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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:Stephen Soroka To:Regg, James B (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Ryan Thompson; Alaska NS - Wells Integrity Subject:Milne Point, Northstar & Point Thompson July MIT"s Date:Thursday, July 31, 2025 1:26:00 PM Attachments:MIT-IA MPU B-24, B-50 7-20-2025.xlsx MIT-IA MPU B-34 07-16-2025.xlsx MIT-IA MPU E-26 07-21-2025.xlsx MIT-IA MPU R-105 7-4-2025.xlsx MIT-IA NS10, NS32 EPA 07-20-2025.xlsx MIT-IA PTU DW-01 7-20-2025.xlsx All – Attached are recently completed MIT’s performed in July for Milne Point, Northstar and Point Thompson. Well PTD# Comment MPU B-24 1960090 Annual EPA MIT-IA MPU B-34 2161390 Annual EPA MIT-IA/Operable Status change MPU B-50 2042520 Annual EPA MIT-IA MPU E-26 2002060 4-Year MIT-IA MPU R-105 2250170 Initial 4-Year MIT-IA NS-10 2001820 Annual EPA MIT-IA NS-32 2031580 Annual EPA MIT-IA PTU DW-01 2142060 Annual EPA MIT-IA Thank you, Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey 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. 1RUWKVWDU16 37' NS-10 2001820 Annual EPA MIT-IA Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001820 Type Inj I Tubing 469 474 469 465 Type Test P Packer TVD 3987 BBL Pump 1.0 IA 464 1738 1696 1685 Interval O Test psi 1500 BBL Return 1.0 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031580 Type Inj I Tubing 1913 1913 1912 1913 Type Test P Packer TVD 4070 BBL Pump 2.2 IA 1731 3500 3463 3456 Interval O Test psi 1500 BBL Return 2.3 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska, LLC Northstar/ NSU/ Northstar Chris Casey 07/19/25 Notes:EPA Class 1 Injection well annual MIT-IA to 1500 psi. Witnessed waived by Kam StJohn. Notes: Notes: Notes: NS-10 NS-32 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:EPA Class 1 Injection well annual MIT-IA to 3500 psi. Witness waived by Kam StJohn. Notes: Notes: Form 10-426 (Revised 01/2017)2025-0719_MIT_Northstar_NS-10 9 9 9 999 9 9 9 9 9 9 -5HJJ NS-10 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: 8/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240807 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 2-72 50029237810000 224016 6/27/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON RBT END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 7/20/2024 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/16/2024 HALLIBURTON MFC MPU E-19A 50029227460100 224010 6/22/2024 HALLIBURTON COILFLAG NS-10 50029229850000 200182 7/18/2024 HALLIBURTON MFC NS-10 50029229850000 200182 7/18/2024 HALLIBURTON TEMP NS-32 50029231790000 203158 7/16/2024 HALLIBURTON MFC NS-32 50029231790000 203158 7/15/2024 HALLIBURTON TEMP PBU H-13A 50029205590100 209044 7/23/2024 HALLIBURTON RBT PBU L-246 50029237650000 223078 7/23/2024 HALLIBURTON IPROF PBU R-26B 50029215470100 210025 7/5/2024 HALLIBURTON RBT PBU R-36 50029225220000 194144 6/21/2024 HALLIBURTON RBT PBU V-216 50029232160000 204130 7/11/2024 HALLIBURTON IPROF PBU V-217 50029233340000 206162 7/11/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39365 T39365 T39365 T39366 T39367 T39368 T39369 T39369 T39370 T39370 T39371 T39372 T39373 T39374 T39375 T39376 NS-10 50029229850000 200182 7/18/2024 HALLIBURTON MFC NS-10 50029229850000 200182 7/18/2024 HALLIBURTON TEMP Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.07 13:19:30 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Darci Horner - (C) To:Regg, James B (OGC); Brooks, Phoebe L (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay Cc:Ryan Thompson; Brenden Swensen; Alaska NS - Milne - Wells Foreman; Alaska NS - Milne - Wellsite Supervisors; Derek Weglin; Alaska NS - Northstar - Field Foreman; Alaska NS - Northstar - Operations Leads; Alaska NS - Environmental Specialist; Chuck Wheat; Amy Peloza; Taylor Wellman; Sara Hannegan; Jess Hall; Matthew Ross; Donald Maxon; Roger Allison; Alaska NS - Milne - Field Operator Leads; Barry Bulot Subject:MIT-IAs for Milne Point, Northstar and Point Thomson Class 1 injection wells (MPB-34, MPB-50, NS-10, NS-32 and PTU DW-1) Date:Friday, August 2, 2024 2:51:56 PM Attachments:MIT NSU NS-10 NS-32 7-23-24.xlsx MIT MPU B-34 B-50 7-29-24.xlsx MIT PTU DW-1 7-17-24.xlsx All, Milne Point wells B-34 (PTD # 2161390), and B-50 (PTD # 2042520) successfully passed MIT- IAs on July 29, 2024. Northstar wells NS-10 (PTD # 2001820) and NS-32 (PTD # 2031580) successfully passed MIT- IAs on July 25, 2024. Also, Point Thomson well DW-1 (PTD# 2142060) successfully passed an MIT on July 17, 2024. All wells are EPA class 1 injection wells requiring annual MITs and were witnessed by EPA personnel. Please call myself or Ryan Thompson (907-564-5005) with any questions. Regards, Darci Horner Technologist Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com 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. 1RUWKVWDU16 37' Northstar wells NS-10 (PTD # 2001820) Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001820 Type Inj I Tubing 815 811 794 780 Type Test P Packer TVD 3987 BBL Pump 4.1 IA 1163 1795 1724 1689 Interval O Test psi 1500 BBL Return 1.3 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031580 Type Inj I Tubing 302 302 302 301 Type Test P Packer TVD 4078 BBL Pump 3.2 IA 1043 1750 1718 1710 Interval O Test psi 1500 BBL Return 1.1 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:EPA Class 1 injection well annual MIT-IA to 1500 psi. AOGCC witness waived by Brian Bixby. Witnessed by EPA's Nick Bruno. Notes: Notes: Hilcorp Alaska, LLC Northstar / NSU / Northstar Barry Bulot 07/25/24 Notes:EPA Class 1 injection well annual MIT-IA to 1500 psi. AOGCC witness waived by Brian Bixby. Witnessed by EPA's Nick Bruno. Notes: Notes: Notes: NS-10 NS-32 Form 10-426 (Revised 01/2017)2024-0723_MIT_Northstar_NS-10 9 9 9 9 9 9999 9 -5HJJ NS-10 1 Regg, James B (OGC) From:Darci Horner - (C) <dhorner@hilcorp.com> Sent:Tuesday, July 25, 2023 3:53 PM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay Cc:Ryan Thompson; Brian Glasheen; Brenden Swensen; Alaska NS - Milne - Wells Foreman; Alaska NS - Milne - Wellsite Supervisors; Derek Weglin; Josh McNeal; Alaska NS - Northstar - Field Foreman; Alaska NS - Northstar - Operations Leads; Alaska NS - Environmental Specialist; Chuck Wheat; apeloza; Taylor Wellman; Sara Hannegan; Jess Hall - (C); Matthew Ross; Donald Maxon Subject:MIT-IAs for Milne Point Class 1 injection wells B-24, B-34 and B-50 as well as Northstar Class 1 wells NS-10 and NS-32 Attachments:MIT MPU B-24 07-20-23.xlsx; MIT MPU B-34 and B-50 07-19-23.xlsx; MIT-IA NS-10 and NS-32 7-23-2023.xlsx All, Milne Point wells B‐24 (PTD # 1960090), B‐34 (PTD # 2161390), and B‐50 (PTD # 2042520) successfully passed MIT‐IAs on July 20, and 19, 2023, respecƟvely. Northstar wells NS‐10 (PTD # 2001820) and NS‐32 (PTD # 2031580) also successfully passed MIT‐IAs on July 23, 2023. Please note that EPA indicated in 2021 the required test pressure for the Northstar wells has been reduced from 3500 psi to 1500 psi. All wells are class 1 injecƟon wells requiring annual MITs. Please call myself or Ryan Thompson (907‐301‐1240) with any quesƟons. Regards, Darci Horner Technologist Alaska Islands Team Office: (907) 777‐8406 Cell: (907) 227‐3036 Email: dhorner@hilcorp.com 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. 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. Northstar NS-10 PTD 2001820 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2001820 Type Inj I Tubing 437 438 438 436 Type Test P Packer TVD 3,987'BBL Pump 0.9 IA 729 1982 1914 1903 Interval O Test psi 1500 BBL Return 0.8 OA 3 4 3 3 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2031580 Type Inj I Tubing 486 473 467 465 Type Test P Packer TVD 4,078'BBL Pump 1.2 IA 197 1872 1791 1756 Interval O Test psi 1500 BBL Return 1.1 OA 8 7 7 7 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Annual Class 1 injection well MIT-IA to 1500 psi. AOGCC witness waived due to EPA witness. Notes: Hilcorp Alaska, LLC Northstar / NSU / Northstar Donnie Maxon 07/23/23 Notes: Notes: Notes: Notes: NS-10 NS-32 Notes:Annual Class 1 injection well MIT-IA to 1500 psi. AOGCC witness waived due to EPA witness. Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Form 10-426 (Revised 01/2017)2023-0723_MIT_Northstar_NS-10 J. Regg; 10/12/2023 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 WFL-NS-10 500292298500 200182 8/18/2022 Halliburton CH TMD3D 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 NS-10 50029229850000 200182 7/23/2022 Halliburton CALIPER + Report Kayla Junke Digitally signed by Kayla Junke Date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ůů͕ DŝůŶĞWŽŝŶƚǁĞůůƐͲϮϰ;WdηϭϵϲϬϬϵϬͿ͕Ͳϯϰ;WdηϮϭϲϭϯϵϬͿ͕ĂŶĚͲϱϬ;WdηϮϬϰϮϱϮϬͿƐƵĐĐĞƐƐĨƵůůLJƉĂƐƐĞĚD/dͲ/Ɛ ŽŶ:ƵůLJϭϵ͕ϮϬĂŶĚϮϭ͕ϮϬϮϮ͕ƌĞƐƉĞĐƚŝǀĞůLJ͘ EŽƌƚŚƐƚĂƌǁĞůůƐE^ͲϭϬ;WdηϮϬϬϭϴϮϬͿĂŶĚE^ͲϯϮ;WdηϮϬϯϭϱϴϬͿĂůƐŽƐƵĐĐĞƐƐĨƵůůLJƉĂƐƐĞĚD/dͲ/ƐŽŶ:ƵůLJϭϵ͕ϮϬϮϮ͘ WůĞĂƐĞŶŽƚĞƚŚĂƚ WŝŶĚŝĐĂƚĞĚůĂƐƚLJĞĂƌƚŚĞƌĞƋƵŝƌĞĚƚĞƐƚƉƌĞƐƐƵƌĞĨŽƌƚŚĞEŽƌƚŚƐƚĂƌǁĞůůƐŚĂƐďĞĞŶƌĞĚƵĐĞĚĨƌŽŵϯϱϬϬ ƉƐŝƚŽϭϱϬϬƉƐŝ͘ ůůǁĞůůƐĂƌĞĐůĂƐƐϭŝŶũĞĐƚŝŽŶǁĞůůƐƌĞƋƵŝƌŝŶŐĂŶŶƵĂůD/dƐ͘ WůĞĂƐĞĐĂůůŵLJƐĞůĨŽƌ:ĞƌŝŵŝĂŚ'ĂůůŽǁĂLJ;ϵϬϳͲϱϲϰͲϱϬϬϱͿǁŝƚŚĂŶLJƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ DarciHorner Technologist Office:(907)777Ǧ8406 Cell:(907)227Ǧ3036 Email:dhorner@hilcorp.com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ubmit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001820 Type Inj N Tubing 576 577 577 577 Type Test P Packer TVD 3,987'BBL Pump 4.6 IA 1226 2004 1976 1969 Interval O Test psi 1500 BBL Return 1.2 OA 3.2 3.39 3.4 3.39 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031580 Type Inj W Tubing 1677 1912 1977 1932 Type Test P Packer TVD 4,078'BBL Pump 1.7 IA 36 2610 2433 2367 Interval O Test psi 1500 BBL Return 2.0 OA 8.6 8.9 9 9 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanicall Integrityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov NS-32 Notes:Annual Class 1 injection well MIT-IA to 1500 psi. Ryan Gross (EPA) witnessed via video conference. Notes: Annual Class 1 injection well MIT-IA to 1500 psi. Ryan Gross (EPA) witnessed via video conference. Notes: Hilcorp Alaska, LLC Northstar / NSU / Northstar Anthony Mangano/Banan Tarr 07/19/22 Notes: Notes: Notes: Notes: NS-10 Form 10-426 (Revised 01/2017)2022-0719_MIT_Northstar_2wells 9 9 9 9 9 9 9 - 5HJJ Annual Class 1 injection well MIT-IA NS-10 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/30/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NS-10 (200-182) Water Flow Record 08/02/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. PTD: 2001820 E-Set: 34148 Received by the AOGCC 10/30/2020 Abby Bell 10/30/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/30/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NS-10 (PTD 200-182) Multi Finger Caliper Log 07/30/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. PTD: 2001820 E-Set: 34147 Received by the AOGCC 10/30/2020 Abby Bell 10/30/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/22/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NS-10 (200-182) Multi Finger Caliper Log 08/14/2018 ANALYSIS FIELD DATA Please include current contact information if different from above. Received by the AOGCC 09/22/2020 PTD: 2001820 E-Set: 33974 Abby Bell 09/22/2020 mor-kLsbv k,15 — I o Regg, James B (CED) P7-6 ZQV/6zo From: Darci Horner - (C) <dhorner@hilcorp.com> / Sent: Monday, July 15, 2019 10:52 AM 241 6? To: Regg, James B (CED); Brooks, Phoebe L (CED); DOA 11CC Prudhoe Bay; Wallace, Chris D (CED) Cc: Wyatt Rivard Subject: Northstar EPA Class 1 Disposal Well MITs 2019 Attachments: MIT NSU NS -10 and NS -32 combined 7-12-2019.xlsx All, Northstar Class 1 disposal wells NS -10 (PTD # 2001820) and NS -32 (PTD # 2031580) successfully passed annual EPA witnessed MIT-IAs on July 12, 2019. Please call myself or Wyatt Rivard (777-8547) with any questions. Regards, Darci Horner (Northern Solutions) Technologist H ilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-84o6 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication maybe legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: an.re00litalaska.0ov. AOGCC. Insoectpre®alaska. oov: Phoebe.brooksilitalaskadov OPERATOR: Hitcorp Alaska, LLC FIELD / UNIT I PAD: Northstar I NSU / Northstar DATE: 07/12/19 OPERATOR REP: Ban Degreffanreid AOG00 REP: Jeff Janes waived witness chits wallacetillalaskagov Well NS -10 P=Pressure Teat Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO 2001820" TYPE IN N Tubing 1920 - 1886 - 1857 - IWO - Type Test P Packer ND 3,137• BBL Pump 16 IA 920 - 3522• 3459 - 3441 Interval 0 Test psi 3500 BBL Return 1.8 OA 0 0 0 0 Result P Notes: Annual Class 1 Injection Well EPA witnessed MIT -IA to 3500 psi. —Well NS -32 Pressures: Pretest Initial 15 Min, W Min. 45 Min. 60 Min. PTD 2031580 Type Inj W Tubing 18]9 1892 18]9 1891 Type Test P Packer ND 4070' BBLPump 2.0 IA ]60 3502 3439 3426 Interval 0 Test psi 3500 BBL Return 1 2.0 1 OA 0 1 0 0 0 Result P Notes: EPA Cie.. l inleclion well MIT -IA to 3500 psi. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer NO BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTDType Tubing Type Test Packer TVD U, m, BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing IType Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Nola.: TYPE INJ Codes W=Water G=Gas s=slum, I=indurr iWarewater N=red I'e ing TYPE TEST Codes INTERVAL Codes P=Pressure Teat 1=1nIYal Test 0= Other Ideanibe In Noreri 4=Four Year Cycle V = Repus. by Variance 0 = Other (describe in noted Form 10426 (Revised 01/201]) MniriO712 MIT N®MWr_NS10 Na -32 Result Codes P=P... F=Fall 1=lnwnduaWe Zbcyk%Z Post office Box 244027 Anchorage, AK 995249524 3800 Centerpoint Or Suite 1400 Hileorp Alaska, LLC Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8560 March 18, 2019 Mr. Edward J. Kowalski RECEIVED Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency MAR 2 7 2019 1200 Sixth Avenue Seattle, WA 98101 AOGCC Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 RE: Mechanical Integrity Test Notifications Northstar Class 1 Iniection Wells, UIC Permit AK -1I002 -B, General Wastewater, Permit No. 2016DB00I -0020 Milne Point Injection Well UIC Permit AK -1I005 -B General Wastewater, Permit No. 2016DB001-0001 Libertv Class 1 Iniection Well, UIC Permit AK -1I013 -A General Wastewater, Permit No. 2016DB001-0025 Dear Sirs: Hilcorp Alaska, LLC (Hilcorp) respectfully submits the following notifications: 1) the annual Mechanical Integrity Test (MIT) and fluid movement tests that are required every two years at the Northstar NS 10 and NS32, Class 1 wells to meet the annual permit requirement in UIC Permit AK -1I002-13; 2) the annual MIT and fluid movement logs that are required every three years at the Milne Point Class I wells, MPB-50, MPB-24 and MPB-34 to meet the permit requirement in UIC Permit AK -1I005 -B; 3) the MIT and fluid movement test that is required at the Liberty Class 1 well to meet the permit requirement in UIC Permit AK -1I013 -A. Mechanical Integrity Test Notification March 18, 2019 Page 2 of 2 By this letter Hilcorp is providing the written notification required by the aforementioned permits. In addition, Hilcorp staff will be coordinating the timeframes for these MITs with Mr. Ryan Gross of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA inspector, so that multiple tests of Class 1 wells can be witnessed in one trip to the North Slope. A summary of the proposed annual testing is presented in the attached table. The fluid movement test procedures that require EPA approval will be sent under separate cover or by email. If you have any questions or require additional information please call me at 907-782-7431, or via e-mail at dheebner@hilcorp.com. Sincerely, Deborah Heebner North Slope Environmental Specialist HILCORP ALASKA, LLC Attachment cc: Ryan Gross, EPA Region 10 U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Evan Osborne, EPA Region 10 U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Kyle Monkelien, BSEE Bureau of Safety And Environmental Enforcement Alaska OCS Region 3801 Centerpoint Drive Ste 500 Anchorage, AK 99503 Jason Seltisch Proposed Schedule for 2019 Mechanical Integrity Testing Class I Well MIT Deadline Proposed MIT test Flexibility in Fluid Movement (s) (May be extended date test date? Logs Planned up to 3 months after MIT? with Director approval) Milne Point By August 9, Approximately July Coordinate with No Fluid movement MPB-24 2019 15 -20, 2019. Northstar test logs are planned as date. they are required for MPB-24 every three years. Previously done on 7/9/2017. Milne Point By August 8, Approximately July Coordinate with Fluid movement MPB-34 2019 15 -20, 2019. Northstar test logs are planned as date. they are required for MPB-34 every three years. Previously done on 4/9/2017. Milne Point By August 9, Approximately July Coordinate with No Fluid movement MPB-50 2019 15 -20, 2019. Northstar test logs are planned as date. they are required for MPB-50 every three years. Previously done on 7/712017. Northstar By August 12, Approximately July Coordinate with No Fluid movement NS10 2019 11 -15, 2019. Milne test date. logs are planned as they are required at NS10 every two years. Previously done on 8/13/2018. Northstar By August 13, Approximately July Coordinate with No Fluid movement NS32 2019 11-15,2019 Milne test date. logs are planned as they are required at NS32 every two years. Previously done on 8/14/2018. Liberty CRI N/A The Liberty CRI well All logs required to Well will not be drilled in complete the well 2019. would be scheduled with the MIT. l�1 24)(eW Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday,July 31, 2017 5:21 PM 1--4/4- 011/ To: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Alaska NS - Northstar- Operations Leads; Alaska NS - Milner Wellsite Supervisors Subject: EPA Class 1 Disposal Well MITs 2017 Attachments: MIT NSU NS-10 7-6-17.xlsx; MIT NSU NS-32 7-6-17.xlsx; MIT MPU B-24 7-6-17.xlsx; MIT MPU B-50 7-7-17.xlsx All, The following Class 1 Disposal Wells had passing annual 2017 EPA witnessed MIT-lAs. Please note that the newly completed Class 1 disposal well MPB-34 (PTD#2161640)was previously MIT'd in May 2017.The MIT forms are attached for reference. Well Field PTD MPB-50 Milne Point 2042520 MPB-24 Milne Point 1960090 NS-10 North Star 2001820 NS-32 North Star 2031580 Thank You, Wyatt Rivard Well Integrity Engineer 1-Iilcorp Alaska, LLC: S NED �� 2017 0: (9O7) 777-85471C: (509)670-8001 I wrivardithilcorp.com 3800 Centerpoint Drive,Suite 1400 ( Anchorage,AK 99503 1 • • 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rerigCctalaska.pov: AOGCC.Inspectorsl alaska.00v phoebe.brookst0talaska.gov chris.wallacel lalaska.00v . OPERATOR: Hilcorp Alaska,LLC I ✓I'(i 1 FIELD/UNIT/PAD: Northstar/NSU/Northstar DATE: 07/06/17 • OPERATOR REP: Bart Degraffenreid AOGCC REP: Well NS-10 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001820 Type Inj N Tubing 494 501 -- 499 - 497 . Type Test P Packer TVD 3,987. - BBL Pump 2.8 - IA 30 3560 " 3440- 3400 Interval 0 • Test psi 3500 - BBL Return 2.8 " OA 11 - 20 " 20- 20- Result P ✓ Notes: Annual Class 1 Injection Well EPA witnessed MIT-IA to 3500 psi.Witness waived by AOGCC's Brian Bixby.Well left shut-in during testing. