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Home My WebLink About196-028Nolan 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 K-17 50029226470000 196028 2/7/2025 AK E-LINE Caliper 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: Milne Point Kuparuk River Oil N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,483'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi 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 7,376' 7,253' 1,975 7,197' 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. AOGCC USE ONLY Tubing Grade: 2/15/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0375133 196-028 Authorized Name and Digital Signature with Date: Tubing Size: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22647-00-00 Hilcorp Alaska LLC C.O. 816 Length Size Proposed Pools: 7,354' PRESENT WELL CONDITION SUMMARY MILNE PT UNIT K-17 110' 110' 9.2# / L-80 / EUE 8rd TVD Burst 7,199' MD N/A 5,750psi 7,240psi 110' 20" 9-5/8" 7" 3,471' 7,430' 7,023' HES Versatrieve & BWD Sump Packer and N/A 3,508' 7,335' 3,508' 7,463' Tubing MD (ft):Perforation Depth TVD (ft): 7,060 MD/ 6,958 TVD & 7,184 MD/ 7,074 TVD and N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 2-7/8" 6.5# / L-80 / EUE 8rd No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-047 By Grace Christianson at 1:53 pm, Jan 30, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.01.30 12:27:41 - 09'00' Taylor Wellman (2143) 10-404 SFD 2/7/2025 X JJL 2/7/25 AOGCC Witnessed BOP and Annular Test to 2500 psi. DSR-1/31/25*&: 2/7/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.07 10:01:38 -09'00' RBDMS JSB 021025 ®ôīīϙbÍıôϡ aϙXϱ͖͐IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͕͓͖͑͑ϱ͏͏ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ Iϙ(ϙŘĺîŪèôŘ ĖČϡ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͓͐ϙ>ôæϙ͑͏͔͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͔ϙ"ÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͕͐͘ϱ͏͑͗ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ͕͔͑͏ϙŕŜĖϙЬϙ͕͓͔͗ϱċťϙa"ϙϼ͕͖͔͕ϱċťϙ«"ϽϙFϙŪŘŽôƅ ͑͗ϙVÍĲϙ͑͏͔͑ϙиϙ͖ϟ͕ϙ(a®ϙϼ͗ϟ͔ϙX®>ϙϳϙĺŪŘèôϙ®ťŘϽ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͖͔͐͘ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϙϼôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͑͐ϟ͒еϙЬϙ͖͔͖͐ϱċťϙa" aÍƄϙ"ĺČīôČϙϼôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͑ϟ͑еϯ͐͏͏ϱċťϙЬϙ͔͕͑͑ϱċťϙa" aĖĲϙI"ϙϼôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͑ϟ͑͏͔ϱĖĲϙI"ϙÍťϙ͕͐͘͏ϱċťϙa"ϙϼbĺϱ@ĺϙĖĲϙ͑ϱ͖ϯ͗Ћϙ³bϙ ĲĖŕŕīôϽ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙXϱ͖͐ϙſÍŜϙîŘĖīīôîϙæƅϙbÍæĺŘŜϙ͖͑(ϙĖĲϙaÍŘèēϙ͕͐͘͘ϙÍŜϙÍϙXŪŕÍŘŪħϙϯϱŜÍĲîϙŕŘĺîŪèôŘϙÍĲîϙèĺıŕīôťôîϙæƅϙ bÍæĺŘŜϙ͓(ϙĖĲϙŪČŪŜťϙ͕͐͘͘ϟϙϙēôϙſôīīϙſÍŜϙŕŪťϙĺĲϙŕŘĺîŪèťĖĺĲϙĺĲϙ͐͏ϙŪČϙ͕͐͘͘ϟϙϙ®ĖťēĖĲϙÍϙſôôħϠϙťēôϙſÍťôŘϙèŪťϙ ſôĲťϙċŘĺıϙ͑҇ϙťĺϙ͕͏҇ϙÍĲîϙſĖťēĖĲϙÍϙıĺĲťēϙťēôϙſÍťôŘϙèŪťϙſôĲťϙťĺϙ͘͏҇ϟϙϙēôϙĖĲĖťĖÍīϙ(ϙèĺıŕīôťĖĺĲϙċÍĖīôîϙĖĲϙ ôŕϙ͕͐͘͘ϙϼ͔͑ϙîÍƅϙŘŪĲϙīĖċôϽϙîŪôϙťĺϙŜĺīĖîŜϙŕŘĺîŪèťĖĺĲϟϙϙϙ®iϙĖĲϙ"ôèϙ͕͐͘͘ϙôƄôèŪťôîϙÍϙŜèŘôôĲôîϙČŘÍŽôīϙŕÍèħϙĺċϙ ťēôϙXŪŕÍŘŪħϙϱŜÍĲîŜϟϙϙēôϙīĺſôŘϙXŪŕÍŘŪħϙϱŜÍĲîŜϙſôŘôϙīôċťϙĖŜĺīÍťôîϙſĖťēϙÍϙ³bϙŕīŪČϙÍĲîϙÍϙĲôſϙ(ϙ èĺıŕīôťĖĺĲϙſÍŜϙŘŪĲϟϙϙēÍťϙ(ϙŜēŪťîĺſĲϙĖĲϙVŪĲϙ͖͐͘͘ϙĺĲϙÍĲϙĺŽôŘīĺÍîϙťŘĖŕϙÍĲîϙſÍŜϙîĖÍČĲĺŜôîϙſĖťēϙÍϙ îĺſĲēĺīôϙŕēÍŜôϱťĺϱČŘĺŪĲîϙŜēĺŘťϙϼ͐͐͘ϙîÍƅϙŘŪĲϙīĖċôϽϟϙϙϙ®iϙſÍŜϙŕôŘċĺŘıôîϙĖĲϙièťϙ͖͐͘͘ϙťĺϙèēÍĲČôĺŪťϙťēôϙ (ϙſēĖèēϙŘÍĲϙŪĲťĖīϙ"ôèϙ͑͏͏͔ϙſēôĲϙÍĲϙŪĲŕīÍĲĲôîϙŜēŪťîĺſĲϙèÍŪŜôîϙÍϙîĺſĲēĺīôϙŜēĺŘťϙϼ͕͖͑͘ϙîÍƅϙŘŪĲϙīĖċôϽϟϙϙ ēÍťϙ(ϙſÍŜϙèēÍĲČôîϙĺŪťϙîŪŘĖĲČϙÍĲϙŪČϙ͑͏͏͖ϙ®iϟϙϙēÍťϙ(ϙŘÍĲϙŪĲťĖīϙĖťϙŜŪƯôŘôîϙÍϙæŘĺħôĲϙŜēÍċťϙĖĲϙVŪĲϙ ͑͏͐͘ϙϼ͓͖͖͑ϙîÍƅϙŘŪĲϙīĖċôϽϟϙϙϙbĺŽϙ͑͏͐͘ϙ®iϙŘôŕīÍèôîϙťēôϙ(ϙſēĖèēϙŘÍĲϙŪĲťĖīϙaÍƅϙ͑͏͑͐ϙϼ͔͔͖ϙîÍƅϙŘŪĲϙīĖċôϽϙ ſēôĲϙťēôϙ(ϙŜťĺŕŕôîϙŜŪŘċÍèĖĲČϙƲŪĖîϙîŪôϙťĺϙÍϙŜŪŜŕôèťôîϙæŘĺħôĲϙŜēÍċťϙϼèĺĲƱŘıôîϙîŪŘĖĲČϙ®iϽϟϙϙaϙXϱ͖͐ϙ ēÍŜϙæôôĲϙIϙŜĖĲèôϟ bĺťôŜϙôČÍŘîĖĲČϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -͑͗ϙVÍĲϙ͑͏͔͑ϙϳϙFϙŪŘŽôƅϙϼ͕͔͑͏ϙŕŜĖϙÍťϙ͕͓͔͗ϱċťϙa"ϙϼ͕͖͔͕ϱċťϙ«"ϽϽ -͑͗ϙVŪĲϙ͑͏͑͐ϙϳϙŪīīôîϙ³³bϙŕīŪČϙċŘĺıϙ͑ϱ͖ϯ͗Ћϙ³bϱĲĖŕŕīôϙŕŘĺƱīôϙÍťϙ͕͐͘͏ϱċťϙa"ϙÍĲîϙŕŪīīôîϙťēôϙ"«ϙċŘĺıϙ @[aϙťÍϙ͐ϙÍťϙ͕͗͑͏ϱċťϙa"ϙÍĲîϙīôċťϙĖťϙĺŕôĲ -͖͑ϙVŪĲϙ͑͏͑͐ϙϳϙôťϙ"«ϙĖĲϙ@[aϙťÍϙ͑ϙÍťϙ͔͑͐ϱċťϙa" -͖͐ϙbĺŽϙ͑͏͐͘ϙϳϙÍŜŜĖĲČϙaIϱIϙϼ͔͑͏͏ϙŕŜĖϽϙſϯϙſĺŘħŜťŘĖĲČϙŜťŪĲČϙĖĲťĺϙŪŕŕôŘϙ@ϙŕħŘϙϼ@ĺĺîϙċĺŘϙ͗ϱƅŘϙŘĺîϙ ŜČϙôŜťϙŕôŘϙi@ϙiϙ͒͘͏Ͻ ®ôīīϡ aϙXϱ͖͐ "ϡ ͕͐͘ϱ͏͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͕͓͖͑͑ϱ͏͏ϱ͏͏ "Íťôϡ ͑͘ϙVÍĲϙ͑͏͔͑ -³bϙŕīŪČϙŜôťϙĖĲϙ͒ϱΫЋϙ³bϱĲĖŕŕīôϙŕŘĺƱīôϙÍťϙ͖͖͐͘ϱċťϙa"ϙϼæôīĺſϙ(ϙĖĲϙŜĖĲČīôϱŜôīôèťĖŽôϙ@ϙèĺıŕīôťĖĺĲϽϙ ŜôťϙŕŘĖĺŘϙťĺϙťēôϙīĺſôŘϙèĺıŕīôťĖĺĲϙŘŪĲϙîŪŘĖĲČϙťēôϙ͕͐͘͘ϙ®iϟϙϙŘĺĲČϙēÍŜϙÍϙ͐ϱ͒ϯ͗ЋϙƱŜēĖĲČϙĲôèħϙÍĲîϙĖŜϙ ͒ϟ͔͖ϱċťϙīĺĲČϟϙϙŪīīĖĲČϙťĺĺīϙϼŕŘĺĲČϽϙϳϙ͑ЋϙϟϙϙŪīīĖĲČϙťĺĺīϙϼŕīŪČϽϙϳϙ͒ϱΫЋϙ@ iæĤôèťĖŽôϡ ®ĖťēϙťēĖŜϙŕŕīĖèÍťĖĺĲϙċĺŘϙŪĲîŘƅϙŕŕŘĺŽÍīϙſôϙÍŘôϙŘôŗŪôŜťĖĲČϙťĺϙŕŪťϙϙϭ͐ϙĺĲϙťēĖŜϙſôīīϙĖĲϙĺŘîôŘϙťĺϙŜſÍŕϙťēôϙ (ϙĖĲϙĺŘîôŘϙťĺϙæŘĖĲČϙťēĖŜϙſôīīϙæÍèħϙĺĲϙŕŘĺîŪèťĖĺĲϟ ēĖŜϙŕŘĺèôîŪŘôϙîôťÍĖīŜϙťēôϙæôīĺſϙĺŪťīĖĲôϙĺċϙťēôϙŜèĺŕôϙĺċϙťēĖŜϙŕŘĺĤôèťϡ -Řôϱ®iϙ®ôīīſĺŘħ -ŪīīϙôƄĖŜťĖĲČϙ(ϙèĺıŕīôťĖĺĲ -ĺĲťĖĲČôĲèƅϙīôÍĲĺŪťϙŪĲ -ŪĲϙĲôſϙ(ϙèĺıŕīôťĖĺĲ -i ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ ͐Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ īôôîϙťæČϯIϙťĺϙ͏ϙŕŜĖϟϙϙĺĲƱŘıϙĲĺϙƲĺſϟ bi(ϡϙϙIċϙŘôŗЍîϠϙèÍīīϙĺŪťϙ>ŪīīæĺŘôϙťĺϙæŪīīēôÍîϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙťĺϙħĖīīϙſôīī æϽ ēĺĺťϙťæČϙÍĲîϙIϙ>[ èϽ īôÍŘϙÍĲîϙīôŽôīϙŕÍîϙÍŘôÍϙĖĲϙċŘĺĲťϙĺċϙſôīīϟϙϙŕĺťϙŘĖČϙıÍťŜϠϙ͔͏͏ϙææīϙťÍĲħϠϙÍĲîϙèĺĲťÍĖĲıôĲťϟ îϽ "ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜϟϙϙīôÍŘϙÍĲîϙīôŽôīϙÍŘôÍϙÍŘĺŪĲîϙſôīīϟ ôϽ aIϙèŘÍĲôϟϙϙôťϙ«ϟϙϙb"ϙťŘôôϙÍĲîϙbϙ͐͐Ћϙi(ϟϙϙbϙi(ϙēĺŪŜôϟϙϙŕĺťϙıŪîϙæĺÍťϟ bi(ϡϙϙ«ϙŕŘĺƱīôϙĖŜϙ͑ϱΫЋϙI®ϙFϱŜťƅīô ®iϙŘĺèôîŪŘôϙϼŪĲîŘĖôîϙ®ĺŘħϽϡ aIϙϯϙôŜťϙi(ϡ ͐Ͻ aIϙFĖīèĺŘŕϙϠϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲťϠϙÍĲîϙīĖĲôŜϙťĺϙ͔͏͏ϙææīϙŘôťŪŘĲϙťÍĲħ ͑Ͻ ťťôıŕťϙťĺϙèĖŘèŪīÍťôϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘϙîĺſĲϙťæČϙϼѷ͓͔ϙææīŜϽϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙIϙϼѷ͑͐͏ϙ ææīŜϽϙťēŘĺŪČēϙťēôϙĺŕôĲϙ@[aϙťÍϙ͐ϙÍťϙ͕͗͑͏ϱċťϙa"ϙŕŘĖĺŘϙťĺϙŜôťťĖĲČϙϙĖĲϙĺŘîôŘϙťĺϙèīôÍĲŪŕϙťæČϟϙϙIċϙ ĲĺϙŘôťŪŘĲŜϙÍċťôŘϙ͓͔ϙææīŜϙÍſÍƅϠϙŜſÍŕϙťĺϙæŪīīēôÍîϙîĺſĲϙťēôϙIϟϙϙēôèħϙċĺŘϙŕŘôŜŜŪŘôϙÍĲîϙĖċϙ͏ϙŕŜĖϠϙŜôťϙ ϙŕīŪČϟϙϙIċϙĲôôîôîϠϙæīôôîϙÍĲƅϙŘôŜĖîŪÍīϙŕŘôŜŜŪŘôϙĺƯϙťæČϙÍĲîϙèŜČϟ bi(ϡϙϙ>īŪĖîϙīôŽôīϙŜēĺťϙĺĲϙ͒͐ϙaÍƅϙ͑͏͑͐ϙĖĲîĖèÍťôŜϙæČϙ>[ϙЬϙѷ͒͏͏͏ϱċťϙa" ͒Ͻ ôŜťϙi(ϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϠϙÍĲĲŪīÍŘϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϙϼēĺīîϙôÍèēϙ ŘÍıϯŽÍīŽôϙċĺŘϙ͔ϱıĖĲϽϟϙϙôèĺŘîϙÍèèŪıŪīÍťĺŘϙŕŘôϱèēÍŘČôϙŕŘôŜŜŪŘôŜϙÍĲîϙèēÍŘťϙťôŜťŜϟ ÍϽ bĺťĖċƅϙi@ϙ͓͑ϱēŘŜϙĖĲϙÍîŽÍĲèôϙĺċϙi(ϙťôŜťĖĲČ æϽ ĺĲƱŘıϙťôŜťϙŕŘôŜŜŪŘôϙŕôŘϙťēôϙŪĲîŘƅϙĺĲîĖťĖĺĲŜϙĺċϙŕŕŘĺŽÍī èϽ ôŘċĺŘıϙťôŜťŜϙÍŜϙŕôŘϙϙ͐ϙi(ϙôŜťϙŘĺèôîŪŘô îϽ ôŜťϙ«ŜϙĺĲϙ͑ϱ͖ϯ͗ЋϙϼôƄĖŜťĖĲČϙÍĲîϙĲôſϙèĺıŕīôťĖĺĲϙťæČϽϙťôŜťϙĤťŜ ®ôīīϡ aϙXϱ͖͐ "ϡ ͕͐͘ϱ͏͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͕͓͖͑͑ϱ͏͏ϱ͏͏ "Íťôϡ ͑͘ϙVÍĲϙ͑͏͔͑ ôϽ ŪæıĖťϙèĺıŕīôťôîϙ͐͏ϱ͓͓͑ϙċĺŘıϙťĺϙi@ϙſĖťēĖĲϙϼ͔ϽϙîÍƅŜϙĺċϙi(ϙťôŜť ͓Ͻ ŪīīϙϙīŪČϟϙϙīôôîϙÍĲƅϙŕŘôŜŜŪŘôϙĺƯϙťæČϯIϙťĺϙťēôϙŘôťŪŘĲŜϙťÍĲħϟϙϙIċϙŘôŗЍîϠϙæŪīīēôÍîϙÍîîĖťĖĺĲÍīϙ͗ϟ͔ϙ īæϯČÍīϙŜĺŪŘèôϙſťŘϟϙϙŪīīϙ«ϟϙϙ[ŪæŘĖèÍťôϙĖċϙŕŘôŜŜŪŘôϙĖŜϙôƄŕôèťôîϟ Ūīīϙ(ƄĖŜťĖĲČϙĺıŕīôťĖĺĲϡ ͔Ͻ aIϙ(ϙÍæīôϙŜŕĺĺīôŘϙťĺϙŕŪīīϙϭ͐ϙϙ((ϙèÍæīôϙ ͕Ͻ aϙīÍĲîĖĲČϙĤťϙĺŘϙŜŕôÍŘϙťæČϙēČŘϟϙϙi["ϟϙϙĲīÍĲîϙťæČϙēČŘϟ bi(ϡϙϙϙĲĺťôîϙ®ϙĺċϙ³³XϙīæŜϙϼĲĺĲôϙĲĺťôîϙĺĲϙŘôŕĺŘťŜϙĺŘϙťÍīīƅϽϙÍĲîϙi®ϙĺċϙ͓͓XϙīæŜϙĖĲϙ͗ϟ͘ϭϙ æŘĖĲôϙîŪŘĖĲČϙ͑͏͐͘ϙ®iϟϙϙbÍæĺŘŜϙ͒ϙĲĺťôîϙ®ϙĺċϙ͔͗XϙīæŜϙÍĲîϙi®ϙĺċϙ͔͕XϙīæŜϙĖĲϙ͗ϟ͘ϭϙæŘĖĲôϙ îŪŘĖĲČϙ͑͏͏͖ϙ®iϙſϯϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙèĺıŕϙťæČϙĖĲϙ͗ϟ͔ϭϙæŘĖĲôϯŜôÍſÍťôŘϟ ͖Ͻ ĺĲƱŘıϙťæČϙēČŘϙċŘôôϟϙϙôèĺŽôŘϙťæČϙēČŘϟ bi(ϡϙϙFČŘϙĖŜϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ((ϙ͗Řîϙſϯϙ͒Ћϙ[FϙèıôϙŪŕϙÍĲîϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ((ϙ͗ŘîϙîĺſĲ ͗Ͻ iiFϙīÍƅĖĲČϙîĺſĲϙťēôϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ((ϙ͗ŘîϙťæČϠϙ(ϙèĺıŕĺĲôĲťŜϠϙÍĲîϙŜŕĺĺīĖĲČϙ(ϙƲÍťϙèÍæīô (ŗŕťϙ"ĖŜŕĺŜĖťĖĺĲϡ æČϙFČŘ IĲŜŕôèťϙÍĲîϙôϱŘŪĲ ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ((ϙ͗Řîϙſϯϙ͒Ћϙ[FϙèıôϙŪŕϙÍĲîϙ͑ϱ ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ((ϙ͗ŘîϙîĺſĲ IĲŜŕôèťϙÍĲîϙŘôϱŪŜô ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ((ϙ͗ŘîϙťæČ IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŘŪĲϙĺŘϙĤŪĲħ bôſϙťæČϙſÍŜϙŘŪĲϙîŪŘĖĲČϙťēôϙ͑͏͐͘ϙ®i ϼ͑Ͻϙ͑ϱ͖ϯ͗Ћϙ@[aϙ"Xϱ͑ϙ[ÍťèēϙXaa VŪĲħ ͑ϱ͖ϯ͗Ћϙ³bϱĲĖŕŕīôϙϼ͑ϟ͑͏͔ϙĲĺϱČĺϽ VŪĲħ ϼ͐͐͗ϽϙŘĺŜŜϙĺīīÍŘϙÍĲĲĺĲϙīÍıŕŜϙϳϙŘŪĲϙĺĲϙ ťēôϙ͐Ŝťϙϼ͐͏ϽϙĤťŜϙťēôĲϙôŽôŘƅϙĺťēôŘϙĤťϙťĺϙŜŪŘċÍèô IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ ϼ͓ϽϙŪıŕϙŘĺťôèťĺīĖƏôŘϙīÍıŕŜ IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ ϼ͐ϽϙaĺťĺŘϙŘĺťôèťĺīĖƏôŘϙīÍıŕŜ IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ ĺīťϙiĲϙ"ĖŜèēÍŘČôϙFôÍî IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ ¾ôĲĖťēϙĺŘťôîϙ"ĖŜèēÍŘČôϙFôÍî IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ Ūıŕ VŪĲħ @ÍŜϙôŕÍŘÍťĺŘ VŪĲħ ŕŕôŘϯ[ĺſôŘϙÍĲîôıϙôÍīŜ VŪĲħ (ϙaĺťĺŘ VŪĲħ ¾ôĲĖťēϙaĺťĺŘϙ@ÍŪČô IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ ôĲťŘÍīĖƏôŘ IĲŜŕôèťϙċĺŘϙŕĺŜŜĖæīôϙŘôϱŪŜôϙĺŘϙĤŪĲħ īĖèħīĖĲôϙ"ŘĖċťϯÍČϡ ͘Ͻ aIϙŜīĖèħīĖĲôϙŪĲĖť ®ôīīϡ aϙXϱ͖͐ "ϡ ͕͐͘ϱ͏͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͕͓͖͑͑ϱ͏͏ϱ͏͏ "Íťôϡ ͑͘ϙVÍĲϙ͑͏͔͑ ͐͏Ͻ "ŘĖċťϙÍĲîϙÍČϙťĺϙ³bϙīŪČϙĖĲŜťÍīīôîϙĖĲťĺϙ³bϱĲĖŕŕīôϙŕŘĺƱīôϙϼ͖͖͐͘ϱċťϙa"Ͻϙſϯϙѷ͑ϟ͘͏͏ϱĖĲϙi"ϟϙϙĺŕϙĺċϙ ŕŘĺĲČϙѷ͖͐͒͘ϱċťϙa"ϟ ͐͐Ͻ "aiϙŜīĖèħīĖĲôϙŪĲĖť bi(ϡϙϙ"ôŕôĲîĖĲČϙĺĲϙîŘĖċťϯťÍČϙŘôŜŪīťŜϙſôϙıÍƅϙſÍĲťϙťĺϙŕôŘċĺŘıϙÍϙƱīīϙèīôÍĲĺŪťϙŘŪĲϟϙϙĺĲťÍèťϙi(ϙċĺŘϙ ŕĺťôĲťĖÍīϙèīôÍĲĺŪťϙFϙĖĲťĺϙťēôϙ@ϙŜèŘôôĲϙÍŜŜôıæīƅϙĖċϙťēôϙÍŘôϙèĺıŕīôťôīƅϙèĺŽôŘôîϟϙϙϙŕôŘċĺŘıôîϙ ÍϙŜèŘÍŕôŘϙèīôÍĲĺŪťϙŘŪĲϙťĺϙťēôϙťĺŕϙĺċϙťēôϙŜèŘôôĲϙÍŜŜôıæīƅϙîŪŘĖĲČϙťēôϙ͑͏͐͘ϙ®iϟ ĺĲťĖĲČôĲèƅϙīôÍĲĺŪťϙŪĲϡ bi(ϡϙϙIċϙſôϙıĺŽôϙÍēôÍîϙſĖťēϙÍϙèīôÍĲĺŪťϙĺŪťϙťŘĖŕϙſôЍīīϙĲôôîϙťĺϙťôŜťϙťēôϙ«ŜϙÍČÍĖĲŜťϙťēôϙ͒ϱΫЋϙťôŜťϙĤťϙ ťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČē ͐͑Ͻ aϙÍĲîϙIFϙſϯϙīôÍĲĺŪťϙFϡ ÍϽ ôŽôŘŜôϙèĖŘèŪīÍťĖĲČϙĤŪĲħϙıĖīī æϽ ŕÍèôŘϙĖŕô bi(ϡϙϙIċϙîôèĖŜĖĺĲϙĖŜϙıÍîôϙťĺϙèīôÍĲĺŪťϙĖĲϙťēôϙ@ϙÍŜŜôıæīƅϠϙťēôϙıĺīîôîϙŜôÍīŜϙĖĲϙťēôϙīĺèÍťĺŘϙŜŪæϙ ēÍŽôϙÍϙ͑ϟ͖͘͏ϱĖĲϙI" èϽ ͖ЋϙŜČϙèŘÍŕôŘϙĺŘϙıĺĺťēϙi"ϙťŘĖĲČϙaĖīī îϽ ϼƄ͑Ͻϙ͖ϱĖĲϙĺĺťϙÍŜħôťŜ ôϽ ͒ϱΫЋϠϙ͐͏ϟ͖͒ϭϙb͒͐ϙſĺŘħŜťŘĖĲČϙťĺϙŜŪŘċÍèôϙÍŜϙŘôŗЍî ͐͒Ͻ IFϙťĺϙèīôÍĲĺŪťϙſôīīϙťĺϙťÍŘČôťϙîôŕťē ͓͐Ͻ ŕĺĲϙŜŪèèôŜŜċŪīϙèīôÍĲĺŪťϠϙiiFϙīÍƅĖĲČϙîĺſĲϙſĺŘħŜťŘĖĲČϙÍĲîϙèīôÍĲĺŪťϙF ͑ϱ͖ϯ͗Ћϙ(ϙĺıŕīôťĖĺĲϡ ͔͐Ͻ īôÍĲϙÍĲîϙèīôÍŘϙŘĖČϙƲĺĺŘϙċĺŘϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ[͗͏ϙ((ϙ͗Řîϙ(ϙèĺıŕīôťĖĺĲϙŘŪĲ ͕͐Ͻ ϙÍĲîϙaϙĲôſϙ(ϙÍŜŜƅϟϙϙIFϙťôŜťĖĲČϙôīôèťŘĖèÍīϙĖĲťôČŘĖťƅϙôŽôŘƅϙ͐͏͏͏ϱċťϟϙϙIĲŜťÍīīϙèīÍıŕŜϙĺĲϙťēôϙ ƱŘŜťϙ͐͏ϙĤťŜϙťēôĲϙôŽôŘƅϙĺťēôŘϙĤťϙťĺϙŜŪŘċÍèôϟ ÍϽ aĺťĺŘϙôĲťŘÍīĖƏôŘϙϳϙÍŘČôťϙŜôťϙîôŕťēϙÍťϙ͖͏͑͒ϱċťϙa" æϽ ¾ôĲĖťēϙ(͖ϙ@ÍŪČô èϽ ͔͕͑³ϙ(ϙaťŘ îϽ [ĺſôŘϙôÍī ôϽ ŕŕôŘϙôÍī ċϽ IĲťÍħô 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 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ŪŘĲϙſôīīϙĺŽôŘϙťĺϙiŕŜϙŽĖÍϙēÍĲîĺŽôŘϙċĺŘı ͑Ͻ ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜ ͒Ͻ iϙŕôŘϙÍħôŘϙôĲťŘĖīĖċťϙťÍŘťŪŕϙŘĺèôîŪŘô ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè ͒Ͻ i(ϙèēôıÍťĖè _____________________________________________________________________________________ Revised By: NLW 3/13/21 SCHEMATIC Milne Point Unit Well: MPU K-17 Last Completed: 11/19/2019 PTD: 196-028 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8"Surface 40 / L-80 / Btrc.8.835 Surface 3,508’ 7"Production 26 / L-80 / Btc Mod 6.276 Surface 7,463’ TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / 8rd EUE 2.441 Surface 7,023’ 3-1/2”Tubing 9.2 / L-80 / N/A 2.992 7,060’7,199’ JEWELRY DETAIL No Depth Item 1 215’STA 2: 2-7/8" x 1" Side-pocket GLM w/ Dummy Valve 2 6,820’STA 1: 2-7/8" x 1" Side-pocket GLM (Open Pocket) 3 6,910’2-7/8” XN-Nipple (2.205 No-go ID) 4 6,962.6’Discharge Head: 5 6,963’Zenith Ported Discharged Head 6 6,964’Pump: 161 P11 / 538 PMSXD 7 6,986’Intake/ Gas Sep.: 538GRS FER N AR 8 6,989’Upper Tandem Seal: GSB3DB HL H6 SB/AB PFSA 9 6,996’Lower Tandem Seal: GSB3DB HL H6 SB/AB PFSA 10 7,002’Motor: 562MSP1 - 150hp / 2,205V / 41A 11 7,019’Sensor: Zenith E7 175C w/ Centralizer –Bottom @ 7,024’ 12 7,060’7” Versatrieve Packer 13 7,121’0.012” Gas Screen 14 7,184’7” BWD Sump Packer 15 7,197’3-1/2” XN-Nipple w/2.635” No-go ID (PXN plug installed) 15 7,198’WLEG –Bottom @ 7,199’ PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Kuparuk Sands 7,125’7,179’7,019’7,069’24’12/14/1996 Open 7,205’7,215’7,094’7,103’10’12/14/1996 Isolated Perforation Charge Detail: Original perf run was with RDX Alpha Jet 135 / 45 Deg Phasing 5 spf shot on 8/5/2019. Second Perf round was with RDX Alpha Jet 135 / 45 Deg Phasing 12 spf shot on 12/14/1996 B-sand perforations isolated with a PXN plug. OPEN HOLE / CEMENT DETAIL 20"Cmt w/ 250 sks of Arcticset I in 30” Hole 9-5/8"Cmt w/ 779 sks PF “E”, 686 sx Class “G”, 250 sx PF “C” in 12-1/4” Hole 7”Cmt w/ 305 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 3,700’ Max Hole Angle = 20 deg. @ 5,800’ Max Hole Angle through perforations = 21 deg. TREE & WELLHEAD Tree Cameron 2-9/16” – 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., top lift threads= 3”,LH Acme, btm= 2-7/8” 8rd EUE & 2.5” CIW H BPV profile GENERAL WELL INFO API: 50-029-22647-00-00 Drilled, Cased & Initial Perfsby Nabors 27E - 3/16/1996 Completed with ESP by Nabors 4ES – 8/5/1996 RWO ESP Changeout by Nabors 4ES – 12/15/1996 RWO ESP Changeout by Nabors 5S – 10/28/1997 RWO ESP Changeout by Nabors 3S – 8/10/2007 RWO ESP Changeout by ASR – TBD WELL STIMULATION 12/9/1996 – C Sand Frac’d pack –5,040lbs of 20/40 Mesh Carbolite behind screen _____________________________________________________________________________________ Revised By: TDF 1/20/2025 PROPOSED Milne Point Unit Well: MPU K-17 Last Completed: 11/19/2019 PTD: 196-028 TD =8,400’ (MD) / TD = 7,287’(TVD) 20” KB Elev.: 28’/ GL Elev.: 33’ (Nabors 27E) 7” 7 3 5 6 8&9 10 12 13 14 15 9-5/8” 1 2 16 KUP C Sands PBTD = 8,306’(MD) / PBTD = 7,210’(TVD) 4 KUP B Sands 11 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 3,508’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 7,463’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / 8rd EUE 2.441 Surface 7,023’ 3-1/2” Tubing 9.2 / L-80 / N/A 2.992 7,060’ 7,199’ JEWELRY DETAIL No Depth Item 1 ±XXX’ ’ STA 2: 2-7/8" x 1" Side-pocket GLM 2 ±X,XXX’ STA 1: 2-7/8" x 1" Side-pocket GLM 3 ±X,XXX’ 2-7/8” XN-Nipple (2.205 No-go ID) 4 ±X,XXX’ Discharge Head: 5 ±X,XXX’ Zenith Ported Discharged Head: 6 ±X,XXX’ Pump: 7 ±X,XXX’ Intake/ Gas Sep.: 8 ±X,XXX’ Upper Tandem Seal: 9 ±X,XXX’ Lower Tandem Seal: 10 ±X,XXX’ Motor: 11 ±X,XXX’ Sensor: Zenith E7 175C w/ Centralizer – Bottom @ ±X,XXX’ 12 7,060’ 7” Versatrieve Packer 13 7,121’ 0.012” Gas Screen 14 7,184’ 7” BWD Sump Packer 15 7,197’ 3-1/2” XN-Nipple w/2.635” No-go ID (PXN plug installed) 15 7,198’ WLEG –Bottom @ 7,199’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk Sands 7,125’ 7,179’ 7,019’ 7,069’ 24’ 12/14/1996 Open 7,205’ 7,215’ 7,094’ 7,103’ 10’ 12/14/1996 Isolated Perforation Charge Detail: Original perf run was with RDX Alpha Jet 135 / 45 Deg Phasing 5 spf shot on 8/5/2019. Second Perf round was with RDX Alpha Jet 135 / 45 Deg Phasing 12 spf shot on 12/14/1996 B-sand perforations isolated with a PXN plug. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 30” Hole 9-5/8" Cmt w/ 779 sks PF “E”, 686 sx Class “G”, 250 sx PF “C” in 12-1/4” Hole 7” Cmt w/ 305 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 3,700’ Max Hole Angle = 20 deg. @ 5,800’ Max Hole Angle through perforations = 21 deg. TREE & WELLHEAD Tree Cameron 2-9/16” – 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., top lift threads= 3”,LH Acme, btm= 2-7/8” 8rd EUE & 2.5” CIW H BPV profile GENERAL WELL INFO API: 50-029-22647-00-00 Drilled, Cased & Initial Perfsby Nabors 27E - 3/16/1996 Completed with ESP by Nabors 4ES – 8/5/1996 RWO ESP Changeout by Nabors 4ES – 12/15/1996 RWO ESP Changeout by Nabors 5S – 10/28/1997 RWO ESP Changeout by Nabors 3S – 8/10/2007 RWO ESP Changeout by ASR – TBD WELL STIMULATION 12/9/1996 – C Sand Frac’d pack – 5,040lbs of 20/40 Mesh Carbolite behind screen Updated 10/24/2024 Milne Point ASR Rig 1 BOPE 2024 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5”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y Anne Prysunka at 2:47 pm, Nov 15, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ 0*5129 %23(WHVWWRSVL$SSURYHGIRUUHYHUVHFLUFXODWLQJMHWSXPS '65 ; '/% '/% ,$669KLJKSUHVVXUHWULSQRWWRH[FHHGSVL ,$669ORZSUHVVXUHWULSQRWWREHORZHUWKDQSVL 3URGXFWLRQWXELQJ669ORZSUHVVXUHWULSQRWWREHORZHUWKDQSVL 669FORVXUHRQ,$ZLOOLQLWLDWHZLWKLQPLQXWHVRI669RQSURGXFWLRQWXELQJDQGYLVDYHUVD 4XDGUHQQLDO0,7,$WRSVL *&: Jessie L. Chmielowski Digitally signed by Jessie L. 