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Home My WebLink About209-134MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 21, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-24A MILNE PT UNIT C-24A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2025 C-24A 50-029-23020-01-00 209-134-0 W SPT 6424 2091340 1606 2585 2585 2580 2581 733 859 862 868 INITAL P Josh Hunt 5/29/2025 This well was just converted to a WAG well. Solid test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT C-24A Inspection Date: Tubing OA Packer Depth 677 1758 1709 1697IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250529110019 BBL Pumped:1 BBL Returned:1 Monday, July 21, 2025 Page 1 of 1            Sundry 325-191 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable MPC-24A (PTD# 2091340) - Conversion to WAG Injector Date:Tuesday, May 20, 2025 10:14:08 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, May 20, 2025 9:38 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Operable MPC-24A (PTD# 2091340) - Conversion to WAG Injector Mr. Wallace, PAL well MPC-24A (PTD# 2091340) has been converted to a WAG injector per sundry #325-191, and obtained a passing MIT-T, MIT-IA & CMIT-TxIA to 3000 psi in March 2025. The well has been re-classified to an Operable WAG well and will be brought on injection. An AOGCC witnessed MIT-IA will be performed within 10 days of injection per the sundry. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable MPC-24A (PTD# 2091340) - Conversion to WAG Injector Date:Tuesday, May 20, 2025 10:14:08 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, May 20, 2025 9:38 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Operable MPC-24A (PTD# 2091340) - Conversion to WAG Injector Mr. Wallace, PAL well MPC-24A (PTD# 2091340) has been converted to a WAG injector per sundry #325-191, and obtained a passing MIT-T, MIT-IA & CMIT-TxIA to 3000 psi in March 2025. The well has been re-classified to an Operable WAG well and will be brought on injection. An AOGCC witnessed MIT-IA will be performed within 10 days of injection per the sundry. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025022 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 14B 50133205390200 222057 4/10/2025 AK E-LINE CBL BRU 241-23 50283201910000 223061 4/7/2025 AK E-LINE Perf BRU 241-26 50283201970000 224068 4/12/2025 AK E-LINE CIBP BRU 244-27 50283201850000 222038 4/8/2025 AK E-LINE Perf MPU B-21 50029215350000 186023 4/7/2025 AK E-LINE LDL MPU C-24A 50029230200100 209134 4/6/2025 AK E-LINE CBL MPU J-25 50029232070000 204073 4/5/2025 AK E-LINE JetCut NCIU A-21 50883201990000 224086 4/4/2025 AK E-LINE Perf NCIU A-18 50883201890000 223033 4/5/2025 AK E-LINE Perf PBU Z-235 50029237600000 223055 4/1/2025 READ InjectiojnProfile HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL HVB 18 50231201210000 225001 4/4/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40328 T40329 T40330 T40331 T40332 T40333 T40334 T40335 T40336 T40337 T40338 T40339 MPU C-24A 50029230200100 209134 4/6/2025 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:42:09 -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: Convert to Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,580'NA Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 7,500psi Liner 10,540psi Liner N/A Liner N/A 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: 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 Erik Nelson Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025516, ADL0047434, ADL0047437 209-134 C.O. 432E MILNE PT UNIT C-24A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23020-01-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 6,991' 10,551' 6,993'899 KUPARUK RIVER OIL Same 113' 113' 9.2 / L-80 / TC-II TVD Burst 6,801' 10,160psi MD N/A 8,430psi 5,750psi 7,240psi 4,609' 6,580' 6,893' 5,057' 7,679' 9-5/8" 7" 5,057' 4-1/2"546' 7,679' 907-564-5277 erik.nelson@hilcorp.com Operations Manager April 1, 2025 10,564'2,167' 3-1/2" 6,992' Perforation Depth MD (ft): See Schematic 7” x 3-1/2” HES ‘TNT’ & 7” x 4-1/2” Baker ‘ZXP’ and N/A 6,696 MD / 5,860 TVD & 7,494' MD / 6,424 TVD and N/A NA 7,657' 8,040' 55' 2-7/8" See Schematic MILNE POINT 740' 3-3/16" 8,397' 7,050' N/A 6,561'3-1/2" 113' 20" Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:13 pm, Apr 01, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.04.01 07:46:04 - 08'00' Taylor Wellman (2143) 325-191 10-404 SFD 4/4/2025 DSR-4/2/25 Apr 01, 2025 MGR18APR25 CDW 04/14/2025 AOGCC witnessed MITIA to be completed after injection begins and well stabilizes (within 10 days). X April 1, 2025 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.18 18:36:55 -08'00'4/18/25 RBDMS JSB 042125 ®ôīīϙbÍıôϡ aϙϱ͓͑IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͑͒͏͑͏ϱ͏͐ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ Iϙ@[ϙŘĺî ĖČϡ bĺĲϱĖČ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͏͖ϙaÍŘϙ͑͏͔͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͑ϙ"ÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͑͏͘ϱ͓͐͒ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ċŘĺıϟFϟŜŪŘŽôƅϟ͗͛ϟŪČϟ͕͗͗͘ ͔͓͐͗ϙŕŜĖϙЬϙ͖͕͗͘ϱċťϙa"ϙϼ͕͓͕͗ϱċťϙ«"Ͻ ͕͑ϙŪČϙ͑͏͑͒ϙиϙ͓ϟ͒ϙ(a®ϙϼ͗ϟ͔ϙX®>Ͻ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͗͘͘ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϙϼŘôīôŽÍĲťϙťĺϙſôīīſĺŘħϽϡ ͔͕ϟ͒еϙЬϙ͕͔͓͔ϱċťϙa" aÍƄϙ"ĺČīôČϙϼŘôīôŽÍĲťϙťĺϙſôīīſĺŘħϽϡ ͔ϟ͓еϯ͐͏͏ϱċťϙЬϙ͕͓͔͐ϱċťϙa" aĖĲϙI"ϙϼŘôīôŽÍĲťϙťĺϙſôīīſĺŘħϽϡ ͑ϟ͖͔͏ϱĖĲϙI"ϙĖĲϙ͒ϱΫЋϙ³bϱĲĖŕŕīôϙÍťϙ͕͖͖͗ϱċťϙa" ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙϱ͓͑ϙſÍŜϙîŘĖīīôîϙÍĲîϙèĺıŕīôťôîϙæƅϙbÍæĺŘŜϙ͑͑(ϙÍĲîϙbÍæĺŘŜϙ͓(ϙŘôŜŕôèťĖŽôīƅϙĖĲϙ͑͏͏͐ϟϙϙēôϙſôīīϙ ŕŘĺîŪèôîϙĺĲϙ(ϙŪĲťĖīϙbĺŘîĖèϙ͑ϙŕôŘċĺŘıôîϙÍϙ"ϙŜĖîôťŘÍèħϙĖĲϙ͑͏͐͏ϟϙϙēôϙſôīīϙſÍŜϙŘôϱèĺıŕīôťôîϙÍŜϙÍĲϙ(ϙ ŕŘĺîŪèôŘϙÍĲîϙŘÍĲϙŪĲťĖīϙ"ĺƅĺĲϙ͕͐ϙŘôϱèĺıŕīôťôîϙťēôϙſôīīϙÍŜϙÍϙ@[ϙŕŘĺîŪèôŘϙĖĲϙ͑͏͐͑ϟϙϙIťϙèĺĲťĖĲŪôîϙ ŕŘĺæīôıÍťĖèϠϙĖĲťôŘıĖťťôĲťϙŕŘĺîŪèťĖĺĲϙÍŜϙÍϙ@[ϙŕŘĺîŪèôŘϙŪĲťĖīϙæôĖĲČϙŜēŪťϱĖĲϙaÍƅϙ͑͏͓͑ϙċĺŘϙČÍŜϱēÍĲîīĖĲČϟϙϙϙ bĺťôŜϙôČÍŘîĖĲČϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -F(ϙ«͏ϱŘÍťôîϙ͐͏XϙbϙħŘϟϙϙÍīèŪīÍťôîϙiϙĖĲϙ͖ЋϙÍĲĲŪīŪŜϙċŘĺıϙbÍæĺŘŜϙ͑͑(ϙŘĖČϙŘôŕĺŘťϙťĺϙæôϙѷ͔͕͖ϙċťϙ ÍæĺŽôϙŕħŘϙŜôťϙîôŕťēϟ -͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙϙϼ«aϽϙϱIIϙŕŘôıĖŪıϙťēŘôÍîôîϙèĺĲĲôèťĖĺĲŜ -ÍŜŜĖĲČϙaIϱϙϼ͔͒͏͏ϙŕŜĖϽϙÍĲîϙaIϱIϙϼ͓͒͏͏ϙŕŜĖϽϙĺĲϙ͐͘ϙVÍĲϙ͑͏͐͒ϙϼ[ϙϙϭ͗Ͻ iæĤôèťĖŽôϡ ®ôϙſĺŪīîϙīĖħôϙťĺϙèĺĲŽôŘťϙťēĖŜϙſôīīϙťĺϙ®@ϙĖĲĤôèťĖĺĲϙťĺϙŕŘĺŽĖîôϙŜŪŕŕĺŘťϙċĺŘϙaϙϱ͓͐ϠϙÍϙ͑͏͓͑ϙ"ϙŜĖîôťŘÍèħϙ ſôīīϟ ēĖŜϙŕŘĺèôîŪŘôϙîôťÍĖīŜϙťēôϙæôīĺſϙĺŪťīĖĲôϙĺċϙťēôϙŜèĺŕôϙĺċϙťēĖŜϙŕŘĺĤôèťϡ -«ôŘĖċƅϙæÍŘŘĖôŘϙĖĲťôČŘĖťƅϙċĺŘϙ®@ϙĖĲĤôèťĖĺĲ -īÍèôϙſôīīϙĺĲϙ®@ϙĖĲĤôèťĖĺĲ ®ôīīϡ aϙϱ͓͑ "ϡ ͑͏͘ϱ͓͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͒͏͑͏ϱ͏͐ϱ͏͏ "Íťôϡ ͑͐ϙ>ôæϙ͑͏͔͑ «ÍŘĖÍĲèôϙôŗŪôŜťϡϙ ϙŽÍŘĖÍĲèôϙťĺϙ͑͏ϙϙ͓͑ϟ͓͐͑ϟæϙťĺϙÍīīĺſϙťēôϙŕÍèħôŘϙťĺϙæôϙŕīÍèôîϙČŘôÍťôŘϙťēÍĲϙ͑͏͏ϙċôôťϙıôÍŜŪŘôîϙîôŕťēϙċŘĺıϙ ťēôϙťĺŕϙŕôŘċĺŘÍťĖĺĲϟϙϙ -īīϙŕĺťôĲťĖÍīīƅϙċŘôŜēϙſÍťôŘϙƏĺĲôŜϙÍŘôϙÍæĺŽôϙťēôϙ͘ϱ͔ϯ͗ЋϙèÍŜĖĲČϙŜēĺôϙÍťϙ͔Ϡ͏͔͖Ѝϙa"ϙϯϙ͓Ϡ͕͏͘Ѝϙ«"ϟϙϙ -ēôϙèôıôĲťĖĲČϙŘôèĺŘîŜϙċĺŘϙťēôϙ͒ϱ͐ϯ͑Ћϙ"ϙ[ĖĲôŘϠϙťēôϙ͓ϱ͐ϯ͑ЋϙŘĺîŪèťĖĺĲϙ[ĖĲôŘϠϙÍĲîϙťēôϙ͖ЋϙŘĺîŪèťĖĺĲϙ ÍŜĖĲČϙÍīīϙĖĲîĖèÍťôϙèĺĲťĖĲŪĺŪŜϙèôıôĲťϙŪŕϙťĺϙÍϙiϙæôēĖĲîϙťēôϙ͖ЋϙÍťϙ͕Ϡ͕͏͒Ѝϙa"ϙϯϙ͔Ϡ͗͏͒Ѝϙ«"ϙ ϼÍèèĺŪĲťĖĲČϙċĺŘϙ͒͏҇ϙſÍŜēĺŪťϽϟϙϙ o ͖ЋϠϙ͕͑ϭϙ[͗͏ϙϱaϙèŜČϙŘŪĲϙťĺϙ͖͕͖͘ϱċťϙa"ϙϼ͕͔͗͏ϱċťϙ«"ϽϙèôıôĲťôîϙſĖťēϙ͔͒ϙææīŜϙϼ͖͐͏ϙŜƄŜϽϟϙ ŪıŕôîϙŕīŪČϙĺĲϙŜťŘĺħôŜϟϙFôīîϙ͔͑͏͏ŕŜĖϠϙīôôîϙťĺϙ͏ŕŜĖϙēôīîϟϙ(ŜťϙiϙÍťϙ͕Ϡ͕͏͒Ѝϙa"ϙϯϙ͔Ϡ͗͏͒Ѝϙ «"ϟϙ o ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙϙèŜČϙŘŪĲϙťĺϙ͓͗͏͓ϱċťϙa"ϙϼ͖͕͑͑ϱċťϙ«"ϽϟϙϙŪıŕôîϙ͔͑ϙææīŜϙϼ͔͐͐ϙŜƄŜϽϙ͔͐ϟ͕ϙ ϭϯČÍīϙīÍťôƄϙèôıôĲťϟϙϙôťϙīĖĲôŘϙťĺŕϙŕħŘϙ͔͐͗ϱċťϙa"ϙÍæĺŽôϙ͖ГϙƲĺÍťϙŜēĺôϙĺŘϙ͖͓͓͘ϱċťϙa"ϙϼ͕͓͓͑ϱċťϙ «"ϽϟϙϙĖŘèŪīÍťôîϙ͐͏ϙææīŜϙĺċϙèôıôĲťϙťĺϙŜŪŘċÍèôϟϙϙôŜťϙ¾³ϙīĖĲôŘϙťĺŕϙŕÍèħôŘϙťĺϙ͔͒͏͏ϙŕŜĖϟ o ͒ϱΫЋϙƄϙ͒ϱ͒ϯ͕͐ЋϙƄϙ͑ϱ͖ϯ͗Ћϙ"ϙīĖĲôŘϙſÍŜϙèôıôĲťôîϙſĖťēϙ͒͐ϙææīŜϟϙϙ͐ϡ͐ϙŘôťŪŘĲŜϙťēŘĺŪČēĺŪťϙ èôıôĲťϙĤĺæϟϙϙѷ͑ϙææīŜϙĺċϙèôıôĲťϙèĖŘèŪīÍťôîϙťĺϙŜŪŘċÍèôϟϙϙ[ĲŘϙťĺŕϙŕŘôŜŜŪŘôϙťôŜťôîϙťĺϙ͑͏͏͏ϙŕŜĖϟϙϙ iϙÍťϙīĖĲôŘϙťĺŕϟ bĺĲϱĖČϙiŕôŘÍťĖĺĲŜϙϼbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ ͐Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ ēĺĺťϙƲŪĖîϙīôŽôīŜϙĖĲϙťæČϙÍĲîϙI ͑Ͻ īĖèħīĖĲô ÍϽ ôťϙŕīŪČϙĖĲϙ͒ϱΫЋϙЌ³bЍϙ͑ϟ͖͔͏ϱĖĲϯ͑ϟ͕͔͒ϱĖĲϙĲĖŕŕīôϙŕŘĺƱīôϙÍťϙ͕͖͖͗ϱċťϙa" æϽ ôťϙèÍťèēôŘϙŜŪæϙĺĲϙťĺŕϙĺċϙŕīŪČ èϽ ŪīīϙiϙċŘĺıϙϙ͐ϙÍťϙ͕͔͓͑ϱċťϙa"ϙÍĲîϙīôÍŽôϙĺŕôĲ îϽ Ūīīϙ@[«ŜϙċŘĺıϙϙ͑ϙϳϙ͔ϙÍĲîϙŜôťϙ"«ŜϙĖĲϙŜÍıô ͒Ͻ >ŪīīæĺŘô ÍϽ >īŪĖîϙŕÍèħϙſôīīϙťēŘĺŪČēϙĺŕôĲϙϙ͐ϙ@[aϙÍťϙ͕͔͓͑ϱċťϙa"ϙſϯϙ͗ϟ͔ϙīæϯČÍīϙŜĺŪŘèôϙſťŘ ĖϽ IϙŽĺīŪıôŜϡ ϼ͐Ͻ ѷ͖͐͑ϙææīŜϙIϙŽĺīŪıôϙťĺϙϙ͐ϙ@[aϙċŘĺıϙŜŪŘċÍèô ϼ͑Ͻ ѷ͔ϙææīŜϙIϙŽĺīŪıôϙċŘĺıϙϙ͐ϙ@[aϙťĺϙF(ϙЌbЍϙŕħŘ ĖĖϽ æČϙŽĺīŪıôŜϡ ϼ͐Ͻ ѷ͔͖ϙææīŜϙťæČϙŽĺīŪıôϙťĺϙϙ͐ϙ@[aϙċŘĺıϙŜŪŘċÍèô ϼ͑Ͻ ѷ͑ϙææīŜϙťæČϙŽĺīŪıôϙċŘĺıϙϙ͐ϙ@[aϙťĺϙ͒ϱΫЋϙЌ³bЍϙ͑ϟ͖͔͏ϱĖĲϯ͑ϟ͕͔͒ϱĖĲϙĲĖŕŕīôϙŕŘĺƱīô æϽ (ĲŜŪŘôϙſôīīϙĖŜϙƲŪĖîϙŕÍèħôîϟ èϽ ôŘċĺŘıϙaIϱƄIϙϼ͒͏͏͏ϙŕŜĖϙϳϙ͒͏ϙıĖĲŜϙèēÍŘťôîϽϙϳϙÍŜŜôîϙ͏͒ϯ͏͘ϯ͑͏͔͑ îϽ ŕĺĲϙŜŪèèôŜŜċŪīϙťôŜťϠϙæīôôîϙŕŘôŜŜŪŘôϙċŘĺıϙťæČϯIϙťĺϙ͏ϙŕŜĖϙæÍèħϙťĺϙŜīĺŕϙťÍĲħ ͓Ͻ īĖèħīĖĲô ÍϽ ôťϙ"«ϙĖĲϙϙ͐ϙÍťϙ͕͔͓͑ϱċťϙa" ͔Ͻ >ŪīīæĺŘô ÍϽ (ĲŜŪŘôϙſôīīϙĖŜϙƲŪĖîϙŕÍèħôîϟ æϽ ôŘċĺŘıϙaIϱϙϼ͒͏͏͏ϙŕŜĖϙϳϙ͒͏ϙıĖĲŜϙèēÍŘťôîϽϙϳϙÍŜŜôîϙ͏͒ϯ͑͘ϯ͑͏͔͑ϙϯϙaIϱIϙÍŜŜôîϙ ͏͒ϯ͒͏ϯ͑͏͔͑ èϽ ŕĺĲϙŜŪèèôŜŜċŪīϙťôŜťϠϙæīôôîϙŕŘôŜŜŪŘôϙċŘĺıϙťæČϙťĺϙ͏ϙŕŜĖϙæÍèħϙťĺϙŜīĺŕϙťÍĲħ ͕Ͻ īĖèħīĖĲô ®ôīīϡ aϙϱ͓͑ "ϡ ͑͏͘ϱ͓͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͒͏͑͏ϱ͏͐ϱ͏͏ "Íťôϡ ͑͐ϙ>ôæϙ͑͏͔͑ ÍϽ ŪīīϙèÍťèēôŘϙŜŪæ æϽ ŪīīϙŕīŪČ èϽ "ŘĖċťϙċĺŘϙ[ϙťĺϙ͗Ϡ͏͏͏Ѝϙa"ϟϙϳϙ"ŘĖċťôîϙſϯϙ͑ϟ͖͏Ћϙ"ıƅϙ®ēĖŕŜťĺèħϙťĺϙ͗Ϡ͏͓͑ЍϙŜīıîϙĺĲϙ͏͒ϯ͒͏ϯ͑͏͔͑ ͖Ͻ (ϱ[ĖĲôϙϼŜēĺĺťϙťæČϙƲŪĖîϙīôŽôīϙŕŘĖĺŘϙťĺϙôĲŜŪŘôϙēĖČēϙôĲĺŪČēϙťĺϙīĺČϙſĖťēĺŪťϙĲôôîĖĲČϙťĺϙŕŪıŕϙĺĲϙťēôϙ ſôīīϽ ÍϽ [ĺČϙ[ϙċŘĺıϙѷ͗Ϡ͏͏͏ϙϳϙ͕Ϡ͏͏͏Ѝϙa"ϟϙ ͗Ͻ FÍĲîϙſôīīϙĺŽôŘϙťĺϙiŕŜϙċĺŘϙiI ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ iϙÍæīôϙÍĲîϙaÍŕ CDW 04/14/2025 AOGCC witnessed MITIA to be completed after injection begins and well stabilizes (within 10 days). CDW 04/14/2025 20 AAC 25.412(b) A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. _____________________________________________________________________________________ Revised By: TDF 8/12/2022 SCHEMATIC Milne Point Unit Well: MPU C-24A Last Completed: 12/22/2012 PTD: 209-134 17 TD =10,580’(MD) / TD =6,991’(TVD) 20” Orig KB Elev.: 44.8’ / Orig GL Elev.: 16.2’ RKB Elev = 23.05’ (Doyon 16) 7” 1 2 3 6 7 8 1 0 13 5 15 2 1 9-5/8” TAM Port Collar @ 1,004’ 16 11 Min ID= 2.750” @ 6,778’ Top of liner @7,598’ ELMD PBTD =10,551’(MD) / PBTD = 6,993’(TVD) 9 Window @ 8,040’ – 8,051’ ELMD 4 9-5/8” 14 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 N/A Surface 113' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 5,057’ 7” Inter. 26 / L-80 / BTC-M 6.276 Surface 7,679’ 4-1/2” Liner 12.6 / L-80 / BTC 3.958 7,494' 8,040’ 3-1/2” Liner 9.3 / L-80 / STL 2.992 7,602’ 7,657’ 3-3/16” Liner 6.2 / L-80 / TC-II 2.800 7,657’ 8,397’ 2-7/8” Liner 6.16 / L-80 / STL 2.441 8,397’ 10,564’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992 Surface 6,801’ JEWELRY DETAIL No Depth Item GLM Detail – 3-1/2” x 1.” KBG-2-9 w/ BTM Latch 1 2,604’ST 5: Port= 10 Dev.= 30, VLV= Dome, TVD= 2,497’, 4/5/2013 2 4,065’ST 4: Port= 12, Dev.= 31, VLV= Dome, TVD= 3,753’, 4/5/2013 3 5,044’ST 3: Port= 12, Dev.= 29, VLV= Dome, TVD= 4,598’, 4/5/2013 4 5,800’ST 2: Port= 12, Dev.= 35, VLV= Dome, TVD= 5,246’, 4/5/2013 5 6,524’ST 1: Port= 16, Dev.= 56, VLV= SO, TVD= 5,764’, 4/5/2013 6 6,581’ 3-1/2” SLB ‘NDPG’ Multi pressure gauge – ID=2.992”, TVD = 5,795’ 7 6,599’ 3-1/2” HES ‘XD’ Dura Sliding Sleeve 8 6,613’ 3-1/2” SLB ‘NDPG’ Single Sub Gauge, ID = 2.992”, TVD = 5,813’ 9 6,670’ 3-1/2” ‘X’ Nipple – ID= 2.813” 10 6,696’ 7” x 3-1/2” HES ‘TNT’ Packer, ID = 2.813” 11 6,726’’ 3-1/2” ‘X’ Nipple, ID = 2.813” 12 6,778’ 3-1/2” ‘XN’ Nipple, Min ID = 2.750” 13 6,800’ 3-1/2” WLEG,Bottom @ 6,801’ 14 7,494’ 7” x 4-1/2” Baker ‘ZXP’ Packer 15 7,602’ Deployment Sleeve w/4” GS profile, ID = 3.0” 16 7,624’ 3-1/2” ‘X’ Nipple, ID = 2.812’ 17 10,562’ Unique Indexing Guide Shoe, bottom at 10,564’ OPEN HOLE / CEMENT DETAIL 20"260 sx of Arctic Set (Approx) in 30” Hole 9-5/8”714 sx Permafrost ‘C’ plus 360 sx Class ‘G’ in a 12-1/4” Hole 7” 170 sx Class “G” in 8-1/2” Hole 4-1/2” 115 sx Class “G” in 6-1/8” Hole 2-7/8” 150 sx Class “G” in 4-1/8” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Hole Angle ~30 Deg. 2,900’ - 5,500’ MD Hole Angle ~90 deg 8,300’ – 10,580’ MD Angle at Top Perf = 92 deg @ 8,824’ WELLHEAD Tree 4-1/16” – 5M Wellhead FMC 11” x 11”, 5M, Gen. 5 and 11” x 4-1/16” adapter flange, 4-1/2” Tbg Hng. w/TC-II T&B threads & 4” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23020-01-00 Spudded & Ran Frac String by Nabors 22E – 7/13/2001 Initial ESP Completion by Nabors 4ES – 8/232001 ESP Rig Workover by Nabors 22E – 10/5/2001 ESP Rig Workover by Nabors 3S – 6/18/2006 ESP Rig Workover by Nabors 3S – 2/27/2008 CTU Horizontal Sidetrack by Nordic 2 - 1/12/2010 ESP Completion by Nabors 4ES – 2/9/2010 Re-Complete as Gas Lift by Doyon 16 – 12/22/2012 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF KUP C 7,986 7,996’ 6,846’ 6,855’ 10’ 7/29/2022 Open 2” 6 KUP B Silt 8,066’ 8,098’ 6,916’ 6,944’ 32’ 7/29/2022 Open 2” 6 KUP A2 8,176’ 8,200’ 7,002’ 7,016’ 24’ 7/29/2022 Open 2” 6 KUP A2 8,218’ 8,276’ 7,025’ 7,039’ 58’ 7/29/2022 Open 2” 6 KUP A2 8,277’ 8,286’ 7,046’ 7,049’ 9’ 8/3/2022 Open 2” 6 KUP A2 8,374’ 8,446’ 7,051’ 7,046’ 72’ 8/3/2022 Open 2” 6 KUP A2 8,468’ 8,515’ 7,046’ 7,045’ 47’ 7/28/2022 Open 2” 6 KUP A2 8,628’ 8,660’ 7,046’ 7,045’ 32’ 7/29/2022 Open 2” 6 KUP A2 8,810’ 8,840’ 7,045’ 7,044’ 30’ 7/29/2022 Open 2” 6 KUP A2 8,810’ 8,840’ 7,045’ 7,044’ 30’ 7/9/2014 Open 2” 6 KUP A2 8,870’ 8,930’ 7042 7,039 60 7/29/2022 Open 2” 6 KUP A2 8,976’ 9,006’ 7,038’ 7,036’ 30’ 7/9/2014 Open 2” 6 KUP A2 9,014’ 9,044’ 7,035’ 7,031’ 30’ 7/8/2014 Open 2” 6 KUP A2 9,050’ 9,080 7,030’ 7,025’ 30’ 7/8/2014 Open 2” 6 KUP A2 9,365’ 9,375’ 7,006’ 7,006’ 10’ 1/19/2013 Open 2” 6 KUP A2 9,640’ 10,270’ 7,025’ 7,018’ 630’ 1/10/2010 Open 2” 6 KUP A2 10,350’ 10,540’ 7,007’ 6,994’ 190’ 1/10/2010 Open 2” 6 Well Name Well identifier (UWI)Surface X Y Z MD Note MPC-46 500292357600 KUP_D 559351.68 6026425.15 -6747.08 7799.00 Top of Pool MPC-45 500292357900 KUP_D 563883.26 6026503.46 -6761.07 9795.00 Top of Pool MPC-24APB1 500292302070 KUP_D 560433.93 6027154.92 -6676.74 7843.00 Top of Pool MPC-24A 500292302001 KUP_D 560433.93 6027154.92 -6676.74 7843.00 Top of Pool MPC-24 500292302000 KUP_D 560433.81 6027155.41 -6675.88 7842.00 Top of Pool MPC-14APB1 MPC-14APB1 KUP_D 561986.71 6027965.11 -6731.30 8131.00 Top of Pool MPC-14A 500292134401 KUP_D 561986.71 6027965.11 -6731.30 8131.00 Top of Pool MPC-14 500292134400 KUP_D 561986.68 6027965.06 -6731.30 8131.00 Top of Pool MPC-13APB1 500292132870 KUP_D 559518.16 6027130.67 -6767.59 7616.00 Top of Pool MPC-13A 500292132801 KUP_D 559518.16 6027130.67 -6767.59 7616.00 Top of Pool MPC-13 500292132800 KUP_D 559518.16 6027130.67 -6767.59 7616.00 Top of Pool MPC-06 500292125700 KUP_D 561142.13 6025786.74 -6631.50 8289.00 Top of Pool PTD Well Name API StatusTop of Kuparuk (MD-ft)Top of Kuparuk (TVD-ft)Top of Cement (TOC)(MD-ft)Top of Cement (TOC)(TVD-ft)Zonal Isolation Comments217-052 MPC-46 500292357600 SI Sag GL Producer 7799 6797 7055 6177 TOC from 10,270 - 9,430-ft MD (8869 - 8137-ft TVD) and again from 8,125 - 7,055-ft MD (7072 - 6177-ft TVD) per USIT (24 June 2017)217-092 MPC-45 500292357900 Kuparuk C-1 RCJP Producer 9795 6803 8508 5739 TOC at 8508-ft MD (5739-ft TVD) per USIT (21 Oct 2017).201-094 MPC-24 500292302000 Abandoned GL Producer 7842 6720 74947" x 4-1/2" Liner Top Packer6424 4-1/2" liner cemented with 25 bbls (115 sxs) cement with 10 bbls of cement to surface. TOC at liner top.209-134 MPC-24A 500292302001 SI Kuparuk GL Producer 7843 6720 7589 CTD Lnr Deployment Sleeve6504 3-½” x 3-3/16” x 2-7/8” CTD liner was cemented with 31 bbls. 1:1 returns throughout cement job. ±2 bbls of cement circulated to surface. Lnr top pressure tested to 2000 psi. TOCat linertop.209-134 MPC-24APB1 500292302070 Inadvertent CTD ST 7843 6720 N/A N/A MPC-24APB1 was left open by Nordic 2 CTD in January 2010.185-088 MPC-14 500292134400 Kuparuk JP Producer 8131 6783 7650 6423 7" casing was cemented with 56 bbls (273 sxs) with good returns throughout the job. TOC referenced at 7650-ft MD based on 100% excess on 10-404.224-015 MPC-14A 500292134401 Kuparuk JP Producer 8131 6783 8010Top of CTD Liner6692CTD 2-3/8" liner set at 8010-ft MD (6692-ft TVD). Cemented with 26 bbls (117 sxs) of cement. 100% returns during cement job and (3) bbls cement returns to surface. TOC at liner top.224-015 MPC-14APB1 500292134470 Inadvertent CTD ST into D-shale 8131 6783 N/A N/A MPC-14APB1 was left uncemented after an open hole sidetrack on 06 May 2024.185-067 MPC-13 500292132800 Kuparuk GL Producer 7616 6820 6900 6261 7" casing cemented with 63.5 bbls (310 sxs) cement. Full returns during job. Est TOC 6900-ft MD based off 100% excess.223-118 MPC-13A 500292132801 Kuparuk GL Producer 7616 6820 7682Top of CTD Liner6871 CTD 3-1/2" x 3-1/4" x 2-7/8" liner cemented with 35 bbls (158.5 sxs) of cement. 100% returns during job. (3) bbls cement returns at surface. TOC at liner top.223-118 MPC-13APB1 500292132870 CTD ST abandoned due to hole stability7616 6820 N/A N/A PB1 was left uncemented after making the decision to set a 2nd whipstock higher on 05 April 2024.184-241 MPC-06 500292125700 Kuparuk Injector 8289 6683 6000 4832 7" casing was cemented with 133 bbls (650 sxs) cement. TOC estimated at 6000-ft MD with 100% excess. Top down job of 33 bbls (200 sxs) cement and ±60 bbls Arctic Pak was performed right after the primary cement job. 1 Christianson, Grace K (OGC) From:Tom Fouts <tfouts@hilcorp.com> Sent:Wednesday, March 19, 2025 7:56 AM To:AOGCC Permitting (CED sponsored) Cc:Erik Nelson - (C); Taylor Wellman Subject:RE: [EXTERNAL] RE: Milne Point well C-24A 10-403 submittal Hello, Hilcorp Alaska LLC would like to request the withdrawal of the original 10-403 submittal for MP C-24A. This submittal was never approved, and we will be submitting a revised 10-403 in its place. Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Friday, February 21, 2025 2:09 PM To: Darci Horner <dhorner@hilcorp.com> Cc: Tom Fouts <tfouts@hilcorp.com>; Erik Nelson - (C) <Erik.Nelson@hilcorp.com> Subject: [EXTERNAL] RE: Milne Point well C-24A 10-403 submittal Received for processing From: Darci Horner <dhorner@hilcorp.com> Sent: Friday, February 21, 2025 1:49 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com>; Erik Nelson - (C) <Erik.Nelson@hilcorp.com> Subject: Milne Point well C-24A 10-403 submittal Good evening, Please Ʊnd an attached 10-403 for Milne Point well C-24A, PTD # 209-134. Regards, Darci Horner CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. RBDMS JSB 032525 2 Regulatory Technologist Alaska Islands and Western North Slope Hilcorp Alaska, LLC dhorner@hilcorp.com 907-777-8406 oƯice 907-227-3036 cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,580'NA Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 7,500psi Liner 10,540psi Liner N/A Liner N/A 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: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE POINT 740' 3-3/16" 8,397' 7,050' N/A 7” x 3-1/2” HES ‘TNT’ & 7” x 4-1/2” Baker ‘ZXP’ and N/A 6,696 MD / 5,860 TVD & 7,494' MD / 6,424 TVD and N/A NA 7,657' 8,040' 55' 2-7/8" See Schematic 907-564-5277 erik.nelson@hilcorp.com Operations Manager March 7, 2025 10,564'2,167' 3-1/2" 6,992' Perforation Depth MD (ft): See Schematic 6,561'3-1/2" 113' 20" 9-5/8" 7" 5,057' 4-1/2"546' 7,679' 5,750psi 7,240psi 4,609' 6,580' 6,893' 5,057' 7,679' 113' 113' 9.2 / L-80 / TC-II TVD Burst 6,801' 10,160psi MD N/A 8,430psi Hilcorp Alaska, LLC Length Size Proposed Pools: 6,991' 10,551' 6,993'899 KUPARUK RIVER OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025516, ADL0047434, ADL0047437 209-134 C.O. 432E MILNE PT UNIT C-24A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23020-01-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Erik Nelson Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-099 By Gavin Gluyas at 2:02 pm, Feb 21, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.02.21 13:41:01 - 09'00' Taylor Wellman (2143) Injection operations to be in accordance with AIO 10C. SFD 2/26/2025 DSR-2/24/25 NOT APPROVED Well Name: MPU C-24A API Number: 50-029-23020-01-00 Current Status: SI GL Prod Rig: Non-Rig Estimated Start Date: 07 Mar 2025 Estimated Duration: 2 Days Regulatory Contact: Tom Fouts Permit to Drill Number: 209-134 First Call Engineer: Erik Q. Nelson (907) 564 – 5277 (O) (907) 903 – 7407 (C) Second Call Engineer: Taylor Wellman (907) 777 – 8449 (O) (907) 947 – 9533 (C) Current Bottom Hole Pressure (BHP): from SBHP survey 26 Aug 2023 1584 psi @ 7986-ft MD (6846-ft TVD) 26 Aug 2023 | 4.3 EMW (8.5 KWF) Max Potential Surface Pressure (MPSP): 899 psi Gas Column Gradient (0.1 psi/ft) Max Deviation (relevant to wellwork): 56.3° @ 6545-ft MD Max Dogleg (relevant to wellwork): 5.4°/100-ft @ 6451-ft MD Min ID (relevant to wellwork): 2.750-in ID in 3-½” XN-nipple at 6778-ft MD Brief Well Summary: MPU C-24 was drilled and completed by Nabors 22E and Nabors 4ES respectively in 2001. The well produced on ESP until Nordic 2 performed a CTD sidetrack in 2010. The well was re-completed as an ESP producer and ran until Doyon 16 re-completed the well as a GL producer in 2012. It continued problematic, intermittent production as a GL producer until being shut-in May 2024 for gas-handling. Notes Regarding Wellbore Condition: - HES V0-rated 10K TNT Pkr. Calculated TOC in 7” annulus from Nabors 22E rig report to be ±567 ft above pkr set depth. - 3-½”, 9.2# L80 AB (VAM) TC-II premium threaded connections - Passing MIT-T (3500 psi) and MIT-IA (4300 psi) on 19 Jan 2013 (SLB CTU #8) - Current GLM Disposition: GLM MD TVD Valve Type Last Date Set ST 5 2604 2497 GLV 5-Apr-2013 ST 4 4065 3753 GLV 5-Apr-2013 ST 3 5044 4598 GLV 5-Apr-2013 ST 2 5800 5246 GLV 5-Apr-2013 ST 1 6524 5764 SO 6-Apr-2013 SS MD TVD Setup Position HES 'XD' Dura Sliding Sleeve 6599 5805 Opens Down Ran Closed on 20 Dec 2012 Well: MPU C-24A PTD: 209-134 API: 50-029-23020-01-00 Date: 21 Feb 2025 Objective: We would like to convert this well to WAG injection to provide support for MPU C-14A, a 2024 CTD sidetrack well. This procedure details the below outline of the scope of this project: - Verify barrier integrity for WAG injection - Place well on WAG injection Non-Rig Operations (Non-Sundried Work): 1) Well Support a) Shoot Ʋuid levels in tbg and IA 2) Slickline a) Set plug in 3-½” ‘XN’ 2.750-in/2.635-in nipple proƱle at 6778-ft MD b) Set catcher sub on top of plug c) Pull SO from ST 1 at 6524-ft MD and leave open d) Pull GLVs from ST 2 – 5 and set DVs in same 3) Fullbore a) Fluid pack well through open ST 1 GLM at 6524-ft MD w/ 8.5 lb/gal source wtr i) IA volumes: (1) ±172 bbls IA volume to ST 1 GLM from surface (2) ±5 bbls IA volume from ST 1 GLM to HES ‘TNT’ pkr ii) Tbg volumes: (1) ±57 bbls tbg volume to ST 1 GLM from surface (2) ±2 bbls tbg volume from ST 1 GLM to 3-½” ‘XN’ 2.750-in/2.635-in nipple proƱle b) Ensure well is Ʋuid packed. c) Perform CMIT-TxIA (3000 psi – 30 mins charted) d) Upon successful test, bleed pressure from tbg/IA to 0 psi back to slop tank 4) Slickline a) Set DV in ST 1 at 6524-ft MD 5) Fullbore a) Ensure well is Ʋuid packed. b) Perform MIT-T (3000 psi – 30 mins charted) c) Upon successful test, bleed pressure from tbg to 0 psi back to slop tank 6) Slickline a) Pull catcher sub b) Pull plug 7) Hand well over to Ops for POI Attachments: 1) Current Wellbore Schematic 2) AOR Table and Map _____________________________________________________________________________________ Revised By: TDF 8/12/2022 SCHEMATIC Milne Point Unit Well: MPU C-24A Last Completed: 12/22/2012 PTD: 209-134 17 TD =10,580’(MD) / TD =6,991’(TVD) 20” Orig KB Elev.: 44.8’ / Orig GL Elev.: 16.2’ RKB Elev = 23.05’ (Doyon 16) 7” 1 2 3 6 7 8 1 0 13 5 15 2 1 9-5/8” TAM Port Collar @ 1,004’ 16 11 Min ID= 2.750” @ 6,778’ Top of liner @7,598’ ELMD PBTD =10,551’(MD) / PBTD = 6,993’(TVD) 9 Window @ 8,040’ – 8,051’ ELMD 4 9-5/8” 14 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 N/A Surface 113' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 5,057’ 7” Inter. 26 / L-80 / BTC-M 6.276 Surface 7,679’ 4-1/2” Liner 12.6 / L-80 / BTC 3.958 7,494' 8,040’ 3-1/2” Liner 9.3 / L-80 / STL 2.992 7,602’ 7,657’ 3-3/16” Liner 6.2 / L-80 / TC-II 2.800 7,657’ 8,397’ 2-7/8” Liner 6.16 / L-80 / STL 2.441 8,397’ 10,564’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992 Surface 6,801’ JEWELRY DETAIL No Depth Item GLM Detail – 3-1/2” x 1.” KBG-2-9 w/ BTM Latch 1 2,604’ST 5: Port= 10 Dev.= 30, VLV= Dome, TVD= 2,497’, 4/5/2013 2 4,065’ST 4: Port= 12, Dev.= 31, VLV= Dome, TVD= 3,753’, 4/5/2013 3 5,044’ST 3: Port= 12, Dev.= 29, VLV= Dome, TVD= 4,598’, 4/5/2013 4 5,800’ST 2: Port= 12, Dev.= 35, VLV= Dome, TVD= 5,246’, 4/5/2013 5 6,524’ST 1: Port= 16, Dev.= 56, VLV= SO, TVD= 5,764’, 4/5/2013 6 6,581’ 3-1/2” SLB ‘NDPG’ Multi pressure gauge – ID=2.992”, TVD = 5,795’ 7 6,599’ 3-1/2” HES ‘XD’ Dura Sliding Sleeve 8 6,613’ 3-1/2” SLB ‘NDPG’ Single Sub Gauge, ID = 2.992”, TVD = 5,813’ 9 6,670’ 3-1/2” ‘X’ Nipple – ID= 2.813” 10 6,696’ 7” x 3-1/2” HES ‘TNT’ Packer, ID = 2.813” 11 6,726’’ 3-1/2” ‘X’ Nipple, ID = 2.813” 12 6,778’ 3-1/2” ‘XN’ Nipple, Min ID = 2.750” 13 6,800’ 3-1/2” WLEG,Bottom @ 6,801’ 14 7,494’ 7” x 4-1/2” Baker ‘ZXP’ Packer 15 7,602’ Deployment Sleeve w/4” GS profile, ID = 3.0” 16 7,624’ 3-1/2” ‘X’ Nipple, ID = 2.812’ 17 10,562’ Unique Indexing Guide Shoe, bottom at 10,564’ OPEN HOLE / CEMENT DETAIL 20"260 sx of Arctic Set (Approx) in 30” Hole 9-5/8”714 sx Permafrost ‘C’ plus 360 sx Class ‘G’ in a 12-1/4” Hole 7” 170 sx Class “G” in 8-1/2” Hole 4-1/2” 115 sx Class “G” in 6-1/8” Hole 2-7/8” 150 sx Class “G” in 4-1/8” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Hole Angle ~30 Deg. 2,900’ - 5,500’ MD Hole Angle ~90 deg 8,300’ – 10,580’ MD Angle at Top Perf = 92 deg @ 8,824’ WELLHEAD Tree 4-1/16” – 5M Wellhead FMC 11” x 11”, 5M, Gen. 5 and 11” x 4-1/16” adapter flange, 4-1/2” Tbg Hng. w/TC-II T&B threads & 4” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23020-01-00 Spudded & Ran Frac String by Nabors 22E – 7/13/2001 Initial ESP Completion by Nabors 4ES – 8/232001 ESP Rig Workover by Nabors 22E – 10/5/2001 ESP Rig Workover by Nabors 3S – 6/18/2006 ESP Rig Workover by Nabors 3S – 2/27/2008 CTU Horizontal Sidetrack by Nordic 2 - 1/12/2010 ESP Completion by Nabors 4ES – 2/9/2010 Re-Complete as Gas Lift by Doyon 16 – 12/22/2012 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF KUP C 7,986 7,996’ 6,846’ 6,855’ 10’ 7/29/2022 Open 2” 6 KUP B Silt 8,066’ 8,098’ 6,916’ 6,944’ 32’ 7/29/2022 Open 2” 6 KUP A2 8,176’ 8,200’ 7,002’ 7,016’ 24’ 7/29/2022 Open 2” 6 KUP A2 8,218’ 8,276’ 7,025’ 7,039’ 58’ 7/29/2022 Open 2” 6 KUP A2 8,277’ 8,286’ 7,046’ 7,049’ 9’ 8/3/2022 Open 2” 6 KUP A2 8,374’ 8,446’ 7,051’ 7,046’ 72’ 8/3/2022 Open 2” 6 KUP A2 8,468’ 8,515’ 7,046’ 7,045’ 47’ 7/28/2022 Open 2” 6 KUP A2 8,628’ 8,660’ 7,046’ 7,045’ 32’ 7/29/2022 Open 2” 6 KUP A2 8,810’ 8,840’ 7,045’ 7,044’ 30’ 7/29/2022 Open 2” 6 KUP A2 8,810’ 8,840’ 7,045’ 7,044’ 30’ 7/9/2014 Open 2” 6 KUP A2 8,870’ 8,930’ 7042 7,039 60 7/29/2022 Open 2” 6 KUP A2 8,976’ 9,006’ 7,038’ 7,036’ 30’ 7/9/2014 Open 2” 6 KUP A2 9,014’ 9,044’ 7,035’ 7,031’ 30’ 7/8/2014 Open 2” 6 KUP A2 9,050’ 9,080 7,030’ 7,025’ 30’ 7/8/2014 Open 2” 6 KUP A2 9,365’ 9,375’ 7,006’ 7,006’ 10’ 1/19/2013 Open 2” 6 KUP A2 9,640’ 10,270’ 7,025’ 7,018’ 630’ 1/10/2010 Open 2” 6 KUP A2 10,350’ 10,540’ 7,007’ 6,994’ 190’ 1/10/2010 Open 2” 6 Well Name Well identifier (UWI)Surface X Y Z MD Note MPC-46 500292357600 KUP_D 559351.68 6026425.15 -6747.08 7799.00 Top of Pool MPC-45 500292357900 KUP_D 563883.26 6026503.46 -6761.07 9795.00 Top of Pool MPC-24APB1 500292302070 KUP_D 560433.93 6027154.92 -6676.74 7843.00 Top of Pool MPC-24A 500292302001 KUP_D 560433.93 6027154.92 -6676.74 7843.00 Top of Pool MPC-24 500292302000 KUP_D 560433.81 6027155.41 -6675.88 7842.00 Top of Pool MPC-14APB1 MPC-14APB1 KUP_D 561986.71 6027965.11 -6731.30 8131.00 Top of Pool MPC-14A 500292134401 KUP_D 561986.71 6027965.11 -6731.30 8131.00 Top of Pool MPC-14 500292134400 KUP_D 561986.68 6027965.06 -6731.30 8131.00 Top of Pool MPC-13APB1 500292132870 KUP_D 559518.16 6027130.67 -6767.59 7616.00 Top of Pool MPC-13A 500292132801 KUP_D 559518.16 6027130.67 -6767.59 7616.00 Top of Pool MPC-13 500292132800 KUP_D 559518.16 6027130.67 -6767.59 7616.00 Top of Pool MPC-06 500292125700 KUP_D 561142.13 6025786.74 -6631.50 8289.00 Top of Pool PTD Well Name API Status Top of Kuparuk (MD- ft) Top of Kuparuk (TVD- ft) Top of Cement (TOC) (MD-ft) Top of Cement (TOC) (TVD-ft) Zonal Isolation Comments 217-052 MPC-46 500292357600 SI Sag GL Producer 7799 6797 7055 6177 TOC from 10,270 - 9,430-ft MD (8869 - 8137-ft TVD) and again from 8,125 - 7,055-ft MD (7072 - 6177-ft TVD) per USIT (24 June 2017) 217-092 MPC-45 500292357900 Kuparuk C-1 RCJP Producer 9795 6803 8508 5739 TOC at 8508-ft MD (5739-ft TVD) per USIT (21 Oct 2017). 201-094 MPC-24 500292302000 Abandoned GL Producer 7842 6720 7494 7" x 4-1/2" Liner Top Packer 6424 4-1/2" liner cemented with 25 bbls (115 sxs) cement with 10 bbls of cement to surface. TOC at liner top. 209-134 MPC-24A 500292302001 SI Kuparuk GL Producer 7843 6720 7589 CTD Lnr Deployment Sleeve 6504 3-½” x 3-3/16” x 2-7/8” CTD liner was cemented with 31 bbls. 1:1 returns throughout cement job. ±2 bbls of cement circulated to surface. Lnr top pressure tested to 2000 psi. TOCat linertop. 209-134 MPC-24APB1 500292302070 Inadvertent CTD ST 7843 6720 N/A N/A MPC-24APB1 was left open by Nordic 2 CTD in January 2010. 185-088 MPC-14 500292134400 Kuparuk JP Producer 8131 6783 7650 6423 7" casing was cemented with 56 bbls (273 sxs) with good returns throughout the job. TOC referenced at 7650-ft MD based on 100% excess on 10-404. 