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL ReturnOA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures:' Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IAInterval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result • Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing _ Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result • Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result • Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test - P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT NSU NS-10 7-6-17 • Loo-‘g-L. Hilcor AlaskLLC Post Office Box 244027 1> a> Anchorage,AK 99524 3800 Centerpoint Dr %ANS) 1'1 J 3 '$ Suite 1400 CERTIFIED MAIL fG►+ Anchorage,AK 99503 Phone: 907/777-8300 March 12, 2017 Fax: 907/777-8560 Mr. Edward J. Kowalski RECEIVED Director, Office of Compliance and Enforcement MAR 2 S 71117 U.S. Environmental Protection Agency 1200 Sixth Avenue A,OGGC Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 RE: Mechanical Integrity Test Notifications Northstar Class 1 Injection Wells, UIC Permit AK-1I002-B, General Wastewater, Permit No. 2005DB001-0020 Milne Point Injection Well, UIC Permit AK-1I005-B, General Wastewater, Permit No. 2005DB001-0001 Liberty Class 1 Infection Well. UIC Permit AK-1I013-A. General Wastewater. Permit No. 2005DB001-0025 Dear Sirs: Hilcorp Alaska, LLC (Hilcorp)respectfully submits the following notifications: 1) The annual Mechanical Integrity Test (MIT) and fluid movement tests that are required every two years at the Northstar NS 10 and NS32, Class 1 wells to meet the annual permit requirement in UIC Permit AK-1I002-B; 2) The annual MIT and fluid movement logs that are required every three years at the Milne Point Class 1 wells, MPB-50, MPB-24 and MPB-34 to meet the permit requirement in UIC Permit AK-1I005-B; 3) The MIT and fluid movement test that is required at the Liberty Class 1 well to meet the permit requirement in UIC Permit AK-1I013-A. • Mechanical IntegTest Notification March 12,2017 Page 2 of 2 By this letter Hilcorp is providing the written notification required by the aforementioned permits. In addition, Hilcorp staff will be coordinating the timeframes for these MITs with Mr. Evan Osborne of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA inspector, so that multiple tests of Class 1 wells can be witnessed in one trip to the North Slope. A summary of the proposed annual testing is presented in the attached table. The fluid movement test procedures that require EPA approval will be sent under separate cover or by email. If you have any questions or require additional information please call me at 907-782- 7431, or via e-mail at dheebner@hilcorp.com. Sincerely, Q '' -Lt 4Cfc<5.6W— Deborah Heebner North Slope Environmental Specialist HILCORP ALASKA, LLC Attachment cc: Evan Osborne, EPA Region 10 U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Kyle Monkelien, BSEE Bureau of Safety and Environmental Enforcement Alaska OCS Region 3801 Centerpoint Drive Ste 500 Anchorage, AK 99503 Kevin Pendergast, BSEE Bureau of Safety and Environmental Enforcement Alaska OCS Region 3801 Centerpoint Drive Ste 500 Anchorage,AK 99503 Timothy Mayers, EPA Region 10 Jason Selitsch,Denali Environmental • I • Proposed Schedule for 2017 Mechanical Integrity Testing Class I Well (s) MIT Proposed MIT test Flexibility in Fluid Movement Deadline date test date? Logs Planned after MIT? Northstar NS10 By July 6, Approximately July 5- Coordinate with No Fluid 2017 10,2017. Milne test date. movement logs are planned as (May be they are required extended up at NS10 every to 3 months two years. with Director Previously done approval) on 7/7/2016. Northstar NS32 By July 8, Approximately July 5 Coordinate with No Fluid 2017 10,2017 Milne test date. movement logs are planned as (May be they are required extended up at NS32 every to 3 months two years. with Director Previously done approval) on 7/9/2016. Milne Point By July 10, Approximately July 10- Coordinate with Fluid movement MPB-24 2017 15, 2017. Northstar test logs are planned date. even though logs were previously done on 7/23/2015. This will get MPB-24 on the same schedule as MPB-50. Milne Point By July 10, Following the Well's Coordinate with The Mechanical MPB-34 2017 Completion Evan Osborne Integrity Testing and Jason and Fluid Selitsch with Movement Logs EPA will be done following the Well's completion Milne Point By July 10, Approximately July 10- Coordinate with Fluid movement MPB-50 2017 15, 2017. Northstar test logs are planned date. as they are required for MPB- 50 every three years. Previously done on 7/24/2014. Liberty CRI Well N/A The Liberty CRI well All logs required will not be drilled in to complete the 2017. well would be scheduled with the MIT. Z0d - \`6Z tE FEB 29 2016 Hilcorp Alaska, LLC �A0bCC, Post Office Box 244027 Anchorage,AK 99524 3800 Centerpoint Dr Suite 1400 CERTIFIED Anchorage,AK 99503 MAIL#7 014 0150 0000 6324 9220 Phone:907/777-8300 February 25, 2016 Fax: 907/777 8560 Mr. Edward J.Kowalski Director, Office of Compliance and Enforcement U.S.Environmental Protection Agency g Y 1200 Sixth Avenue Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage,AK 99501 RE: Mechanical Integrity Test Notifications Northstar Class 1 Injection Wells, UIC Permit AK-1I002-B, General Wastewater, Permit No. 2005DB001-0020 Milne Point Injection Well, UIC Permit AK-1I005-B, General Wastewater, Permit No. 2005DB001-0001 Liberty Class 1 Injection Well, UIC Permit AK-1I013-A, General Wastewater, Permit No. 2005DB001-0025 Dear Sirs: Hilcorp Alaska, LLC (Hilcorp) respectfully submits the following notifications: 1) the annual Mechanical Integrity Test (MIT) and fluid movement tests that are required every two years at the Northstar NS 10 and NS32, Class 1 wells to meet the annual permit requirement in UIC Permit AK-1I002-B; 2) the MIT that is required every year at the Milne Point Class 1 wells, MPB-50 and MPB-24 to meet the permit requirement in UIC Permit AK-1I005-B; 3) the MIT and fluid movement test that is required at the Liberty Class 1 well to meet the permit requirement in UIC Permit AK-1I013-A. • • Mechanical Integrity Test Notification February 25,2016 Page 2 of 2 By this letter Hilcorp is providing the written notification required by the aforementioned permits. In addition, Hilcorp staff will be coordinating the timeframes for these MITs with Mr. Thor Cutler of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA inspector, so that multiple tests of Class 1 wells can be witnessed in one trip to the North Slope. A summary of the proposed annual testing is presented in the attached table. The fluid movement test procedures that require EPA approval will be sent under separate cover or by email. If you have any questions or require additional information please call me at 907-782- 7431, or via e-mail at dheebner@hilcorp.com. Sincerely, Deborah Heebner North Slope Environmental Specialist HILCORP ALASKA, LLC Attachment cc: Thor Cutler,EPA Region 10 Kyle Monkelien, BSEE Kevin Pendergast, BSEE Jason Seltisch ` • • Proposed Schedule for 2016 Mechanical Integrity Testing Class I Well (s) MIT Proposed MT test Flexibility in Fluid Deadline date test date? Movement Logs Planned after MIT? Milne Point By July 20, Approximately July 10 - Coordinate with No, fluid MPB-24 2016 15, 2016. Northstar test movement logs date. were done in 2015 and are only required at Milne Point every three years. Milne Point By July 20, Approximately July 10- Coordinate with No, fluid MPB-50 2016 15, 2016. Northstar test movement logs date. were done in 2014 and are only required at Milne Point every three years. Northstar NS10 By July 24, Approximately July 5- Coordinate with Fluid movement 2016 10, 2016. Milne test date. logs are planned as they are (May be required at NS10 extended up every two years. to 3 months Previously done with Director in 2014. approval) Northstar NS32 By July 25, Approximately July 5- Coordinate with Fluid movement 2016 10, 2016 Milne test date. logs are planned as they are (May be required at NS32 extended up every two years. to 3 months Previously done with Director in 2014. approval) Liberty CRI Well N/A The Liberty CRI well All logs required will not be drilled in to complete the 2016. well would be scheduled with the MIT. 1-4/16]-4-- MS-lo . Pt Zoo zo Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> qt 6/411C Sent: Thursday, July 30, 2015 4:59 PM To: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Alaska NS - Northstar- Operations Leads; Alaska NS - Milne - Wellsite Supervisors; Taylor Wellman; Stan Porhola Subject: EPA Class 1 Disposal Well MITs Attachments: B-50 EPA MIT Pressure vs Temperature 7-20-15.xls; HAK EPA Class 1 Disposal Well MITs 2015.zip All, The following Class 1 Disposal Wells had passing EPA witnessed MIT-lAs. Please note that MPB-50 (PTD#2042520) demonstrated difficult stabilization due to-10degF wellhead temperature swings while injecting at"29000BWPD.Two attempts were required before operations and EPA inspectors were satisfied with stabilization.The attached plot shows the MPB-50 Pressure vs Temperature correlation during the second, passing,test. The MIT forms are attached for reference. Well Field PTD MPB-50 Milne Point 2042520 MPB-24 Milne Point 1960090 NS-10 North Star 2001820 NS 32 North Star 2031580 SCANNED AUG 2 4 2015 Thank You, Wyatt Rivard I Well Integrity Engineer t): (it)7j 777-8547 I C:(509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 i averts Mas&.,L1 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to Jim reqs@alaska qov doa aoocc prudhoe bay(aDalaska goy phoebe brooks[Dalaska.gov n CC/)'q I!S OPERATOR: Hilcorp Alaska LLC I FIELD/UNIT/PAD: Northstar/NSU/NS DATE: 07/24/15 OPERATOR REP: Keith Crowder AOGCC REP: Waived Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS-10 - _ Type In) N " _ TVD " 3,987 Tubing 394 -396 - 395 "395 Interval 0 P T.D 2001820 - Type test P Test psi " 1500 Casing 1010 3,544 -3,436 '3,411 _ P/F P Notes: Yearly Class 1 MIT-IA to 3500 psi.Witnessed by OA 0 0 0 0 / Thor Cutler and Jason Selisch 1 bbl to pressure up.Waived by AOGCC John Cnsp Well not injecting during test. Well Type Inj TVD , _ Tubing Interval P T D Type test Test psi Casing, P/F Notes: OA Well Type Inj TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval - - P T D Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Infecting A=Temperature Anomaly Survey 0=Other(descnbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 02/2012) MIT NSU NS-10 7-24-15 xis coREC • EIV ,'' 7,4 APR 1 6 2015 t Post Office Box 244027 tallilcorp Alaska,LLC AOGCC Anchorage,AK 99524 AOGCC 3800 Centerpoint Dr Suite 1400 CERTIFIED MAIL#7014 0150 0000 6239 5461 Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777-8560 April 13, 2015 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 tv Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 SCANNED 4 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 RE: Mechanical Integrity Test Notifications Northstar Class 1 Injection Wells, UIC Permit AK-11002-B, General Wastewater, Permit No. 2005DB001-0020 Milne Point Injection Well, UIC Permit AK-1I005-B, General Wastewater, Permit No. 2005DB001-0001 Liberty Class 1 Injection Well, UIC Permit AK-1I013-A, General Wastewater, Permit No. 2005DB001-0025 Dear Sirs: Hilcorp Alaska, LLC (Hilcorp) respectfully submits the following notifications: 1) the annual Mechanical Integrity Test (MIT)that is required every year at the Northstar NS 10 and NS32, Class 1 wells to meet the annual permit requirement in UIC Permit AK- 1I002-B; 2)the MIT that is required every year at the Milne Point Class 1 well, MPB-50 to meet the permit requirement in UIC Permit AK-1I005-B; 3) the MIT and fluid movement test that is required at the Liberty Class 1 well to meet the permit requirement in UIC Permit AK-II013-A. • Mechanical Integrity Test Notification April 13,2015 Page 2 of 2 R4 By this letter Hilcorp is providing the written notification required by the aforementioned permits. In addition, Hilcorp staff will be coordinating the timeframes for these MITs with Mr. Thor Cutler of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA inspector, so that multiple tests of Class 1 wells can be witnessed in one trip to the North Slope. A summary of the proposed annual testing is presented in the attached table. If you have any questions or require additional information please call me at 907-777- 8452, or via e-mail at d_h_eebner@hil_corp.com. Sincerely, 4 4 44'W-- Deborah Heebner Environmental Specialist HILCORP ALASKA, LLC Attachment cc: Thor Cutler, EPA Region 10 • •~ • Proposed Schedule for 2015 Mechanical IntegrityTesting Class I Well (s) MIT Proposed MIT test Flexibility in Fluid Deadline date test date? Movement Logs Planned after MIT? Milne Point By July 28, Approximately July 22- Coordinate with Fluid movement MPB-50 2015 25, 2015. Northstar test logs were done date. in 2014 and are only required at Milne Point every three years. Northstar NS10 By July 28, Approximately July 25- Coordinate with Fluid movement 2015 29, 2015. Milne test date. logs were done in 2014 and are (May be only required at extended up NS10 every two to 3 months years. with Director approval) Northstar NS32 By July 28, Approximately July 25- Coordinate with Fluid movement I 2015 29, 2015 I Milne test date. logs were done in 2014 and are (May be only required at extended up NS32 every two to 3 months years. with Director approval) Liberty CRI Well N/A The Liberty CRI well All logs required will not be drilled in to complete the 2015. well would be scheduled with the MIT. XHVZE Inj je Project Well History File Cml' Page This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C'~,.-~ -(~ ~ c:~ Well History File Identifier Organizing ~o,,~i [] RESCAN '/Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: D IG~.~¢rTA ~ Diskettes, No. J [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYLONDY OVERSIZED (Scannable) [] P~aps: Other items scannable by large scanner [] Other Project Proofing BY; BEVERLY ROBIN VINCENT SHERYL~~WINDY Scanning Preparation .~' x 30 = I~---~+ BY: BEVERLY ROBIN VINCENT SI'"tERYL~,WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON~ PAGE BASIS ~ - X' DUE TO QUALITY, G~YSCALE OR COLOR IMAGES ) NO NO I I I RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd Immem. 200-(1'2 bp • 21�S�3 Date: 8/30/2012 Transmittal Number: 03 NeEivED BPXA WELL DATA TRANSMITTAL SEP 0 4 2012 AOGCC Enclosed are the materials listed below: If you have any questions, please contact Analisa Steger @ 564 -5439 Delivery Contents Top Bottom SW Name Date Company Run Depth Depth Description Schlumberger Water Flow Injection Log Press/Temp /CCL /GR NS32 NS32 07/26/2012 BPXA 1 3850 ft. 8050 ft. 07/26/2012 Schlumberger Water Flow Injection Log Press/Temp /CCL/GR NS10 NS10 07/27/2012 BPXA 1 4800 ft. 7950 ft. 07/27/2012 114- Please Sign and Return one copy of this transmittal. Thank You, Analisa Steger Petrotechnical Data Center ��1� SCANNED JU L AOGCC Christine Shartzer Murphy Exploration Ignacio Herrera DNR Corazon Manaois Bureau of Ocean Energy Mgt, Reg and Enforcement Kyle Monkelien Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519 -6612 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Wednesday, August 01, 2012 7:24 PM / � To: Regg, James B (DOA); Brooks, Phoebe L (DOA) ! 6 W ill i Cc: AK, D &C Well Integrity Coordinator Subject: July 2012 AOGCC MIT Forms Attachments: July 2012 MIT Forms.zip Jim, Phoebe, SCANNED MAY 0 7 2013 Please find attached MIT forms for July 2012. Sent Previously L -218 (PTD #2051190) sent 7/9/2012 04 -11A (PTD #1931580) sent 7/17/2012 S -112 (PTD #2021350) sent with reclassification notice Enclosed in .zip file END 1- 41/0 -23 (PTD #1870320) 3 -1 . - I ' I • 2032160) NS10 (PTD #2001820) EPA i Hesse C1Q5 L wet( NS32 (PTD #20311580)'b�t nessed L5 -29 (PTD #1870450) MPB -25 (PTD # 1972330) MPB -50 (PTD #2042520) EPA Witnessed MPC -25A (PTD # 1960210) MPC -42 (PTD #2040280) B -31 (PTD #1910460) 04 -09 (PTD #1760300) Corrected packer depth (original sent 7/30) 04 -13 (PTD #1780310) Corrected packer depth (original sent 7/30) 04 -350 (PTD #2111060) 11 -02 (PTD #1811280) 17 -15A (PTD #1991310) E -100 (PTD #1971880) GC -2E (PTD #1970180) L -111 ( PTD #2020300) LPC -01 (PTD #1860480) V -220 (PTD #2080200) — well is currently on gas and was during test, inspector may have been told it was on water Y -03A (PTD # 2042350) secured for drill by on Y -19 Y -07A (PTD #2071050) Please let me know if I can be of further assistance. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIlntegrityCoordinator (c�BP.com 1 . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg (alaska.gov; doa. aoacc.prudhoe.bavaalaska.gov; phoebe.brooks @alaska.aov; tom.maunde OPERATOR: BP Exploration (Alaska), Inc. I l e> F � ( FIELD / UNIT / PAD: ACT / North Start / NS ( 7 ( DATE: 07/26/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NS10 " Type lnj. W TVD ' 3,987' Tubing 2016 2000 2027 ' 2045' Interval 0 P.T.D. 2001820 - Type test P _ Test psi - 3500 Casing 82 - 3570' 3420 ' 3425 ' P/F P ✓ Notes: OW - Annual EPA MIT- IA/waterflow logging OA 80 , 80 ' 80 - 80 -- Ussed 3 bbl diesel to increase IAP to test pressure. Well NS32 Type lnj. W TVD 4,070' Tubing 1,153 1,053 1,018 1,091 Interval 0 P.T.D. 2031580 Type test P Test psi 3500 Casing 48 3,560 3,486 3,457 P/F P Notes: DW - Annual EPA MIT- IA/waterfow logging OA 0 0 0 0 Ussed 3.6 bbl diesel to increase IAP to test ressure. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Dnlling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Vanance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT ACT NS10 & NS32 07 - 25 - 12 • • bp Date: 09 -09 -2011 I Transmittal Number: 93209 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Nita Summerhays at (907)564 -4035 Delivery Contents Top Bottom SW Name Date Company Run Depth Depth Description WATER FLOW INJECTION NS32 07 -29 -2011 BPXA 1 3700 8123 LOG - PAPER AND CD WATER FLOW INJECTION 411 t NS10 07 -29 -2011 BPXA 1 4780 7996.6 LOG - PAPER AND CD I LQ Please Sign and Return one copy of this transmittal. lac Thank You, Nita Summerhays °° ;- 0 S 1' : _ 2.014 Petrotechnical Data Center AOGCC Christine Shartzer Murphy Exploration Ignacio Herrera DNR Corazon Manaois BOEM Doug Chromanski Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519 -6612 ad6 —($01- • • bp Date: 08 -24 -2011 ,, g , ReceNtD Transmittal Number: 93205 I 01 • Sion I, FAS G . VIC BP, , ' ' ' L,,.. , t`qRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Nita Summerhays at (907)564 -4035 Delivery Contents Top Bottom \9 SW Name Date Company Run Depth Depth Description ( MULTI - FINGER CALIPER 3D \ ` NS10' 07 -27 -2011 PDS 11 0 8006 DATA & VIEWER — 1CD ` � MULTI - FINGER CALIPER LOG ,/ NS10 07 -27 -2011 PDS 11 0 8006 RESULTS SUMMARY )0 MULTI- FINGER CALIPER 3D NS32 07 -28 -2011 PDS 8 0 8100 DATA & VIEWER — 1CD MULTI - FINGER CALIPER LOG NS32 07 -28 -2011 PDS 8 0 8100 RESULTS SUMMARY _____ts,I)LL._ 4 Please Sign and Return one copy of this transmittal. Thank You, Nita Summerhays Petrotechnical Data Center ;:dl., ;4,1'i AUC1 .' 2.t.t,i Murphy Exploration Ignacio Herrera BOEM Doug Chromanski DNR Corazon Manaois State of Alaska Christine Shartzer Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519 -6612 02.66- 1$3. I • • I 1111 • S . Memory Multi- Finger Caliper Log Results Summary I Company: BP Exploration (Alaska), Inc. Well: NS -10 Log Date: July 27, 2011 Field: Northstar I Log No.: Run No.: 11593 State: Alaska 11 API No.: 50- 029 - 22985 -00 Pipet Desc.: 4.5 in. 12.6 lb. L -80 TCII / IBT -M Top Log Intvll.: Surface Pipet Use: Tubing & Tubing Stub Bot. Log Intvll.: 8,006 Ft. (MD) I Inspection Type : Corrosion Monitoring Inspection COMMENTS : I This caliper data is tied into the WLEG at 8,006 feet (Driller's Depth). This log was run to assess the condition of the tubing and tubing stub with respect to corrosive and I mechanical damage. The caliper recordings indicate the 4.5 inch tubing and tubing stub appear to be in good to poor condition, with a maximum recorded wall penetration of 54% in a line of pits in joint 131 (5,571 feett). Recorded damage I appears as isolated pitting, with intermittent line of pits and line corrosion. No significant areas of cross - sectional wall loss or I.D. restrictions are recorded. This is the eleventh time a PDS caliper has been run in this well, the eleventh time the 4.5 inch tubing stub has been logged from 4,981 feet to 8,006 feet, and the sixth time the 4.5 inch tubing has been logged from I surface to 4,981 feet. A comparison of the current and previous log (June 12, 2010) indicates little if any increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by-joint basis between the current and previous log is included in this report. I The apparent large decreases in maximum recorded penetrations from surface to —1,500 feet, and from —5,000 feet to —6,200 feet in the included comparison graph appear to be due to the caliper fingers tracking a line of pits differently in the current log than the previous log. Time to Failure Evaluation graphs of both the replaced tubing (surface — 4,981 feet) and the tubing stub (4,981 I feet. — 8,006 feet) are included in this report. These graphs project a failure date range based on corrosion rates calculated from changes in the deepest recorded penetration in the entire well over time. The tubing from surface to 4,981 feet is projected to fail between —.75 years and —7.25 years. The tubing stub (4,981 feet - I 8,006 feet) is projected to fail between today and 9 years. MAXIMUM RECORDED WALL PENETRATIONS: I Line of Pits ( 54 %) Jt. 131 @ 5,571 Ft. (MD) Isolated Pitting (51 %) Jt. 134 @ 5,705 Ft. (MD) Line of Pits ( 47 %) Jt. 145 © 6,147 Ft. (MD) Line of Pits ( 46 %) Jt. 123 @ 5,259 Ft. (MD) I Line Corrosion ( 45 %) Jt. 141 @ 5,986 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: i I No significant areas of cross - sectional wall loss (> 5 %) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: I No significant I.D. restrictions are recorded. I I Field Engineer: T. Thompson Analyst: C. Waldrop Witness: B. Rochien ProActEve Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS,g`memorylog.corn Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I I li ( g / ( ' s_ (Sot NM MN =I= 11•1111011111111 • MN OM M•111111111•11111111111111111111•11••1111111 IM Time to Failure Evaluation BP Exploration (Alaska), Inc. Northstar \ Corrosive Trend: Isolated Pitting, Line of Pits Well : NS -10 4.5" Tubing and Overshot I July 27, 2011 Years Following Most Recent Log 4.5 in. 12.6IbL- 80TCI1 0' -498 1 ( 4,981') 0 5 Wall Thickness = 271 mill 1 1 1 , 1 1 i 260 1 (85° Wall Thickness afetv �.