .797 ,5(0 PROX ,570 ~OIA ,594 CGR ,6~5 . ~00 ,68~ ,750 ,758 ,0~3 CG~ ,000 ,06J GR · ,650 0.014 42.78~ 2.756 62.688 43.750 62.813 5.029 0.015 46.844 3.895 40,656 45.215 42.594 7.112 0.009 36.156 4.957 57.~19 45. 12 64.938 4.5~1 0.014 52.219 3.182 49.938 41.260 ,54.219 4.595 0.01.5 36.094 4.375 46.938 40.234 49.594 6.995 0.010 38.844 3.084 e7.500 50.293 73,063 .3.096 0.014 47.969 3.1'89 55.469 43.994 52.531 THOR iLM DT RHOB NRAT MINV THOR DT RHOB NRAT M1NV QHOR ~lb~ RHOB NRAT NiNV THOR D~ NRA~ NINV THOR ILM DT RHOB NRAT MIN¥ ~HOR ILM DT RHUB NRAT MiNV THOR DT RHOB NRAT 6.0R7 2.207 115.750 2.209 3.756 1.430 7.496 2.135 113.375 2.129 3.885 1.243 6.656 4,184 114.563 2.191 3.861 2.701 9.008 2.682 114.750 2.162 3.623 1.693 4.352 2.586 119.503 2.164 3.555 !.623 2.465 127.375 2,176 4.109 1.631 7.723 3.281 116.375 2.137 3,758 ORAN iLL SP DRHO NCNL ORAN iLD 8P DgHO NCNL MNOR ORAN 6P DRHfi NCNL MNGR ORAN iLD 8P DRHO NCNL MNf]R ORAN ILD 8P DRHO NCNL ~NO.R ORAN ILl) SP DRHO NCNL MNOR ORAN SP ',[ B? (] N2NL ~.623 1.775 -999.250 0.042 i900.000 2.419 2.262 i.758 -999.250 -0.003 1743.000 1.958 0,541 3.744 -999.250 0.029 1726.000 3.529 1.802 2.348 -999.250 0.015 1797.000 3.299 2.568 2.184 -999.250 0 015 1983:000 3,102 2,186 2.590 -999.250 0,043 }3660.000 2.199 3.563 3.268 -999.250 0.008 2080.000 009.H03 VERIFICATION L16TING PAGE 14. LVP CALl SGR DEPT SP CALl fCNL CALl DEPT SP CALl f'CNL CALl SGR DEP~ SP GR CALl FCNL CALl SP CALl FCNL CALl DEPT SP GR CALl FCNL CALl o~Pr CALl FCNL CAb1 DEPT SP GR 551.000 PROX 15.555 POTA b2.531 C~ 3b00.000 -83.312 GR 56.625 NPHI 12.~06 518.0(0 PROA 15,625 PO~h b5.o8~ CG~ 3400.000 SFLU -80.813 GR 51.125 NPEI 12.969 SGR 624.000 PRO~ 15.773 53.594 ~300.000 6~'bU -71.125 GR 74.813 N~kl 12.711 SG~ 385.500 PROX 15.773 POTA 07.938 CG~ 3200.000 6FLU -14,813 G~< 70. 363 NPbI ~1 3 · 5~- 5 6GR 375.000 P~UX 15.859 PO'lA 74.312 CGI~ 3100.000 SFLU -88.625 GR 51.469 N~EI 12.445 5GR 497.500 PROX 15.08~ POmA 52.281 CG~ 3000.000 $FLU -94.938 GR 58.406 NPBI 541.000 PRUX 15.844 PO]A 52.250 29C 0. O( 0 ,Si:;' LU -88.312 GR 4 b. 4( t NP~ l 3.785 0.018 45.625 58.525~ 43.018 55.688 8.327 0.016 49.438 6.887 51.125 3¢.424 53.594 7.255 0.014 43.031 3,189 74.813 52.979 67.)38 2. '147 0.01~ 53.344 3.799 ?0,063 52.490 .74.312 3.0O5 0.018 55.156 7.992 51.469 39.551 52.281 7.438 0.013 36.063 7.840 58.406 42.480 52.250 7.210 0.014 43.406 5.789 46.406 .4~.434 THOR D3 NRAT MINV THOR NRAT M1NV THOR D3 RBOB NINV THOR ILM RHOB MINV THOR [ILN RHOB NRAT NJNV 1LM BHOB NINV ILM DT 1.500 5.770 4.2~8 12/:.375 2.158 3.697 1.583 7.555 6.223 114.000 2,229 3.2~4 1.598 6.504 3.