224-015 MPC-14A 500292134401 Kuparuk JP Producer 8131 6783 8010 Top of CTD Liner 6692 CTD 2-3/8" liner set at 8010-ft MD (6692-ft TVD). Cemented with 26 bbls (117 sxs) of cement. 100% returns during cement job and (3) bbls cement returns to surface. TOC at liner top. 224-015 MPC-14APB1 500292134470 Inadvertent CTD ST into D-shale 8131 6783 N/A N/A MPC-14APB1 was left uncemented after an open hole sidetrack on 06 May 2024. 185-067 MPC-13 500292132800 Kuparuk GL Producer 7616 6820 6900 6261 7" casing cemented with 63.5 bbls (310 sxs) cement. Full returns during job. Est TOC 6900-ft MD based off 100% excess. 223-118 MPC-13A 500292132801 Kuparuk GL Producer 7616 6820 7682 Top of CTD Liner 6871 CTD 3-1/2" x 3-1/4" x 2-7/8" liner cemented with 35 bbls (158.5 sxs) of cement. 100% returns during job. (3) bbls cement returns at surface. TOC at liner top. 223-118 MPC-13APB1 500292132870 CTD ST abandoned due to hole stability 7616 6820 N/A N/A PB1 was left uncemented after making the decision to set a 2nd whipstock higher on 05 April 2024. 184-241 MPC-06 500292125700 Kuparuk Injector 8289 6683 6000 4832 7" casing was cemented with 133 bbls (650 sxs) cement. TOC estimated at 6000-ft MD with 100% excess. Top down job of 33 bbls (200 sxs) cement and ±60 bbls Arctic Pak was performed right after the primary cement job. (3) bbls cement returns Well Completion Report SFD TOC USIT ~7,230' MD SFD Appears sufficient. Daily Rpt of 5/11/2024 SFD(3) bbls cement returns to surfaceffi i t Dil Rt f 5/11/202 Daily Ops Rpt of 4/17/2024 SFD Agree. SFD Well Completion Report SFD ST depth within Kup at ~9712' MD SFDDaily Ops Rpt of 5/5/2024 SFD Agree. SFD Agree. SFD Inadvertent ST depth within Kup at ~8522' MD SFD 10 bbls of cement to surface KOP within Kup. Daily Ops Rpt of 4/5/2024 SFD 2 bbls of cement circulated to surface Daily Ops Rpt of 1/4/2010 SFD Agree. SFD David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. T37103 T37104 T37105 T37106 T37107 T37108 T37109 T37110 T37111 T37112 T37113 T37114 T37115 T37116 T37117 T37118 T37119 T37120 MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 11:39:32 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220902 Well API #PTD #Log Date Log Company Log Type Notes AOGCC Eset # END 3-11 50029218480000 188087 8/1/2022 Halliburton CALIPER + Report KALOTSA 4 50133206650000 217063 7/18/2022 Halliburton PPROF + Processing KBU 22-06Y 50133206500000 215044 7/14/2022 Halliburton PPROF + Processing KTU 24-06H 50133204900000 199073 7/21/2022 Halliburton PPROF + Processing KU 24-05B 50133206830000 219072 7/20/2022 Halliburton PPROF + Processing MPU C-24A 50029230200100 209134 7/28/2022 Halliburton COIL FLAG MPU I-17 50029232120000 204098 7/19/2022 Halliburton FREEPOINT NS-10 50029229850000 200182 7/23/2022 Halliburton CALIPER + Report NS-32 50029231790000 203158 7/24/2022 Halliburton CALIPER + Report PBU 18-02C 50029207620300 213009 7/14/2022 Halliburton CAST/CBL PBU C-10B 50029203710200 211092 7/15/2022 Halliburton PPROF + Processing PBU L5-03 50029236230000 219033 7/25/2022 Halliburton PPROF + Processing Please include current contact information if different from above. T36973 T36974 T36975 T36976 T36977 T36978 T36979 T36980 T36981 T36982 T36983 T36984 MPU C-24A 50029230200100 209134 7/28/2022 Halliburton COIL FLAG Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.07 11:00:16 -08'00' By Samantha Carlisle at 8:47 am, Aug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;ϱ͘ϲƉƉĨͿ ϴϮϴϲͲϴϯϳϰ ϴϴ͛>E< ϴϮϭϴͲϴϮϴϲ ϲϴ͛ ϴϮϬϬͲϴϮϭϴ ϭϴ͛>E< ϴϭϳϲͲϴϮϬϬ Ϯϰ ϴϬϵϴͲϴϭϳϲ ϳϴ͛>E< ϴϬϲϲͲϴϬϵϴ ϯϮ͛ ϳϵϵϲͲϴϬϲϲ ϳϬ͛>E< ϳϵϴϲͲϳϵϵϲ ϭϬ͛ ϭϭ͘ Z/,ǁŝƚŚƉĞƌĨŐƵŶĂŶĚƚŝĞͲŝŶƚŽĐŽŝůĨůĂŐĐŽƌƌĞůĂƚŝŽŶ͘WŝĐŬƵƉĂŶĚƉĞƌĨŽƌĂƚĞŝŶƚĞƌǀĂůƉĞƌWĞƌĨ^ĐŚĞĚƵůĞ ĂďŽǀĞ͘ Ă͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ ϭϮ͘ ĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽĞƐŶ͛ƚĨĂůůŝŶŽŶƚŚĞŐƵŶƐĂŶĚ ƐƚŝĐŬƚŚĞ,͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌǇďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘ ϭϯ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ ϭϰ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚ ĐŽŵŵĞŶĐŝŶŐďƌĞĂŬĚŽǁŶŽĨdWŐƵŶƐƚƌŝŶŐ͘ ϭϱ͘ ŶƐƵƌĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůǇĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌƚŽ>ŐƵŶ,͘ ϭϲ͘ ZDKdh͘ ϭϳ͘ ZdWŽƌ&WǁĞůů͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ϱ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ ϲ͘ dŝĞ/Ŷ>ŽŐͬWĞƌĨ^ŚĞĞƚ ϳ͘ ^ƵŶĚƌǇŚĂŶŐĞ&Žƌŵ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ ŽŝůĞĚdƵďŝŶŐKWƐ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ 7LH,QW^ĐŽŝůĨůĂŐϴƚŚ:ƵůǇϮϬϭϰ'ZͲ>&/E>WZ/Ed tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ tĞůů͗DWͲϮϰ Wd͗ϮϬϵϭϯϰϬ W/͗ STATE OF ALASKA i Al A OIL AND GAS CONSERVATION COMM&N REPORT OF SUNDRY WELL OPERATIONS RECEIVED AUG 052014 1. Operations Abandon Repair Well Plug Perforations Perforate , Other Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑✓ Exploratory ❑ Stratigraphic❑ Service ❑ 209-134-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-23020-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047437 KUP MPC -24A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): MILNE POINT, KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 10580 feet Plugs measured None feet true vertical 6991.17 feet Junk measured 10538 feet Effective Depth measured 10551 feet Packer measured See Attachment feet true vertical 6993.08 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor None None None None None None Surface 5027 9-5/8" 40# L-80 30-5057 30-4609.3 5750 3090 Intermediate None None None None None None Production 7651 7 26# L-80 28-7679 28-6580.13 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 8810-8840 feet 8976-9006 feet 9014-9044 feet 9050 - 9080 feet 9365-9375 feet 9640-10270 feet 10350 - 10540 feet True Vertical depth 7045.05 - 7043.98 feet 7037.65 - 7035.72 feet 7034.89 - 7030.82 feet 7029.88 - 7024.85 feet 7006.3 - 7005.91 feet 7025.09 - 7017.54 feet 7006.82 - 6993.81 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 27-7485 27-6416.2 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED OCT 2 6 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 100 32 120 963 258 Subsequent to operation: 72 24 243 1049 240 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil L2Gas WDSP GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC[-] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita. SummerhaYs(ftp.com Printed Name Nita Summerhay Title Petrotechnical Data Engineer natur Phone 564-4035 Date 8/5/2014 I Form 10-404 Revised 10/2012 aeons AUG - s zoM Submit Original Only Daily Report of Well Operations ADL0047437 .�5UMMARY coi Mob from Deadhorse. MIRU. RIH with BKR CTC Shorty MHA 5 PDS with 2.2 carrier DJSN OAL = 12.25'. Stacked wt down at 8252' pulled 10 k over, brought pump online down CT. RIH down to 9200' PU wt's clean (18 k). PUH logging at 40 ft/min. POOH. 7/7/2014 ***Job continued on WSR 07-08-2014— CTU#8 1.5"coil CV=23.9 bbl Objective: CIBP + Addperf Continue logging with BKR CTC Shorty MHA 5 PDS with 2.2 carrier DJSN CAL = 12.25'. Log from 9200' to 6600'w/ flag @ 9000.18' (Unc EOP = 8990.74'). POOH. LD logs and download (+5 correction). MU Baker shorty MHA, S30' of SLB 2006 PJ Omegas 2" guns SPF 60 Deg (OAL = 38.61' MOD= 2.12"). RIH. Correct depth to 9002.32 (TOP SHOT) at flag. RIH. Pump 1/2" ball to seat w/ 1% Slick KCL. Perforated 9050'- 9080'w/ 2.00" SLB 2006 PJOmega HMX @ 6 spf, 60 deg phz. POOH. LD spent guns. MU 30' of 2.0" SLB guns (Run 2, OAL = 38.61' MOD = 2.13"). RIH. Correct depth to 9002.32 (TOP SHOT) at flag. RIH. Pump 1/2" ball to seat w/ 1 % Slick KCL. Perforated 9014'- 9044'w/ 2.00" SLB 2006 PJOmega HMX @ 6 spf, 60 deg phz. POOH. LD spent guns. Ball recovered. MU PDS GR/CCL in carrier (OAL = 12.25' MOD = 2.2"). RIH Log 9200' to 6599.3'w/ flag @ 8999.5 (Unc EOP = 8990.06') (+2 correction).. Gun #3 MU Baker shorty MHA, S30' of SLB 2006 PJ Omegas 2" guns SPF 60 Deg (OAL = 38.61' MOD= 2.12"). 7/8/2014 ***Job continued on WSR 07-09-2014*** =Pump 10 bbls neet meth down IA. Riggedup to AL line an 7/9/2014 pumped 10 bbls deet down IA. Final WHPs=SSV/850/0 CTU#8 1.5"coil CV=23.9 bbl Objective: CIBP +Addperf Gun #3 MU Baker shorty MHA, S30' of SLB 2006 PJ Omegas 2" guns SPF 60 Deg (OAL = 38.61' MOD= 2.12"). Perforated 8976 - 9006'w/ 2.00" SLB 2006 PJOmega HMX @ 6 spf, 60 deg phz. POOH. Gun #4 MU Baker shorty MHA, S30' of SLB 2006 PJ Omegas 2" guns SPF 60 Deg (OAL = 38.61' MOD= 2.12"). Pump 1/2" ball to seat w/50/50 Meoh. Perforated 8810'- 8840'w/ 2.00" SLB 2006 PJOmega HMX @ 6 spf, 60 deg phz. POOH. Freeze protect tubing. 7/9/2014 ***Job in progress*** FLUIDS PUMPED BBLS 47 50150 METH 95.4 1% SLICK KCL 10 METH 152.4 TOTAL Casing / Tubing Attachment ADL0047437 Casing Length Size MD TVD Burst Collapse LINER 12 3-1/2" 9.3# L-80 7494 - 7506 6423.73 - 6433.79 10160 10530 LINER 2962 2-7/8" 6.16# L-80 7602 - 10564 6514.67 - 6992.2-2-13450 13890 NIPPLE 1 2-7/8" X Nipple 6670 - 6671 5844.98 - 5845.55 NIPPLE 1 2-7/8" X Nipple 6726 - 6727 5876.55 - 5877.12 NIPPLE 1 2-7/8" XN Nipple 6778 - 6779 5906.42 - 5907.01 PRODUCTION 7651 7" 26# L-80 28 - 7679 28 - 6580.13 7240 5410 SURFACE 5027 9-5/8" 40# L-80 30 - 5057 30 - 4609.3 5750 3090 TUBING 7458 2-7/8" 6.5# L-80 27 - 7485 27 - 6416.2 10570 11160 Packers and SSV's Attachment ADL0047437 SW Name Type MD TVD Depscription MPC -24A PACKER 6696 5814.81 4-1/2" HES TNT Perm Packer MPC -24A PACKER_ 7494 6378.93 7" Baker ZXP Top Packer A Tree: 41 /16", 5M Wellhead: FMC 11" x 11", 5M, en. 5 and 11" x 4 1/16" Adapter Flange 4 1/2" Tbg Hgr w/ TC -1I T&B Threads & 4" CIW 'H' BPV profile 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965' Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. = +30 deg. 9-5/8", 40#/ft., L-80 BTC 5,056' 3 1/2" 9.2 ppf, L-80 TC -II & IBT-M Tubing (drift ID = 2.867", cap = 0.0087 bpf) 7" 26#/ft., L-80 BTC -MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) (Capacity w/ 3 1/2" Tbg inside = 0.0264 bpf) Pertoration Summary Ref. Loa CCL/GR DB/00/01 Size SPF Interval TVD 149 S s �esz�ees as s �i se4s sasa Ino;,nor 9640'-10270' s %1191.' 24i s 44 _" gaze �ay� Size SPF Interval TVD 2" 6 9640'-10270' 6971'- 7002' 2" 6 10350'-10540' 6948'-6960' 2" 1 f 6 I 9365'- 9375' I 7006'-7007' I I 7-30-13 CTD Perforation c immary Add PeAs 07-09-14 Size SPF Interval TVA 2" 6 8810' - 8840' 7043'- 7045' 2" 6 8976 - 9006' 7036'-7038' 2" 6 9014'-9044 7032'-7036 2" 6 9050'- 9080' 7026'- 7030' TOL @ 7,598' ELMD Window CcD 8,040'- 8051' ELMD \ Single Solid, cemented and perf'd 3-3/16 x 2-7/8" Liner. TD = 10 580' ELMD 10;538 CTM Milled WFT CBP 7-30.13 DATE REV. BY COMMENTS 7/13/01 GMH Drill & Run Frac String. N -22E 10/5/01 GMH Nabors 4ES ESP Completion 026/18/06 MOR Nabors 43S ESP Completion /12%108 REP CTDoridetrack NorQlc Zut 2/9/10 LH ESP Completion - Nabors 4ES 08/23/13 Bill K 10,538 CTM Milled WFT CBP 7-30-13 7/9/2014 B. Bixby I CTU -Add Perfs .24A c CB Elev. = 41.5' (N -22E) Orly. GL Elev. = 17.0' RT to Tog. Spool = 27.5' (N -22E) Csg tested to 3500 psi from 7046' during 12/22/12 RWO 2604 2497 4065 3753 5044 4598 5800 5246 6524 5764 SLB 'NDPG' Gauge 6581' Gauge TVD = 5795' HES 'XD' Dura SSD 6599' SLB 'NDPG' Gauge 1" x 3 1/2" KBG-2-9 w/ BTM latch Gauge TVD = 5813' ST MD TVD I DEV TYP VLV Latch I Port Date 5 M. 2497 30 KGB Dame INTG 10/64 4/5/13 4 4065 3753 31 KGB Dome INTG 12/64 4/5/13 3 5044 4598 29 KGB Dome INTG 12/64 4/5/13 2 5800 5246 35 KGB Dome INTG 126d 4/5/13 1 16524 5764 1 56 KGB SO NTG 1fi/69 4/5/13 2604 2497 4065 3753 5044 4598 5800 5246 6524 5764 SLB 'NDPG' Gauge 6581' Gauge TVD = 5795' HES 'XD' Dura SSD 6599' SLB 'NDPG' Gauge 6613` Gauge TVD = 5813' 7594• HES 2.813" 'X' nipple 6670` HES 'TNT' Packer (2.813" ID) 6696' HES 2.813" 'X' nipple 6726' HES 2.813" 'XN' nipple 6778` (2.750" no-go ID) WLEG 6800' 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594• 7'. Float Shoe 7679' 4.5" Baker Flexlock Liner 7506' Hanger 4.5" Baker Landing Collar 8317' 4.5" HES Float Collar 8361' 4.5" HES Float Shoe 8404' (PBTD) 8406' 1 � • 1 1 1 1 1 STATE OF ALASKA A14C OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS AUG 2 12013 1. Operations Abandon Li Repair Well Li Plug Perforations Perforate Lj Other I -, I Mill Plug Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development0 Exploratory ❑ Stratigraphic❑ Service ❑ 209-134-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-23020-01-00, 7. Property Designation (Lease Number): 8. Well Name and Number: [, ADL0047437 �r' j.S�W �' ��^t� KUP MPC -24A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted MILNE POINT, KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 10580 feet Plugs measured None feet true vertical 8991.17 feet Junk measured None feet Effective Depth measured 10551 feet Packer measured See Attachment feet true vertical 6993.08 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" 92# H-40 31-113 31-113 0 0 Surface 5027 9-5/8" 40# L-80 30-5057 30-4609.3 5750 3090 Intermediate None None None None None None Production 7651 7 26# L-80 28-7679 28-6580.13 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9365-9375 feet 9640 - 10270 feet 10350 - 10540 feet True Vertical depth 7006.3 - 7005.91 feet 7025.09 - 7017.54 feet 7006.82 - 6993.81 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 27-7485 27-6416.2 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: SEP 2 213 Intervals treated (measured): SCANNED Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 81 70 104 1127 244 1 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratorl❑ Development ❑Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ✓ , Gas 0 WDSPLLJ 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: N/A Contact Nita Summerhays Email Nita. Sum merhaystED_BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician nature Phone 564-4035 Date 8/21/2013 RBDMS SEP - 5 20) Form 10-404 Revised 10/2012 Submit Original Only E Daily Report of Well Operations ADL0047437 CTU 43 - of Job Objective: FCO and Mill CBP MIRU CTU. Make up FCO BHA with 1.75" DJN, RIH. Dry tag fill at 9460. Pull uphole and bleed gas cap and confirm returns. Begin FCO from 9300'. 7/29/2013 ...Continued on WSR 7-30-13... CTU #3 - 1.b I Goil***Continued rom VVbR 7-9q-1 Job Objective: FCO, Mill CBP Continue FCO down to CBP tag at 9675' CTM, 80' deeper than expected. Chase solids out of hole @ 80%.Make up milling BHA with 2.25" mill and RIH. Tagged the plug @ 9680'. pushed the plug down to 10538' CTM, POOH. RDMO 7/30/2013 ***Job Complete*** FLUIDS PUMPED BELS 104 POWERVIS 774 1% SLICK KCL 2015 /50 METH 898 TOTAL n LJ • Casing / Tubing Attachment ADL0047437 Casing Length Size MD TVD Burst Collapse LINER 12 3-1/2" 9.3# L-80 7494 - 7506 6423.73 -16433.79 10160 10530 LINER 2962 2-7/8" 6.16# L-80 7602 - 10564 6514.67 -16992.22 13450 13890 PRODUCTION 7651 7" 26# L-80 28 - 7679 28 -16580.13 7240 5410 SURFACE 5027 9-5/8" 40# L-80 30 - 5057 30 -1 4609.3 5750 3090 TUBING 7458 2-7/8" 6.5# L-80 27 - 7485 27 - 6416.2 10570 11160 CONDUCTOR 82 20" 92# H-40 31 - 113 31 - 113 n LJ • Tree: 4 1/16", 5M Wellhead: FMC 11 " x 11 ", JRen. 5 and 11" x 4 1/16" Adapter Flange 4 1/2" Tbg Hgr w/ TC -1I T&B Threads & 4" CIW 'H' BPV profile 113` 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965' Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. = +30 deg. 9-5/8", 40#/ft., L-80 BTC 5,056' 3 1/2" 9.2 ppf, L-80 TC -II & IBTM Tubing (drift ID = 2.867", cap = 0.0087 bpf) 7" 26#/ft., L-80 BTC -MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) (Capacity w/ 3 1/2" Tbg inside = 0.0264 bpf) Perforation Summary Ref. Loa CCL/GR 08/03/01 Size SPF Interval TVD 231&.Sl 6 4P 496 911461 69Aa 2-31& 6971'- 7002' 6948'- 6960' 3993--7g32: za& 6 o CTD Sidetrack - Nordic 2 ESP Completion - Nabors 4ES 12/22/12 A9 J lftg 2-31& 6 gy8}.Q�}6 39,2&-i9§2= Size SPF Interval TVD 2" 2" 6 6 9640'-10270' 10350'-10540' 6971'- 7002' 6948'- 6960' TOL P, 7,598' ELMD 27o de Window 8,040'- 8051' ELMD Single Solid, cemented and perf'd 3-3/16 x 2-7/8" Liner. TD = 10,580' ELMD A3 A2 (t 0 DATE REV. BY COMMENTS 7/13/01 10/5/01 GMH GMH Drill & Run Frac String. N -22E Nabors 4ES ESP Completion )6/18/06 )2/27/08 MOR REH Nabors 43S ESP Completion Nabors 3S ESP change out 1/12/10 2/9/10 REH LH CTD Sidetrack - Nordic 2 ESP Completion - Nabors 4ES 12/22/12 LH Re -complete as GL Well - Doyon 16 KB Elev. = 41.5'(N -22E) O GL Elev. = 17.0' RT to Tbg. Spool = 27.5'(N -22E) Csg tested to 3500 psi from 7046' during 12/22/12 RWO 2604 2497 4065 3753 50"459858005246 6524 5764 SLB `NDPG' Gauge Gauge TVD = 5795' HES 'XD' Dura SSD SLB 'NDPG' Gauge Gauge TVD = 5813' HES 2.813" 'X' nipple HES 'TNT' Packer (2.813" ID) HES 2.813" `X' nipple HES 2.813" `XN' nipple (2.750" no-go ID) WLEG 6581 ` •• 6613' 6670' 6696' 6726` 6778' 7" Baker "ZXP" Packer 1" x 3 1/2" KBG-2-9 w/ BTM latch 7" Float Collar ST MD TVD DEV TYP VLV Latch Port Data 5 2604 2497 30 KGB Dome INT. 10/64 4/5/13 4 4065 3753 31 KGB Dome INTG 12/64 4/5/13 3 5044 4598 29 KGB Dome INTG 12/64 4/5/13 2 5800 5246 35 KGB Dome INTG 12164 4/5/13 1 6524 5764 56 KGB I SO INTG 16/64 4/5/13 2604 2497 4065 3753 50"459858005246 6524 5764 SLB `NDPG' Gauge Gauge TVD = 5795' HES 'XD' Dura SSD SLB 'NDPG' Gauge Gauge TVD = 5813' HES 2.813" 'X' nipple HES 'TNT' Packer (2.813" ID) HES 2.813" `X' nipple HES 2.813" `XN' nipple (2.750" no-go ID) WLEG 6581 ` •• 6613' 6670' 6696' 6726` 6778' 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594' 7" Float Shoe 7679' 4.5" Baker Flexlock Liner 7506' Hanger 4.5" Baker Landing Collar 8317' 4.5" HES Float Collar 8361` 4.5" HES Float Shoe 8404' (PBTD) 8406` •�• 1 1 • 1 1 1 STATE OF ALASKA Al ;A OIL AND GAS CONSERVATION COMMWIN REPORT OF SUNDRY WELL OPERATIONS KtUt1vtU MAR 12 2013 AOGCC 1. Operations Abandon H Repair Well Ll Plug Perforations U Perforate Other Lj Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑✓ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑✓ Exploratory ❑ Stratigraphic❑ Service ❑ - 209-134-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-23020-01-00 7. Property Designation (Lease Number): I.� 8. Well Name and Number: j LJ32 ADL0047437 r 5 1' KUP MPC -24A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted MILNE POINT, KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 10580 feet Plugs measured None feet true vertical 6991.17 feet Junk measured None feet Effective Depth measured 9594 feet Packer measured See Attachment feet true vertical 7017.01 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" 92# H-40 31 - 113 31 -113 0 0 Surface 5027 9-5/8" 40# L-80 30-5057 30-4609.3 5750 3090 Intermediate None None None None None None Production 7651 7" 26# L-80 28-7679 28-6580.13 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9365-9375 feet 9640 - 10270 feet 10350 - 10540 feet True Vertical depth 7006.3 - 7005.91 feet 7025.09 - 7017.54 feet 7006.82 - 6993.81 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 27-7485 27-6416.2 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): � 0 C I �fi 8 OCT r, /� 2U14 9640'-10270', 10350'-10540' Treatment descriptions including volumes used and final pressure: 353BBL MINERAL OIL, 7BBL DIESEL, 1279BBL 25# XLINK GEL, 1411 BBL 25# LINEAR GEL 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 125 200 83 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil _ ✓ Gas Lj WDSPLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 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: N/A Contact Nita Summerhays Email Nita. SummerhaysABP.com Printed Name Nita Summerh Title Petrotechnical Data Technician Signatur Phone 564-4035 Date 3/12/2013 RBDMS MAR 14 2015 �1, 4, I` - Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0047437 ea inera i o or C. o con roue on - 2/12/2013 13 WSR*** ***Job continued from 2-12-13 WSR*** LRS 46 heat Mineral Oil to 100' 2/13/2013 LRS RU to PRV skid and test PRVs to 3300 psi. Job postponed. LK6 46 heat Minerali o 1 OF for FRAC. KU to PRV si es s and set to 3300 psi. Maintain IAP while SLB Fracs well. ***Job 2/16/2013 continued on 2/17/13 WSR*** 2/16/2013 Heat Frac an s an 77 ***Job continued from 2/16/13 WSR*** Assist SLB, maintain IAP 2/17/2013 durning Frac. See log for details. ***Job continued to 2/18/18 WSR*** SLB Frac: Job Scope: Fracture Treatment - Kuparuk A Sands: Pump breakdown, scour, data frac, and fracture treatment. After break down decision was made to pump scour stage. NWBF after scour = 350 psi. Datafrac analysis showed frac gradient = 0.788 psi/ft, ISIP = 2634 psi, Pc = 2383 psi, Tc = 20.84 min, eff = 0.61, FL = 0.0025 Pump frac at 20 bpm using YF125FIexD gel system: Pad stage of 150 bbls, 1 PPA Flat stage in 100 bbls, ramp 1 PPA - 3 PPA in 100 bbls, ramp 3 PPA - 5 PPA in 250 bbls, ramp 5 PPA - 7 PPA in 100 bbls, ramp IPPA - 10PPA in 150 bbls and 10 ppa flat stage in 180 bbls. Flush volumes of 29 bbls 25# XL gel, 29 bbls 25# linear gel, and 26 bbls LVT-200 mineral oil. Seven bbls of mineral oil in surface lines, and 19 bbls in the well, placing freeze protect at 2184'. Pnet for frac = 400 psi. Pumped a total of 145,767 lbs of 20/40 SBExcell propant, of which 143,121 lbs were 2/17/2013 placed behind pipe with 12,646 lbs in pipe. ***Job Complete*** ***Job continued from 2/17/13 WSR*** Maintain IAP while SLB fracs. 2/18/2013 See log for details. Bleed IAP to 500 psi SLB on well upon departure. FLUIDS PUMPED BELS 353 MINERAL OIL 7 DIESEL 1279 25# XLINK GEL 1411 25# LINEAR GEL 3050 TOTAL Casing / Tubing Attachment ADL0047437 Casing Length Size MD TVD Burst Collapse LINER 12 3-1/2" 9.3# L-80 7494 - 7506 6423.73 - 6433.79 10160 10530 LINER 2962 2-7/8" 6.16# L-80 7602 - 10564 6514.67 - 6992.22 13450 13890 PRODUCTION 7651 7" 26# L-80 28 - 7679 28 - 6580.13 7240 5410 SURFACE 5027 9-5/8" 40# L-80 30 - 5057 30 - 4609.3 5750 3090 TUBING 7458 2-7/8" 6.5# L-80 27 - 7485 27 - 6416.2 10570 11160 CONDUCTOR 82 20" 92# H-40 31 - 113 31 113 • Packers and SSV's Attachment ADL0047437 SW Name Type MD---T—TVD Depscription MPC -24A PACKER 6696 5814.81 4-1/2" HES TNT Perm Packer MPC -24A PACKER 7494 6378.93 7" Baker ZXP Top Packer Tree: 4 1/16", 5M Wellhead: FMC 11 " x 11", 5M, Sen. 5 and 11 " x 4 1/16" Adapter Flange 4 1/2" Tbg Hgr w/ TC -II T&B Threads & 4" CIW 'H' BPV profile 113' 9-5/8" TAM Port Collar 1004' 9-5/8", 40#/ft., L-80 BTC 5,056' Perforation Summary Ref_ Loa CCL/GR 08/03/01 Size SPF Interval TVD 241& 6 411; 495 Q 6846, 686& Agg 44 249 6 D �/ Nabors 43S ESP Completion Nabors 3S ESP change out 1/12/10 2/9/10 a2 CTD Sidetrack - Nordic 2 ESP Completion - Nabors 4ES 241& 6 9448246 ;9291 ;952, Size SPF Interval TVD 2" 2" 6 6 9640'-10270' 10350'- 10540' 6971'- 7002' 6948'-6960' TOL @ 7,598' ELMD L 27a de low @ 8,040' - 8051' ELMD TD = 10,580' ELMD A3 A2I DATE REV. BY COMMENTS 7/13/01 10/5/01 GMH GMH Drill & Run Frac String. N -22E Nabors 4ES ESP Completion 06/18/06 02/27/08 MOR REH Nabors 43S ESP Completion Nabors 3S ESP change out 1/12/10 2/9/10 REH LH CTD Sidetrack - Nordic 2 ESP Completion - Nabors 4ES 12/22/12 LH Re -complete as GL Well - Doyon 16 On<B Elev. = 41.5'(N -22E) GL GL Elev. = 17.0' RT to Tbg. Spool = 27.5' (N -22E) Csg tested to 3500 psi from 7046' during 12/22/12 RWO 1 " x 3 1/2" KBG-2-9 w/ BTM latch # and tvd dg 5 2604' 2497' 30 4 4065' 3753' 31 3 5044' 4598' 29 2 5800' 5246' 35 1 6524' 5764' 56 SLB 'NDPG' Gauge 6581 ` Gauge TVD = 5795' MILNE POINT WELL C -24A API No. 50-029-23020-01 HES 'XD' Dura SSD 6599' SLB 'NDPG' Gauge 6613` Gauge TVD = 5813' HES 2.813" 'X' nipple 6670` HES 'TNT' Packer (2.813" ID) 6696' HES 2.813" 'X' nipple 6726' HES 2.813" 'XN' nipple 6778` (2.750" no-go ID) WLEG 6800' 7" Baker "ZXP" Packer 7" Float Collar 7" Float Shoe 4.5" Baker Flexlock Liner Hanger 4.5" Baker Landing Collar 4.5" HES Float Collar 4.5" HES Float Shoe (PBTD) 7494' 7594' 7679' 7506' 8317' 8361' 8404' 8406' MILNE POINT WELL C -24A API No. 50-029-23020-01 UNIT (K BE EXPLORATION (AK) STATE OF ALASKA • VASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN :I-f2013� 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service r 209-134 3. Address: 6. API Numbe_ P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-23020-01-00 7. Property Desi nation (Lease Number): „ 8. Well Name and Number: ADL 047434 & 047437 ( I ):v MPC -24A 9. Logs (list logs bnd submit electronic and printed data per 2 AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Oil Pool 11. Present well condition summary: Total depth: measured 10580' feet Plugs:(measured) None feet true vertical 6991' feet Junk: (measured) None feet Effective depth: measured 10551' feet Packer: (measured) 6696' feet true vertical 6993' feet Packer: (true vertical) 5860' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 31'- 113' 31'- 113' 1490 470 Surface 5027' 9-5/8" 30'- 5057' 30' - 4609' 5750 3090 Intermediate Production 7651' 7" 28'- 7679' 28'- 6580' 7240 5410 Liner 551' 4-1/2" 7494'-8045' 6424'-6898' 8430 7500 Liner 2962' 3-1/2" x 3-3/16" x 2-7/8" 7602'- 10564' 6515'- 6992' 10160 10530 Perforation Depth: Measured Depth: 9640'- 10540' feet True Vertical Depth: 7025'-6994' feet Tubing (size, grade, measured and true vertical depth): 3-1/2", 9.2# L-80 6801' 5919' Packers and SSSV (type, measured and true vertical depth): 7" x 3-1/2" HES TNT Packer 6696' 5860' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: cWNED i 0L 2 _2 2013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl J Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 0 0 Subsequent to operation: 0 0 0 1 0 0 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: 0A [IExploratory [IStratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: ® Oil [I Gas [3WDSPL ® Well Schematic Diagram ❑ 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: Contact: Noel Nocas, 564-4667 N/A Email: Noel.Nocas@bp.com Printed amVITL"st#Title: Drilling Technologist Signature. one: 564-4091 Date: Form 10-404 R'eqdd 10/2012 vz-,r— 7-/V/ 3 4,-q- / Submit Original Only • • Printed 1/7/2013 1:17:23PM Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-OOVWV-E: (11 7881,000 00 ) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/16/2012 08:00 - 09:30 1.50 MOB P PRE PJSM, PULL OFF MPF -14 WELL. JACK UP RIG - TEST MOVING SYSTEM ESD. - WSL AND TOOL PUSHER PRESENT. - PULL OFF WELL. - PARK IN CENTER OF PAD. 09:30 - 12:00 2.50 MOB P PRE PJSM, REMOVE BOP STACK FROM RIG. - JACK UP AND POSITION RIG AT ENTRANCE OF PAD. - MOVE WSL OFFICE TO MPC -PAD. - ORDER KWF, 120 DEG.F, 10.1 PPG BRINE. 12:00 - 12:30 0.50 MOB P PRE PJSM, REVIEW DDI RIG MOVE S.O.P. - PERFORM EQUIPMENT CHECKS - NOTIFY MPU SECURITY OF MOVE TIME. 12:30 - 19:30 7.00 MOB P PRE MOVE RIG OFF MPF -PAD TRAVEL TO MPL-PAD. LET TRAFFIC PASS. - PROCEED TO MILNE POINT SPINE L&F INTERSECTION. - 15:30 HRS MPC -24 HAS BEEN DE -MOB. - ROADS & PADS START WORK ON PAD PREP. - ARRIVE ON MPC -PAD AT 19:00 HRS. 19:30 - 22:00 2.50 MOB P PRE PJSM RAISE AND PIN THE DERRICK - UNBRIDLE THE BLOCKS - R/U FOOR EQUIPMENT - BOB NOBLE AOGCC INSPECTOR WAIVED STATES RIGHT OF WITNESS BOP TEST AT 17:50 HRS 12/16/2012. 22:00 - 00:00 2.00 MOB P PRE PJSM, REMOVE SUB WHEEL BOOSTERS - INSTALL BOP'S IN CELLAR 12/17/2012 00:00 - 03:30 3.50 MOB P PRE ROADS & PAD CONTINUE PAD PREP. -LEVEL PAD - SET RIG MATS AND BUILD RAMP W/ GRAVEL. INSTALL 11" ADAPTER ON BOP - SET NEW WELL HEAD EQUIPMENT BEHIND CELLAR. 03:30 - 05:30 2.00 MOB P PRE PJSM TEST E -STOP ON MOVING SYSTEM PRIOR TO BACKING OVER WELL - PULL OVER MPC -24A - LEVEL AND SHIM SUB BASE 12/18/2012 00:00 - 01:00 1.00 WHSUR N WAIT OTHCMP NOTIFIED RWO SUPERINTENDENT OF THE INABILITY TO START A DAYLIGHT WELL KILL DUE TO TIME RESTRAINT. - SERVICE RIG - GENERAL HOUSEKEEPING HELD RIG EVAC-DRILL AAR: - DRESS FOR COLD WEATHER WHEN EXITING. - PROPER PPE (TRACTION FOOTWEAR) Printed 1/7/2013 1:17:23PM Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-OOVWV-E: (1,788,000-00) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 03:30 2.50 WHSUR P OTHCMP PJSM WITH DSM - RU LUBRICATOR AND TEST - PULL TWC - RD LUBRICATOR - SECURE WELL - TBG PRESSURE = 850 PSI - IA PRESSURE = 850 PSI - OA PRESSURE = 0 PSI 03:30 - 06:00 2.50 WHSUR N WAIT OTHCMP - CONTINUE TO WAIT ON DAY LIGHT KILL RIG MAINTENANCE - HOUSEKEEPING - B/D HARDLINE TO FBT TWICE DURING THE NIGHT. 06:00 - 06:30 0.50 WHSUR P OTHCMP PJSM, WELL KILL OPERATIONS. - WSL, TOOLPUSHER, SCS, CH2 TRUCK PUSHER, DRILLER AND RIG CREW IN ATTENDANCE. REVIEW DDI WELL KILL SOP. Printed 1/7/2013 1:17:23PM r1 d Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 7,4-OOVWV-E: (1,788,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 11:00 4.50 WHSUR P OTHCMP WELL KILL WITH 10.1 PPG HEATED BRINE.. - WSL / TOOL PUSHER VERIFY VALVE ALIGNMENT. - SITP = 850 PSI, SICP = 850 SIOA = 0 PSI - BLEED GAS FROM IA F/ 850 T/'O' PSI IN 3 MIN. SITP/125 PSI - PUMPED 45 BBLS 10.1 PPG BRINE AT 3 BPM WITH 500-50 PSI DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK. ICP = 500 PSI - FCP = 50 PSI - BULL HEAD 40 BBLS DOWN THE TBG AT 0.8 BPM / 2950 PSI. - NOTIFY TOWN RWO ENGR. MONITOR. - SITP AFTER 17 MINUTE = 125 PSI SICP = 900 PSI. PUMPED 70 BBLS HEATED 10.1 PPG BRINE AT 5 BPM DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK. - ICP = 3 BPM / 900 PSI. 5 BPM / 1200 PSI. - PUMPED 252 BBLS KWF AT 5 BPM AND STARTED TO GET 8 PPG FORMATION WATER IN RETURNS. - AFTER PUMPING 93 BBLS KWF. - CLEAN 10.1 PPG KWF AT SURFACE, STOP PUMP. MONITOR 20 MINUTES WHILE R/U TO CIRCULATE TO PITS. - IA DEAD AND TBG HAD UNREABLE PRESSURE. -FINISH CIRCULATION 100 BBLS KWF THRU RIG CHOKE TO PITS. 5 BPM / 1450 PSI TBG 260 IA. - BLOW DOWN HARD LINES. - SHUT IN WELL WHILE VAC OUT FLOW BACK TANK. - TBG NOT DEAD, IA DEAD. MONITOR 30 MINUTES. TBG AND IA DEAD. - TOTAL LOSSES DURING WELL KILL - 40 BBLS BULLHEAD PLUS 37 BBLS KWF. - RECOVERED 47 BBLS OIL 11:00 - 11:30 0.50 WHSUR P OTHCMP CREW MEETING WITH GREG MATTSON / JOHN RALL. - DISCUSSED WELL KILL AAR. - SCS HAD VAC TRUCK MOVE DUE TO CLOSE PROXIMITY TO FBT. - REMARKED OLD KILL MANIFOLD VALVE TO REFLECT VALVE SCHEMATIC. Printed 1/7/2013 1:17:23PM Ah Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-00VWV-E: (1,788,000.00) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud DatelTime: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 12:00 0.50 WHSUR P OTHCMP PJSM, P/U DSM LUBRICATOR. - WELL SUPPORT REP AND SUPERVISOR IN ATTENDANCE. - LOSSES TO WELL LAST 12 HRS-- 63 BBLS 10.1 PPG KWF. 12:00 - 13:30 1.50 WHSUR P OTHCMP PJSM, TEST DSM LUBRICATOR T/ 250 / 3500 PSI. SET TWC PER WELL SUPPORT REP. - UD DSM LUBRICATOR. 