�.,rt 240 -- / 7 / 7 v 220 _ - i y E 200 , / .0 180 I i ez / 9 . 160 V 7 2011 Maximum Recorded Wall Penetration _ y 0.118" = 44% Wall Thickness in Joint 6 (290'). a 140 -NMIIIIIII 10- July -08 to 03- Jan -06 (Completion Date) = 34 mpy 20- June -09 to 03- Jan -06 (Completion Date) = 43 mpy 120 12- June -10 to 03- Jan -06 (Completion Date) = 29 mpy •' 27- July -11 to 03- Jan -06 (Completion Date) = 21 mpy O 100 Best Fit= 35 MPY (Bold Dotted Line) Cld = 80 2011 vs 2010 Joint -by -Joint Comparison Approx. Corrosion Rate = 0 MPY Tubing Failure Projected Between -.75 and -7.25 years • 40 20 — I 1 I I I 0 5 10 Years Since Well Completion - im_ Time to Failure Evaluation BP Exploration (Alaska), Inc. • , O Northstar Corrosive Trend: Isolated Pitting, Well : NS -10 Lines of Pits and Line Corrosion 4.5" Tubing Stub below Overshot July 27, 2011 Years Following Most Recent Log 4.5 in. 12.6 lb L -80 IBT -M (4,981' - 8,006') 0 5 Wall Thickness = 271 mill + 1 1 1 1 1 J 1 i i 1 260 (85% Wall irhick1ess Safet. actor) # 240 - -- -- i i 220 — 1 I — f __ _ i 0 200 — � , 0 180 — ..-, r 1,- I I 1 I 1 . 160 — I— 2011 Maximum Wall Penetration in Stub c — 0.145" = 54% Wall Thickness in Joint 131 (5,571'). � 140 — - - -- 10- July -08 to 11- Jan -01 (Completion Date) = 26 mpy 120 — 20- June -09 to 11- Jan-01 (Completion Date) =17 mpy - _ 12- June -10 to 11 -Jan -01 (Completion Date) = 15 mpy O 100 — 27- July -11 to 11- Jan -01 (Completion Date) = 14 mpy u _ cd 80 — Best Fit =18 MPY (Bold Dotted Line) — 2011 vs 2010 Joint -by -Joint Comparison Approx. 0 2 60 Corrosion Rate = 0 MPY 40 — 1 _ I Tubing Failure Projected Between Today and 9 Years 20 - - 1 0 I 1 1 0 5 10 s 15 20 Years Since Well Completion 1 • • I Maximum Recorded Penetration '`S Comparison To Previous I Well: NS -10 Survey Date: J uly 27, 2011 I I Field: Northstar Prev. Date: June 12, 2010 Company: BP Exploration (Alaska), I nc. Tool: UW MFC 40 No. 213121 I Country: USA Tubing: 4.5" 12.6 lb L-80 TCII / IBT-M Overlay Difference 1 Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) 1 0 50 100 150 200 250 -100 -50 0 50 100 0.1 17 1 - 27 11 27 1 _ I 37 wi= 37 47 47_ 1 Sq — 54 64 6 IIA I 74 3 84 84-4 E 94 E 94 I z o o —_ 104 104 114 a 11 # 1 116.8 116.8 NMI 123 - ��e 123 1 133 — 133 143 ®- 143 I 153 153 r 163 163 . 173 — I — 173 183 `� 183 189.4 :9.4 , 1 -89 -45 0 45 89 •July 27, 2011 • June 12, 2010 Approx. Corrosion Rate (mpy) 1 1 1 • • 1 PDS Report Overview Body Region Analysis I Well: NS10 Survey Date: July 27, 2011 Field: Northstar Tool Type: UW MFC 40 No. 213121 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L -80 TCII / IBT-M Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 4.5 in. 12.6 ppf L -80 TCII / IBT -M 3.958 in. 4.5 in. 6.0 in. 6.0 in. I Penetration(% wall) Damage Profile (% wall) I 1 00 Penetration body Metal loss body 0 50 100 80 0 60 ' 40 1 20 1 0 47 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 203) I 97 89 17 0 95 I Damage Configuration ( body ) 200 150 100, + 1 39 1 50 0 ■ I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged (total = 178) 189 I 172 0 6 0 0 Bottom of Survey = 189.4 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in. 12.6 ppf L -80 TCII / IBT -M Well: NS -10 Body Wall: 0.271 in. Field: Northstar Upset Wall: 0.271 in. Company: BP Exploration (Alaska), Inc. I Nominal I.D.: 3.958 in. Country: USA Survey Date: July 27, 2011 I Joint Jt. Depth Peri. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 37 0 0.02 9 0 3.91 Pup I 1 41 U 0.05 18 U 3.89 Shallow Pitting Er 1.1 82 0 0.06 23 0 3.89 Pup Isolated Pitting. ■■ 1.2 102 0.04 0.06 23 0 3.88 Pu Isolated Pitting. ■� 1.3 112 0 0.04 17 0 3.91 Pup Shallow Line of Pits. I 2 116 0.04 0.06 23 0 3.89 Line of Pits. Egg 3 158 0.04 0.07 25 0 3.89 Line of Pits. ■■ 4 199 0 0.10 38 1 3.89 Isolated Pitting. ■ 5 242 0 0.09 31 0 3.90 Isolated Pitting. ■■ I 6 283 0 0.12 44 2 3.90 Line of Pits. Egg 7 324 0.06 0.09 31 1 3.89 Isolated Pitting ■■ 8 366 0 0.06 23 0 3.89 Line of Pits. ■■ 9 408 0 0.07 25 0 3.89 Isolated Pitting. ■ 10 449 0 0.04 17 0 3.90 Shallow Pitting. � I 11 491 U 0.09 31 0 3.89 Isolated Pitting ■■■ 12 533 0 0.08 29 0 3.89 Isolated Pitting. Eli 13 575 0 0.02 8 0 3.89 14 616 0 0.06 23 0 3.88 Isolated Pitting. ■l I 15 658 0 0.04 13 0 3.90 Shallow Pitting. 16 700 0 0.06 21 2 3.90 Isolated Pitting. 17 741 0 0.03 13 1 3.90 Shallow Pitting. ■ 18 783 0 0.03 11 0 3.89 ■ I 19 824 0 0.07 25 0 3.88 Isolated Pitting. ■ 20 866 0 0.03 13 0 3.88 Shallow Pitting. ■i 21 908 0 0.10 38 U 3.89 Isolated Pitting. ■■ 22 949 0 0.07 25 1 3.89 Line of Pits. ■■ I 23 991 0 0.09 33 0 3.89 Isolated Pitting. Egg 1032 0 0.09 34 1 3.91 Isolated Pitting. ■■ 25 1073 0 0.11 41 1 3.91 Isolated Pitting ■■ 26 1115 0 0.11 40 1 3.90 Isolated Pitting. ■■ U 27 1156 0 0.08 29 0 3.90 Isolated Pitting. ■■ 28 1198 0 0.06 23 1 3.90 Isolated Pitting. ■■ 29 1240 0.06 0.06 23 0 3.90 Isolated Pitting. ■■ 30 1281 0 0.10 36 1 3.92 Line of Pits. ■■ 31 1322 0.06 0.09 31 0 3.92 Isolated Pitting. ■■ I 32 1364 0 0.09 34 1 3.92 Isolated Pitting. ■■ 33 1406 0 0.09 32 0 3.91 Line of Pits. ■■ 34 1447 0.07 0.07 26 1 3.92 Isolated Pitting. ■■ 35 1488 U 0.07 25 1 3.91 Isolated Pitting. ■■ I 36 1530 0.07 0.08 30 1 3.91 Line of Pits. ■■ 37 1572 U 0.07 24 1 3.91 Isolated Pitting Igo 38 1614 () 0.07 24 1 3.91 Isolated Pitting. ■■ 39 1656 0 0.11 41 2 3.92 Isolated Pitting. ■■ I 40 1697 0.04 0.07 25 1 3.92 Isolated Pitting. ■■ 41 1739 0 0.06 20 1 3.91 Line of Pits. Egg 42 1781 ().0.5 0.08 29 1 3.92 Line of Pits. ■ 43 1823 0 0.05 19 1 3.92 Shallow Pitting. ■ � 44 1864 0.06 0.07 2 5 1 3.92 Line of Pits. ■■ I 45 1906 0 0.06 23 0 3.90 Isolated Pitting. ■■ 46 1948 0.04 0.07 28 1 3.92 Isolated Pitting. I Penetration Body Metal Loss Body Page 1 1 1 III • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in. 12.6 ppf L -80 TCII / IBT -M Well: NS -10 Body Wall: 0.271 in. Field: Northstar I Upset Wall: 0.271 in. Company: Exploration (Alaska), Inc. Nominal I.D.: 3.958 in. Country: USA .Survey Date: July 27, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss LD• Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 47 1989 0 0.06 23 1 3.92 Isolated Pitting 47.1 2031 0 0.02 9 1 3.92 Pup 47.2 2040 0 0 0 0 3.80 4.5" X Nipple 47.3 2042 0 0.02 9 2 3.93 Pup 48 2052 0 0.07 25 1 3.92 Isolated Pitting. I 49 2094 0.06 0.07 25 1 3.92 Isolated Pitting. ■ 50 2136 0 0.07 26 1 3.93 Isolated Pitting. ■ 51 2177 0 0.06 20 1 3.92 Line of Pits. ■ 52 2219 0.05 0.04 17 0 3.91 Shallow Pitting. ■ I 53 2261 0 0.09 32 1 3.91 Isolated Pitting. ■ 54 2303 0 0.07 25 1 3.92 Isolated Pitting ■ 55 2345 0 0.06 20 1 3.92 Isolated Pitting. ■ 56 2387 0 0.04 15 1 3.91 Shallow Pitting. I 57 2429 0 0.05 18 2 3.91 Shallow Pitting. ■ 58 2471 0 0.06 23 1 3.92 Isolated Pitting. ■ 59 2512 0 0.07 25 1 3.92 Isolated Pitting IN 60 2553 0 0.04 14 3 3.92 Shallow Pitting. • I 61 2596 0 0.04 14 3 3.91 Shallow Pitting. ■ 62 2637 O 0.03 13 2 3.92 Shallow Pitting ■ 63 2679 0 0.04 13 .1 3.92 Shallow Pitting. ■ 64 2721 0 0.05 18 2 3.92 Shallow Pitting. ■ 65 2762 0 0.06 21 2 3.92 , Isolated Pitting. ■ I 66 2804 0 0.04 14 3 3.92 Shallow Pitting. ■ 67 2846 0 0.03 13 2 3.92 Shallow Pitting. ■ 68 2888 0 0.06 23 2 3.92 Line of Pits. ■ 69 2929 0 0.04 15 2 3.92 Shallow Pitting. ■ I 70 2971 0.07 0.04 14 3 3.93 Shallow Pitting. in 71 3013 0 0.04 13 1 3.91 Shallow Pitting ■ 72 3055 0 0.04 15 1 3.92 Shallow Pitting ■ 73 3096 () 0.04 15 1 3.92 Shallow Pitting. ■ I 74 3138 0 0.03 13 2 3.92 Shallow Pitting. ■ 75 3180 0 0.03 11 2 3.92 ■ 76 3221 0 0.04 15 1 3.90 Shallow Pitting. ■ 77 3263 0 0.05 18 2 3.91 Shallow Pitting. ■ 78 3305 0 0.04 13 1 3.92 Shallow Pitting. ■ I 79 3347 0 0.03 11 1 3.92 ■ 80 3389 O 0.04 17 1 3.92 Shallow Pitting ■ 81 3431 0 0.04 13 3 3.91 Shallow Pitting. • 82 3473 0.01 0.04 17 1 3.91 Shallow Pitting. ■ I 83 3515 0 0.04 15 1 3.91 Shallow Pitting. ■ 84 3556 0 0.04 15 2 3.92 Shallow Pitting. ■ 85 3598 0 0.03 10 1 3.91 86 3638 0 0.03 11 1 3.92 I 87 3680 0.03 0.08 30 1 3.91 Isolated Pitting. 88 3721 0 0.04 13 2 3.91 Shallow Pitting • 89 3763 O 0.06 21 1 3.91 Isolated Pitting. ■ 90 3804 0 0.07 24 2 3.92 Isolated Pitting. a 91 3846 0 0.04 14 1 3.91 Shallow Pitting. ■ 92 3888 0 0.03 13 3 3.91 Shallow Line of Pits. • 93 3929 0 0.04 15 1 3.92 Shallow Pitting. Penetdy I Metal Loss ration Bo Page 2 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in. 12.6 ppf L-80 TCII / IBT -M Well: NS -10 Body Wall: 0.271 in. Field: Northstar I Upset Wall: 0.271 in. Company: plo (Alaska), Inc. Nominal I.D.: 3.958 in. Country: BP USA Ex Survey Date: July 27, 201 ration 1 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 94 3970 95 4012 0 0.04 14 1 3.91 Shallow Pitting. 0 0.03 10 1 3.91 96 4054 0 0.03 10 1 3.90 97 4096 0 0.03 11 2 3.91 98 4138 0 0.04 14 2 3.90 Shallow Pitting. ■, 99 4179 0 0.02 9 1 3.91 ■� 100 4221 0.04 0.03 13 1 3.90 Shallow Pitting. • 101 4260 0 0.03 11 1 3.90 • 102 4302 0 0.03 11 1 3.91 • I 103 4344 0 0.03 10 2 3.91 • 104 4386 0.01 0.04 13 2 3.91 Shallow Pitting. 105 442 8 0 0.03 10 1 3.91 • 106 4470 0 0.04 14 2 3.90 Shallow Pitting. • I 107 4512 0 0.03 13 2 3.92 Shallow Pitting. ■ 108 4553 0 0.04 15 2 3.92 Shallow Pitting • 109 4595 0 0.03 11 1 3.92 • 110 4637 0 0.04 15 1 3.91 Shallow Pitting • I 111 4679 0 0.03 11 2 3.92 • 112 4721 0 0.04 17 2 3.91 Shallow Pitting. • ■ 113 4761 0 0.04 13 2 3.91 Shallow Pitting • 114 4803 0 0.04 13 1 3.91 Shallow Pitting. • 115 4845 0 0.04 14 2 3.91 Shallow Line of Pits. • I 116 4887 0 0.04 17 1 3.91 Shallow Pitting. 116.1 4929 0 0.03 10 2 3.92 Pup 116.2 4939 0 0 0 0 3.78 4.5 "X Nipple 116.3 4940 0 0.03 10 1 3.92 Pup ■ I 116.4 4950 116.5 4959 0 0.03 10 1 3.91 Pup ' 0 0 0 0 3.83 7.625" x 4.5" Baker Premium Packer 116.6 4966 0 0.04 13 2 3.91 Pup Shallow Pitting. 116.7 4972 0 0 0 0 3.70 4.5" X N Nipple I 116.8 4974 0 0 0 0 3.88 4.5" Unique Overshot 117 4983 0.03 0.11 39 4 3.90 Top of 4.5" Tubing Stub. Line of Pits. • 117.1 5004 0 0.04 15 2 3.90 Pup Shallow Line of Pits. • 117.2 5013 0 0 0 0 3.83 Baker S-3 Packer 117.3 5018 0.07 0.09 34 4 3.89 Pup Line Corrosion. ■ I 118 5027 0.03 0.07 28 2 3.89 Line of Pits. ■ 119 5069 0 0.06 21 1 3.89 Line of Pits. ■ 120 5110 0 0.06 20 3 3.89 Isolated Pitting. • 121 5152 0 0.07 26 1 3.89 Isolated Pitting. ■ I 122 5192 0.04 0.11 40 2 3.89 Isolated Pitting. • 123 5234 0.05 0.13 46 3 3.89 Line of Pits. ■ 124 5275 0.04 0.06 21 3 3.89 Isolated Pitting. • 125 5316 0 0.07 24 3 3.89 Line of Pits. • I 126 5357 0 0.12 43 2 3.89 Line of Pits. • 127 5398 (1 0.11 39 3 3.90 Isolated Pitting. • 128 5439 (1 0.06 23 1 3.90 Isolated Pitting • 129 5480 (1.04 0.07 28 3 3.90 Line of Pits. • I 130 5521 0 0.11 40 1 3.89 Line of Pits. • 131 5561 0 0.14 54 2 3.89 Line of Pits. • ■ 132 5603 0.04 0.07 25 1 3.89 Isolated Pitting. dy y I Metal Loss Penetration Bo II Page 3 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in. 12.6 ppf L -80 TCII / IBT -M Well: NS -10 Body Wall: 0.271 in. Field: Northstar I Upset Wall: 0.271 in. Company: (Alaska), Inc. Nominal I.D.: 3.958 in. Country: BP USA Survey Date: July 27, 201Exploration 1 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 133 5644 0.04 0.08 30 3 3.88 Line of Pits. aar 134 5685 0.03 0.14 51 2 3.89 Isolated Pitting. aam 135 5726 0.01 0.09 33 3 3.90 Line of Pits. ■a■ 136 5767 0 0.10 37 3 3.89 Line of Pits. aim 137 5808 0 0.12 45 2 3.90 Isolated Pitting. mom I 138 5848 0.04 0.12 42 3 3.90 Isolated Pitting. as 139 5890 0.04 0.07 28 3 3.89 Line of Pits. ■aa 140 5931 0.06 0.10 38 5 3.88 Line of Pits. ■a■ 141 5972 0 0.12 45 3 3.90 Line Corrosion. ■■ I 142 6013 0 0.10 38 3 3.89 Line of Pits. ■�■ 143 6055 0.03 0.11 39 3 3.90 Line of Pits. Nam 144 6096 0 0.11 41 2 3.90 Line of Pits. ■a■ 145 6137 0.04 0.13 47 3 3.90 Line of Pits. ■am I 146 6178 0 0.11 41 "3 3.89 Line of Pits. ■a■ 147 6219 0.04 0.11 40 3 3.89 Line of Pits. mug 148 6260 0 0.09 34 3 3.89 Line of Pits. ■aa 149 6300 0 0.09 31 4 3.90 Line of Pits. ■a 150 6341 0 0.08 29 3 3.89 Line of Pits. ■a � I 151 6382 0.04 0.10 38 3 3.89 Line of Pits. Nom 152 6424 0.04 0.11 39 3 3.91 Line of Pits. ■a 153 6465 0 0.07 28 3 3.91 Line of Pits. ■a 154 6507 0.04 0.07 28 3 3.90 Line of Pits. ■a I 155 6548 0 0.07 25 3 3.90 Line of Pits. ■E 156 6590 0.04 0.06 21 3 3.88 Isolated Pitting. a 157 6631 0 0.05 18 2 3.88 Shallow Pitting,. 158 6671 U 0.04 16 i 3.90 Shallow Line Corrosion. ■ I 159 6712 0 0.05 18 3 3.88 Shallow Pitting. ■ 160 6753 0.04 0.07 26 4 3.89 Line Corrosion. ■� 161 6794 0 0.05 19 2 3.88 Shallow Line of Pits. 162 6835 0.03 0.04 15 2 3.88 Shallow Line of Pits. I 163 6876 0 0.06 20 2 3.89 Line of Pits. ■■ 164 6917 0 0.06 21 3 3.88 Line of Pits. ■ 165 6958 0 0.03 11 1 3.89 166 6998 0.04 0.04 14 2 3.89 Shallow Line of Pits. I 167 7039 0 0.05 19 2 3.89 Shallow Line of Pits. a 168 7080 0.03 0.04 15 2 3.89 Shallow Line of Pits. 169 7120 0 0.07 28 2 3.89 Line of Pits. 170 7161 0 0.05 19 2 3.90 Shallow Line of Pits. ■ 171 7202 0 0.03 11 1 3.87 I 172 7244 0 0.03 11 1 3.90 . i 173 7285 0 0.06 20 2 3.89 Line of Pits. as 174 7327 0.04 0.06 21 2 3.89 Line of Pits. ■ 175 7368 0 0.04 17 2 3.90 Shallow Line of Pits. ■ I 176 7409 0 0.05 18 3.88 Shallow Pitting. ■ 177 7450 0.04 0.05 18 1 3.89 Shallow Pitting. ■ 178 7491 0 0.04 15 2 3.90 Shallow Pitting. a 179 7532 0.04 0.05 19 2 3.89 Shallow Line of Pits. a I 180 7573 0 0.04 16 1 3.86 Shallow Line of Pits. a 181 7614 0 0.04 16 2 3.89 Shallow Pitting. ■ 182 7655 0 0.04 14 1 3.89 Shallow Pitting dy I Metal Loss Penetration BoBody Page 4 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in. 12.6 ppf L -80 TCII / IBT -M Well: NS -10 Body Wall: 0.271 in. Field: Northstar Upset Wall: 0.271 in. Company: BP Exploration (Alaska), Inc. I Nominal I.D.: 3.958 in. Country: USA Survey Date: July 27, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 183 7696 0 0.07 25 2 3.88 Line of Pits. 184 7737 0.03 0.04 17 2 3.89 Shallow Pitting. 185 7779 0 0.06 20 2 3.89 Line of Pits. 186 7820 0 0.05 18 2 3.88 Shallow Line of Pits. 187 7861 0 0.05 19 3 3.87 Shallow Line of Pits. I 188 7902 0.04 0.04 15 1 3.88 Shallow Pitting. 189 7943 0 0.05 19 2 3.90 Shallow Line of Pits. 189.1 7984 0.04 0.07 28 1 3.87 Pup Line Corrosion. 189.2 7994 0 0 0 0 3.75 4.5" Otis XN Nipple I 189.3 7995 0.04 0.06 23 4 3.90 Pup Line Corrosion. 189.4 8006 0 0 0 0 3.92 4.5" WLEG I Pratd y Metal Loss ion Body 1 1 1 1 1 1 1 1 1 Page 5 1 1 1 0 • 1 PDS Report Cross Sections I Well: NS-10 Survey Date: July 27, 2011 Field: Northstar Tool Type: UW MFC 40 No. 213121 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 4.5 in. 12.6 ppf L -80 TCII / IBT -M Analyst: C. Waldrop 1 1 Cross Section for Joint 131 at depth 5570.790 ft Tool speed = 51 Nominal ID = 3.958 I Nominal OD = 4.5 Remaining wall area = 98% Tool deviation = 46° j 1 1 -----) 1 ( _------ 1 1 i F; `1PW I Finger = 1 Penetration = 0.145 in. Line of Pits 0.15 in. = 54% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 s PDS Report Cross Sections I Well: NS-10 Survey Date: Tool Type: July 27, 2011 Field: Northstar UW MFC 40 No. 213121 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 4.5 in. 12.6 ppf L -80 TCII / IBT -M Analyst: C. Waldrop 1 1 Cross Section for Joint 134 at depth 5705.250 ft Tool speed = 52 Nominal ID = 3.958 I Nominal OD = 4.5 - -- Remaining wall area = 97% Tool deviation = 46° / I, 1 r 1 I 1 Finger = 1 Penetration = 0.139 in. Isolated Pitting 0.14 ins = 51% Wall Penetration HIGH SIDE = UP 1 1 1 1 TREE= ABB -VGI 5 -1/8" 5KSI SAFETY I WELLHEAD= ABB -VG' 11" MULTBOWL 5KSI ACTUATOR = BAKER KB. ELEV = 55.77' KOP EV 39.87' (CB 15.9') N S 1 O Max Angle = 51° @ 4424' Datum MD = 13071' I Datum 1VD = 10500' SS 120" CONDUCTOR, 169#, X -56 H 199' I I `' I 2043' 1--1 PROTECTIVE D= 2 (01/05/06) I Minimum ID = 2.6" @ 2043' I 4 -1/2" X NIPPLE w /PROTECTIVE SLV I 110 -3/4" CSG, 45.5#, L -80 BTC, ID = 9.95 "? I—I 3726' I-A ■ I I , 1 I 4938' H4- 1 /2 "XNP, D= 3.813" I X g-1 4960' H7-518" x4-1/2" BKR PREM PKR, D= 3.875" I I I I I 4972' H4 -1/2" XN NP, D= 3.725" I I 4 -1/2" TBG, 12.6 #, L -80 TCH, .0152 bpf, ID = 3.958" L_I 4977' I I 49 I-ITB 7/0 4986 J--I4 -1/2 S " UNIQUE (12/2 OVER SHOT, D = 4.654" I I Z 5015' BKR S-3 PKR, D = 3.875" I I I I I 7994' H4 -1/2" OTIS XN NP, D = 3.725" I 4 -112" TBG, 12.6 #, L -80 BT -M, .0152 bpf, D = 3.958" IA 8006' L 8006' H4-1/2" WLEG, ID = ?. ? ? ?" 17-5/8" CSG, 29.7 #, L -80 BTC, ID = 6.875 "? I-_I 8029' \ � I H ELMD TT NOT LOGGED? I I 1 I 1 6 -3/4" OPEN HOLE TD I—I 8246' I ) I DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 01/11/01 AGK ORIGINAL COMPLETION WELL: NS10 01/03/06 N33E RWO PERMIT No: '2001820 01/05/06 JGB/TLH PROTECTIVE NPPLE SLV SET API No: 50- 029 - 22985 -00 I 01/21/06 ?? ?/TLH DRLG DRAFT CORRECTIONS SEC 11, T13N, R13E 1139' FSL & 643' FEL 11/27/07 WRR/PJC WELLHD/LOCATION CORRECTIONS I BP Exploration (Alaska) I NS10 (PTD #2001820) & NS32 (PTD #2031580) Disposal Wells Compliance Testing Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, June 17, 2011 10:33 AM To: 'Vazir, Mehreen' Cc: Regg, James B (DOA) Subject: RE: N'S10 (PTD X8287 & NS32 (PTD #2031580) Disposal Wells Compliance Testing Mehreen, If the EPA will have representative(s) there, we will not be sending an Inspector. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Friday, June 17, 2011 8:14 AM To: 'Vazir, Mehreen'; Regg, James B (DOA) Subject: RE: NS10 (PTD #2001820) & NS32 (PTD #2031580) Disposal Wells Compliance Testing Sorry about that. The annual MIT schedule is at EPA's direction. Their increased schedule meets our minimum requirements of 2 -years for a slurry well and 4 -years for a liquid disposal well. Tom From: Vazir, Mehreen [mailto:Mehreen.Vazir @bp.com] Sent: Friday, June 17, 2011 8:06 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: RE: NS10 (PTD #2001820) & NS32 (PTD #2031580) Disposal Welis Compliance Testing Hi Tom, The last MIT -IA was completed on 6/18/2010 and based on the 12 month testing frequency we are currently due for our annual MIT -IA by 6/18/2011. However, EPA has made an inspector available to us 7/29 - 8/1/2011 which will put us beyond 12 months from the last successful MIT -IA. EPA has agreed to extend our current test due date to 8/30/2011 in order to accomodate this delay. I want to confirm that AOGCC will find it acceptable to provide a similar extension. Thank you, 4'8414a) JUN 1 T7 2011 Mehreen From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, June 17, 2011 7:52 AM To: Vazir, Mehreen; Regg, James B (DOA) Subject: RE: NS10 (PTD #2001820) & NS32 (PTD #2031580) Disposal Welis Compliance Testing Mehreen, 1 am not clear here. You say the MIT -lAs have been done. Is the testing planned for the end of July logging types? Tom Maunder, PE AOGCC 6/17/2011 NS10 (PTD #2001820) & NS32 (PTD #2031580) Disposal Wells Compliance Testing Page 2 of 2 • From: Vazir, Mehreen [mailto:Mehreen.Vazir @bp.com] Sent: Thursday, June 16, 2011 4:39 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: NS10 (PTD #2001820) & NS32 (PTD #2031580) Disposal Wells Compliance Testing Hello Tom /Jim, North Star disposal wells NS10 (PTD #2001820) and NS32 (PTD #2031580) had successful MIT-lAs completed on 6/18/2010 witnessed by the EPA. Both wells are on a 12 month testing frequency. In order to facilitate completion of multiple tests at a time and save travel for EPA representatives to the Slope, the EPA will be available to witness these tests during the period of July 29 - August 1, 2011. Our current plan is to invite the Slope AOGCC inspector to witness these same tests and submit the test results to AOGCC after completion. Please let me know if this is unsatisfactory to the AOGCC. Thank you, Mehreen Vazir (Alternate: Gerald ,Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 6/17/2011 by ~ Arlene Chow Area Operations Manager -North BPXA ~~~v ~ \~JeC~o~ July 21, 2010 • ` - BP Exploration (Alaska) Inc. - 900 East Benson Boulevard PO Box 196612 Anchorage, AK 99519-6612 (907) 564-5111 ~'~,-off - c. f.