~6 15~.125 2.098 4.25.8 1,200 B'.344 3,695 143,000 2.070 4,254 1,333 8.023 7.328 142.375 2.051 3,508 1.951 5.973 8,070 138,500 2.080 3.606 2,310 7.004 6.230 131.000 2.O55 U~ N iLD SP NCNL MNOR URAN 'ILD DRHO NCNL MNCR UB~N 1 SP ~NCR URAN ILD SP NCNI, URAN SP F~NCR ILD SP DRHO NCNL MNOR UR~N ILD SP DRHO 2.44/ 0.980 4,379 -~99,250 0.028 1983,000 2,756 0,860 6.426 -999.250 0.032 :;oeo,ooo 2.942 1,452 3.723 -999.250 0.049 1677,000 1.924 2,076 4.250 -999.250 0.020 1633.0C0 1.917 2.611 7,234 -999.250 0,002 1927,000 3.488 2,297 8'.461 -999.250 -0.010 2090.000 3.756 0.953 6.883 -999.250 0.005 COMflBBfllAL 6VP O)9.HOJ VERIFICATION L],S'IlNG PAGE 15 iCAL/ 13.031 SGR FCNb 458.750 PRiX CALl 16.891 POmA SGR 51.063 CGR D~PT 2800.000 SP -04,375 GB 60.625 NPHI CALl 12.984 FCNL 4VO.O(O PROX CALl 16,547 POmA SGR 56,68~ CGR DEPT 2700.000 8P'LU SP -88.7:5O GU GR 53. 500 NPHi CALl '12.6E8 SGP FCNL 505.500 PROX CALl 16.224 POmA SGR 48. 344 CGR D~.PT. 2600.000 6FLU 6P '7b.438 GR Ga 55 . 031 CALl 13.102 ~'CNL 530.000 PROX CALl 16.672 POmA ~GR 57.563 DEPT 2500.000 5P -'15.938 GR GR 60.938 NPHI CALl FCNb 465.000 CALl IL.b25 POmA SGR ~3.68~ CG~ OkPT 2~00.000 SP '85.938 GR 39. 188 NiCk i CALl 13.133 ~CNL 366.5fi0 PROX CALl 16.750 SGR 37.969 CGR DEPr 2300.000 ~P -17.063 GR GR 63.375 CALl 12.867 SGR FCNL 299.500 CALl 4.277 POIA SGR 41.406 CG~ DEPT 2200.000 SFLU 8P -26.328 GR 51. 0. 39. ~0. 45. 56. 5. O. 50. . 4~. 48. 5. O. 41. 55. 41. 57. 4. 0. 36. 60. 46. 5. O. 48. 39. 51. 37. 3. D i. 31. 1~. 63. 58. 4~.. 1, O. 35. 0~3 010 188 734 625 361 688 514 015 531 08~ 50O 555 344 499 012 625 461 031 064 563 432 625 707 938 53.3 688 331 013 031 352 15~ 807 ~69 009 922 227 375 105 4(6 104 01! 125 180 NR~T 'Ml~V ~HOk IbM DT RHOB NRAT THOR DT NRAT MINV THOR DT NEAT THOR DT NRAT ThOR DT RHOB NRAT MINV THOR ILM DT NRAT MiNV THOR ILM DX' 3, ]~. 3 NCNL 2.312 MNOR 7, ] ~. 3 U~I N O.3§5 ILD 135.500 2,129 3.846 NCNL 1,896 MNCR 9,383 URAN 7,262 ILO 138.000 SP 2.082 DRBO 3,736 NCNL 1,976 MNOR 6,832 URAN 5.2t6 133.000 3. 607 N 1,980 · 6.172 ORAN 6,418 ILD 137.000 8P 2. 188 DRHO 3.9~4 NCNL 2.214 MNOR 8.523 UR~N 5.51'6 ILE 162.500 SP 2.006 ~[g[O 4.207 N~NL 2.148 MNGR 5.176 URAN 9.422 137.750 SP 2.205 DRMO 4.5~7 NCNL ].359 ~NOR 5.402 'UR~N 7,109 ILO 147!.000 SP 1762.000 3.434 1.682 7.004 -999.250 0,007 1854.000 3.320 0.726 8.031 -999.250 0.019 1994.0~0 3.331 0.867 5.852 -999.250 0.007 1860.000 3.052 2.775 7.098 -999.250 0.008 1763.0~0 3.577 1.501 6.~!4 -999.250 -0.010 1563.000 3.649 '0.578 9.398 -999;250 -0.386 ~4~1.000 0.502 0.889 6.815 -999.250 LYP 009.;F03 VEFI~I,£A'I'lbN JuJb'll{l,G PA'(.E 16 CALl FCNL CALl SGR DEPT SP CALk ~:CNL CALl SGR DEPT SP CALl CALl SGR D~FT CALl ~'CNL CALl D~PT SP GR CALl FCNL CALl DEpT SP GR CALl FCNL CALl GR CALk FCNL CALl 44,18B NPHi -999.250 6GH -999.250 PRUX -999.~50 POIA -999.250 CGR 2100.000 SFLU -37.844 GR 3~.000 -999 · 250 -999.250 PROX -999,250 PU'IA -9c. 9. 250 2000.000 SFLU -9.047 00.0~3 NPHI -999.250 -999,250 -999.250 -999.250 CGR 1900.000 :fFLO -8.578 GA 6~.6;5 NPHI -999.250 6Gm -999,250 PRGX -999.250 PO'IA -999.250 1~00.000 $FLU -25.078 GR 4U.312 NP~I -999.250 6GR -999.250 PHOA -999.250 POTA -999.250 CGR 17C O. 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