13:30 - 15:00 1.50 WHSUR P OTHCMP PERFORM ROLLING TEST TO TEST TWC. - TEST F/ BELOW @.4 BPM WITH 610 PSI FOR 10 CHARTED MIN. - TEST TWC F/ ABOVE TO 250 / 3500 PSI FOR 5 CHARTED MIN EA. 15:00 - 16:00 1.00 WHSUR P OTHCMP PJSM, BLOW DOWN LINES. R/D KILL MANIFOLD. - VAC FLUID FROM TREE. 16:00 - 17:00 1.00 WHSUR P OTHCMP PJSM FOR N/D TREE AND NU BOPE. REVIEW DDI SOP. - BARRIERS IN PLACE, TESTED TWC, 10.1 PPG KWF AND HANGER SEALS. - FMC REP BLEED TREE VOID. - N/D TREE AND ADAPTOR FLANGE. - FMC INSPECT 2 7/8" EUE 8RD HANGER THREADS. 9.5 TURNS. - USE CONTINUOUS HOLE FILL DOWN VA WITH 10.1 PPG KWF. 17:00 - 20:00 3.00 BOPSUR P OTHCMP N/U 4 PREVENTER BOP WITH 11" X 13 5/8" SPACER SPOOL. - VERIFY PENETRATOR FOR CLEARANCE. - USE CONTINUOUS HOLE FILL DOWN VA WITH 10.1 PPG KWF. 20:00 00:00 4.00 BOPSUR P OTHCMP PJSM, TESTING BOPE EQUIPMENT. - R/U TEST EQUIPMENT. - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250/3500 PSI5 MIN EA. - TEST UPPER AND LOWER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4 1/2" TEST JOINTS TO 250/3500 PSI 5 MIN EA. - TEST BLIND RAMS, FLOOR VALVES AND CHOKE MANIFOLD TO 250/3500 PSI 5 MIN EA. - FAIL/ PASS # 3 CHOKE MANIFOLD VALVE. - SERVICE VALVE AND RETEST, GOOD TEST. -TEST WITH FRESHWATER. - CHART RECORD ALL TESTS. - AOGCC REP BOB NOBLE WAIVED WITNESS TO BOP TEST. - USE CONTINUOUS HOLE FILL DOWN VA WITH 10.1 PPG KWF. - LOSSES TO WELL LAST 12 HRS-- 23 BBLS 10.1 PPG KWF. - WELLBORE TAKING 2- 4 BPH. Printed 1/7/2013 1:17:23PM Printed 1/7/2013 1:17:23PM Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-OOVWV-E: (1,788,000.00) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/19/2012 00:00 - 01:00 1.00 BOPSUR P OTHCMP PJSM, CONTINUE BOP TEST. - COMPLETE TESTING WITH 4 1/2" TEST JT. - PERFORM FLOW TEST ON MANUAL AND SUPER CHOKE. - PERFORM ACCUMULATOR DRAW DOWN TEST. - USE CONTINUOUS HOLE FILL DAWN VA WITH 10.1 PPG KWF. 01:00 01:30 0.50 BOPSUR P OTHCMP R/D TEST EQUIPMENT. - DRAIN BOP. BLOW DOWN CHOKE MANIFOLD AND KILL LINE. 01:30 - 03:00 1.50 BOPSUR P DECOMP PJSM. R/U OFF CENTER LUBRICATOR. - CLOSE ANNULAR. PRESSURE TEST TO 250/3500 PSI 5 MIN EA. CHARTED. - DSM PULL TWC. TBG ON SLIGHT VAC. - OPEN ANNULAR. R/D LUBRICATOR. 03:00 - 04:00 1.00 PULL P DECOMP PJSM FOR PULLING HANGER TO RIG FLOOR WITH FMC, CENTRALIFT AND CREW. - REVIEW PLAN FOR CUTTING CABLE AND R/U TO CIRC. - REVIEW PLAN FOR WELL CONTROL. - M/U 2 7/8" LANDING JT WITH FOSV. - UNSEAT HANGER AT 100K. INCLUDES 40K TOP DRIVE WT. - P/U WT 90K. INCLUDES 40K TOP DRIVE WT. - PULL HANGER AND FULL JT TO LOWER CLAMP. CUT ESP CABLE. LOWER HANGER TO RIG FLOOR. - S/O WT 85K. INCLUDES 40K TOP DRIVE WT. - UD LANDING JT. - M/U FOSV, HEADPIN AND CIRC HOSE. - CLOSE ANNULAR. - LINE UP TO CIRC DOWN TBG WITH RETURNS THROUGH CHOKE AND GAS BUSTER. 04:00 - 05:00 1.00 PULL P DECOMP CIRCULATE BOTTOMS UP 5 BPM 1480 PSI WITH 10.1 PPG BRINE. - LOST (2) BBLS TO FORMATION WHILE CIRCULATING. 05:00 - 11:30 6.50 PULL P DECOMP POOH W/ 2 7/8" TUBING, STANDING BACK. - CONTINUOUS HOLE FILL, LOSS RATE 2 - 3 BPH. 11:30 - 12:00 0.50 PULL P DECOMP PJSM. BREAK DOWN ESP ASSEMBLY. - BREAK DOWN/ LAY DOWN ASSEMBLY AS PER CENTRILIFT. LOSSES TO WELL LAST 12 HRS = 48 BBLS. - RECOVERED 123 LA SALLE CLAMPS, 7 PUMP CLAMPS, 3 PROTECTRALIZERS AND 2 FLAT GUARDS. 12:00 - 14:00 2.00 PULL P DECOMP PJSM. INSPECT FLOOR EQUIPMENT. - CONTINUE TO LAY DOWN PUMP / MOTOR ASSEMBLY. 14:00 - 16:00 2.00 PULL P DECOMP PJSM. CLEAR AND CLEAN FLOOR. -RIG DOWN TRUNK AND SHEAVE. 16:00 - 16:30 0.50 EVAL P DECOMP PJSM. PICK UP RUNNING TOOL. - SET WEAR BUSHING, LAY DOWN RUNNING TOOL. - 9" ID OF WEAR BUSHING. Printed 1/7/2013 1:17:23PM r� VA i FIN Common Well Name: MPC -24 AFE No X4-00VWV-E: (1,788,000.00) Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 20:30 4.00 EVAL P DECOMP PJSM, WU 7" CHAMP 4 PACKER BHA. - 7" PACKER # 10256836, XO, 2 7/8" EUE PUP-- UP=16.45' 16.45' - RIH WITH 223 JTS 2 7/8 EUE WORK STRING FROM DERRICK. - RIH TO 7050' WITH CENTER OF PACKER ELEMENT AT 7046' MD. - INSTALL FOSV 20:30 - 00:00 3.50 EVAL N RREP 7,050.0 DECOMP PJSM FOR C/O ENCODER ON TOP DRIVE. - REVIEW PLAN FOR C/O ENCODER WITH RIG ELECTRICIAN, CREW, TOOL PUSHER AND WSL. - REVIEW DDI HAZARDOUS ASSESMENT. - DISCUSS PROCESS SAFETY FOR WELL CONTROL WHILE WORKING ON TOP DRIVE. - POSITION TOP DRIVE AS LOW TO RIG FLOOR AS POSSIBLE. - FOLLOW DDI LOCKOUT TAGOUT SOP. - RIG ELECTRICIAN C/O TOP DRIVE ENCODER PER DDI ASSESMENT GUIDELINES. - USE CONTINUOUS HOLE FILL FROM TRIP TANK. - CONTINUOUSLY MONITOR VOLUMES WHILE WORKING ON TOP DRIVE. - LOSSES TO WELL LAST 12 HRS-- 32 BBLS 10.1 PPG BRINE. - LOSSES TO WELL CONTINUE AT 2-3 BPH - LOAD COMPLETION JEWELRY INTO PIPE SHED. 12/20/2012 00:00 - 06:30 6.50 EVAL N RREP 7,046.0 DECOMP PJSM FOR C/O ENCODER ON TOP DRIVE. - REVIEW PLAN FOR C/O ENCODER WITH RIG ELECTRICIAN, CREW, TOOL PUSHER AND WSL. REVIEW DDI HAZARDOUS ASSESMENT. - DISCUSS PROCESS SAFETY FOR WELL CONTROL WHILE WORKING ON TOP DRIVE. - RIG ELECTRICIAN CONTINUES C/O TOP DRIVE ENCODER. - USE CONTINUOUS HOLE FILL FROM TRIP TANK. - CONTINUOUSLY MONITOR VOLUMES WHILE WORKING ON TOP DRIVE. 06:30 - 07:30 1.00 EVAL P DECOMP PJSM. SETTING AND TESTING PACKER & CASING. - SET PACKER @ 7046'. 76K UP WT, 70K DOWN WT. FILL HOLE, CLOSE UPPER PIPE RAMS. - LINE UP AND TEST 7" CASING TO 250 / 3500 PSI. 2.8 BBLS TO ACHIEVE 3700 PSI. - BLED OFF 70 PSI IN 1ST 15 MINUTES AND 15 PSI IN 2ND 15 MINUTES WITH GOOD FLAT LINE FOR LAST 10 MINUTES OF TEST, CHARTED. - RECEIVED PERMISSION FROM WTL TO PROCEED AHEAD. Printed 1/7/2013 1:17:23PM e e Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-00VWV-E: (1,788,000.00) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 08:00 0.50 EVAL P DECOMP PJSM. BLEED PRESSURE, OPEN UPPER RAMS. - RELEASE PACKER. - MONITOR WELL F/ 10 MINUTES, WELL STABLE. 08:00 - 12:00 4.00 EVAL P DECOMP PJSM. POOH W/ 2 7/8" TUBING. - POOH & UD 2 7/8" TUBING. - CONTINUOUS HOLE FILL, WELL TAKING 2 - 3 BPH OVER PRESCRIBED HOLE FILL. - LAST 12 HRS 33 BBLS LOST TO WELL BORE. - SLOW PUMP RATE ON BOTTOM, 20 SPM / 190 PSI. 12:00 - 13:00 1.00 EVAL P DECOMP SERVICE RIG EQUIPMENT. - INSPECT AND LUBRICATE RIG. 13:00 - 15:00 2.00 EVAL P DECOMP PJSM. CONTINUE TO UD 2 7/8" TUBING. - CONTINUOUS HOLE FILL, WELL TAKING 2 - 3 BPH OVER HOLE FILL. 15:00 - 15:30 0.50 EVAL P DECOMP PJSM. PICK UP RUNNING TOOL - BOLDS, PULL WEAR BUSHINHG, UD RUNNING TOOL. 15:30 - 19:00 3.50 RUNCOM P RUNCMP PJSM, R/U TO RUN 3 1/2" COMPLETION STRING. - R/U DDI3 1/2" TORQUE TURN EQUIPMENT - R/U SLB I -WIRE EQUIPMENT. 19:00 - 19:15 0.25 RUNCOM P RUNCMP PJSM FOR RUNNING COMPLETION. - IN ATTENDANCE, WSL, TOOL PUSHER, CREW, SLB, HES AND DDI TORQUE TURN REPS. - REVIEW RUNNING ORDER PER WSL TALLY. - DISCUSS PLAN FOR NON SHEARABLES ACROSS BOP. - REVIEW DDI SOP FOR RUNNING COMPLETION. 19:15 - 20:00 0.75 RUNCOM P RUNCMP M/U PACKER AND TAILPIPE ASSEMBLY PER HES REP AND WSL TALLY. - BAKER LOC ALL CONNECTIONS BELOW PACKER. - USE STABBING GUIDE. - USE JET LUBE SEAL GUARD THREAD COMPOUND. - USE TORQUE TURN WITH COMPENSATOR, USE OPTIMUM TORQUE 2300 FT LBS. 20:00 - 00:00 4.00 RUNCOM P RUNCMP INSTALL DOWNHOLE PRESSURE GUAGE. - PRESSURE TEST TO 5000 PSI FOR 15 MIN. - SLB INSTALL I -WIRE. - RIH WITH 3 1/2" GAS LIFT COMPLETION PER WSL TALLY FOLLOWING WELL PLAN STEPS. - INSTALL CABLE CLAMP ON EVERY JT. - TEST I -WIRE CONTINUITY AND GUAGE FUNCTION EVERY 10 JTS RAN. - USE CONTINUOUS HOLE FILL WITH 10.1 PPG BRINE. - RIH 261' - LOSSES TO WELL LAST 12 HRS-- 26 BBLS 10.1 PPG BRINE. - WELL CONTINUES TAKING 2-3 BPH. Printed 1/7/2013 1:17:23PM Ah Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-00VWV-E: (1,788,000-00) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Daterrime: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/21/2012 00:00 - 00:15 0.25 RUNCOM P RUNCMP PJSM FOR RUNNING COMPLETION. - IN ATTENDANCE, WSL, TOOL PUSHER, CREW, SLB, HES AND DDI TORQUE TURN REPS. - REVIEW RUNNING ORDER PER WSL TALLY. - DISCUSS PLAN FOR NON SHEARABLES ACROSS BOP. - REVIEW DDI SOP FOR RUNNING COMPLETION. 00:15 - 05:00 4.75 RUNCOM P RUNCMP - RIH FROM 261' WITH 3 1/2" GAS LIFT COMPLETION PER WSL TALLY FOLLOWING WELL PLAN STEPS. - INSTALL. CABLE CLAMP ON EVERY JT. - TEST t -WIRE CONTINUITY AND GAUGE FUNCTION EVERY 10 JTS RAN. - USE STABBING GUIDE. - USE JET LUBE SEAL GUARD THREAD COMPOUND. - USE TORQUE TURN WITH COMPENSATOR, USE OPTIMUM TORQUE 2300 FT LBS. - USE CONTINUOUS HOLE FILL WITH 10.1 PPG BRINE. - RIH TO 3050' WITH 74 JTS IN. 05:00 - 12:00 7.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 3 1/2" COMPLETION. INSTALLING CLAMP ON EVERY JT. - TESTING I WIRE CONTINUITY AND GAUGE FUNCTION EVERY 10 JTS. - CONTINUOUS HOLE FILL, WELL TAKING 2 - 3 BPH. 10.1 PPG BRINE LOST TO WELL BORE LAST 12) HRS = 21 BBLS. 12:00 - 16:00 4.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 3 'V2" COMPLETION. - INSTALLING CLAMP ON EVERY JT. - TESTING I WIRE CONTINUITY AND GAUGE FUNCTION EVERY 10 JTS. - CONTINUOUS HOLE FILL, WELL TAKING 2 - 3 BPH. 16:00 - 18:00 2.00 RUNCOM P RUNCMP PJSM. PICK UP LANDING JT. - MAKE UP TUBING HANGER W/ TORQUE TURN. - P/U WT= 91 K. S/O WT= 86K INCLUDES 40K TOP DRIVE WT. - LAND TBG HANGER WITH TBG SET AT 6800' MD. - LAND HANGER WITH I -WIRE ORIENTED AWAY FROM VA VALVE. - DDI 16 RK6= 23.05' MD. - RILDS PER FMC REP. - BACK OUT AND UD TBG HANGER. 18:00 - 19:30 1.50 RUNCOM P RUNCMP PJSM WITH VAC TRUCK DRIVERS, MI, HES REP, TOOL PUSHER, WSL AND CREW. - R/U TO REVERSE CIRCULATE DOWN VA WITH RETURNS OUT TBG. - CLOSE BLIND RAMS. - TEST LINES TO 250/3500 PSI 5 MIN EA. CHARTED. Printed 1/7/2013 1:17:23PM Printed 1/7/2013 1:17:23PM Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-00VWV-E: (1,788,000.00) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 23:00 3.50 RUNCOM P RUNCMP REVERSE CIRCULATE PUMPING 150 BBLS 10.1 PPG BRINE 3 BPM AT 400 PSI. - FOLLOWED WITH 300 BBLS 120 DEG 10.1 PPG BRINE WITH MI KI -3908 CORROSION INHIBITOR. SHUT DOWN PUMP. BLEED OFF PRESSURE. - OPEN BLIND RAMS. 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM, WU LANDING JT. HES REP DROP BALL AND ROD. - UD LANDING JT. CLOSE BIND RAMS. - SET AND TEST PACKER PER HES REP. - LET ROD FALL FOR 20 MIN. - PRESSURE UP ON TBG TO SET PACKER. - LINE UP AND PUMP DOWN TBG 1 BBL TO 3600 PSI. - SETTING PACKER AT 6700' MD. - SHUT IN AND TEST 3 V2" TBG TO 3600 PSI FOR 30 MIN. - CHART RECORD TEST. - 1ST 15 MIN LOST 100 PSI, LAST 15 MIN LOST 40 PSI. - PASSING TEST. - LOSSES TO WELL LAST 12 HRS-- 39 BBLS 10.1 PPG BRINE. 12/22/2012 00:00 - 02:00 2.00 RUNCOM P RUNCMP PJSM WITH ONCOMING CREW, WSL, TOOLPUSHER AND HES REP. - BLEED OFF TBG PRESSURE TO 1500 PSI AND SHUT IN. ATTEMPT TO TEST VA TO 3500 PSI. LINE UP AND PRESSURE UP VA TO 3500 PSI. - DURING PRESSURE UP SEQUENCE FROM 1500 PSI TO 2300 PSI RAPID INCREASE IN TBG PRESSURE, TRACKING VA PRESSURE TO 3500 PSI. - BLEED OFF VA SLOWLY WITH TBG PSI BLEEDING OFF ALSO TO 0 PSI. - NOTIFY ODE, REVIEW OPTIONS WITH HES REP. - SUSPECT SHEAR VALVE SET IN GLM AT 2610' SHEARED. - THUS CAUSING COMMUNICATION BETWEEN VA AND TBG. - DECISION MADE TO PERFORM TBG VA COMBINATION MIT. 02:00 - 02:30 0.50 RUNCOM P RUNCMP PJSM, PUMP 2.7 BBLS PRESSURING UP ON TBG AND VA TO 3700 PSI. - PERFORM COMBINATION MIT ON VA X TBG FOR 30 MIN. - LOST 60 PSI 1ST 15 MIN AND 0 PSI IN LAST 15 MIN OF TEST. - CHART RECORD TEST. PASSING TEST. - NOTIFY WTL OF TEST RESULTS AND RECIEVE APPROVAL TO CONTINUE OPS. BLEED PRESSURE OFF VA AND TBG. - OPEN BLIND RAMS. 02:30 - 03:00 0.50 RUNCOM P RUNCMP CIRCULATE BOTH WAYS DOWN TBG AND VA TO CLEAR ANY DEBRIS AT HANGER. - USE DRY ROD AND INSTALL TWC PER WELL PLAN. Printed 1/7/2013 1:17:23PM r -I ' 111 011 IBM 1 01 Common Well Name: MPC -24 AFE No Event Type: WORKOVER (WO) Start Date: 12/16/2012 End Date: 12/22/2012 X4-00VWV-E: (1,788,000.00) Project: Milne Point Site: M Pt C Pad Rig Name/No.: DOYON 16 Spud Datelrime: 7/13/2001 12:00:OOAM Rig Release: 12/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @44.8ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 03:30 0.50 RUNCOM P RUNCMP PJSM, PRESSURE TEST TWC FROM BELOW TO 1000 PSI FOR 10 MIN. - CLOSE BLIND RAM AND TEST TWC FROM ABOVE TO 250 PSI FOR 5 MIN. - TEST TO 3500 PSI FOR 10 MIN. - CHART RECORD TESTS. - OPEN BLIND RAMS. 03:30 - 05:00 1.50 BOPSUR P POST PJSM FOR N/D BOPE. BLOW DOWN LINES. - N/D BOPE. 05:00 - 07:30 2.50 WHSUR P POST PJSM- - FMC CLEAN AND INSPECT HANGER AND INSTALL NECK SEAL. - N/U ADAPTER FLANGE, SLB TERMINATE I -WIRE. - TEST VOID TO 250 PSI / 5 CHARTED MIN, 5000 PSI / 30 CHARTED MIN, OK. - SCHLUMBERGER TEST I -WIRE, ALL GOOD. 07:30 - 10:00 2.50 WHSUR P POST PJSM. " NIPPLE UP TREE & FILL W/ DIESEL. - PRESSURE TEST TREE @ 250 / 5000 PSI, 5 CHARTED MIN EACH, OK. 10:00 - 11:00 1.00 WHSUR P POST PJSM. SUCK DIESEL OUT OF TREE. - NIPPLE UP ADAPTER FLANGE ON WING VALVE FOR FREEZE PROTECT. 11:00 - 12:00 1.00 WHSUR P POST PJSM. PICK UP LUBRICATOR. - PRESSURE TEST @ 250 3500 PSI, 5 MIN EACH/CHARTED, OK. LOST (7) BBLS 10.1 PPG BRINE TO WELL LAST (12) HOURS. 12:00 - 12:30 0.50 WHSUR P POST PJSM. PULL TWO WAY CHECK VALVE. - LAY DOWN LUBRICATOR. 12:30 - 14:30 2.00 WHSUR P POST PJSM W/ LITTLE RED SERVICES. - PRESSURE TEST LINES @ 250 / 3500 PSI, 5 MIN EACH / CHARTED, OK. - PUMP (8) BBLS 60 DEGREE DIESEL DOWN I/A TAKING BRINE RETURNS UP TUBING. - PUMPING @.8 BPM, 200 PSI ICP, 350 PSI FCP. 14:30 - 15:30 1.00 WHSUR P POST PJSM. ALLOW DIESEL TO U TUBE BACK INTO TUBING. - CHECK FOR PRESSURE, NO PRESSURE. 15:30 - 17:30 2.00 WHSUR P POST PJSM. PICK UP LUBRICATOR. - PRESSURE TEST LUBRICATOR @ 250 3500 PSI / CHARTED, OK. - SET BPV. 17:30 - 18:30 1.00 WHSUR P POST PJSM. R/U LRS. - TEST BPV FROM BELOWTO 1000 PSI FOR 10 CHARTED MIN WITH DIESEL. 18:30 - 19:00 0.50 BOPSUR P POST R/D LITTLE RED. - BLOW DOWN AND RIG DOWN LINES. - SECURE TREE. 19:00 - 19:30 0.50 RIGD P POST PJSM FOR PULLING OFF WELL. WARM RIG MOVE SYSTEM. - MOVE EQUIPMENT. - DSO DECLINED TO WITNESS PULLING OFF WELL. - RIG RELEASED FROM MPC -24A AT 1930 HRS. Printed 1/7/2013 1:17:23PM Tree: 4 1/16", 5M Wellhead: FMC 11" x 11", 5 PGen. 5 and 11 " x 4 1/16" Adapter Flange 4 1 /2" Tbg Hgr w/ TC -11 T&B Threads & 4" CIW 'H' BPV profile 113' 9-5/8" TAM Port Collar 1004` KOP @ 400` to 1965` Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. = +30 deg. 9-5/8", 40#/ft., L-80 BTC 5,056' 11 3 1/2" 9.2 ppf, L-80 TC -II & IBT M Tubing (drift ID = 2.867", cap = 0.0087 bpf) 7" 26#/ft., L-80 BTC -MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) (Capacity w/ 3 1/2" Tbg inside = 0.0264 bpf) Perforation Summary Ref i — nni /r;R nR/n�/m Wig. KB Elev. = 41.5'(N -22E) Orig. GL Elev. = 17.0' RT to Tbg. Spool = 27.5'(N -22E) Csg tested to 3500 psi from 7046' during 12/22/12 RWO 1" x 3 1/2" KBG-2-9 w/ BTM latch # and tvd dg 5 2604' 2497' 30 4 4065' 3753' 31 3 5044' 4598' 29 2 5800' 5246' 35 1 6524' 5764' 56 SLB'NDPG'Gauge 6581` Gauge TVD = 5795' HES `XD' Dura SSD 6599' Size SPF Interval TVD CTD Sidetrack - Nordic 2 LH ESP Completion - Nabors 4ES LH Re -complete as GL Well - Doyon 16 Hanger 2218 6 79137;996 5846=-6863 SLB `NDPG' Gauge 6613` g3 Gauge TVD = 5813' 6 HES 2.813" `X' nipple 6670' 6 n+neon c �� HES `TNT' Packer (2.813" ID) 6696` Perforation Summary Ref Baker H yah c iNT D MWD R/R 07- AN- 0'10 j HES 2.813"X nipple 6726` Size SPF Interval TVD HES 2.813" 'XN' 6778` 2" 6 9640'- 10270' 6971'-7002' nipple 2" 6 10350'- 10540' 6948'-6960' (2.750" no-go ID) WLEG 6800` TOL (a) 7,598' ELMD 27o de Window @ 8,,040'- 8051' ELMD Single Solid, cemented and perf'd 3-3/16 x 2-7/8" Liner. DATE I REV. BY 06/18/06 02/27/08 12/22/12 COMMENTS MOR REH Nabors 43S ESP Completion Nabors 3S ESP change out REH CTD Sidetrack - Nordic 2 LH ESP Completion - Nabors 4ES LH Re -complete as GL Well - Doyon 16 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594' 7" Float Shoe 7679' 4.5" Baker Flexlock Liner 7506' Hanger 4.5" Baker Landing Collar 8317` 4.5" HES Float Collar 8361' 4.5" HES Float Shoe F 8404' (PBTD) 8406' DATA SUBMITTAL COMPLIANCE REPORT 8/13/2012 Permit to Drill 2091340 Well Name/No. MILNE PT UNIT KR C -24A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23020-01-00 MD 10580 TVD 6991 Completion Date 2/9/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survrjr Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, GR / CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Meoll-rmt Numoer Name INV Jwit VLVr! + • w +�••••••�•• Log Neutron 25 Blu 7160 10463 Case 2/24/2010 MCNL, Mem Lee, CCL, GR, TNF, TNN ED ' C Lis 19384 Neutron 7145 10471 Case 2/24/2010 CH LIS GR, CNT Plus PDS Graphics Rpt LIS Verification 7615 10580 Open 4/24/2010 For 19565 ED C Lis 19565 Induction/Resistivity 7615 10580 Open 4/24/2010 OH LIS GR, ROP, RAD, RAS, RPD, RPS Data Plus CGM & PDF Graphics Log Induction/Resistivity 25 Col 8045 10580 Open 4/26/2010 MD MPR, GR LZ Log / Induction/Resistivity 5 Col 8045 10580 Open 4/26/2010 TVD MPR, GR Log v Gamma Ray 25 Col 8045 10580 Open 4/26/2010 MD GR Log / Gamma Ray 5 Col 7610 10580 Open 4/26/2010 Depth Shift Monitor Plot Rpt LIS Verification 7615 9410 Open 4/28/2010 P131 for 19567 ED Lis 19567 Induction/Resistivity 7615 9410 Open 4/28/2010 P61 OH LIS GR, ROP, RAD, RAS, RPD, RPS Data Plus CGM & PDF Graphics Log / Induction/Resistivity 25 Col 8040 9410 Open 4/28/2010 P131 MD MPR, GR Log Induction/Resistivity 5 Col 8040 9410 Open 4/28/2010 P131 TVD MPR, GR Log Gamma Ray 25 Col 8040 9410 Open 4/28/2010 P131 MD GR Log / Gamma Ray 5 Col 7610 9410 Open 4/28/2010 PB1 Depth Shift Monitor Plot ED ` E Asc Directional Survey 8497 10580 Open Rpt Directional Survey 8497 10580 Open ED �-C Asc Directional Survey 7957 9410 Open P131 11 • DATA SUBMITTAL COMPLIANCE REPORT 8/13/2012 Permit to Drill 2091340 Well Name/No. MILNE PT UNIT KR C -24A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23020-01-00 MD 10580 TVD 6991 Completion Date 2/9/2010 Completion Status 1-0I1- Current Status 1 -OIL UIC N C -p - Directional Survey 7957 9410 Open PB1 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFOR= Well Cored? Chips Received? --Y rlg— Analysis Received? Comments: Compliance Reviewed By: t Daily History Received? Q ��y, N Formation Tops b / N L Date: • COMPANY WELL NAME FIELD I V � EE D _E 1 NOW,® _ BAKER HY6ME5 Baker Atlas PRINT DISTRIBUTION LIST BP EXPLORA'I ION (ALASKA) INC COUNTY NOKTH SLOPE BOROUGH MPC -24A STATE ALASKA Milne Point Unit DATE 4/23/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: Donna Moss SO #:2948650 Copies of Copia Digital Copies of Copia Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated BY: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston Texas 77073 This Distribution List Completed By: CP09 -13q Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7`" Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPC -24A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job#: 2948650 c�bn) - 13q s Sent by: Donna Moss Date: 04/23/10 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 FEARS BAKER mucmn uv t r:V Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 M aM BAKER HUGMES • Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUN 1 Y NORTH SLOPE BOROUGH WELL NAME MPC-24APB1 STATE ALASKA FIELD Milne Point Unit DATE 4/27/2010 THIS DISTRIBUTION LIST AUTHORIZED BY. Donna Moss SO #: 2948650 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-I Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE AK 99501 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MA14NKEN Person. Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: cqdo�-'3� Page 1 of 1 • a INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 71h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPC-24APB1 ?R 2 8 Contains the following: 1 LDWG Compact Disc ! (Includes Graphic Image files) 1 LDWG lister summary a 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job#: 2948650 r Sent by: Donna Moss Date: 04/27/10 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 IPA®N BAKER M MMES u-4iG04 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 Scahmherper, Alaska Data & Consulting Services 2525 Gembail Street, Suite 400 Anchorage, AK 98503-2838 ATTN: Beth Well Job 8 NO. 5473 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD r�ar+ac ha,nnvn�cvvc nc..c.�. o. �...,..,... ..... ..�............ .,.._..... _�._.. ._. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 02/1 H/10 I��L�� ' 0-0-- r�ar+ac ha,nnvn�cvvc nc..c.�. o. �...,..,... ..... ..�............ .,.._..... _�._.. ._. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 02/1 H/10 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED .rEB 2 2 2010 WELL COMPLETION OR RECOMPLETION REPOR 1a. Well Status: ® Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 20AAC 25.105 20AAC 25.110 1b. Well Class:�n(�h ® DeveloprrlmPor xploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: Permit to Drill Number. BP Exploration (Alaska) Inc. 2/9/2010 209-134 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 12/29/2009 50-029-23020-01-00 4a. Location of Well (Governmental Section): 7. Date T. D. Reached: 14. Well Name and Number. Surface: 1/7/2010 MPC -24A 1171' FSL, 2446' FEL, SEC. 10, T13N, R10E, UM 8. KB (ft above MSL): 44,80 15. Field / Pool (s): Top of Productive Horizon: 1295' FNL, 21' FWL, SEC. 14, T13N, R10E, UM GL (ft above MSL): 16.2' Milne Point Unit / Kuparuk River Total Depth: Oil Pool 9. Plug Back Depth (MD+TVD): 1975' FNL, 2198' FWL, SEC. 14, T13N, R10E, UM 10551' 6993' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD): 16. Property Designation: Surface: x- 558013 y- 6029452 Zone- ASP4 10580' 6991' ADL 047434 & 047437 11. SSSV Depth (MD+TVD): 17. Land Use Permit: TPI: x- 560504 y- 6027006 Zone- ASP4 Total Depth: x- 562688 y- 6026344 Zone- ASP4 None 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): 18. Directional Survey: ® Yes ❑ No Submit electronic and printed information per 20 AAC 25.050 N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: 1 MWD DIR, GR, RES, GR / CCL 8045' 6898' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TvD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 9# H-4 1' 113' 1' 11 x Ar i A r ' 1 -1 7" 7679' -1/2" 7 x 4-1/2" 1 74 4' 6-1/8" 11 3-1/2" x 3-3/16" / # 10564'l 4-1/8" 150 sx Class'G' x 2-7/8" 1 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET MD PACKER SET MD / TVD (MD+TVD of Top & Bottom; Perforation Size and Number): 2-7/8", 6.5#, L-80 7485' 2" Gun Diameter 6 spf MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9640'- 10270' 7025'- 7018' 10350'- 10540' 7007'- 6994' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2300' Freeze Protected w/ 37 Bbls of Diesel 27, PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 19, 2010 Electric Submersible Pump Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: 2/19/2010 12 Test Period 180 -0- 58 N/A 710 Flow Tubing Casing Press: Calculated OIL -BBL: GAs-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 241 260 24 -Hour Rate 360 -0- 116 Not Available 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results pe f � 1. IT d None I RBDMS FEB 2 3 2010 ~° Form 10-407 Revised 12/2009 CONTINUED ON REVERSE �• Z�'�� C0ri incl Only V l/l /O r� n 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS ` NAME MD TVD Well Tested? ❑ Yes ® No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kuparuk A 8158' 6990' None Kuparuk A3 8175' 7002' Kuparuk A2 8217' 7025' Kuparuk A2 9090' 7023' Kuparuk A2 10285' 7015' Formation at Total Depth (Name): Kuparuk A2 10285' 7015' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. 1 hereby certify that the foregoing ' true and correct to the best of my knowledge. Oo /z— /%h �v,Jl Signed: Terrie Hubble /%� Title: Drilling Technologist Date: (/ v MPC -24A 209-134 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Sean McLaughlin, 564-4387 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only II BP EXPLORATION Page 1 of 6 Operations Summary Report P 61k Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/21/2009 00:00 - 06:00 6.00 RIGD P PRE RIG DOWN OPERATION I SCOPE DOWN AND LAY OVER DERRICK. -AOGCC GIVEN 24-HR. NOTICE OF IMPENDING BOPE TEST. -NOTICE GIVEN AT 11:50-HRS. ON 11/20/2009. -CHUCH SCHEVES W/AOGCC WAIVED TEST WITNESS 06:00 - 07:00 1.00 MOB P PRE MOVE PITS, PIPE SHED AND SUB OFF WELL. -PICK UP RIG MATS AND HERCULITE AROUND WELLHEAD. 07:00 - 09:00 2.00 MOB P PRE MOVE RIG COMPONENTS FROM MPE-14 TO MPC-24 09:00 - 12:30 3.50 RIGU P PRE SPOT SUB, PITS AND PIPESHED. -RAISE AND SCOPE DERRICK. -HOOK UP LINES BETWEEN SUB AND PITS. 12:00 - 15:00 3.00 RIGU P PRE RAISE AND SCOPE DERRICK. 15:00 - 18:00 3.00 RIGU P PRE ACCEPTED RIG AT 17:00 HRS. -RU, SPOT TIGER TANK AND HOOK UP LINES. -RU CIRCULATING LINES TO TREE WING VALVE AND IA. -TEST LINES TO 3,500 PSI. -PASS. 18:00 -19:00 1.00 RIGU P PRE PU AND RU LUBRICATOR -TEST WITH DIESEL TO 500 PSI. -PASS. 19:00 - 23:30 4.50 KILL P DECOMP CIRCULATE KILLFLUID, 8.45 PPG 120 DEG SEAWATER. -BLEED DOWN TBG AND IA. -PUMP 58 BBLS HEATED SEAWATER DOWN THE TBG 3 BPM @ 0/30 PSI -NO RETURNS -COMFIRM W/ ADW RWO ENGINEERING ON PLAN FORWARD. ;$ULL HEAD 300 BBLS HEATED SEAWATER DOWN THE IA 3 BPM @ 30-1080 PSI -PUMP 50 BBLS DOWN THE TBG, 3 BPM @ 30-980 PSI 23:30 - 00:00 0.50 KILL P DECOMP -MONITOR WELL - WELL WAS DEAD- WELL ON VAC BOTH TBG AND IA -PUMPED A TOTAL OF 408 BBLS. -LOST 161 BBLS TO THE FORMATION. 11/22/2009 00:00 - 01:30 1.50 WHSUR P DECOMP (FMC) SET TWC WITH T-BAR -TESTED FROM ABOVE TO 3500 PSI FOR 10 CHARTED MIN -CONDUCTED ROLLING TEST FROM BELOW INJECTED 50 BBLS, REACHED 500 PSI. 01:30 - 03:30 2.00 WHSUR P DECOMP ND PRODUCTION TREE AND ADAPTER FLANGE. -TREE WILL STAY ON LOCATION 03:30 - 06:00 2.50 BOPSUF P DECOMP NU BOPE. -RIG UP BOPE TEST EQUIPMENT. 06:00 - 07:00 1.00 BOPSUE P DECOMP INSPECT DERRICK SERVICE DRAWORKS 07:00 - 13:30 6.50 BOPSUF P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. Printed: 2/11/2010 10:50:32 AM BP EXPLORATION Operations Summary Report Page 2 of 6 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code I NPT Phase Description of Operations 11/22/2009 107:00 - 13:30 1 6.501 BOPSURP 13:30 - 14:30 1.00 BOPSU P 14:30 - 16:00 1.50 BOPSU 16:00 - 17:00 1.00 BOPSU P 17:00 - 19:00 2.00 WHSUR P 19:00 - 20:00 I 1.001 PULL IP 20:00 - 21:00 1 1.001 WHSUR I P 21:00 - 21:30 0.50 PULL P 21:30 - 00:00 2.50 PULL P 11/23/2009 00:00 - 06:00 6.00 PULL P 06:00 - 06:30 1 0.50 PULL P 06:30 - 07:30 1.00 PULL P 07:30 - 10:3 1 3.00 PULL P DECOMP -2 7/8" X 5" VARIABLE BORE RAMS. -TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" AND 4 1/2" TEST JOINTS. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. -TESTED KELLY 200 PSI BUILD UP FROM 1600 PSI = 52 SECONDS. -FULL BUILD UP TO 3000 PSI = 208 SECONDS. -4 BOTTLES x 1525 PSI. -CHUCK SCHEVES WAIVED AOGCC RIGHT TO WITNESS BOPE TESTING AT 11:00 -HRS. ON 11/20/2009. DECOMP R/U DUTCH SYSTEM DECOMP WAIT ON WELL SUPPORT LUBRICATOR FROM MPC -14 -R/U ESP CABLE SHEAVE DRAIN HOSE AND ELEPHANT TRUNK -CHANGE OUT GERANIMO CARD. DECOMP 2010 BP TEAM ALASKA SAFETY HANDBOOK TRAINING -CONDUCTED BY NABORS SAFETY REP PAUL HOLLEY. DECOMP PULL TWC -M/U AND TEST LUBRICATOR TO 500 PSI -PULL TWC -L/D LUBRICATOR -R/D DUTCH SYSTEM. DECOMP WEEKLY SAFETY MEETING -NABORS SAFETY PAUL HOLLEY DID TASH BOOK TRAINING W/ CREWS. DECOMP PULL TBG HANGER. -FMC BACKED OUT LOCK DOWN SCREWS. -PULLED 2-7/8" TUBING HANGER. -PULL OFF SEAT AT 50-K WITH 55-K PUW. -BREAK OUT LAY DOWN HANGER. DECOMP CIRCULATED A TUBING VOL. 40 BBLS WITH 8.5 SEAWATER. -REQUIRED 22 BBLS TO FILL. THE HOLE. -3 BPM AT 0-120 PSI. DECOMP I POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE -LAYING DOWN TO PIPE SHED 2-7/8' TBG. DECOMP CONT: POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -LAYING DOWN TO PIPE SHED 2-7/8' TBG. DECOMP RIG SERVICE AND PRE -TOUR CHECKS. DECOMP CONT. L/D 2 7/8 TBG. DECOMP ESP vrirnea: uiuzutu IUAu:.SziAm k 0 0 BP EXPLORATION Operations Summary Report Page 3 of 6 1 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To I Hours Task I Code NPT I Phase Description of Operations 11/23/2009 07:30 - 10:30 3.00 PULL P DECOMP -L/D PUMP AND MOTOR -LOWER ESP CABLE OVER SHEAVE IN DERRICK. 10:30 -11:30 1.00 PULL P DECOMP LOAD PIPE SHED W/ 3.5" DP. -STRAP AND RABBIT -P/U BHA TO FLOOR 11:30 -12:00 0.50 PULL P DECOMP INSTALL 6.9375" I.D. WEAR RING. 12:00 - 14:00 2.00 PULL P DECOMP BHA #1 -6.125" PACKER MILL W 2.5" OD EXT. -(4) BOOT BASKETS -XO, BUMPER JARS, OIL JARS, -(9) 4.75" DC's, PUMP -OUT -SUB. 11/24/2009 00:00 - 03:00 3.00 CLEAN P DECOMP -TOTAL = 320.08 14:00 - 21:00 7.00 PULL P DECOMP RIH W/ 3.5", 15.5# DRILL PIPE SINGLES FROM PIPE SHED -FEED WELL AT 20 BPH Printed: 2/11/2010 10:50:32 AM 21:00 - 00:00 3.00 PULL P DECOMP MILL PACKER PER BAKER REP. -RIH TO TOP OF FISH AND ESTABLISH MILLING PARAMETERS, -TAGGED UP ON 4.5" TUBING @ 7,394' WITH 227 JNTS + 11' -PUW 110 -SOW 82-PU K-PUW 115 -SOW 87 -EST. -PARAMETERS-60-80 RPM, 195 AMPS ROTATING TORQUE -WT 10-15 K -2/4 BPM @ 150/170 PSI -ROT. -MILL F/. 