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ϭϬϳ͕ϬϬϮ͛DŽƚŽƌ͗ϱϲϮD^WϭͲϭϱϬŚƉͬϮ͕ϮϬϱsͬϰϭ ϭϭϳ͕Ϭϭϵ͛^ĞŶƐŽƌ͗ĞŶŝƚŚϳϭϳϱǁͬĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛϳ͕ϬϮϰ͛ ϭϮϳ͕ϬϲϬ͛ϳ͟sĞƌƐĂƚƌŝĞǀĞWĂĐŬĞƌ ϭϯϳ͕ϭϮϭ͛Ϭ͘ϬϭϮ͟'ĂƐ^ĐƌĞĞŶ ϭϰϳ͕ϭϴϰ͛ϳ͟t^ƵŵƉWĂĐŬĞƌ ϭϱϳ͕ϭϵϳ͛ϯͲϭͬϮ͟yEͲEŝƉƉůĞǁͬϮ͘ϲϯϱ͟EŽͲŐŽ/;WyEƉůƵŐŝŶƐƚĂůůĞĚͿ ϭϱϳ͕ϭϵϴ͛t>'ʹŽƚƚŽŵΛϳ͕ϭϵϵ͛ WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ <ƵƉĂƌƵŬ ^ĂŶĚƐ ϳ͕ϭϮϱ͛ϳ͕ϭϳϵ͛ϳ͕Ϭϭϵ͛ϳ͕Ϭϲϵ͛Ϯϰ͛ϭϮͬϭϰͬϭϵϵϲKƉĞŶ ϳ͕ϮϬϱ͛ϳ͕Ϯϭϱ͛ϳ͕Ϭϵϰ͛ϳ͕ϭϬϯ͛ϭϬ͛ϭϮͬϭϰͬϭϵϵϲ/ƐŽůĂƚĞĚ WĞƌĨŽƌĂƚŝŽŶŚĂƌŐĞĞƚĂŝů͗KƌŝŐŝŶĂůƉĞƌĨƌƵŶǁĂƐǁŝƚŚZyůƉŚĂ:ĞƚϭϯϱͬϰϱĞŐWŚĂƐŝŶŐϱƐƉĨƐŚŽƚŽŶϴͬϱͬϮϬϭϵ͘ ^ĞĐŽŶĚWĞƌĨƌŽƵŶĚǁĂƐǁŝƚŚZyůƉŚĂ:ĞƚϭϯϱͬϰϱĞŐWŚĂƐŝŶŐϭϮƐƉĨƐŚŽƚŽŶϭϮͬϭϰͬϭϵϵϲ ͲƐĂŶĚƉĞƌĨŽƌĂƚŝŽŶƐŝƐŽůĂƚĞĚǁŝƚŚĂWyEƉůƵŐ͘ KWE,K>ͬDEdd/> ϮϬΗŵƚǁͬϮϱϬƐŬƐŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴΗŵƚǁͬϳϳϵƐŬƐW&͕͟͞ϲϴϲƐǆůĂƐƐ͞'͕͟ϮϱϬƐǆW&͟͞ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ŵƚǁͬϯϬϱƐŬƐůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϯ͕ϳϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϮϬĚĞŐ͘Λϱ͕ϴϬϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϮϭĚĞŐ͘ dZΘt>>, dƌĞĞĂŵĞƌŽŶϮͲϵͬϭϲ͟ʹϱD tĞůůŚĞĂĚϭϭ͟ǆϳͲϭͬϭϲ͟ϱD&D'ĞŶϱ͕ǁͬϮͲϳͬϴ͟&DdďŐ͘,ŶŐƌ͕͘ƚŽƉůŝĨƚ ƚŚƌĞĂĚƐсϯ͕͟>,ĐŵĞ͕ďƚŵсϮͲϳͬϴ͟ϴƌĚhΘϮ͘ϱ͟/t,WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϰϳͲϬϬͲϬϬ 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ŽĨϮϬͬϰϬDĞƐŚĂƌďŽůŝƚĞďĞŚŝŶĚƐĐƌĞĞŶ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS y�:rr�tl iv�x w.9 DEC - 4 2019 nnr;Ill" rr 1. Operations Abandon Ll Plug Perforations LJ Fracture StimulateLJ n �v wrvv Pull Tubing L41 Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casin 9 ❑ Change Approved Program ❑ Plugfor Redrill ❑ erforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: ESP Change -out ❑� 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory 1:11 196-028 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-029-22647-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0375133 MILNE PT UNIT K-17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 7,483 feet Plugs measured 7,197 feet true vertical 7,654 feet Junk measured N/A feet Effective Depth measured 7,376 feet Packer measured 7,060 & 7,184 feet true vertical 7,253 feet true vertical 6,958 & 7,074 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 3,471' 9-5/8" 3,508' 3,508' 5,750psi 3,090psi Production 7,430' 7" 7,463' 7,335' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5# / L-80 / EUE 8rd 7,023' 6,924' Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 / EUE 8rd 7,199' 7,088' HES Versatrieve Packers and SSSV (type, measured and true vertical depth) & BWD Sump N/A See Above N/A 12. Stimulation or cement squeeze summary: NIA Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: NIA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 490 0 Subsequent to operation: 131 10 1 395 80 201 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-497 Authorized Name: Chad Helgeson Contact Name: Ian Toomey Authorized Title: Operations Manager Contact Email: Itoorney(oDhilcoro.corn Authorized Signature: Date 11/26/2019 Contact Phone: 777-8434 Form 10-404 Revised 4/2017 RBDMS46- DEC 0 5 2019 Submit Original Only KSCHEMATIC corn Alaska. LLC TD =8,400' (MD) / TD=7,287'(TVD) PBTD=8,306' (NO) / PBTD= 7,210rM) TREE & WELLHEAD Milne Point Unit Well: MPU K-17 Last Completed: 11/19/2019 PTD: 196-028 Tree Cameron 2 -9/16" -SM Wellhead 11 x 7-1/16" SM FMC Gen 5A, w/ 2-7/8" FMC Tbg. Hngr., top lift threads= 3",LH Acme, btm= 2-7/8" 8rd EUE & 2.5" CIW H BPV profile OPEN HOLE/ CEMENT DETAIL CASING DETAIL Size 1 Cmt w/ 250 sks of Arcticset I in 30" Hole li20" 9-5/8" 1 Cmt w/ 779 sks PF "E", 686 sx Class "G", 250 sx PF "C" in 12-1/4" Hole 7" 1 Curt w/ 305 sks Class "G" in 8-1/2" Hole CASING DETAIL Size Type I Wt/Grade/Conn ID Top I Btm 20" Conductor 1 91.1/H-40/N/A I N/A I Surface 1 11(' 9-5/8" Surface 1 40 / L-80 / Btrc. 1 8.835 1Surface 3,508' 7" Production 1 26 / L-80 / Btc Mod 6.276 Surface 7,463' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 7,023' 3-1/2" Tubing 9.2/L-80/N/A 2.992 7,060' 1 7,199' WELL INCLINATION DETAIL KOP @ 3,700' Max Hole Angle =20 deg. @5,800' Max Hole Angle through perforations = 21 deg. JEWELRY DETAIL No Depth Item 1 215' STA 2: 2-7/8" x 1" Side -packet GLM w/.25 OV 2 6,820' STA1: 2-7/8" z 1" Side -pocket GLM w/Dummy Valve 3 6,910' 2-7/8" XN-Nipple (2.205 No-go ID) 4 6,962.6' Discharge Head: 5 6,963' Zenith Ported Discharged Head 6 6,964' Pump: 161 P11/538 PMSXD 7 6,986' Intake/Gas Sep.: 538GRS PER N AR 8 6,989' Upper Tandem Seal: GSB3DB HL H6 SB/AB PFSA 9 6,996' Lower Tandem Seal: GSB3DB HL H6 SB/AB PFSA 30 7,002' Motor- 562MSP1- 150hp/ 2,205V/ 41A 11 7,019' Sensor: Zenith E7175C w/Centralizer -Bottom@7,024' 12 7,060' 7" Versatrieve Packer 13 7,121' 0.012" Gas Screen 14 7,184' 7"BWD Sump Packer 15 7,197' 3-1/2"XN-Nipple w/2.635" No-go ID(PXN pluginstalled) 15 7,198' WLEG-Bottom@7,199' PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 7,125' 7,179'7,019' 1 7,069' 1 24' 1 12/14/1996 1 Open Sands 7,205' 7,215' 1 7,094' 1 7,103' 1 10' 1 12/14/1996 Isolated Perforation Charge Detail: Original perf run was with RDX Alpha Jet 135 /45 Deg Phasing 5 spf shot on 8/5/2019. Second Perf round was with RDX Alpha 1 et 135 /45 Deg Phasing 12 spf shot on 12/14/1996 B -sand perforations isolated with a PXN plug. WELL STIMULATION 12/9/1996 -C Sand Frae'pac' pack-1,040lbs of 20/40 Mesh Ca rbolite behind screen GENERAL WELL INFO API: 50-029-22647-00-00 Drilled, Cased & Initial Perfsby Nabors 27E - 3/16/1996 Completed with ESP by Nabors 4ES-8/5/1996 RWO ESP Changeout by Nabors 4ES-12/15/1996 RWO ESP Changeout by Nabors 5S-10/28/1997 RWO ESP Changeout by Nabors 3S-8/10/2007 RWO ESP Changeout by ASR -TBD Revised By: TDF 11/27/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-17 ASR#1 50-029-22647-00-00 196-028 11/14/2019 11/19/2019 11/13/2019- Wednesday No operations to report. 11/14/2019 - Thursday R/U in prep for BOP testing. Top off accumulator with new ISO 15 hydraulic fluid. Grease choke manifold in mud pits as well as flow cross on BOP stack. Take on 200bbls of 8.9ppg NaCl brine into pits #1-3. Fill BOP stack w/ 8.33ppg fresh water from rig pit #4. P/U test mandrel and set in BOP stack. Attempt to function accumulator from rig floor remote station. Unable to get station to function. Trouble shoot w/ electrician, Co Rep, TP. AOGCC Rep Adam Earl on location to witness testing. Find closed hydraulic needle valve inside accumulator junction box. Test BOPE as per ASR # 1 BOP test procedure and Sundry to 250/2,500psi with 2-7/8" and 3-1/2" test joints. The test was witnessed by AOGCC inspector Adam Earl. Had 1 fail/pass on choke manifold valve #4. Monitor for leaks on flow lines and BOPE. Continue Rig Up. Rig Down Test Equipment. Blow flow lines and BOPE dry. Hang Sheave and Containment Trunk for ESP Cable. Add extension on Pipe Handler. Pick up Landing Joint and make up XO's. Pull Test Plug and BPV. Make up Landing Joint. Screw out LDS and Un land TBG Hanger Max Up Weight 53K. Pull Hanger to surface. Cut Cable and lay down Landing with TBG Hanger. Suck out Test Fluid from Pits and spot Pipe Racks. Well under balanced. Rig Up to pump 40BBLS of 8.9# NaCl down TBG. 11/15/2019 - Friday Crew Change/Safety Meeting. SIMOPS: Continue to circulate lighter fluid ends out of wellbore. thaw rig pump and add RV antifreeze to rod washer fluid to prevent freeze up. Begin pulling TBG. first joint laid down came in contact w/ V -door due to well floor angle. Utilize loader to slide well but and rig floor into desired position. Blow down circulation lines. Difficult to access blow down location with winterization tarps in place. Continue pulling 2-7/8" w/ESP. Pumping Hole Fill and blowing Pump Lines dry. Transfer TBG to Pipe Tub. Crew Change/Safety Meeting. Fluid Checks. Trouble shoot loss of Hydraulic Power to equipment. Walk out Electrical Connections, Check Breakers and relays. While trouble shooting Crew Loaded 3-1/2" WS into Warm Up Trailer and Fill Certek Unit with Glycol. Found cap that fell of a Hydraulic Solenoid screwed it back on and Hydraulics Power can back on. Continue Laying down TBG W/ESP. Pumping Hole Fill and blowing Pump Lines dry. Transfer TBG to Pipe Tub. @ Joint #215. Inspected 2-7/8" Tbg- all looked good. 11/16/2019 -Saturday Held PJSM, serviced and checked fluids. Continued POOH with 2-7/8" Completion displacing every 15 its.. L/D 215 As of 2- 7/8" 6.5# L-80 EUE 8rd Tbg, 2 GLM, XN-nipple and 4 Pup Jts. Sent Completion string to G&I for cleaning. Decompleted and LD ESP assembly. Some light scaling around the pump and the shaft is broken. Send assembly to Baker's shop and final inspection report will be sent out. Cleaned and cleared rig floor. L/D 2-7/8" handling tools and ESP spooling equip. PU 3-1/2" handling tools for cleanout/Seal Ext trip. Racked and tallied 90jts of 3-1/2"' 10.37# nc-31 workstring. Tallied and MU the BHA consisting of 3.880" Seal Assembly 1 joint of 3-1/2" worksting and 7" Cgs Scraper. TIH with Seal Assembly and Csg Scraper BHA on 3-1/2" 10.37# nc-31 workstring. Crew Change/Safety Meeting. Check Fluids on equipment. Continue TIH with Seal Assembly and CSG Scraper BHA on 3-1/2" 10.37# NC -31 work string. Rack & Tally TBG. Load TBG into Warm Up Trailer. Secure Well and Muster. Camp Drill Code 99. RED. Continue TIH with Seal Assembly and CSG Scraper BHA on 3-1/2" 10.37# NC -31 work string. Rack & Tally TBG. Load TBG into Warm Up Trailer. Tagged top of Packer 35' in on it #175 (7,083' MD). LD 1 Joint. Establish parameters 66K UP/59K DN. Line up to Reverse Circulate Bottoms Up at 4bpm. After Bottoms up Returns Clean. SD Pump. PU JT#175. Sting Seal Assembly into GP Packer and set 5K DN. Filled IA w/2.7 bbls & Pressured up to 2,500PSI & Charting Test @ report time. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-17 ASR#1 50-029-22647-00-00 196-028 11/14/2019 1 11/19/2019 11/13/2019- Wednesday 11/17/2019-Sunday PJSM, Continued Testing IA @ 2,500psi. Charted for 30mins-good test. AOGCC waived witness. Bled off pressure and blew down circulating lines. Serviced equipment and checked fluids. Unseated seal assembly and TOH with L/D 3-1/211' Workstring. Pumping displacement every 15jts with 8.9# NaCl. Off-loaded new 2-7/8" Production Tbg. Preformed well control drill during trip. Well secured in 93 seconds. SD and secured well due to losing air pressure for rig. Found a steel braided hose coming off the air compressor that was blown out. Called VMS for repairs. Replaced Hose and resumed ops. Continued TOH with L/D 3-1/2"' Workstring. Pumping displacement every 15jts with 8.9# NaCl. Crew Change Safety Meeting. Check Fluids in equipment. Continued TOH with L/D 3-1/2"' Work string. Pumping displacement every 15jts with 8.9# NaCl. LD Seal Assembly/CSG Scraper BHA. Seals on the bottom of assembly looks good. PU handling equipment and tools to run ESP Completion, Tallied and racked 2-7/8" Tbg and Jewelry. MU and serviced ESP Assembly. Surface Tested connection and cable-good check. TIH with ESP completion on 2-7/8" 6.5# L-80 EUE 8rd tbg. PU 2-7/8" x 2.313" XN Nipple (2.205" no-go) and Lower GLM (2-7/8" x 1" KBMM-R with dummy valve w/BK latch installed) Cable test every 1,000'. 11/18/2019 - Monday PJSM, Serviced rig and checked fluids. TIH with ESP completion on 2-7/8" 6.5# L-80 EUE 8rd tbg. f/1000'md t/6,100'md clamping cable every otherit and Cable test every 1000'. PJSM, Serviced rig and checked fluids. TIH with ESP completion on 2-7/8" 6.5# L-80 EUE 8rd tbg. Test Cable. M/U Landing Joint w/TBG Hngr. Rig up Splice Eq. Cut ESP Cable. Start Splice. Crew assist Well Head Hand w/ swapping out LDS on Well Head. Assist Center Lift w/Splice.. Blow down Flow Lines. Test Penetrator @ TBG Hngr. Land TBG Hngr. 44k Down Weight. RILDS. L/D Landing Joint. Set BPV, EOT @ 7,023'RKB. Start Rig Down. Crew move Pipe Racks. De-Winterize Eq. Disconnect Flow Lines. Loosen BOPE's. Rig Down TBG Handling Eq. Work w/Roads & Pads to Load & Road Eq. 11/19/2019-Tuesday PJSM, Continue RDMO. RU Crane Fly off work floor, and well house. Loaded trailer with assistance from Roads and Pads. ND annular and BOPE. NU Production Tree. Tested void to 5,000psi-good test. Move to M-Pad. Turned well overto production. Akl it h c 7 Regg, James B (CED) Fn nt' (_'ZP'0 From: Wade Hudgens - (C) <whudgens@hilcorp.com> Sent: Tuesday, November 19, 2019 4:07 PM To: Regg, James B (CED) / Cc: Brooks, Phoebe L (CED) ' ! I "l t/ /q Subject: RE: [EXTERNAL] RE: MIT -IA MPU K-17 Attachments: MIT -IA MPU K-17 11-17-19.xlsx Sorry about that the K-17 was tested. I revised the PTD number on the form attached. Thanks Wade Hudgens WSM Hilcorp Alaska whudgens@hilcoD.com Office 907-283-2505 Cell 903-331-6711 From: Regg, James B (CED) [mailto:jim.regg@alaska.gov] Sent: Tuesday, November 19, 2019 3:27 PM To: Wade Hudgens - (C) <whudgens@hilcorp.com> Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] RE: MIT -IA MPU K-17 Listed PTD is for MPU M-22. Everything else references K-17. Which well was tested? Jim Regg Supervisor, Inspections AOGCC 333 W.7`h Ave, Suite 100 Anchorage; AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reggC@alaska.eov. From: Wade Hudgens - (C) <whudgens@hilcorp.com> Sent: Tuesday, November 19, 2019 11:20 AM To: Regg, James B (CED) <aim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bav alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: MIT -IA MPU K-17 Attached MIT 10-426. Submit to: Iim.reaotldlalaska.i OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test AOGCC.Insoegors®alaskaooVphoebe.bi-C.CIdialaskaaov Hilcorp Alaska LLC Milne Point UniU K-17/ K Pad Wade Hudgens Thuswallacele.i.ska aov 2et1 II (II("T Well TYPE TEST Cotlea 1 Presss: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. O= Other (diseases In Notes) 4=Four Year Cycle PTD 1960280 Type Inj N TibingureType V=Ryula00y Variance 1=Inconclusive I = Industrial Wasovessi r O =gaer dese ibe In notes) Test P Packer ND 7060' BBL Pump 2.6 IA 0 2750. 2750 2750 Interval O Test psi 2500 1 BBL Return 2 6 OA I N/A I N/A NIA N/A Result P Note.: Produce,Mpar sundry 319-40 IT-IA nal T/I/O OpsirOpatopsi. 8.9C NaCl was used for test water Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi 1381 Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min 60 Min. PTD Type Inj TubingType Test Packer ND BBL Pump IA11 Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL ReIum OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Retum OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing I Type Tesl Packer ND BBL Pump IA Interval Test psi BBL Retum OA Result Notes: TYPE INJ Codes TYPE TEST Cotlea INTERVAL Codes Reault Code. W=Warm P=Pressure Test 1=Initial Test P=Pana G=Gas O= Other (diseases In Notes) 4=Four Year Cycle F=Fail a=Slurry V=Ryula00y Variance 1=Inconclusive I = Industrial Wasovessi r O =gaer dese ibe In notes) N = Net Injects, Form 10-426 (Revised 01/2017) MIT -IA MPO K-1711-1719 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, November 5, 2019 11:12 AM To: Ian Toomey - (C) Subject: RE: K-17 RWO updated SBHP p� I V 1 1 Ian, Per CO 390A Kuparuk producers with BHP of>8.55 ppg EMW require a ESP packer. As K-17 has been shut in for a long period the BHP should drop very quickly below the 8.55 ppg cutoff for requiring a packer. AOGCC will waive the ESP packer under CO 390A for this well. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDEN17ALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska.Qov). From: Ian Toomey - (C) <itoomey@hilcorp.com> Sent: Tuesday, November 5, 2019 10:03 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: K-17 RWO updated SBHP Guy, As we discussed our SBHP that was obtained yesterday (11/4/19) has increased from the previous SBHP (7/31/18). The new SBHP = 3,078 psi at 6,872' TVD which EMW = 8.62 ppg with a MPSP of 2391 psi. Our new KWF = 8.9 ppg NaCl. K-22 injector supports K-17 and K-09 which are both SI due to failed ESP. K-22 has been on injection but is going to be SI today. Let me know is you have any questions. Regards, Ian Toomey I Operations Engineer Hilcorp Alaska, LLC I Milne Point Cell: 907-903-3987 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard. and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE 1 A t 045 UWV GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU K-17 Permit to Drill Number: 196-028 Sundry Number: 319-497 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Price Chair DATED this's day of November, 2019. OWS/i`"' NOV 0 6 2019 NOV 01 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION p OGC� APPLICATION FOR SUNDRY APPROVALS H 711 AAC 75 9Rn 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ cry j�� Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program EJ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑' Stratigraphic ElService ❑ 196-028 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22647-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT K-17 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO375133 MILNE POINT/ KUPARUK RIVER OIL r it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,483' 7,654' 7,376' 7,253' 2,290 7,197' N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 3,471' 9-5/8" 3,508' 3,508' 5,750psi 3,090psi Production 7,430' 7" 7,463' 7,335' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing 2-7/8" 6.5# / L-80 / EUE 8rd 7,007' See Schematic See Schematic 3-1/2" 9.2#/ L-80 / EUE 8rd 7,199' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES Versatrieve & BWD Sump Packer and N/A 7,060 MD/ 6,958 TVD & 7,184 MD/ 7,074 TVD and N/A 12. Attachments: Proposal Summary LJ Wellbore schematic = 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑.r Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 11/19/2019 Commencing Operations: OIL ❑ WINJ F]WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Ian Toomey_ -Cy— Authorized Title: Operations Manager Contact Email: itoorneyehilcorp.conn Contact Phone: 777-8434 Authorized Signature: Date: 11/1/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that thhaat/a representative may witness Sundry Number: ^ ,r 19 419 I Plug Integrity ❑ BOP Test LMechanical Integrity Test El Location Clearance ElJ/( Other: �5{,�^OSi �� Ie --s r 7' cav,- c 500 F s: ISDMS I� NOV 0 6 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No [q/ Subsequent Form Required: t 0 '• Y APPROVED BY p S Approved by: r COMMISSIONER THE COMMISSION Date: 1 -115`17 ��((�'' 1 1 /J1� ^��111 Submit Form and Form 10jf03 Revised 412017 Approved application is valigroL'[t.)fr�nRW �te�f approval. I�h,4/�nachments in Du lica1e n�01 �14 ff EIil..p Alaska, LL, ESP Changeout Well: MPU K-17 Date: 11-01-19 Well Name: MPU K-17 API Number: 50-029-22647-00-00 Current Status: 51 -ESP Producer Pad: K -Pad Estimated Start Date: November 19th, 2019 Rig: ASR Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-028 First Call Engineer: Ian Toomey (907) 777-8434 (0) (907) 903-3987 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: I Job Type: ESP Swap Most recent SBHP (7/31/18): 2,886 psi @ 6841' TVD KWF = 8.2 PPG Maximum Expected BHP: 3,000 psi @ 7103' TVD KWF = 8.2 PPG MPSP: 2,290 psi Gas Column Gradient = 0.1 psi/ft Max Inclination 21° @ 7,157' MD Max Dogleg: 2.2'/100ft @ 5,263' MD Tree: Cameron 2-9/16" 5M Wellhead: FMC Gen 5, 11" x 7-1/16" 5M Tubing Hanger: 3" LH Acme on top x 2-7/8" EUE 8rd on bottom BPV Profile: 2-1/2" CIW Type H Brief Well Summary: Well K-17 was drilled by Nabors 27E in March 1996 and completed by Nabors 4ES in August 1996 in the Kuparuk Band C sands. The well was put on production on August 101h, 1996. Within a week the water cut increased from 2% to 60% and within a month the water cut was up to 90%. The ESP failed in September 1996 (52 day run life) due to solids production. A RWO was done in December 1996 where a gravel pack was done on the C sand, the B sand was isolated with a PXN plug in the gravel pack completion and a new ESP completion was installed. The ESP shutdown in June 1997 on an overload trip (191 day run life). The ESP was diagnosed with a downhole phase to ground short. In October 1997 a RWO was done to changeout the ESP. That ESP ran until December 2005 when an unplanned shutdown caused a downhole short (2,967 day run life). The ESP was changed out during a RWO in August 2007. The most recent ESP failure was in June 2019 with a broken shaft (4,277 day run life). Notes Regarding the Well & Design • 7" Casing MIT to 3,500 psig passed on 3/16/1996 Offset Injector Support o K-22: SBHP on 9/16/17 was 3,120 psi o K-21: SI but possible support through fault. Objective: • Pull 2-7/8" ESP completion / • Pressure test the 7" casing. • Install new 2-7/8" ESP completion N ltilwu p Alaska, LL Pre -Rig Procedure: 1. RU slickline. 2. Pull DV from GLM at 6,793' MD. Leave pocket open. 3. Pull DPSOV from GLM at 151' and install DV. 4. RIH with gauges to obtain SBHP. 5. RD Slickline Unit �J 6. RU LRS and PT lines to 3,000 psi. 7. Bleed gas to 0 psi (if needed). 8. Attempt to reverse circulate 206 bbls of seawater down IA taking returns up the tubing. ESP Changeout Well: MPU K-17 Date: 11-01-19 a. If seeing > 80% returns: Continue to reverse circulate until returns are clean. Then SI the IA and bullhead an additional 11 bbls down the tubing to the formation. b. If seeing < 80% returns: SI the IA and bullhead 41 bbls down the tubing. SI the tubing and bullhead an additional 11 bbls down the IA to the formation. 9. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH (90 bbls to freeze protect to 2,500' MD). a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 10. RD Little Red Services. 11. RD well house and flowlines. Clear and level pad area around the well. Spot rig mats and containment 12. RU crane. Set 2-1/2" HP BPV. ND Tree. Inspect the lift threads on the tubing hanger. Install plug off tool into the BPV. -L /-rlut ZZ 7 13. NU 11", 5M BOPE with two sets 2-7/8" x 5" VBR s. RD Crane. 14. RU BOPE house. Spot the mud boat. RWO Procedure: 15. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 16. Test BOPE to 250/ 2,500 psi and annular to 250/2,500 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Perform test per ASR #1 BOPE test procedure dated 11/3/15. P/ c. Confirm test pressures per the Sundry Conditions of approval. 'ltv d. Test VBR's and annular with 2-7/8" and 3-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. A email explaining the wellhead situation prior to performing the rolling test. send an inspector to witness test if test witness was waived. b. With stack out of the test path, test choke manifold per standard procedure m Regg (AOGCC) via AOGCC may elect to c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. ESP Changeout Well: MPU K-17 EIil..m Alaska, M Date: 11-03-19 e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 17. RU to pull 2-7/8" ESP completion. 18. Pull plug off tool, check for pressure under the BPV. if needed kill the well with KWF and pull the BPV. 19. MU the landing joint to the tubing hanger, BOLDS, unseat the tubing hanger and pull to the rig floor. a. Max allowable pull = 116K lbs (80% of 2-7/8", 6.5#, L-80 tubing tension rating). String PU = 58K and SO = 56K when landed by Nabors 3S. 20. Lay down the landing joint and tubing hanger. RU to pull ESP and capillary tubing over sheaves to spooling units. a. Inspect the tubing hanger and note any corrosion or damage. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 21. POOH laying down the 2-7/8" tubing spooling capillary tubing, ESP cable and removing all jewelry as it presents itself. Lay down ESP components. a. Note any corrosion, sand, or scale on the tubing with associated depths and ESP components on the morning report. Equipment Disposition Tubing hanger Junk Tubing & Pup joints Junk Gaslift Mandrels/Nipple Junk ESP equipment/Power Cable Centrilift to take possession for inspection and teardown Capillary Tubing Junk Protectorlizer (4) Visually inspect on site then restock orjunk LaSalle cable clamps (126) Visually inspect on site then restock orjunk Flat cable guard (2) Visually inspect on site then restock or junk 22. RD ESP pulling equipment. 23. PU and MU HES locator seal assembly (LTSA) and 7" casing scraper. 24. RIH with LTSA/casing scraper on 3-1/2" work string to just above the GP packer at 7,060' MD. l 25. If circulation is possible, circulate the well clean at max rate. G 26. Engage the seal assembly into the GP packer. Ensure the IA is fluid packed and PT the IA to 2,500 psi for 30 minutes charted. a. Notify the AOGCC 24 hours in advance of the MIT -IA. /A (i -7 b. If the test fails, notify the operations Engineer for a plan forward. 27. POOH laying down work string, scraper and LTSA. oZ 28. RU to run ESP completion. H IIile.p Alaska, LG ESP Changeout Well: MPU K-17 Date: 11-01-19 29. PU and MU new Baker ESP assembly. Set base of ESP assembly at±7,000' MD. Check electrical integrity test every 1,000'. Install clamps on the first 15 joints then every other joint to surface. a. Motor centralizer b. Motor gauge unit, Zenith c. ESP motor, 562, 150 HP, 2205 V, 41 A d. Lower tandem seal e. Upper tandem seal, 513, GST3 4B f. Gas separator, 538 GSR g. Pump, Centurion 161-538P11SXD / h. Ported discharge head, Zenith ✓/ 1. 1 joint, 2-7/8", 6.5#, L-80, EUE 8rd tubing j. Nipple, HES 2.313" XN (2.205" no-go) with 10' handling pups above and below k. 2 joints, 2-7/8", 6.5#, L-80, EUE 8rd tubing 1. GLM, 2-7/8" x 1", DV installed with 10' handling pups above and below m. XXX joints, 2-7/8", 6.5#, L-80, EUE 8rd tubing n. GLM at ±200' MD, 2-7/8" x 1", .025" OV installed with 10' handling pups above and below o. X joints, 2-7/8", 6.5#, L-80, EUE 8rd tubing 30. PU and MU the new 2-7/8" tubing hanger. Make final splice of the ESP cable to the penetrator and dummy off control line port if present. 31. Land tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. Record PU and SO weights on tally. Lay down the landing joint. 32. Set 2-1/2" HP BPV. Post -Rig Procedure: 33. RD mud boat. RD BOPE house. Move to next well location. 34. RU crane. NO BOPE. Install plug off tool 35. NU the tubing head adapter and 2-9/16", 5M tree. PT tubing hanger void to 500/5000 psi. PT the tree to 250/5000 psi. ull plug off tool and BPV. 37. RD crane. Move re urns tank and rig mats to next well location. 38. Replace gauge(s) if removed. 39. Freeze protect tubing/casing as needed with 60/40 McOH (90 bbls to freeze protect to 2500' MD). a. Freeze protect is up to the discretion of the Wells Supervisor/Foreman depending on timing for the well to be POP. 40. Turn well over to production via handover form. RU well house and flowlines. Attachments: 1. Current schematic 2. Proposed schematic 3. BOP Schematic 4. Blank RWO MOC Form n l ilcocp Alaska. LLC IB Elev.: 28'/ GL Elev.: 33' (Nabors 27E) TD =8,400' (MD) /TD = 7,28TM0) PBTD=8,306' (MD) / PBTD=7,21d(TVD) 5D e5 SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU K-17 Last Completed: 8/10/2007 PTD: 196-028 Tree Cameron 2 -9/16" -SM Wellhead 11" x 7-1/16" SM FMC Gen SA, w/ 2-7/8" FMC Tbg. Hngr., top lift threads= 3",LH Acme, btm= 2-7/8" and EUE & 2 5" COW H BW profile OPEN HOLE/ CEMENT DETAIL 20" Cmt W/ 250 sks of Arcticset I In 30" Hole 9-S/8" I Cmt w/ 779 sks PF "E", 686 sx Class "G", 250 sx PF "C" in 12-1/4" Hole 7" 1 Cmt W/ 305 sks Class "G" in 8-1/2" Hole CASING DETAII Size Type Wt/Grade/Conn ID 151' STA 2: 2-7/8" x 1" GLM W/ DPSOV 2 ductor 91.1/H-40/N/A N/A S9-5/8"Surface 0151A63;' 2-7/8'XN-Nipple (2.205 No-go lD) 4 6,954' 40/L-80/Btrc. 8.835 S7" Pump: 145P11 / PMSSD 1:1 6 Production 26 / L-80 / Bic Mod 6276 S Upper Tandem Seal: GSB3DB 58/SB PFSA TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EU E 2.441 Surface 7,007' 3-1/2" 1 Tubing 9.2/L-80/N/A 1 2.992 1 7,060' 1 7,199' WELL INCLINATION DETAIL KOP C 3,700' Max Hole Angle=20 deg. @5,800' Max Hole Angle through perforations= 21 deg. JEWELRY DETAIL No Depth Item 1 151' STA 2: 2-7/8" x 1" GLM W/ DPSOV 2 6,793' STA 1: 2-7/8" x 1"GLM w/Dummy 3 6,935' 2-7/8'XN-Nipple (2.205 No-go lD) 4 6,954' Discharge Head: GPDIS 5 6,955' Pump: 145P11 / PMSSD 1:1 6 6,975' Intake: GPINTXAR 7 6,976' Upper Tandem Seal: GSB3DB 58/SB PFSA 8 61983' Lower Tandem Seal: GSB3DB SB/SB PFSA 9 6,990' Motor: KMH - 114hpW/3A10 7,001' Sensor:Pumpmate @ 7,007'11 7,060' 7" Versatrieve Packe12 7,121' 0.012" Gas Screen 13 7,184' 7" BWD Sump Packe14 7,197' 3-1/2"XN-Nipple w/ug Installed) 15 7,198' WLEG-Bottom@7 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (ND) Btm (ND) FT Date Status Kuparuk 7,125' 7,179' 7,019' 7,069' 1 24' 12/14/1996 1 Open Sands 7,205' 7,215' 7,094' 7,103' 1 10' 12/14/1996 1 Isolated 'erforetion Charge Detail: Original perf run was with RDX Alpha Jet 135 /45 Deg Phasing 5 spf shot on 8/5/2019. 'second Pert round was with RDX Alpha Jet 135 /45 Deg Phasing 12 spf shot on 12/14/1996 I -sand perforations isolated with a PXN plug. WELL STIMULATION 12/9/1996 - C Sa nd Fraed pack -51 5,0401bs of 20/40 Mesh Carbolite behind screen GENERAL WELL INFO API: SO -029-22647-00-00 Drilled, Cased & Initial Perfsby Nabors 27E -3/16/1996 Completed with ESP by Nabors 4ES-8/5/1996 RWO ESP Changeout by Nabors 4ES -12/15/1996 RWO ESP Changeout by Nabors SS -10/28/1997 RWO ESP Changeout by Nabors 3S-8/10/2007 RWO ESP Changeout by ASR -TBD Revised By: IAT 9/5/2019 LLC KB Elev.: 28'/ GL Elev.: 33' (Nabors 27E) TD=8,400' (IVCD) /TD = 7,287'(1VD) PBTD=8,306' (MD) / PBTD= 7,210'(TVD) PROPOSED Milne Point Unit Well: MPU K-17 Last Completed: 8/10/2007 PTD: 196-028 TREE & WELLHEAD Tree Cameron 2-9/16"-5M Wellhead 11"X7-1/16" 5M FMC Gen SA, W/2-7/8" FMC Tbg. Hngr., top lift threads= 3",LH Acme, btm= 2-7/8" 81d EUE & 2.5" CIW H BPV profile OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I In 30" Hole L 9-5/8" 1 Cmt w/ 779 sks PF "E", 686 sx Class "G", 250 sx PF "C" in 12-1/4" Hole 7" 1 Cmt w/ 305 sks Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID ±151' STA 2: 2-7/8" x 1" GLM w/ DPSOV 20" Conductor 91.1/H-40/N/A N/A S9-5/8" 03'!Sfl63;' 2-7/8" XN-Nipple (2.205 No-ga ID) 4 Surface 40/L-80/Btrc. 8835 S7" Pump: 145P31 /PMSSD I:1 6 Production 26/L-80/Btc Mod 6276 S Upper Tandem Seal: GSB3DB SB/58 PFSA TUBING DETAIL 2-7/8" Tubing 6.5/L-80/Brd EUE 2.441 Surface 7,007' 3-I/2" Tubing 9.2 / L-80 / N/A 2.992 7,060' 7,199' WELL INCLINATION DETAIL KOP @ 3,700' Max Hole Angle =20 deg. @5,800' Max Hole Angle through perforations= 21 deg. JEWELRY DETAIL No Depth Item 1 ±151' STA 2: 2-7/8" x 1" GLM w/ DPSOV 2 ±6,793' STA 1: 2-7/8" x 1"GLM w/ Dummy 3 16,935' 2-7/8" XN-Nipple (2.205 No-ga ID) 4 ±6,954' Discharge Head: GPM DIS ±6,955' Pump: 145P31 /PMSSD I:1 6 ±6,975' Intake: GPINTXAR 7 ±6,976' Upper Tandem Seal: GSB3DB SB/58 PFSA 8 ±61983' Lower Tandem Seal: GSB3DB SB/SB PFSA 9 }6,990' Motor:KM- - 114hp 11 1-11 /30A0 ±7,001' Sensor: Pumpmate w/Centralizer- Bottom @±7,007• 11 7,060' 7" Versatrieve Packer 12 7,121' 0.012" Gas Screen 13 7,184' 7" BWD Sump Packer 14 7,197' 3-1/2" XN-Nipple w/2.635" No-go ID (PXN plug Installed) 15 7,198' WLEG - Bottom @ 7,199' PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk I 7,125' ,IV I t,ul91 7,069' 1 24' 1 12/14/1996 Open Sands 1 7,205' 1 7,215' 1 7,09,V 1 7,103' 1 10' 1 12/14/1996 Isolated 'erforation Charge Detail: Original perf run was with RDX Alpha Jet 135 / 45 Deg Phasing 5 spf shot on 8/5/2019. econd Pert round was with RDX Alpha let 135 / 45 Deg Phasing 12 spf shot on 12/14/1996 -sand perforations Isolated with a PXN plug. WELL STIMULATION 12/9/1996 - C Sand Frac'd pack - 5,040lbs of 20/40 Mesh Carbolite behind screen GENERAL WELL INFO API: 50-029-22647-00-00 Drilled, Cased & Initial Perfsby Nabors 27E -3/16/1996 Completed with ESP by Nabors 4ES-8/5/1996 RWO ESP Changeout by Nabors 4ES -12/15/1996 RWO ESP Changeout by Nabors 5S-10/28/1997 RWO ESP Changeout by Nabors 3S-8/10/2007 RWO ESP Changeout by ASR -TBD Revised By: IAT 11/1/2019 Milne II ASR Rigg B 1 BODE n;k a�..►._ i.0 2019 11" BOPE BR or Pipe Rams lind ,es Tt m 0 N O d E d 0 z m Ti @ L L• � Y d � R •L Q' C U � U c d Q C ¢a •0 N d Y >: x 0.- a am •a N cc L am c R z U a m 0 a` w R 0 m R CL a y El Cp v m m CL N a` _d R 0 d d e M c L c 0 R d a E • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder n� Alaska Oil and Gas Conservation Commission / 0 333 West 7 Avenue 4 � Ip Anchorage, Alaska 99501 1" 91K - \"/ Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPK 10/2912011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK -06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK-09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 "----> MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK -34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK -38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 · ~ STATE OF ALASKA I ~?~ ALASKA Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED SEP 0 6 2007 Alaska Oil & Gas Cons. GOOlmission 1. Operations Performed: :[17.''