~_ ~ O w4\~~~.~o~F~~`~ ~~a~s ~l~c ` e i Phone: (907) 564-4101 ~`lm'~.~ ~G-T`J4 ~'~,LC `~~ ~-" Cell: (907) 602-2407 ~ ` `~ x ~ ` ~~` S Email Arlene.chowo~bp.com i u Web: www.bp.com Mr. Peter Contreras ~--~-~~~ .~ UIC Manager, Ground Water Protection Unit VIA CERTIFIED MAIL U.S. Environmental Protection Agency (OCE-127) 1200 Sixth Avenue Suite 900 Seattle, Washington 98101 ~~~ Mr. Thor Cutler AIJG t- 2 201 U.S. Environmental Protection Agency (EPA) ~~~~~~ ~ ~~ ~~ ~ i~~ 1200 Sixth Avenue ~,~c~idt~~ Seattle, WA 98101 goo y ~~ a Re: NS10 -Report on Annual Demonstration of Mechanical Integrity Dear Mr. Contreras and Mr. Cutler: '~J~\ '(ZU~ ~ ; ~~ ~ ~~\~ ~~\ ~~ Please find enclosed the Report on Annual Demonstration of Mechanical Integrity for the NS10 well, Permit No. AK-11002-A Part II.C.3.b.(1) and Part II.C.3.c.(1), As stipulated by the permit, two (2) copies of the logs and two (2) copies of the descriptive and interpretive report are being sent to the EPA to your attention. I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. If you have any questions please call Mark Sauve at 907-564-4660. Sincerely, t~ Arlene Chow °Y ,i~)~fi ~ ~" ,,~..,~. Attachments • by NS10 • EPA UIC Class (Permit AK-11002-A Part II.C.3.b (2): Report on Annual Demonstration of Mechanical Integrity July 23, 2010 • • Executive Summary: Annual Surveillance on the NS10 EPA UIC Class I disposal well was performed on June 12th, 17th and 18th 2010. The scope of work included a Water Flow Log (WFL) and a Mechanical Integrity Test (MIT) and aMulti-Finger Caliper Log. The MIT, pressure tested to 3500 psi, demonstrated mechanical integrity of the casing, tubing and packer. The test was witnessed by EPA representative Talib Syed. The WFL results indicate there is good vertical containment of injected fluids in the permitted interval. Ten WFL stops were made starting just above the casing shoe and stopping just above the packer. Fluid movement was not detected on any of these stops. The test was witnessed by EPA representative Talib Syed. The Multi-Finger Tubing Caliper Log survey indicated significant tubing wall loss above the packer up to 47% (last year's tubing caliper survey found 55% wall loss above the packer). Remaining tubing life is estimated to be one to five years. Attachments include the well bore diagram (attachment 1), MIT documentation (attachments 2-4), the Schlumberger RST-WL log (attachment 5) and the PDS ~ Memory Multi-Finger Caliper log (attachment 6). • • Discussion ~ Mechanical Integrity Test of Inner Annulus EMIT-IA)' r On June 18, 2010 aMIT-IA was pertormed on NS10. The inner annulus (4-1/2" x ® 7-5/8" casing annulus) was pressurized to 3500 psi with 5 barrels of diesel. ® During the first 15 minutes of the test pressure dropped 140 psi and in the second 15 minutes the pressure dropped 40 psi. This pressure decline of 5.14% during the allotted 30 minute test period test indicates there is good tubing and ~ casing mechanical integrity. The test was witnessed by EPA. representative Talib r Syed. The MIT results are summarized attachment 2, the pressure chart recorded during this test is shown in attachment 3 and the well service report for this work is included in attachment 4. Fluid Movement Lods Water Flow Log (WFL) and Temperature Log] On June 17th, 2010, a Schlumberger Reservoir Saturation Tool Water Flow Log (WFL) was run in NS10. The purpose of the log was to detect movement of any fluids in vertical channels adjacent to the wellbore and to determine that the confining zone is not fractured. The log was conducted with an injection pressures ranging from 2250 to 2278 psig. Injection rate at the time of logging was approximately 18,309 - 18,500 BPD of produced water. The WFL bombards water with neutrons and detects gamma rays from the resulting interactions. The tool has a neutron generator and three gamma ray detectors. For this job, the tool was configured to detect the upward movement of water. The neutron generator was placed below the three gamma ray detectors. To detect the movement of water behind pipe, the tool is positioned at the desired depth and the neutron .generator is turned on briefly. If there is upward movement of water (e.g. channels behind the casing), the gamma ray detectors see the energized water as it moves up past them. Ten WFL stops were made in NS10. The depths were 7950', 7900', 7850',.6050', 5050', 5000', 4950', 4900', 4850' and 4800'. The casing shoe in this open hole completion is at 8029'. The original packer is set at 5015', the packer from the January 06, 2006 RWO is set at 4960' and the intermediate casing shoe is at 8029'. No water movement was detected at any of the stops. The WFL results indicate there is good vertical containment of injected fluids in the permitted interval. The test was witnessed by EPA representative Talib Syed. The detailed report for the RST Water-flow log is attachment 5 and the well service report for this work is included in attachment 4. Tubing Inspection Caliper Log ProActive Diagnostic Services (PDS) was retained to provide a 1-11116", 40 finger memory caliper tool and interpretation of the results. This tool was run on Schlumberger slickline from the tubing tail back to surface on June 12, 2010. This tool digitally records the internal diameter of the tubing, which is used to determine pipe thickness, and hence metal loss. A rig work-over (RWO) was completed on NS10 January 06, 2006. As a result, the multi-finger caliper data reflects the condition of the tubing string ran in January 2006 (above 4981'); as well as, the original tubing tail ran in January 2001 (below 4981'). The caliper tubing inspection log indicates the tubing is in fair to poor condition. During the 2008 caliper survey an area of poor condition with maximum wall penetration of 72% was located in the original tubing string below the new tubing ran in January 2006. During the 2010 caliper survey the maximum wall penetration found in the lower section of tubing was only 54% and it is likely the 2010 caliper simply missed the 72% pit recorded during 2008. The maximum wall penetration of the tubing string ran in January 2006 is 47% at joint 33 (1,405'), indicating this portion of the tubing is in fair condition. The damage appears mostly in the form of isolated pitting. No significant areas of cross- sectional metal loss or I.D. restrictions are recorded. The detailed report from PDS is attachment 6 and the well service report for this work is included in attachment 4. • 1 - - <_'~ ~~o~a~ :~~~~~~ ~i~C~ y i~ ~~ i _i • ~ ~ • ~ ~ ~ WATERFLOW INJECTION LOG ~ 5 WITH PRESS /TEMP / GR / CCL ~ z 17~lUN-2010 ~ ~O ~ w ~ p= ~ Q c j ~ ~ can u_ O _ ~ o a O ~ 1139.05' FSL & 642.96' FEL AT SURFACE Elev.: K.B. 55.77 ft G.L. 16.Oti ft D.F. ~ ~ °' ° ~ z z ~ z m o ~ U Permanent Datum: MSL Elev.: 0.00 ft Log Measured From: KB 55.77 ft above Perm. Datum Drilling Measured From: KB '~ ~ - E m m° ~ .° 3 U API Serial No. so-029-22985-00 Section 11 Township 13N Range 13E Lo in Date 17-Jun-2010 Run Number ONE Depth Driller 8246 ft Schlumberger Depth TD NOT TAGGED Bottom Log Interval 7960 ft Top Log Interval 4780 ft Casing Fluid Type INJECTED PRODUCED WATER Salinit Densit Fluid Level BIT/CASING/TUBING STRING Bit Size 6.750 in From 8029 ft To 8246 ft Casin jt'ubin Size 7.625 in Wei ht 29.71bm/ft Grade L-BO From 0 ft To 8029 ft Maximum Recorded Temperatures `~ ; Logger On Bottom Time 17-Jun-2010 10:06 ~ Unit Number Location 4101 PRUDHOE BAY Recorded B DECKERT/ RIVARD/LOBBY/GEAR Witnessed B ' ~~, z . ~. ._ . . AUCiC;C: M1 ilA l+orms I/Nlll-US (18060), END1-15 (1930560), NS-10 (20820), NS-32 (20... Page 1 of 2 Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Tuesday, July 06, 2010 10:46 AM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA) ~~ Subject: RE: AOGCC MITIA Forms END1-05 (1861060), END1-15 (1930560), NS-10 (2001820), NS-32 (2031580), MPF-42 (1970200), MPJ-17 (1972080), MPS-11 (2021130), MPS-31 (2020140) Attachments: MIT ACT NS-10 NS-32 06-18-10 Revised.xls; MIT MPU J-17 06-05-10.x1s Jerry/Torin, Our database only allow numeric data for the Pretest, Initial, 15 Min., and 30 Min, data so I've removed the verbiage from report MIT ACT NS-10 NS-32 06-18-10, well NS-10 PTD #2001820 that was included for the Pretest Casing data and included "VAC" in the notes. I've also removed the NAs (OA data} for MIT MPU 5-11 5-3106-05-10 and MIT MPU J-17 06-OS-10 and include OA-NA in the notes as well. Well MPJ- 20 PTD #2001850 did not include any data (as the well was shut in} so I removed this well from report MIT MPU J-17 J-20 06-05-10. Also, can you please verify the Packer TVD for well MPU 5-31 PTD #2020140 (we have 3857'}? Thank you, Phoebe Phoebe Brooks Statistical Technicianll ~,A-~~~:!`;~~ei~,, r~~J~° ~ ~()j~4 Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] , Sent: Thursday, July 01, 2010 4:13 PM To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Subject: AOGCC MITIA Forms END1-05 (1861060), END1-15 (1930560), NS-10 (2001820), NS-32 (2031580), MPF-42 (1970200), MPJ-17 (1972080), MPS-11 (2021130), MPS-31 (2020140) Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: END1-05 (PTD #1861060) END1-15 (PTD #1930560) NS-10 (PTD #2001820) NS-32 (PTD #2031580) MPF-42 (PTD #1970200) MPJ-17 (PTD #1972080) MPS-11 (PTD #2021130) MPS-31 (PTD #2020140) «June 2010 MIT Forms END-NS-MPU.zip» 7/12/2010 AUUC:C; Ml"llA Forms END1-O5 (1060), END1-15 (1930560), NS-10 (2820), NS-32 (20... Page 2 of 2 Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/ 12/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /ACT / NS DATE: 06/18/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well NS-10 Type Inj. I TVD 3,987' Tubing 520 520 520 515 Interval O P.T.D. 2001820 Type test P Test psi 3500 Casing VAC 3,500 3,360 3,320 P/F P Notes: Annual MIT-IA for Class I disposal regulatory OA 50 50 50 50 compliance. Well NS-32 Type Inj. W TVD 4,070' Tubing 2,000 2,010 2,005 2,008 Interval O P.T.D. 2031580 Type test P Test psi 3500 Casing 20 3,500 3,420 3,420 P/F P Notes: Annual MIT-IA for Class I disposal regulatory OA compliance. Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11 /27/07 MIT ACT NS-10 NS-32 08-18-10.x1s 5~ by 2~~~ i Date: 07-01-2010 Transmittal Number: 93149 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. nlease contact Joe Lastufka at (9071564-4091 Delive Contents Bottom SW Name Date Contractor Run Top De th De th Descri tion WATERFLOW INJECTION LOG WITH NS10 06-17-2010 SCH 1 4780 7960 PRESSlTEMP/GR/CCL CD-ROM - WATERFLOW INJECTION LOG WITH NS10 06-17-2010 SCH PRESS/TEMP/GR/CCL WATERFLOW INJECTION LOG WITH NS32 06-18-2010 SCH 1 3800 8060 PRESS/TEMP/GR/CCL CD-ROM - WATERFLOW INJECTION LOG WITH NS32 06-18-2010 SCH PRESS/TEMP/GR/CCL ~ j V~ ' _ 1 use Sign and Return one copy of this transmittal. Thank You, Joe Lastuflca Petrotechnical Data Center BPXA AOGCC DNR Murphy Exploration MMS ~a-~~ 2 ~~~ -~s~ 'a° 1~~~ 1 ~ ~r~ Petrotechnical Data Center L1Z2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 David Fair Christine Mahnken Corazon Manaois Ignacio Herrera Doug Chromanski .--~ ;? ~~ Date: 06-28-2010 Transmittal Number: 93148 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastuflca at (9071564-4091 Delive Contents Bottom SW Name Date Contractor Run To De th De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS32 06-12-2010 PDS 7 0 8100 SUMMARY CD-ROM.- MEMORY MULTI- FINGER CALIPER LOG NS32 06-12-2010 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS10 06-12-2010 PDS 10 0 8006 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS10 06-12-2010 PDS RESULTS SUMMARY ~ _--.~ PI~e Sign and Return one copy of this transmittal. Thank You, Joe Lastuflca Petrotechnical Data Center BPXA ~., $ , a ~~.t~ t x~ ?~ ~t~ AOGCC `~``` ~~~ Murphy Exploration MMS DNR ~3 - 75~ 1 ~~~ ~ • U' ~ ~ ~ ~, ., ~, ~~. ~rs~ q David Fair Christine Mahnken Ignacio Herrera Doug Chromanski Corazon Manaois Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • Memory Multi-Finger Ca{iper S Log Results Summary Company: BP Exploration (Alaska), Inc. Well: NS-10 Log Date: June 12, 2010 Field: Northstar Unit Log No.: 1010 State: Alaska Run No.: 10 API No.: 50-029-22985-00 - _.... Pipet Desc.: 4.5" 12.6 Ib. L-80 TCII ! IBT-M Top Log Intvl1.: Surface Ptpe1 l1se: Tubing & Tubing Stub Bot. Log tMvt1.: 8,008 Ft. r;MDj Inspection Type : Corrosion Monitoring Inspection COMMENTS : M ~ `^ f~^++~" This log is tied into the WLEG @ 8,006' (FEND). ~ ~ ~~~ ~.r~.~..., r ~~ This tog was run to assess the condition of the tubing and tubing stub with respect to corrosive and mechanical damage. The caliper recordings indicate the 4.5" tubing and tubing stub is in good to poor condition, with a maximum recorded wall penetration of 54% recorded in a line of pits in joint 134 (5,722'). Recorded damage appears as isotated pitting, with intermittent tine of pits and tine corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The body region analysis and joint tabulation data for the 4.5" tubing and tubing stub logged are combined. This is the tenth time a PDS caliper has been run in this well, the tenth time the 4.5" tubing stub has been logged from 4,981' to 8,006', and the fifth time the 4.5" tubing has been logged from surtace to 4,981'. A comparison of the current and previous log (June 20, 2009} indicates little if any increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis between the current and previous log is included in this report. The intermittent large increases in maximum recorded penetrations from _5,000' to 6,800' in the included comparison graph appear to be due to the caliper fingers better tracking a line of pits gver this interval in the current log than the previous tog, rather than an actual increase in corrosive damage. C Time to Failure Evaluation graphs of both the replaced tubing (0' - 4,981') and the tubing stub (4,981' - 8,006')are included in this report. These graphs project a failure date range based on corrosion rates calculated from changes in the deepest recorded penetration in the entire well over time. The tubing from surtace to 4,981' is projected to fail between 1 and 5 years. The tubing stub (4,981' - 8,006') is projected to fail between today and 8 years. MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits (54%) Jt. 134 @ 5,722 Ft. (MD} Line of Pits (51°~} Jt. 121 @ 5,171 Ft. (MD) Line of Pits (51%) Jt. 143 @ 6,067 Ft. (MD) Line of Pits (50°!0) Jt. 147 @ 6,235 Ft. (MD) Line of Pits (49%) Jt. 137 @ 5,820 Ft. (MD) MAXIMUM RECORDED CROSS-SECT{ONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. Field Engineer. E. Gustin Analyst: HY. Yang & M. Lawrence Witness: B. Rochin & B.Tilbery ProActive Diagnostic Services, Inc. j P.O. Bax 1369, Stafford, TX 77497 Phone: {281) or {8$$) 565-9085 Fax: {281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 Time to Failure Evaluation BP Exploration (Alaska-, Inc. ~ Northstar Unit Gorrosive Trend: Isolated Pitting Well : NS-10 4.5" Tubing and Overshot June 12, 2010 Years Following Most Recent Log 4.5" 12.6 Ib L-80 TCII (0' - 4,981') 0 5 Wall Thickness = 271 mill ~ 260 - 240 ~ 220 ... ~ 200 0 180 , 160 C 4 140 a 120 O 100 u ~ 80 y! 60 40 20 o- -__ _-_ - I ~ ~~ .¢_~_ __ 8 /o Wall ickness afety F cto~) i ~ ~ ~ ~ ~ I ~ ~ ,,.~ ~.. 1 i i ~ ----- --- - ~ ~ I~ i ~ ~ i ~ i~ i I ~ 2010 M d i R d W ll P t ti I ~ ax mum ecor ene e a ra on ~~;;; I i 0.128" = 47% Wall Thickness in Joint 33 (1,429'). I ~ 10-July-08 to 03-Jan-06 (Completion Date) = 34 mpy 20-June-09 to 03~1an-06 (Completion Date) = 43 mpy I 12-June-10 to 03-Jan-06 (Completion Date) = 29 mpy ~" I Best Fit= 35 MPY (Bold Dotted Line) -. I 2010 vs 2009 Joint-by-Joint Comparison Approx. I Corrosion Rate = 0 MPY I Tubing Failure Projected Between 1 and 5 years I I I I o ~ s 10 Years Since Well Completion ~ llllll~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ l~ Time to Failure Evaluation BP Exploration (Alaska), Inc. ~ ~ Northstar Unit Corrosive Trend: Isolated Pitting, Well : NS-10 Lines of Pits and Line Corrosion 4.5" Tubing Stub below Overshot June 12, 2010 Years Following Most Recent Log 4.5" 12.6 tb L-80 IBT-M (4,981' - 8,006') 0 5 10 Wall Thickness = 271 mill 260 240 v 220 ._ ~ 200 c ,~ 180 160 a~ C ~ 140 a. y 120 '~ O 100 V G1L 80 x ~ 60 40 ao 0 _~~ _ f_ ,- I . ~ _ ~_.a .-_l _ ~ I L ,_., l.fR ess ~5afet ~=;~ ~. ~ ~.~~~ ~ I~ I' ~ - !~ I ~ ~ I ,, ~ - ~ I 2010 Maximum Wall Penetration in Stub 0.146" = 54% Wall Thickness in Joint 134 (5,722'). I 10,,July-08 to 11-Jan-01 (Completion Date) = 26 mpy - I 20,,lune-09 to 11-Jan-01 (Completion Date) = 17 mpy I 12,,June-10 to 11-Jan-01 (Completion Date) = 15 mpy 1- - ,, I I I Best Fit =18 MPY (Bold Dotted Line) 2010 vs 2009 Joint-by,Joint Comparison Approx. - I I Corrosion Rate = 0 MPY -- I Tubing Failure Projected Between Today and 8 Years I B 0 5 10 15 ZO Years Since Well Completion • c Maximum Recorded Penetration 1 `~~ Comparison To Previous Well: NS-10 Survey Date: June 12, 2(110 Field: Northstar Unit Prev. Date: June 20, 2009 Company: BP Exploration (Alaska), Inc. Tool UW MFC 40 No. 213121 Country: USA Tubing: 4.5" 12.6 Ib L-80 TCII / IBT-M Overlay rli{{o ronro • Correlation of Recorded Daman Pipe 1 4.5 in (35.0' - 8006.1') Well: Field: Company: Country: Survey Date i ;e to Borehole Profile NS-10 Northstar Unit BP Exploration (Alaska), Inc. USA June 12, 2010 Approx. Tool Deviation ^ Approx. Borehole Profile 1 38 25 1072 50 ~„ ~~ 2135 75 ti 3179 Q ~ a, 100 ~ 4221 ~ ~ ~ .c z a ° p 12.5 '~ 5315 150 6340 175 7367 189.4 8006 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 189.4 • PDS Report Overview ~y,.__ 5,~. Body Region Analysis Well: NS-10 Survey Date: June 12, 2010 Field: Northstar Unit Tool Type: UW MFC 40 No. 213121 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: HY'. Y'an Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 13 > >f I_-80 TCII IBT-M 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 200 150 00 1 50 0 0 to 1 to 10 to 1% 10% 20°/ 20 to 40 to over 40% 85% 85% Number of ~oints anal sed total = 203 pone loss . 0 9 81 51 152 0 94 19 0 0 0 0 Damage Configuration (body ) 200 150 100 50 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ihle hole Number of ~oints dama ed total = 202 189 0 13 0 0 Damage Profile (% wall) ~ penetration body metal foss body 0 50 0 47 1__J 100 95 189 Bottom of Survey = 189.4 139 Analysis Overview page 2 • PDS REPORT JO INT TABULATION SH EET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Unit Upset Wall: 0.271 rn Company: BP Exploration (,Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: June 12, 2010 Joint No. Jt. Depth (Ft.) Pen. (11,~c~1 !Ins.) Pen. Body flns.} Pen. % Metal I r>~s "~: Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 35 i~ 0.02 8 U 3.92 PUP 1 38 it 0.07 Zi I 3.92 Isolated ittin . 1.1 81 l) 0.10 Sri 1 3.91 PUP tsolated ittin 1.2 101 0 0.08 3U 1 3.91 PUP Isolated it6n . 1.3 111 ~? 0.04 I(> I 3.93 PUP Sha-low ittin . 2 115 t) 0.10 ii I 3.91 Isolated ittin . 3 157 €? 0.10 37 I 3.91 Isolated ittin . 4 199 t) 0.11 39 ! 3.90 Isolated ittin . 5 240 U 0.07 25 I 3.92 Isolated ittin 282 t) 0.11 4U 3 3.92 Isola e itt n 7 323 U 0.08 .3~) I 3.91 Isolated ittin 8 365 i1 0.08 fU I 3.92 Isolated ittin . 9 407 l) 0.07 27 I 3.91 Isolated ittin . 10 448 O.Ut~ 0.08 _"i I 3.91 tsolated thin . 11 490 U 0.07 14 I 3.91 Isolated ittin . 12 531 (1 0.08 l9 I 3.92 Isolated ittin . 13 573 U 0.07 ~7 I 3.91 Isolated ittin . 14 615 U 0.09 92 I 3.91 Isolated ittin . 15 657 U 0.05 1 tf I 3.92 Shallow ittin 16 699 i) 0.05 18 4 3.91 Shallow ittin . 17 740 l7 0.06 21 2 3.91 Isolated ittin . 18 782 U 0.05 18 U 3.91 Shallow ittin . 19 823 U 0.10 i7 I 3.91 Isolated ittin . 20 865 U 0.10 ~' I 3.91 Isolated ittin 21 907 U 0.11 -11 I 3.92 Isolated ittin ~ 22 949 U 0.10 ,£s _' 3.92 Isolated ittin 23 990 t) 0.06 ~'3 4 3.92 Isolated ittin . 24 1031 t~ 0.07 27 1 .3.92 Isolated ittin 25 1072 €! 0.12 44 4 3.94 Isolated ittin - 26 1114 (~ 0.11 ~~) 2 3.93 Isolated ittin . 27 1155 t) 0.09 32 I 3.92 Isolated ittin . 28 1197 U 0.06 24 3.93 tsolated ittin . 29 1238 ~? 0.10 >' 3.90 Isolated ittin . 30 1280 a 0.06 21 4 3.94 Isolated ittin - 31 1321 € ~ 0.08 14 3.93 Isolated ittin . 