7394' TO 7,402' -EST LOSS RATE DURING MILLING OPS. 50 BPH 11/24/2009 00:00 - 03:00 3.00 CLEAN P DECOMP CONT: MILL PACKER PER BAKER REP. -MILLING AT 7402' -PUW 115 -SOW 87 -PARAMETERS-195 AMPS ROTATING TORQUE -WT 10-15 K -2/4 BPM @ 150/770 PSI -ROT -MILLED THROUGH SLIPS, PACKER CAME LOOSE AND FELL TO TOP OF 4.5" LINER. -EST. LOSS RATE DURING MILLING OPERATION @ 50 BPH 03:00 - 04:00 1.00 CLEAN P DECOMP CHASED PACKER DOWN TO TOP OF 4.5 " PRODUCTION LINER -W/ 229 JNTS +34' @ 7,477' -PARAMETERS 80 SPM, 180 AMPS ROT, 15 K WT, 40 SPM 04:00 - 06:00 2.00 CLEAN P DECOMP PUMP 20 BBL HIGH VIS SWEEP ALL THE WAY AROUND -PUMP 3-4.5 BPM @ 410-1060 PSI. -LOSS RATE OF 50-60 BPH 06:00 - 06:30 0.50 CLEAN P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 06:30 - 10:30 4.00 CLEAN P DECOMP POH F/ 7,477' MD -SERVICE BOOT BASKETS -RECOVERED (4) GALLONS METAL CUTTINGS. 10:30 -11:00 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. 11:00 -12:00 1.00 CLEAN P DECOMP MU BHA #2 -ITCO SPEAR, BUMPER SUB, OIL JAR, (9) 4 3/4" DC"s, PUMP -OUT -SUB = 301.25 12:00 - 15:00 3.00 CLEAN P DECOMP RIH WITH BHA # 2 -T/ 7,422' MD Printed: 2/11/2010 10:50:32 AM BP EXPLORATION Operations Summary Report Page 4of61 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date I From - To I Hours I Task Code I NPT Phase I Description of Operations 11/24/2009 115:00 - 16:00 I 1.001 CLEAN I P 16:00 - 20:00 1 4.001 CLEAN I P 20:00 - 22:00 1 2.001 CLEAN I P 22:00 - 23:00 1 1.001 CLEAN I P 23:00 - 00:00 I 1.001 CLEAN I P 11/25/2009 100:00 - 01:30 I 1.501 CLEAN I P 01:30 - 04:00 I 2.501 CLEAN I P DECOMP SPEAR FISH -P/U KELLY -230 JOINTS + 20' TO 7,477' MD -3 BPM / 430 PSI. PUW = 112 (K). SOW = 90 (K) -ENGAGE SPEAR AT 7,477' MD -OBSERVED 15 (K) OVER PULL -SET BACK KELLY DECOMP POH F/ 7,477' -L/D (2) JOINTS DP -POH W/ 76 JNTS -FEED WELL AT -20 BPH + DBL-DISPLACMENT. DECOMP I LD BHA # 2 7" BAKER ZXP PACKER AND 4.5"TAIL PIPE DECOMP MU CLEAN OUT BHA #3 -3-3/4" MILL,PAC COLLAR,TBR POLISH MILL,(4)-JUNK BASKETS7' CSG SCRAPER, BUMPER SUB,OIL JAR, (9) 4 3/4" DC"s, PUMP -OUT -SUB = 368.48 DECOMP RIH W/ 76 JNTS OF 3.5", 15.5# DRILL PIPE -WITH CLEAN OUT BHA# 3. -FEED WELL AT 20 BPH DECOMP CONT: RIH W/ CLEAN OUT BHA# 3 ON 3.5", 15.5# DRILL PIPE -FEED WELL AT 20 BPH -76 STANDS DECOMP RECIPROCATE 7" SCRAPER ACROSS PACKER SETTING. Printea: Z111/ZU1U IU:bU:JZ HM -ESTABLISH CIRCULATION @ 7423'W/ 3-4 BPM 680-1600 PSI -50 BPH LOSS RATE -POLISH TOP OF LINER AT 7,494' -PARAMETERS -PUW- 120 SOW -97,3000-3800 FT/LB TORQUE 04:00 - 06:00 2.00 CLEAN P DECOMP CIRCULATE THE LONG WAY WITH 2OBBL HIGH VIS SWEEP. -3-4 BPM @ 680-1000 PSI -50-70 BBL LOSS RATE WHILE PUMPING -SAW SMALL AMOUNT OF METAL CUTTINGS AT SHAKER -WITH SOME GAS BUBLES 06:00 - 06:30 0.50 CLEAN P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 06:30 - 08:00 1.50 CLEAN P DECOMP CUT AND SLIP 84' DRILL LINE. 08:00 - 11:00 3.00 CLEAN P DECOMP POH WITH BHA # 3 -F/ -7,400' MD - FEED WELL WITH SEAWATER -@ 20 BPH + DBL DISPLACMENT. 11:00 -13:00 2.00 CLEAN P DECOMP L/D BHA # 3 -SERVICE BOOT BASKETS -RECOVERED 3 CUPS OF FINE METAL CUTTINGS.. -NO-GO COMFIRMS DEPTH @ -7,490' MD. -REMOVE BHA FROM FLOOR. 13:00 - 13:30 0.50 CLEAN P DECOMP CLEAN RIG FLOOR. 13:30 -15:30 2.00 WHSUR P DECOMP CHANGE PACK -OFF Printea: Z111/ZU1U IU:bU:JZ HM k 9 0 BP EXPLORATION Operations Summary Report Page 5of61 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/25/2009 13:30 - 15:30 2.00 WHSUR P DECOMP -PULL WEAR RING -BOLDS AND PULL 7" PACK -OFF WITH 8(K) -FLUSH AND INSTALL NEW FMC MANDREL PACK -OFF -FMC TO RILDS AND TEST HANGER FLANGE AND PACK -OFF SEALS TO 5,000 PSI F/ 30 MINUTES. -INSTALL WEAR RING. 15:30 -16:30 1.00 CLEAN P DECOMP MU BHA # 4 16:30 - 20:00 1 3.501 CLEAN I P 20:00 - 21:00 1 1.001 CLEAN I P 21:00 - 22:30 I 1.501 CLEAN I P 22:30 - 00:00 1.50 CLEAN P 11/26/2009 00:00 03:30 3.50 CLEAN P 03:30 - 04:00 1 0.50 WHSUR I P 04:00 - 06:00 1 2.00 CLEAN P 06:00 -15:00 1 9.00 15:00 -16:00 1 1.00 16:00 - 20:00 1 4.00 20:00 - 20:30 0.50 RUNCOII' 20:30 21:30 1.00 WHSUR I P 21:30 - 00:00 1 2.501 WHSUR I P -RIH TO -7,450' SET RTTS -PRESSURE TEST CSG TO 2000 PSI FOR 30 IN TEST) DECOMP RIH W/ 7" RTTS PACKER -RIH ON 76 STANDS TO 7,450' DECOMP SET PACKER -TEST CASING TO 2,000 PSI FOR 30 CHARTED MIN. (GOOD TEST) DECOMP UNSET RTTS AND ALLOW ELEMENTS TO RELAX -CIRCULATE 64 BBLS, 4 BPM @ 560 PSI DECOMP POH W/ 3.5" DP LAYING DOWN TO PIPE SHED DECOMP POH W/ 3.5" DP LAYING DOWN TO PIPE SHED -BREAK OUT AND LD COLLARS AND CIRCULATING. DECOMP -PULL WEAR BUSHING DECOMP CLEAN AND CLEAR RIG -RU TO RUN 4.5" WORK STRING TUBING EQUIPMENT AND TORQUE TURN EQUIPMENT - FINISH LOADING PIPE SHED WITH 4.5" TUBING AND JEWLERY. RUNCMP PU & RUN 4-1/2" TBG WORK STRING FOR CTD OPERATIONS. -WITH BAKER PREMIER PACKER AND GLM ASSEMBLY. -RUN 176 JNTS OF 4-1/2",12.6#, L-80, IBT TUBING. -OPTIMUM TORQUE 3,400 FT/LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. RUNCMP SPACE -OUT -NO / GO AT 7,498' MD -LD (3) JOINTS. -PU PUP'S (9.84',9.84', 7.81', 5.11', 3.83',) -MU LANDING JOINT WITH TIW VALVE. RUNCMP STAND DOWN FOR THANKSGIVING. CREW SENT TO MILNE PIONT CAMP FOR DINNER. RUNCMP PTSM , PJSM FOR LANDING HANGER. TUBHGR LAND HANGER, RILDS BY FMC 75K UP WT 64K DOWN WT TUBHGR DROP BALL TO SET AND TEST PACKER. -TEST LINES TO 4200 PSI -PRESSURE UP TO 4200 PSI AND SET PACKER. -TEST TBG TO 3500 PSI FOR 30 CHARTED MIN, TEST GOOD -BLEED DOWN TO 1500 PSI. -PRESSURE TEST TO 2000 ON THE IA FOR 15 MIN, TEST GOOD rrimea: en uzuiu ivw:a4 Nm k 0 0 BP EXPLORATION Operations Summary Report Page 6of61 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code I NPT I Phase Description of Operations 11/26/2009 21:30 - 00:00 2.50 WHSUR P 11/27/2009 00:00 - 01:30 1.50 WHSUR P 01:30 - 03:30 2.00 BOPSU P 03:30 - 07:00 3.50 WHSUR P 07:00 - 08:00 1.00 WHSUR P 08:00 - 08:30 0.50 WHSUR P 08:30 - 10:00 I 1.501 WHSUR I P 10:00 - 11:30 1 1.501 WHSUR I P 11:30 - 12:30 1.00 WHSUR P 12:30 13:00 0.50 WHSUR P TUBHGR -BLEED OFF TBG AND SHEAR DCK VALVE, PUMP BOTH WAYS 10 BBLS TO ENSURE FULLY OPEN RUNCMP SET AND TEST TWC -FMC SET TWC -TESTED 3500 PSI FROM ABOVE- -TESTED 1000 PSI FROM BELOW BOTH FOR 10 CHARTED MIN. -ALL TESTS GOOD RUNCMP PJSM FOR ND BOP OPERATIONS -ND BOPS, REMOVE FLOW RISER AND BREAK OUT KILL AND CHOKE LINES. -SET BACK RUNCMP NU ADAPTER FLANGE AND CAMERON 4-1/16" CTD TRE -TEST THE TUBING HANGER VOID AND TREE FOR 5 MIN. RUNCMP RU TEST LUBRICATOR -PT TO 500 PSI AND PULL TWC RUNCMP LITTLE RED SERVICES RU AND TEST LINES TO 2500 PSI -PUMP 70 BBLS OF DIESEL DOWN THE I.A. TAKING RETURNS OUT THE FLOWLINE -RD LRS RUNCMP RU TO ALLOW WELL TO U -TUBE -OPENED THE IA TO THE CEMENT LINE TO THE MANIFOLD THROUGH THE KILL LINE TO THE TUBING RUNCMP INSTALL BPV AND TEST -LITTLE RED SERVICES TO TEST FROM BELOW THROUGH THE SHEAR VALVE TO 1000 PSI FOR 5 MIN. RUNCMP SECURE THE TREE AND CELLAR -BLOW DOWN AND R/D LINES. RUNCMP AFTER ACTION REVIEW WITH CREW. -RIG RELEASE AT 13:00 HRS 11/27/2009. Printed: 2/11/2010 10:50:32 AM BP EXPLORATION Pagel of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 C—TD vPi:�2Ai'IaN Rig Name: NORDIC 2 Rig Number: N2 Date I From - To Hours Task I Code NPT Phase Description of Operations 12/26/2009 109:00 - 12:00 I 3.001 MOB I P I I PRE 12:00 - 15:00 I 3.001 MOB I P I I PRE 05:00 - 06:00 15:00 - 18:15 3.25 RIGU P PRE PRE 0.25 18:15 - 20:00 1.75 RIGU P 06:15 - 12:00 PRE BOPSU 20:00 - 22:15 2.25 RIGU P PRE 22:15 - 22:25 0.17 MOB P PRE 22:25 - 22:45 0.33 MOB P PRE 22:45 - 23:45 1.00 MOB P PRE 23:45 - 00:00 0.25 MOB P PRE 12/27/2009 00:00 - 03:00 3.00 RIGU P PRE 03:00 - 05:00 2.00 BOPSUFIP P PRE 05:00 - 06:00 1.00 BOPSU P P PRE 06:00 - 06:15 0.25 BOPSU P RIGU PRE 06:15 - 12:00 5.75 BOPSU P 0.33 PRE 12:00 - 12:15 1 0.251 BOPSUR P I I PRE MOVE RIG FROM MPU E PAD TO MPU C PAD. PARK RIG AT ENTRANCE TO PAD WHILE PERMITING ISSUE IS RESOLVED. SPOT HERCULATE AND RIG MATS. SPOT RIG OVER WELLHEAD. LEVEL RIG. ACCEPT RIG AT 1300 HRS. CONTINUE TO RIG UP IN CELLAR. INSTALL BERM AND FLOOR BOARDS IN CELLAR, LOAD MPD LOOP INTO CELLAR ND TREE CAP, SET DOWN STACK AND CHECK POSITION PJSM FOR SKIDDING RIG SKID RIG TO REPOSITION OVER WELLHEAD LOAD 2-3/8" REEL INTO REELHOUSE MU HARDLINE IN REEL, BEGIN NU MPD LOOP SET DOWN BOP AND NIPPLE UP RIG UP MPD LOOP TO FLOW CROSS, SPOT IN TIGER TANK AND CUTTINGS BOX, HARDLINE CREW MU LINE TO TT AND PT. FILL BOP STACK CREW CHANGE. DISCUSS OPS. HSE ISSUES. MAKE RIG CHECKS AND ROUNDS. TEST BOP EQUIPMENT AS PER PERMIT TO DRILL. AOGCC BEGS, WELL PLAN, AND BP DWOP GUIDELINES. RECORD TEST ON TOTCO, CHART, AND SLB DIGITAL SYSTEMS. TEST MPD LOOP COMPONENTS, CHOKE MANIFOLD, AND CT HARDWARE. TEST WITNESS WAIVED BY J. JONES, AOGCC. CREW CHANGE. DISCUSS OPS. MAKE ROUNDS AND RIG CHECKS. CONTINUE TESTING BOP EQUIPMENT. PU INJECTOR AND STAB ONTO PACKOFFS PJSM FOR PULLING COIL ACROSS PULL COIL ACROSS FROM REELHOUSE TO INJECTOR AND STAB IN INJECTOR LOAD PITS WITH FLUID, CREW WALK AROUNDS PJSM WITH NEW CREW FOR LOADING REEL W/ FLUID LOAD REEL WITH 5 BBLS MEOH, H2O SPACER, GEO-VIS. PJSM FOR PICKING UP INJECTOR AND STABING ON WELL PU INJECTOR, MU TO LUBRICATOR SECTION, STAB ON WELL, PT INNER REEL VALVE PUMP SLACK BACK, POP OFF INJECTOR AND CUT 76' TO FIND ELINE. TEST ELINE, MEG TEST GOOD, TROUBLESHOOT BAD CONTINUITY TEST TROUBLESHOOT ELINE PROBLEMS, REPLACE TERMINAL BLOCK IN JUNCTION BOX, ELINE TEST IS GOOD INSTALL SLB CTC PULL TEST CTC TO 36K HEAD UP BHI UQC PT BHI UQC TO 4200 PSI PJSM FOR LOADING VALVE CREW TO FLOOR AND PULL rnntea: uzwzuiu 7z:uJ:44 YM 12:15 - 16:00 3.75 BOPSUF P PRE 16:30 - 18:00 1.50 RIGU P PRE 18:00 - 18:20 0.33 RIGU P PRE 18:20 - 19:25 1.08 RIGU P PRE 19:25 - 20:00 0.58 RIGU P PRE 20:00 - 20:25 0.42 RIGU P PRE 20:25 - 22:15 1.83 RIGU P PRE 22:15 - 22:30 0.25 RIGU P PRE 22:30 - 23:00 0.50 BOPSUF P PRE 23:00 - 23:50 0.83 RIGU P PRE 23:50 - 00:00 0.17 RIGU N SFAL PRE 12/28/2009 00:00 - 00:30 0.50 RIGU N SFAL PRE 00:30 - 01:00 0.50 RIGU P PRE 01:00 - 01:10 0.17 RIGU P PRE 01:10 - 01:55 0.75 RIGU P PRE 01:55 - 02:05 0.17 RIGU P PRE 02:05 - 02:20 0.25 RIGU P PRE MOVE RIG FROM MPU E PAD TO MPU C PAD. PARK RIG AT ENTRANCE TO PAD WHILE PERMITING ISSUE IS RESOLVED. SPOT HERCULATE AND RIG MATS. SPOT RIG OVER WELLHEAD. LEVEL RIG. ACCEPT RIG AT 1300 HRS. CONTINUE TO RIG UP IN CELLAR. INSTALL BERM AND FLOOR BOARDS IN CELLAR, LOAD MPD LOOP INTO CELLAR ND TREE CAP, SET DOWN STACK AND CHECK POSITION PJSM FOR SKIDDING RIG SKID RIG TO REPOSITION OVER WELLHEAD LOAD 2-3/8" REEL INTO REELHOUSE MU HARDLINE IN REEL, BEGIN NU MPD LOOP SET DOWN BOP AND NIPPLE UP RIG UP MPD LOOP TO FLOW CROSS, SPOT IN TIGER TANK AND CUTTINGS BOX, HARDLINE CREW MU LINE TO TT AND PT. FILL BOP STACK CREW CHANGE. DISCUSS OPS. HSE ISSUES. MAKE RIG CHECKS AND ROUNDS. TEST BOP EQUIPMENT AS PER PERMIT TO DRILL. AOGCC BEGS, WELL PLAN, AND BP DWOP GUIDELINES. RECORD TEST ON TOTCO, CHART, AND SLB DIGITAL SYSTEMS. TEST MPD LOOP COMPONENTS, CHOKE MANIFOLD, AND CT HARDWARE. TEST WITNESS WAIVED BY J. JONES, AOGCC. CREW CHANGE. DISCUSS OPS. MAKE ROUNDS AND RIG CHECKS. CONTINUE TESTING BOP EQUIPMENT. PU INJECTOR AND STAB ONTO PACKOFFS PJSM FOR PULLING COIL ACROSS PULL COIL ACROSS FROM REELHOUSE TO INJECTOR AND STAB IN INJECTOR LOAD PITS WITH FLUID, CREW WALK AROUNDS PJSM WITH NEW CREW FOR LOADING REEL W/ FLUID LOAD REEL WITH 5 BBLS MEOH, H2O SPACER, GEO-VIS. PJSM FOR PICKING UP INJECTOR AND STABING ON WELL PU INJECTOR, MU TO LUBRICATOR SECTION, STAB ON WELL, PT INNER REEL VALVE PUMP SLACK BACK, POP OFF INJECTOR AND CUT 76' TO FIND ELINE. TEST ELINE, MEG TEST GOOD, TROUBLESHOOT BAD CONTINUITY TEST TROUBLESHOOT ELINE PROBLEMS, REPLACE TERMINAL BLOCK IN JUNCTION BOX, ELINE TEST IS GOOD INSTALL SLB CTC PULL TEST CTC TO 36K HEAD UP BHI UQC PT BHI UQC TO 4200 PSI PJSM FOR LOADING VALVE CREW TO FLOOR AND PULL rnntea: uzwzuiu 7z:uJ:44 YM BP EXPLORATION Page 2 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date I From - To Hours Task Code NPT Phase I Description of Operations 12/28/2009 02:05 - 02:20 02:20 - 02:40 02:40 - 03:30 03:30 - 03:45 03:45 - 04:15 04:15 - 06:00 06:00 - 06:15 06:15 - 07:00 0.25 RIGU P 0.33 RIGU P 0.83 RIGU P 0.25 CLEAN P 0.50 CLEAN P 1.75 CLEAN P 0.25 CLEAN P 0.75 CLEAN P 07:00 - 09:00 2.001 CLEAN I P 09:00 - 13:00 4.001 STWHIP P 13:00- 15:00 2.00 STWHIPIP 15:00 - 16:30 1.50 STWHIP P 16:30 - 18:00 1.50 STWHIP P 18:00 - 00:00 1 6.001 STWHIPI P 12/29/2009 100:00 - 04:45 I 4.751 STW H I P 1 P 04:45 - 06:00 1 1.251 STWHIPI P 06:00 - 06:15 0.25 STWHIP P 06:15 - 08:45 2.50 STWHIP P 08:45 -10:15 1.50 STWHIP P 10:15 -10:30 0.25 STWHIP P 10:30 -12:15 1.75 STWHIP P 12:15 -15:30 3.25 DRILL P PRE BPV PRE LOAD LUBRICATOR AND RODS TO FLOOR PRE LUBRICATE OUT BPV, WHP SHOWS 800 PSI, OFFLOAD BPV CREW & LUBRICATOR WEXIT PJSM FOR MAKING UP NOZZLE WEXIT MU NOZZLE ASSY AND STAB INJECTOR ON WELL WEXIT OPEN MASTER AND PREPARE TO RIH HOLDING 800 PSI, PRESSURE BLEEDS OFF IMMEDIATELY AND WELL IS FLUID PACKED, RIH TO 8000' AND DISPLACE BACKSIDE TO GEOVIS WEXIT CREW CHANGE. DISS OPERATIONS. MAKE RIG ROUNDS AND CHECKS. WEXIT DISPLACE WELL TO 8.9 PPG GEOVIS MUD. TAKE WELL RTNS TO FLOW BACK TANK. FLOW CHECK WELL. WEXIT CIRCULATE OUT OF HOLE. WEXIT AT SURFACE. HOLD PJSM TO REVIEW DEPLOYMENT PROCEDURE. DISCUSS PROCESS STEP BY STEP. MOST HANDS NOT FAMILIAR WITH DEPLOY PROCEDURE. TOOK EXTRA TIME TO DISCUSS EACH STEP. WEXIT RUN IN HOLE. CIRC AT MIN RATE THROUGH EDC. WEXIT LOG INITIAL GR TIE IN TO PDC LOG FROM 7600' TO 8000'. SUBTRACT 16' CORRECTION. WEXIT TAG PINCH POINT AT 8045'. PU BRING ON PUMPS AND MILL AHEAD FROM 8044.5'. 2200 PSI FS AT 2.49 BPM IN/OUT. DHWOB: 0.5 - 1.OK# WEXIT ITIME MILL WINDOW @ 17HR,_BEGIN SEEING MW @ 8044.5' CONTINUE TIME MILLING W/ 250-350 PSI MW AND 0.8-1.5K DHWOB WEXIT CONTINUE TIME MILLING WINDOW W/ 250-300 PSI MW AND 1.5K DHWOB, WOB INCREASES TO 2.5K @ 8051', WOB DROPS OFF TO 0.7K @ 8051.5', CAUGHT SAMPLE 8052' W/ METAL, CEMENT, TRACE OF DARK SHALE & GLAUCONITE. TIME MILL TO 8053' WEXIT MILL RATHOLE IN FORMATION FROM 8053' TO 8063' AT 4-5'/HR W/ -1.OK DHWOB AND 250 PSI MW @ 10.0 PPG ECD. WEXIT CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND ROUNDS. WEXIT REAM WINDOW. MAKE SEVERAL PASSES. DRY DRIFT. WINDOW SMOOTH. WEXIT OPEN EDC. CIRCULATE OUT OF HOLE. MAINTAIN 10.OPPG EMW ON BTM USING MDP EQUIPMENT AND PRESSURE SCHEDULE. WEXIT AT SURFACE. HOLD PJSM WITH RIG CREW TO REVIEW AND DISCUSS PROCEDURE. WEXIT PRESSURE UNDEPLOY WITH 400 PSI ON WELL. LD TOOLS. MILLS GAUGED: 3.79" NO GO PROD1 MU UP BUILD BHA. (2.7 DEG MTR W/ NEW HYC RAPTOR RAZOR BIT) Printed: 1/25/2010 12:05:44 PM 5 0 0 BP EXPLORATION Page 3 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/29/2009 12:15 - 15:30 3.25 DRILL P PROD1 ATTEMPT TO PRESSURE DEPLOY. WORK TOOL WITH SLICKLINE. UNABLE TO PASS WELLHEAD. BLEED WHP TO ZERO. OPEN HOLE DEPLOY BHA. STAB COIL. TEST TOOLS. 15:30 -17:15 1.75 DRILL P PROD1 RUN IN HOLE AS PER WHP SCHEDULE. 17:15 -17:30 0.25 DRILL P PROD1 LOG GR TIE IN FROM 7970'. ADD 30' CORRECTION. 17:30 - 00:00 6.50 DRILL P PROD1 DRILL AHEAD FROM 8063'. 2400 PSI FS AT 2.53 BPM IN/OUT. WHP/BHP/ECD:48 PSI/3552 PSI/10.01 PPG. RILL TO 8,190' 12/30/2009 00:00 - 00:20 0.33 DRILL P PROD1 DRILL AHEAD FROM 8,190'. 2400 PSI FS AT 2.53 BPM IN/OUT. WHP/BHP/ECD:48 PSI/3552 PSI/10.27 PPG. DRILL TO 8,200' 00:20 - 00:35 0.25 DRILL P PROD1 WIPER TO WINDOW 00:35 - 01:20 0.75 DRILL P PROD1 LOG TIE IN FROM 7,970' TO 8,088' CORRECTION OF -2' RESET DEPTH TO 8,086' 01:20 - 01:30 0.17 DRILL P PROD1 RIH TO TD 01:30 - 05:30 4.00 DRILL P PROD1 DRILL AHEAD FROM 8,200'. 2600 PSI FS AT 2.6 BPM IN/OUT. WHP/BHP/ECD:32 PSI/3552 PSI/10.2 PPG. 05:00 DRILLING BUILD @ 8,295' TD @ 8,320' 05:30 - 07:30 2.00 DRILL P PROD1 POH WITH BUILD BHA. MAINTAIN ECD OF 10.0 PPG FOLLOWING PRESSURE SCHEDULE. HOLD PJSM TO DISCUSS PRESSURE UNDEPLOY PROCEDURE. 07:30 - 09:30 2.00 DRILL P PROD1 AT SURFACE. TAG UP AND SPACE OUT BHA. GET OFF WELL. PRESS UNDEPLOY BHA. 09:30 - 10:30 1.00 DRILL P PROD1 REVIEW AND INVESTIGATE DROPPED 5/8" NUT FROM GOOSENECK. DOCUMENT SAME. RE HEAD SLICKLINE TOOL. 10:30 -12:45 2.25 DRILL P PROD1 PJSM. PRESS DEPLOY 1.2 DEG MTR WITH RR HYCALOG RAZOR RAPTOR BIT. 12:45 - 14:45 2.00 DRILL P PROD1 GET ON WELL. RUN IN HOLE. MAINTAIN 10.0 PPG BHP USING CHOKE & SCHEDULE. 14:45 -15:00 0.25 DRILL P PROD1 LOG GR TIE IN. SUBTRACT 16CORRECTION. 15:00 -16:00 1.00 DRILL P PROD1 MAKE MAD PASS DOWN FOR RESISITVITY DATA IN BUILD. MAINTAIN AS DRILLED TF. 1208 PSI FS AT 0.60 BPM IN. 16:00 -17:15 1.25 DRILL P PROD1 DRILL AHEAD FROM 8320'. 2820 PSI FS AT 2.49 BPM IN/OUT. 2-3K# DHWOB, 200-30OPSI MOTOR WORK DRILL TO 8,450' 17:15 -19:45 2.50 DRILL P PROD1 WIPER TO WINDOW SMOOTH rnmea: uzoreviv icvo:vvrm BP EXPLORATION Page 4 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To I Hours Task Code NPT Phase Description of Operations 12/30/2009 119:45 - 22:20 I 2.581 DRILL I P 22:20 - 23:10 1 0.831 DRILL P 23:10 - 00:00 1 0.831 DRILL P 12/31/2009 100:00 - 01:40 1 1.671 DRILL 1 P 01:40 - 02:20 1 0.67 DRILL P 02:20 - 02:30 1 0.17 DRILL P 02:30 - 03:00 1 0.501 DRILL P 03:00 - 03:45 1 0.751 DRILL P 03:45 - 06:00 06:00 - 06:30 06:30 - 06:45 06:45 - 08:45 08:45 - 10:00 10:00 - 17:15 2.25 DRILL N 0.50 DRILL N 0.25 DRILL N 2.00 DRILL N 1.25 DRILL N 7.25 DRILL N PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 SFAL PROD1 17:15 - 18:20 1 1.081 DRILL IN DFAL PROD1 18:20 - 18:40 0.33 DRILL N DFAL PROD1 18:40 19:00 0.33 DRILL N SFAL PROD1 19:00 - 20:20 1.33 DRILL N SFAL PROD1 20:20 - 23:15 2.92 DRILL N HMAN PROW DRILL AHEAD FROM 8,450'. 2,450 PSI FS @ 2.44 BPM IN/OUT. 1.5K -3K# DHWOB 250-50OPSI MOTOR WORK DRILL TO 8,601' WIPER TO WINDOW DRILL AHEAD FROM 8,601'. 2,760 PSI FS @ 2.6 BPM IN/OUT. 1.5K -3K# DHWOB 250-35OPSI MOTOR WORK DRILL TO 8,660' DRILL AHEAD FROM 8,660'. 2,760 PSI FS @ 2.6 BPM IN/OUT. 1.5K -3.5K# DHWOB 250-35OPSI MOTOR WORK DRILL TO 8,750' WIPER TO WINDOW LOG TIE IN FROM 8,080' TO 8,097' CORRECTION +3' RESET DEPTH TO 8,100' RIH TO TD DRILL AHEAD FROM 8,750'. 2,650 PSI FS @ 2.5 BPM IN/OUT. 1.5K -3.5K# DHWOB 250-35OPSI MOTOR WORK DRILL TO 8,751' , POH FOR HOT FAILURE CREW CHANGE. REVIEW OPERATIONS. MAKE RIG CHECKS AND ROUNDS. HOLD PJSM TO DISCUSS PRESS UNDEPLOY PROCEDURE. PRESSURE UNDEPLOY BHA. MAINTAIN 400 PSI WHP DURING PROCESS. MU REPLACEMENT BHI TOOLS. PRESSURE DEPLOY BHA. UNABLE TO BLEED OFF LUBRICATOR PRESSURE DURING DEPLOYMENT. DISCOVER CHOKE MANIFOLD IS CLOGGED WITH CEMENT CHUNKS AND SHALE. APPEARS TO BE OLD MATERIAL, DISCOLORED AND OIL STAINED. DISASSEMBLE NUMEROUS CHOKE MANIFOLD COMPONENTS. REMOVE A FIVE GALLON BUCKET OF CEMENT AND SHALE CHUNKS. MOST THUMB SIZED REASSEMBLE AND TEST COMPONENTS. STILL PARITALLY PLUGGED OFF. CONTINUE TO DISSASSEMBLE AND REMOVE DOWN HOLE MATERIAL. PRESSURE DEPLOY BHA CHECK MWD TOOLS @ SURFACE PJSM TO DISCUSS THE PRESSURE UNDEPLOY PROCEDURE PRESSURE UNDEPLOY BHA. MAINTAIN 400 PSI WHP DURING PROCESS. 2-3/8" RAMS CLOSED ON 3" TOOL ASSY 2-3/8" RAMS CLOSED ON 3" TOOL ASSY, CLOSED 3" VBR'S & BLED TRAPPED PSI FROM STACK WHILE vnniea: 1/eaizU1U 1z:U0:44k'M r BP EXPLORATION Page 5 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code I NPT Phase I Description of Operations 12/31/2009 120:20 - 23:15 I 2.921 DRILL IN I HMAN I PROD1 23:15 - 00:00 1 0.751 DRILL IN I HMAN I PROD1 1/1/2010 100:00 - 00:10 1 0.171 DRILL IN I HMAN I PROD1 04:00 - 04:55 00:10 - 00:30 0.33 DRILL N HMAN PROD1 7.08 00:30 - 00:45 0.25 DRILL N DFAL PROD1 DRILL 00:45 - 02:30 1.75 DRILL N DFAL PROD1 N 02:30 - 03:15 0.75 DRILL N DFAL PROD1 WAIT 03:15 - 03:30 0.25 DRILL N SFAL PROD1 03:30 - 04:00 0.50 DRILL N SFAL PROD1 04:00 - 04:55 0.92 DRILL N SFAL PROD1 04:55 - 12:00 7.08 DRILL N WAIT PROD1 12:00 - 13:00 1.00 DRILL N WAIT PROD1 13:00 - 20:00 7.00 DRILL N WAIT PROD1 20:00 - 21:00 1.00 DRILL N WAIT PROD1 MAINTAINING 40OPSI ON FORMATION, OPENED 2-3/8" RAMS & FINISHED UNDEPLOYING BHA. SLIGHT MARKINGS ON TOOLS FROM RAMS BUT TOOLS UNDAMAGED LD TOOLS & PREPARED NEXT SET OF TOOLS ON CATWALK PJSM TO REPLACE 2-3/8" RAMS & PT SAME REPLACED 2-3/8" RAMS WHILE MWD TOOLS WERE BEING SET UP FOR NEXT BHA PT 2-3/8" RAMS UNABLE TO BUILD PSI CHANGE OUT POP-OFF ON TEST PUMP PT 2-3/8" RAMS HOLD PJSM TO RD FROM PT RD FLOOR FROM 2-3/8" RAMS PT PJSM TO DEPLOY LATERAL BHA WITH NEW HOT ASSY DEPLOY LATERAL BHA WITH NEW HOT ASSY WHILE MAINTAINING 40OPSI WHP TEST MWD TOOLS @ SURFACE EDC MOTOR NOT RESPONDING PJSM TO UNDEPLOY & CHANGE OUT EDC COIL FROZE WHILE TESTING TOOLS RIH & THAW COIL POH TO SURFACE UNDEPLOY TO SWAP EDC WHILE MAINTAINING 40OPSI WHP PHASE 3 WEATHER CONDITIONS ANNOUCED IN MPU ALL WORK STOPPED ON RIG DUE TO SAFETY. DISCUSS CREW CHANGE WITH MILNE POINT OPERATIONS. CONVOY CREWS TO AND FROM RIG USING CAMP LOADER. LEAVE UNEEDED PERSONNEL AT MAN CAMP. MAINTAIN RIG WATCH. CONVOY CREWS TO AND FROM RIG USING CAMP LOADER. LEAVE UNEEDED PERSONNEL AT MAN CAMP. MAINTAIN RIG WATCH. MAINTAIN RIG WATCH. PHASE 2, LEVEL 2 CONDITIONS CALLED @ 00:40 WAIT ON NON-ESSENTIAL PERSONEL TO CONVOY FROM CAMP PJSM TO FINISH UNDEPLOYING BHA FOR EDC SWAP UNDEPLOY BHA FOR EDC SWAP WHILE MAINTAINING 40OPSI WHP RU NEW EDC ONTO MWD TOOL STRING & TEST PJSM TO DEPLOY BHA DEPLOY BHA WHILE MAINTAINING 40OPSI WHP TEST MWD TOOLS @ SURFACE, TEST GOOD RIH WITH LATERAL BHA TO 2,850' CREW CHANGE. DISCUSS OPS. MAKE RIG ROUNDS AND CHECKS. COORDINATE CONVOY BACK TO MAN CAMP. rnntea: uzoizuiu iz:ua:vwrm 21:00 - 00:00 3.00 DRILL N WAIT PROD1 1/2/2010 00:00 - 00:40 0.67 DRILL N WAIT PROD1 00:40 - 01:30 0.83 DRILL N WAIT PROD1 01:30 - 01:50 0.33 DRILL N DFAL PROD1 01:50 - 02:45 0.92 DRILL N DFAL PROD1 02:45 - 03:45 1.00 DRILL N DFAL PROD1 03:45 - 04:00 0.25 DRILL N DFAL PROD1 04:00 - 05:15 1.25 DRILL N DFAL PROD1 05:15 - 05:30 0.25 DRILL N DFAL PROD1 05:30 - 06:00 0.50 DRILL N DFAL PROD1 06:00 - 18:00 12.00 DRILL N WAIT PROD1 MAINTAINING 40OPSI ON FORMATION, OPENED 2-3/8" RAMS & FINISHED UNDEPLOYING BHA. SLIGHT MARKINGS ON TOOLS FROM RAMS BUT TOOLS UNDAMAGED LD TOOLS & PREPARED NEXT SET OF TOOLS ON CATWALK PJSM TO REPLACE 2-3/8" RAMS & PT SAME REPLACED 2-3/8" RAMS WHILE MWD TOOLS WERE BEING SET UP FOR NEXT BHA PT 2-3/8" RAMS UNABLE TO BUILD PSI CHANGE OUT POP-OFF ON TEST PUMP PT 2-3/8" RAMS HOLD PJSM TO RD FROM PT RD FLOOR FROM 2-3/8" RAMS PT PJSM TO DEPLOY LATERAL BHA WITH NEW HOT ASSY DEPLOY LATERAL BHA WITH NEW HOT ASSY WHILE MAINTAINING 40OPSI WHP TEST MWD TOOLS @ SURFACE EDC MOTOR NOT RESPONDING PJSM TO UNDEPLOY & CHANGE OUT EDC COIL FROZE WHILE TESTING TOOLS RIH & THAW COIL POH TO SURFACE UNDEPLOY TO SWAP EDC WHILE MAINTAINING 40OPSI WHP PHASE 3 WEATHER CONDITIONS ANNOUCED IN MPU ALL WORK STOPPED ON RIG DUE TO SAFETY. DISCUSS CREW CHANGE WITH MILNE POINT OPERATIONS. CONVOY CREWS TO AND FROM RIG USING CAMP LOADER. LEAVE UNEEDED PERSONNEL AT MAN CAMP. MAINTAIN RIG WATCH. CONVOY CREWS TO AND FROM RIG USING CAMP LOADER. LEAVE UNEEDED PERSONNEL AT MAN CAMP. MAINTAIN RIG WATCH. MAINTAIN RIG WATCH. PHASE 2, LEVEL 2 CONDITIONS CALLED @ 00:40 WAIT ON NON-ESSENTIAL PERSONEL TO CONVOY FROM CAMP PJSM TO FINISH UNDEPLOYING BHA FOR EDC SWAP UNDEPLOY BHA FOR EDC SWAP WHILE MAINTAINING 40OPSI WHP RU NEW EDC ONTO MWD TOOL STRING & TEST PJSM TO DEPLOY BHA DEPLOY BHA WHILE MAINTAINING 40OPSI WHP TEST MWD TOOLS @ SURFACE, TEST GOOD RIH WITH LATERAL BHA TO 2,850' CREW CHANGE. DISCUSS OPS. MAKE RIG ROUNDS AND CHECKS. COORDINATE CONVOY BACK TO MAN CAMP. rnntea: uzoizuiu iz:ua:vwrm 1 0 0 BP EXPLORATION Page 6 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To I Hours Task I Code I NPT I Phase Description of Operations 1/2/2010 06:00 - 18:00 12.00 DRILL N WAIT PROD1 18:00 - 18:45 0.75 DRILL N DFAL PROD1 18:45 - 19:00 0.25 DRILL N DFAL PROD1 19:00 - 19:45 0.75 DRILL N DFAL PROD1 OPEN EDC. HOLD 300 PSI WHP AT 2846' BIT DEPTH. 1310 PSI FS AT 0.81 BPM IN/OUT. CIRCULATE WHILE WAITING ON WEATHER GPB AND KRU HAVE CALLED PHASE 3. MPU HAS AGREED TO SAME DUE TO SUPPORT LOGISITCS. PHASE 2 CALLED BY GPB. AGREE TO RESUME WELL WORK AT 1800 HRS TO GIVE FIELD SUPPORT SERVICES TIME TO "CATCH" UP. CONTINUE TO CIRCULATE AT 3100'. 1320 PSI AT 0.82 BPM W/ EDC OPEN. CREW C/O COMPLETE. BEGIN RIH WHILE CIRCULATING THROUGH OPEN EDC MAINTAINING -10.0 PPG EMW ON BOTTOM. LEAK AT PLUG VALVE ON CHOKE MANIFOLD DOWNSTREAM OF RETURN MM. LEAK IS AT PLUG ON BACK OF VALVE BODY. REPLACE W/ TESTED PLUG VALVE. RESUME CIRCULATING THROUGH OPEN EDC WHILE RIH 19:45 - 20:15 0.50 DRILL N DFAL PROD1 LOG TIE-IN IMMEDIATELY ABOVE WINDOW. CORRECTION OF (-16'). CIRCULATING THROUGH OPEN EDC AT 0.84 BPM AT 1290 PSI CIRC PRESSURE WITH 100 PSI BACKPRESSURE AND EMW OF -10 PPG. IAP = 10 PSI. OAP = 15 PSI. 20:15 - 00:00 3.75 DRILL P PROD1 DOWN ON PUMP TO RIH THROUGH WINDOW. CLOSE EDC. BELOW WINDOW, BACK ONLINE THROUGH BIT. CHOKE PLUGS UP; BYPASS AND SURGE TO CLEAR. SEEMS TO CLEAR, BUT IS STILL APPLYING -70 PSI WHP WITH FOC. UP WEIGHT IS 31000 LB. RIH WEIGHT IS 8400 LB. CIRCULATING AT 2.6 BPM WITH FREESPIN CIRC PRESSURE OF 2750 PSI WITH 70 PSI WHP. ECD IS 10.4 PPG. RIH AND TAG TD AT 8752' MD. BEGIN DRILLING AHEAD. DRILLING AHEAD WITH AVERAGE OF 4K STACKED ON BIT (SURFACE WEIGHT) WITH WOB INDICATOR SHOWING 2K LB WOB. SEEING -300 PSI MOTOR WORK (CIRC PRESSURE OF 3050 PSI). DRILL AHEAD WITH THESE PARAMETERS WITH NO STALLS TO -8900' MD. LOG SHOWS NO SIGNS OF THE POSSIBLE FAULT AT 8850' MD. PERFORM WIPER TRIP TO WINDOW, PU CLEAN AT 31000 LB. SEE -80 PSI MOTORWORK BACKREAMING THROUGH BUILD SECTION (FROM 8124' TO 8300' MD); NO OVERPULL OBSERVED IN CONJUNCTION WITH THIS BACKREAMING MOTOR WORK. GEO SAMPLE AT 8850' MD SHOWS TRACE (LESS THAN 1%) OF SHALE SLIVERS (1/8" LONG OR LESS). ALL OTHER GEO SAMPLES SHOW NO SIGNS OF HOLE INSTABILITY. NO BACKREAMING OR OVERPULLS HAVE BEEN NOTED IN THE LATERAL SECTION OF THE OPEN HOLE. IAP = 5 PSI. OAP = 46 PSI. CONTINUED ON DIMS REPORT 01/03/10. 1/3/2010 00:00 - 05:10 5.17 DRILL P PROD1 CONTINUED FROM DIMS REPORT 01/02/10. IAP = 10 PSI, OAP = 60 PSI. Printed: 125/2010 1Z:Ub:44 PM 1 0 0 BP EXPLORATION Page 7 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date I From - To Hours I Task Code NPT Phase Description of Operations 1/3/2010 00:00 - 05:10 5.17 DRILL P PROD1 05:10 - 06:30 1.33 DRILL P PROW 06:30 - 08:20 1.83 DRILL P PROD1 08:20 - 09:30 1.17 DRILL P PROD1 09:30 - 09:40 0.17 DRILL P PROW 09:40 - 10:55 1.25 DRILL P PROD1 10:55 - 14:50 3.92 DRILL P PROW FINISH WIPER TRIP. RBIH TO CONTINUE DRILLING AHEAD. PUMPING THROUGH BIT AT 2.6 BPM AT 2760 PSI FREESPIN WITH -40 PSI WHP (10.5 PPG ECD). UP WEIGHT 31000 LB. RIH WEIGHT 6000 LB. DRILL AHEAD TO 8932' MD. ENCOUNTER HARD DRILLING AT 8932' MD; STACKING EXCESSIVE WEIGHT WITH NO MOTOR WORK. PU'S ARE STICKY (OVERPULLS OF -10K LB). DRILL AHEAD IN THIS FASHION TO 8938' MD. RESUME CONSISTENT DRILLING FROM 8938' MD WITH CONSISTENT -250 PSI MOTOR WORK AND 3K LB WOB (AT TOOL). DRILL TO 9,045' WIPER TO WINDOW 80PSI MTR WORK @ 8,525' REST OF WIPER WAS SMOOTH TAG BOTTOM @ 9,041' DRILL FROM 9,041' FS 2,680PSI 0 2.55BPM 06:30 - 300-45OPSI MTR WORK, 1.5K - 3.2K WOB, 10.5 ECD STACK WT & STALL @ 9,059', 9,067', 9,074' WHEN RIH ON LAST PU TAGGED FORMATION @ 9,068' & STALLED OUT, 75K OVER PULL TO PU, RIH BACK TO 9,068' WORK AHEAD WITH 100 - 20OPSI MTR WORK IN THIS AREA WITH LESS THAN 0.1 K WOB TO 9,070' & STALL OUT PU TO 9,066', RIH TO 9,069' 1.5K WOB WITH 250PSI MTR WORK, 10.54 ECD MILL TO 9,073' & STALL OUT PU TO 9,055', RIH TO 9,071'& MILL TO TD 07:45- 9,077' @ 1.5K - 2.3K WOB, 100-250PSI MTR WORK, 10.54 ECD STALL @ 9,078' & PU TO 9,000', RIH TO 9,074'. WITH 100PSI MTR WORK TO TD STALL @ 9,078', PU TO 9,065', RIH TO TD FS 2,700PSI @ 2.56BPM 150-30OPSI MTR WORK, 1.8K - 2.5K WOB, 10.55 ECD STALL @ 9,082', 9,088' 9,088'80K OVER PULL COIL HUNG UP @ 9,074 -WORK COIL FREE WIPER TRIP TO WINDOW LOG TIE IN FROM 8,075' TO 8,089- +1 1' ,089'+11' CORRECTION RESET DEPTH TO 8,100' RIH TO TD & TAG @ 9,096' 80PSI OF MTR WORK @ 8,525' NEW MUD ON LOCATION @ 10:40 DRILL FROM 9,096' FS 2,680PSI @ 2.52 BPM 150 - 250PSI MTR WK, 1.9K - 3.2K WOB, 10.51 ECD STALL @ 9,099',9,100',9,103',9,108- DROPPED ,099',9,100',9,103',9,108'DROPPED PUMP RATE TO 2.44BPM, FS 2,500PS1 Printed: 1/25/2010 12:05:44 PM BP EXPLORATION Operations Summary Report Page 8 of 20 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task I Code I NPT I Phase I Description of Operations 1/3/2010 110:55 - 14:50 1 3.921 DRILL I P 14:50 - 16:20 I 1.501 DRILL I P 16:20 - 19:15 1 2.921 DRILL I P 19:15 - 20:00 1 0.751 DRILL I P 20:00 - 21:45 I 1.751 DRILL I P 21:45 - 23:15 1 1.501 DRILL IN 23:15 - 00:00 1 0.751 DRILL IN PROD1 --SWAP TO NEW MUD WHILE DRILLING AHEAD -- 12:40 - 9,143', 350PSI MTR WORK, 4.4K WOB, 10.22 ECD 13:40 - 9,241', 50OPSI MTR WORK, 3.75K WOB, 10.35 ECD STALL @ 9,247' DRILL TO 9,251' PROD1 WIPER TO WINDOW 80PSI OF MTR WORK RIH @ 8,525' TAG TD @ 9,249' PROD1 DRILL FROM 9,249' FS 2,500PSI @ 2.44BPM 17:10 - 9,319', 550PSI MTR WORK, 3.28K WOB, 10.42 ECD STALL @ 9,319' WITH 15K OVER PULL STALL @ 9,376'. DRILL AHEAD TO 9410' MD. PROD1 WIPER TO WINDOW. 