- ''''t." ¡·mcnorage o Abandon IS Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well / o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other Change Out ESP - o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 196-028 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612. Anchorage. Alaska 99519-6612 50-029·22647-00-00 / 7. KB Elevation (ft): 61.50' 9. Well Name and Number: MPK-17 - 8. Property Designation: 10. Field / Pool(s): ADL 375133 - Milne Point Unit / Kuparuk River Sands - 11. Present well condition summary Total depth: measured 7483 . feet true vertical 7354 feet Plugs (measured) 7197' Effective depth: measured 7376 feet Junk (measured) None true vertical 7253 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 110' 110' 1490 470 Surface 3472' 9-5/8" 3508' 3508' 5750 3090 Intermediate Production 7429' 7" 7463' 7335' 7240 5410 Liner SCANNED SEP 1 1 2007 Perforation Depth MD (ft): 7125' -7215' Perforation Depth TVD (ft): 7019' - 7103' 2-7/8",6.5# L-80 7007' Tubing Size (size. grade, and measured depth): Packers and SSSV (type and measured depth): Gravel Pack Assembly: 7" HES Verstrieve packer and 7060' HES 7" 'BWD' sump packer 7197' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Averaoe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after work: 181 Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after work: ~ Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 N/A Printed Name Sondra Stewman Title Technical Assistant ~ature~rf))..~ --... ~ (\ q Prepared By Name/Number: Phone 564-4750 Date ~lJ((;()1ondra Stewman, 564-4750 . . Form 10-404 Revised 04/2006 0 R , GIN A L RBDMS BFL SE? 1 0 20D7 Js:'t \ "" Submit Onglnal Only Tree: Cameron 2 9/16" - 5 Wellhead: 11" x 7 1/16" 5M FMC Gen 5A, wi 27/8" FMC Tbg. Hng., top lift thread = 3" LH Acme, btm = 2 7/8" 8rd EUE & 2.5" CIW H BPV profile I 20" 91.1 ppf, H-40 115' KOP @ 3700' Max. hole angle = 20 deg. fl 5800' to PBTO' Hole angle thru' perfs = 210 deg. 95/8",40 ppf, L-80 Btrc.13,508' mdl 2-7/8", 6.5#, L-80, EUE 8rd tubing drift 10 = 2.347", cap == .00579 7", L-80, Mod.Btrc. production casing 26 ppf fl 4946' to TO (drift 10 = 6.151", cap. = 0.0383 bpf) 29 ppf fl 4946' to surf. (drift = 6.184", cap. = 0.0371 bpf) 7" short joint from 6,803' to 6,823' Mid-perf TVO = 7061' Mid-perf MO =7170' PBTO TVO = 7261' PBTO MO = 7376' Stimulation Summary 12/09/96 - 'C' Sand frac pack - 5040 Ibs of 20-40 mesh Carbolite behind screen. Perforation Summary Ref log: Atlas GR/CCL dated 717/96 Size SPF Interval (TV D) 7125'-7179' 7020'-7070' 7205'-721! 7020'-7103' 4.5" 5 4.5" 5 Alpha Jet charges @ 45/135 deg. phasing * 12/13/96 - Lower zone isolated w/ 'PXN' plug Note: FCO by Nabors 3S to 7175'- 8/10/07 No fill noticed. DATE 03/17/96 B/4/96 8/8/96 1 0/28/97 REV. BY JBF O'Malley M. Linder JBF REH COMMENTS Drilled and Cased by Nabors 27E Initial perforations Initial completion 4-ES ESP change out by Nabors 5S ESP RWO by Nabors 3S (added SPM & XN) 8/12/07 MPU K-17 Orig. KB Elev. = 61.89' (N 27E) Orig. GL Elev. = 28.7' RT To Tbg. Spool = 33.45' (N 27E) Cameo 2 7/8" x 1" I 141' md I sidepoeket KBMM GLM Cameo 2 7/8" x 1" sicJepocket KBMM GLM 27/8" XN Nipple - 2.205 ID Centrilift 145 P11 PMSS01 :1 I 6793' md I 6935' md I I 6954' md I Centrilift GSB3I;JBFERHLE¡SCVH\3SB/SBPFSA /6976' md I tandem seal sections Centrilift KMH 114 hp motorl 6990' md I 2330 v. I 30 am~ Centrilift Pumpmate 17001' md 7" HES Versatrieve pkr. 17060' md I 3.5' blank pipe (10=2.992") 17092' md 3.5", 0.012" gæcreen (10 =2.992") HES 7" 'BWO' sump pkr. 3.5" HES 'XN' npl. (wi 2.635" no-go W/LEG 7" float collar (PBTO) 7" float shoe 17121' mdl 7184' md 7197' md 7199' md MILNE POINT UNIT WELL K - 17 API NO: 50-029-22647 BP EXPLORATION {AK . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-17 MPK-17 WORKOVER NABORS ALASKA DRilLING I NABORS 3S Start: Rig Release: Rig Number: 8/5/2007 8/11/2007 Spud Date: 3/6/1996 End: 8/11/2007 04:00 - 05:30 1.50 KILL P RDMO to MPK-Pad from MPE-Pad. Move Carrier, Pits, and Pipe Shed to MPK Pad. Move Camp and Shop to MPK Pad. Lay Herculite. Spot Tiger Tank. Back Carrier over the well. Spot Pipe Shed. Spot Pits. PRE Raise Derrick. Make electrical connections. Make fluid transfer connections. Accept rig @ 20:00 hrs. DECOMP R/U Hardline to Tiger Tank. Install additionallA valve. Install Fusible Caps on Actuators. Install circulating lines and test. Pressure test hard line to 1000 psi. Pressure test circulating lines to 3500 psi. Hold Pre-Spud and Pre-Tour meeting with crew and DSM. P/U DSM lubricator and R/U DSM Continue R/U DSM lubricator and tools. Pull BPV and UD. RID DSM lubricator and tools. TBG Pressure- 250 psi, IA Pressure- 250 psi. PJSM with crew on well kill and spill prevention. R/U and make final circulating line checks. SITP- 190 psi and SICP- 320 psi. Start Kill Procedures by pumping 45 bbls down TBG with a pump rate of 2.7 BPM and 900 psi TBG pressure. Maintain 100 psi down stream of the choke pressure so as not to create a mist at the tiger tank. DECOMP Shut in choke and bullhead 15 bbls at 1 bpm with 2050 psi. Shut down pump and monitor SITP. SITP dropped to 0 psi. SICP- 400 psi. DECOMP Open choke and continue circulating 235 bbls down the TBG at 2.8 bpm maintaining constant casing pressure to FCP. Maintain FCP with 50-100 psi overbalance and keeping downsteam back pressure <150 psi. DECOMP Shut down pumps and monitor well. SITP- 0 psi and SICP- 0 psi. DECOMP Dry Rod TWC per FMC. R/U to test from above and below TWC. Test from above to 3500 psi. Test from below to 1000 psi. Both tests charted. Injection rate down IA of 0.5 BPM @ 1000 psi. N/D Tree. Inspect Hanger. Hanger looks to be in good condition. M/U 3" LH ACME crossover to Hanger with 9.5 turns. N/U BOPE. Stack configuration: 2-7/8" x 5-1/2" VBRs, Blinds, Annular Preventer. Avg=3 Bbl/hr loss. Test BOPE to 250 low pressure and 3500 psi high pressure. Each test was held for 5 minutes. AOGCC witness of test was waived by John Crisp. Test was witnessed by Nabors Toolpusher and BPX WSL. Test 1- Choke Valves 1, 2, 3, Blind Rams, and HCR Kill Test 2- Choke Valves 4, 5, 6, and Manual Kill Test 3- Choke Valves 7,8, and 9 Test 4- Choke Valves 10 and 11 Test 5- Choke Valves 12 and 13 Test 6- HCR Choke Test 7- Variable Pipe Rams with 2-7/8" Test Joint Test 8- Annular Preventer with 2-7/8" Test Joint and Manual Choke Test 9- Variable Pipe Rams with 3-1/2" Test Joint 17:00 - 20:00 3.00 RIGU P 20:00 - 23:00 3.00 WHSUR P 23:00 - 23:30 0.50 DHB P DECOMP 23:30 - 00:00 0.50 DHB P DECOMP 8/6/2007 00:00 - 00:30 0.50 DHB P DECOMP 00:30 - 01 :00 0.50 KILL P DECOMP 01 :00 - 01 :30 0.50 KILL P DECOMP 01 :30 - 02:00 0.50 KILL P 02:00 - 04:00 2.00 KILL P 05:30 - 07:00 1.50 DHB P 07:00 - 09:00 2.00 WHSUR P DECOMP 09:00 - 18:30 9.50 BOPSU P DECOMP 18:30 - 23:00 4.50 BOPSU P DECOMP Printed: 8/26/2007 1:31:14 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-17 MPK-17 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Ta~k<~$ 4.50 BOPSU~ P I I I ¡ I I 0.50 BOPSU1P 0.50 DHEQP I P 1.00 DHB P I 0.50 CLEAN I P 1.50 CLEAN I P 0.50 CLEAN I P 1.00 PULL IP I I I 2.00 PULL I P I 5.50 PULL I P I I I I I 8/6/2007 18:30 - 23:00 8/7/2007 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 06:30 06:30 - 12:00 Start: 8/5/2007 Rig Release: 8/11/2007 Rig Number: Spud Date: 3/611996 End: 8/11/2007 DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP I DECOMP 12:00 - 13:30 1.50 EVAL P DECOMP 13:30 - 15:30 2.00 FISH P DECOMP 15:30 - 00:00 8.50 FISH P DECOMP 8/8/2007 00:00 - 02:00 02:00 - 05:00 05:00 - 07:45 07:45 - 11 :00 2.00 FISH P DECOMP 3.00 FISH P DECOMP 2.75 FISH 3.25 FISH P P DECOMP DECOMP Test 10- Annular Preventer with 3-1/2" Test Joint and Outside Valve Test 11- Inside Valve Accumulater Test- 3000 psi starting pressure. After accuation- 1800 psi. First 200 psi recovery- 22 seconds. Full Recovery- 1 minute and 48 seconds. 4 Nitrogen Bottles @ 2000 psi. RID BOP testing equipment and blow down lines. P/U DSM Lubricator and R/U to pull TWC. P/U Lopso Opso and RIH. R/U DSM and Lubricator with extention rod. RIH and pull BPV. UD BPV and DSM Lubricator. PJSM with rig crew. R/U and prep to CBU. Circulate one hole volume at 3 BPM with 410 psi. Bottoms up was clean with no well bore fluids. Blow down choke and circulating lines. P/U and RIH with landing joint and sting into HGR with 3" LH ACME threads 9.5 turns. BOLDS. Check IA for pressure and pull HGR to rig floor. HGR and TBG pulled free @ 58,000 Ibs. (Block Weight- 10,000 Ibs) Cut ESP cable and check conductivity. Conductivity check was good. UD HGR and landing joint. R/U rig floor to POOH with 2-7/8" EUE 8rd TBG. Crew Change. POH wi ESP completion while SIB 2-7/8" Tubing into Derrick. Losses are at -4 BPH. There is no noticeable drag while POH. ESP is not on completion. Recovered Discharge head which is heavily damaged below the flange. Recovered all cable. The outside armour of the cable had wrapped itself around the three wires at bottom which likely gave a false reading that the ESP was still attached. Wait on Baker BHA to arrive on location. P/U and strap Drill Collars. Install Wear Ring. R/U to run 3-1/2" DP. Change of Scope meeting. P/U Baker BHA #1: Overshot wI 4" Grapple, Overshot extension, Bumper Sub, Oil Jar, Pump Out Sub, 6 ea.-4-3/4" Drill Collars. Total length of BHA #1- 208.07' RIH wi BHA #1 on 3-1/2" DP while picking up singles from the Shed. Continuous hole fill with an average of 4-6 BPH losses. 10 jts in @ 1800- hrs, 50 jts in @ 20:00 hrs, 100 jts in @ 22:18 hrs, 150 jts in @ 24:00 hrs. RIH wi BHA #1 on 3-1/2" DP while picking up singles from the Shed. Continuous hole fill with an average of 4-6 BPH losses. 150 jts in @ 00:00 hrs, 200 jts in @ 24:00 hrs. PJSM with rig crew on PU/MU Kelly. P/U Kelly Shuck and secure into place. P/U Kelly Swivel and Kelly. M/U Kelly to Swivel. P/U Kelly Bushings and assemble to Kelly. Secure Kelly in Kelly Shuck. P/U and Pressure Test Kelly and stand back. RIH wi BHA #1 on 3-1/2" DP to 6,992' MD. Kelly up. Establish parameters: 40 psi at 1 BPM, P/U=105k-lbs, S/O=50k-lbs, Free Spinning Torque=2000 ft-Ibs @ 20 RPM with free spinning weight 103k-lbs. RIH while pumping 1 BPM at 40 psi. Tag top of pump @ 7011' MD. Unable to Swallow. P/U 3" and rotate. Printed: 8/26/2007 1:31:14 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-17 MPK-17 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 8/5/2007 8/11/2007 Spud Date: 3/6/1996 End: 8/11/2007 RBIH and tag at 7011' and swallow 4'. See pump pressure increase to 400 psi once pump is swallowed. Set 4k-lbs down on Pump. POH and see 5k-lbs overpull. POH to 6992' MD. Overpull is not present. Pump down DP and see pressure increase again which indicates Fish is still on. 11 :00 - 12:00 1.00 FISH P DECOMP Break Kelly. Drop Ball and Rod down DP and pressure up to 2130 psi to shear Pump Out Sub. POH 4 stands while pulling wet. Pressure up once again on DP, pressure increases to 220 psi and then drops off to 40 psi. Scale most likely plugged ports in pump out sub off. Circulate 70 Bbls of seawater at 4 BPM at 430 psi down DP while taking returns to the Pits. 12:00 - 16:30 4.50 FISH P DECOMP POH wi Fish while SIB 3-1/2" DP in the Derrick. Losses are at 4 BPH. 16:30 - 18:00 1.50 FISH P DECOMP POH and SIB Drill Collars. Break and UD Purnp out Sub and, Oil Jars, and Bumper Sub. POH wI Overshot extension, Overshot, and ESP. Recovered all lost ESP comoonents UD Overshot and ESP. 18:00 - 18:30 0.50 FISH P DECOMP Clean up Rig Floor. Crew change out. 18:30 - 20:00 1.50 CLEAN P DECOMP RIH with 3 stands of Drill Collars. POH wI Drill Collars and UD into the Pipe Shed. 20:00 - 20:30 0.50 CLEAN P DECOMP PUMU BHA #2: Mule Shoe, 4-jts of 2-1/16" CS Hydril, X/O Sub, and Purnp Out Sub, on 3-1/2" Drill Pipe out of derrick. 20:30 - 00:00 3.50 CLEAN P DECOMP RIH with BHA #2 on 3-1/2" IF Drill Pipe out of derrick. 8/9/2007 00:00 - 03:00 3.00 CLEAN P DECOMP RIH with BHA #2 on 109 stands of 3-1/2" IF Drill Pipe out of derrick. 03:00 - 03:30 0.50 CLEAN P DECOMP Continue to RIH by picking up 3 single joints of 3-1/2" Drill : Pipe. Establish parameters of 94,000 Ibs up weight and 90,000 llbs down weight. Continue RIH through 3-1/2" liner without any indications. Continue RIH by picking up 7 more singles of 3-1/2" Drill Pipe. Tagged out at 7175'. Pick up and R/U circulating head on top single. Establish clean out parameters of 95,000 Ibs up weight; 93,000 Ibs down weight; slow pump rate at 3 BPM with 440 psi. Increase pump rate to 3.5 BPM and 570 psi. RIH and tag at 7175' placing 3-1/2" X/O sub on top of liner. Pressure increased from 570 psi to 750 psi. Confirmed tag once more. Pressure increased immediately at tag. 03:30 - 05:30 2.00 CLEAN P DECOMP Pump 10 bbl high vis sweep and chase with 125 bbls at 3.5 BPM with 570 psi. Stop circulating, break tool joint, and pump ball and rod to open circulating sub at 1.5 BPM with 140 psi. Chase circulating sub with 20 bbl high vis sweep. Open circulating sub with 1900 psi. Continue pumping sweeps out of hole. Flowcheck well. 05:30 - 12:00 6.50 CLEAN P DECOMP POOH laying down 31/2" DP wi continuous hole fill, losses @ - 5 Bls/Hr 12:00 - 13:30 1.50 CLEAN P DECOMP Make breaks in Kelly. CIO Pull-Back line. 13:30 - 15:30 2.00 CLEAN P DECOMP POOH laying down 3 1/2" DP wI continuous hole fill, losses @ - 4 Bls/Hr 15:30 - 16:00 0.50 CLEAN P DECOMP UD BHA #2: Pump Out Sub, XO, 2-1/16" CS Hydrill, Mule Shoe. 16:00 - 19:30 3.50 CLEAN P DECOMP Pull Wear Ring. Clear and Clean Rig Floor. UD Kelly and Kelly Shuck. 19:30 - 21 :00 1.50' RUNCO P RUNCMP Clear and clean rig floor. R/U floor to run 2-7/8" completion Printed: 8/26/2007 1:31:14 PM . . , .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-17 MPK-17 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 8/5/2007 8/11/2007 Spud Date: 3/6/1996 End: 8/11/2007 8/9/2007 assembly. M/U ESP: Centralizer, PumpMate, Motor (KMH 2330 VI 30 A), Lower Tandem Seal, Upper Tandem Seal, Intake (GPINTXAR), Pump, and Discharge Head. 23:30 - 00:00 0.50 RUNCMP RIH with ESP. M/U 2-7/8" "XN" Nipple and Dummy GLM for completion BHA. 8/10/2007 00:00 - 08:30 8.50 RUNCMP Continue RIH with 2-7/8" EUE 8rd ESP completion. Using constant hole fill while RIH, Torque connections to optimum torque of 2300 ft-Ibs, use Best-O-Life pipe dope, clamping cable with LaSalle clamps each joint for the first 9 joints and every other connection from there on. Checking conductivity each 2000'. Ran 25 stds @ 01 :58 hrs, 50 stds @ 03:06 hrs, 75 stds @ 05:00 hrs. P/U Landing Joint and M/U to Hanger. M/U Hanger with Penetrator orientated correctly. Ran a total of 126 LaSalle Clamps, 2 Flatgaurds, and 4 Protectolizers. 08:30 - 10:00 I 1.50 RUNCMP Perform Penetrator Splice on the ESP cable with Centrilift rep. 10:00 - 10:30 0.50 RUNCMP Establish final PUW = 58K and SOW = 56K. Conduct ESP I Cable check: Phase to Phase = 4.3 ohms, Phase to Ground = 1.07 G ohms, 3063 psi, 162 F. RIH and Land Hanger. RILDS. UD Landing Joint. 10:30 - 12:00 RUNCMP Dry Rod TWC. Test from above to 1000 psi for 10 minutes. Tested TWC from below to 1000 psi by injecting at 0.5 BPM. No visual signs of leak during test from below. Good tests. Charted both tests. 12:00 - 17:00 5.00 BOPSU P RUNCMP N/D BOPE. UD Stack into cradle. 17:00 - 18:00 1.00 WHSUR P RUNCMP N/U Tree. Conduct final conductivity test per Centrilift. 18:00 - 19:30 1.50 WHSUR P RUNCMP R/U with FMC testing equipment and test tree adapter flange to 5000 psi for 30 minutes. Good test. Test witnessed by BPX WSL. 19:30 - 23:00 3.50 WHSUR P RUNCMP R/U and attempt to test tree to 5000 psi. Test no good. Isolate master valve and test (no good). Isolate rig testing equipment and test (good test). Test against SSV (no good). R/U tree with sensator to isolate tree and test (no good). 23:00 - 00:00 1.00 WHSUR P RUNCMP R/U DSM and grease all tree valves. Test tree against TWC (no good). 8/11/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP R/U DSM lubricator and change out TWC. RID DSM. 00:30 - 02:30 2.00 WHSUR P RUNCMP Test tree against new TWC (no good). RlU tree with tree cap and open Swab Valve. Test Tree to 5000 psi for 10 minutes, good test. Test charted. 