32 1363 t) 0.09 3Z 3.92 Isolated ittin - 33 140.5 i~ 0.13 4i 3.93 Isolated ittin - 34 1446 (1.U7 0.11 4O t 3.93 Isolated ittin - 35 1487 U Q07 27 1 3.94 Isolated ittin 36 1529 t).1 U 0.09 34 I 3.93 Isolated ittin - 37 1571 tl 0.05 1 ~) 3.94 _ Shallow ittin . 38 1613 U 0.06 Z4 ~, 3.93 Isolated ittin 39 1655 O.U7 0.11 ~~) ~ 3.94 Isolated ittin . 40 1696 t) 0.08 iU ~ 3.93 Isolate ittin . 41 1738 U 0.08 >i? 3 3.93 Isolated ittin . 42 1779 t~ 0.10 > 5 3.93 Isolated ittln . 43 1822 (1 0.05 Zl) -1 3.93 Isolated ittin . 44 1863 U 0.06 24 t 3.93 Isolated ittin . 45 1905 t! 0.08 3.93 Isolated ittin . 46 1947 ~? 0.08 3.94 Isolated ittin `~ _ Penetration Body ~V1eta1 Loss Body Page I • PDS REPORT JO INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Unit Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: }une 12, 2010 Joint No. Jt Depth (Ft.) t't~n. ilt~s~t (!nsJ Pen. Body (Ins.} Pen. % Metal toss °~~ Min. LD• (lam.) Comments Damage Profile (%wall) 0 50 100 47 1988 O 0.06 l3 ~ 3.94 Isolated i[tin . 47.1 2030 U 0.03 13 I 3.94 PUP Shallow ittin . 47.2 2039 U 0 U ~i 3.81 4S" X Ni _ , le 47.3 2042 ti 0.02 'i 1 3.94 PUP 48 2051 ii 0.07 3.94 Isolated ittin . 49 2093 a 0.07 ' ~ 3.93 Isolated ittin . 50 2135 i l 0.06 _' 3 3.94 Isolated ittin - 51 2177 ti 0.06 Z4 ~ 3.94 Isolated ittin . 52 2219 a 0.07 25 I 3.93 Isolated ittin . 53 2260 ii 0.07 24 1 3.93 Isolated ittin . 54 2302 t~ 0.05 19 ~' 3.94 Shallow ~ittin 55 2345 a 0.06 11 3.93 Isolated ittin . 56 2386 ti 0.05 ~!U _' 3.93 Isolated ittin . 57 2428 (i 0.06 21 3.93 Isolated ittin . 58 2470 U 0.04 16 I 3.92 Shallow ittin . 59 2512 ll 0.05 2(1 1 3.93 Isolated ittin . 60 2553 U 0.04 14 3.93 Shallow ittin 61 2595 U 0.04 1 5 ? 3.94 Shallow ittin . 62 2637 t) 0.04 15 3.93 Shallow ittin . 63 2678 ti 0.05 ~t) 3.93 Isolated ittin . 64 2720 ti 0.05 I ~) ? 393 Shallow ittin . 65 2762 !i 0.04 l~ I 3.93 Shallow ittin . 66 2804 i? 0.04 15 1 393 Shallow ittin . 67 2845 !) 0.06 1 ? 3.93 Isolated ittin . 68 2887 t'~ 0.06 ' "; 1 393 Isolated ittin . 69 2929 !. 0.04 i~; 3.93 Shallow ittin . 70 2971 ti 0.07 2U ~ 3.93 Isolated ittin . 71 3012 t) 0.05 1 ti _' 3.92 Shallow ittin 72 3054 ti 0.04 15 I 3.93 Shallow ittin . 73 3096 U 0.05 fit) 3.93 Isolated ittin . 74 3138 a 0.06 Z I 3.93 Isolated ittin . 75 3179 ti 0.06 21 ~ 3.94 Isolated ittin . 76 3221 U 0.04 15 1 3.93 Shallow ittin . 77 3263 t1 0.06 21 Z 3.93 Isolated ittin . 78 3304 ii 0.05 19 3.93 Shallow ittin . 79 3346 ti 0.05 18 ? 3.93 Shallow ittin 80 3388 ti 0.05 1 t3 3.94 Shallow ittin . 81 3430 ti 0.05 ! t> 3.93 Shallow ittin - 82 3472 ti 0.04 14 1 3.92 Shallow ittin 83 3514 U 0.04 t t, 3.92 Shallow ittin - 84 3556 i? 0.06 Z< ~ .94 Isolated ittin . 85 3597 ti 0.03 1 3 3.93 Shallow ittin . 86 3637 U 0.05 I ~~ 4 3.94 Shallow ittin . 87 3679 t) 0.05 ZU 4 3.94 Isolated ittin . 88 3721 U 0.04 1 G i 3.94 Shallow ittin . 89 3763 t) 0.06 22 a 3.94 Isolated ittin . 90 3804 a 0.07 Zf, -I 394 Isolated ittin . 91 3846 ti 0.04 l4 ~ 3.94 Shallow ittin . 92 3887 t) 0.04 17 3 3.93 Shallow ittin - 93 3928 U 0.04 16 Z 3.94 Shallow ~itiin . _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JO INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Unit Upset Wall: 0.271 in Company: BP Exploration (Alaska), tnc. Nominal I.U.: 3.958 in Country: USA Survey Date: June 12, 2010 Joint No. Jt. Depth (Ft.) I'~~n. t ll~u~t (!!;..) Pen. Body Qrrs.} Pen. % a1c>!,il I ~~ss °~ Min. LD• (Errs.) Comments Damage Profile (%wall) 0 50 100 94 3970 i) 0.03 11 I 3.93 Shallow ittin . 95 4012 !) 0.03 13 I 3.93 Shallow ittin . 96 4053 U 0.03 10 I 3.92 97 4096 (1 0.03 7t) i 3.92 98 4138 l) 0.06 ~t) ! 3.92 Isolated ittin . 99 4178 U 0.03 ~~ ! 3.92 100 4221 ~l 0.03 1 (1 1 3.92 101 4260 c' 0.03 l:~ 1 3.91 Shallow ittin . 102 4302 i:~ 0.03 11 1 3.93 Shallow ittin . 103 4344 i ~ 0.03 1 U 1 3.92 104 4385 U 0.03 12 I 3.93 Shallow ittin . 105 4427 tLt)5 0.03 11 I 3.93 Shallow ittin . 106 4469 t1 0.04 1 r, I 3.92 Shallow ittin . 107 4511 U 0.04 15 3.92 Shallow ittin . 108 4553 it 0.05 Ili i 3.93 Shallow ittin . 109 4594 !) 0.03 1 I 1 3.93 Shallow ittin . 110 4636 U 0.03 1."3 I 3.92 Shallow ittin . 111 4679 U 0.04 14 3.93 Shallow ittin . 112 4720 U 0.04 i .5 _' 3,92 Shallow ittin . 113 4761 i~ 0.03 13 I 3.94 Shallow ittin . 114 4803 t~ 0.05 2U ~l 3.94 Isolated ftttn . 115 4845 t) 0.04 1? 5 3.94 Shallow ittin . 116 4886 !) 0.04 1 5 1 3.94 Shallow ittin . 116.1 4928 !.) 0.03 ~) -1 3.95 PUP 116.2 4938 ! ~ 0 U d 3.81 4.5" X Ni le 116.3 4940 !i 0.03 lt) -1 3.95 PUP 116.4 4949 i? 0.03 13 s 3.90 PUP Shallow ittin . 1165 4960 I I 0 tl ! ~ 3.88 7.625" X 4.5" BKR Premier Packer 116.6 4965 U 0.04 14 t~ 3.96 PUP Shallow ittin . 116.7 4972 U 0 U ; ~ 3.73 4.5" XN Ni le 116.8 4974 U 0 O !) 4.65 4.5" Uni ue Overshot 117 4982 0 0.09 3_' 3.94 Isolated ittin . To of Tubin Stub. 117.1 5004 U 0,08 > 1 ! 3.92 PUP Isolated ittin . 117.2 5013 t) 0 U t~ 3.88 BKR S-3 Packer 117.3 5017 U 0.10 38 - 3.94 PUP Line corrosion. 118 5027 ii 0.10 37 c. 3.92 Isolated ittin 119 5068 l~ 0.07 27 3.91 Line of its. 120 5110 t) 0.09 32 - 3.91 Line of its. 121 5151 i~ O.t4 ''il 3.93 Line of its. 122 5192 i~ 0.09 ~"? (, 3.92 Line of its. 123 5233 t) 0.09 a ~ > 3.92 Line of its. 124 5274 O 0.12 -4 1 3.92 Line of its. 125 5315 i! 0.09 s~1 -t 3.92 Line of its. 126 5356 i~ 0.05 16 -1 3.92 Shallow line of its. 127 5397 ~~ 0.10 iti 4 3.92 Line of its. 128 5438 t) 0.07 5 1 3.89 Line of its. 129 5479 I~ 0.11 41 -+ 3.90 Line of its. 130 5520 t~ 0.08 28 -t 3.90 Line of its. 131 5561 i ~ 0.1 1 40 3.91 Line of >its. 132 5602 !! 0.09 33 3.91 Isolated ~ittin _ Penetration Body Metal Loss Body Page 3 i • PDS REPORT JO INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Unit Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: June 12, 2010 Joint No. Jt. Depth (Ft.) I'en. I )poet (I;iti.l Pen. Body (Ins.) I'en. °~ :etc tal I Uss 9~, Min. LD• (Ins.) Comments Damage Profile (% wall} 0 50 100 133 5643 U 0.11 ~0 ~ 3.91 Line of its. - 134 5684 U 0.15 54 ? 3.90 Line of its. - ' t 135 5725 U 0.1.0 35 -1 .3.92. Line of .its. - 136 5767 t) 0.13 47 3.90 Line of its. 137 5807 U 0.13 49 t, 3.87 Line of its. 138 5848 t) 0.12 46 -1 3.90 Line of its. 134 5890 t) 0.12 44 S 3.90 Line of its. 140 5930 t:' 0.12 44 3.90 Line of its. 141 5971 a 0.13 48 -1 3.90 Line of its. 142 6013 U 0.13 47 4 3.91 Line of its. - 143 6054 U 0.14 51 4 3.90 Line of its. - 1 144 6096 t) 0.13 47 -1 3.91 Line of its. 145 6137 tt 0.11 39 5 3.92 Line of its. 146 61,'8 O 0.09 s 1 +> 3.93 Line of its. 147 6219 U 0.14 50 - 3.92 Line of pits. -- 148 6260 t) 0.11 ~1 3.92 Line of its. 149 6300 U 0.12 ~t(~ i, 3.92 Line of its. 150 6340 U 0.09 >3 > 3.91 Line of its. 151 6382 i) 0.09 t > 3 3.91 Line of its. 152 6424 U.i)i', 0.08 31 ~ 3.91 Line of its. 153 6465 U 0.08 t 1 3.92 Line of ~ts. 154 6507 U 0.07 Z5 a 3.90 Line of its. 155 6548 U 0.05 I t3 -! 3.89 Shallow line of its. 156 6590 ! t 0.06 ~ I 3.91 Line of its. 157 6631 t) 0.05 19 3.90 Shallow line of its. 158 6671 tt 0.04 14 3.91 Shallow ittin . 159 6712 it 0.06 23 a 3.90 Line of its. 160 6753 U .0.08 3U 4 3.92 Line of its. 161 6794 a 0.07 27 ~ 3.91 Isolated ittin 162 6835 t) 0.04 15 ~ 3.91 Shallow ittin 163 6876 O 0.05 20 5 3.91 Line of its. 164 6917 U 0.04 16 5 3.91 Shallow itfin . 165 6958 t) 0.04 14 -i 3.91 Shallow ittin . 166 6997 U 0.05 1 tY -1 3.91 Shallow ittin . 167 7038 ~ t 0.05 1 f} ^; 3.89 Shallow ittin . 168 7080 U 0.04 1 i -1 3.90 Shallow ittin . 169 7121 U 0.06 ~ ; 3.92 Line of its. 170 7161 t) 0.04 1(i -1 3.92 Shallow ittin . 171 7202 U 0.05 18 3 3.90 Shallow ittin . 172 7244 i) 0.06 2U 3.91 Isolated ittin . 173 7285 t) 0.0 76 -1 3.90 Line of its. 174 7326 U 0.11 39 ~ 3.91 Line of its. 175 7367 ~ ~ 0.05 20 3 3.91 Line of its. 176 7409 ~) 0.04 16 3.90 Line shallow corrosion. 177 7450 tt 0.06 11 =l 3.91 Isolated ittin . 178 7491 +? 0.05 1 ti I 3.91 Shallow itti 179 7532 !) 0.06 Z 1 -1 3.91 Isolated ittin . 180 7573 (t 0.05 ~'U -1 3.91 Isolated ittin . 181 7614 tl 0.05 19 5 3.92 Line shallow corrosion. 182 7655 rt 0.06 22 i 3.92 Line corrosion. ~ _ Penetration Body Metal Loss Body Page 4 i • PDS REPORT JO INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Unit Upset Wall: O.Z71 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: June 12, 2010 Joint No. Jt~. Depth (Ft.) I'<~n. ~ lFisc~l (Ins.) Pen. Body (Ens.) Pen. °/> alct.il I ~~ts "4~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 183 7696 i ~ 0.09 32 5 3.90 Line corrosion. 184 7737 r) 0.05 ~U 4 3.91 Line corrosion. 185 7779 U 0.05 i ~) ~ 3.91 I ine shallow corrosion. 186 7820 U 0.05 tO 3.91 Line corrosion. 187 7861 t~ 0.05 'U a 3.90 Line corrosion. 188 7902 ! ~ 0.06 ~' 1 3.90 Line corrosion. 189 7943 ~, ~ 0.05 i `> "~ 3.90 Line shallow corrosion. 189.1 7984 ! r 0.08 SU _' 3.93 PUP Line corrosion. 189.2 7994 ! ? 0 ! 1 3.73 4.5" XN Ni le 189.3 7998 - n.(>> _ - 3.93 __ PUP Line shallow corrosion. 189.4 8006 ~ U _~ ~ti' A 4.5" WIJY; Penetration Body Metal Loss Body Page 5 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ w ~ PDS Report Cross Sections ~,-4~a~_m~ ,. Well: NS-10 Survey Date: June 12, 2010 Field: Northstar Unit Tool Type: UW MFC 40 No. 213121 Company: BP Exploration (Alaska}, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 4.5 ins 13 f L-80 TCII IBT-M Anal st: HY. Yan Cross Section for Joint 134 at depth 5722.106 ft Tool speed = 44 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 98 Tool deviation = 48 ° Finger 23 Penetration = 0.146 ins Line of Pits 0.15 ins = 54% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 PDS Report Cross Sections Well: NS-10 Survey Date: June 12, 2010 Field: Northstar Unit Tool Type: UW MFC 40 No. 213121 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: US,q No. of Fingers: 40 Tubin 4.5 ins 13 f I_-80 TCII IBT-M Anal st: HY. Yan Cross Section for Joint 121 at depth .170.817 ft Tool speed = 44 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 93 Tool deviation = 49 ° Finger 8 Penetration = 0.138 ins Line of Pits 0.14 ins = 51% Wall Penetration HIGH SIDE = UP Cross Sections page 2 TRIE- AE36-VGI ~tt~SKSI AClLATi7R - . EiF dC4' - 99.87;~~3 15..9r K:.~P' Mra. Angle - .. Om~t1'1t AO ~i~neTV®, _ Minimum Id = 2.6" ~ 2043' 4-1f2" ~ NtPPI~ wlPRbT~CTIYE SLY ~~~ 1 sng~'r rat: 1 Ia/7xNfi.0-3..813' ~ Id-1~7lfiG,12.8M.t-80TCi...O1S2h~i.0-3%8' 1 GAIL P.L1+ E1Y COMd¢¢T'S DATL f~Y EiY CAI11~Td'IS OtNt01 A0~0 GW1?LEf~NI O 1,'0Sl68 N99E IfYt97 9t:Q5.016 J(.~f3Ttti Pf~T[~T-tLNFPLCSrV SLT 41:21,016 ???t'0.N QiLGQRAFTCCR~NS MaRIF6TRR. W dt: 14S t~l PQ7Nii Pio.~.. ~xi 1S2CI API fem. StM2g-2298SU0 ~ fxpbratiom 9Aiska! D:\Sondex Ultrawire Memlog\Projects\NS-10.prj\NS10 Annual EPA Surveillance (MIT-IA, Caliper Survey & WFL) 2010.doc • ~ _~ J~~~~ rA F UNITED STATES ENVIRONMENTAL PROTECTION AGENCY s Ts• REGION 10 Y ~ 21 ~~ ~ y~ 1200 Sixth Avenue, Suite 900 ~ " Seattle, WA 98101-3140 `~ 2 Q ~ - o= ~~~qC PRO'~~'\ ~'~ n'Y - ~ ~ ~ OFFICE OF COMPLIANCE AND ENFORCEMENT Reply To: OCE-082 CERTIFIED MAIL -RETURN RECEIPT REQUESTED ~ Ms. Arlene Chow North Area Operations Manager BP Exploration (Alaska) Inc. P.O. Box 196612 ~ ~ ,, Anchorage, Alaska 99519 --~`'~~ ~~~~~ °~ ~"~ ~~ '` Re: Issuance of Underground Injection Control (UIC) Permit No. AK1I002-B Northstar Unit, North Slope, Alaska Dear Ms. Chow: The U. S. Environmental Protection Agency, Region 10, (EPA) is re-issuing an Underground Injection Control permit for BP Exploration (Alaska) Inc. (BPXA), Northstar Unit (NLT), North Slope, Alaska. The enclosed document authorizes the facility to continue to inject non-hazardous industrial waste utilizing up to two Class I injection wells at the Northstar Unit. The operator is authorized to continue Class I injection activities on August 5, 2010, until midnight August 4, 2020, per the ten year permit. This letter serves as service of notice under 40 C.F.R. 124.19(a). The permit will become effective on the date indicated in the permit unless the Environmental Appeals Board receives a timely appeal meeting the requirements of 40 C.F.R. 124.19. Information about the administrative appeal process maybe obtained on-line at epa.gov/eab or by contacting the Clerk of the Environmental Appeals Board at (202) 233-0122. Sincerel Edwar .Kowalski Director Enclosures cc w/enc: Shawn Stokes, ADEC Division of Water/Wastewater Discharge Permits Dan Seamount, Commissioner, AOGCC Pr/nted on Recycled Paper • • Page 1 of 2 4 ISSUANCE DATE AND SIGNATURE PAGE U.S. ENVIRONMENTAL PROTECTION AGENCY UNDERGROUND INJECTION CONTROL PERMIT: CLASS I Permit Number AK-1I002-B In compliance with provisions of the Safe Drinking Water Act (SDWA), as amended, (42 U.S.C. 300f-300j-9), and attendant regulations incorporated by the U.S. Environmental Protection Agency (EPA) under Title 40 of the Code of Federal Regulations, BP Exploration (Alaska) Inc. (BPXA) (Permittee) is authorized to inject non-hazardous industrial waste utilizing up to two (2) Class I injection wells at the Northstar Unit (located northwest of Prudhoe Bay, in the Beaufort Sea off the North Slope of Alaska), into the Schrader Bluff, Prince Creek/LJgnu and lower Sagavanirktok Formations, in accordance with conditions set forth herein. The current waste disposal system at the Northstar facility utilizes two (2) Class I wells (NS 10 and NS32) both injecting into the Schrader Bluff/Ugnu formation below approximately 8,000 feet measured depth (MD) (approximately 6,500 feet true vertical depth subsea (TVDss)). Northstar is the first joint (State and Federal) offshore Arctic development with surface production facilities situated on an existing gravel island six miles offshore in the Beaufort Sea. Class I injection is critical to the Northstar area development because it is located offshore, remote and isolated from other North Slope infrastructure. With no year-round connecting road, waste storage and transportation is prohibitively expensive and introduces the added potential for spills on the fragile Arctic tundra. Permit Number AK-l I002-A was originally issued by EPA on August 4, 2000, and expires on August 4, 2010. Injection began in January 2001 in well NS 10 and the second injection well, NS32, was completed on May 2, 2004. Total volume of non- hazardous fluids including drill cuttings/muds injected in NS10 acid NS32 since start-up in January 2001 is approximately 32 million barrels (MMB}. The wells have consistently demonstrated sound mechanical integrity (both internal and external) on an annual basis with the testing witnessed by EPA representatives. Well NS 10 was worked over in January 2006 to replace tubing and install new packer. There are no reported underground sources of drinking water (USDWs) at this location. Injection of hazardous waste as defined under the Resource Conservation and Recovery Act (RCRA), as amended, (42 U.S.C: 6901) or radioactive wastes (other than naturally occurring radioactive material (NORM)) are not authorized under this permit. Injection shall not commence until the Permittee has received written authorization from EPA Region 10 Director of the Office of Compliance and Enforcement (Director) to inject. All references to Title 40 of the Code of Federal Regulations are to regulations that are in effect on the date that this permit is issued. Figures and appendices are referenced to the Northstar Development Project Underground Injection Control (UIC) Class I Permit Renewal Application dated February 2, 2010, (and original Permit Application and related material submitted by the Permittee in August 1997 and March, 2000). 5~ • Page 2 of 2 4 This permit renewal shall become effective on August 5, 2010, in accordance with 40 C.F.R. 124.15. This permit and the authorization to inject expire at midnight, August 4, 2020, unless terminated. Signed this~_ day of May, 2010. Edward Tow ski, Director Office f C pliance and Enforcement U.S. Environmental Protection Agency Region 10 (OCE-164) . 1200 Sixth Avenue, Suite 900 Seattle, Washington 98101 Page 3 of 24 TABLE OF CONTENTS ISSUANCE DATE AND SIGNATURE PAGE 1 PART I GENERAL PERMIT CONDITIONS 5 EFFECT OF PERMIT 5 PERMIT ACTIONS 5 Modification, Reissuance, or Termination 5 Transfer of Permits 6 SEVERABILITY 6 CONFIDENTIALITY 6 GENERAL DUTIES AND REQUIREMENTS 6 Duty to Comply 6 Penalties for Violations of Permit Conditions ~ Duty to Reapply ~ Need to Halt or Reduce Activity Not a Defense ~ Duty to Mitigate ~ Proper Operation and Maintenance ~ Duty to Provide Information 7 Inspection and Entry g Records g Reporting Requirements 10 Anticipated Noncompliance 10 Twenty-Four Hour Reporting 10 Other Noncompliance 11 Reporting Corrections 11 Signatory Requirements 11 PLUGGING AND ABANDONMENT 12 Notice of Plugging and Abandonment 12 Plugging and Abandonment Report 12 Cessation Limitation 12 Cost Estimate for Plugging and Abandonment 13 FINANCIAL RESPONSIBILITY 13 • Page 4 of 24 PART II WELL SPECIFIC CONDITIONS CONSTRUCTION Casing and Cementing Tubing and Packer Specifications New Wells in the Area of Review CORRECTIVE ACTION WELL OPERATION Prior to Commencing Injection During Injection Mechanical Integrity Injection Zone Waivers to UIC Program Requirements Injection Pressure Annulus Pressure Injection Fluid Limitation MONITORING Monitoring Requirements Continuous Monitoring Devices Monitoring Direct Waste Injection Alarms and Operational Modifications REPORTING REQUIREMENTS Quarterly Reports Annual Reports Report Certification REPORTING FORMS 14 14 14 14 14 15 15 15 16 17 19 20 21 21 21 21 21 21 22 22 22 22 24 23 24 Page S of 24 PART I GENERAL PERMIT CONDITIONS A. EFFECT OF PERMIT The Permittee is allowed to engage in underground injection in accordance with the conditions of this permit. The underground injection activity, otherwise authorized by this permit, shall not allow the movement of fluid containing any contaminant into underground sources of drinking water, if the presence of that contaminant may cause a violation of any primary drinking water regulation under 40 C.F.R. Part 141 or may otherwise adversely affect the health of persons or the environment. Compliance tivith~ this permit during its term constitutes compliance for purposes of enforcement with Part C of the Safe Drinking Water Act (SDWA). Such compliance does not constitute a defense to any action brought under Section 1431 of the SDWA, or any other law governing protection of public health or the environment from imminent and substantial endangerment to human health or the environment. This permit maybe modified, revoked and reissued, or terminated during its term for cause. Issuance of this permit does not convey property rights or mineral rights of any sort or any exclusive privilege; nor does it authorize any injury to persons or property, any invasion of other private rights, or any infringement of State or local law or regulations: This permit does not authorize any above ground generating, handling, storage, or treatment facilities. This permit is based on the permit renewal application submitted by BPXA on February 2, 2010. Additional materials that were reviewed included the data submitted prior to issuing the original Permit No. AK-1I002-A by EPA in August 2000. B. PERMIT ACTIONS 1. Modification; Reissuance, or Termination This permit may be modified, revoked and reissued, or terminated for cause as specified in 40 C.F.R. §§ 144.39 and 144.40. In addition, the permit can undergo minor modifications for cause as specified in 40 C.F.R. § 144.41. The filing of a request for a permit modification, revocation and reissuance, or termination, or the notification of planned changes, or anticipated noncompliance on the part of the Permittee does not stay the applicability or enforceability of any permit condition. Page 6 of 24 2. Transfer of Permits This permit is not transferable to any person except after notice to the Director on APPLICATION TO TRANSFER PERMIT (EPA Form 7520-7) and in accordance with 40 C.F.R. § 144.38., The Director may require modification or revocation and reissuance of the permit to change the name of the Permittee and incorporate such other requirements as maybe necessary under the SDWA. C. SEVERABILITY The provisions of this permit are severable, and if any provision of this permit or the application of any provision of this permit to any circumstance is held invalid, the application of such provision to other circumstances, and the remainder of this permit, shall not be affected thereby. D. CONFIDENTIALITY In accordance with 40 C:F.R. Part 2, any information submitted to EPA pursuant to this permit maybe claimed as confidential by the submitter. Any such claim must be asserted at the time of submission in the manner prescribed in 40 C.F.R. § 2.203 and on the application form or instructions, or, in the case of other submissions, by stamping the words "confidential" or "confidential business information" on each page containing such information. If no claim is made at the time of submission, EPA may make the information available to the public without further notice. If a claim is asserted, the information will be treated in accordance with the procedures in 40 C.F.R. Part 2 (Public Information). Claims of confidentiality for the following information will be denied: 1. The name and address of the Perrnittee. 