250 PSI BACKREAMING MOTOR WORK WITH NO ASSOCIATED OVERPULL AT 8522' MD. RBIH TO RESUME DRILLING. TAG AND STALL AT 8522' MD RUNNING AT 30 FPM PUMPING AT 2.4 BPM WITH TOOLFACE AT 80 L. PU CLEAN. PROD1 REPEATEDLY ATTEMPT TO WORK PAST TAG AT 8522' MD WITH NO SUCCESS. TRY RIH AT VARIOUS SPEEDS AND VARIOUS PUMP RATES (ADJUSTED CHOKE WHILE ATTEMPTING TO WORK PAST OBSTRUCTION TO MAINTAIN EMW OF -10 PPG). TRY PARKING ON TAG DEPTH AND ROTATING TOOLFACE THROUGH 360 DEGREES ROTATION. TRY PARKING ON TAG AND SURGING PUMP TO WORK THROUGH (STALL EVERY TIME). AS -DRILLED TOOLFACE ORIENTATION AT THIS POINT IS 115 DEGREES LEFT OF HIGH SIDE. ATTEMPTED TO RUN PAST AT 115 L, 140 L, 90 L, AND 65 R. PICK-UPS ARE CLEAN OFF OF TAG DEPTH, EVEN AFTER STALLING. TAG DEPTH IS CONSISTENT. DPRB IPRODI DPRB IPRODI 1/4/2010 100:00 - 00:50 1 0.831 DRILL IN I DPRB I PROD1 PUH AND REPEAT TIE-IN. CORRECTION OF (+3.5'). CALL TOWN ENGINEER. DECIDE TO ATTEMPT TO DRILL THROUGH OBSTRUCTION. RBIH TO ATTEMPT TO DRILL THROUGH OBSTRUCTION. FREESPIN OF 2500 PSI WITH -100 PSI WHP AND 2.5 BPM, -10.2 PPG ECD. TIME DRILL INTO TAG; ENGAGE AT 8525.9' MD. SEE -100 PSI MOTOR WORK, ALLOW TO MILL OFF. CONTINUE TIME DRILLING INTO OBSTRUCTION AT -15 FPH. IAP = 15 PSI. OAP = 95 PSI. CONTINUED ON DIMS REPORT 01/04/10. CONTINUED FROM DIMS REPORT 01/03/10. IAP = 15 PSI. OAP = 95 PSI. CONTINUE TIME DRILLING AT -15 - 20 FPH. AFTER MAKING -20', ATTEMPT TO INCREASE ROP. STACK -3K WOB WITH -300 PSI MOTOR WORK. BELIEVE WE HAVE SIDETRACKED. DRILL AHEAD TO 8566' MD. PU Printed: 1/25/2010 12:05:44 PM 1 0 0 BP EXPLORATION Page 9 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To I Hours I Task Code I NPT Phase I Description of Operations 1/4/2010 00:00 - 00:50 0.83 DRILL N I DPRB I PROD1 AND DRIFT CLEANLY PAST PREVIOUS OBSTRUCTION DEPTH WITH MOTOR NOT TURNING, TAG TD AT 8566' MD. 00:50 - 04:00 3.17 DRILL N �SFAL PROD1 04:00 - 07:15 3.25 DRILL N DPRB PROD1 07:15 - 08:00 1 0.75 DRILL N DPRB PROD1 08:00 - 10:25 1 2.42 DRILL N DPRB PROD1 10:25 -12:40 1 2.251 DRILL IN I DPRB I PROD1 12:40 - 13:00 0.33 DRILL N DPRB PROD1 13:00 14:20 1.33 DRILL N DPRB PROD1 14:2014:30 0.17 DRILL N DPRB PROW 14:30 14:40 0.17 DRILL IN DPRB PROD1 14:40 - 15:00 0.33 DRILL N DPRB PROD1 15:00 - 16:05 1.08 DRILL N DPRB PROD1 16:05 16:20 0.25 DRILL N DPRB PROD1 16:20 17:45 1.42 DRILL N DPRB PROD1 17:45 -18:45 1.00 DRILL N DPRB PROD1 18:45 - 20:45 2.00 DRILL N DPRB PROD1 20:45 - 21:15 I 0.501 DRILL IN I DPRB I PROD1 PUH AND CIRCULATE/RECIPROCATE WHILE DD AND MWD LOGGER RESET THEIR COMPUTERS. BEGIN DRILLING AHEAD FROM 8566' MD. UP WEIGHT IS 35000 LB. RIH WEIGHT IS 11400 LB. FREESPIN IS 2520 PSI AT 2.55 BPM AT 60 PSI WHP (ECD IS 10.2 PPG). DRILL AHEAD CONSISTENTLY WITH -200 PSI MOTOR WORK AND 3000 LB WOB MAKING AN AVERAGE ROP OF 80 FPM. DRILL TO 8,700' WIPER TRIP TO WINDOW SMOOTH DRILL FROM 8,700' FS 2,500PSI @ 2.47BPM 08:30 - 8,715', 20OPSI MTR WK, 6.4K WOB, 10.29 ECD 09:30 - 8,741', 165PSI MTR WK, 4.9K WOB, 10.29 ECD DRILL TO 8,762' POH TO CHECK TOOLS OPEN EDC ABOVE WINDOW & CONTINUE TO POH JOG HOLE 2 TIMES TO 500' FROM SURFACE WELL UNLOADED QUITE A BIT OF CUTTINGS ACROSS THE SHAKERS RANGING IN SIZE FROM 1/16"-1/8" DURING JOGS PJSM TO UNDEPLOY BHA UNDEPLOY BHA AS PER LARGE TOOL UNDEPLOYMENT PROCEDURE WHILE MAINTAINING 40OPSI WHP BIT HAS 1 COMPLETLY PLUGGED JET & 1 PARTIALLY PLUGGED JET RU NEW MTR ON CATWALK PJSM TO DEPLOY BHA DEPLOY BHA WITH NEW MTR & BIT AS PER LARGE TOOL DEPLOYMENT PRCEDURE WHILE MAINTAINING 40OPSI WHP TEST TOOLS AT SURFACE RIH W/ NEW BIT & MTR LOG TIE-IN FROM 8025'. CORRECTION OF (-8.5'). BACK ON BOTTOM DRILLING, HOLDING ECD OF 10.3 PPG. FREESPIN OF 2700 PSI AT 2.5 BPM W/ 60 PSI WHP. DRILLING AHEAD HOLDING -200 PSI MOTOR WORK WITH AN ASSOCIATED WOB OF -2500 LB. WHILE RBIH DURING SHORT TRIP, SAT 8K DOWN AT 8715' (SUSPECTED FAULT). MOTOR STALLED; SHUT DOWN PUMP AND FREELY DRY RUN PAST THIS DEPTH. DRILL AHEAD TO 8900'. GEO SAMPLES SHOW NO EVIDENCE OF HOLE INSTABILITY. PERFORM WIPER TO WINDOW. REDUCE PUMP RATE TO 0.8 BPM WHEN PASSING 8715', SEE -2K OVERPULL AT THIS DEPTH WITH NO ASSOCIATED CHANGE IN CIRC PRESSURE. SEE 10K OVERPULL AND A BACKREAMING STALL AT 8510', REDUCE PUMP RATE TO 0.8 BPM AND PULL THROUGH CLEANLY. SEE 8K OVERPULL AND A rnrnev: uewev iv —vv --m BP EXPLORATION Page 10 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To I Hours Task I Code NPT Phase Description of Operations 1/4/2010 120:45 - 21:15 21:15 - 21:45 21:45 - 00:00 11/5/2010 100:00 - 00:40 00:40 - 02:20 0.501 DRILL IN 0.501 DRILL IN 2.251 DRILL IN 0.671 DRILL IN 1.671 DRILL IN 02:20 - 03:00 0.67 DRILL N 03:00 - 03:20 0.33 DRILL N 03:20 - 05:30 2.17 DRILL N DPRB PROD1 BACKREAMING STALL AT 8444' MD, REDUCE PUMP RATE TO 0.8 BPM AND PULL THROUGH CLEANLY. FINISH WIPER TO WINDOW. DPRB PROD1 RBIH AFTER WIPER. REDUCE PUMP RATE TO 0.8 BPM AT TROUBLE SPOT AT 8444' MD. TAG AT THIS DEPTH (8452' DOWN DEPTH) AND SET DOWN 6K LB HOLDING 120 L TF ORIENTATION (AS -DRILLED TF IS 150 L HERE) WITH NO ASSOCIATED CHANGE IN CIRC PRESSURE. PU AND REPEAT WITH 150 L TF ORIENTATION PUMPING AT 0.8 BPM AND PASS WITH -2K WEIGHT BOBBLE. CONTINUE IN HOLE WITH REDUCED RATE OF 0.8 BPM THROUGH TROUBLE SPOTS AT 8510' MD AND 8715' MD. PASS EACH WITH SMALL (2-3K) WEIGHT BOBBLE. DPRB PROD1 RBIH TO RESUME DRILLING. UP WEIGHT IS 32000 LB. RIH WEIGHT IS 12500 LB. FREESPIN IS 2730 PSI AT 2.55 BPM AT 62 PSI WHP. ECD IS 10.3 PPG. ENGAGE AT 8902' MD. DRILL AHEAD WITH CONSISTENT 270 PSI - 300 PSI MOTOR WORK WITH 3000 LB WOB TO 9026' MD AND COUNTING. IAP = 10 PSI. OAP = 100 PSI. CONTINUED ON DIMS REPORT 01/05/10. DPRB PROD1 CONTINUED FROM DIMS REPORT 01/04/10. IAP = 10 PSI, OAP = 100 PSI. CONTINUE DRILLING AHEAD FROM 9026' MD. DRILL AHEAD WITH --300 PSI MOTOR WORK AND -3100 LB WOB TO 9053' MD. GEO SAMPLES SHOW NO INDICATION OF HOLE INSTABILITY. DPRB PROD1 WIPER TO WINDOW. MAINTAIN AS -DRILLED TF AS PUH THROUGH PREVIOUS TROUBLE SPOT AT 8715'- MAINTAIN FULL PUMP RATE WITH NO WEIGHT BOBBLE, NO CHANGE IN CIRC PRESSURE. MAINTAIN AS -DRILLED TOOLFACE FOR REMAINDER OF WIPER TRIP. PASS 8510' WITH NO PROBLEM. AT 8440' MD, OVERPULL 10K AND STALL MOTOR. REDUCE PUMP RATE TO 0.8 BPM AND PULL THROUGH CLEANLY. REMAINDER OF WIPER TRIP UP TO WINDOW WITHOUT OVERPULUMOTOR WORK. RBIH TO TD WITH REDUCED PUMP RATE OF 0.8 BPM AND HOLDING AS DRILLED TF; NO WEIGHT BOBBLES TO TD. DPRB PROD1 UP WEIGHT 32000 LB. RIH WEIGHT 12000 LB. FREESPIN 2600 PSI AT 2.5 BPM W/ 55 PSI WHP. ENGAGE AT 9052' MD AND DRILL AHEAD WITH 250 PSI MOTOR WORK AND 2500 LB WOB. DPRB PROD1 DRILL AHEAD TO 9092' MD. STOP DRILLING AHEAD AS PER GEO REQUEST; GEO IS ANALYZING DATA TO CONFIRM THAT WE SHOULD START TO CREST HERE. PERFROM SHORT TRIP. DPRB PROD1 GEO INSTRUCTS US TO BEGIN CRESTING OVER. RBIH TO RESUME DRILLING AHEAD. FREESPIN 2600 PSI AT 2.5 BPM W/ 60 PSI WHP. DRILL AHEAD WITH 220 PSI MOTOR WORK AND 3500 LB WOB. DRILL TO 9,200' rnniev: irzoizviv iz:vo:vwrm BP EXPLORATION Page 11 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code I NPT I Phase I Description of Operations 1/5/2010 05:30 - 06:30 1.00 DRILL N DPRB PROD1 0.75 06:30 - 06:40 0.17 DRILL N DPRB PROD1 DRILL 06:40 - 07:20 0.67 DRILL N DPRB PROD1 07:20 - 09:10 1.83 DRILL N DPRB PROD1 09:10 - 10:30 1.33 DRILL N DPRB PROD1 10:30 - 11:15 0.75 DRILL N DPRB PROD1 11:15 - 13:20 2.08 DRILL N DPRB PROW 13:20 - 15:50 1 2.501 DRILL I P 15:50 - 17:20 1.50 DRILL P 17:20 - 21:50 4.50 DRILL P PROD1 PROD1 PROW WIPER TO WINDOW LOG TIE IN 8,080' TO 8,094' +3.5' CORRECTION RESET DEPTH TO 8,091.5' RIH TO TD TAG @ 9,197' DRILL FROM 9,197' FS 2,675PSI @ 2.47BPM 07:30 - 9,214', 30OPSI MTR WK, 1.9K WOB, 10.58 WOB 08:30 - 9,310', 20OPSI MTR WK, 3.3K WOB, 10.69 WOB PUMPED 5BBL HIGH VIS SWEEP @ 9,333' FOR WIPER 9,350' LOST MTR WORK @ 9,334' PU TO 9,303' WITH 40K OVER PULL @ 9,325' DRILL TO 9,342' WIPER TRIP TO WINDOW NO MTR WK OR VER PULLS OBSERVED TOOLS BECOMING INTERMITTENT PU TO 8,008' WITH EDC OPEN & CHECK TOOL CONNECTIONS TOOLS BACK ONLINE RIH TO TD TAG @ 9,339' DRILL FROM 9,339' FS 2,650PSI @ 2.44BPM 11:30 - 9,358', 30OPSI MTR WK, 1.89K WOB, 10.65 ECD STALL @ 9,377' 2 TIMES DROP PUMP RATE TO 2.25BPM FS 2,500PSI 12:30 - 9,382', 250PSI, 4.5K WOB, 10.57 ECD STALL @ 9,385' BRING PR UP TO 2.45BPM FS 2,650PSI 9,410 REACHED COMING OFF NPT AS PER TOWN INSTRUCTIONS DRILL AHEAD FROM 9,410' FS 2,650PSI @ 2.45BPM STALL @ 9,415', 9,416' 13:50 - 9,442', 20OPSI MTR WK, 1.67K WOB, 10.67 ECD DROP PR TO REDUCE TOOL VIBRATION FS 2,300PSI @ 1.95BPM 14:30 - 9,460', 30OPSI, 4.59K WOB, 10.55 ECD STALL @ 9,467' BRING UP PUMPS TO 2.36 FS 2,600PSi STALL @ 9,467', 9,487' DRILL TO 9505' WIPER TO WINDOW WAS CLEAN BOTH DIRECTIONS PVT 387 DRILL FROM 9505'2.38/2580/160L W/ 200-400 PSI DIFF, 0.5-2.5K DHWOB (5-10K SURFACE WT) W/ 10.65 ECD AT 40-807HR AT 83 DEG AT 6960' TVD. 21:20 - DRILLING AHEAD AT 9625' MD. UP WEIGHT 35000 LB. RIH WEIGHT 10900 LB. FREESPIN 2870 PSI AT 2.5 BPM W/ 55 PSI WHP. ECD IS 10.6 PPG. PVT=387. DRILLING AHEAD WITH 200 - 270 PSI MOTOR WORK WITH Printea: 1/25/2010 12:US:44 PM 0 BP EXPLORATION Page 12 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date I From - To Hours Task Code NPT Phase Description of Operations 1/5/2010 117:20 - 21:50 1 4.501 DRILL I P 21:50 - 00:00 I 2.171 DRILL I P 1/6/2010 100:00 - 00:30 00:30 - 04:10 0.501 DRILL I P 3.671 DRILL I P 04:10 - 06:50 1 2.671 DRILL I P 06:50 - 10:50 1 4.001 DRILL I P 10:50 - 13:00 1 2.171 DRILL I P PROD1 3000 LB WOB (10000 LB STACKED AT SURFACE) AT 45-80 FT/HR ROP AT 81 DEG AT 6965' TVD. DRILL AHEAD TO 9630' MD. PROD1 GEO REQUESTS A CHANGE IN WELLBORE TRAJECTORY BEFORE DRILLING ANY FARTHER IN REPSONSE TO PERCEIVED DIP FLEXIONS. WORK OUT PLAN WITH GEO AND DD AND SUBMIT TO ASSET FOR APPROVAL. BEGIN WIPER TO WINDOW HOLDING AS -DRILLED TF AS POOH. WHILE PUH DURING WIPER, OVERPULL 10K AND STALL AT 8510' MD. REMAINDER OF WIPER TO WINDOW CLEAN. TIE-IN AT RA TAG, LEAVING BIT BELOW WINDOW. CORRECTION OF (+7'). RBIH TO RESUME DRILLING AHEAD (GEOS REVISED TRAJECTORY APPROVED BY ASSET). IAP = 20 PSI. OAP = 175 PSI. CONTINUED ON DIMS REPORT 01/06/10. PROD1 CONTINUED FROM DIMS REPORT 01/05/10. IAP = 20 PSI. OAP = 175 PSI. RBIH CLEANLY AFTER WIPER HOLDING AS -DRILLED TF TO RESUME DRILLING. PROD1 BACK ON BOTTOM. UP WEIGHT 36000 LB. RIH WEIGHT 11500 LB. FREESPIN 2800 PSI AT 2.5 BPM W/ 60 PSI WHP. ECD 10.5 PPG. PVT=387. ENGAGE AT 9633' MD. BEGIN DRILLING AHEAD AT 200 - 300 PSI MOTOR WORK WITH 2000 -4000 LB WOB (7000 - 10000 LB STACKED AT SURFACE). STALL AT 9640'. CONTINUE DRILLING AHEAD. SWAP TO 48 BBL HIGH VIS PILL, THEN SWAP TO NEW GEOVIS. SEND OLD GEOVIS BACK TO MI TO RECONDITION. WATCH SHAKER AS HI -VIS SWEEP REACHES SURFACE; NO OBVIOUS INCREASE IN CUTTINGS RETURNS WITH HI -VIS SWEEP. 02:10 - DRILLING AHEAD AT 9718' MD WITH NEW GEOVIS IN HOLE. UP WEIGHT 33000 LB. RIH WEIGHT 12400 LB. FREESPIN 2410 PSI AT 2.5 BPM W/ 70 PSI WHP. ECD 10.2 PPG. CONTINUE DRILLING AHEAD FROM 9718' MD WITH 250 PSI MOTOR WORK AND 3700 LB WOB (7K LB STACKED AT SURFACE) MAKING -50-70 FPM ROP. GEO SAMPLES AT 9650' AND 9700' SHOW NO EVIDENCE OF HOLE INSTABILITY. DRILL AHEAD TO 9800' MD. PROD1 PU CLEAN AT 33000 LB OFF BOTTOM AT 9800' MD. FREESPIN 2400 PSI AT 2.5 BPM W/ 65 PSI WHP, ECD 10.2 PPG. WIPER TO WINDOW HOLDING AS -DRILLED TF. NO OVERPULLS OR MOTOR OBSERVED DURING WIPER TO WINDOW. WIPER BACK TO TD WAS CLEAN AND TOOK LONGER THAN NORMAL WHILE GEO'S DETERMINE PLAN FORWARD PVT 431 PROD1 DRILL FROM 9800'2.55/2620/80L W/ 100-300 PSI DIFF, 1.5-4.5K WOB (2.5K SURFACE WT) W/ 10.16 ECD AT 25-70'/HR AT 85 DEG AT 6995' TVD. POINT TF HS AT 9900' AND BEGIN INVERT. DRILL TO 9950' PVT 432 PROD1 WIPER TO WINDOW 35K, 10K WAS CLEAN BOTH F'nntea: 1/2D/LU1U 1Z:UY.441'M 1 0 0 BP EXPLORATION Page 13 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase I Description of Operations 1/6/2010 10:50 - 13:00 2.17 DRILL P PROD1 13:00 - 17:00 4.00 DRILL P PROD1 17:00 - 19:30 2.50 DRILL P PROD1 19:30 - 22:00 2.50 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 1/7/2010 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 02:50 2.08 DRILL P PROD1 02:50 - 04:20 1.50 DRILL P PROW 04:20 - 05:30 1.17 DRILL P PROD1 05:30 - 08:05 2.58 DRILL P PROW 08:05 - 11:00 2.92 DRILL P PROD1 11:00 - 12:30 1.50 DRILL P PROW 12:30 - 12:40 0.17 DRILL P PROW 12:40 - 14:00 1.33 DRILL P PROW DIRECTIONS DRILL FROM 9950'2.51/2660/l OR W/ 100-300 PSI DIFF, 2.5-4.5K WOB (OK SURFACE WT) W/ 10.33 ECD AT 15-70'/HR AT 92 DEG AT 7002' TVD. DRILL TO 10100' PVT 427 WIPER TO WINDOW, CLEAN BOTH DIRECTIONS. UP WEIGHT 35000 LB. RIH WEIGHT 10000 LB. TIE-IN AT RA TAG, (+6') CORRECTION. DRILL FROM 10100'. UP WEIGHT 35000 LB. RIH WEIGHT 9200 LB. FREESPIN 2670 PSI AT 2.6 BPM W/ 70 PSI WHP. DRILL AHEAD WITH 200-300 PSI MOTOR WORK AND 2-4K LB WOB (9000 LB - 10000 LB STACKED AT SURFACE) W/ 10.4 ECD AT -50 FPH. PVT = 422. DRILL AHEAD TO 10250'. WIPER TO WINDOW. UP WEIGHT 35000 LB. RIH WEIGHT 10000 LB. HOLD AS -DRILLED TF IN BOTH DIRECTIONS. RUNNING BACK IN HOLE AFTER WIPER. IAP = 20 PSI. OAP = 300 PSI. CONTINUED ON DIMS REPORT 01/07/10. CONTINUED FROM DIMS REPORT 01/06/10. IAP = 20 PSI. OAP = 300 PSI. CONTINUE RIH AFTER WIPER. WIPER CLEAN IN BOTH DIRECTIONS. CONTINUE DRILLING AHEAD FROM 10250' MD. UP WEIGHT 35500 LB. RIH WEIGHT 9200 LB. FREESPIN 2650 PS AT 2.6 BPM AT 70 PSI WHP (ECD 10.4 PPG). PVT 409. DRILL AHEAD WITH AVERAGE OF 250 PSI MOTOR WORK AND 2500 LB WOB (10K STACKED AT SURFACE). DRILL AHEAD TO 10340' MD. FIND ONE DIME SIZED RUBBER CHUNCK IN SAMPLE FROM 10300'. PERFORM SHORT WIPER TRIP AS PER GEO. GEO NEEDS TIME TO EVALUATE LOGS TO GIVE US REVISED TRAJECTORY. RBIH TO RESUME DRILLING. UP WEIGHT 35500 LB. RIH W EIGHT 9100 LB. FREESPIN 2650 PSI AT 2.56 PSI W/ 60 PSI WHP. ECD 10.4 PVT 405. ENGAGE AT 10339' MD. BEGIN DRILL AHEAD W/ 200-300 PSI MOTOR WORK AND -3000 LB WOB (17000 LB STACKED AT SURFACE). WIPER TO WINDOW. UP WEIGHT 35000 LB. WIPER WAS CLEAN BOTH DIRECTIONS EXCEPT FOR SETDOWN AT 10280' AT TF CHANGE AREA AND GOT STOPPED OUT DRILL FROM 10400'2.60/2720/90-1 IOL W/ 200-500 PSI DIFF, 1.0-2.OK WOB (+6K SURFACE WT) W/ OPEN CHOKE AND 10.42 ECD AT 94 DEG AT 6958' TVD. DRILL TO 10498' AND STACKING. REVISED PLAN IS TO DRILL TO -10580' WIPER TO WINDOW. HAVE NUMEROUS CT PRESSURE SURGES DUE TO ASSUMED MOTOR RUBBER PLUGGING BIT JETS. HAD MINI OP AT 8725' AND ALSO PLUGGED OFF OUT MM DUE TO SAME. HOLE WAS CLEAN LOG TIE-IN DOWN FROM 8070', CORR +6' WIPER BACK TO TD WHILE CONTINUE TO CLEAN OUT RETURN LINE THRU OUT MM. FOUND ANNULAR RUBBER. HOLE WAS CLEAN TO SET DOWN AT 10280' Printed: 1/25/2010 1Z:0b:44 PM BP EXPLORATION Page 14 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations rnntea: uzorzuiu iz:uo:vvrm 1/7/2010 14:00 - 14:40 0.67 DRILL P PROD1 WORK TO GET BY 10280',10320- AND 10340'. A2/A3 SHALE AND THEN 180 DEG TF CHANGE AT 10340' CONTRIBUTED TO DIFFICULTY. GET BY AT 0.5 BPM AND RIH TO 10420'. BACKREAM W/ MINOR OP'S, BUT MW IN SAME AREAS. RBIH AS BEFORE AND FINISH WIPER TO TD TAGGED AT 10499' 14:40 - 15:50 1.17 DRILL P PROD1 DRILL FROM 10499'2.62/3200/90L W/ 200-400 PSI DIFF, 1.5-3.5K WOB (+5K SURFACE WT) W/ OPEN CH AND 10.89 ECD AT 93 DEG AT -6950' TVD AT 90-150'/HR INITIAL. DRILL TO END OF POLYGON AT 10580' 15:50 - 16:25 0.58 DRILL P PROD1 SWAP TO 50 BBLS FRESH MUD FOLLOWED BY USED MUD WHILE WIPER TO 10200',CLEAN WIPER BACK TO TD W/ MIN RATE THRU SHALE AREA WAS CLEAN 16:25 -17:50 1.42 DRILL P PROW WIPER BACK TO WINDOW LEAVING FRESH MUD IN OPEN HOLE WAS CLEAN. PULL THRU WINDOW, OPEN EDC 17:50 -18:50 1.00 DRILL P PROD1 POH TO 7000' WHILE CIRC THRU EDC 3.1/2800. PAINT WHITE FLAG AT 7000' EOP (UDAC), 7083.3' CTDS. 18:50 -19:20 0.50 DRILL P PROD1 PARK AT 7000' AND CIRCULATE 11.0 PPG NaBr INTO WELLBORE. 19:20 - 21:00 1.67 DRILL P PROD1 PULL TO SURFACE CIRCULATING WITH -0.7 BPM RETURNS. 21:00 - 21:30 0.50 DRILL P PROD1 TAG UP AT SURFACE. FLOW CHECK. PJSM TO LAY DOWN BHA. 21:30 - 22:00 0.50 DRILL P PROD1 STAND BACK INJECTOR, REMOVE 5' LUBRICATOR. LD BHA. 22:00 - 22:20 0.33 CASE P RUNPRD PU BTT TOOLS. MU CTC, PULL TEST TO 35K. GOOD. PRESSURE TEST CTC TO 4000 PSI, GOOD. 22:20 - 00:00 1.67 CASE P RUNPRD CUT OFF CONNECTOR AND 9' OF CT. PUMP OUT ELINE SLACK AT 3.4 BPM, GET 265' OF ELINE OUT. IAP = 10 PSI. OAP = 10 PSI. CONTINUED ON DIMS REPORT 01/08/10. 1/8/2010 00:00 - 01:30 1.50 CASE P RUNPRD CONTINUED FROM DIMS REPORT 01/07/10. IAP = 10 PSI. OAP = 10 PSI. STAB ON, PUMP OUT ELINE SLACK AT HIGHER RATE (4.6 BPM); CUT OFF ADDITIONAL 3' ELINE. PREPARE FOR RUNNING LINER. STAGE FARR TONGS. MU SAFETY JOINT. CHANGE OUT DIES ON SLIPS. 01:30 - 02:15 0.75 CASE P RUNPRD PJSM FOR MAKING UP LINER. REVIEW LINER SUMMARY. 02:15 - 06:00 3.75 CASE P RUNPRD BEGIN MAKING UP LINER. 06:00 - 06:30 0.50 CASE P RUNPRD CREW CHANGE/SAFETY MTG 06:30 - 07:45 1.25 CASE P RUNPRD FIN MU LINER 07:45 - 08:50 1.08 CASE P RUNPRD MU CTLRT W/ LOWER MHA + 3 JTS 2-3/8 PH6 + BTT SWIVEL FILL MT PITS W/ 225 BBLS SLICK 2% KCL. ADD FLOVIS TO PIT 4 AND BIOZAN TO PIT 5 08:50 - 09:25 0.58 CASE P RUNPRD FILL CT W/ 45 BBLS FLOPRO 2.8/1280 FROM PIT 4 WHILE TAKE NaBr TO PIT 3 THRU BUNGHOLE. SWAP TO KCL. STAB ON W/ INJECTOR 09:25 - 10:30 1.08 CASE P RUNPRD LINER CIRC KCL 0.40/700 DOWN CT WHILE TAKE 11.0 PPG KWF RETURNS. MUD AT SHOE AT 7000' 10:30 -11:55 1.42 CASE P RUNPRD 8000' 35k, 11k RIH THRU WINDOW, CLEAN. RIH IN OPEN HOLE TO rnntea: uzorzuiu iz:uo:vvrm BP EXPLORATION Page 15 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date I From - To I Hours Task Code NPT Phase Description of Operations 1/8/2010 110:30 - 11:55 11:55 - 13:00 1.421 CASE I P 1.081 CEMT I P 13:00 -13:40 1 0.671 CEMT I P 13:40 -15:00 1 1.331 CEMT 1 P 15:00 -15:20 0.33 CEMT P 15:20 -15:40 0.33 CEMT P 15:40 - 16:50 1.17 CEMT P 16:50 - 17:30 0.67 CEMT P 17:30 - 19:45 2.25 CEMT P 19:45 - 20:45 20:45 - 21:15 1.001 CEMT IP RUNPRD 10240' RELATIVELY CLEAN. SEE FLAG ON DEPTH. WORK LINER TO BOTTOM AND GET TO 10580' THREE TIMES, BUT FEELS HIGH MIRU SWS CEMENTERS RUNPRD CIRC KCL 1.50/1500 W/ FULL RETURNS OF 10.6 PPG KWF. WORK RATE UP TO 2.0/1740 TO SHEAR MUD AND MOVE PATTIES OUT OF OPEN HOLE (SEE PRESSURE AND RATE CYCLES). PUH 40K TO BALL DROP AT 10571' LOAD 5/8" STEEL BALL AND LAUNCH W/ 500 PSI. DID NOT HEAR BALL ROLLING, RIH AND STACK 10K AT 10580', CIRC 2.39/1540. AFTER 35 BBLS PUMPED, RED RATE TO 0.5 BPM TO LET BALL FALL AND LOST STRING WT. RIH TO FINAL TD OF 10594% CIRC 0.52/400 W/ FULL RETURNS AND WAIT FOR BALL TO SEAT. MUD BACK TO SURFACE RUNPRD WORK TO GET BALL ON SEAT WO SUCCESS PUH 53K -43K WHILE PULL TO BALL DROP AT 10571'. LOAD 5/8" ALUMINUM BALL AND LAUNCH W/ 2000 PSI AGAINST REEL MANIFOLD VALVE AND CIRC 2.0/1000. SET LINER BACK DOWN, BUT STOPPED AT 10581' AGAIN. HEARD (PROBABLY) THE STEEL BALL ROLLING UNTIL GOING OVER GOOSENECK. RED RATE TO 0.54/150 AND LET BALL(S) FALL. KCL BACK TO SURFACE RUNPRD CIRC, SURGE AND WORK PIPE AND FINALLY GOT A BALL ON SEAT. LOST GROUND BACK TO 10578'. ATTEMPT TO WORK DEEPER, BUT NO PROGRESS. PRESSURE UP ON BALL SEAT AND SHEARED AT 3500 PSI, LOOK FOR PIPE MOVEMENT, BUT NONE. PUH 30K AND WERE RELEASED. RBIH AND SET 10K AT 10578' AND CIRC KCL 1.52/500 RUNPRD SAFETY MTG RE: CEMENTING RUNPRD CONTINUE TO CIRC WHILE WO CEMENTERS TO TAKE ON WATER AND BATCH UP RUNPRD START TO GET GAS AND SKIM OF CRUDE BACK W/ 10 PPM LEL 1.53/520. MONITOR FOR 10 MIN, THEN APPLY 200 PSI WHP. THEN GET 20 PPM LEL AND TAKE RETURNS TO TIGER TANK 1.54/700. TAKE 20 BBLS TO TIGER TANK AND GAS ENDED, BUT CRUDE HAS INCREASED AND NOW SEE OUT MM DENSITY AT 7.57 PPG. CBU 1.55/700 RUNPRD SEE DRAMATIC CHANGE IN OUT DENSITY AT 30 BBLS BEFORE BU AND ARE NOW AT CORRECT OUT DENSITY AND RATE. BRING RETURNS BACK INSIDE RUNPRD CONTINUE TO CIRC 1.55/750 HOLDING 200 PSI WHP ON CHOKE WHILE WO RIG AND CEMENTERS CREW CHANGE OUT RUNPRD PJSM RE: CEMENTING. DURING SAFETY MEETING, CONTINUE CIRCULATING AT 1.55 BPM AT 840 PSI W/ 220 PSI WHP. RETURNS ARE 1:1. 0.50 CEMT P RUNPRD BEGIN BATCHING CEMENT. CEMENT IS 15.8 PPG CLASS G WITH A TT OF 3 HOURS 5 MINUTES TO 70 BC. CEMENT AT WEIGHT AT 20:57; CEMENT SHOULD BE AT 70 BC AT 00:02. Nnntea: 7/1b/LUIU 1L:u5:44YM BP EXPLORATION Page 16 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 1/8/2010 20:45 - 21:15 0.50 CEMT P RUNPRD RIG MOVE PRECLUDES SENDING SAMPLE BACK TO DEADHORSE FOR UCA TESTING. INSTEAD, HAVE SLB LABORATORY START A UCA TEST WITH SAMPLES OF THE ACTUAL MIX WATER AND CEMENT BLEND THAT WAS TAKEN WHEN THE CEMENT WAS LOADED OUT THIS MORNING. 21:15 - 21:40 0.42 CEMT P RUNPRD SWAP TO BIO TO DISPLACE LINE TO CT W/ BIO. DOWN ON PUMP, TRAPPING 200 PSI WHP. SWAP TO CEMENTERS PUMP. BEGIN PUMPING FW FROM CEMENTERS DOWN CT HOLDING 200 PSI WHP. ISOLATE, TRAP 200 PSI WHP, PT CEMENTERS TO 4000 PSI. GOOD. BYPASS MM AND PT CEMENTERS TO 5500 PSI, GOOD. 21:40 - 22:50 1.17 CEMT P RUNPRD ONLINE WITH FW FROM CEMENTERS PUMP PUMPING 1.45 BPM AT 810 PSI. BEGIN CEMENT DOWN COIL, CALL DENSITY AT 15.0 PPG. INCREASE RATE TO 2 BPM AT 1340 PSI (AND CONTINUALLY INCREASING W/ MORE CEMENT IN COIL) AND 220 PSI WHP. IAP = 5 PSI, OAP = 10 PSI. RETURNS ARE 1:1. MAINTAIN -10K ON WEIGHT CELL. 13 BBLS AWAY, PRESSURE IS 2290 PSI AT 2 BPM W/ 220 PSI WHP. 22 BBLS AWAY, GOING OVER GOOSENECK. 2.0 BPM AT 2974 PSI W/205 PSI WHP. 28 BBLS AWAY, REDUCE RATE TO 0.5 BPM TO GET ALL OF PRODUCT OUT OF BATCH MIXER. 0.5 BPM, 630 PSI, 200 PSI WHP. 31 BBLS AWAY, RIG MM DENSITY FALLS TO 15.0 PPG. DOWN ON PUMP. END OF CEMENT STAGE. TOTAL OF 31.0 BBLS CEMENT LINE UP WITH RIG PUMP. PUMP -3 BBLS BIO DOWN CEMENTERS LINE TO CEMENTERS. LINE UP WITH BIO DOWN CT W/ RIG PUMP. ZERO RIG MM AND OUT MM. ONLINE WITH 2 PPB BIOZAN DOWN CT WITH RETURNS UP BACKSIDE. MAINTAIN -10K ON WEIGHT CELL. AFTER 12 BBLS BIO AWAY, CATCH UP W/ FALLING CEMENT. RETURNS NOW 1:1. PUMPING 945 PSI AT 2.13 BPM W/ 200 PSI WHP. MAINTAINING -10K LB ON WEIGHT CELL. 37.8 BBLS AWAY, ZERO RETURN MM (CEMENT AT SHOE). RETURNS ARE 1:1. 45.5 BBLS AWAY, PUMPING AT 2 BPM AT 1800 PSI W/ 220 PSI WHP. SWAP TO KCL AND REDUCE RATE. PRESSURE AT 1.5 BPM IS 1300 PSI W/ 220 PSI WHP. 48.7 BBLS AWAY, DOWN ON PUMP. TWO BBLS CEMENT REMAIN ABOVE GEN 2 SELRT. PU UNTIL BO (33K AT 10570' MD). PU ADDITIONAL 13' TO 10557'. IAP = 5 PSI, OAP = 10 PSI. RBIH 10' TO RELEASE PEE WEE DART. RIH UNTIL HAVE -10K ON WEIGHT INDICATOR (DEPTH IS 10568' W/ -10K ON WEIGHT INDICATOR). SLOWLY BRING ON PUMP DOWN CT TO DISPLACE PEE WEE DART TO LWP. PUMP UP TO 520 PSI; SD PUMP AND HOLD FOR -30 SECONDS, winteU: 1/15/ZU1U 11:UY.44 F'M BP EXPLORATION Page 17 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours I Task Code NPT Phase I Description of Operations 1/8/2010 21:40 - 22:50 1.17 CEMT P RUNPRD 22:50 - 23:20 0.50 CEMT P RUNPRD 23:20 - 00:00 0.67 CEMT P RUNPRD 1/9/2010 00:00 - 01:30 1.50 CEMT P RUNPRD PRESSURE HOLDING. PU TO BO AT 10560.3'. CIRC PRESSURE FALLS AWAY. ONLINE AT 1.5 BPM TO SIDE EXHAUST CEMENT. PUMPING AT 1.5 BPM AT 930 PSI AT 220 PSI WHP. RETURNS ARE 1:1. INCREASE RATE TO 2.0 BPM AT 1170 PSI W/220 PSI WHP. DOWN ON PUMP AFTER 5 BBLS PUMPED OUT SIDE EXHAUST (2 BBLS CEMENT AND 3 BBLS BIO). OPEN BAKER CHOKE. S T CELL. CLOSE BAKER CHOKE. PRESSURE UP ON CT TO SHEAR. SHEAR AT 3470 PSI, SEE IMMEDIATE REPSONSE IN WHP (INCREASES BY —100 PSI). ZERO RIG MM. ONLINE AT 1.4 BPM TO DISPLACE PLUG TO SEAT, PUMPING AT 1.4 BPM AT 1415 PSI W/ 200 PSI WHP. RETURNS ARE 1:1. AT —8.5 BBL AWAY, CIRC PRESSURE INCREASE TO 1500 PSI AT 1.4 BPM W/ 210 PSI WHP. AT 12.6 BBL AWAY, CIRC PRESSURE INCREASE TO 1800 PSI AND CLIMBING AT 1.4 BPM W/ 210 PSI WHP. REDUCE RATE TO 1.3 BPI AND REDUCE WHP TO 180 PSI, CIRC PRESSURE 1930 PSI. RETURNS 1:1. AT 17.4 BBLS AWAY, REDUCE RATE TO 0.6 BPM AT 1250 PSI W/ 170 PSI WHP. BUMP AT 18 BBLS AWAY. INCREASE CIRC PRESSURE TO 1000 PSI ABOVE BUMP. HOLD FOR 3 MINUTES (SOLID AT 2200 PSI). OPEN BAKER CHOKE, CHECK FLOATS - GOOD (WHP IS 140 PSI). PRESSURE UP ON LINER TO 490 PSI. SLOWLY PU, PRESSURE FALL AWAY AT 10561' AT 27000 LB UP WEIGHT. ONLINE DOWN CT W/ RETURNS UP BACKSIDE HOLDING 150 PSI WHP. RETURNS ARE 1:1. RECIPROCATE WITH BIOZAN ACROSS 500' INTERVAL ABOVE LT, MAINTAINING 0.75 BPM ON OUT RATE. ESTIMATED TOC IS AT LINER TOP AT 7602' MD. RETURNS 1:1 THROUGHOUT CEMENT JOB. SWAP TO 9.8 PPG NACL AT 33 ON MM. PUMPING 1.2 BPM AT 530 PSI W/ 160 PSI WHP WHILE RECIPROCATING TO LAY -IN BIO. BACK ABOVE LT (WILL CONTINUE TO RECORD CTDS DEPTHS) AT 10535'. KCL AT END OF TOOLS. RECIPROCATE HERE AND WAIT FOR KWF TO HIT EOT. AT 28 BBLS OF KW AWAY, BEGIN TO GET BIO BACK AT SURFACE. DIVERT TO OUTSIDE. IAP = 5 PSI, OAP = 10 PSI. CONTINUED ON DIMS REPORT 01/09/10. CONTINUED FROM DIMS REPORT 01/08/10. IAP = 5 PSI. OAP = 15 PSI. CIRCULATE KWF OOH. SEE SMALL VOLUME OF CEMENT COME BACK ON SCHEDULE. CEMENT IS STRUNG OUT AND CONTAMINATED BUT LOOKS LIKE LESS THAN 2 BBLS. KWF AT SURFACE, WHP 40 PSI AT FOC. BEGIN POOH. rnniea: vzwzuiu iz:ua:av rm BP EXPLORATION Page 18 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To I Hours Task I Code I NPT Phase Description of Operations 1/9/2010 01:30 - 04:00 2.50 CEMT P RUNPRD AFTER PUH 500' SEE SMALL VOLUME GAS AT SHAKER, LEL=4. RBIH TO JUST ABOVE LINER AND CIRCULATE. BEGIN PUH AGAIN, GET SMALL VOLUME GAS AT SHAKER, LEL=3. FLOWCHECK - NO FLOW. BLEED SMALL GAS HEAD OUT OF LUBRICATOR. BEGIN POOH CIRCULATING 9.8 NACL AT 1.2 BPM PULLING AT -100 FPM W/ 15 PSI WHP. TAKING COIL VOIDAGE INTO ACCOUNT, RETURNS ARE 1:1. 04:00 - 05:00 1.00 CEMT P RUNPRD TAG UP AT SURFACE. PJSM FOR LAY DOWN LINER RUNNING TOOLS. BEGIN LAY DOWN LINER RUNNING TOOLS. RECOVER BOTH BALLS. STEEL BALL WAS ON SEAT AND STUCK IN TOOL. FOUND 3' ELINE OUT END OF CTC. CHASED OUT DEAD LEGS IN CHOKE AND REELHOUSE. 05:00 - 05:30 0.50 EVAL P LOWER1 PREP FLOOR FOR MU CSH. 05:30 - 06:30 1.00 EVAL P LOWER1 CREW CHANGE/SAFETY MTG, -39F 06:30 - 08:45 2.25 EVAL P LOWER1 MU SWIZZLE STICK. JET STACK AND RECHECK ALL DEAD LEGS WHILE WO SWS MCNL LOGGER. D-14 RIG MOVE HAS BLOCKED THE SPINE BETWEEN MPU TURNOFF AND V PAD. RD SWIZZLE STICK, SET INJECTOR ON LEGS 08:45 - 09:45 1.00 EVAL P LOWER1 WAIT FOR LOGGER MIX FLO PRO PILL. UCA IS AT 2000 PSI AFTER 11 HRS 09:45 -11:10 1.42 EVAL P LOWER1 SAFETY MTG RE: SOURCE BRING SWS MCNL TOOLS TO FLOOR. MU NEW 2.30" D331 MILL ON 2-1/8" BTT MOTOR W/ 2 JTS 1-1/4" CSH. MU MCNL AND LOAD SOURCE. ADD LOWER MHA 11:10 -14:45 3.58 EVAL P LOWER1 MU 95 JTS OF 1-1/4" CSH SINGLES. ADD UPPER MHA 14:45 - 15:45 1.00 EVAL P LOWER1 RIH W/ CT CIRC 30 BBLS OF FLOPRO 0.37/490 FOLLOWED BY 9.8# NaCl 15:45 - 17:40 1.92 EVAL P LOWER1 7300'25.5K, 10.3K LOG DOWN AT 307MIN TO PBD. DID NOT SEE TOL. TAGGED PBD AT 10555' CTD -NORMAL CORR IS -9' SO PBD EST AT 10546' 17:40 - 18:40 1.00 EVAL P LOWER1 LOG UP HOLE 31K AT 607MMIN WHILE LEAVING FLOPRO MUD IN LINER. LOG TO 7234' MD. 18:40 - 19:40 1.00 EVAL P LOWER1 POOH CIRCULATING 9.8 PPG NaCl AT -1 BPM AT 1450 PSI. 19:40 - 20:00 0.33 EVAL P LOWER1 PJSM FOR LAYING DOWN PH6. 20:00 - 20:20 0.33 EVAL P LOWER1 LAY DOWN PH6. ZERO FOOT OF ELINE IN PH6. 20:20 - 20:45 0.42 EVAL P LOWER1 PJSM FOR DROPPING BALL TO OPEN CIRC SUB AND FOR STANDING BACK CSH. 20:45 - 22:25 1.67 EVAL P LOWER1 DROP 0.5" STEEL BALL TO FUNCTION CIRC SUB. OPEN CIRC SUB AT 2400 PSI W/ TEST PUMP. BEGIN PULLING AND STANDING BACK CSH. 22:25 - 23:15 0.83 EVAL P LOWER1 DIFFICULTY FUNCTIONING DRAWWORKS. STOP STANDING BACK CSH AND STANDBY TO TROUBLESHOOT. FIND THAT THE ANNULAR PREVENTER, WHICH WAS CLOSED TO PRESSURE UP ON CT TO FUNCTION CIRC SUB, WAS NOT OPENED AFTER THAT OPERATION WAS COMPLETE. THE STANDS OF CSH HAVE BEEN PULLED THROUGH A CLOSED ANNULAR rnnceu: uzorzuiu iz:uo:wvrm BP EXPLORATION Page 19 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date I From - To I Hours Task I Code NPT I Phase 1/9/2010 122:25 - 23:15 1 0.831 EVAL I P 23:15 - 00:00 1 0.751 EVAL I P 1/10/2010 100:00 - 00:45 I 0.751 EVAL I P 00:45 - 01:10 1 0.421 EVAL I P 01:10 - 01:40 1 0.501 EVAL I P 01:40 - 02:10 0.501 EVAL I P 02:10 - 04:00 1.831 EVAL I P 04:00 - 06:00 1 2.001 PERFOB� P 06:00 - 07:00 1.00 PERFO P 07:00 - 07:15 0.25 PERFO P 07:15 - 09:15 2.00 PERFO P 09:15 - 09:30 0.25 PERFO P 09:30 - 10:50 1.33 PERFO P 10:50 - 13:00 1 2.171 PERFOBI P 13:00 - 13:20 1 0.331 PERFOBI P 13:20 - 13:35 1 0.251 PERFOB P 13:35 - 15:45 1 2.171 PERFOB P Description of Operations LOWER1 BAG. WITH CREW, FORMULATE AND EXECUTE PLAN TO PREVENT RECURRENCE. ADDITIONALLY, PLAN TO TEST ANNULAR BAG BEFORE MAKING ANOTHER RUN TO ENSURE ITS FUNCTIONALITY. LOWER1 CONTINUE STANDING BACK CSH. IAP = 0 PSI. OAP = 10 PSI. CONTINUED ON DIMS REPORT 01/10/10. LOWER1 CONTINUED FROM DIMS REPORT 01/09/10. IAP = 0 PSI, OAP = 10 PSI. DETAILED PJSM FOR RECOVERING RADIOACTIVE SOURCE FROM LOGGING TOOL. LOWER1 RECOVER LOGGING TOOL. SECURE SOURCE. RECOVER BALL. LOWER1 CONFIRM GOOD DATA. CORRECTION OF (-77'). CORRECTED PBTD IS 10548.6' MD. FIND TOL AT 7598' MD. EMAIL/FAX 2" MCNL LOG TO GEOLOGIST FOR FINAC=N OF PERF PICKS (04:15 AM). LOWER1 PJSM FOR LINER LAP PRESSURE TEST. LOWER1 PT LINER LAP TO 2000 PSI. WHIPS ARE: 0 MINUTES: 2085 PSI 15 MINUTES: 2067 PSI 30 MINUTES: 2056 PSI IAP REMAINED UNCHANGED AT 0 PSI DURING TEST. LINER LAP PRESSURE TEST PASSED. PRESSURE TEST ANNULAR BAG TO 200 PSI / 2500 PSI, PASSED. LOWER1 CREW CHANGE/SAFETY MTG, WO CONFIRMATION OF PERF INTERVAL FROM TOWN GEO. REMOVE 20' GUN AND ADD 10' GUN TO BOTTOM INTERVAL DUE TO PBD BEING HIGHER THAN INITIALLY PLANNED LOWER1 SAFETY MTG RE: MU PERF GUNS LOWER1 MU 43 SWS 2" 6 SPF GUNS LOWER1 SAFETY MTG RE: MU CSH LOWER1 MU SWS FIRING HEAD ON 1 JT CSH W/ DISCONNECT MU 35 STDS CSH FROM DERRICK LOWER1 RIH W/ CT CIRC 0.35/150. RIH TO PBD AND TAG AT 10555.5' CTD, CORR TO 10548.6' (CNL DOWN) LOWER1 PUH FROM PBD AT 33.5K AND FIND BO AT 10545.6' THREE TIMES. PUH TO 10520'33.5K SMOOTH EACH TIME. RBIH TO 10540' AND PARK. PUH TO BO AT 10537.5' TWICE. THIS IS PLANNED PERF DEPTH PARK AT 10545' AND PRACTICE PUMPING SEQUENCE FOR E -FIRE GUNS PVT 159 LOWER1 ACTIVATE FIRING SEQUENCE. PUH 33K SLOW FROM 10545' AND PERFORM DRIVE BY PERFORATING AND GUNS FIRED W/ BOTTOM NOSE AT 10540.7' PERFORATED 9640-10270' AND 10350-10540'W/ SWS 2" 2006PJ GUNS AT 6 SPF LOWER1 PUH CLEAN AT 31K AND LOST 2 BBLS BEFORE RETURNS CAME BACK. LOST 5 BBLS OVER THE FIRST 10 MIN. POOH W/ NEARLY FULL RETURNS AND LOST AN Printed: 1252010 12:U5:44 PM ! • BP EXPLORATION Page 20 of 20 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 1/11/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task I Code NPT I Phase Description of Operations 1/10/2010 13:35 - 15:45 2.17 PERFOB P LOWERI ADDITIONAL 4 BBLS PVT 110 15:45 - 16:15 0.50 PERFOB P LOWERI LD UPPER BHA 16:15 - 18:45 2.50 PERFOB P LOWERI LD CSH SINGLES 18:45 -19:30 0.75 PERFOB P LOWERI WELCOME BACK MEETING W/ FRESH NORDIC CREW. 19:30 - 20:00 0.50 PERFOB P LOWERI PJSM RE: LAYING DOWN PERF GUNS. NOTE: PERF GUNS WERE 2" POWERJET HSD, 2006,6 SPF W/ 60 DEG PHASING. EACH BLANK SECTION CONTAINED A PURE PUNCHER TO RELIEVE TRAPPED PRESSURE. PERFS WERE SHOT W/ REFERENCE TO BAKER HUGHES INTEO MWD GR/RES LOG DATED 07 -JAN -2010. 