02:30 - 03:00 0.50 WHSUR P RUNCMP R/U DSM lubricator and pull TWC. Set BPV. 03:00 - 04:00 1.00 WHSUR P RUNCMP Secure Tree, Wellhead, and Cellar. Prep to move rig. Release Rig at 04:00 hrs 8/11/2007. Printed: 8/26/2007 1:31:14 PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON :OR BEFORE JANUARY 03,2001 p i M ATE E W IA L U N u t:: ~ I H IS M ARK ER c:LO~M.DOC P E RM I T DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 11/25/98 RUN RECVD 96 - 028 SBL ~PIA 96-028 GR/OCL 96-028 CDN-MD ~L'~3400-7360 96-028 CDN-TVD ~400-7230 96-028 CDR-MD ~/3500- 7420 96-028 CDR-TV~D ~3500-7290 96-028 GR/CCL ~/~50-7366 96-028 7448 J/~406-7483 96-028 SUMP PACKER ~6735-7224 96-028 PERF ~6290-7373 96-028 DIR SRVY LwR/l12-7347 CDR/CDN 1 04/16/96 05/03/96 1 07/26/96 1 08/12/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 1 08/30/96 2 09/05/96 FINAL 01/24/97 FINAL 01/24/97 03/05/97 10-407 ~R/COMPLETION DATE DAILY WELL 0PS R ~/3/q~ TO l~//j~/~/~/ Are dry ditch samples required? yes ~__~And received? Was the well cored? yeses.Analysis & description received? Are well testS required? s ~Received. Well is in compliance Initial COMMENTS ye s--~rfo STATE OF ALASKA ALASK/-, OIL AND GAS CONSERVATION C~MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Exchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3648' NSL, 2101' WEL, Sec. 3, T12N, R11E, UM At top of productive interval 3946' NSL, 2702' WEL, Sec. 3, T12N, R11 E, UM At effective depth 3987' NSL, 2786' WEL, Sec. 3, T12N, R11E, UM At total depth 4000' NSL, 2813' WEL, Sec. 3, T12N, R11 E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 62' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-17 9. Permit Number / Approval No. 96-28 10. APl Number 50- 029-22647 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 7463' feet true vertical 7335' feet Effective depth: measured 7376' feet true vertical 7254' feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented MD TVD 72' 20" 250 sx Arcticset I (approx) 11 O' 11 O' 3472' 9 5/8" 740 sx PF 'E', 250 sx 'G' 3508' 3508' 96 sx PF 'E' 7429' 7" 285 sx Class 'G' 7463' 7335' Perforation depth: measured true vertical 7125'-7179',7205'-7215' 7020'-7070',7093'-7103' Oixi i{Ak Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 6998' Packers and SSV (type and measured depth) 7" HES 'VTL' pkr @ 7061' & HES 7" 'BWD' Sump pkr_-@-7~18:4'..,_ ~ 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 In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~/~r.f-,J~ d (/",~,'~ Title Engineering Supervisor Date _~t/~'-//)~ Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Du Facility Date/Time 25 Oct 97 26 Oct 97 27 Oct 97 28 Oct 97 29 Oct 97 30 Oct 97 M Pt K Pad 13:00 14:00 17:00 18:00 18:30 22:00 01:00 01:30 02:00 03:30 04:30 12:00 15:30 19:00 19:30 21:30 22:00 22:30 05:00 06:00 08:30 15:30 21:30 23:00 08:00 10:00 11:00 23:00 01:30 02:30 04:00 06:00 10:30 14:00 14:30 15:30 18:00 06:00 Progress Repo . Well MPK- 17 Rig Nabors 5S Page 1 Date 13 February 98 Duration Activity At well location - Cellar Completed operations Completed operations Stopped: To hold safety meeting Completed operations Equipment work completed Hole displaced with Seawater - 120.00 % displaced Observed well static Equipment work completed Equipment work completed Equipment work completed Equipment work completed Pressure test completed successfully - 5000.000 psi Equipment work completed Equipment work completed Equipment work completed In 0.50 hr had 19.000 bbl Loss Equipment work completed Stopped: At sub-assembly Completed operations Completed operations Completed run with Swage from 0.0 ft to 7199.0 ft Equipment work completed Stopped: To circulate Hole displaced with Fresh water - 100.00 % displaced Stopped: To circulate Hole displaced with Fresh water - 100.00 % displaced Stopped: To splice cable Equipment work completed Hanger landed Equipment work completed Equipment work completed Pressure test completed successfully - 5000.000 psi Completed operations Completed operations Equipment work completed Equipment work completed At well location - Slot STATE OF ALASKA ALASKA ~,,L AND GAS CONSERVATION COIVlivllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 12. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 96-28 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22647 ~_. ::~.-,-.~.~. 4. Location of well at surface ¢ ..... ~.. -- ..... ~ ,~ ~ ~¢~.~¢~:~i 9. Unit or Lease Name 3648'NSL, 2101'WEL, SEC. 3, T12N, R11E i ~:':;',i'.'-,:, ~ ~ ~~ Milne Point Unit At top of productive interval i/~_~_/.~._~_ ' ~~ i10. Well Number~ 3946' NSL, 2702' WEb, SEC. 3, T12N, R11E _~ ......... MPK-17 At total depth i-:~~."";*~::;~ ~ ~ 11. Field and Pool 4003' NSL, 2820' WEb, SEC. 3, T12N, R11E .~,; ................. ..,.%. Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 61.7'I ADb 375133 12. Date Spudded03/06/96 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re I 16' N°' °f C°mpleti°ns03/14/96 12/15/96 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrost 7483 735,4 F-ri 7376 7253 F~ []Yes []No I N/A MD, 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, GR/CCL, GR/JB 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1Cf NTSOLHE 38' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40Cf L-80 36' 3508' 12-1/4" 740 sx PF 'E', 250 sx 'G', 96 sx PF 'E' 7" 26# L-80 34' 7463' 8-1/2" 285 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5cf, L-80 6988' N/A MD TVD MD TVD 7125'-7179' 7019'-7070' 7125'-7179' 7019'-7070' 7205'-7215' 7094'-7103' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/70 bbls diesel Gravel pacassy, 7061'-7184' 866000# 20/40 Carbolite behind pipe 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) August 9, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing PressureCALCULATED . OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL 1997 ~eska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. , ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top KC1 7115' 6948' Top Kuparuk 'B' 7176' 7005' Top Kuparuk B7 7199' 7027' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is t[ue and~c~rrect to the best of my knowledge Tim Schofield ".;'~, -~ Title Senior Drilling Engineer Da Prepared By Name/Number: Kathy C'ampoamor, 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M P K- 1 7 Rig Name: N 2 7 E AFE: 3 3 7 0 1 0 Accept Date: 03/05/96 Spud Date: 03/06/96 Release Date: 03/1 6/96 Mar 3 1996 (1) Rig moved 45 %. Mar 4 1996 (2) Rig moved 75 %. Mar 5 1996 (3) Rig moved 85 %. Mar 6 1996 (4) Rig moved 100%. Nabors rig #27E accepted 03/05/96 @ 1200 hrs. RU divertor. MU BHA #1. Tested divertor. Held safety meeting. MU BHA #1. Drilled to 435 ft. ) Serviced mud shakers. Drilled to 2399 ft. Circulated at 2399 ft. Mar 7 1996 (5 Drilled to 2272 ft. Drilled to 2743 ft. Mar 8 1996 (6 Drilled to 2768 ft. Circulated at 2768 ft. Drilled to 2871 ft. Circulated at 2871 ft. Circulated at 2871 ft. Drilled to 2967 ft. Circulated at 2967 ft. Drilled to 3527 ft. Circulated at 3527 ft. Mar 9 1996 (7) Circulated at 3527 ft. POOH to 2451 ft. Pumped out of hole to 2355 ft. Jarred stuck pipe at 2355 ft. Worked stuck pipe at 2353 ft. Jarred stuck pipe at 2355 ft. RU drillfloor/derrick. Jarred stuck pipe at 2355 ft. Circulated at 2465 ft. RD drillfloor/derrick. RIH to 3167 ft. Reamed to 3527 ft. Circulated at 3527 ft. Mar 10 1996 (8) Circulated at 3527 ft. Pulled BHA. Reamed to 2387 ft. Circulated at 2292 ft. Pulled BHA. MU BHA #2. RIH to 3527 ft. Circulated at 3527 ft. Pulled BHA. RU, casing handling equipment· Serviced dr~llfloor/dernck. Held safety meet~ng.~~[¢',~-~ 3300 ff (9.625 in OD). Page Mar 11 1996 (9) Ran casing to 3508 ft (9.625 in OD). Circulated at 3508 ft. Mixed and pumped slurry - 340 bbl. Displaced slurry - 249 bbl. Tested casing. RU drillfloor/derrick. Mixed and pumped slurry- 37 bbl. RD divertor. Installed wellhead integral components. RU BOP stack. Tested BOP stack. Installed bore protector. MU BHA #3. RIH to 1200 ft. Serviced block line. Mar 12 1996 (10) Serviced block line. RIH to 1121 ft. POOH to 96 ft. MU BHA #3. RIH to 2434 ft. Repaired iron roughneck. Serviced crown block. RIH to 3421 ft. Tested casing. Drilled installed equipment - float collar. Performed formation integrity test, 12.5 ppg EMW. Drilled to 3886 ft. POOH to 3500 ft. Repaired standpipe manifold. RIH to 3886 ft. Drilled to 4046 ft. Repaired standpipe manifold. Drilled to 4711 ft. Mar 13 1996 (11) Drilled to 4919 ft. POOH to 4000 ft. RIH to 4919 ft. Drilled to 5900 ft. Circulated at 5900 ft. POOH to 4890 ft. RIH to 5900 ft. Drilled to 6659 ft. Circulated at 6659 ft. POOH to 5831 ft. RIH to 6567 ft. Mar 14 1996 (12) Took wireline multishot survey at 6265 ft. Drilled to 6783 ft. Circulated at 6783 ft. Drilled to 7132 ft. Mar 15 1996 (13) Drilled to 7483 ft. Circulated at 7483 f. POOH to 3450 ft. RIH to 7483 ft. Circulated at 7483 ft. LD 6640 ft of 5 in OD drill pipe. Pulled BHA. Removed bore protector. RU casing handling equipment. Ran casing to 543 ft (7 in OD). Mar 16 1996 (14) Ran casing to 3500 ft (7 in OD). Circulated at 3500 ft. Ran casing to 7463 ft (7 in OD). Circulated at 7463 ft. Mixed and pumped slurry- 104 bbl. Displaced slurry - 282 bbl. Tested casing. RD cement unit. RD BOP stack. Installed wellhead integral components. Installed hanger plug. Serviced sand traps. Nabors rig #27E released 03/16/96 @ 0400 hrs. Page 2 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-1 7 Rig Name: N-4ES AFE: 337010, 339025 Accept Date: 08/03/96, Spud Date: Release Date: 08/05/96, 12/11/96 12/15/96 Aug 3 1996 RD to move, waiting on truck to move rig. Aug 4 1996 RD to move, lay swamp mats. Cont to wait on truck. Lay herculite. MIRU. Move & spot rig. Raise & scope derrick, berm rig. Nabors rig #4ES accepted 08/03/96 @ 1300 hrs. Take on brine in pits, spot & berm tiger tank. ND tree. NU DSA & BOP's. Test all rams & valves. Test annular. Perform accumulator test. Witness waived by AOGCC inspector Chuck Scheve. BOLDS, pull hanger. Strap & calipher scrapper & XO's. PU mule shoe & scrapper assy & RIH t/2150'. Circ out diesel freeze protect from 2150'. Cont RIH t/3700'. CBU. Cont PU 2-7/8" tubing. Tagged PBTD at 7374'. Reverse cement contaminated fluid through sock filters Aug 5 1996 RU MI filter unit. Filter fluid in pits. Rev circ hole volume. Hole out of balance. Circ tubing volume. Monitor well. LD 15 jts 2-7/8" tubing. TOH in stands. Laid out casing scrapper & XO's. ND flow nipple & NU perf nipple. RU Atlas WL, test lubricator. Run #1, RIH w/gun-5 spf & perfed 7205'-7215'. Run #2, RIH w/gun-5 spf & perfed 7159'- 7179'. Run #3, RIH w/gun-5 spf & perfed 7139'-7159'. Run #4, RIH w/gun-5 spf & perfed 7125'-7139'. RIH w/GR & junk basket 7330'. RD Atlas. ND shooting flange & NU flow nipple. RU to run ESP. MU & service ESP. TIH with 2-7/8" ESP completion. MU hanger & LT. Attempt to install penetrator in hanger. Unable to seat penetrator in hanger. MU new hanger & penetrator. Make upper pigtail splice. Aug 6 1996 Finish making upper pigtail splice at hanger. Land tubing. RILDS. LD LJ. Set TWC. ND BOP's & adapter flange. NU tubing head adapter & tree& test tree & hanger. Pull TWC. Set BPV. RD cellar & secure well. Hauled fluids out of rig pits & tiger tank & cleaned rig pits. Nabors rig released 08/05/96 @ 1330 hrs. Dec 11 1996 MIRU. Berm & level. Nabors rig #4ES accepted 12/11/g6 @ 0600 Page Dec 12 1996 RU to pits in offset position. NU to tree, tiger tank w/filling pits w/fluid. Test lines, pull BPV, tbg, ann. Kill well, spot pill @ perfs, monitor well static, set TWC. ND comp/NU BOP. RU & test BOP/AOGCC waived inspection. Pull TWC, install LJ, bk out LDS. CBU, LD hanger LJ, monitor well. Ok. POOH, stand back tubing, LD ESP assy. Dec 13 1996 Lube rig. MU muleshoe string scraper, RIH. Rev circ, cond, clean hole @ 7361'. Pull up t/7020', LD 11 jts 2-7/8" tubing. Circ hole w/fluid trucks. Mix/pump dirt mag casing wash. Circ casing wash, circ w/filtered brine, circ caustic sweep chase w/filtered seawater. POOH, LD casing scrapper/muleshoe. ND flow nipple/NU perf flange. RU SWS test lub. Run ¢1, RIH with CCL/GR. Dec 14 1996 RIH with GR/CCL. Gun run ¢1, RIH with 4-1/2", 12 spf perfed 7159'-7179'. Run ¢2 perfed @ 7139'-7159'. Gun run ¢3 misfire, gun run ¢4 perfed 7125'-7139'. GR/JB run t/7365', POOH recover perf debris/made 2nd run. RIH w/BWD perm pkr set @ 7184'. RD SWS. ND shooting flange, NU flow nipple, set test plug, change pipe rams, test t/5000¢, set WR. RU floor. MU gravel pack assy. RIH with gravel pack assy. Dec 15 1996 Space out frac pac, drop ball, set test pkr @ 7056'. RU DS, test lines. Perform evalu data frac, reperform data pac & evalu. Perf frac pac, restress, blow down lines, RD DS. Monitor well, mix/pump fluid. Monitor well static. POOH, LD tubing & tools. Install 2-7/8" rams & test. MU service ESP. RIH w/2-7/8" ESP. Dec 16 1996 RIH w/2-7/8" compl drift. MU hanger & splice. LD tubing, RILDS, set TWC. ND BOP's. NU tree, test tree & adapter. Pull TWC, set BPV, test lines, bullhead 60 bbls diesel down annul, 10 bbls diesel down tubing. Blow down lines, secure cellar/tree. Nabors rig #4ES released 12/15/96 @ 1800 hrs. RDMO. Page MILNE POINT, ALASKA TO: FROM: WELL# Main Category: Sub Category: Operation Date: Hendrix/Stevens O'Malley Mark RWO / Frac Pack Add Perf / Pkr. set 12-13-96 Date: 112-15-96 Objective: Add Perfs to the Kuparuk C-Sands for a Gravel Pack and set a Sub Packer. Operation: (06:00) RU SWS on 4-ES and pressure test equip, to 1,000 psi. Held pre job safety meeting. #1 Run 20' Perf gun 4.5" 12 spf. 24g RDX Big hole charge. 135/45° . RIH Tied into Marked line log 7/07/96. Tied into short joint 1' correction. Dropped down logged tool into position 3' from CCL to top shot 7,156' All shots fired ( 7,159' - 7,179' ) #2 Run 20' Perf gun 4.5" 12 spf. 24g RDX Big hole charge. 135/45° . RIH Tied into Marked line log 7/07/96. Tied into short joint 3' correction. Dropped down logged tool into position 3' from CCL to top shot 7,136' All shots fired ( 7,139' - 7,159' ) #3 Run 14' Perf gun 4.5" 12 spf. 24g RDX Big hole charge. 135/45° .RIH Tied into Marked line log 7/07/96. Tied into short joint 3' correction. Dropped down logged tool into position 8.5' from CCL to top shot 7,116.5') GUN FAILED TO FIRE. POH Checked over equip, on surface Nothing obvious. Changed out firing cap re-ran gun to same. All shots fired ( 7,125 - 7,139' ) Made two JB/GR runs through the perfs to 10' above TD @ 7,371' First run had some perf debris. Second run was clean. "BWD" Halliburton 7' 26# permanent packer, assemble. ( Pkr., 6' pup, 3.5 XN-Nipple w/plug, W/L entry guide.) RIH 11' from CCL to the top of the pkr. Logged pkr. into place @ 7,173'. Middle element approx. 1.8" down from top of pkr. Set pkr. POH RD. Conclusion: All shots fired and sump pkr. set. Diesel Used I Methanol Used Page I BP EXPLORATION (ALASKA) INC. Mine Point Unit TO: S. Rossberg FROM: M O'Malley DATE: 12/09/96 RE: MPU K-17 "C" Sand Frac Pack SERVICE CO'S.: Dowell, Halliburton, Nabors, Peak '11 I JOB SUMMARY INJECTIVITY TEST .. Design Rate, Bbls Gel Max Rate, Final STP, Final Csg. ISIP BPM Pumped bpm psi psi 15 40 (XL) 15.7 4005 2857 670 #1 DATA FRAC Design Rate, Bbls Gel Max Rate, Final STP, Final Csg. ISIP BPM Pumped bpm psi psi 15 40 (XL) 15.6 3483 2513 2240 #2 DATA FRAC Design Rate, Bbls Gel Max Rate, Final STP, Final Csg. ISIP BPM Pumped bpm psi psi I 5 30 I 5 3519 2477 2381 FRAC PACK Sand pumped, Prop behind pipe Design total (lbs) 20~40 size behind pipe, Job was (lbs.) flush 9474 4174 lbs. 20~40 Carbolite 10,300 RE- PACK Sand pumped, Prop behind pipe, M# Design total (lbs) 20/40 size behind pipe, Job was (lbs.) flush 1250 862 10~300 Page 2 Comments: - The data frac was under displaced with the XL gel. The XL gel was changed after it was proven to be too efficient. It was replaced by linear gel WF-40. - In order to keep proppant from falling out the treating rate was maintained at 10 bpm. while mixing / pumping the slurry and the displacement. 10 Bbls before the slurry was at the perfs, the rate was increased to 15 bpm until screen out. As screen out pressure was approached the rate was maintained until total screen out. - As the formation screened out and the tubing pressures increased the turbine driven pumps tripped off at 6000 psig. Opened the choke and dehydrate the pack. Once open, the annulus pressure bled down and the tubing pressure slowly followed. After several minutes of slow bleeding off, the remaining tubing pressure was bled off at surface so that the tool could be picked up into the reverse position. Once the tubing had been completely reversed. The pack was restressed to 2300 psig. We're abl to circ. at 2100 psi 1.6 bpm. A top off job was performed on the pack. Circulated the hole at 4 bpm. to get the pad through the rig floor. Then we shifted the tool to the sqz. position slowed the pump down to 1 bpm. The pump slowly brought the pressure up to 2300 psig, To maintain that pressure we had to drop down to .7 bpm. When the pump shut down the pressure bleed of fairly slowly. The second stress at .6 bpm. required approx. I bbl to come up to pressure and the pump was shut down. Pressure bleed off but no fluid was detected on surface. The pack was considered good with a top off. Total carbolite behind pipe = DATE/TIME OPERATIONS SUMMARY 12/14/96 06:00 MIRU Dowel frac fleet. 06:30 Set scr. & pkr. Rig up surface treating lines to top joint of 3.5" 8.6 ppg seawater in hole with .012 ga all welded screen. 