2. Information that deals with the existence, absence, or level of contaminants in drinking water. E. GENERAL DUTIES AND REQUIREMENTS Duty to Comply The Permittee shall comply with all conditions of this permit. Any permit noncompliance constitutes a violation of the SDWA and is grounds for enforcement action, permit termination, revocation and reissuance, modification, or for denial of a permit renewal application; except that the Permittee need not comply with the provisions of this permit to the extent and for the duration such noncompliance is authorized in an emergency permit under 40 C:F.R. § 144.34. • Page 7 of24 2. Penalties for Violations of Permit Conditions Any person who violates a permit condition is subject to a civil penalty not to exceed $37,500 per day of such violation. Any person who willfully or negligently violates permit conditions is subject to a fine of not more than $37,500 per day of violation and/or being imprisoned for not more than three years. 3. Duty to Reapply If the Permittee wishes to continue an activity regulated by this permit after the expiration date of this permit, the Permittee must apply for and obtain a new permit. To be timely, a complete application for a new permit must be received at least 180 days before this permit expires. 4. Need to Halt or Reduce ActivityNot a Defense It shall not be a defense for a Permittee in an enforcement action that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of this permit. 5. Duty to Mitigate The Permittee shall take all reasonable steps to minimize or correct any adverse impact on the environment resulting from noncompliance with this permit. 6. Proper Operation and Maintenance The Permittee shall, at all times, properly operate and maintain all facilities and systems of treatment and control (and related appurtenances) which are installed or used by the Permittee to achieve compliance with the conditions of this permit. Proper operation and maintenance includes effective performance, adequate funding, adequate operator staffing and training, and adequate laboratory and process controls, including appropriate quality assurance procedures. This provision requires the operation ofback-up or auxiliary facilities or similar systems only when necessary to achieve compliance with the conditions of this permit. 7. Duty.to Provide Information The Permittee shall provide to the Director, within a reasonable time, any information that the Director inay request to determine whether cause exists for modifying, revoking and reissuing, terminating this permit, or to determine • Page 8 of 24 compliance with this permit. The Permittee shall also provide to the Director, upon request, .copies of records required to be kept by this permit. Inspection and Entry The Permittee shall allow the Director, or an authorized representative, upon the presentation of credentials and other documents as may be required by law to: a. Enter upon the Permittee's premises where a regulated facility or activity is located or conducted, or where records are kept under the conditions of this permit; b. Have access to and copy, at reasonable times, any records that are kept under the conditions of this permit; c. Inspect at reasonable times any facilities, equipment (including monitoring and control equipment), practices, or operations regulated or required under this permit; and d. Sample or monitor at reasonable times, for the purposes of assuring permit compliance or, otherwise, authorized by the SDWA, any contaminants or parameters at any location. 9. Records a. The Permittee shall retain records and all monitoring information, including all calibration and maintenance records and all original strip chart recordings (or electronic data) for continuous monitoring instrumentation, copies of all reports required by this permit and records of all data used to complete this permit application for a period of at least three years from the date of the sample, measurement, report or application. These periods maybe extended by request of the Director at any time. b. 'The Permittee shall retain records concerning the nature and composition of all injected fluids until three years after the completion of plugging and abandonment. At the conclusion of the retention period, if the Director so requests, the Permittee shall deliver the records to the Director. The Permittee shall continue to retain the records after the three-year retention period unless he delivers the records to the Director or obtains written approval from the Director to discard the records. i Page 9 of 24 c. Records of monitoring information shall include: (1) The date, exact place, and time of sampling or measurements; (2) The name(s) of the individual(s) who performed the sampling or measurements; (3) The date(s) analyses were performed; (4) The name(s) of the individual(s) who performed the analyses; (5) The analytical techniques or methods used; and (6) The results of such analyses. d. Monitoring of the nature of injected fluids.shall comply with applicable analytical methods cited and described in Table I of 40 C.F.R. § 136.3, in appendix III of 40 C.F.R. Part 261, or in certain circumstances by other methods that have been approved by the Administrator. All environmental measurements required by the permit, including, but not limited to measurements of pressure, temperature, mechanical integrity, and chemical analyses shall be dorie in accordance with EPA's Quality Assurance Program Plan. f. As part of the completion report, the Permittee must submit a waste analysis plan (WAP). The WAP must include the critical elements needed to satisfy EPA's quality assurance project plan (QAPP) requirement. The WAP must describe the procedures to be carried out to obtain detailed chemical and physical analysis of representative samples of the waste including the quality assurance procedures used including the following: (1) The parameters for which the waste will be analyzed and the rationale for the selection of these parameters; (2} The test methods that-will be used to test for these parameters; and (3) The sampling method that will be used to obtain a representative sample of the waste to be analyzed. This permit covers active Class I wells that have been in operation since January 2001. The WAP from the permit application maybe incorporated by reference to satisfy the WAP plan submittal requirements. Page 10 of 24 g. For waste streams that are not hard piped and continuous, the Permittee shall complete a written manifest for each batch load of waste received. The manifest shall contain a description of the nature and composition of all injected fluids, date of receipt, source of material received for disposal, name and address of the waste generator, a description of the monitoring performed and the results, a statement stating if the waste is exempt from regulation as hazardous waste as defined by 40 C.F.R. § 261.4, and any information on extraordinary occurrences. For waste streams that are hard-piped continuously from the source to the wellhead, the Permittee shall provide for continuous, recorded measurement of the discharge rate. h. Dates of the most recent calibration or maintenance of gauges and meters used for monitoring required by this permit shall be noted on the gauge or meter. Earlier records shall be available through a computerized maintenance history database. 10. Reporting Requirements The Permittee shall give notice to the Director, as soon as possible, of any planned physical alterations or additions to the permitted facility or changes in type of injected waste. 11. Anticipated Noncompliance The Permittee shall give advance notice to the Director of any significant planned changes in the permitted facility or activity that may result in noncompliance with permit requirements. 12. Twenty-Four Hour Reporting a. The Permittee shall report to the Director or an authorized representative any noncompliance that may endanger health or the environment. Any information shall be provided orally within 24 hours from the time the Permittee becomes aware of the circumstances. The following shall be included as information that must be reported orally within 24 hours: (1) Any monitoring or other information that indicates that any contaminant may cause an endangerment to an underground source of drinking water. (2) Any noncompliance with a permit condition or malfunction of the injection system. i Page 11 of 24 b. A written submission shall also be provided within five (5) days of the time the Permittee becomes aware of the circumstances. The written submission shall contain a description of the noncompliance and its cause, the period of noncompliance, including exact date and times, and, if the noncompliance has not been corrected, the anticipated time it is expected to continue, and steps taken or planned to reduce, eliminate, and prevent recurrence of the noncompliance. 13. Other Noncompliance The Permittee shall report all other instances of noncompliance not otherwise reported at the time monitoring reports are submitted. The reports shall contain the information listed in Permit Condition E.12.b. 14. Reporting Corrections When the Permittee becomes aware that he/she failed to submit any relevant facts in the permit application or submitted incorrect information in a permit application or in any report to the Director, the Permittee shall promptly submit such facts or corrected information. 15. Si atory Requirements a. All permit submittals required by this permit and other information requested by the Director shall be signed by a principal executive officer of at least the level ofvice-president, or by a duly authorized representative of that person. A person is a duly authorized representative only if: (1) The authorization is made in writing by a principal executive of at least the level ofvice-president. (2) The authorization specifies either an individual or a position having responsibility for the overall operation of the regulated facility or activity, such as the position of plant manager, operator of a well or a well field, superintendent, or position of equivalent responsibility. A duly authorized representative may thus be either a named individual or any individual occupying a named position. (3) The written authorization is submitted to the Director. b. If an authorization under paragraph 15.a. of this section is no longer accurate because a different individual or position has responsibility for Page 12 of 24 the overall operation of the facility, a new authorization satisfying the requirements of paragraph a. of this section must be submitted to the Director prior to or together with any reports, information, or applications to be signed by an authorized representative. c. .Any person signing a document under paragraph 15.a. of this section shall make the following certification: "I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment." F. PLUGGING AND ABANDONMENT Notice of Plu~~in~ and Abandonment The Permittee shall notify the Director no later than 45 days before conversion or abandonment of any Class I well(s). 2. Plu~gin~ and Abandonment Report The Permittee shall plug and abandon the well as provided in the Well Abandonment portion (Section 1.3 and Exhibit 1-7C/EPA Form 7520-14 of the February 2, 2010, permit application), which is hereby incorporated as a part of this permit or an updated plan approved by the Director or EPA representative. Abandonment plans will be implemented in accordance with AOGCC and EPA regulatory requirements, as well as utilizing current technology applicable to the condition of the well at the time. Within 60 days after plugging any well the Permittee shall submit a report to the Director in accordance with 40 C.F.R. § 144.51(p). EPA reserves the right to change the manner in which the well will be plugged if the well is not proven to be consistent with EPA requirements for construction and mechanical integrity. The Director may ask the Permittee to update the estimated plugging cost periodically. Cessation Limitation After cessation of facility operations of two years, the Permittee shall plug. and abandon the well in accordance with the plan unless he/she: a. Provides notice to the Director; Page 13 of 24 b. Demonstrates that the well will be used in the future; or c. Describes actions or procedures, satisfactory to the Director that the Permittee will take to ensure that the well will not endanger underground sources of drinking water during the period of temporary abandonment. These actions and procedures shall include compliance with the technical requirements applicable to active injection wells unless waived by the Director. 4. Cost Estimate for Plug ing and Abandonment a. The Permittee estimates the 2010 cost of plugging and abandonment of the permitted Class I wells NS 10 and NS32 to be approximately one million dollars per well. The Permittee must submit financial assurance and a revised plugging and abandonment estimate prior to April each year. The estimate shall be made in accord with 40 C.F.R. § 144.62. b. The Permittee must keep at the facility at Northstar or at the Perrnittee's central files in Anchorage during the operating life of the facility the latest plugging and abandonment cost estimate. When the cost estimate changes, the documentation submitted under 40 C.F.R. § 144.63(f) shalLbe amended to ensure that appropriate financial assurance for plugging and abandonment is maintained continuously. d. .The Permittee must notify the Director by registered mail of the commencement of a voluntary or involuntary proceeding under Title 11 (Bankruptcy), U.S. Code, naming the owner or operator as debtor, within ten business days after the commencement of the proceeding . G. FINANCIAL RESPONSIBILITY The Permittee shall maintain continuous compliance with the requirement to maintain financial responsibility and resources to close, plug, and abandon the underground injection well. If the financial test and corporate guarantee provided under 40 C.F.R. § 144.63(f) should change, the Permittee shall immediately notify the Director in writing. The Permittee shall not substitute an alternative demonstration of financial responsibility for that which the Director has approved, unless it has previously submitted evidence of that alternative demonstration to the Director and the Director notifies him that the alternative demonstration of financial responsibility is acceptable. CJ PART II <,,,;_. Page 14 of 24 WELL SPECIFIC CONDITIONS A. CONSTRUCTION Casing and Cementing of Existing Sidetrack and/or Replacement Wells The Permittee shall case and cement the well(s) to prevent the movement of fluids into strata other than the authorized injection interval (see II.C.3, below). Casing and cement shall be installed in accordance with a casing and cement program approved by the Director and in accordance with EPA Class I well construction practices (40 C.F.R. § 146.12) and will also follow the State of Alaska/AOGCC Regulations (20 AAC 25.412 and 20 AAC 25.252). For any other future Class I wells to be drilled at this location (including replacement/sidetracks), in addition to the above requirements, the Permittee shall provide not less than ten days advance notice to the Director or EPA authorized representative to witness all cementing operations. If primary cement returns to surface are not observed for the surface casing cementing procedure, the Director or an authorized representative is to be notified as to the nature of the augmented testing proposed to ensure the integrity of the cement bond and adequacy of any Top Job procedure. Note: Since these are existing Class I wells NS 10 and NS32 drilled, cemented and completed as per EPA and AOGCC regulations in 2001 and 2004 respectively, EPA is accepting the current well casing and cementing configuration as meeting the requirements of this section. 2. Tubing and Packer Specifications The well shall inject fluids through tubing with a packer. The current tubing and packer locations for well and NS32 are approved. In future sidetracks, replacement wells and workovers to install new tubing, the tubing and packer shall be installed in the casing with the packer set not more than 100 feet MD from the top of the permitted injection zone/interval (based on well testing and reservoir/log analysis) and confirmed by tubing tally. In the event that the packer needs to be re-set at a revised depth at a later date, the Permittee will submit the necessary data and obtain authorization from EPA, prior to resumption of continued injection activities. 3. New Wells in the Area of Review New wells within the Area of Review (AOR) shall be'constructed in accordance with the EPA and AOGCC Regulations Title 20, Chapter 25. Further, all wells that penetrate the injection intervals within the area of review shall have casing • Page 15 of 24 cemented to the formation throughout the entire section from at least the top of the lower confining zone (Colville/Seabee CM3 Formation Marker underlying the Schrader Bluff injection interval) to at least 100 feet TVD above the top of the permitted secondary Sagavanirktok injection interval SV2 (from approximately 6,784 feet TVDss to the SV2 marker at 4,042 feet TVDss) based on NS32 completion logs. B. CORRECTIVE ACTION The applicant has identified two wells within the areas of review for-wells NS10 and NS32 at the Northstar project site. If the applicant later discovers that a well or wells within the AOR require(s) corrective action to prevent fluid movement, then the applicant shall inform EPA upon such discovery and provide a corrective action plan for EPA Director or authorized representative review and approval. If EPA or the Permittee discovers that fluids have moved above the upper confining zone along a wellbore within the AOR, then injection shall cease until. the fluid movement problem can be diagnosed and corrected. C. WELL OPERATION 1. Prior to Commencing Injection Under This Permit in Existing. Sidetrack or Replacement Wells Injection operations pursuant to this permit shall not commence until: a. Construction is complete and the Permittee has submitted two copies of COMPLETION FORM FOR INJECTION WELLS (EPA Form 7520-9), see APPENDIX A; and b. The Director or authorized representative has inspected or otherwise reviewed the new, existing, sidetrack or replacement injection well(s) and finds it is in compliance with the conditions of the permit; or the Permittee has not received notice from the Director or authorized representative of intent to inspect or otherwise review the new, sidetrack or replacement injection well(s) within thirteen days of receiving the COMPLETION REPORT in which case prior inspection or review is waived and the Permittee may commence injection; and c. The Permittee demonstrates that the well has mechanical integrity as described in Part II.C.3. below and the Permittee has received notice from the Director or authorized representative that such a demonstration is satisfactory. The Permittee shall notify EPA at least four weeks prior to conducting this initial test so that an EPA representative may be present. Note• Since these wells NS 10 and NS32 Have been on injection since • Page 16 of 24 January 2001 and May 2004 respectively and with mechanical integrity successfully demonstrated on an annual basis since 2001 the requirements of C.l.a. and C.l.b. from above have been met However the requirements under Part II. C 3 -Mechanical Integrity remain in force for wells NS10 and NS32; and d. The Permittee has conducted astep-rate injection test (SRT) and submitted a preliminary report to EPA that summarizes the results. A SRT was conducted in April 1999 and the results were submitted to EPA. Therefore, the Permittee is not required to conduct another SRT prior to resumption of Class I injection activities upon renewal. 