20:00 - 23:00 3.00 PERFOB P LOWERI LAY DOWN PERF GUNS. CONFIRM ALL SHOTS FIRED. ALL SHOTS ON SCALLOPS. NO EVIDENCE OF LOW -ORDERING. 23:00 - 23:15 0.25 RIGD P POST PJSM W/ LRS RE: PUMPING WARM DIESEL INTO CT. 23:15 - 00:00 0.75 RIGD P POST RIH TO 2300' CTMD. CIRCULATE/LAY-IN 37 BBLS DIESEL (AT -75 DEG F) INTO WELLBORE FROM 2300' CTMD. CONFIRM CLEAN DIESEL RETURNS AT SURFACE. IAP = 10 PSI. OAP = 10 PSI. CONTINUED ON DIMS REPORT 01/11/10. 1/11/2010 00:00 - 00:05 0.08 RIGD P POST CONTINUED FROM DIMS REPORT 01/10/10 IAP = 10 PSI, OAP = 10 PSI. TAG UP AT SURFACE. ISOLATE WELL. LEFT 0.5 BBLS DIESEL IN CT. 00:05 - 00:45 0.67 RIGD P POST REMOVE CHECKS FROM BHA. STAB ON AND REVERSE AIR INTO REEL. EVACUATE LAST 5.8 BBLS COIL. 00:45 - 01:00 0.25 RIGD P POST PJSM RE: LAYING DOWN CSH. 01:00 - 01:50 0.83 RIGD P POST USE MOUSEHOLE, LAY DOWN REMAINING STANDS CSH. 01:50 - 02:10 0.33 RIGD P POST PJSM RE: UNLOAD PIPE SHED. 02:10 - 02:50 0.67 RIGD P POST UNLOAD PIPE SHED. 02:50 - 03:15 0.42 RIGD P POST PJSM RE: REPLACE ANNULAR ELEMENT. 03:15 - 09:00 5.75 RIGD P POST REPLACE ANNULAR ELEMENT. 09:00 - 09:30 0.50 RIGD P POST PJSM FOR C/O 2-3/8" COMBIS. 09:30 -11:00 1.50 RIGD P POST C/O 2-3/8" COMBIS. 11:00 -11:20 0.33 RIGD P POST PJSM FOR C/O VALVE BOP 17. 11:20 -14:00 2.67 RIGD P POST C/O VALVE BOP 17. 14:00 - 16:00 2.00 RIGD P POST RU OTIS FLANGE FOR BPV LUBRICATOR. 16:00 - 16:30 0.50 RIGD P POST PJSM FOR SETTING BPV. 16:30 - 18:00 1.50 RIGD P POST SET BPV. 18:00 - 22:00 4.00 RIGD P POST ND MPD LOOP. GREASE TREE VALVES. ND BOPS. MOVE CUTTINGS BOX. 22:00 - 22:30 0.50 RIGD P POST NU TREE CAP. PRESSURE TEST TREE CAP TO 3500 PSI, PASSED. 22:30 - 23:00 0.50 RIGD P POST PJSM TO MOVE RIG. 23:00 - 00:00 1.00 RIGD P POST JACK UP RIG. PULL OFF WELL. RIG RELEASE AT 24:00 HOURS (MIDNIGHT) 01/11/10. ROAD RIG TO MPL-02. rnnzeu: veoicuiv icuo:v 0 BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 2/1/2010 End: 2/9/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/9/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task I Code NPT Phase Description of Operations 2/6/2010 100:00 - 08:30 I 8.501 RIGD I P 08:30 - 09:30 1 1.001 RIGD I P 09:30 - 12:00 1 2.501 MOB P 12:00 - 13:30 1 1.501 MOB P 13:30 - 15:00 1.50 MOB P 15:00 - 21:00 6.00 MOB P 02:30 - 04:00 1 1.501 WHSUR I P 04:00 - 06:00 1 2.001 WHSUR I P 06:00 - 06:30 1 0.501 WHSUR I P 06:30 - 08:30 1 2.001 WHSUR I P 08:30 - 10:30 1 2.001 WHSUR I P 10:30 - 16:30 1 6.001 WHSUR I P 21:00 - 22:00 1.00 MOB N PRE 22:00 - 22:30 0.50 BOPSU P -BLOW DOWN AND RIG DOWN LINES. 22:30 - 23:30 1.00 KILL P 23:30 - 00:00 0.50 KILL P 2/7/2010 00:00 - 00:30 0.50 KILL N CONTINUE TO RD RIG IN PREPERATION TO MOVE TO 00:30 - 02:30 2.00 WHSUR P 02:30 - 04:00 1 1.501 WHSUR I P 04:00 - 06:00 1 2.001 WHSUR I P 06:00 - 06:30 1 0.501 WHSUR I P 06:30 - 08:30 1 2.001 WHSUR I P 08:30 - 10:30 1 2.001 WHSUR I P 10:30 - 16:30 1 6.001 WHSUR I P rrintea: emizuiu W[au:44AM PRE RD RIG IN PREPARATION TO MOVE TO MPC -24. -BLOW DOWN AND RIG DOWN LINES. -SCOPE DOWN AND LOWER DERRICK. -MOVE SHOP TO MPC PAD. -PULL PIT MODULE AND PIPE SHED AWAY FROM SUB. PRE CONTINUE TO RD RIG IN PREPERATION TO MOVE TO MPC -24. -PULL SUB BASE OFF OF WELL MPF -96. PRE MOVE RIG FROM MPF PAD TO MPC PAD. PRE SPOT SUB BASE OVER WELL MPC -24. -LAY HURCULITE AND RIG MATS AROUND WELL. -BACK SUB BASE AND CENTER OVER WELL. PRE RIG UP RIG ON MPC -24. -SPOT PIT MODULE, PIPE SHED, FUEL TRAILER, AND TIGER TANK. PRE RIG UP RIG ON MPC -24. -RAISE AND SCOPE UP DERRICK. ACCEPT RIG AT 21:00 HOURS. -RIG L PU LINES TO TIGER TANK AND PITS. WAIT PRE WAIT ON BPV CREW DECOMP PU LUBRICATOR AND TEST TO 500 PSI WITH DIESEL. PULL BPV 280 PSI ON TUBING. DECOMP CIRCULATE WELL SURFACE TO SURFACE. 6 BPM 600-1050 PSI. DECOMP MONITOR WELL. WAIT DECOMP CONTINUE TO WAIT FOR TWC. DECOMP SET TWC WITH DRY ROD. TEST TO 1000 PSI FROM BELOW FOR 10 MINUTES AND TEST FROM ABOVE TO 3500 PSI FOR 10 MINUTES. DECOMP ND TREE AND ADAPTER FLANGE. DECOMP NU BOPE. DECOMP CREW CHANGE -PERFORM PRE -TOUR CHECKS. -ENVIRONMENTAL WALKAROUND. DECOMP CONTINUE TO NU BOPE. -NU TEST SPOOL. -FINISH TIGHTENING FLANGES. -SERVICE CHOKE AND MUD CROSS VALVES. DECOMP RIG UP TEST EQUIPMENT ON FLOOR -MARK TEST BOTH 2-7/8" AND 4-1/2" TEST JTS. -RIG UP TEST CHART -RIG UP TEST PUMP. REMOVE STEAM HEATER ON RIG FLOOR FOR REPAIRS. DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. -2 7/8" X 5" VARIABLE BORE RAMS. -TEST SPOOL. rrintea: emizuiu W[au:44AM BP EXPLORATION Operations Summary Report Page 2 of 3 Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 2/1/2010 End: 2/9/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/9/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To I Hours I Task I Code I NPT Phase I Description of Operations 2/7/2010 110:30 - 16:30 I 6.001 WHSUR I P I I DECOMP 16:30 - 18:00 1.50 BOPSUF N WAIT DECOMP 18:00 - 19:30 1.50 BOPSU P DECOMP 19:30 - 21:30 2.00 BOPSUF P DECOMP 21:30 - 21:45 0.25 PULL P DECOMP 21:45 - 22:30 0.75 PULL P DECOMP 22:30 - 23:00 0.50 PULL P DECOMP 23:00 - 23:30 1 0.501 PULL I P 23:30 - 00:00 1 0.50 PULL P 2/8/2010 00:00 - 06:00 1 6.00 PULL P 06:00 - 07:00 I 1.001 PULL I P 07:00 - 09:00 2.00 PULL I P 09:00 11:00 2.00 PULL P 11:00 - 12:00 I 1.001 PULL IP 12:00 - 13:00 I 1.001 PULL IP 13:00 - 14:30 I 1.50 -TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" AND 4 1/2" TEST JOINTS. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. 200 PSI BUILD UP FROM 1600 PSI = 46 SECONDS. -FULL BUILD UP TO 3000 PSI = 171 SECONDS. -4 BOTTLES x 1813 PSI. -JOHN CRISP WAIVED AOGCC RIGHT TO WITNESS BOPE TESTING AT 18:30 -HRS. ON 02/06/2010. LOAD PIPE SHED WITH 2-7/8 TUBING WHILE WAITING ON REPAIR PART FOR CHOKE MANIFOLD VALVE. REPLACE SREAM HEATER CORE. TEST REBUILT MANIFOLD VALVE #8. RU DUTCH SYSTEM AND RISER. PU LUBRICATOR AND PRESURE TEST TO 500 PSI. LD TWC. PRESURE TO 1700 PSI TO SHEAR OUT PLUG. BULL HEAD 1.5 LINER VOLUME = 25 BBLS 23 SPM @2300 PSI. IA = 2200 PSI. SHUT DOWN WELL BLEED OF TO 1650 PSI IN 5 MINUTES. BLEED OFF WELL AND ANNULUS. BOLDS PU TO 185K. SLACK OFF TO 100K. PICK BACK 185K. PACKER SHEARED. OBSERVE WELL. WELL STATIC. DECOMP PU TUBING HANGER TO FLOOR WITH 85K UP WT. FLOW CHECK. DECOMP CIRCULATE BOTTOMS UP. DECOMP LD 4-1/2" COMPLETION IN PREPARATION TO RUNNING THE ESP COMPLETION. DECOMP PREFORM PRE -TOUR CHECKS. -CHECK AND SET PVT ALARMS. -ENVIROMENTAL WALK AROUND. -SERVICE DRAW WORKS. -DERRICK INSPECTION. DECOMP CONTINUE TO POH AND LD THE 4-1/2" COMPLETION. DECOMP BREAK OUT PACKER ASSEMBLY. THE CONNECTIONS BELOW THE PACKER WERE BAKER-LOC'D. FLOORHANDS HAD TO USE STEAM AND SHOCK THE CONNECTIONS WITH A HAMMER TO LOOSEN THE CONNECTIONS. DECOMP CLEAN AND CLEAR THE RIG FLOOR. REMOVE ALL OF THE 4-1/2" TBG FROM THE PIPE SHED. DECOMP RIG DOWN ALL OF THE 4-1/2" HANDLING EQUIPMENT. RIG UP TO PICK UP THE PUMP ASSEMBLY. RUNCMP RIG UP SHEAVE AND PULL ESP CABLE TO RIG FLOOR. rnrueu. urucviv ru.vu.yc nm 0 i BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPC -24 Common Well Name: MPC -24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 2/1/2010 End: 2/9/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/9/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To I Hours I Task I Code I NPT Phase I Description of Operations 2/8/2010 13:00 - 14:30 1.50 RUNCOAP RUNCMP INSTALL BLEEDER VALVE ON MUD MANIFOLD AND TEST TO 250 / 3500 PSI. 14:30 - 16:00 1.50 RUNCO RUNCMP PICK UP AND MAKE UP ESP PUMP AND MOTOR ASSEMBLY. 16:00 - 18:00 2.00 RUNCOMN WAIT RUNCMP WAIT FOR CENTRILIFT TO BRING OUT THE CORRECT COUPLER FOR THE PUMP AND MOTOR ASSEMBLY. 18:00 - 21:00 3.00 RUNCOMN RUNCMP MU MOTOR AND PUMP AND SERVICE SAME. 21:00 - 00:00 3.00 RUNCOMN RUNCMP RUN ESP COMPLETION 95 OF 232 JOINT OF 2-7/8" EUE 8RD TUBING. 2/9/2010 00:00 - 05:30 5.50 RUNCOMP RUNCMP CONTINUE TO RUN ESP COMPLETION - 232 JOINTS OF 2-7/8" EUE 8RD TUBING. 05:30 - 06:00 0.50 RUNCOMP RUNCMP PICK UP AND MAKE UP TUBING HANGER AND LANDING JOINT. 06:00 - 06:30 0.50 RUNCOMP RUNCMP CREW CHANGE -PERFORM PRE -TOUR CHECKS. -SERVICE RIG. -ENVIRONMENTAL WALK AROUND. 06:30 - 08:00 1.50 RUNCO P RUNCMP CENTRILIFT - MAKE UP PENETRATOR SLICE. 08:00 - 09:00 1.00 RUNCO P RUNCMP LAND TUBING HANGER AND 2-7/8" ESP COMPLETION. RUN IN LOCK DOWN SCREWS. -232 JOINTS OF 2-7/8" TUBING, MU TORQUE = 2,300 FT -LBS. -PU WT = 65K LBS, SO WT = 51 K LBS. -123 LASALLE CLAMPS, 7 CANNON CLAMPS, 2 FLAT GUARDS, AND 3 PROTECTOLIZERS 09:00 - 10:00 1.00 WHSUR P RUNCMP INSTALL TWC AND TEST. -1000 PSI FROM ABOVE FOR 10 CHARTED MINUTES. -500 PSI ROLLING TEST FROM BELOW FOR 10 CHARTED MINUTES -2 SPM, 2.6 BBLS TOTAL. 10:00 - 12:00 2.00 BOPSUF P RUNCMP NIPPLE DOWN BOP STACK AND ADAPTER. 12:00 - 12:30 0.50 WHSUR P RUNCMP PJSM FOR NU TREE AND ADAPTER. -PAUL HOLLEY AND JOHN HAYNES FROM NABORS SAFETY PRESENT. 12:30 - 14:30 2.00 WHSUR P RUNCMP NIPPLE UP ADAPTER FLANGE AND TREE. CLEAN OUT PITS. 14:30 - 16:00 1.50 WHSUR P RUNCMP PRESSURE TEST HANGER VOID TO 5K PSI FOR 30 MINUTES - GOOD TEST. TEST TREE WITH DIESEL TO 5K PSI - GOOD TEST. CENTRILIFT PERFOMED FINAL CHECKS - GOOD. 16:00 - 17:00 1.00 WHSUR P RUNCMP RIG UP LUBRICATOR AND TEST WITH DIESEL TO 500 PSI - GOOD TEST. PULL TWC AND INSTALL BPV. 17:00 - 17:30 0.50 WHSUR P RUNCMP RIG DOWN LUBRICATOR AND TEST BPV TO 500 PSI FROM BELOW FOR 5 CHARTED MINUTES - GOOD TEST. 17:30 - 18:00 0.50 WHSUR P RUNCMP CLEAN CELLAR AND SECURE TREE. RELEASE RIG AT 18:00. rnmeu. cn —u w 1 ---vi MPC -24A, Well History (Post Rig Sidetrack) Date Summary 1/13/2010 RIH W/ 3.84" NO-GO, S.S, DUAL SPARTEK GAUGES. S/D @ 1682' SLM. UNABLE TO WORK THRU. RIH W/3.20" CENT, S.S, DUAL SPARTEK GAUGES. MADE 30 MINUTE STOP @ 6925' SLM & 3 HOUR STOP @ 7440' SLM. ATTEMPT TO SET 4.5" PX PLUG BODY @ 7463' MD, PLUG NOT SET. RECOVER 1/4 CUP OF METAL CHUNKS/SHAVINGS. RIH W/ 3.5" MAGNET DOWN TO 7520' SLM. SAW NO RESTRICTIONS. RECOVERED 1/4 CUP OF METAL SHAVINGS. 1/14/2010 MADE MULTIPLE RUNS W/ 3.5" MAGNET DOWN TO 7520' SLM. RECOVERED 1/2 CUP OF METAL SHAVINGS. RIH W/ 3.80" GAGE RING JUNK BASKET DOWN TO 7520' SLM. BASKET EMPTY. RIH W/ 4.5" B.L.B, BRUSHED NIPPLE @ 7438' SLM. ATTEMPT TO SET 4.5" PX PLUG @ 7463' MD, UNABLE TO SET, METAL PIECES INSIDE LOCK. BRUSH AND FLUSH TUBING, LRS PUMPED 85 BBLS DIESEUCRUDE MIX, BRUSH X -NIPPLE @ 7463' MD. WELL S/I ON DEPARTURE. 1/17/2010 WELL S/I ON ARRIVAL. SET 3.813" XX PLUG W/ SHEAR SUB (CAL 40", 8 x 1/8" EQZ PORTS, SHEAR SUB HAS 5 -BRASS & 1 -STEEL PIN, SET TO SHEAR @ 2465 PSI). PT TUBING W/ TRIPLEX TO 1000 PSI, LOSE 10 PSI IN 10 MIN. GOOD TEST. WELL S/I ON DEPARTURE. 1/23/2010 WELL SHUT-IN ON ARRIVAL. INITIAL T/IA/OA: ?/0/0 RIG UP E -LINE. 1/24/2010 RIH WITH 30'x1.6875" TOOL STRING (1.56" TUBING PUNCHER LOADED 4' WITH 17 SMALL CHARGES). TIED INTO TUBING TALLY DATED 11/26/2009. SHOT TUBING PUNCHER FROM 73661- 73701. GOOD INDICATION OF COMMUNICATION TO IA. FINAL T/IA/OA: 300/100/0. JOB COMPLETED, WELL LEFT SHUT- IN. 1/25/2010 T/I = 200/0. CMIT TAA to 1000 psi PASSED. Pressured up w/ 3,5bbls diesel. Tubing @ 1000psi, IA @ 760psi. Lost 0 psi in 10min. test. Bled to starting. FWHP's = 200/0. Page 1 of 1 .Naa BAKER RHES INTEQ North America Milne Point M Pt C Pad MPC -24 MPC-24APB1 Survey: MWD C� - ALASKA - BP Survey Report - Geographic 08 January, 2010 0 is Survey Report - Geographic 0 bp Local Co-ordinate Reference: Well MPC -24 TVD Reference: MPC -41: (iia 44.80ft (MPC -41:) was MPC -41: @ 44.80ft (MPC -41:) INTEQ True Company: North America - ALASKA - BP Project: Milne Point Site: M Pt C Pad Well: MPC -24 Wellbore: MPC-24APB1 Design: MPC-24APB1 0 is Survey Report - Geographic 0 bp Local Co-ordinate Reference: Well MPC -24 TVD Reference: MPC -41: (iia 44.80ft (MPC -41:) MD Reference: MPC -41: @ 44.80ft (MPC -41:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt C Pad, TRA 3-10 Site Position: From: Map Position Uncertainty: 0.0 Well MPC -24 Well Position +N/ -S +E/ -W Position Uncertainty Wellbore MPC-24APB1 Magnetics Model Name bggm2007 Design MPC-24APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S (ft) (ft) 28.70 0.00 Tie On Depth: +E/ -W (ft) 0.00 70° 29'7.200 N 149° 31'31.821 W 0.45- 70' .45- 70° 29'27.903 N 149° 31' 32.650 W'. 0.00 ft Field Strength (nT) 57,593 7,957.66 Direction (I 126.55 Northing: 6,027,347.71 ft Latitude: Survey Program Easting: 558,058.04ft Longitude: D ft Slot Radius: 0.000in Grid Convergence: (ft) (ft) Survey (Wellbore) Tool Name API No 500292302000 100.00 1,930.04 0.00 ft Northing: 6,029,452.34 ft Latitude: 0.00 ft Easting: 558,013.45 ft Longitude: 0.00 ft Wellhead Elevation: MWD (MPC-24APB1) ft Ground Level: MWD - Standard API No 500292302070 Sample Date Declination (I Dip Angle (I 2/24/2006 24.09 80.93 Design MPC-24APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S (ft) (ft) 28.70 0.00 Tie On Depth: +E/ -W (ft) 0.00 70° 29'7.200 N 149° 31'31.821 W 0.45- 70' .45- 70° 29'27.903 N 149° 31' 32.650 W'. 0.00 ft Field Strength (nT) 57,593 7,957.66 Direction (I 126.55 1/812010 9:53:48AM Page 2 COMPASS 2003.16 Build 71 Survey Program Date: 1/4/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 1,930.04 MPC -24 GYRO (MPC -24) GYD-CT-DMS Gyrodata cont.drillpipe m/s 1,965.09 7,957.66 MPC -24 IIFR (MPC -24) MWD+IFR+MS MWD + IFR + Multi Station 8,045.00 9,410.00 MWD (MPC-24APB1) MWD MWD - Standard 1/812010 9:53:48AM Page 2 COMPASS 2003.16 Build 71 7,957.66 • 167.53 • -2,369.70 Mae 6,027,101.78 Survey Report - Geographic 70° 29'4.594 N bp 0 1NTEQ Company: North America - ALASKA - BP Local Co-ordinate Reference: Well MPC -24 Project: Milne Point TVD Reference: MPC -41: @ 44.80ft (MPC -41:) 6,897.76 Site: M Pt C Pad MD Reference: MPC -41: @ 44.80ft (MPC -41:) 70° 29'4.200 N Well: MPC -24 North Reference: True Wellbore: MPC-24APB1 Survey Calculation Method: Minimum Curvature Design: MPC-24APB1 Database: EDM .16 - Anc Prod - WH24P 6,922.08 Survey 2,427.29 6,027,049.65 560,459.33 70° 29'4.080 N Measured Vertical Map Map 6,946.24 Depth Inclination Azimuth Depth +N/ -S +E/ -W Northing Easting 560,466.40 70° 29'3.958 N (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,957.66 28.74 167.53 6,820.70 -2,369.70 2,414.48 6,027,101.78 560,446.12 70° 29'4.594 N 149° 30'21.622 W TIP 8,045.00 27.40 167.19 6,897.76 -2,409.80 2,423.47 6,027,061.75 560,455.42 70° 29'4.200 N 149° 30' 21.358 W KOP 8,072.45 27.99 158.00 6,922.08 -2,421.94 2,427.29 6,027,049.65 560,459.33 70° 29'4.080 N 149° 30'21.246 W' 8,100.53 33.45 144.50 6,946.24 -2,434.37 2,434.27 6,027,037.27 560,466.40 70° 29'3.958 N 149° 30'21.040 W'i 8,130.51 39.83 133.00 6,970.31 -2,447.68 2,446.11 6,027,024.06 560,478.35 70° 29'3.827 N 149° 30'20.692 W 8,159.32 46.76 124.72 6,991.28 -2,459.97 2,461.52 6,027,011.88 560,493.85 70° 29'3.706 N 149° 30'20.239 W 8,190.05 55.03 118.60 7,010.66 -2,472.40 2,481.82 6,026,999.61 560,514.24 70° 29'3.584 N 149° 30' 19.642 W 8,221.08 62.80 111.83 7,026.68 -2,483.65 2,505.85 6,026,988.56 560,538.36 70° 29'3.473 N 149° 30' 18.935 W 8,251.50 69.38 104.29 7,039.02 -2,492.21 2,532.26 6,026,980.20 560,564.83 70° 29'3.389 N 149° 30' 18.158 W 8,282.90 77.11 97.61 7,048.08 -2,497.88 2,561.75 6,026,974.76 560,594.36 70° 29'3.333 N 149° 30' 17.291 W 8,300.68 83.23 96.18 7,051.11 -2,499.98 2,579.13 6,026,972.80 560,611.76 70° 29'3.312 N 149° 30' 16.780 W' 8,320.54 89.26 94.61 7,052.41 -2,501.84 2,598.85 6,026,971.09 560,631.49 70° 29'3.294 N 149° 30'16.199 W 8,348.21 92.00 92.67 7,052.11 -2,503.60 2,626.46 6,026,969.55 560,659.11 70° 29'3.277 N 149° 30' 15.387 W I 8,378.43 92.73 89.02 7,050.86 -2,504.04 2,656.64 6,026,969.34 560,689.29 70° 29'3.272 N 149° 30' 14.499 W 8,401.27 94.43 85.76 7,049.43 -2,503.00 2,679.41 6,026,970.56 560,712.05 70° 29'3.282 N 149° 30' 13.830 W 8,435.75 94.09 81.37 7,046.87 -2,499.15 2,713.57 6,026,974.67 560,746.18 70° 29'3.320 N 149° 30' 12.825 W 8,465.16 91.11 80.47 7,045.54 -2,494.52 2,742.58 6,026,979.54 560,775.14 70° 29'3.366 N 149° 30' 11.971 W 8,497.34 89.91 77.16 7,045.25 -2,488.27 2,774.14 6,026,986.02 560,806.65 70° 29'3.427 N 149° 30' 11.043 W 8,530.04 88.56 73.31 7,045.69 -2,479.94 2,805.75 6,026,994.60 560,838.20 70° 29'3.509 N 149° 30'10.113 W 8,560.77 88.22 76.21 7,046.55 -2,471.87 2,835.39 6,027,002.90 560,867.76 70° 29'3.588 N 149° 30' 9.241 W 8,590.97 88.37 81.36 7,047.45 -2,466.00 2,864.99 6,027,009.00 560,897.31 70° 29'3.646 N 149° 30'8.370 W 8,621.77 87.02 86.15 7,048.69 -2,462.65 2,895.57 6,027,012.59 560,927.87 70° 29'3.678 N 149° 30' 7.470 W 8,650.52 89.11 90.23 7,049.66 -2,461.75 2,924.28 6,027,013.72 560,956.57 70° 29'3.687 N 149° 30'6.626W 8,680.86 92.09 93.87 7,049.34 -2,462.83 2,954.59 6,027,012.87 560,986.88 70° 29'3.676 N 149° 30'5.734W 8,704.86 93.35 97.49 7,048.20 -2,465.20 2,978.44 6,027,010.69 561,010.75 70° 29'3.653 N 149° 30'5.032 W 8,734.55 94.14 101.70 7,046.26 -2,470.14 3,007.65 6,027,005.98 561,039.99 70° 29'3.604 N 149° 30'4.173 W 8,764.39 91.81 105.37 7,044.71 -2,477.11 3,036.61 6,026,999.23 561,069.00 70° 29'3.536 N 149° 30' 3.321 W 8,794.53 90.89 109.89 7,044.00 -2,486.24 3,065.32 6,026,990.33 561,097.78 70° 29'3.446 N 149° 30'2.477 W ; 8,824.81 91.41 115.12 7,043.39 -2,497.82 3,093.28 6,026,978.97 561,125.83 70° 29' 3.332 N 149° 30' 1.655 W 1 8,856.20 91.66 119.89 7,042.55 -2,512.31 3,121.10 6,026,964.70 561,153.76 70° 29'3.189 N 149° 30'0.836 W 8,885.66 92.27 123.45 7,041.54 -2,527.76 3,146.16 6,026,949.44 561,178.93 70° 29'3.037 N 149° 30' 0.100 W 8,915.04 92.92 119.53 7,040.21 -2,543.09 3,171.18 6,026,934.31 561,204.07 70° 29'2.886 N 149° 29'59.364 W 8,946.35 91.20 116.03 7,039.09 -2,557.67 3,198.86 6,026,919.95 561,231.86 70° 29'2.743 N 149° 29'58.550 W 8,975.85 91.07 112.69 7,038.50 -2,569.84 3,225.72 6,026,908.00 561,258.81 70° 29'2.623 N 149° 29' 57.759 W 9,006.85 94.05 108.61 7,037.12 -2,580.75 3,254.69 6,026,897.30 561,287.87 70° 29'2.515 N 149° 29' 56.907 W' 9,040.26 98.38 103.79 7,033.50 -2,590.02 3,286.57 6,026,888.29 561,319.81 70° 29'2.424 N 149° 29'55.970 W'I 9,070.41 100.28 99.85 7,028.61 -2,596.12 3,315.68 6,026,882.42 561,348.97 70° 29'2.364 N 149° 29'55.114 W 9,098.91 102.03 96.69 7,023.09 -2,600.14 3,343.35 6,026,878.61 561,376.66 70° 29'2.324 N 149° 29'54.300 W 9,129.04 100.93 97.10 7,017.10 -2,603.68 3,372.66 6,026,875.30 561,406.00 70° 29'2.289 N 149° 29'53.438 W 9,159.48 99.13 95.60 7,011.80 -2,607.00 3,402.45 6,026,872.22 561,435.81 70° 29'2.257 N 149° 29'52.561 W 9,195.42 97.82 100.72 7,006.50 -2,612.05 3,437.62 6,026,867.44 561,471.02 70° 29'2.207 N 149° 29'51.527 W 9,227.41 94.67 106.04 7,003.01 -2,619.40 3,468.54 6,026,860.33 561,501.99 70° 29'2.134 N 149° 29' 50.617 W' 9,264.79 90.64 108.89 7,001.28 -2,630.61 3,504.15 6,026,849.40 561,537.68 70° 29'2.024 N 149° 29'49.570 W 9,298.27 88.19 113.55 7,001.62 -2,642.72 3,535.35 6,026,837.53 561,568.97 70° 29'1.905 N 149° 29'48.652 W 9,327.82 86.16 118.11 7,003.08 -2,655.58 3,561.91 6,026,824.89 561,595.62 70° 29'1.778 N 149° 29'47.871 W 9,410.00 86.16 118.11 7,008.58 -2,694.21 3,634.23 6,026,786.82 561,668.24 70° 29'1.398 N 149° 29'45,744 W TO 1/8/2010 9:53:48AM Page 3 COMPASS 2003.16 Build 71 • .WAFsa BAKER HUGHES INTEQ 0 0 North America - ALASKA - BP Milne Point M Pt C Pad MPC -24 MPC -24A Survey: MWD Survey Report - Geographic 08 January, 2010 °desbp Survey Report - Geographic Company: North America - ALASKA - BP Local Co-ordinate Reference: Well MPC -24 Project: Milne Point TVD Reference: MPC -41: @ 44.80ft (MPC -41:) Site: M Pt C Pad MD Reference: MPC -41: @ 44.80ft (MPC -41:) Well: MPC -24 North Reference: True Wellbore: MPC -24A Survey Calculation Method: Minimum Curvature Design: MPC -24A Database: EDM .16 - Anc Prod - WH24P Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt C Pad, TRA 3-10 i Site Position: From: Map Position Uncertainty: 0.00 ft Well MPC -24 Northing: 6,027,347.71 ft Latitude: Easting: 558,058.04ft Longitude: Slot Radius: 0.000in Grid Convergence: API No 500292302000 Well Position +N/ -S 0.00 ft Northing: 6,029,452.34 ft Latitude: +E/ -W 0.00 ft Easting: 558,013.45 ft Longitude: Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: Wellbore MPC -24A API No 500292302001 Magnetics Model Name Sample Date Declination Dip Angle BGGM2009 1/4/2010 22.03 80.97 Design MPC -24A Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S (ft) (ft) 28.70 0.00 Survey Program Date: 1/8/2010 From To (ft) (ft) Survey (Wellbore) 100.00 1,930.04 MPC -24 GYRO (MPC -24) 1,965.09 7,957.66 MPC 24 IIFR (MPC 24) 8,045.00 8,497.34 MWD (MPC-24APB1) 8,525.00 10,580.00 MWD (MPC -24A) 70° 29' 7.200 N 149° 31' 31.821 W 0.45 ° i 70° 29'27.903 N 149° 31'32.650 W 0.00 ft �I Field Strength (nT) 57,669 Tie On Depth: 8,497.34 +E/ -W Direction (ft) (I 0.00 124.09 Tool Name Description GYD-CT-DMS Gyrodata cont.drillpipe m/s MWD+IFR+MS MWD + IFR + Multi Station MWD MWD - Standard MWD MWD - Standard 1/8/2010 9:00:08AM Page 2 COMPASS 2003.16 Build 71 �/LG °s INTEQ Company: North America - ALASKA - BP Project: Milne Point Site: M Pt C Pad Well: MPC -24 Wellbore: MPC -24A Design: MPC -24A Survey • -r Survey Report - Geographic Measured Vertical Depth Inclination Azimuth Depth +N/ -S (ft) l°) V) (ft) (ft) 8,497.34 89.91 TIP MPC -41: @ 44.80ft (MPC -41:) 8,525.00 89.69 KOP Minimum Curvature 8,525.01 89.69 8,555.46 87.67 8,586.16 89.35 8,615.78 91.81 8,644.99 92.24 8,672.05 92.12 8,700.37 90.28 8,731.08 89.17 8,762.15 88.28 8,792.03 89.91 8,824.47 91.96 8,853.36 94.15 8,883.28 94.14 8,914.25 92.05 8,944.17 91.10 8,976.63 91.87 9,005.79 95.56 9,034.81 98.43 9,064.86 99.95 9,094.18 101.24 9,125.40 98.07 9,154.55 95.94 9,188.14 93.47 9,219.03 91.01 9,251.27 91.78 9,281.17 91.63 9,315.20 90.95 9,341.44 92.27 9,373.54 92.21 9,402.40 93.10 9,430.73 91.90 9,470.95 88.90 9,496.77 85.66 9,527.42 82.95 9,557.72 81.63 9,589.94 80.84 9,620.71 79.41 9,649.45 80.20 9,680.25 81.34 9,709.82 83.20 9,739.38 84.43 9,769.36 85.29 9,797.02 85.33 9,825.01 86.65 9,852.39 87.60 9,880.77 88.37 9,916.06 92.12 9,949.44 90.89 9,981.78 94.09 10,011.75 95.62 10,052.35 94.46 Local Co-ordinate Reference: Well MPC -24 TVD Reference: MPC -41: @ 44.80ft (MPC -41:) MD Reference: MPC -41: @ 44.80ft (MPC -41:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P -2,473.57 2,830.35 Map Map +E1 -W Northing Easting (ft) (ft) (ft) Latitude 77.16 7,045.25 -2,488.27 2,774.14 6,026,986.02 560,806.65 70° 29'3.427 N i { Longitude 149° 30' 11.043 W 75.84 7,045.35 -2,481.82 2,801.04 6,026,992.69 560,833.49 70° 29'3.490 N 149° 30' 10.251 W 75.84 7,045.35 -2,481.82 2,801.05 6,026,992.69 560,833.50 70° 29'3.490 N 149° 30'10.251 W 72.73 7,046.05 -2,473.57 2,830.35 6,027,001.16 560,862.74 70° 29'3.571 N 149° 30'9.389 W 70.40 7,046.85 -2,463.87 2,859.46 6,027,011.09 560,891.77 70° 29'3.667 N 149° 30'8.533 W 73.12 7,046.55 -2,454.60 2,887.58 6,027,020.58 560,919.82 70° 29'3.758 N 149° 30' 7.705 W ! 78.15 7,045.51 -2,447.36 2,915.85 6,027,028.04 560,948.03 70° 29'3.829 N 149° 30'6.874 W 82.74 7,044.48 -2,442.87 2,942.51 6,027,032.73 560,974.65 70° 29'3.873 N 149° 30'6.089 W 85.79 7,043.89 -2,440.04 2,970.68 6,027,035.78 561,002.79 70° 29'3.901 N 149° 30'5.261 W 89.45 7,044.04 -2,438.77 3,001.36 6,027,037.30 561,033.45 70° 29'3.913 N 149° 30' 4.358 W 91.32 7,044.73 -2,438.98 3,032.42 6,027,037.33 561,064.51 70° 29'3.911 N 149° 30:3.444 W 92.82 7,045.20 -2,440.05 3,062.27 6,027,036.48 561,094.37 70° 29'3.900 N 149° 30' 2.566 W 95.39 7,044.67 -2,442.38 3,094.62 6,027,034.42 561,126.73 70° 29'3.877 N 149° 30'1.615 W 99.42 7,043.13 -2,446.09 3,123.22 6,027,030.92 561,155.36 70° 29'3.840 N 149° 30'0.773 W 103.57 7,040.97 -2,452.04 3,152.46 6,027,025.21 561,184.64 70° 29'3.782 N 149° 29' 59.913 W 107.92 7,039.29 -2,460.43 3,182.21 6,027,017.05 561,214.45 70° 29'3.699 N 149° 29' 59.038 W' 112.12 7,038.47 -2,470.67 3,210.31 6,027,007.03 561,242.63 70° 29'3.598 N 149° 29' 58.212 W' 116.78 7,037.63 -2,484.09 3,239.84 6,026,993.84 561,272.26 70° 29'3.466 N 149° 29' 57.343 W 119.99 7,035.74 -2,497.92 3,265.43 6,026,980.21 561,297.95 70° 29'3.330 N 149° 29'56.591 W' 119.46 7,032.21 -2,512.20 3,290.44 6,026,966.13 561,323.07 70° 29'3.190 N 149° 29'55.85,15 W 117.08 7,027.41 -2,526.25 3,316.56 6,026,952.28 561,349.30 70° 29'3.051 N 149° 29' 55.087 W', 114.22 7,022.02 -2,538.73 3,342.54 6,026,940.01 561,375.37 70° 29'2.928 N 149° 29' 54.323 W 112.43 7,016.78 -2,550.91 3,370.80 6,026,928.05 561,403.72 70° 29'2.809 N 149° 29'53.492 W 110.63 7,013.22 -2,561.52 3,397.71 6,026,917.65 561,430.71 70° 29'2.704 N 149° 29'52.700 W 107.43 7,010.47 -2,572.43 3,429.35 6,026,906.99 561,462.44 70° 29'2.597 N 149° 29'51.769 W 105.18 7,009.26 -2,581.10 3,458.97 6,026,898.55 561,492.12 70° 29'2.511 N 149° 29' 50.898 W 101.56 7,008.48 -2,588.55 3,490.32 6,026,891.35 561,523.53 70° 29'2.438 N 149° 29'49.976 W 100.37 7,007.59 -2,594.24 3,519.66 6,026,885.89 561,552.91 70° 29'2.382 N 149° 29'49.113 W 106.52 7,006.82 -2,602.14 3,552.74 6,026,878.24 561,586.04 70° 29'2.304 N 149° 29'48.140 W' 110.05 7,006.08 -2,610.37 3,577.64 6,026,870.21 561,611.00 70° 29'2.223 N 149° 29'47.408 W 114.79 7,004.83 -2,622.60 3,607.28 6,026,858.21 561,640.73 70° 29'2.102 N 149° 29'46.536 W 119.87 7,003.49 -2,635.83 3,632.88 6,026,845.19 561,666.44 70° 29'1.972 N 149° 29'45.783 W 123.47 7,002.25 -2,650.69 3,656.97 6,026,830.52 561,690.63 70° 29'1.826 N 149° 29'45.075 W j 125.62 7,001.97 -2,673.49 3,690.09 6,026,807.98 561,723.93 70° 29'11.6011 N 9'44.101W 149° 29'44.10'1W 124.43 7,003.20 -2,688.29 3,711.21 6,026,793.34 561,745.16 70° 29'1.456 N 149° 29'43.48() W 122.89 7,006.24 -2,705.19 3,736.59 6,026,776.64 561,770.67 70° 29'1.289 N 149° 29'42.734 W 119.67 7,010.30 -2,720.78 3,762.24 6,026,761.25 561,796.44 70° 29' 1.136 N 149° 29' 41.979 W 116.60 7,015.22 -2,735.80 3,790.32 6,026,746.46 561,824.63 70° 29'0.988 N 149° 29'41.153 W' 114.05 7,020.49 -2,748.76 3,817.72 6,026,733.71 561,852.13 70° 29'0.861 N 149° 29'40.348 W 110.92 7,025.58 -2,759.58 3,843.85 6,026,723.10 561,878.34 70° 29'0.754 N 149° 29'39.579 W 107.61 7,030.52 -2,769.61 3,872.54 6,026,713.30 561,907.11 70° 29'0.655 N 149° 29'38.735 W 104.41 7,034.50 -2,777.69 3,900.71 6,026,705.44 561,935.33 70° 29'0.576 N 149° 29'37.907 W 100.99 7,037.69 -2,784.14 3,929.37 6,026,699.20 561,964.04 70° 29'0.512 N 149° 29'37.064 W': 98.16 7,040.37 -2,789.11 3,958.81 6,026,694.47 561,993.52 70° 29'0.463 N 149° 29'36.198 W 95.82 7,042.64 -2,792.46 3,986.17 6,026,691.33 562,020.90 70° 29'0.430 N 149° 29'35. W 93.28 7,044.59 -2,794.68 4,014.00 6,026,689.33 562,048.75 70° 29'0.408 N 149° 29'34. W 93.34 7,045.97 -2,796.26 4,041.30 6,026,687.96 562,076.05 70° 29'0.392 N 149° 29'33.771 W 95.50 7,046.96 -2,798.44 4,069.58 6,026,686.00 562,104.34 70° 29'0.371 N 149° 29'32.940 W 98.20 7,046.81 -2,802.65 4,104.60 6,026,682.07 562,139.40 70° 29'0.329 N 149° 29'31.909 W 100.20 7,045.94 -2,807.99 4,137.54 6,026,676.99 562,172.37 70° 29'0.276 N 149° 29' 30.941 W 101.44 7,044.53 -2,814.05 4,169.27 6,026,671.17 562,204.15 70° 29'0.217 N 149° 29'30.007 W'. 103.55 7,041.99 -2,820.51 4,198.42 6,026,664.94 562,233.35 70° 29' 0.153 N 149° 29'29.150 W 107.76 7,038.43 -2,831.42 4,237.36 6,026,654.34 562,272.36 70° 29'0.045 N 149° 29' 28.005 W 1//2010 9:00:08AM Page 3 COMPASS 2003.16 Build 71 a 9 u�ac.-, Company: North America - ALASKA - BP Project: Milne Point Site: M Pt C Pad Well: MPC -24 Wellbore: MPC -24A Design: MPC -24A Survey Survey Report - Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: is Well MPC -24 MPC -41: @ 44.80ft (MPC -41:) MPC -41: @ 44.80ft (MPC -41:) True Minimum Curvature EDM .16 - Anc Prod - WH24P Measured Vertical Casing Vertical Depth (ft) Map Map Depth Inclination Azimuth Depth +N/ -S +E/ -W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) 10,084.97 92.45 111.27 7,036.46 -2,842.30 4,268.04 6,026,643.70 562,303.13 10,114.64 93.84 113.95 7,034.83 -2,853.69 4,295.39 6,026,632.53 562,330.56 10,147.78 95.13 117.65 7,032.24 -2,868.06 4,325.13 6,026,618.39 562,360.40 10,180.54 96.33 121.62 7,028.97 -2,884.17 4,353.45 6,026,602.49 562,388.85 10,209.73 97.57 125.76 7,025.43 -2,900.24 4,377.56 6,026,586.62 562,413.08 10,239.71 98.66 129.59 7,021.20 -2,918.38 4,401.04 6,026,568.67 562,436.71 10,270.59 99.58 134.40 7,016.30 -2,938.77 4,423.70 6,026,548.46 562,459.52 10,299.75 98.56 138.80 7,011.70 -2,959.69 4,443.48 6,026,527.69 562,479.45 10,327.76 96.55 142.85 7,008.02 -2,981.21 4,461.01 6,026,506.31 562,497.15 10,355.04 95.34 141.77 7,005.19 -3,002.68 4,477.60 6,026,484.97 562,513.91 10,392.34 95.26 137.25 7,001.75 -3,030.92 4,501.71 6,026,456.93 562,538.23 10,425.23 94.42 134.45 6,998.97 -3,054.43 4,524.53 6,026,433.60 562,561.24 10,460.39 92.36 129.87 6,996.89 -3,077.98 4,550.54 6,026,410.25 562,587.43 10,490.05 92.62 127.32 6,995.60 -3,096.46 4,573.70 6,026,391.95 562,610.73 10,522.36 93.71 123.87 6,993.82 -3,115.24 4,599.93 6,026,373.39 562,637.10 10,535.00 93.78 121.95 6,992.99 -3,122.09 4,610.52 6,026,366.62 562,647.74 10,580.00 93.78 121.95 6,990.03 -3,145.85 4,648.62 6,026,343.16 562,686.02 TO - 2 7/8" Casing Points Measured Depth (ft) 10,580.00 Survey Annotations Latitude 70° 28'59.938 N 70° 28'59.826 N 70° 28'59.685 N 70° 28'59.526 N 70° 28'59.368 N 70° 28'59.189 N 70° 28'58.989 N 70° 28'58.783 N 70° 28'58.571 N 70" 28'58.360 N 70° 28'58.082 N 70° 28'57.850 N 70° 28'57.619 N 70° 28'57.437 N 70° 28'57.252 N 70° 28'57.185 N 70° 28' 56.951 N Longitude 149° 29'27.102 W 149° 29'26.298 W j 149° 29'25.424 W 149° 29'24.591 W 149° 29'23.882 W' 149° 29'23.191 W 149° 29'22.525 W 149° 29'21.944 W 149° 29'21.429 W 149° 29'20.941 W 149° 29' 20.232 W 149° 29' 19.561 W 149° 29' 18.797 W 149°29'18.116 W, 149° 29' 17.345 W 149° 29' 17.033 W'. 