08:00 Hold tailgate safety meeting. 08:15 Pressure test surface lines to 7400 psig. - OK. Set trips at 6000 psig. 08:50 Drop HES tool down into sqz. position w/ith the choke open and circulate seawater at 2 and 3 bpm to obtain initial circulating pressure. 08:56 Pump 40 bbl. 30 ppt XL guar gel and displace w/tubing vol. of seawater at 15 bpm for injectivity test. 09:05 Pump 40 bbl. 30 ppt XL guar gel data frac and displace with tubing vol. of seawater at 15 bpm. 09:28 Shut down pumps and monitor pressure falloff. Wait for analysis and re-design. Following end of falloff survey, periodically injected water down treating lines to keep lines from freezing. 10:30 The XL gel was proven to be to efficient. A second data frac will be done with a linear gel. 10:56 Pump 30 bbl. 30 WF-40 linear gel data frac and displace with tubing vol. of seawater at 15 bpm. :11:08 Shut down pumps and monitor pressure falloff. Wait for analysis and re-design. Following end of falloff survey, periodically injected water down treating lines to keep lines frOm freezing. . . ...... ~ -~ e3 12:56 Start mixing and pumping pad /slurry at 10 bpm. Once flush was called increase rate to 15 bpm. 20-40 Carbolite slurry schedule as per re-design. As design volume was displaced into the perfs and predetermined screen out pressure was approached rapitly the pumps tripped out. 10 ppg slurry was on perfs. Open choke to dehydrate pack. Pressure bled off for several minutes. Pick tool up into the reverse position and reverse out remaining slurry in the tubing. 13:25 Attempt to Re-stress the pack able to circulate @ 1.6 bpm 2100 psig. Top off job determined to be required. 14:12 Start mixing and pumping pad / slurry at 5 bpm. With the tool in the reverse position until pad cleared the rig floor. Moved the tool into sqz. position. Dropped down to 1 bpm. The idea to just fill up the pack. Once 2300 psi was approached we dropped down to .6 bpm. Stopped pumping Pressure bled off slowly over several minutes. Pick tool up into the reverse position and reverse out remaining slurry in the tubing. 15:1 5 Attempt to Re-stress the pack pumping .5 bpm. 2300 psig. No returns on surface pushing the fluid through the pack and into the formation. Stop pumping. Top job determined to be good. RD DS PUMPING SUMMARY TIME I RATE ANNP WHP STAGE CUM cOMMENTS I BPM PSIG PSIG BBL BBL 12/14/96 INITIAL CIRC. PRESSURES 08:50 2 / 3 78 520 0/6 0 Initial circulation pressure at 2 bpm. Increase rate to 3 bpm. In the sqz. position 08:53 3.0 96 670 8 6 Initial circulating pressure at 3 bpm. 08:54 3.0 / 0 60 580 0 1 4 Final ICP at 3 bpm. S/D pumps. INJECTIVITY TEST DISPLACEMENT = 61.4 BBLS 08:53 0 55 380 0 1 4 Start pumping XL gel for injectivity test 08:56 8 2464 3409 40 14 Rate established. 09:00 8 2381 3222 21 54 Cut X-Link and go to water for displacement 09:04 15 2857 4005 40 75 On flush. Gel on perfs 09:05 15 / 0 2536 3560 0 115 Shut down pumps and allow fracture to close. ISlP = 2240 psig Page 4 DATA FRAC 09:20 0 1057 902 0 115 Prepare for data frac. Pump 40 bbl. of 30 ppt crosslinked guar gel pad. 09:22 0/15 2756 3691 0/5 115 Rate established. 09:23 15.4 2555 3579 20.7 120 09:24 1 5 2513 3483 40 140.7 Cut XL and go to water flush 09:26 15.5 2500 3533 0/30 155.7 09:28 15.3 2536 3538 60 285 Gel completely displaced. S/D pumps and monitor pressure falloff. Wait for data analysis results. ISIP = 2381 psi9. 10:55 0 650 732 0 216 XL Gel was too efficient a second data frac was scheduled with a linear gel 10:56 0 229 384 0 216 Prepare for data frac. Pump 30 bbl. linear gel pad. 10:56 15 2587 3583 0/30 216 10:57.5 15.2 2463 3515 0/60 246 Cut linear gel and go to water flush 10:59 15.1 2491 3437 0 305 Gel completely displaced. S/D pumps and monitor pressure falloff. Wait for data analysis results. ISIP -- 2243 p, sig 11:10 0 1941 2073 Monitor pressure falloff. 11:20 0 1319 1446 12:55 0 289 434 FRAC PACK 12:55.5 0 289 434 0 0 Preparing to pump frac pack. 12:56 10 426 2517 4 0 Pumping 10 bbl. linear gel pad. Rate established. Start pumping proppant. 12:56 10 444 2444 4 4 Pumping 10 bbl. linear gel pad. Rate established 12:56 1 0 385 2352 I 8 Start sand " 12:57 1 0 421 2540 1.2 9 Slurry conc. = 3. ppg 12:58 1 0 607 2526 2.7 10.2 12:59 1 0 490 2526 1 2 18.8 Slurry conc. --- 12.6 ppg 13:00 1 0 499 2526 1 0 36.7 Cut linear pad Flush 13:00 1 5 559 2329 42 46.5 Pad on perfs 13:04 14.6 2848 6013' 5 89.7 Backed off on rate as max. press, approached 6000 psig. * Actual pressure 6403 The turbine driven pumps kicked out as designed, pump did kick out at it's set pressure. 13:05 0 1749 6013' 94.7 Rate to zero. Open choke to dehydrate the pack. Because of the linear gel used we did not say in this position log. 13:10 0 5160 69 81.8 Bleed pressure off of the tubing from the surface. Pressure up annulus to pick up into reverse out tubing. 13:30 While attempting to re-stress the pack leaked 1.6' bpm at 2100 psi. We decided to do top job on the pack. 14:12 1.6 0 · 2300 6 6 stressed the pack mixing slurry up. 14:33 5 96 670 16 6 Pump with the tool in the circulating position until the slurry past the rig floor. 14:35 .9 0 2400 50 22 Pumped at slow rate had to drop down to .5 Bpm. to finish the job. 14:58 .2 0 2400 2 72 Stressed the pack. Reverse out two tubing volumes. 120 Bbls 15:15 .68 0 2200 2 1 94 During the restress of the top job no fluid was detected on the surface. Pack was bleeding off slowly back into the formation. FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 493 Bbls FRAC: 100 Bbls 593 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME GEL QUALITY CONTROL CHECK SEA H20 SEA H20 GEL 30# GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.3 97° / 77° 7.1 1 8 na na na FLUID ADDITIVES F75 ( Surftactant ) I gal/1000 M275 (Bactenacide) .6 gal/1000 ANNULAR INJECTION DATA ENTRY SCREEN Asset Rig Name ~27.E_.-. ........ Inj Well Name .M.P..~.-1]. .............. Permit Start .... PermitEnd ................ _ _4~..1.B =9.~._. ...._~..I.B.~9.Z ..... Sur Csg Dap ~5..0.~.~__ Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ct,q WaSh Fluids i : ; FJuidS Freeze Freeze I _._1.9.~8_.._..:LS..5.3JL..-_-2.85---------- ~ ___.6.8,5 ....... Legal Desc .3~.~,B. WR! ;21DQ~W. EL~S.e,c,,03JJ.21~LB.l.:LE. ......... Research Dali Data .... · .... IniermiMant Fma~ ' i i i SourceDar@of [iMUd'co~taminatedCtgs' Cm~. RigWash ii Completionj F0rma~n Freeze ~ Freeze Daily i I ., Annulus I !Well Injection i DrlgMud ! Ruids i Fluids I RUids ProteCtion ProteCtion Total i Rate[ Pressurej Status 103/15/96 i i i 1140 ~__i140 i i03/20/96 175 i225 i i i--i __! 1400 i UPK-25 i03/21/96 1,273 i i i i ! ,273 i MPK-25 i03/23/96 i80~ i__! __i__J iS0 upK-25 !03/24/96 i i__i__i70 ! !70 i MPK-3~ 103/25/96 ~50 i__i i i- i !150 i UPK-3~ i03/26/96 243 i i i i I i243 i MPK-38 103/27/96 163 i ! i i20 i i183 i ~P~-38 i03/29/96 19s i i i i i 119s i uPK-3~ i03/30/9~ 155 i__i i i ~ !~55 ! uP~-3~ I03/31/96 250 i i i !10 i i260 i uP~-3~ i04/0~/96 320 i ! i--~' i i320 i UPK-36 [04/02/96 185 i i i i ! 11S5 MPK-38 !04/03/96 335 i i ! i10 I !345 MPK-38 i04/04/96 400 ! i i i. ! i400 i MPK-38 104/05/96 949 i ! I t6~i--i 1,009 ! MPK-38 !04/06/96 0 i i__i i' i--lO MPK-38 !04/07/96 0 i i i i !0 i MPK-38 i04/08/96 150 i i I I i150 i -- MPK-38 104/09/96 1,373 i [--i i--! 11,373 MPK-38 i04/10/96 280 i i i 118 !--i298 i MPK-38 i04/11/96 260 i !--i 120 i i2S0 i MPK-38 i04/12/96 490 i i i i7 i !497 i MPK-38 !04/13/96 { i i i20 ~__i20 i MPK-38 104/14/96 135 . i i i10 ! i145 i MPK-38 104/15/96 140 --i--i i20 J i160 'i MPK-38 i04/16/96 50 i i i i70 i i120 i __ MPK-37 i04/23/96 30 i60 i--i 110 ~--1100 MPK-37 i04/24/96 1,240 _ i i i10 !--il,250 MPK-37 i04/25/96 300 i i10 i i310 MPK-37 i04/26/96 200 i i i i10 i__ 210 i il.5BPM @ 700 PSI _ MPK-37 104/27/96 700 i--i i '-- i .~710 i MPK-37 i04/28/96 50 ! i ! !20 i 170 i I1.5BPM @ 700PSI ~P~-37 104/30/96 ~,000 i i i i~o i i~,o~o i~PU@600PS, MPK-02 i05/04/96 350 i ! i i ?--------]350 i BPU @ S00PS~ UPK-02 !05/05/96 950 I--I i i10 i--i960 i 170 ~s of~ 9S0 ..... ~ .... d ..... t MPK-02 ]05/06/96 390 { J i i20 i 1410 { MPK-02 05/07/96 280 i i i 110 i i290 !1.5 BPM @ 700 PSI MPK-02 05/08/96 520 J i 110 i i530 i !1.5 BPM @ 700 PSI MPK-02 05/09/96 522 i i--!20 i !542 'i 105/10/96 221 i i i i10 ! i231 ! MPK-02 MPK-02 105/~1/96 335 i i i ! I !335 MPK-02 105/12/96 925~{--i ! ! ! i925 MPK-02 i05/13/96 625 i i i i !100 i'725 i 13 BPM @ 750 PSI COMPANY WELL NA~£ MPK-17 LOCATIO~ 1 MILNE PT LOCATION 2 ALASI<A ~AGN~IC DECLINATION 27.B0 ~RII) CONVERGI~ICE AN~LE APl ~ 50-029-2254Z JOB ~ 3775~ DATE: 05-14AR-9~. WELL N~B~ 0 TIE IN POINT(TIP) ~FASURED DEPTH 112.00 .TRB~ VERT DEPTM 112,00 I~LINATION 0 AZII~UTH LATITUDE (N/-S) 0 DBPARI'u~E(~-W) 0.® T.)E?(E/-W) 0,00 296.43 M~P, 0 5 1997 ~sl<~ Oi~ & G~s COns, Commission Anchorage ORIGINAL 2 E~]RVE¥ CAkCULATIONS **.*********** CIF£~AR AE~ TAE~ET STATION AZIMUTH LATITUDE SB~TION INCLN. ~-S ft deo Eeo ft 0,00 0,O0 0,00 0,00 -0+,5 0+31 59,55 0,05 -0.~ 0.55 4t,90 0,55 -0,66 0.52 57,08 1,10 -1,17 0.73 55,60 1,61 D~PARTURE DISPLAC~T at AZIMUTH ~-W ft ft deo 0,O0 0,00 0,00 0,08 0,09 59,55 0.64 0.84 49,45 1,28 1.68 49,35 2,10 2,65 52.51 OLS deo/ l(X)ft 0,00 0,89 0.28 0.16 0.24 517,46 610,69 689,03 778,72 ~78,70 90,6 517,44 93,2 610,66 78,3 689,00 89,7 776,69 100,0 -1,54 0,I2 73,07 1,94 2,69 3,32 54,15 O,6B -1.85 0,80 47,88.. 2,41 3,27 4,~, 53,61 0.74 -2.23 0.70 48.26 3,09 4,03 5,08 52,49 0,12 -2,67 0,79 48,97 3,~ 4,91 6,25 51,77 0,11 -3,26 0,74 ~,50 4,68 5,97 7,58 51,92 0.1~ 971 1069,83 1164,46 1258,10 1351 93,1 971,75 90,0 1069,~ 94,6 1164.,40 ~,6 1258,04 93,8 1~1,84 -3,82 0,68 53,71 5,34 6,92 8,73 52,35 0.08 -4.14 0,50 33,79 6,03 7,62 9,72 51,63 0.27 -4,16 0,59 ~,41 - 6,82 8,04 10.55 49,69 0,14 -4,06 0,~3 16,96 7,73 8,38 I1,40 47,30 O,Q6 -3,88 0,40 8.45 8,52 8.57 12,08 45,15 0,22 1447,76 1541.~ 1634.0~ 1727,64 1821.98 95,9 1447,69 93,5 1541,23 92,8 1~4,0I 93.6 1727,56 94,3 1821,69 -3,77 0,41 25,95 9,16 6,76 12,68 43,74 0,13 -3,71 0,37 15,53 9,75 8.99 13,26 42,68 -3,68 0,57 :30,05 10,44 9,30 13,98 41,71 0°24 -3.63 0.68 18,19 11,36 9,71 .14,95 40,50 O,1B -3.64 0,56 37.55 12,26 lO+16 15,93 39.65 0.25 1917,50. 2011.19 2107,67 2202,81 2298,34 95,5 1917,41 93+7 2011,10 96,5 2107,57 '~,1 22O2,70 ~.5 2298.23 -3,72 0,45 24.84 12,97 10.61 16,76 39,27 0,17 -3,71 0.59 26.59 13,73 10,97 17,58 38,63 0,15 -3,67 0.62 21,52 14,~ 11,~7 18,~6 37,84 0.05 -3,70 -0,86 S(2,59 15,74 11,96 19,76 37,23 0,30 -3,81 0,09 49,96 16,~' 12,40 20,55 37,11 0,82 ~93,01 2487,24 2f~1,67 2676,26 2771,91 94,7 2~2,90 94,2 2467,13 94,4 2581,56 94,6 2676,15 95,6 2771,79 -3,77 0,13 245,95 16.39 12,36 20,53 37,02 0,22 -3,69 0,09 217,20 16,29 12,22 20,36 36,87 0,07 -3,.A3 ' 0,18 1~,86 16.15 12,30 20,30 37,30 0.22 -4,02 0.0~ 160.~ 16,00 12.45 20,27 37,~ 0.13 -4,25 0.21 i~,76 15,88 12,63 20,29 38,51 0,17 2867,19 2961,29 3151,59 3246,17 95,3 2867,08 94,1 2961,17 95,1 3056,24 95,2 3151,47 94,6 3246,04 -4,76 0,49 149,01 15,47 13.01 20,21 40,05 0,37 -5,44 0,46 142,90 14,83 13,44 20,01 42,19 0,07 -6,19 0.61 152,83 14,07 13,90 19.78 44,66 0,19 -6,93 0,54 156,95 13,20 14,30 19,46 47,29 O,lO -7.72 0.69 151,85 12,28 14.73 19,17 50,18 0.18 3341.84 3437.24 3457.37 3557,76 ~52.50 95,7 3341,71 95,4 3437,10 20,1 .3457,23 100,4 3557,61 94,7 3652,33 -8,69 0,65 139,86 11.35 15,35 19,09 53,51 0,15 -9,71 0,73 147,70 10,42 16,03 19,12 56,96 0,13 -9,94 0,79 150,84 10,19 16,16 19,11 57,77 0,33 -11,28 0,94 137.65 8,98 17,O6 19,27 62,24 0,24 -12,55 0,97 163,66 7,63 17,80 19,37 66,80 0.45 , 3 MBAS~£D IET]~JAL V~ICAL I)£Pllq ]}EPTH 3746.71 94.2 3746,53 3843.26 ?6.5 3843,04 3938,46 95,2 3938,21 4032.98 94.5 4032.70 4127.85 94.9 4127.54 TARGE? STATI~ AZI~ LATIllJD£ SEC%IC~ INCH, N/-S -13.37 1,32 191.50 5.81 -13,56 1.48 210.4/:. 3.64 -13,.45 1,56 207.73 1,43 -13,15 1.44 219.55 -0.62 -11,99 1.65 246,95 -2.07 MPY,-17 DEPARTURE DISPLACEMBqT at AZIMUTH ft it deo 17.81 16.73 71,95 16,% 17.34 77.89 15,73 15,79 64,80 14.38 14.39 92.47 12,36 12,54 99,51 DLS deo/ lOOft 0,69 0.51 0,11 0,35 4221,03 93.2 4220.67 4315,93 94,9 4315,52 44~.53 93.6 4409,06 4504,90 95.4 4504,38 4600.35 95.4 4599.75 -9,81 1.83 268,07 -2,65 -6,77 2,14 280.25 - -2,38 -3,54 2+01 277,30 -1,86 -0,54 1,72 2?7,40 -0,99 2,97 2.63 314,65 1.21 9,64 10.00 105.34 0,71 6,38 6,81 110.46 0,55 3.03 3.56 121.54 0,I9 O.11 1,O0 173.74 0,74 -2.72 2.97 2?3.93 1.1~ 4655,18 94,8 4674,41 4789,78 94,6 4788,72 4885.37 95.6 4883.77 4979.45 94,1 4977.56 5072,96 93,5 5070,34 8.50 4.32 310.74 5.07 15.72 4,66 307,48 9,73 23,63 5,08 311,21 14.89 32.84 6,47 309,06 20,97 44,34 7,87 303.50 27,83 -6,97 6.62 306,00 1,79 -12.72 16,02 ~7.41 0,45 -18,99 24,13 308,09 0,55 -26,25 33.60 308,63 1,50 -35,66 45,25 307.95 1,67 5168.33 95,4 5164,59 5262,84 94,5 5257.46 5358.32 95,5 5350,67 5453,21 94.9 5442.79 5547.60 94,4 5534,05 58,81 9.66 2?9.79 35.41 76,28 11.69 300.56 44,22 96,96 13,3J 278.73 54.48 119.66 14,33 297,91 65.2? 143.77 15,27 297.59 76,51 -48,08 59,71 306,38 -63.20 77,13 394,98 -81,20 97,78 303.~, -101.18 120,41 302,83 -I22,52 144,45 301.98 2,15 1,81 1,04 1,00 5642;79 95.2 5625.48 5737,68 94,? 5715.75 5832,92 f5.2 5805.57 5s'?_7.98 95,1 5894.85 6021.18 ?3.2 5982.~ 170,24 17,03 295,96 ~,42 179.48 18,89 274,13 100.78 231.t0 19,93 2?3.78 113,63 263,71 20,25 2~.72 126.57, 296,49 20,?~ 2?4,47 139,76 -146.16 170,83 301,17 1,91 -172.67 17~,93 300,Z7 2,05 -201.59 231,41 299,41 1,I0 -Y31,57 263,91 296,66 0,46 -261.62 296,61 298,11 0,98 6115,86 94,7 6070.58 6210.69 94.8 6159;42 6305.77 95.1 6248.65 6401,27 95,5 6328,28- 6496.55 95.3 6427.61 330.11 20.64 294,14 153.61 363.27 20.32 295.20 167,46 3%.06 20,07 2?9,76 182,57 428.76 20.02 L;~5,88 197,66 462.22 21,11 274,11 211,~ -292.27 330,19 297.72 0,38 -322,43 363,33 297,45 0,52 -351,53 396.12 2?7.45 1,67 -380,46 428.84 297,48 1,39 -410,80 462.28 297,30 1,32 6590.19 93.6 6515.20 6684.2? 94.1 6603.71 6779,47 95.2 6693,64 6874,31 94,8 6783,40 6968,35 94,0 6872,26 495,20 20.25 291.15 224.72 527.05 19.42 294,02 236,97 558,20 18,83 2?3.66 249.58 560,83 18,88 2?5.54 262.33 619,58 19,30 295,24 275.52 -441,30 495,22 296,99 1,44 -470,78 527.06 296,72 1,36. -499,30 558,20 2?6,56 0.64 -527.17 588,82 2?6,46 0.64 -554.95 619.58 296,40 0,46 7062,3/... 94,0 6960,61 6S1,69 7157,23 94,9 7049.20 685,63 7252,07 94,8 7137,64 719,67 7347,29 ?5,2 7226.65 753,73 , 7483,03 135,7 7353,70 801,48 20,65 296.24 289,47 -583,87 21.28 2?6.3? 304.51 -614,30 21,05 2~,15 319,40 -M5,13 20,60 276,15 334.06 -675.65 20.60 296.10 355,09 -718,53 . .. 651,69 296,37 685,63 2?6,37 719.87 753,73 296,31 601,48 2?6,30 1,48 0,67 0.52 0,60 O,O0 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10728 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 1/23/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPC-25A JEWELRY LOG-GR/CCL 9 61 2 2 2 1 1 MPC-25A INJECTION PROFILE 9 61 2 2 2 I 1 MPC-25A WATER FLOW LOG-TDTP-GR/CCL 9 61 2 2 3 I 1 MPE-16 PERFORATING RECORD 9 61 2 2 9 1 1 MPE-16 PACKER DEPTH DETERMINATION 9 61 23 0 I 1 MPE-16 DEPTH CONTROL LOG-GR/CCI. 9 61 2 2 2 I 1 !MPE-16 CEMENT BOND LOG 961 222 1 1 MPU F-77 TUBING PUNCHING RECORD 9 61 21 0 I 1 MPU F-77 GRAVEL PACK LOG 9 61 21 7 I 1 MPU K-13 GR/CCL CORRELATION LOG 9 61 2 0 8 1 1 MPU K-13 PERFORATING RECORD 9 61 2 0 8 I 1 MPU K-13 STATIC PRESSURE/TEMP LOG 9 61 2 0 9 1 1 MPU K-13 PACKER SEI-I'ING RECORD 9 61 2 0 9 1 1 -- MPU K-17 SUMP PACKER SE'Fi'lNG RECORD 9 61 21 3 1 1 MPU K-17 PERFORATION RECORD 961 21 3 I 1 M P K-38 PERFORATION RECORD 9 61 2 01 1 1 MPK-38 PACKER SET RECORD 9 61 2 01 1 1 MPK-38 PERF RECORD 961 204 1 I oho c~, O%O PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by~~~ Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 29, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 ~ ._.~) ~,/8 ,~ 900 E. Benson Blvd.-- Anchorage, Alaska 99519-6612 ,) The following data of the cD~SJCDN, CDR/CDN 'rVD'S for well MPK-17 Job # 96105 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each .~-~ ............. State of Alaska Alaska Oil & Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive '------Anchorage, Alaska .-99501- 1 OH LIS Tape '"-.~ 1 Biueline each "--... ~ 1 RF Sep~ia_eackr----~ OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 464 .NOTE' NO DEPTH SHIFT PER MATT LINDER PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RECEIVED Date Deliver~EP 0 5 '1996 Reoei,ed .