2. During Injection Recording and non-recording inj ection pressure gauges, inner annulus (IA) and outer annulus (OA) gauges, injection rate gauges, and temperature gauges will be maintained. Out-of--limit Alarms and shut-off systems will be maintained and the injection facility plant shall be manned by trained and qualified operators during injection. Visual and automatic monitoring of the IA and tubing pressures will occur routinely with pre-set, out-of--limit alarms to inform supervisory personnel. 3. MechanicalInte~rity a. Standards The injection well(s) must have and maintain mechanical integrity pursuant to 40 C.F.R. ~ 146.8. b. Prohibition without Demonstration of Mechanical Integrity Injection operations are prohibited after the effective date of this permit unless the Permittee has conducted the following tests and submitted the results to the Director: (1) In order_to demonstrate there is no significant leak in the casing, tubing or packer, the tubing/casing annulus must be pressure tested to at least 3,500 pounds per square inch gauge (psig) for not less than thirty minutes. Pressure shall show a stabilizing tendency. That is, the pressure may not decline more than ten percent during the 30-minute test period and shall experience less than one-third of its total loss in the last half of the test period. If the total loss exceeds five percent or if the loss during the second 15 minute period is equal to or greater than one-half the loss during the first 15 minutes, the Permittee may extend the test period for an • Page 17 of 24 additiona130 minutes to demonstrate stabilization. Since these wells have been on injection since January 2001 and May 2004 respectively and have successfully demonstrated their mechanical integrity (both internal and external) on an annual basis (with the tests being witnessed by EPA representatives), the wells are approved to continue injection upon approval of this permit renewal. The SAPT will be required annually if the well(s) is active and once every two years if the well(s) are inactive. The SAPT due dates maybe extended up to three months to accommodate constraints resulting from drilling, operational.or other logistics related to operating in the Arctic North Slope environment. At the discretion of the Director, and depending on the results of the SAPT (inner annulus mechanical integrity test) data, the frequency for demonstrating internal mechanical integrity (no leaks in the tubing-casing annulus or in the tubing-packer assembly) may bexevised (either increase or decrease in frequency) as specified and approved by the Director or authorized representative. (2) To detect movement of fluids in vertical channels adjacent to the well bore and to determine that the confining zone is not. fractured, an approved fluid movement test shall be conducted at an injection pressure at least equal to the average continuous injection pressure observed in the previous six months. Approved fluid movement tests include, but are not limited to tracer surveys, temperature logs, noise logs, oxygen activation/water flow logs (WFL), borax pulse neutron logs (PNL), or other equivalent logs. Fluid movement tests not previously used to satisfy this requirement . must be submitted 30 days in advance and are subject to prior approval by the Director or authorized representative. Copies of all logs shall be accompanied by a descriptive and interpretive report. Fluid movement/confinement logs will be run initiall upon completion of the new or replacement or sidetrack well and prior to initiation of injection at start-up. After acquiring this baseline data, the fluid movement/confinement logs will be required every two years while the well(s) are active until expiration of the ten year permit period. The test due dates maybe extended up to three months to accommodate constraints related to operating in the Arctic North Slope environment. At the discretion of the Director, and depending on the results of the baseline data, the frequency for demonstrating external mechanical integrity (no flow behind pipe that penetrates the confining zone) and utilizing alternative diagnostic techniques, may be revised (either increase • CJ Page 18 of 24 or decrease in frequency) as specified and approved by the Director or authorized representative. (3) Tubing inspection logs (pipe analysis logs, caliper logs, or other equivalent logs) shall be run once every two years while the well(s) are active, or at the Director or authorized representative's discretion, to monitor condition, thickness and integrity of the do~vnhole tubing. A three month grace period is granted to the test due dates. Any exposed section of the injection casing previously located behind the tubing tail must be logged during any scheduled workover for tubing change-out. In the event that (1) surveillance determines tubing above the packer wall losses or casing above the packer wall losses exceed 80% of the wall thickness or (2) for other reasons, EPA or Permittee believe the downhole tubular integrity maybe compromised, surveillance logs and other information shall be reviewed by EPA and Permittee to determine if additional surveillance or remedial activities are necessary. EPA reserves the right to have the Permittee shut in the well pending diagnostics or well repair, or until a successful tubing/casing annulus pressure test under Part II C.3.b(1). Copies of the logs shall be accompanied by a descriptive and interpretive report. c. Terms and Reporting (1) Two copies of the log(s) and two copies of a descriptive and interpretive report of the mechanical integrity tests identified in C.3.b shall be submitted within 45 days of completion of the testing and logging. (2) Mechanical integrity shall also be demonstrated by the pressure test in Part II C.3.b (1) any time the tubing is removed from the well or if a loss of mechanical integrity becomes evident during operation. The Permittee shall report the results of such tests within 45 days of completion of the tests. (3) After the initial mechanical integrity demonstration, the Permittee shall notify the Director of intent to demonstrate mechanical integrity at least 30 days prior to subsequent demonstrations. (4) The Director will notify the Permittee of the acceptability of the mechanical integrity demonstration within thirteen days of receipt of the results of the mechanical integrity tests. Injection operations may continue during this thirteen day review period. If the Page 19 of 24 Director does not respond within thirteen days, injection may continue. (5) In the event that the well fails to demonstrate mechanical integrity during a test or a loss of mechanical integrity occurs during operation, the Permittee shall halt operation immediately and shall not resume operation until the Director or EPA authorized representative gives approval to resume injection. (6) The Director may, by written notice, require the Permittee to demonstrate mechanical integrity at any time. 4: Infection Zone Injection shall be limited to the Schrader Bluff/Ugnu (current primary injection interval) and Sagavanirktok (future secondary injection interval for use if needed) Formations, below the top of the Sagavanirktok SV2 formation marker at approximately 4,042 feet TVDss as depicted on the NS32 electric logs. The permitted injection zone extends to the CM3 marker estimated at 6784 feet TVDss in NS32. Waivers to UIC Program Requirements As a result of the "no USDW" ruling for Class I injection granted by EPA in 2000 when the original permit was issued, EPA is granting three waivers of UIC regulatory program requirements as listed below: a. Compatibility of Formation and Injectate (40 C.F.R.` §§ 146.12(e) and 146.14(a)(8)): Based upon the applicability of past injection studies, petrophysical logging data and existing rock and fluid data (utilized in the fracture model studies) and successful injection practices at Northstar since January 2001, EPA waives the above two requirements for any additional sampling and characterization of formation fluids and injection rock matrix in order to determine whether or not they are compatible with the proposed injectate. b. Infection Zone Fracturing (40 C.F.R. § 146.13(a)}: Class I injection wells are prohibited from injection at pressures that would initiate new fractures or propagate existing fractures within the injection zone. Based on the successful ten year performance history at NS 10 and NS32 and the fracture modeling data submitted by BPXA • Page 20 of 24 which confirms that the injection fluids are contained within the injection zone, the EPA permit waives this prohibition. In no case shall injection pressures initiate fractures in the upper and lower confining intervals. Ambient Monitoring Above the Confining Zone (40 C F R ~ 146 13(a))• There are no USDWs (between the base of the permafrost at approximately 1,519 feet TVDss and the top of the injection zone at approximately 4,042 feet TVDss) (based on NS32 electric logs) in this area, no transmissive faults within 1/z mile of the current injection wells, the formations are thick and laterally extensive, and the possibility of any waste migration above the upper confining zone is extremely low (fracture height contained within the injection zone). Also, the only two wells within the AOR are adequately cemented and therefore do not require any corrective action. Therefore, EPA is waiving the requirement to monitor the strata overlying the confining zone for fluid movement. However, external mechanical integrity demonstrations are required, to verify that all injected fluids are exiting the injection interval and that there is no flow behind pipe due to channeling etc. (See Part II C.3.b(2)). Injection Pressure Injection pressure shall not initiate new fractures or propagate existing fractures in the upper confining zone as that stratigraphic interval (SV6 marker at approximately 3,047 feet TVDss and a base at 3305 feet TVDss) described in the NS32 electric logs. Although no surface injection pressure limit is specified in the permit, it should be noted that the wellhead working pressure limit of 5000 psi should not be exceeded at any time. Besides alarms and automatic shutdown controls, the wellhead assembly will include a surface safety valve to provide additional security. Annulus Pressure The annulus between the tubing and the long string casing shall be filled with a corrosion inhibited non-freezing solution. To accommodate swings in wellbore temperatures and tubing thermal expansion, a positive surface pressure up to 1500~sig is authorized for the inner annulus (tubing x long string injection casing). Since the tubing-casing annulus volume -will vary due to temperature changes, the high-low annulus pressure limits can be adjusted, if necessary and upon approval by the Director or EPA authorized representative. Page 21 of 24 Note: The authorization of up to 1500 psig on the inner annulus is to enable shut- down and alarm systems to be set at appropriate pressure limits, so as not to -shut- down the facility from unintended causes not related to direct injection activities, and is not intended to allow the Permittee to continue to maintain the well on injection, in the evenf of a loss of mechanical integrity or when there is pressure build-up either in the tubing x inner annulus or between the injection casing and surface casing (between the IA x OA), resulting in a potential sustained casing pressure (SCP) scenario. In the event of a loss of mechanical integrity, then the Permittee has to meet the requirements as outlined in Part II.C.3.c.5 of this permit. 8. Ini ection Fluid Limitation This permit only authorizes the injection of those fluids identified in the permit documentation. In the event that third party wastes are accepted, the third party must certify that fluids for injection are not hazardous waste or radioactive wastes. Fluids generated from Class I inj ection well construction and well workover, and fluids generated from the operation and maintenance of Class I injection wells and associated injection well piping, maybe disposed in a Class I non-hazardous injection well. De-characterized waste generated during remedial well workovers or well construction operations maybe appropriately disposed in aClass Inon-hazardous well (refer to 40 C.F.R. § 148.4(d)). NOTE: Neither hazardous waste as defined in 40 C.F.R. § 261 nor radioactive wastes other than naturally occurring radioactive material (NORM) from pipe scale shall be injected for disposal. D. MONITORING 1. Monitoring Requirements Samples and measurements collected for the purpose of monitoring shall be representative of the monitored activity. 2. Continuous Monitoring Devices Continuous monitoring devices shall be installed, maintained, and used to monitor injection pressure and rate for those streams that are hard-piped and continuous, and to monitor the pressure ofnon-freezing solution in the annulus between the tubing and the long string casing. Calculated flow data are not acceptable except as a back-up system if the primary continuous injection rate device malfunctions. • Page 22 of 24 3. Monitoring Direct Waste Injection Direct waste injection pumping operations at the well site shall be continuously manned and visually monitored. During these pumping operations, a chronological record of the time of day, a description of the waste pumped, injection rate and pressure, and well annulus pressure observations shall be maintained. The pumping record must be signed by the person in charge. 4. Alarms and Operational Modifications a. The Permittee shall install, continuously operate, and maintain alarms to detect excess injection pressures and significant changes in annular fluid pressures. These alarms must be of sufficient placement and urgency to alert operators in the control room. b. The Permittee shall install and maintain an emergency shutdown system to respond to losses of internal mechanical integrity as evidenced by deviations in the annular fluid pressures. c. Plans and specifications for the alarms shall be submitted to the Director or authorized representative prior to the initiation of injection. Since Wells NS 10 and NS32 are existing Class I wells and have been on infection since January 2001 and current information was submitted in the February 2 2010 permit application the monitoring and alarm systems in place for Wells NS 10 and NS32 are hereby approved as meeting the requirements of this section. E. REPORTING REQUIREMENTS Quarterly Reports The Permittee shall submit quarterly reports to the Director containing the following information: a. Monthly average, maximum, and minimum values for injection pressure, rate, and volume shall be reported on INJECTION WELL MONITORING REPORT (EPA Form 7520-8). b. Graphical plots of continuous injection pressure and rate monitoring. Raw monitoring data in an electronic format. d. Physical, chemical, and other relevant characteristics of the injected fluid. • Page 23 of 24 e. Any well workover or other significant maintenance of downhole or injection-related surface components. £ Results of all mechanical integrity tests performed since the previous report including any maintenance-related tests and any "practice" tests. g. Any other tests required by the Director. 2. Report Certification All reporting and notification required by this permit shall be signed and certified in accordance with Part I.E.15., and submitted to the following address: Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency (OCE-164} 1200 Sixth Avenue, Suite 900 Seattle, Washington 98101 Any notification to an EPA authorized representative maybe submitted to the following address: UIC Manager, Ground Water Unit U.S. Environmental Protection Agency (OCE-082) 1200 Sixth Avenue, Suite 900 Seattle, Washington 98101 • • Page 24 of 24 APPENDIX A REPORTING FORMS Enclosed are EPA Forms: 7520-7 APPLICATION TO TRANSFER PERMIT 7520-8 INJECTION WELL MONITORING REPORT 7520-9 COMPLETION FORM FOR INJECTION WELLS LJ OMB No. 2040-0042 Aooroval EYOlfes 12/31/2011 United States Environmental Protection Agency ~~EPA Washington, DC 20460 Application To Transfer Permit Name and Address of Existing Penriittee Name and Address of Surface Owner ( I ~ i i Locate Wst! and Ou!!ine Uni4 on Section Plat - 640 Acres W ~ ~ ~ -~~- ~ ~ 1 f -t-~-t- _ -r_ T I ~ I T~ ~rT~ I 1 1 I -F-~-- --~--~--~- State County Permit Number ' i k i Surface Location Description ~!,__,'•1/4of _,~1l4ot~1/4 of~~1/4 of Section~!Township!_~Range Locate well in two directions from nearest lines of quaRer section and drilling unit Surface Location ~ ift. frm (NIS) ~~~ Line of quarter section andi_„^!ft. from (E/W),~„-_Line of quarter section. Well Activity Well Status ;-,,E Class I Class II Brine Disposal i ~ Enhanced Recovery ~.,,,,,-',t Hydrocarbon Storage __! Class III -~~ Other Lease Number r l( Operating !~-+ ModificationlConversion ~ Proposed Type of Permit +~-I Individual 'Area ,Number of Wells ~ WeII.Number j E I Name(s) and Address(es) of Naw Owner(s) Name and Address of New Operator f r ~ i ! . Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permitfee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. Certification 1 certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed i crn rune rya-r ~tcev, rt-uo) PAPERWORK REDUCTION ACT The public reporting and record keeping burden forthis collection of information is estimated to average 5 hours per response. Burden means the totattime-effort,-or financiatresourceexpended by persons to generate; maintairi,-retain; or disclose or provide information to or for a Federal Agency. This includes the time needed to review instructions; develop, acquire, install, and utilize technology and systems for the purposes of collecting, validating, and verifying information, processing and maintaining information, and disclosing and providing information; adjust the existing ways to comply with any previously applicable instructions and requirements; train personnel to be able to respond to the collection of information; search data sources; complete and reviewthe collection ofinformation;and, transmitorotherwisedisclosethe information.An agencymay not conduct orsponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB control number. Send comments on the Agency's need for this information, the accuracy of the provided burden estimates, and any suggested methods for minimizing respondent burden, including the use of automated collection techniques to Director, Collection Strategies Division, U.S. Environmental Protection Agency (2822), 1200 Pennsylvania Ave., NW, Washington, D.C. 20460. Include-the OMB control number in any correspondence. Do not send the completed forms to' this address. Weli Ciass and Type Code Class I Wells used to inject waste below the deepest underground source of drinking water. Type "I" Nonhazardous industrial disposal well "M" Nonhazardous municipal disposal well "W" Hazardous waste disposal well injecting below USDWs "X" Other Class I wells (not included in Type "I," "M," or "W") Class I! Oil and gas production and storage related injection wells. Type "D"' Produced fluid disposal well "R" Enhanced recovery well "H" Hydrocarbon storage well (excluding natural gas) "X" Other Class Il wells (not included in Type "D," "R," or "H") Class III Special process injection wells. Type "G" Solution mining well "S" Sulfur mining well by Frasch process "U" Uranium mining well "X" Other Class III wells (not included in Type "G," "S," or "U") Other Classes Wells not included in classes above. Class V wells which may be permitted under § 144.12 Wells not currently classified as Class I, II, III, or V EPA Form 7520-7 (12-08) Reverse • • OMB No. 2040-0042 Approval Expires 1 2131120 1 1 United States Environmental Protection Agency ~~EPA Washington, DC 20460 .Injection Weil Monitoring Report ------ - - -- Year -- -- - --- -- . _ _...-___- NYonth---..... ___...- .. ._ _ .._ _.__. Month-_ __ ._ __ _ _ _ Month---- . _ _ Injection Pressure (PSI) ( i r 1. Minimum i i 1 E I 2. Average i i i t 3. Maximum ~ 1 j f ~ ~ l Injection Rate (GaI1Min) I ! ; i 1. Minimum j i i ' t ~- 2. Average j { ~ ; f _ 3. Maximum ~ ~ i ~ 4 Annular Pressure (PSI) r ~ i ; - ~ ! 