149'29'15.913W Vertical Vertical Casing Hole Depth (ft) Diameter Diameter (ft) Name (in) (in) 4,548.70 95/8" 9.620 12.250 6,618.70 7" 7.000 8.500 6,990.03 27/8" 2.875 4.125 4,548.70 95/8" 9.620 12.250 6,618.70 7" 7.000 8.500 Measured Vertical Depth Depth (ft) (ft) 8,497.34 7,045.25 8,525.00 7,045.35 10,580.00 6,990.03 Local Coordinates +N/ -S +E/ -W (ft) (ft) Comment -2,488.27 2,774.14 TIP -2,481.82 2,801.04 KOP -3,145.85 4,648.62 TD Checked By: Approved By: Date: 1/8/2010 9:00:08AM Page 4 COMPASS 2003.16 Build 71 4 Tree: 2 9/16", 5M w Wellhead: FMC 11" x 11", 5M, Gen. 5 and 11" x 2 7/8" NSCT Tog. Hgr. w/ 2.5" CIW 'H' BPV profile 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965' Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. = +30 deg. 9-5/8", 40#/ft., L-80 BTC f 5,056' 2 7/8" 6.5 ppf, L-80 8rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC -MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) Size SPFJ Interval TVD 2318 219 6 7987-7995 A3 6846'' 5853 7003' 7012' 2318 5 7993'-7021 2718 n2 6 81918201 CTD Sidetrack - Nordic 2 239 6 84gi 8216 ESP Completion - Nabors 4ES Size SPF Interval TVD 2" 2" 6 6 9640'- 10270' 10350'- 10540' 6971'- 7002' 6948'- 6960' TOL 6D 7,598' ELMD Window P, 8,040'- 8051' ELMD Single Solid, cemented and perfd TD = 10,580 ELMD A3 A2 K MPC -24A DATE REV. BY COMMENTS 7/13/01 10/5/01 GMH GMH Drill & Run Frac String. N -22E Nabors 4ES ESP Completion 06/18/06 02/27/08 MOR REH Nabors 43S ESP Completion Nabors 3S ESP change out 1/12/10 REH CTD Sidetrack - Nordic 2 2/9/10 LH ESP Completion - Nabors 4ES Orig'qM Elev. = 41.5'(N -22E) Orig. GL Elev. = 17.0' RT to Tbg. Spool = 27.5' (N -22E) Camco 2-7/8" x 1" sidepocket KBMM GLM Camco 2-7/8" x V sidepocket KBMM GLM 2-7/8" XN nipple (ID 2.250") Tandem Pumps, 137-P17 SXD 63-G12 MVP -SSD Gas Separator GRSFTX AR H6 Tandem Seal Section Model GSB3DB LT/UT SB/SB PFSA Motor, 152 HP, 2325 volt, 40 amp, Model KMH PumpMate XTO w/ 5 Fin Centralizer 7" Baker "ZXP" Packer 7" Float Collar 7" Float Shoe 4.5" Baker Flexlock Liner Hanger 4.5" Baker Landing Collar 4.5" HES Float Collar 4.5" HES Float Shoe (PBTD) 139` 7233' 7375' 7419' 7448' 7453` 7467' 7481' 7494' 7594' 7679' 7506' 8317' 8361 ` 8404' —8-4 0-67' =1191 =11 ffi wety-Z' IF—Awl • 1111 1 :1 • 1 1 1 w Il1 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPC24-A BP Exploration (Alaska) Inc. Permit No: 209-134 Surface Location: 1171' FSL, 2446' FEL, SEC. 10, T13N, R10E,UM Bottomhole Location: 1907' FNL, 2205' FWL, SEC. 14, T13N, R10E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). S' cerely, aniel= . Seamount, Jr. Chair DATED this � Zday of November, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. r, lN t k i fi 4 p o r relnl '' F SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 �1t� CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPC24-A BP Exploration (Alaska) Inc. Permit No: 209-134 Surface Location: 1171' FSL, 2446' FEL, SEC. 10, T13N, R10E,UM Bottomhole Location: 1907' FNL, 2205' FWL, SEC. 14, T13N, R10E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). S' cerely, aniel= . Seamount, Jr. Chair DATED this � Zday of November, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASSIL AND GAS CONSERVATION COMMIIGON PERMIT TO DRILL 20 AAC 25.005 RECEIVED ) v 0 6 2 Na009 1 a. Type of work: ❑ Drill ® Redrill ❑ Re -Entry 1b. Proposed Well Class: ® Development Oil ❑ Service - Wini ❑ Single Zone ❑ Stratigraphic Test ❑ Development Gas ❑ Service -Supply ❑ Multiple Zone ❑ Exploratory ❑ Service - WAG ❑ Service - Disp 1 c. Specify if well isproed for; Uk0E 6 ' '0 bax�& Anchuftle Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ® Blanket ❑ Single Well Bond No. 6194193 11. Well Name and Number: MPC -24A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10520' TVD 6935'ss 12. Field / Pool(s): Milne Point Unit / Kujruk River S s Ur jg,� �J c 4a. Location of Well (Governmental Section): Surface: 1171' FSL, 2446' FEL, SEC. 10, T13N, R10E, UM' Top of Productive Horizon: 1208' FNL, 34' FEL, SEC. 15, T13N, R10E, UM Total Depth: 1907' FNL, 2205' FWL, SEC. 14, T13N, R10E, UM 7. Property Designation (Lease Number): ADL 047434, 025516 & 047437 'g 8. Land Use Permit: 13. Approximate Spud Date: November 20, 2009 - 9. Acres in Property: 2560 14. Distance to Nearest Property: 9,000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 558013 - 6029452 ' Zone- ASP4 10. KB Elevation above MSL: 44.80'- feet GL Elevation above MSL: 16.2' feet 15. Distance to Nearest Well Open to Same Pool: 1,216' 16. Deviated Wells: Kickoff Depth: 8060 • feet Maximum Hole Angle: 102 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2540 • Surface: 1840 18. CasingPro ram: Specifications I To - Setting Depth - Bottom Quantity of Cement c.f. or sacks Hole Casino Wei ht Grade Cou lin Length MD TVD MD TVD(including stage data 4-1/8" 3-3/16° x 2-3/8" 6.2# / 4.7# L-80 TCII / STL 9820' 7700' 6553'ss 10520' 35'ss 145 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): 8406' 722 Plugs (measured): 1 None Effective Depth MD (ft): 8298' Effective Depth TVD (ft): 7127' Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor / Structural i A 113' 11 ' Surface 5027' 9-5/8" 714 sx PF ' 360 sx CI 'G' 57' 4609' Intermediate Production 7651' 7" 170 sx l 7679' Liner 912' 4-1/2" 115 sx Class 'G' 1 7494'- 8406' 1 6424'- 7228' Perforation Depth MD (ft): 7987'-8216' Perforation Depth TVD (ft): 6846'- 7052' 20. Attachments: ❑ Property Plat ® BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name John Mc I Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-4711 Date C l �� Q Terrie Hubble, 564 4628 Commission Use Only Permit To Driff Dr' Number:'/ API Number: 50-029-23020-01-00 PermitAg val t See cover letter for other requirements e, gas hydrates, or gas contained shales: �- Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed m7No O (� Ca 1 e,5' _ Samples Req'd: ❑ es Mud Lo Re d: ❑ es Ll!No Other. ,� 3Sa `a Sc, � l Y9 q' �Y S D d psi; Ah titi H2S Measures: Yes ❑ No Directional Survey Req'd: Yes ❑ No /� APPROVED BY THE COMMISSION / Date COMMISSIONER 11112-1-1 Form 10-4011 Revised 00/2009' This permit is valid fSr 24�itonths fr6m the date of approval (20 AAC 25.005(8)) U R luiiNAL Submit In Duplicate To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: November 04, 2009 Re: Milne Point C -24A PTD request Approval is requested for a permit to drill a CTD sidetrack from well Milne Point C -24A. MPC -24 was drilled 7/13/01 and completed as a A2/A3/C sand KUP producer. 'The A sands were fraced in August -2001 with 180,000 # of 16/20 carbolite. 2 ESP's were RIH before the 3rd one finally ran for a substantial amount of time (Oct -01). The well has had 2 additional ESP's since the Oct -01 pump including the current pump installed on 3- 15-08. The well is currently online making low oil rate and high water cut. MPC -24A will be drilled to a more optimum location. The sidetrack, MPC -24A, is scheduled to be drilled by Nordic 2 starting January 10, 2010 using the managed pressure drilling technique. This horizontal lateral will target Kuparuk A2 and A3 reserves to capture currently nonrecoverable resources. The perforations in the parent well will be abandoned with cement downsqueezed past the whipstock. The sidetrack lateral will exit the parent well at 8,040' and in the B shale and drill a -2480' lateral to a TD of 10,520' md.*The sidetrack will be completed with a solid, cemented and perforated 3-3/16" x 2- 7/8" liner. The following describes work planned. Managed Pressure Drilling Technique The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is . drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using 8.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits and will be independent of the BOPE choke. This well does not have a functioning tubing sub -surface safety valve that could be utilized to facilitate BHA deployments and liner running. It is possible that deployment of the BHA under trapped wellhead pressure may be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (3" slip rams, see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected for MPC -24A: • Latest Reservoir pressure in the parent well: 2,540 psi at 7000' TVDSS, 7.0 ppg EMW. • Expected pressure as the lateral is drilled is the same as the parent (2,540 psi). • Expected annular friction losses while circulating: 462 psi at KOP and 685 psi at TD (assuming 90 psi/1000 ft, for a 2480' lateral). • Planned mud density: 8.8 ppg equates to 3,154 psi hydrostatic pressure at the window. • While circulating 8.8 ppg fluid, at the start of the lateral, the bottom hole circulating pressure is estimated to be 3,616 psi or 10.0 ppg ECD. For shale stability an 10.0 EMW will be held while drilling, no back pressure will . be applied at surface. When circulation is stopped, a -462 psi surface pressure will be applied to maintain a constant BHP of 10 ppg EMD. At the start of the lateral, the mulohe rig pits will be 8.8 ppg mud. KWF willsitored on location in upright tanks. The tankage will contain 2 wellbore volumes of KWF (11 ppg expected) to exceed the maximum possible BHP to be encountered as the lateral is drilled. This KWF will also be used for liner running operation. CTD Sidetrack Summary Prior to drilling operations a workover rig will lay down the ESP completion, pull the 4-1/2" x 7' packer, and run a 4-1/2" workstring. After the coil drilling unit is rigged down the workover rig will return to pull the kill string and rerun the ESP completion. Nabors 4ES RWO operations: The RWO is slated to begin about November 20, 2009. 1. MIRU. Test BOPE to 3500 psi. 2. Kill Well 3. Pull 2-7/8" ESP completion 4. Mill / Fish 4-1/2" x 7" packer 5. Perform a scraper run in the 7" csg to the top of the 4-1/2" liner 6. RIH with 7" test packer. Test 7" csg integrity to 2000 psi. 7. Run 4-1/2" workstring with a 7" retrievable pkr and PBR. 8. RDMO to allow Nordic II to sidetrack well Pre -CT Rig Work: The pre CTD work is slated to begin immediately following the RWO. 1. Pull ball and rod 2. Pull RHC sleeve 3. Run dummy WS drift to 8,100' 4. Set Baker whipstock at 8,040' 5. Downsqueeze cement past whipstock, 16 bbls of 15.8 ppg cement 6. Extend pad with an ice apron 7. Bleed, remove, and blind flowlines 8. Drill mousehole extension Rig Sidetrack Operations: (Scheduled to begin on January 10, 2010 using Nordic rig 2) 1. MIRU Nordic Rig 2 " CT DrillinaBOPE and test. 3. Mill 3.8" window in 4-1/2" liner from mechanical whipstock set at 8,040'. 4. Drill build section with 4-1/8" bicenter bit, and land well in target A sand. - 5. Drill lateral section to 10,520'. • 6. Flow check well and lay in KWF as needed. , 7. Run and cement a 3-3/16" x 2-3/8" L-80 liner string. Expect -30 bbl of 15.8 ppg cement 4k' 8. Cleanout and log liner with a memory SWS GR -CCL logging tool. 9. Perforate well. 10. Circulate well to KWF brine. FP well to 2000'. 11. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 2. Nabors 4ES RWO operations: The RWO is slated to begin after the sidetrack. 1. MIRU after Nordic II finishes 2. Test BOPE to 3500 psi. 3. Release packer and pull 4-1/2" workstring 4. Run new ESP on 2-7/8" tubing 5. RDMO Post -Rig Work: 1. Re -install wellhouse and FL's. 2. Pull BPV. Mud Program: • Well kill: 8.4 ppg brine to start. Adjust with real time BHP monitoring. • Milling/drilling: 8.4 ppg Geo -VIS or biozan for milling, new 8.8 ppg Geo -VIS for drilling. . • KWF will be needed for running and cementing liner. BHP will be measured prior to tripping to run liner and KWF adjusted as needed. • Standby KWF. At the start of the well there will be 2 wellbore volumes of 11.0 ppg KWF on location in upright tanks. Disposal: • All Class II drilling and completion fluids will go to Grind & Inject at DS 4, or to the KRU 1 R pad disposal well. • All Class II drilling solids will go to Grind & Inject at DS 4. • All Class I wastes will go to Pad 3 for disposal. Hole sizes: 4-1/8 bi-center hole: 8,040' to 10,520' Casing Program: solid and cemented production liner • 3-3/16", L-80 6.2# TCII 7,700' and - 9,000' and • 2-3/8",L-80 4.70# STL 9,000' and -10,520' and • A minimum of 30 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 4.125" bit size and TD @ 10,520', with 40% excess in the open hole interval) • TOC planned at 7,700' (at the top of the liner) • A liner top packer will be run if the liner lap fails to test. Well Control: • Two wellbore volumes of KWF (-280 bbls) will be on location at all times during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 102 deg at 9,080'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 9000 ft. (To planned perforations in new lateral) • Distance to nearest well within pool -1216' from MPC -14 perforations to planned perforations in new lateral. Anti -Collision • There are no collision issues Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole section. • • Cased hole GR/CCL, logs will be run. Hazards • The maximum recorded H2S level on MPC -24 is 21.2 ppm. • The maximum recorded H2S level on MP C pad was 21.2 ppm on well MPC -24. (July 09). • Lost circulation risk is low. Reservoir Pressure • The reservoir pressure on MPC -24 is expected to be 2,540 psi at 7,000' TVDSS. (7.0 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to psi/ft) is 1,840 psi. - Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble Tree: 2 9/16", 5M MPC -24 QMKB Elev. = 41.5' (N22E) Wellhead: FMC 11" x 11 ", An. 5 CqWSL Elev. = 17.0' and 11" x 2 7/8" NSCT Tbg. Hnr. w/I I I I I I RT o Tbg. Spool = 27.5' (N22E) 2.5" CIW 'H' BPV profile 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965' Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. = +30 deg. 9-5/8", 40#/ft., L-80 BTRC 57056` 2 7/8" 6.5 ppf, L-80 8 rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC -MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) Jet Cut 4.5" tubing w/ 7396' bazooka top 7/13/01 4.5" Baker Model "S-3" Pkr. 7,402' 4.5" HES "XN" nipple ID 7,415' (No -Go = 3.725") WLEG 7,426' 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594' 7" Float Shoe 7679' 4.5" Baker Flexlock Liner 7506` Hanger (tag fill @ 8201 Nabors 3S 2/27/08) 4.5" Baker Landing Collar 8317` 4.5" HES Float Collar 8361' 4.5" HES Float Shoe 8404' (PBTD) 8406` DATE REV. BY COMMENTS 7/13/01 GMH Drill & Run Frac String. N -22E 10/5/01 GMH Nabors 4ES ESP Completion 06/18/06 MOR Nabors 43S ESP Completion 02/27/08 REH Nabors 3S ESP change out Cameo 2-7/8" x 1" 142` sidepocket KBMM GLM Cameo 2-7/8" x 1" 2029 sidepocket KBMM GLM Cameo 2-7/8" x 1" 6852' sidepocket KBMM GLM 2-7/8" XN nipple 6999' (ID 2.205") Tandem Pump, 18P75 SXD 160P11 SSD 7042` Tandem Gas Separator 7070' GRSFTX AR H6 Tandem Seal Section Model GSB3DB LT/UT SB/SB PFSA/FSACL5 7075` Motor, 152 HP, 2325 volt, 7088` 40 amp, Model KMH Pumpmate 7102' w/ 5 Fin Centralizer 1/ ► 1�Il�r��(I MAI :110 i►• e • • *-. d Lei ON wym II MPC -24A Propos CTD sidetrack - Single Cem ed Liner -r—I [ Orig. GLEIev. = 17.0' Tree: 2 9/16", 5M Wellhead: FMC 11" x 11 ", 5M, Gen. 5 Frl RT to Tbg. Spool = 27.5' (N22E) and 11" x 2 7/8" NSCT Tbg. Hnr. w/ 2.5" CIW 'H' BPV profile 113' 9-5/8" TAM Port Collar 1004' KO P @ 400' to 1965' Max. Hole Angle = 56.32 deg. Max. Plerft AnglWTftg. 9-5/8", 40#/ft., L-80 BTRC 5,056' 11 4.5" L-80 workstring 7" 26#/ft., L-80 BTC -MOD Production Casing, (Drift ID = 6.151 ", cap. = 0.0383 t Stimulation Summary 179,534 # 16/20 carbolite behind pip 8/4/01 -dR . I I[Ti16 uu.r TOL @ 7,700' Single Solid, cemented and perf'd 3-3/16 x 2-7/8" Liner Window @ M=10,520' A3 A2 DATE REV. BY COMMENTS 7/13/01 GMH Drill & Run Frac String. N -22E 06/18/06 MOR Nabors 43S ESP Completion 02/27/08 REH Nabors 3S ESP change out 6/25/09 1 MSE PROPOSED CTD SIDETRACK :e SPF Interval (TVD) 8" 6 7987-7995 6846'-6853' anger (tag fill @ 8201 Nabors 3S 2/27/08) 5" Baker Landing Collar 8317' .5" HES Float Collar '8" 6 8162-8172 7003'-7012' 18" 6 8162-8172 7003'-7012' A2 '8" 6 8191-8201 7029'-7038' 8" 6 8191-8216 7029'-7052' ' x 4-1/2" retrievable packer @ 7400' Baker "ZXP" Packer 7494' Float Collar 7594' Float Shoe 7679' 5" Baker Flexlock Liner 7506' anger (tag fill @ 8201 Nabors 3S 2/27/08) 5" Baker Landing Collar 8317' .5" HES Float Collar 8361' .5" HES Float Shoe 8404' 'BTD) 8406` BP EXPLORATION (AK) ■ Baker Hughes INTEQ SM�R KV"K$ Baker Hughes INTEQ Planning Report -0bp INTEQ Company: North America - ALASKA - BP Local Coordinate Reference: Well MPC -24 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt C Pad MD Reference: MPC -41: @ 44.80ft (MPC -41:) Well: MPC -24 North Reference: True . Wellbore: Plan 9, MPC -24A Survey Calculation Method: Minimum Curvature Design: Plan 9, MPC -24A Database: EDM 2003.16 Single User Db Survey Tool Program Date 10/28/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 1,929.94 MPC -24 GYRO (MPC -24) GYD-CT-DMS Gyrodata cont.drillpipe m/s 1,965.09 7,957.66 MPC -24 IIFR (MPC -24) MWD+IFR+MS MWD + IFR + Multi Station 7,957.66 10,520.00 Plan 9, MPC -24A (Plan 9, MPC -24A) MWD MWD - Standard Planned Survey MD Inc Azi TVDSS NIS EIW Northing Easting DLeg V. Sec TFace (ft) 0 (0) (ft) (ft) (ft) (ft) (ft) (0/10011t) (ft) (0) 7,957.66 28.74 167.53 6,775.90 -2,369.70 2,414.48 6,027,101.78 560,446.12 0.00 3,189.74 0.00 TIP 8,000.00 28.09 167.37 6,813.14 -2,389.37 2,418.86 6,027,082.15 560,450.65 1.54 3,202.02 -173.32 8,040.00 27.48 167.21 6,848.53 -2,407.56 2,422.96 6,027,063.99 560,454.89 1.54 3,213.43 -173.18 KOP 8,060.00 27.53 163.31 6,866.27 -2,416.49 2,425.31 6,027,055.08 560,457.31 9.00 3,219.33 -90.00 End of 9 Deg/100' DLS 8,100.00 30.64 134.97 6,901.38 -2,432.63 2,435.23 6,027,039.02 560,467.35 35.00 3,235.14 -90.00 4 8,200.00 58.34 102.90 6,972.88 -2,461.03 2,496.66 6,027,011.10 560,529.00 35.00 3,302.82 -52.00 8,299.90 90.00 87.22 6,999.94 -2,468.32 2,590.94 6,027,004.54 560,623.32 35.00 3,391.35 -28.15 10 End of 35 Deg/100' DLS 8,300.00 90.00 87.22 6,999.94 -2,468.32 2,591.04 6,027,004.55 560,623.42 0.00 3,391.44 0.00 8,349.90 90.00 81.22 6,999.94 -2,463.28 2,640.66 6,027,009.97 560,673.00 12.02 3,434.28 -90.00 6 8,400.00 90.00 87.23 6,999.94 -2,458.24 2,690.49 6,027,015.40 560,722.78 12.00 3,477.31 90.00 8,499.90 90.00 99.22 6,999.94 -2,463.84 2,790.05 6,027,010.57 560,822.37 12.00 3,569.91 90.00 7 8,500.00 90.00 99.22 6,999.94 -2,463.86 2,790.15 6,027,010.56 560,822.47 0.00 3,570.00 0.00 8,600.00 90.00 87.20 6,999.94 -2,469.44 2,889.81 6,027,005.76 560,922.16 12.01 3,662.69 -90.00 8,659.90 90.00 80.02 6,999.94 -2,462.77 2,949.30 6,027,012.89 560,981.59 12.00 3,713.78 -90.00 8 10128/2009 11:35:36AM Page 3 COMPASS 2003.16 Build 71 MFRS Baker Hughes INTEQ MIIaiNRf Baker Hughes INTEQ Planning Report bp 0 INTEQ Company: North America - ALASKA - BP Local Coordinate Reference: Well MPC -24 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt C Pad MD Reference: MPC -41: @ 44.80ft (MPC -41:) Well: MPC -24 North Reference: True Wellbore: Plan 9, MPC -24A Survey Calculation Method: Minimum Curvature Design: Plan 9, MPC -24A Database: EDM 2003.16 Single User Db Planned Survey MD Inc Azi TVDSS NIS EIW Northing Easting DLeg V. Sec TFace (ft) (°} (°) (ft) (ft) (ft) (ft) (ft) (°1100ft) (R) (°) 8,700.00 90.00 84.83 6,999.94 -2,457.49 2,989.04 6,027,018.48 561,021.28 12.00 3,747.56 90.00 8,800.00 90.00 96.83 6,999.94 -2,458.93 3,088.84 6,027,017.82 561,121.08 12.00 3,838.63 90.00 8,869.90 90.00 105.22 6,999.94 -2,472.28 3,157.39 6,027,005.01 561,189.73 12.00 3,906.40 90.00 9 8,900.00 91.75 108.38 6,999.48 -2,480.97 3,186.20 6,026,996.54 561,218.60 12.00 3,936.18 61.00 9,000.00 97.50 118.95 6,991.40 -2,520.87 3,277.34 6,026,957.36 561,310.04 12.00 4,035.64 61.05 9,079.90 101.91 127.59 6,977.91 -2,563.98 3,343.13 6,026,914.76 561,376.16 12.00 4,113.49 61.90 10 9,100.00 100.52 125.58 6,974.00 -2,575.73 3,358.96 6,026,903.14 561,392.08 12.00 4,132.80 -125.00 9,200.00 93.45 115.80 6,961.81 -2,626.24 3,444.19 6,026,853.30 561,477.69 12.00 4,231.39 -125.39 9,259.90 89.16 110.03 6,960.45 -2,649.54 3,499.31 6,026,830.44 561,532.99 12.00 4,291.20 -126.59 11 9,300.00 88.74 114.83 6,961.18 -2,664.83 3,536.36 6,026,815.43 561,570.15 12.00 4,331.24 95.00 9,339.90 88.34 119.60 6,962.20 -2,683.07 3,571.82 6,026,797.48 561,605.75 12.00 4,371.08 94.91 12 9,400.00 86.98 112.51 6,964.66 -2,709.43 3,625.73 6,026,771.54 561,659.86 12.00 4,431.09 -101.00 9,500.00 84.83 100.67 6,971.83 -2,737.87 3,721.14 6,026,743.84 561,755.48 12.00 4,529.58 -100.71 9,600.00 82.90 88.76 6,982.55 -2,746.05 3,820.05 6,026,736.44 561,854.44 12.00 4,622.67 -99.86 9,609.90 82.72 87.58 6,983.79 -2,745.74 3,829.86 6,026,736.83 561,864.25 12.00 4,631.43 -98.58 13 9,700.00 84.75 98.26 6,993.65 -2,750.31 3,919.17 6,026,732.95 561,953.58 12.00 4,714.31 79.80 9,800.00 87.21 110.04 7,000.68 -2,774.67 4,015.71 6,026,709.35 562,050.30 12.00 4,812.10 78.63 9,859.90 88.75 117.06 7,002.80 -2,798.57 4,070.55 6,026,685.88 562,105.32 12.00 4,871.90 77.80 14 9,900.00 89.17 112.27 7,003.53 -2,815.30 4,106.98 6,026,669.44 562,141.87 12.00 41911.98 -85.00 9,979.90 90.03 102.72 7,004.09 -2,839.29 4,183.09 6,026,646.05 562,218.16 12.00 4,991.10 -84.91 15 10,000.00 90.69 105.04 7,003.97 -2,844.11 4,202.60 6,026,641.38 562,237.71 12.00 5,010.83 74.10 10/28/2009 11:35:36AM Page 4 COMPASS 2003.16 Build 71 was NIS wn (ft) INTEQ -2,879.55 Company: North America - ALASKA - BP Project: Milne Point Site: M Pt C Pad Well: MPC-24 Wellbore: Plan 9, MPC-24A Design: Plan 9, MPC-24A Planned Survey MD (ft) 10,100.00 10,200.00 10,220.00 16 10,300.00 10,400.00 10,420.00 17 10,500.00 10,520.00 TD at 10520.00 Inc 93.94 97.02 97.61 99.17 100.75 101.01 101.69 101.81 Azi 116.60 128.25 130.60 121.02 108.94 106.52 116.28 118.73 Baker Hughes INTEQ Baker Hughes INTEQ Planning Report 0 bp TVDSS NIS (ft) (ft) 6,999.92 -2,879.55 6,990.34 -2,932.81 6,987.79 -2,945.40 6,976.09 -2,991.66 6,958.74 -3,033.20 6,954.96 -3,039.19 6,939.18 -3,067.76 6,935.11 -3,076.80 Local Co-ordinate Reference: Well MPC -24 TVD Reference: Mean Sea Level MD Reference: MPC -41: @ 44.80ft (MPC -41:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM 2003.16 Single User Db EM Northing (ft) (ft) 4,295.83 6,026,606.67 4,379.71 6, 026, 554.07 4,395.03 6,026,541.60 4,459.12 6,026,495.84 4,548.21 6, 026, 455.00 4,566.92 6,026,449.17 4,639.85 6,026,421.17 4,657.22 6,026,412.26 Easting DLeg (ft) (%100ft) 562,331.20 12.00 562,415.48 12.00 562,430.90 12.00 562,495.35 12.00 562,584.75 12.00 562,603.50 12.00 562,676.65 12.00 562,694.08 12.00 V.Sec TFace (ft) (°} 5,110.29 74.11 5,208.82 74.5E 5,228.03 75.7( 5,305.67 -80.00 5,403.97 -81.4C 5,423.45 -83.5( 5,501.63 85.00 5,521.19 86.9E r1 10128/2009 11:35:36AM Page 5 COMPASS 2003.16 Build 71 Project: Milne Point Site: M Pt C Pad Well: MPC -24 Wellbore: Plan9,MPC-24A Plan: Plan 9, MPC-24A(MPC-241PIan 9, MPC -24A) WELL DETAILS: MPC -24 Ground Level: 0.00 +N/ -S +E/ -W Northing Easting Laaltude Longitude Slot 0.00 0.00 6029452.34 558013.45 70° 29'27,903 N 149° 31'32.650 W �- O -T -Nom Magr,enc Norm: 2409 WELLBORE DETAILS: Plan 9, M Map.knW Parent Wellbore: MPC -24 575930= Dip Angle'. 8093 Date 2rz4rz Tie on MD: 7957.66 ANNOTATIONS MO i BGGM200 MD WELL DETAILS: MPC -24 Ground Level: 0.00 +N/ -S +E/ -W Northing Easting Laaltude Longitude Slot 0.00 0.00 6029452.34 558013.45 70° 29'27,903 N 149° 31'32.650 W REF626JCENFORMATION G-minate(N/E)Rebmnw WelMPG24,TMeNOM \ ric@I ND)Ret°rence: Mean Sea L -I Seouon(VS)R b-': S0t-(000N,0.00E) Measun:d Depth Rekrenro: MPC41: Q44.Wft(MPC ryfit BAKER HUGHES INTEQ West(-)/East(+)(150 ft/in) Vertical Section at 115.00° (75 ft/in) i is SECTION DETAILS ANNOTATIONS Sec MD Inc Azi ssTVD +N/ -S +E/ -W Meg TFace VSec Target Annotation 1 7957.66 28.74 167.53 6775.90 -2369.70 2414.48 0.00 0.00 3189.74 TIP 2 8040.00 27.48 167.21 6848.53 -2407.56 2422.96 1.54 -173.32 3213.43 KOP 3 8060.00 27.53 163.31 6866.27 -2416.49 2425.31 9.00 270.00 3219.33 End of 9 Deg/100' DLS 4 8100.00 30.64 134.97 6901.38 -2432.63 2435.23 35.00 270.00 3235.14 4 5 8299.90 90.00 87.22 6999.94 -2468.32 2590.94 35.00 308.00 3391.35 End of 35 Deg/100' DLS 6 8349.90 90.00 81.22 6999.94 -2463.28 2640.66 12.00 270.00 3434.28 6 7 8499.90 90.00 99.22 6999.94 -2463.84 2790.05 12.00 90.00 3569.91 7 8 8659.90 90.00 80.02 6999.94 -2462.77 2949.30 12.00 270.00 3713.78 8 9 8869.90 90.00 105.22 6999.94 -2472.28 3157.39 12.00 90.00 3906.40 9 10 9079.90 101.91 127.59 6977.91 -2563.98 3343.13 12.00 61.00 4113.49 10 11 9259.90 89.16 110.03 6960.45 -2649.54 3499.31 12.00 235.00 4291.20 11 12 9339.90 88.34 119.60 6962.20 -2663.07 3571.82 12.00 95.00 4371.08 12 13 9609.90 82.72 87.58 6983.79 -2745.74 3829.86 12.00 259.00 4631.43 13 14 9859.90 88.75 117.06 7002.80 -2798.57 4070.55 12.00 79.80 4871.90 14 15 9979.90 90.03 102.72 7004.09 -2839.29 4183.09 12.00 275.00 4991.10 15 16 10220.00 97.61 130.60 6987.79 -2945.40 4395.03 12.00 74.10 5228.03 16 17 10420.00 101.01 106.52 6854.96 -3039.19 4566.92 12.00 280.00 5423.45 17 18 10520.00 101.81 118.73 6935.11 -3076.80 4657.22 12.00 85.00 5521.19 TD at 10520.00 REF626JCENFORMATION G-minate(N/E)Rebmnw WelMPG24,TMeNOM \ ric@I ND)Ret°rence: Mean Sea L -I Seouon(VS)R b-': S0t-(000N,0.00E) Measun:d Depth Rekrenro: MPC41: Q44.Wft(MPC ryfit BAKER HUGHES INTEQ West(-)/East(+)(150 ft/in) Vertical Section at 115.00° (75 ft/in) i is wag � BPPASSPORT "Ims Travelling Cylinder Report 0 by INTEQ Company: North America - ALASKA - BP Project: Milne Point Reference Site: M Pt C Pad Site Error: 0.00ft Reference Well: MPC -24 Well Error: 0.00ft Reference Wellbore Plan 9, MPC -24A Reference Design: Plan 9, MPC -24A Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well MPC -24 MPC -41: @ 44.80ft (MPC -41:) MPC -41: @ 44.80ft (MPC -41:) True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum teference Plan 9, MPC -24A 'filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( ►terpolation Method: MD Interval 25.00ft Error Model: ISCWSA lepth Range: 7,957.66 to 10,520.00ft Scan Method: Tray. Cylinder North tesults Limited by: Maximum center -center distance of 1,249.13ft Error Surface: Elliptical Conic Survey Tool Program Date 10/2812009 Offset Centre to From To Measured Centre (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 1,929.94 MPC -24 GYRO (MPC -24) GYD-CT-DMS Gyrodata cont.drillpipe m/s 1,965.09 7,957.66 MPC -24 IIFR (MPC -24) MWD+IFR+MS MWD + IFR + Multi Station 7,957.66 10,520.00 Plan 9, MPC -24A (Plan 9, MPC -24A) MWD MWD - Standard Casing Points __... Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 7,724.23 6,618.70 7" 7.000 8.500 4,987.42 4,548.70 9 5/8" 9.620 12.250 10,520.00 6,979.91 2-7/8" 2.875 4.125 Summary Site Name Offset Well - Wellbore - Design M Pt C Pad MPC -01 - MPC -01 - MPC -01 MPC -02 - MPC -02 - MPC -02 MPC -11 - MPC -11 - MPC -11 MPC -13 - MPC -13 - MPC -13 MPC -14 - MPC -14 - MPC -14 MPC -23 - MPC -INE - MPC -INE WP01 MPC -23 - MPC -PSE- MPC -PSE WP01 MPC -24 - MPC -24 - MPC -24 MPC -26 - MPC -261-1 - Plan #6 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) 8,110.00 8,200.00 802.70 9,765.63 8,650.00 1,216.36 8,050.00 8,050.00 0.08 Out of range Out of range Out of range 484.27 360.48 Pass - Major Risk 738.15 493.20 Pass - Major Risk Out of range Out of range 2.73 -2.61 FAIL - Major Risk Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10128/2009 2:06:48PM Page 2 of 6 COMPASS 2003.16 Build 71 0 easurements are from top of Riser i U) cc of bag of bag iddle of slips I Blind/Shears middle of pipes 1 3° slips Mud Cross middle of flow cross e of blind/shears I variable bore pipe 3 1/2"-2 3/8" of pipe/slips i 2-3/8" combi ram/slips Swab Valve Flow Tee 0 11/4/2009 MPC -24A BAG 7 1/16" 5000 psi. TOTs 7 1/16" 5000psi Mud Cross 7 1/16" 5000psi TOTs 7 1/16" 5000psi TRANSMITTAL LETTER CHECKLIST WELL NAME MILNE PT UNIT KR C -24A PTD# 2091340 X Development Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: MILNE POINT POOL: MILNE POINT, KUPARUK RIVER OIL Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTILATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non -Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program-____ Rev: 1/11/2008 Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 __— Well Name: MILNE PT_ UNIT KR C -24A -----Program DEV Well bore seg ❑ 7Administration 1340 Company BP EXPLORATI.ON (ALASKA) INC_ - — __ Initial Class/Type DEV / PEND GeoArea 890 _ — Unit 1.1328 On/Off Shore On - Annular Disposal ❑ 11 Permit fee attached NA 2 Lease number appropriate_ Yes - - - - Surface location in ADL 47434 top prod interval_ in ADL 255.16; TD in ADL 474.37 - - - Surface casing set in C-24 name an number -Unique we _ Yes CMT vol_ adequate to circulate on conductor_ & surf csg NA Surface casing is cemented C-24 located in a defined pool Yes Kuparuk River Oil_ Pool, governed by Conservation Order No. 432C I4Well i5 Production casing set in -C-24 Well located proper distance from drilling unit -boundary - - - Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit boundaries. p 9- I6 Liner to be cemented and perfed_ Well located proper distance from other wells - - - Yes _ Conservation Order No. 432C has no in_terwell spacing restrictions. 7 Sufficient acreage available in -drilling unit Yes - - - - Conservation Order No. 432C has no interwell_spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes an external property line_ where -ownership or -landownership changes. 9 Operator only affected party Yes 309-371 P &A sundry - - 10 Operator has appropriate_ bond in force Yes Proximity analysis performed .. No issues. 