~,: Alaska Oil & Gas Cons. Commission ~c~ora~ HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 22 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION MPK-38 ~-e~0 MPK- 17 ff~- 0A~ MPK-37 ~'~7~ MPF-21 ~ - I J~' MPF-21 ~'{ ) )- /PFC/PERF FINAL BL+RF ~/PFC/PERF FINAL BL+RF ~ PLS FINAL BL+RF ~/PFC/PERF FINAL BL+RF I/ff/TEMP FINAL BL+RF ~SBT FINAL BL+RF MPF-02 ~ ' ¢~ 0 ~ GR/CCL FINAL BL+RF 6/i PFC/PERF FINAL BL+RF ~1 GR/CCL FINAL BL+RF ECC No. Run # 1 6638.03 Run # 1 6639.02 Run # 1 Run # 1 6729.01 Run # 1 6773.00 Run # 1 6773.01 Run # 1 Run # 1 Run # 1 6774.00 Received by: Please sign and return to: Attn. Rochney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 [ Or to ~ ~/~~ Date: RECEIVED AUG 30 1995 .... · .,:, ,, ,. .... ...,~?,~ Anch. or~ HOWARD OKLAN-D Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 July 1996 RE: Transmittal of Data Sent by: HAND CARRY WELL Dear Sir/Madam, Enclosed, please find the data as described below: ~ DESCRIPTION ~(.f '"0~ } MPK-02 ~(~ - 03~ MPK- 37 MP -7 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 SBT/GR FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6638.02 6639.01 6728.00 6729.00 6730.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FA/~ to (907) 563-7803 Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 19 April 1996 Transmittal of Data ECC #: 6639.00 Sent by: HAND CARRY Data: SBT/GR Dear Sir/Madam, Reference: MILNE POINT / SBP NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 (9o,) 563-78o3 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PoRcUPINE DRIVE ANCHORAGE AK, 99501. -. Date= 10 April 1996 RE= Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 SBT FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run # 1 6512.02 Run # 2 6630.01 Run $ 1 6639.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, /~K 99518 7) 563-7803 Date: 1996 AJaska Oil & Gas Cons. Commission Anchorage --_B.P. ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX'. (907) 276-7542 February 16, 1996 Tim Schofield, Senior Ddlling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPK-17 BP Exploration (Alaska), Inc. Permit No 96-028 Surf Loc 3648'NSL, 2100'WEL, Sec. 03, T12N, R11E, UM Btmhole Loc 4041'NSL, 2893'WEL, Sec. 03, T12N, R11E,UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contactin the Commission petroleum field inspector on the North Slope pager at 659-3607. David ChairmaJ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] RedrillE]llb. Type of well. Exploratoryl~ Stratigraphic Test [-1 Development Oil[] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE= 61 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. 0. Box 196612, Anchoraae. Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3648' NSL, 2100' WEL, SEC. 3, T12N, R11E ¢/J!nc Pc;',,,';f-b~,it At top of productive interval '8. Well number Number 3957' NSL, 2724' WEL, SEC. 3, T12N, R 11E MPK- 17 2S 100302630-277 At total depth 9. Approximate spud date Amount 4041' NSL, 2893' WEL, SEC. 3, T12N, R11E 02/20/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 028232 1239 feet Cascade lA, 73' @ 5550 feet 2560 7659'MD/7510' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 4soo feet Maximum hole angle2~.o8 ° Maximum surface 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement · Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ,.. 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3469' 31' 31' 3500' 3500' 691 sx PF 'E; 250 sx 'G; 250 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc & Mod B 7629' 30' 30' 7659' 7510' 237 Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface Intermediate Production FEB 0 6 ' 30'0 Liner Perforation depth measured ....... ¢ r.:,:m:-';, r',~.,-,'--`-.: ..... ' ~,..-, .,,.-....~,~ ~ true vertical /~';'.'~ '- 2(~. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certif~that the folegoing i$ J~rue and correct to the best of my knowledge _-~,1%'r.~ "/, .~.~' ~ Signed /~¢'q ~'~~:-'~' , Title Senior Drilling Engineer Date Commission Use Only 15'~rmit Number IAFt'F number~. Approvabdate See cover letter . ~'~¢'~'-~___--4~ 150-O,~'~ ~__.Z~'~'> ~_~.///(_,,/¢(~ for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg r~quir~d []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; ,I~5M; Fll0M; I-I15M; Other: ¢_,.-~r~¢.1 Signed By ,.,,,~,u .... by order of Approved by David W. Joh,,s,.,¢n Commissioner tne commission Date p'licate Form 10-401 Rev. 12-1-85 Submit Target Location: 393'/' FSL 2'/24' I~EL Sec 3 TI2N RI IE UM., AK. Bottom Hole 4041' FSL 2893' FEL Sec 3 T12N R11E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: 1337010 I I Rig: I..N. abors27E,. I I Estimated Start Date: February 20, 1996 Operating days to drill and case: 113 [ IuD: 17659' I I TVD: 17510' BKB [ I KBE: I61' [ IWell Design (conventional, slimhole, etc.): Ultra Slimhole, 7" Longstring Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1811 1811 n/a NA (Top Schrader) 4581 4581 1905 psig / 8.0 ppg OA 4701 1955 psig / 8.0 ppg Base Schrader Bluff 4796 4796 1995 psig / 8.0 ppg Top HRZ 6470 6401 n/a Base HRZ 6591 n/a Kupark D Shale 6888 6791 n/a Kuparuk C 7135 7021 3650 psig / 10 ppg TKB 7135 7056 3669 psig / 10 ppg Total Depth 7659 7510 n/a Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32' 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3469' 3 1' 3500/3500 8 1/2" 7" 26# L-80 Btrc & 5129 30' 7659/7510 Mod B 2500 N/A (tbg) 2-7/8" 6.5# L-80 EUE 6771' 2 9' 6800/7021 8rd Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. The Modified Buttress 7" 26# will be run on bottom. ~ ~ ..... ~ : ~ .... il '~ ? i~i~. !,-~) .[~ v. ,~.~-2- ~"~.c.,¢~ \ '! Logging Program: 3;3'0 l Open Hole Logs: Surface Intermediate Final Mud Logs: MWD ONLY MRIL Wireline logs in SB (Depths from geologist) LWD GR/Resistivity/SFC CSG to TD Neutron/Density over Kupamk intervals Mud logs and samples (as per AOGCC 20.25.071) were gathered in Cascade 1 & lA. We request this requirement be waived for K Pad wells AP1 # 50-029-22XXX February 5, 1996 to to to to to to to 9.6 100 35 15 30 10 15 Production Mud Properties: [LSND Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.5 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I goP: 14500' Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: 21.08 degrees < 4 degrees 21 Degrees See Traveling Cylinder report There is a close approach well for drilling MPK-17. Cascade IA is the only close approach well, and was drilled and abandoned. This well has cement plugs over the Kuparuk , and from 5100 to 4712, and a cement retainer at 2820. This will be treated as a plugged well This will allow MPK-17 wellpath to be drilled as per BP's close approach guidelines. The well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. AP1 # 50-029-22XXX February 5, 1996 pad/drillsit~ previously permitted for disposal 'ac~vities by AGOCC. 2. The Base of the Permafrost for all wells located in the Milne Point Unit is 1750 feet. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. 3. The receiving zone to which the fluids will migrate is identified as the Prince Creek geological formation at 2500 - 3300' TVD. The confining layer is the Sagavanirktok Shale defined by logs between 2500 'TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7-24-95. 4. There are no wells on Milne Point K Pad. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The drilling wastes to be disposed of during this operations can be defined as drilling mud, cement contaminated drilling mud, and drill cuttings; rig wash fluid (inclusive of rig boiler blow down, and mud and cement rinse water of associated rig equipment, completion fluids (seawater and brine), formation fluids, reserve pit fluids, and drill rig domestic waste water. (Note: if you plan to dispose of fluids OTHER than those outlined above you must list them on the request) The maximum volume to be disposed of in the annulus is 35,000 bbls. Fluid densities will range from 8.3 to 13.0 ppg. Any deviation from this program must be detailed separately. 6. The 9.625 "surface casing shoe will set at 3500'md 3500 ('tvd) and cemented with 691 "E" and 250 "G" sacks cement. This depth is below the base of the permafrost (1750' TVD) and into the top of the Prince Creek formation which has a long established history of annular pumping at Milne Point. The break down pressure of the Prince Creek formation is 13 to13.5 ppg equivalent mud weight. 7. The burst rating (80%) for the 9.625" 40# 'surface casing is4600 psi. The collapse rating (80%) for the7" 26# 'intermediate/production casing is 4325 psi. 8. The Maximum Allowable Surface Pressure while annular pumping is the lesser of 2000 psi or the calculated pressure according to the following equation: MASP (psi) = (Max Breakdown ppg-8.3 ppg) X 0.052 X Surf Csg Shoe TVD MASP (psi) = 855 psi 9. The maximum pressure imposed at the surface casing shoe is calculated according to the following equation: Max Press @ Surf Csg Shoe (psi) - .052 x Max Breakdown ppg x Surf Csg Shoe TVD Max Prss at Surf Csg Shoe =2457 psi This pressure is less than the 80% burst and collapse casing pressures calculated in #7. 1 0. Additional data supplied as needed. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (aBE) VOL (BBL) Milne Point MPK-1 7 0 35,000 I Requested FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. AP1 # 50-029-22XXX February 5, 1996 I,.U.,,,,L ~,..ilt,,,Ul ,LI~.)il. I II..,,. ixulJ,,...lU,,, ,..,,~...IIU,,.. ,,.,.IIL,I f,.;. IIMIIIL)'~,..I VI ,..,.il~,.'.llVvv'r,.,.I IIIL~,,.,'i v~J.i,~.? ~.$~..~.J~.,~,~ _~ ,,,~.;,, j fractured. Wells on F Pad have lost varying amounts of mud (from 70 to 1000 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 97.5 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3594 psi @ 7200' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. Several wells from F pad have exhibited "breathing" of mud, alternating loss and flow back of uncontaminated muds volume. No oil, gas, or other formation fluid influx have been confirmed even when large fluid influx have been measured. In spite of this we will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. When this occurs, the drilling superintendent should always be quickly notified and kept appraised. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. AP1 # 50-029-22XXX February 5, 1996 3. MIRU Nabors 27E drilling rig. . NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. 5. Drill 12-1/4" surface hole to 3500' md (3500' tvd).. Run and cement 9-5/8" casing. 8. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. , RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well t-de. Follow Pad Data Sheet short trip guidelines. 10. Drill 8-1/2" hole to Base of Schrader Bluff at 5000' MD (4998' TVD). POOH to run MRIL wireline logs. 11. Drill 8-1/2" hole to TD at 7659' MD (7510' TVD). (Note: This hole section will be logged with LWD Triple Combo (GR/Res/Neu/Dens). 12. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing with 1 stage cement program. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. Make sure there is a circulating head for the topdrive before starting to run casing. 13. ND BOPE and NU dry hole tree. Release rig to MPK-25 Note: This well will be ROPE perforated, and cleaned out with a completion rig and prior to running the ESP completion. 14. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. 15. PU and RIH with 3.5" DP and 6" bit, clean out to PBTD. TOOH. 16. PU and RIH with ROPE perforating string (procedure to be distributed later with perforation intervals). 17. PU and RIH with 2-7/8" EUE 8rd tubing with Electric Submersible Pump (ESP) completion. 18. 17. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. POST RIG WORK . Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. . A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. , An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. . The rig will not complete this well. PEs will perforate and clean out this well with a pulling unit. AP1 # 50-029-22XXX February 5, 1996 BPF+100% i 0.1116 ................................. ~!~ ............................... BBLS Cu. Ft. Sacks Top of Cemenl S h o e D e p t h !.i.~.!.i.~!.~:.i.!.;i !i;!!!~i~!~,i~ii~i:i!i~ili~ii~ii~ii~:?:i i C a lc u la t e d G Tail Volume 623 51.2 i 288 j 250 287~7 E Lead Volume~ 1500 167.3 940 433 1377 E Tail Volume 1377 99.8 561 258 0 I , Total E 691 Total G I 2 5 0 9-5/8" Bows I 0 ~ I Production 1-Stage Cement Job t , i I Cement Yield Hole Size ' 8.5 Silicalite Slurry 2.81 Casing Size 7 BPF , 0.0226 BPF + 30% I 0.0294 I I Top of Cemenl Stage 1 BBLS Cu. Ft. Sacks Calculated Formation Top iiii~ii~i~i!ii';iii~'~ilil;;iiiiiiii::iiiiiii!i~i~i~i 11 9 668 238 4000 Centralizers J 1 78 Turbulators ~ I ~ _ I I I I i , i i Total G ST1 I i Total ST Blade~ 1 79 I , Page 2 LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS' 691 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES- 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc YIELD:I.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. Casing has been stuck while we were shut down filling only 5 joints. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. · .-~ ..... . '.:~ ~- .~ _: !~ AP1 # 50-029-22XXX February 5, 1996 ~.[-_,ax~,..,s2~lx: .~U uul6 ll~bH Wctt~t . 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.3% CFR-3, 30#/SK Silicalite, 1.7% Halad 344 WEIGHT: 12.25 ppg YIELD: 2.81 cu ft/sk APPROX # SACKS: 237 FLUID LOSS: < 45cc/30 min @ 140° F MIX WATER: 16 gal/sk THICKENING TIME: 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casing (34 total). This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6900' - 6100' to cover the Schrader Bluffs Sands (20Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4" Straight Blade Rigid Centralizers needed is 55. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Top with 30% excess. API # 50-029-22XXX February 5, 1996 ~FACER: 30 bbls /resh water . 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.3% CFR-3, 30#/SK Silicalite, 1.7% Halad 344 WEIGHT: 12.25 ppg YIELD: 2.81 cu ft/sk MIX WATER: 16 gal/sk APPROX # SACKS: 237 THICKENING TIME: 4 1/2 hrs @ 140° F FLUID LOSS: < 45cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casing (34 total). This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6900' - 6100' to cover the Schrader Bluffs Sands (20Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4" Straight Blade Rigid Centralizers needed is 55. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Top with 30% excess. AP1 # 50-029-22XXX February 5, 1996 0- 50) '311 ~0£ 5874 "l VERTICAL VIEW SCALE 500 ft. / DIVISION TVD RED': WELLEIEAD VERTICAL SECTION REF: WELLHEAD 1 0.00' @ 0 MD TIE IN 0,00° 8 I000 MD 901 800 0.00' @ 1811 MD Base PerF~aFrost 9 5/8 in OD, ~ 2500 MD, 2500 'r'~ I I 700 600 500 400 300 P00 ! O0 0 l O0 CRITICAL POINT DATA MD Inc AzI, TVD N/S E/W TIE IN 0 0,00' 896,48' 0 0 N 0 E Bose 1811 O, 00' 296, 48' 1811 0 N 0 E Per?moPro;t KIDP / .RTART 4500 0,00' 296.48' 4500 0 N O E L]F DUI L D @ 1.50'/100 ?t NA Sands 4581 1,22' 296,48' 4501 0 N I ~ Bose Schroder 4796 4,44' 296,48' 4796 5 N 10 W END OF BUILD 5905 21,08' 296,48' 5874 114 N 229 W THRZ 6470 21,08' 296,48' 6401 205 N 411 W TKUD 6888 21,08' 296, 48' 6791 272 N 545 W K-B / TKUCI 7135 21,08' 296.48' 7021 31~ N 625 W CASING POINT DATA fid MD lnc Azt TVD N/S E/W 9 5/8 in 8500 0.00' 0,00' 2500 0 N 0 E TocDe% Nome TVD NS EW Grid X Grid Y K-B 7021 311N 625 W 58~828 6006086 0.00° @ 4500 MD KOP / START OF BUILD ~ 1.50'/100 Pt 1,22' @ 4581 MD NA Sonds 3,00' 8 4700 MD 4.44' @ 4796 MD B~se ~chr~der 6.00' @ 4900 MD 7, 50' ~ 5000 MD 9.00' ~ 5100 MD ~ ~0,50' ~ 5200 MD ~ 1~,00' 8 5300 MD ~ ~3,50' ~ 5400 MD ~!5,00o ~ 55O0 MD ~ 16.50' @ 5600 MD ~8.00' e 5700 MD 111,% 256 ~0 --~59~ -~1, 08' 8 6470 Mil I'HRZ 609_ ~21.08' e 6888 MD TKUD - ~-~- -~21.08' 8 7135 MD K-B / TKUCI 778 ~k81.08' 8 7359 MD ~11 R1,08' ~ 7659 MD 886 7 ~ OD, ~ 7~59 MD, 7510 TVD I I I -500 0 500 1000 VERTICAL SECTION PLANE: 896.48" PROPOSED BHL TVD 7500.93 MD 7658.74 VS 886.22 N~ 895,10 N E/W 703.27 W Dote Pro'Ired ; 1129/96 Creoted By Checked By Approved By Date , HaHib~on Energy Services - DrYing Systems PSL Propo~ Report Sunv, y ~: W~XJ. HEAD ~ct ~V~M O~o~d~c~ Lat 70.25.33 lq _ l~m§. i~9.18,42 TV ~ G'~,ID System: Alaslkn Sbic PlancZos~cc Alaska 4 Refm~r~mc GRID Oooniinalcs: (f0c 61RD782.0014 564456.~0 E Phmh Aligned'fo: TRIJE NORTH Con~ ~rs~g WTN-CADD~ REV2. I.B Venk~ Se=l~n Plane: 2~6A8 d~ BPX-Ehmed ~es l~illing A1ad~ Sta~ Plam~: Zone4 ]~nc FI: MPK MPK-17 l~t MPK-17 Wpl Cb3mm ¥~ Ba/Id Walk DI~ ~ ExlmcmdToml }.lax Hnr Min ~ IXst. Dic Socl~on ga~c Rate Dogleg Bctta~gular Cmnda Etmr F~, (#) (dcg.) (it) (dg/lOO~) (dl~lOOfO (dg/l~) (ecg) (fl) (fl) (It) (fl TO~h'q 0.00 (L00 0~0 -61~0 0_00 0J}0 0.