11 Permit can be issued without conservation order - - - Yes - - - - Appr Date �12 Permit_ can be issued without administrativ_e_approval Yes Max formation pressure= 2540psi (7_.0 ppg EMW) . Will drill_ with 8.8 ppg _mud and Managed Pressure_ Drilling . GLS 11/10/2009 13 Can permit be approved before 15 -day wait Yes SFD 11/9/2009 14 Well located within area and strata authorized by Injection Order # (put -10# in comments) (For NA_ Yes 15 All wells -within 1/4 mile area of review identified (For service well only) NA_ Choke manifold complies w/API RP -53 (May 84) Yes I16 Pre -produced injector: duration of pre -production Less than 3 months- (For service well only) NA Work will occur without operation shutdown_ Yes 17 Nonconven. gas conforms to AS3.1.05.030(j.1_.A),0.2_.A-D) NA_ - Yes 118 Conductor string provided N_A Conductor set in C-24 - - Engineering 19 Surface casing protects all -known USDWs NA - - - - Surface casing set in C-24 20 CMT vol_ adequate to circulate on conductor_ & surf csg NA Surface casing is cemented C-24 21 CMT vol_ adequate to tie-in long string to surf csg NA Production casing set in -C-24 122 CMT will cover all known -productive horizons Yes Liner to be cemented and perfed_ i23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage -or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a_re-drill, has a 10-403 for abandonment been approved Yes 309-371 P &A sundry - - :26 Adequate wellbore separation proposed Yes Proximity analysis performed .. No issues. 27 �28 If diverter required, does it meet regulations NA wellhead -in place... BOP installed._ _ Appr Date Drilling fluid_ program schematic __&_ equip list adequate Yes Max formation pressure= 2540psi (7_.0 ppg EMW) . Will drill_ with 8.8 ppg _mud and Managed Pressure_ Drilling . GLS 11/10/2009 29 BOPEs,_do they meet regulation - - - - Yes 30 BOPE_press rating appropriate; test to _(put psig in comments) Yes MASP=1840 psi . Will test BOPs to 3500 psi 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown_ Yes 33 Is presence of H2S gas_ probable - - Yes - - - - H2S reported at MP Cpad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For_ service well only) - NA 35 Permit _c_an be issued w/o hydrogen sul-fide measures No MPU C -2 -4 -measured 21 ppm H2S_ in July 2009._ Measures required. - - - - Geology 36 Data presented on potential overpressure zones Yes - - - Expected reservoir pressure is 2540 psi (7.0-ppg EMW_); will be_drilled_with 8.8 ppg mud Appr Date Seismic analysis of shallow gas_zones_ - - - NA - - - - - using coiled tubing rig and employing _managed pressure drilling techniques to maintain borehole stability. SFD 11/9/2009 137 38 Seabed condition survey _(if off -shore) NA_ - - - - - - - - - - 39 Contact name/phone for weekly progress reports [exploratory only] - - - - - - NA - - - - - - - - - - - - Geologic Engineering Public Redrilled well bore intended to produce from Kuparuk A2 and A3. Commissioner: Date: Commissioner: Date Com o r Date 0 is Well History File 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. f tapescan.txt **** REEL HEADER **** MWD 10/04/14 BHI 01 LIS Customer Format Tape **** TAPE HEADER""*** MWD 10/01/07 2948650 01 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information #--------- ------------- ------------------------------- STRT.FT 7615.0000: Starting Depth STOP.FT 10580.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPC -24A FLO FIELD: Milne Point Unit LOC LOCATION: 70 deg 29' 27.903"N 149 deg 31' 32.650"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 07 Jan 2010 API . API NUMBER: 500292302001 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 10 TOWN.N T13N RANG. R10E PDAT. MSL EPD .F 0 LMF . OF FAPD.F 44.80 DMF . DF EKB .F 0 EDF .F 44.80 EGL .F 0 Page 1 Description section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level aCPt _t3q �s��- tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 09 jan 2010 per Katie Nitzberg with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from MPC -24 through a milled window in a 4.5 inch liner. Top of window 8045 ft.MD (6853.0 ft.TVDSS) Bottom of window 8051 ft.MD (6858.3 ft.TVDSS) (9) Tied to MPC -24 at 7958 feet MD (6775.9 feet TVDSS). (10) CoilTrak downhole logging tools were not utilized on INTEQ run 1. (11) The resistivity interval from 8045 ft to 8288 ft MD (6853.0 ft to 7004.3 ft TVDSS) was logged on run 4. (12) Baler Hughes INTEQ runs 5 and 6 were used to drill MPC-24APB1. (13) MPC -24A was completed with an open Hole Sidetrack at 8525 ft MD (7000.5 ft TVDSS). (14) The interval from 10538 ft to 10580 ft MD (6948.0 ft. to 6945.2 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP—AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(Ls)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 7621.84, 7620.94, ! -0.896973 7626.5, 7625.61, ! -0.896973 7636.01, 7634.94, ! -1.07617 7642.11, 7641.39, ! -0.717773 7650.54, 7650.19, ! -0.358887 7653.95, 7652.52, ! -1.43506 7663.1, 7661.85, ! -1.25586 7683.73, 7681.76, ! -1.97363 7692.29, 7691.21, ! -1.07666 7697.31, 7696.78, ! -0.538574 7701.98, 7700.36, ! -1.61475 7703.95, 7702.88, ! -1.07617 7707, 7706.29, ! -0.717285 7713.82, 7713.28, ! -0.538086 7716.15, 7715.97, ! -0.179688 7721, 7719.56, ! -1.43506 7722.43, 7722.07, ! -0.358887 7724.23, 7724.58, ! 0.358887 Page 2 f 7730.5, 7730.5, 7738.4, 7737.86, 7749.16, 7747.36, 7755.79, 7755.79, 7764.58, 7764.58, 7772.48, 7771.76, 7774.09, 7773.55, 7781.99, 7781.81, 7789.34, 7788.8, 7795.03, 7794.67, 7802.92, 7802.56, 7804.9, 7805.08, 7813.51, 7813.33, 7818.17, 7817.63, 7823.91, 7824.27, 7836.29, 7834.68, 7844.54, 7842.39, 7850.29, 7849.93, 7854.76, 7853.86, 7857.09, 7856.73, 7860.68, 7860.68, 7862.29, 7861.75, 7866.42, 7865.88, 7874.13, 7873.95, 7880.23, 7879.69, 7892.43, 7891.71, 7899.79, 7899.43, 7904.31, 7903.77, 7907.72, 7907.36, 7910.59, 7910.77, 7912.74, 7913.28, 7930.33, 7929.43, 7938.04, 7937.32, 7942.17, 7941.45, 7943.46, 7942.92, 7945.43, 7945.79, 7952.61, 7951.89, 7959.61, 7957.63, 7961.31, 7959.33, 7968.66, 7966.87, 7971.53, 7970.82, 7973.51, 7972.97, 7976.92, 7975.66, 7981.4, 7981.04, 7985.71, 7985.17, 7990.37, 7988.94, 7995.04, 7994.14, 8003.95, 8001.8, 8006.29, 8004.49, 8012.21, 8010.59, 8027.1, 8025.3, 8031.12, 8029.51, 8040.73, 8038.94, 8051.85, 8050.96, 8054.19, 8053.11, 8055.26, 8054.54, 8067.18, 8066.82, 8072.92, 8072.92, 8076.51, 8076.87, 8079.38, 8079.92, 8081, 8081.18, 8087.63, 8089.06, 8094.45, 8094.81, tapescan.txt 0 -0.538086 -1.79395 -0.717773 -0.538086 -0.179199 -0.538574 -0.358887 -0.358887 0.179199 -0.179199 -0.538086 0.358398 -1.61475 -2.15283 -0.358398 -0.896973 -0.358887 -0.538086 -0.538574 -0.179688 -0.538086 -0.717773 -0.358887 -0.538086 -0.358887 0.179199 0.538086 -0.896973 -0.717285 -0.717773 -0.538574 0.358887 -0.717773 -1.97314 -1.97363 -1.79395 -0.717773 -0.538086 -1.25586 -0.358887 -0.538574 -1.43555 -0.896973 -2.15283 -1.79395 -1.61475 1.79443 -1.61426 -1.79443 -0.897461 -1.07617 -0.717773 -0.358887 0 0.358887 0.538574 179688 1.43506 0.358887 Page 3 • i rl tapescan.txt 8101.8, 8102.7, ! 0.896973 8107.36, 8108.44, ! 1.07666 8116.15, 8116.33, ! 0.179199 8120.64, 8118.84, ! -1.79395 8123.95, 8123.59, ! -0.358887 8128.8, 8128.44, ! -0.358887 8135.61, 8135.97, ! 0.358398 8144.76, 8144.94, ! 0.179688 8153.2, 8154.09, ! 0.896973 8163.06, 8162.52, ! -0.538086 8171.13, 8170.77, ! -0.358887 8175.61, 8174.9, ! -0.717773 8180.1, 8179.02, ! -1.07666 8183.69, 8182.25, ! -1.43506 8187.45, 8186.74, ! -0.717773 8189.97, 8189.43, ! -0.538574 8193.91, 8193.91, ! 0 8196.42, 8195.89, ! -0.538086 8198.4, 8198.04, ! -0.359375 8205.16, 8205.52, ! 0.358398 8209.47, 8210.01, ! 0.538086 8214.31, 8213.95, ! -0.359375 8217.59, 8216.7, ! -0.897461 8220.64, 8219.93, ! -0.717773 8228.84, 8228.48, ! -0.358398 8233.33, 8231.89, ! -1.43555 8237.45, 8236.74, ! -0.716797 8248.22, 8246.78, ! -1.43555 8251.63, 8250.37, ! -1.25586 8253.42, 8252.17, ! -1.25586 8255.39, 8253.6, ! -1.79395 8259.7, 8258.44, ! -1.25586 8265.98, 8264.54, ! -1.43555 8268.35, 8266.2, ! -2.15332 8271.94, 8269.61, ! -2.33203 8277.86, 8276.6, ! -1.25586 8288.62, 8287.36, ! -1.25586 8298.3, 8297.41, ! -0.896484 8307.28, 8307.1, ! -0.179688 8313.59, 8312.88, ! -0.717773 8335.34, 8335.16, ! -0.178711 8351.85, 8352.38, ! 0.538086 8361.35, 8359.92, ! -1.43457 8368.35, 8366.02, ! -2.33203 8372.48, 8370.15, ! -2.33203 8376.42, 8373.91, ! -2.51172 8393.77, 8392.16, ! -1.61523 8424.63, 8422.12, ! -2.51172 8439.33, 8439.33, ! 0 8448.3, 8447.23, ! -1.07617 8468.4, 8468.4, ! 0 8473.46, 8473.64, ! 0.179688 8487.45, 8484.76, ! -2.69043 8490.5, 8487.81, ! -2.69043 8501.13, 8499.69, ! -1.43555 8508.93, 8507.67, ! -1.25586 8521.49, 8522.56, ! 1.07617 8524.54, 8525.25, ! 0.717773 8525.79, 8526.87, ! 1.07715 8539.25, 8541.76, ! 2.51172 8549.29, 8550.73, ! 1.43555 8560.05, 8557.9, ! -2.15332 8566.87, 8565.08, ! -1.79492 Page 4 rl 0 8570.82, 8568.48, 8588.76, 8585.89, 8596.11, 8593.41, 8603.28, 8600.41, 8619.07, 8617.1, 8631.81, 8628.94, 8657.99, 8654.58, 8662.07, 8660.27, 8666.37, 8663.86, 8669.6, 8667.63, 8687.72, 8686.82, 8703.69, 8701.89, 8721.09, 8718.58, 8731.67, 8730.23, 8735.25, 8733.1, 8738.12, 8739.02, 8741.35, 8742.61, 8782.07, 8782.07, 8788.17, 8787.45, 8805.2, 8803.77, 8825.87, 8825.33, 8833.59, 8832.51, 8849.2, 8846.15, 8864.84, 8863.77, 8903.23, 8901.08, 8923.36, 8922.29, 8935.02, 8934.48, 8943.85, 8942.06, 8954.44, 8953.18, 8971.21, 8970.31, 9000.49, 8999.41, 9016.82, 9018.25, 9030.49, 9031.21, 9039.64, 9040.54, 9049.69, 9049.69, 9061.39, 9059.95, 9067.67, 9066.41, 9074.88, 9074.52, 9084.93, 9082.6, 9113.95, 9113.23, 9131.25, 9129.46, 9145.79, 9143.45, 9162.29, 9158.7, 9185.69, 9184.08, 9188.21, 9186.59, 9201.3, 9198.43, 9209.55, 9206.33, 9211.89, 9208.84, 9229.28, 9225.69, 9235.56, 9233.41, 9244.39, 9244.93, 9249.41, 9249.59, 9264.03, 9262.42, 9281.16, 9278.83, 9289.59, 9286.9, 9299.86, 9296.99, 9313.36, 9313.9, 9319.46, 9318.38, 9342.33, 9344.12, 9350.76, 9351.3, 9404.53, 9401.66, 9407.04, 9403.81, 9437.8, 9440.85, tapescan.txt -2.33203 -2.87012 -2.69141 -2.87012 -1.97363 -2.87012 -3.4082 -1.79395 -2.51172 -1.97363 -0.896484 -1.79395 -2.51172 -1.43555 -2.15234 0.897461 1.25586 0 -0.717773 -1.43555 -0.538086 -1.07617 -3.0498 -1.07617 -2.15332 -1.07617 -0.538086 -1.79395 -1.25586 -0.896484 -1.07715 1.43555 0.716797 0.896484 0 ! -1.43555 ! -1.25586 ! -0.359375 ! -2.33301 ! -0.717773 ! -1.79395 ! -2.33301 ! -3.58789 ! -1.61426 ! -1.61426 ! -2.87012 ! -3.22852 ! -3.0498 ! -3.58789 ! -2.15234 ! 0.539062 ! 0.179688 ! -1.61426 ! -2.33301 ! -2.69141 ! -2.87012 ! 0.538086 ! -1.07617 ! 1.79395 ! 0.538086 ! -2.87109 ! -3.22852 ! 3.0498 Page 5 0 9444.26, 9445.69, 9448.03, 9449.82, 9452.51, 9456.64, 9458.25, 9463.1, 9464.17, 9467.4, 9484.21, 9485.83, 9507, 9508.43, 9518.66, 9521.71, 9538.12, 9541.17, 9542.07, 9543.32, 9545.12, 9547.45, 9551.79, 9553.23, 9564.89, 9565.43, 9574.4, 9574.94, 9584.62, 9582.82, 9592.96, 9590.62, 9617.53, 9614.3, 9638.88, 9634.76, 9645.33, 9640.67, 9653.77, 9650.19, 9660.05, 9655.56, 9669.55, 9665.25, 9676.41, 9671.57, 9681.61, 9677.31, 9690.58, 9686.46, 9695.61, 9692.38, 9698.12, 9696.33, 9704.4, 9701.89, 9708.88, 9705.12, 9714.62, 9711.39, 9725.2, 9721.43, 9729.87, 9726.28, 9752.69, 9747.67, 9754.48, 9750.18, 9764.17, 9760.58, 9772.96, 9772.24, 9783.9, 9783.18, 9792.33, 9790.9, 9794.12, 9793.23, 9799.51, 9798.79, 9809.02, 9806.33, 9835.16, 9832.82, 9843.05, 9839.64, 9850.76, 9848.79, 9862.29, 9861.39, 9871.43, 9871.61, 9885.43, 9884.53, 9897.09, 9896.91, 9911.34, 9910.44, 9918.7, 9918.88, 9927.8, 9926.72, 9933.9, 9933.18, 9938.7, 9937.08, 9944.08, 9943.9, 9947.13, 9946.95, 9972.64, 9971.21, 9981.08, 9980.18, 9989.69, 9989.87, 9999.2, 9998.66, 10014.1, 10015.5, 10020, 10021.4, 10022.3, 10023.8, 10025.4, 10026.8, tapescan.txt 1.43555 1.79395 4.12598 4.84375 3.22949 1.61426 1.43555 3.0498 3.0498 1.25586 2.33301 1.43555 0.538086 0.538086 -1.79395 -2.33203 -3.22949 -4.12598 -4.66504 -3.58789 -4.48535 -4.30566 -4.84375 -4.30566 -4.12598 -3.22949 -1.79395 -2.51172 -3.76758 -3.22949 -3.76758 -3.58789 -5.02344 -4.30566 -3.58789 -0.717773 -0.717773 -1.43457 -0.896484 -0.717773 -2.69043 -2.33203 -3.4082 -1.97363 -0.897461 0.179688 -0.896484 -0.178711 -0.896484 0.179688 -1.07617 -0.717773 -1.61426 -0.179688 -0.179688 -1.43555 -0.896484 0.179688 -0.538086 1.43457 1.43555 1.43555 1.43555 Page 6 0 0 tapescan.txt 10034, 10033.5, ! -0.538086 10039.4, 10039.4, ! 0 10058.3, 10057.8, ! -0.538086 10077.5, 10075.4, ! -2.15332 10089.4, 10087, ! -2.33203 10111.7, 10108, ! -3.76758 10129, 10125.6, ! -3.40918 10143.4, 10138.9, ! -4.48535 10163.1, 10159.7, ! -3.40918 10166.8, 10162.8, ! -3.94629 10174.1, 10170.2, ! -3.94629 10181.5, 10177.9, ! -3.58887 10183.6, 10179.7, ! -3.94727 10193.1, 10189.9, ! -3.22949 10202.8, 10199.6, ! -3.22949 10222.3, 10220.8, ! -1.43555 10228.4, 10225.9, ! -2.51172 10233.6, 10231.3, ! -2.33203 10241.8, 10240.8, ! -1.07617 10244.2, 10243.1, ! -1.07617 10249.7, 10247, ! -2.69043 10252.4, 10248.8, ! -3.58789 10262.1, 10259.8, ! -2.33203 10271, 10267.6, ! -3.40918 10280, 10276.4, ! -3.58789 10293.3, 10288.3, ! -5.02344 10302.2, 10297.6, ! -4.66406 10318.7, 10318, ! -0.716797 10320.5, 10319.6, ! -0.897461 10323.7, 10322.8, ! -0.896484 10341.2, 10340.8, ! -0.358398 10375.5, 10376, ! 0.538086 10382.3, 10383.2, ! 0.896484 10386.9, 10388.7, ! 1.79395 10391.6, 10393.4, ! 1.79395 10401.3, 10400, ! -1.25586 10411.9, 10410.4, ! -1.43555 10418.2, 10416.7, ! -1.43457 10425.3, 10424.4, ! -0.897461 10433.2, 10432.3, ! -0.897461 10437.5, 10436.8, ! -0.717773 10448.8, 10447.8, ! -1.07715 10457.8, 10455.7, ! -2.15234 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 392 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 Page 7 0 tapescan.txt LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 09 San 2010 per Katie Nitzberg with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub -type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 165 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 7615.000000 Tape File End Depth = 10578.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape subfile: 2 178 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 Page 8 • 0 tapescan.txt 1024 LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw -unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optica l Log Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub -type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 330 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File start Depth = 7615.750000 Tape File End Depth = 10580.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 343 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 10/01/07 2948650 01 Page 9 0 **** REEL TRAILER*** MWD 10/04/14 BHI 01 Tape subfile: 4 Minimum record length: Maximum record length: tapescan.txt 2 records... 132 bytes 132 bytes 0 0 Tape Subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 7615.0000 111.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7615.5000 109.5404 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7700.0000 118.7888 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7800.0000 114.7388 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7900.0000 107.5187 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8000.0000 66.5713 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8100.0000 112.5676 26.1708 6.5951 6.8688 6.2661 5.7422 8200.0000 86.3556 58.9527 8.6891 9.1911 9.0305 9.0154 8300.0000 90.8591 47.1198 20.5645 23.2881 22.3463 21.0019 8400.0000 52.9979 62.0450 24.7496 36.5127 43.9600 50.3610 Page 10 tapescan.txt 8500.0000 77.2160 79.4405 20.9921 29.8687 32.7705 34.0230 8600.0000 62.1857 53.7000 9.8374 11.0985 11.2920 11.5190 8700.0000 88.4996 15.1494 11.9570 12.4851 12.1641 11.4696 8800.0000 78.8592 74.1395 13.5586 15.7383 14.5003 13.8125 8900.0000 45.3476 132.1870 13.5885 14.2067 12.0719 10.4888 9000.0000 46.8955 102.9045 18.8723 30.8435 48.0641 75.5048 9100.0000 112.4607 43.7508 9.4384 8.4714 10.0850 11.3952 9200.0000 73.1691 55.6671 12.5904 14.8856 14.5505 13.7378 9300.0000 50.7684 128.4737 13.5016 16.7518 16.0012 14.9133 9400.0000 38.2339 76.7361 13.2090 16.5779 16.3190 15.9496 9500.0000 58.2973 46.4001 14.2319 21.3511 18.6221 18.1151 9600.0000 120.8360 78.6544 8.6388 7.9508 8.4632 8.5670 9700.0000 92.0405 112.0505 22.0045 31.1692 38.4127 40.2033 9800.0000 116.4793 35.1793 20.1843 23.3608 28.4932 30.7244 9900.0000 95.6681 54.1302 16.8410 28.8262 35.1139 48.5987 10000.0000 83.3771 59.3632 18.6138 23.7804 33.7850 43.3280 10100.0000 55.7669 160.7655 30.8417 30.9186 38.0890 50.2640 10200.0000 52.7915 177.5860 20.2749 31.8744 39.4920 45.1420 10300.0000 107.7068 45.0304 9.3451 8.2764 9.9044 11.2867 10400.0000 46.5619 57.4139 13.5880 15.4588 13.8159 12.1509 10500.0000 61.2629 80.4379 12.8984 14.0739 13.4540 12.0573 Page 11 tapescan.txt 10578.0000 -999.2500 157.3000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 7615.000000 Tape File End Depth = 10578.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 7615.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7616.0000 111.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7700.0000 118.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7800.0000 111.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7900.0000 103.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8000.0000 70.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8100.0000 119.3000 26.0000 6.3840 6.5090 6.1540 5.8040 8200.0000 81.1000 58.3000 8.7310 9.2550 9.1140 9.1260 8300.0000 93.3000 48.3000 20.6910 23.5250 21.9560 20.3140 8400.0000 47.3000 61.0000 24.4370 35.7750 44.8410 50.3610 8500.0000 70.2000 81.9000 21.2870 30.8250 33.0700 34.6250 8600.0000 74.5000 31.9000 10.1810 11.8830 11.6000 11.5520 8700.0000 99.0000 41.5000 12.0680 12.9060 12.6590 12.1640 8800.0000 92.0000 72.7000 13.2530 15.1770 14.0700 13.0320 8900.0000 40.8000 112.7000 13.6180 14.6350 12.2530 10.7650 9000.0000 43.7000 102.9000 18.9670 31.4590 47.5390 74.3640 Page 12 0 tapescan.txt 9100.0000 113.9000 45.1000 10.1720 10.9820 9200.0000 79.3000 47.7000 14.1070 13.3710 9300.0000 37.2000 127.7000 15.6480 14.3050 9400.0000 36.3000 77.4000 16.8520 16.8300 9500.0000 51.7000 47.0000 18.2050 17.5630 9600.0000 118.6000 27.0000 8.4890 8.5670 9700.0000 77.3000 118.9000 43.8480 48.6350 9800.0000 113.3000 28.1000 27.6600 28.2990 9900.0000 89.2000 55.3000 35.5240 49.6880 10000.0000 83.3000 61.6000 33.7850 43.3280 10100.0000 50.2000 85.2000 36.7690 49.1640 10200.0000 45.7000 72.8000 40.9860 48.1050 10300.0000 105.5000 67.1000 9.4320 10.9820 10400.0000 67.4000 87.0000 14.3530 13.0330 10500.0000 59.3000 70.8000 13.5970 11.7910 10580.0000 -999.2500 157.3000 -999.2500 -999.2500 Tape File start Depth = 7615.750000 Tape File End Depth = 10580.000000 Tape File Level spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS Page 13 0 9.7070 12.2810 13.2530 13.3420 14.2330 8.7520 22.0700 20.5310 16.7130 18.6840 19.8730 21.1180 8.9430 13.5230 13.7120 -999.2500 8.7600 14.3730 16.3920 17.0240 21.2300 8.1010 33.4730 24.6990 28.6280 23.8760 27.1460 32.6690 7.8240 15.5890 14.8560 -999.2500 0 tapescan.txt **** REEL HEADER **** MWD 10/04/19 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 10/01/04 2948650 O1 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las 0 version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: one line per frame well Information Block #MNEM.UNIT Data Type Information #--------- ------------- ------------------------------- STRT.FT 7615.0000: Starting Depth STOP.FT 9410.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPC-24APB1 FLD FIELD: Milne Point Unit LOC LOCATION: 70 deg 29' 27.903"N 149 deg 31' 32.650"W CNTY. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 04 Jan 2010 API . API NUMBER: 500292302070 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 10 TOWN.N T13N RANG. R10E PDAT. MSL EPD .F 0 LMF . DF FAPD.F 44.80 DMF . DF EKB .F 0 EDF .F 44.80 EGL .F 0 Page 1 opt -c3q Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level tapescan.txt CASE.F N/A Casing Depth osl . DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting sub with a Near Bit inclination sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 09 ]an 2010 above the Kick off Point of 8522 ft. MD per Katie Nitzberg with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from MPC -24 through a milled window in a 4.5 inch liner. Top of window 8045 ft.MD (6853.0 ft.TVDSS) Bottom of window 8051 ft.MD (6858.3 ft.TVDSS) (9) Tied to MPC -24 at 7958 feet MD (6775.9 feet TVDSS). (10) CoilTrak downhole logging tools were not utilized on INTEQ run 1. (11) The resistivity interval from 8045 ft to 8288 ft MD (6853.0 ft to 7004.3 ft TVDSS) was logged on run 4 10 hours after drilling. (12) MPC-24APB1 was abandoned from 8525 ft. to 9410 ft. MD (7000.5 ft to 6963.8 ft TVDSS). (13) The interval from 9368 ft to 9410 ft MD (6961.0 ft. to 6963.8 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD1 (MWD -API units) ROP—AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 7621.84, 7620.94, ! -0.896973 7626.5, 7625.61, ! -0.896973 7636.01, 7634.94, ! -1.07617 7642.11, 7641.39, ! -0.717773 7650.54, 7650.19, ! -0.358887 7653.95, 7652.52, ! -1.43506 7663.1, 7661.85, ! -1.25586 7683.73, 7681.76, ! -1.97363 7692.29, 7691.21, ! -1.07666 7697.31, 7696.78, ! -0.538574 7701.98, 7700.36, ! -1.61475 7703.95, 7702.88, ! -1.07617 7707, 7706.29, ! -0.717285 7713.82, 7713.28, ! -0.538086 7716.15, 7715.97, ! -0.179688 7721, 7719.56, ! -1.43506 7722.43, 7722.07, ! -0.358887 7724.23, 7724.58, ! 0.358887 Page 2 • tapescan.txt 7730.5, 7730.5, ! 0 7738.4, 7737.86, ! -0.538086 7749.16, 7747.36, ! -1.79395 7755.79, 7755.79, ! 0 7764.58, 7764.58, ! 0 7772.48, 7771.76, ! -0.717773 7774.09, 7773.55, ! -0.538086 7781.99, 7781.81, ! -0.179199 7789.34, 7788.8, ! -0.538574 7795.03, 7794.67, ! -0.358887 7802.92, 7802.56, ! -0.358887 7804.9, 7805.08, ! 0.179199 7813.51, 7813.33, ! -0.179199 7818.17, 7817.63, ! -0.538086 7823.91, 7824.27, ! 0.358398 7836.29, 7834.68, ! -1.61475 7844.54, 7842.39, ! -2.15283 7850.29, 7849.93, ! -0.358398 7854.76, 7853.86, ! -0.896973 7857.09, 7856.73, ! -0.358887 7860.68, 7860.68, ! 0 7862.29, 7861.75, ! -0.538086 7866.42, 7865.88, ! -0.538574 7874.13, 7873.95, ! -0.179688 7880.23, 7879.69, ! -0.538086 7892.43, 7891.71, ! -0.717773 7899.79, 7899.43, ! -0.358887 7904.31, 7903.77, ! -0.538086 7907.72, 7907.36, ! -0.358887 7910.59, 7910.77, ! 0.179199 7912.74, 7913.28, ! 0.538086 7930.33, 7929.43, ! -0.896973 7938.04, 7937.32, ! -0.717285 7942.17, 7941.45, ! -0.717773 7943.46, 7942.92, ! -0.538574 7945.43, 7945.79, ! 0.358887 7952.61, 7951.89, ! -0.717773 7959.61, 7957.63, ! -1.97314 7961.31, 7959.33, ! -1.97363 7968.66, 7966.87, ! -1.79395 7971.53, 7970.82, ! -0.717773 7973.51, 7972.97, ! -0.538086 7976.92, 7975.66, ! -1.25586 7981.4, 7981.04, ! -0.358887 7985.71, 7985.17, ! -0.538574 7990.37, 7988.94, ! -1.43555 7995.04, 7994.14, ! -0.896973 8003.95, 8001.8, ! -2.15283 8006.29, 8004.49, ! -1.79395 8012.21, 8010.59, ! -1.61475 8027.1, 8025.3, ! -1.79443 8031.12, 8029.51, ! -1.61426 8040.73, 8038.94, ! -1.79443 8051.85, 8050.96, ! -0.897461 8054.19, 8053.11, ! -1.07617 8055.26, 8054.54, ! -0.717773 8067.18, 8066.82, ! -0.358887 8072.92, 8072.92, ! 0 8076.51, 8076.87, ! 0.358887 8079.38, 8079.92, ! 0.538574 8081, 8081.18, ! 0.179688 8087.63, 8089.06, ! 1.43506 8094.45, 8094.81, ! 0.358887 Page 3 • • 8101.8, 8102.7, 8107.36, 8108.44, 8116.15, 8116.33, 8120.64, 8118.84, 8123.95, 8123.59, 8128.8, 8128.44, 8135.61, 8135.97, 8144.76, 8144.94, 8153.2, 8154.09, 8163.06, 8162.52, 8171.13, 8170.77, 8175.61, 8174.9, 8180.1, 8179.02, 8183.69, 8182.25, 8187.45, 8186.74, 8189.97, 8189.43, 8193.91, 8193.91, 8196.42, 8195.89, 8198.4, 8198.04, 8205.16, 8205.52, 8209.47, 8210.01, 8214.31, 8213.95, 8217.59, 8216.7, 8220.64, 8219.93, 8228.84, 8228.48, 8233.33, 8231.89, 8237.45, 8236.74, 8248.22, 8246.78, 8251.63, 8250.37, 8253.42, 8252.17, 8255.39, 8253.6, 8259.7, 8258.44, 8265.98, 8264.54, 8268.35, 8266.2, 8271.94, 8269.61, 8277.86, 8276.6, 8288.62, 8287.36, 8298.3, 8297.41, 8307.28, 8307.1, 8313.59, 8312.88, 8335.34, 8335.16, 8351.85, 8352.38, 8361.35, 8359.92, 8368.35, 8366.02, 8372.48, 8370.15, 8376.42, 8373.91, 8393.77, 8392.16, 8424.63, 8422.12, 8439.33, 8439.33, 8448.3, 8447.23, 8468.4, 8468.4, 8473.46, 8473.64, 8487.45, 8484.76, 8490.5, 8487.81, 8501.13, 8499.69, 8508.93, 8507.67, 8521.49, 8522.56, EOZ END ! BASE CURVE: GROH, u tapescan.txt ! 0.89673 1.079666 1907666 ! 0.179199 ! -1.79395 ! -0.358887 ! -0.358887 ! 0.358398 ! 0.179688 ! 0.896973 ! -0.538086 ! -0.358887 ! -0.717773 -1.07666 ! -1.43506 ! -0.717773 ! -0.538574 ! 0 ! -0.538086 ! -0.359375 ! 0.358398 ! 0.538086 ! -0.359375 ! -0.897461 ! -0.717773 ! -0.358398 ! -1.43555 ! -0.716797 ! -1.43555 ! -1.25586 ! -1.25586 ! -1.79395 ! -1.25586 ! -1.43555 ! -2.15332 ! -2.33203 ! -1.25586 ! -1.25586 ! -0.896484 ! -0.179688 ! -0.717773 ! -0.178711 ! 0.538086 ! -1.43457 ! -2.33203 ! -2.33203 ! -2.51172 ! -1.61523 ! -2.51172 ! 0 ! -1.07617 0 ! 0.179688 ! -2.69043 ! -2.69043 ! -1.43555 ! -1.25586 ! 1.07617 OFFSET CURVE: GRAX Tape subfile: 1 216 records... Page 4 • Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 tapescan.txt 10 bytes 132 bytes *** LIS COMMENT RECORD *** 0 !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 09 ]an 2010 above the KOP os 8522 ft MD per Katie Nitzberg with BP Exploration (Alaska), Inc * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub -type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 100 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File start Depth = 7615.000000 Tape File End Depth = 9411.000000 Tape File Level spacing = 0.500000 Tape File Depth units = feet Page 5 **** FILE TRAILER **** Tape subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 1024 tapescan.txt 113 records... 54 bytes 4124 bytes *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw -unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub -type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code Samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 200 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 7616.000000 Tape File End Depth = 9410.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Page 6 0 **** REEL TRAILER **** MWD 10/04/19 BHI 01 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • 0 tapescan.txt **** FILE TRAILER **** Tape subfile: 3 213 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 10/01/04 Tape Subfile 2 is 2948650 01 **** REEL TRAILER **** MWD 10/04/19 BHI 01 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 7615.0000 111.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7615.5000 109.5404 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7700.0000 118.7888 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7800.0000 114.7388 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7900.0000 107.5187 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8000.0000 66.5713 -999.2500 -999.2500 -999.2500 Page 7 tapescan.txt -999.2500 -999.2500 8100.0000 112.5676 26.1708 6.2661 5.7422 8200.0000 86.3556 58.9527 9.0305 9.0154 8300.0000 90.8591 47.1198 22.3463 21.0019 8400.0000 52.9979 62.0450 43.9600 50.3610 8500.0000 77.2160 79.4405 32.7705 34.0230 8600.0000 62.3365 86.0445 12.5778 12.5860 8700.0000 111.9416 44.3518 13.3280 14.6670 8800.0000 89.4715 76.2701 13.2655 12.9207 8900.0000 69.8963 85.7000 22.1207 24.8200 9000.0000 105.8760 90.7730 28.2690 25.8937 9100.0000 67.8525 56.5555 27.3562 35.0426 9200.0000 59.3861 73.6029 15.7390 13.7253 9300.0000 44.5555 79.2139 16.7710 17.1150 9400.0000 -999.2500 128.5416 -999.2500 -999.2500 9411.0000 -999.2500 104.8342 -999.2500 -999.2500 Tape File start Depth = 7615.000000 Tape File End Depth = 9411.000000 Tape File Level spacing = 0.500000 Tape File Depth units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RPD RPS 7616.0000 111.9000 -999.2500 -999.2500 -999.2500 7616.2500 110.9000 -999.2500 -999.2500 -999.2500 Page 8 Ll MUM 8.6891 20.5645 24.7496 20.9921 11.0153 10.7391 12.2329 14.9183 22.0312 15.0051 14.6820 12.9166 -999.2500 -999.2500 RAD -999.2500 -999.2500 6.8688 9.1911 23.2881 36.5127 29.8687 12.8023 12.9420 14.1205 20.1045 34.0576 Paw&61-411 17.1571 17.2290 -999.2500 -999.2500 RAs -999.2500 -999.2500 0 tapescan.txt 7700.0000 118.6000 -999.2500 -999.2500 -999.2500 7800.0000 111.5000 -999.2500 -999.2500 -999.2500 7900.0000 103.3000 -999.2500 -999.2500 -999.2500 8000.0000 70.4000 -999.2500 -999.2500 -999.2500 8100.0000 119.3000 26.0000 6.1540 5.8040 8200.0000 81.1000 58.3000 9.1140 9.1260 8300.0000 93.3000 48.3000 21.9560 20.3140 8400.0000 47.3000 61.0000 44.8410 50.3610 8500.0000 70.2000 81.9000 33.0700 34.6250 8600.0000 59.2000 88.6000 12.4770 12.4540 8700.0000 114.7000 31.0000 13.5870 15.0040 8800.0000 84.5000 73.1000 13.5420 13.3040 8900.0000 70.8000 86.8000 22.1590 24.8200 9000.0000 102.1000 81.8000 28.6870 26.3400 9100.0000 73.2000 69.3000 23.6260 27.1550 9200.0000 62.7000 72.2000 16.2430 13.8990 9300.0000 40.7000 83.8000 16.5920 16.9090 9400.0000 -999.2500 119.7000 -999.2500 -999.2500 9410.0000 -999.2500 103.6000 -999.2500 -999.2500 Tape File Start Depth = 7616.000000 Tape File End Depth = 9410.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Page 9 • -999.2500 -999.2500 -999.2500 -999.2500 6.3840 8.7310 20.6910 24.4370 21.2870 10.9770 10.7430 12.1940 15.0210 21.9280 14.8500 15.7520 12.9730 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6.5090 9.2550 23.5250 35.7750 30.8250 12.8610 13.0510 13.9220 20.2340 34.2910 19.8080 17.7100 17.1730 -999.2500 -999.2500 . 9 0 Tape Subfile 4 is type: LIS tapescan.txt Page 10