(iON 1000_00 0.OO 0.00 939.00 1000.00 1000.00 O. OON 1811.00 {kll0 0.00 1750.00 1811.1}0 811.00 O.~ON (LOOE 6iRD782.01 5~P1~6.~0 0.00B' 6(RD78Z01 5844~6.0D O.OOE 60(b*'782.01 0.(]C4P 0J}0 0~0 GOO 0.(]O 0.00 0.(}C~ 0.00 0.00 0.O0 0.QO 0.00 0J} ~00N 0.00E 3.17 0_(ICO (LOO 0JR) GOO 0.(I0 0JR) 0.0 0.00N 0.~0E 5.00 5. CASINGPOIWI' OD=95/Sin. ID=8.84im, Weight=40.001bfl~ 2500.fl0 0_00 0.O0 2439.00 25~0.00 ~89.1}0 0.OON KOP I.%'TART OF BUILD ~ !.50 d~[p'100 4500.100 (LOO 0.00 4439.00 45~0~ 2000.00 O.(iON 4581.01 1.22 296.48 4520.00 4581.00 81.0t (LOOB 60(~.01 5844~6.OO 0.OOE 60(i~.01 58445'6.(]0 (LT'AV 6OO57~ 584455.23 0.(lC~ 0.O0 0.O0 (L00 0.(]0 0.00 0J} 0.00N 0~0E 0.00 0.0C~ (L00 (LO0 (L00 0.(}0 0.00 (LO 0.00N 0.00E 11.79 l 0.~29~48 0.86 1.50 0~GO 1.50 1.2 0_38N 0_77~ 12.00 1: 4600.00 1.50 2~6.48 4538.99 4~J9.99 18-99 0.58N 4700.OO 3.O0 2~6A8 46~HL91 4699.91 100.00 2.33N Ba~ $¢hmd~ 4796.~ ~.44 296.48 4735.OO 4796.00 96.30 5.12,N 1_17~ 6OO5'782, .~B 4.6';W 6065'7R4.29 S~t.51.29 131~296.4S !.31 1.51} 0.(]0 1.50 1_5 0.58N 1.17W 12.05 5~3~296A8 5.23 1.50 0.(]0 1.50 3.0 7~32N .4.6~N IZ31 IO. 2L~ 6OO5787.01 584445.46 1 i.4~296A8 11.49 i.50 0.00 1.50 &4 5.08N 10..~ 12.57 1,~ 41i00.00 4.50 2~6.48 4738.69 4799.69 3.70 $.251q 10.SqW 6005787.14 5tM445.40 II.T~296.48 Il.T/ 4g00.00 6.00 296.48 4938.27 4899.27 100.00 9.33N 18.7'3W 6005791.12 5~MM.17 20.9~2~296A8 20.92 5000.00 7-50 2~6.48 4937.57 4998.57 100.00 i4.57N 29.25W' 6005796.24 584426.59 32.~2.,q6.48 ~2-68 !.50 0.00 1.50 0.00 i.50 0.00 1.50 4.5 5.20N 10.STAY 12.58 !-', 1.50 6.0 9~23N 18.TL~V 12.8~ 1: LS0 7.5 14.39N 29.34W 13.16 5100.00 9.OO 2~A8 5036.54 5097.54 100.00 20.97N 42.0~'W 60(}5802.49 584413.67 47.03~29&48 47.0~ 5200.00 10.50 296.48 5135J}9 519K09 100.00 28.52N 57.2~W 6005609_8'7 5843~.43 63__~(~(~2.q~48 63.96 MOO. OO 12.OO Z96.48 5233.16 5Z94.16 100.00 37.21N 74.'~/' 600~18.37 584380_67 83.4~2,96.~ 83.47 1-50 1.~1) i.S0 0.00 0~0 0.00 1.51) 9.0 20.(~6N 4Z25W 13.46 1: 1.50 10.5 23.05N 57.48W 13.85 1~ 1.50 12.0 36.5¢N 75.05W 14.Z6 !: !-50 1.50 1.50 0.00 0..0o O.O0 !-50 13.5 46.11N 94,94W 14.73 1.50 15.0 56.76N I !?. 14t~V 15.28 !'_ 1.50 16.5 641A6N 141.6,~V 15.92 1, 57110.00 18,.OO Z96AB 5619.36 568036 100.00 83.35N 167.34W' 6005863.4.~ 5~42B7.74 186.95@296.48 1116.95 5800.00 19-50 Z96.48 5714J)5 5775.05 1O0J}O 97.68N 196.11W 6005877.45 5942~8.81 219.0~296.48 219_09 1.50 - 0.00 1.50 0.OO 1.50 18.0 81.22N 16&4CW 16.6~ !,- 1.50 19.5 95.00N 197.45W 17.50 I, Hnlliburlon Energy Services - Drilling Systems PSL Propo.~! Report l~l~smod lncl Drift Sul~a TVD Comsc T O T A L GRID Coo~dina~s C[o~rc Vertical Bui~ %Vnlk DLS Cum. Expec~ ToOd Max Hot Deplb Dir. De~lh lgng~h Recla~g~larO~ Noflhing ~zling Dist. IXr. Secfioo Ralg l~lc Dogh~ R~ctm~iarCoo~d~ Error Far (ft) (~g.) (~g.) (1t) (fi) (h) (It) (l~) (it) (n) (fi) (deg.) (fi.) (dg/lO01t) (dg/100t~) (dg/100l'0 (dcg) 0t) (It) (1~) 5900.00 21.~0 296.4~ 5807.86 5864t.86 100.00 113. lIN 2Lr/.I~V 6005892.53 584227.66 253.7K(~296.48 253.70 1.50 O.00 1-50 21,0 109.80N 228,74W' 18.45 i, END OF BUILD 5905.23 21.08 296.48 5812.'74 5873.74 5.23 !!3.95N 228,77W 6005893.35 584225.97 255.~296.48 255..58 1,50 O.(iO 1.50 21,1 IIO,61N 230.44W 18,52 I, TI~'~ 6470.29 21.08 296.48 6340.00 6401.00 565.07 204.55N 410.61~II/ 6005~81.89 584043.07 455.~2.96,45 458.80 0.00 O.(lO 0.~']0 21.1 19cL63[~ 414.13~¥' 24.93 ItS TKUD 688;8.26 21.08 296.48 6730.00 6791.t]0 417.97 271.56N 545,24W 6006047.38 583907.711 609.12~296,41~ 609.12 K-B/TKUCI 7134.75 21.08 296.48 6960.00 7021.00 2d6.49 311.09N 624,5SW 6006086.00 583828.(}0 697.7'~Z96.45 6D7.77 7358.74 21.08 296.48 7169.00 7230.00 7.23.99 347.00N 69&,TCW 6006121.10 583755.50 7'/8-33~296.4S 778.33 0.00 ~ 0.00 0.~!0 0.00 21.1 262.00N 550.0CW ~;).2~ I'. 0.00 21.1 299.96N 6_qO. 13W 33.54 0.00 21.1 334.46N 702.94W 36.56 7658.74 21.08 296.48 7448.93 7509.93 300,00 39.5.10N 793.27W' 6006168.11 583658,40 886.22~296.48 886.22 0.00 O. t30 0.00 21.1 3~1)_66N 800.4'/W 40.68 20 700 400 ~550 275O ~0 180 2t0 150 I~_LLS C~:-~A CASCAI)E-Ol ~K-~ Wp~ STATUS SHUT-IN sFLrl'-IN FLDWING CLOSEST PUIN-rS Slot ]~stonce I)irec~io~ ReP MD ReP TVD Sep. F:c'ko¢ 5536.83 ' 0,70 ,'1899.27 31,60 O,DO ..... ..,59,0-0 CASCADE- CASCADE-OI 72,93 348.51 5550,00 1326,81 106.04 4900,00 _59,62 t57.g5 0,00 D~te ~o~ed , C~e~ed By Checked By ; Approved ]3y ' N/$ ~'~d ~-/~ ~'~ ~llr~d fi. om ~ W~LLH~ Ali Di~ions u~ing ~P Hi~sid~ M~o~ ~ D~.D~, All De~ ~d Dis~ ~e in FE~T All ~~ ~ ~n E~E~ED Po~i~ons Close Approach Status off'set Flowing Zone Plowing Shut-in Well $~)' Min, Sa~o~ Sdoty Shut-in Clear Spr~i MD TVD D/st Dist Zone CASCADE-IA -96.6 -47,7 ~qS0 5537 62,7 13,9 CASCADE-01 1225.2 1272.3 4950 4949 59.5 12.4 M:PK-25 WpI 15,? 43.7 2000 2000 30.0 5.0 l~nt~r Er, i~ F, xit Dmlsor Danger Shut-in Zone Zone Zone MD MD MI) 5450 5750 58~0 Clo~ Approach DANGER OK OK N/$ nd ~ ar~ measured from the Wi~,bl.,liltl~ TVD ~ me~ ~om ~c In~c~ Szcp Dcp~ 50.00 fl.~) From 0.00 To 7658.74 ~(MD) ~ D~fions us~ BP ~g~ide Me~ ~ D~.Deg. All ~s ~ Di~ ~c ~ FE~ All ~~ ~o ~n E~E~D Positio~ Closest Points Slot W~llpata Distan~ Direction CASCADE-lA CASCADI~-IA 72.93 34i.51 5550.~ CASC~01 C~C~I 1326.81 106.~ 4900.~ 1434.83 115.14 ~550.00 ~K-25 ~t ~K.25 Wpl 59,62 157.95 0.00 61.33 159.25 2100,00 Roi'MD Rcf TVD Sop Facu~r 5536.83 0.? 4899.27 31.6 ~36.83 27.~ 0,00 59,6 2100,00 5.4 WELL PERMIT CHECKLIST COMPANY ~/ WELL NAME /~f~-' / 7 PROGRAM] exp [] dev.. redrll [] s err [] we 1 lbo ? ADMINISTRATION ENGINEERING REMARKS 1. Permit ................... Y~ N ~ ' ~ , 2. Lease numberfee attachedappropriate ............... ~. N ./.~C~ ,,~/~//, /_~ .~~~ Unique well name and n~ber .............. ~N ~ ~" 4. Well located in a defi~ed pool ............. ~ N ~~.~ ~/~ ~ Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ...... .~. 9. 10. 11. 12. 13. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Operator only affected party· .......... in force. Operator has appropriate bond ....... conservation order. Permit can be issued without .'.'. can be issued without Permi t administrative approval. 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf cng..~ N 17. CMT vol adequate to tie-in long string to surf cng . . ~ N 18. CMT will cover all known productive horizons......~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~O~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... .Y ~J~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measure 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . [exploratory only] GEOLOGY_: ENGINEERING: COMMISSION: Comments/Instructions: HOW/lib - A:~FORMSlcheklist rev 11/95 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. R .CE VEO * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAME : MPK- 17 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22647-00 REFERENCE NO : 96105 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 16:28 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/20 ORIGIN : FLIC REEL NAME : 96105 CONTINUATION # : PREVIOUS REEL : CO~4MENT : B.P. EXPLORATION, MILNE POINT MPK-17, API #50-029-22647-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/20 ORIGIN : FLIC TAPE NAME : 96105 CONTINUATION # : 1 PREVIOUS TAPE : COI~4FJ~f : B.P. EXPLORATION, MILNE POINT MPK-17, API #50-029-22647-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API AUJM~ER : OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS '. SURFACE LOCATION BIT RUN 1 SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPK- 17 500292264700 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 20-AUG-96 BIT RUN 2 96105 RUMINER/DENN TOM I. BIT RUN 3 3 12N liE 3648 2100 61.89 60.89 28.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 3508.0 LIS Tape verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 16:28 3RD STRING PRODUCTION STRING Well drilled 05-MAR through 15-MAR-95 with CDR/CDN. Well was logged in two bit runs, however the tool failed after run one and no data was recovered. The data on this tape is only from bit run two. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION ' O01CO1 DATE · 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NLrM~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 3406.0 7482.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: No depth adjustments were made as per Matt Linder. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 16:28 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630363 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~ 630363 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~ 630363 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD Otff4~630363 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD Oh?4Iq630363 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OI4F~I630363 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630363 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630363 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630363 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 630363 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO MWD G/C3 630363 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630363 O0 000 O0 0 1 1 1 4 68 0000000000 CALN MWD IN 630363 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI MWD PU-S 630363 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7482.000 RA.MWD -999.250 RP.MWD -999.250 VRA.~FD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 77.293 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 3406.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD 20-AUG-1996 16:28 -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD 48.8O0 -999.250 -999.250 -999.250 VRA . FET.MWD PEF. MWD PAGE: -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE StC4~RY VENDOR TOOL CODE START DEPTH MWD 3406.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : STOP DEPTH 7482.0 15-MAY-96 FAST2.5 4.0 MEMORY 7483.0 3406.0 7483.0 60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 16:28 PAGE: HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 0.8 21.3 TOOL NUMBER ........... RGS751 NDS055 8.500 3508.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S) : 49.0 MUD PH: MUD CHLORIDES (PPM) : 1400 FLUID LOSS (C3): 3.6 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 761 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 495 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ***RUN 1 - CDR ONLY 112'-3529'*** NO DATA AVAILABLE DUE TO TOOL FAILURE ***RUN 2 - CDR/CDN 3529'-7483'*** Rm=l. 761@60 DEG, Rmf=l. 495@60 DEG RES TO BIT: 64.32'; GR TO BIT: 74.74' DEN TO BIT: 119.48'; NEUT TO BIT: 126.46' WELL TD'D AT 1400 14-MAY-96 MAX DEVIATION 21.28 DEG AT 7157' $ LIS FORMAT DATA 60.0 60.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 16:28 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API- API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630363 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW2 OH~q630363 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW2 OH~q630363 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW2 0HI4~630363 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW2 F/HR 630363 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW2 HR 630363 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW2 GAPI 630363 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW2 G/C3 630363 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW2 G/C3 630363 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LW2 BN/E 630363 O0 000 O0 0 2 1 1 4 68 0000000000 CALNLW2 IN 630363 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LW2 PU 630363 O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW2 630363 00 000 O0 0 2 1 1 4 68 0000000000 DPHI LW2 PU 630363 O0 000 O0 0 2 1 1 4 68 0000000000 DCAL LW2 IN 630363 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7482.500 ATR.LW2 -999.250 PSR.LW2 -999.250 DER.LW2 ROPE. LW2 -999.250 TABR.LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO. LW2 -999. 250 PEF. LW2 -999. 250 CALN. LW2 -999. 250 TNPH. LW2 TABD.LW2 -999.250 DPHI.LW2 -999.250 DCAL.LW2 -999.250 -999.250 -999.250 -999.250 LIS Tape verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 16:28 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME '. EDIT DATE '. 96/08/20 ORIGIN '. FLIC TAPE NAME : 96105 CONTINUATION # : 1 PREVIOUS TAPE : CO~94~NT : B.P. EXPLORATION, MILNE POINT MPK-17, API #50-029-22647-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE '. 96/08/20 ORIGIN : FLIC REEL NA~ : 96105 CONTINUATION # PREVIOUS REEL COf~4~NT : B.P. EXPLORATION, MILNE POINT MPK-17, API #50-029-22647-00 MPK- 17 MILNE POINT // Run 1' 07 - July - 1996 GR/CCL Marked Line 7360' WESTERN ATLAS Logging Services Tape Subfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MPK - 17 500292264700 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 29-JUL-96 6639.01 B. ESARY O'MALLEY 3 12N liE 3648 2100 61.89 60.89 28.70 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 20.000 115.0 91.10 9.625 3508.0 40.00 7.000 4946.0 29.00 7.000 7463.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GR 1 1 07-JUL-96 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: GR/CCL Marked Line. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** *** NOTE: THERE WAS A PREVIOUS MARKED LINE GR RUN WITH AN SBT ON 31-MAR-96 FROM 4245-7330'. THIS CURRENT MARKED LINE GR REPLACES THE 31-MAR-96 MARKED LINE GR PER LARRY VENDL AT BP. SHIFT PROCEDURE AS FOLLOWS: 1) SECONb PASS GAMMA RAY DEPTH MATCH..~ TO FIRST PASS GAMMA RAY. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 35.0 7360.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS · · EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPK - 17 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 116 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 35.000000 7365.000000 0.500000 Tape File Depth Unxts = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29323 datums Tape Subfile: 2 212 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 7040.0 7360.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 7176.0 7176.0 7176.5 7176.5 7177.5 7177.0 7182.0 7181.5 7199.5 7199.5 7208.5 7208.5 7341.5 7341.0 7355.0 7355.0 7355.5 7355.5 REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS). / ? ?MATCH2A. OUT $ CN : BP EXPLORATION WN : MPK - 17 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth'ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 1022 BYTES * Tape File Start Depth = 7035.000000 Tape File End Depth = 7365.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1323 datums Tape Subfile: 3 46 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile-4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 35.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 7372.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PCM PULSE CODE MODULATOR CCL CASING COLLAR LOC. GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-JUL-96 FSYS REV. J001 VER. 1.1 2153 07-JUL-96 7376.0 7362.0 35.0 7360.0 3600.0 YES TOOL NUMBER 8250XA 8248XA 8262XA 0.000 7463.0 0.0 BRINE/DIESEL CAP 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZi~G WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1 (MAIN PASS) . $ CN : BP EXPLORATION WN : MPK - 17 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 1 1 F/MN 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 587 Tape File Start Depth = 35.000000 Tape File End Depth = 7370.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 176029 datums Tape Subfile: 4 661' records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7040.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 7372.0 TOOL.STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PCM PULSE CODE MODULATOR CCL CASING COLLAR LOC. GR GAMMARAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-JUL-96 FSYS REV. J001 VER. 1.1 2137 07-JUL-96 7376.0 7362.0 35.0 7360.0 2100.0 YES TOOL NUMBER 8250XA 8248XA 8262XA 0.000 7463.0 0.0 BRINE/DIESEL CAP 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZi~G WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2 (REPEAT PASS) . $ CN : BP EXPLORATION WN : MPK - 17 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 27 Tape File Start Depth = 7040.000000 Tape File End Depth = 7370.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7929 datums Tape Subfile: 5 101 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 6 is type: LIS 96/ 8/ 1 01 **** REEL TRAILER **** 96/ 8/ 1 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 1 AUG 96 l:14p Elapsed execution time = 16.92 seconds. SYSTEM RETURN CODE = 0