1. Minimum ` ' 2. Average E ' ! j 3. Maximum i I I i ~ i Injection Volume (Gal) ; f ! i t 1. Monthly Total . ! ! I 2. Yearly Cumulative ' i , i I Temperature (F °) { ~ 1 i i ~ _ 1. Minimum . ~ ~ ~ I 2. Average I ~ z , ~ ; ~ _ 3. Maximum { i f ~ ~ i p H f i ~______~.____.~ -J 1. Minimum ( ~ E ~ I I 1 ~ 2. Average j 3. Maximum ~ L ~-~ I ..~ Other L i I I i ~ z ~ i ~ ~ ( _ # _._____ ~.. z Name and Address of Permittea Permit Number ------ I k -- - Name and Official Title Please tYee or riot - - -- Signature Date Signed ~ EPA Form 7520-8 (Rev. 12-08) r~ u OMB No. 2040-0042 Approval Expires 1213112011 United States Environmental Protection Agency :EPA Washington, DC 20460 Completion Form For Injection Vllells __._ _. __ Administrative-.lnformatior .__ _.___ .-- _ -- __ _ _ _..__ .. _ 1. Permittee I ___ _i Address (Permanent Mailing Address) (Street, City, and ZIP Code) i i i i 2. Operator 1 S i Address (Street, City, State and Z1P Code) I . i { 3. Facility Name Telephone Number kk ~ 4 ~ Address (Street, City, State and Z1P Code) I ~ i ' i 4. Surface Location Description of Injection Well(s) State County ~ i ~ ~ I I Surface Location Description i r--_ ! ii/4 of f1/4 of ~-114 of; !114 of Section ice! Township- Ranged ~ Locate well in two directions from nearest lines of quarter section and drilling unit Surface ~-~ Location; i ft. frm (N/S) !_ Line of quarter section and ft: from (E/VII) _ _, 'j Line of quarter section. Well Activity Well Status Type of Permit ! E Class I ! !1 .Operating ~ Individual ~-! 4 ~ Class II t ModificationlConversion __' Area :Number of Welis(~i t--'Brine Disposal , Proposed - r 'Enhanced Recovery i +Hydrocarbon Storage ^_~ Class III ~~ Other Lease Number; Well Number I Submit with this Completion Form the attachments listed in Attachments for Completion Form. Certification 1 certify under the penalty of law that I have personalty examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Tille (Please type or printt r Signature ~ Date Signed ~~ ._~_ i i_ _._._. _ ~_ _ __ _ EPA Form 7520-9 (Rev. 12-08) PAPERWORK REDUCTION ACT The public reporting and record keeping burden for this collection of information is estimated td average 49 hours per response fora Class I hazardous facility, and 47 hours per response for aClass Inon-hazardous facility. Burden means the total time, effort, or financial resource expended by persons to generate, maintain, retain, or disclose or provide information to odor a Federal Agency. This includesthe time needed to review instructions; develop, acquire, install, and utilize technology and systems for the purposes of collecting, validating, and verifying information, processing and maintaining information, and disclosing and providing information; adjust the existing ways to comply with any previously applicable instructions and requirements; train personnel to be able to respond to the collection of information; search data sources; comprete and review the collection-of information; and; transmit-or otherwise disclose- the- information. Art agency may notconduct or sponsor,- and aperson is not required to respond to, a collection of information unless it displays a currently valid OMB control number. Send comments on the Agency's need for this information, the accuracy of the provided burden estimates, and any suggested methods for minimizing respondent burden, including the use of automated collection techniquesto Director, Collection Strategies Division, U.S. Environmental Protection Agency (2822), 1200 Pennsylvania Ave., NW, Washington, D.C. 20460. Include the OMB control number in any correspondence. Do not send the Cumpietcd fVIT$ to th 15 addi es5. Attachments to be submitted with the Completion report: I. Geologic Information 1. Lithology and Stratigraphy A. Provide a geologic description of the rock units pene- trated by name, age, depth, thickness, and lithology of each rock unit penetrated. B. Provide a description of the injection unit. (1) Name (2) Depth (drilled) (3) Thickness (4) Formation fluid pressure (5) Age of unit (6) Porosity (avg.) (7) Permeability (8) Bottom hole temperature (9) Lithology (10) Bottom hold pressure. (11) Fracture pressure 4. Provide data on centralizers to include number; type and depth. 5. Provide data on bottom hole completions. 6. Provide data on well stimulation used. III. Description of Surface Equipment 1. Provide data and a sketch of holding tanks, flow lines, filters, and injection pump. IV. Monitoring Systems 1, Provide data on recording and nonrecording injection pressure gauges, casing-tubing annulus pressure gauges, injection rate meters, temperature meters, and other meters or gauges. 2. Provide data on constructed monitor wells such as location, depth, casing diameter, method of cementing, etc. C. Provide chemical characteristics of formation fluid (attach chemical analysis): D. Provide a description of freshwater aquifers (1) Depth to base of fresh water (less than 10,000 mg/I TDS). (2) Provide a geologic description of aquifer units with name, age, depth, thickness, lithology, and average total dissolved solids. II. Well Design and Construction 1. Provide data on surface, intermediate, and long string casing and tubing. Data must include material, size, weight, grade, and depth set. 2. Provide data on the well cement, such as type/class, additives, amount, and method of emplacement. 3. Provide packer data on the packer (if used) such as type, name and model, setting depth, and type of annular fluid used. V. Logging and Testing Results Provide a descriptive report interpreting the results of . geophysical logs and other tests. Include a description and data on deviation checks run during drilling. VI. Provide an as-built diagrammatic sketch of the injec- tionwell(s) showing casing, cement, tubing, packer, etc., with proper setting depths. The sketch should include well head and gauges. VII. Provide data demonstrating mechanical integrity pursuant to 40 CFR 146.08. VIII. Report on the compatibility of injected wastes with fluids and minerals in both the injection zone and the confining zone. IX. Report the status of corrective action on defective wells in the area of review. X. Include the anticipated maximum pressure and flow rate at which injection wiil operate. EPA Form 7520-9 Reverse • s -. Paperwork Reduction Act The public reporting and record keeping burden for this collection of information is estimated to average 2S hours per quarter for operators of Class I hazardous wells, 16 hours per quarter for operators of Class I non- hazardous wells, and 30 hours per quarter for operators of Class III wells. Burden means the total time, effort, or financial resource expended by persons to generate, maintain, retain, or disclose or provide information to or for a Federal Agency. This includes the time needed to review instructions; develop, acquire, install, and utilize technology and systems for the purposes of collecting, validating, and verifying information, processing and maintaining information, and disclosing and providing information; adjust the existing ways to comply with .any previously applicable instructions and requirements; train personnel to be able to respond to the collection of information; search data sources; complete and review the collection of information; and, transmit or otherwise disclose the information. An agency may no.t conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB control number. Send comments on the Agency's need for this .information, the accuracy of the provided burden estimates, and any suggested methods for minimizing respondent burden, including the use of automated collection techniques to Director, Collection Strategies Division, U.S. Environmental Protection Agency (2822), 1200 Pennsylvania Ave., NW., Washington, D.C. 20460. Include the OMB control number in any correspondence. Do not send the completed forms to this address. EPA Form 7520-8 Reverse BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 • tt k t~M'~' Sk.v~/ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, °"" b Ns' ~ by ~~~ ~ AY p ~ 2010 .~~~d ~~o-I$~' Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) I ilia Date Northstar a/~n/~n1 n Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 .2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NSO6 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NS08 20 0210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30!2009 NSi1 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na * na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3!2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 * na * na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. • Proposed Schedule for 2010 Mechanical Integrity Testing Class I Well (s) MIT Deadline Proposed MIT Flexibility Fluid Movement test date in test Logs Planned after date? MIT? Milne Point By April 6, 2010 Late March/Early Fluid movement logs MPB-50 April 2010 are not required till -~ ~ ~v 2011. Badami B1-01 By September Late July 2010 Weather Fluid movement logs 15, 2010 permitting are required in 2010 because of the scheduled drilling program and are planned during the ~~~ ~ t 5 ~ summer barge season. Northstar NS10 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer a~~' ~~~- bar a season. Northstar NS32 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer a®~'" ~~~ bar a season. Liberty CRI Well N/A September 2010 All logs required to complete the well will ~®~- ~ ~~, ~~ ~ ~ ~- be scheduled with the MIT. Pad 3 - NW, SE, By September Late September Yes Borax-RST logs for and SW 26, 2010 for SE /Early October, each well, scheduled Oq-~ a ~ `~ and NW wells 2010 with MIT's. and by Caliper logs in ~~ ~ November 7, summer/fall 2010. ^a~ u 2010 for SW well (Can be 3 months later with Director discretion Grind and Inject By October 25, Late September Yes Shut -In Temperature -GNI-02A, GNI- 2010 forGNI- /Early October, Logs and/or Water 03 ,and GNI-04 02A, GNI-03 and 2010 Flow Logs planned for ~~~~ ~~~ GNI-04. summer 2010. Caliper logs in 1 R " ~ ~ summer/fall 2010. ~°~~ ~~~ ~~,~~~ ~"~d ~~ L 20~ by • Alison D. Cooke Environmental Advisor, Air Quality CERTIFIED MAIL # 7008 1830 0001 2703 7263 February 23, 2010 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 Mr. Shawn Stokes Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 ;~~t ,. ~1 A e a 5' BP Exploration (Alaska) Inc. P. 0. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 Direct 907 561 5111 Phone: (907) 564-4838 Email: Alison.Cooke~bp.com Web: www.bp.com -~ ~ FEB ~ 4 201' ~~l~ ~(,: ~~ RE: Mechanical Integrity Test Notifications Badami Class 1 Iniection Well, UIC_ Permit AK-11001-A, Disposal Iniection Order No. 12 General Wastewater Permit No 2005DB001-0010 Northstar Class 1 Iniection Wells, UIC Permit AK-11002-A General Wastewater, Permit No. 2005DB001-0020 Milne Point Iniection Well, UIC Permit AK-11005-A General Wastewater Permit No. 2005DB001-0001 Pad 3 Iniection Wells. UIC Permit AK-1(004-A Wastewater Disaosal Permit No. 2005D60001-0021 Grind and Iniect Iniection Wells, UIC Permit AK-11008-A Area Iniection Order No. 4E, General Wastewater. Permit No. 2005D6001-0012 Liberty Class 1 Iniection Well. UIC Permit AK-11013-A General Wastewater Permit No. 2005D6001-0025 Mechanical Integrit st Notification -- ~ , February 23, 2010 Page 2 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) the annual Mechanical Integrity Test (MIT) and fluid movement test that is required every other year at the Badami Class 1 well to meet the permit requirement in UIC Permit AK-11001-A; 2) the MIT and fluid movement tests at the Northstar NS10 and NS32, Class 1 wells to meet the annual permit requirement in UIC Permit AK-11002-A; 3) the MIT and fluid movement test that is required every three years at the Milne Point Class 1 well to meet the permit requirement in UIC Permit AK-11005-A; 4) the MIT and fluid movement tests at the Pad 3 Class 1 wells in the Prudhoe Bay Unit to meet the annual permit requirement in UIC Permit AK 11004-A; 5) the MIT and fluid movement tests at the Grind and Inject Facility, in the Prudhoe Bay Unit to meet the annual permit requirement in UIC Permit AK-11008-A; and 6) the MIT and fluid movement test that is required at the Liberty Class 1 well to meet the permit requirement in UIC Permit AK-11013-A. By this letter BPXA is providing the written notification required by the aforementioned permits. In addition, BPXA staff will be coordinating the timeframes for these MIT and fluid movement tests with Mr. Thor Cutler of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA inspector, so that multiple tests of Class 1 wells can be witnessed in one trip to the North Slope. A summary of the proposed annual testing is presented in the attached table. The fluid movement test procedures that require EPA approval have been or will be sent under separate cover or by a-mail. If you have any questions, please contact me at (907) 564-4838. Sincerely, Alison Cooke Environmental Advisor Attachment cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant ~_ ~~ by ~ ~ Tom V. Marshall Head of Operations BP Exploration (Alaska) Inc. Alaska Consolidated Team (ACT) P. O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519.6612 ~~~ ~~ IC~CIEK Direct 907 561 5111 Phone: (907) 564-5006 February 2, 2O1 O Fax: (907) 564-4441 Email: MarshaTV~bp.com Web: www.bp.com UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE-127) 1200 Sixth Avenue Suite 900 Seattle, Washington 98101 RE: Renewal Application for UIC Permit AK-11002A Dear UIC Manager: RECEt110ED FEB 0 3 2x10 Alaska Oil 8 bas Cons. Commission Anchorage The Northstar UIC permit AK-11002A will expire on August 4, 2010. By this letter and submittal of the attached application, BP Exploration (Alaska) Inc. requests the Environmental Protection Agency renew the permit for another 10 year term. The two Class I disposal wells at the Northstar facility have successfully injected approximately 32 million barrels of waste. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. If you need any clarification or additional information concerting this application, please contact Alison Cooke, at (907) 564-4838 or Alison.Cooke~bg.com. ___--- Sincerely, r~~ ~~ `` - ®-~ ~ --~ 1 ~ Tom V. Marshall Attachments cc: Thor Cutler, EPA Region 10 (hard copy wlapplication) Talib Syed, PE/Talib Syed and Associates (hard copy w/application) Dan Seamount, AOGCC (hard copy w/o application) Shawn Stokes, ADEC (hard copy w/o application) r OMB No. 2040-0042 Approval Expires 42d~~<'sSS~i United States Environmental Protection Agency ` ' ~ EPA Underground Injection Control ~r'~i ~ ~-i Permit Application _ ; ~-~---~ _-- (Collected under the authority of the Safe Drinking U f Water Act. Sections 1421, f422, 40 CFR 144) i___ _ Read Attached Instructions Before Starting For Official Use Only Application approved Date received Permit Number Well ID FINDS Number mo day year mo day year ~.<. ;e ...- x --. ~,. y < ,, ~ Owner NA111~e ____ ..._.._.._~ {B~ P Exploration (Alaska) Inc. _ - _ ~.._ Owner Name ABP E'~ xp)oration (Alaska) Inc. - ~~ Street Address '~~~~'-'LL~ ~'~M~~ ~ ~~ ~~' Phone Number Street Address _ ,__ ' ___,_ Phone Number 1 (900 E. Benson Blvd. I 907 561-5111 900 E. Benson Blvd. ~(___Z_ ~ L 907) 561-5111 I ~ -~ itv~_____,__^__.~,__~ _.__. Anchorage _._ State ;AK ~ ZIP CODE Cit _.__„~~,___._ X99508 _.~ ~Anch rao geiy~_~_ ,__~ State ZIP CODE f ~ ~ 99 8 yes ~ Private Owner ( SIC Codes 1311 and 2911 No Federal Operator ~ Other ~ _~____ z i A Date Started ~ g, Modification/Conversion ~ C. Proposed mo day year Operating !01/26/2001 ~ ~' i Number of Existing Wells Number of Proposed Wells Name(s) of field(s) or project(s) A. Individual a B. Area 1~--------------~----~ °°°°'_""_ '_"~ .` ~_____"~'~.~ ;2 wells NS10 and NS32 j ~2 wells NS10 and NS32 { Northstar Unit -Beaufort Sea 3 ~ ~~_~ ~ 'Offshore Production Island __3 i_______.__~.._..__ _. _. A. Class(es) B. Type(s) C. If class is "other" or type is code 'x; explain D. Number of wells per type (if area permit) (enter code(s)) (enter code(s)) I ~ i 2 - Class I (Industrial) 3 r-- ! ~ _~__.__~_ _..u__. ""~ j ~ i ' ~ (Complete the following questions on a separate sheet(s) and number accordingly; see instructions) For Classes 1, II, III, (and other classes) complete and submit on a separate sheet(s) Attachments A-U (pp 2-S) as appropriate. Attach maps where required. List attachments by letter which are applicable and are included with your application. I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibliity of fine and imprisonment. (Ref. 40 CFR 144.32) A. Name and Title_ (Type o_r Print) _ __ ~ -~ ~z ~~A_ ~ B. Phone No. (Area Code and No.) ;Tom Marshall -Head of Operations Alaska Coysolidated Team _ ~' ~(907~ 564-5006 • bp David J. Szabo Head of Resource Management Alaska Consolidated 7eam (ACT) September 10, 2009 ~~~~~ ' ~~ ~~ ~. `~ 2009 Mr. Peter Contreras UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE-127) 1200 Sixth Avenue Suite 900 Seattle, Washington 98101 ~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907)561-5111 Phone: (907) 564-4788 Fax: (907) 564-4440 Email SzaboDJ~bp.com Web: www.bp.com VIA CERTI~I~~,.~I~-J1~ , _ _ ~ ~ ,~ ~ ., 1 ~l ~; ~a _ t-x-: < ~ ~ ~ Mr. Thor Cutler U.S. Environmental Protection Agency (EPA) 1200 Sixth Avenue ~, ~~ Seattle, WA 98101 Q~,.Q~ ~ Re: NS10 - Report on Annual Demonstration of Mechanical Integrity Dear Mr. Contreras and Mr. Cutler: Please find enclosed the Report on Annual Demonstration of Mechanical Integrity for the NS10 weil, Permit No. AK-11002-A Part II.C.3.b.(i ) and Part II.C.3.c.(i ), As stipulated by the permit, two (2) copies of the logs and two (2) copies of the descriptive and interpretive report are being sent to the EPA to your attention. I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. lf you have any questions please call Mark Sauve at 907-564-4660. Sincerely, Q~~ David J. Szabo Attachments ~ ~ Re: NS~ 0- Report on Annual Demonstration of Mechanicai Integrity September 10, 2009 Page 2 cc: Talib Syed, EPA Consultant Sean Stokes, ADEC Jim Regg, AOGCC Jeff Walker, MMS Alison Cooke, BPXA File Copy Compliance Matrix Administrator: Matrix ID 8774 ~ ~ ~ ~ ~ ^;', ~ ~. ~ ~_s~ ~ NS10 ~-~ ~ ~ `~ ~- ~ EPA UIC Class I Permit AK-11002-A Part II.C.3.b (2): Report on Annual Demonstration of Mechanical Integrity September 4, 2009 ~ ~ ADDRESSES: With Loqs Mr. Peter Contreras & Mr. Thor Cutier (2 Copies to this address) EPA Region 10 (OW-137) 1200 Sixth Ave Suite 900 Seattle, WA 98101 Mr. Talib Syed, EPA Consultant c/o TSA, Inc. 6551 South Revere Pkwy, Ste 215 Centennial, CO 80111 Mr. Jim Regg AK Oil & Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage, AK 99501 ~ Badami File Copy c/o David Fair ' BP Internal Mail i MB 4-2 Without Loqs Mr. Shawn Stokes Alaska Department of Environmental Conservation ; , 555 Cordova St. Anchorage, Alaska 99501 Ms. Alison Cooke ,: BP Internal Mail MB 11-6 Badami Operations Lead Tech Badami, North Slope Mark Sauve BP Internal Mail MB 4-2 Compliance Matrix Administrator: Matrix ID 7318, 7319 ~ ~ _ ~, ~ ~ NS10 EPA UIC Class I Permit AK-11002-A Part II.C.3.b (2): Report on Annual Demonstration of Mechanical Integrity September 4, 2009 ~ ~ Executive Summary: Annual Surveillance on the NS10 EPA UIC Class I disposal well was performed on August 12t" and 13t" 2009. The scope of work included a Water Flow Log (WFL) and a Mechanical Integrity Test (MIT). A Multi-Finger Caliper Log was successfully completed on June 20t", 2009. The MIT, pressure tested to 3520 psi, demonstrated mechanical integrity of the casing, tubing and packer. The test was witnessed by EPA representative Thor Cutler. The WFL results indicate there is good vertical containment of injected fluids in the permitted interval. Nine WFL stops were made starting just above the casing shoe and stopping just above the packer. Fluid movement was not detected on any of these stops. The test was witnessed by EPA representative Thor Cutler. The Multi-Finger Caliper Log Report was submitted to the EPA in June 2009. This log indicated significant tubing wall loss up to 55% (last year's tubing caliper surveyfound 72% wall loss). Remaining tubing life is estimated to be one to three years. Attachments include the well bore diagram (attachment 1), MIT documentation (attachments 2-4), the Schlumberger RST-WL log (attachment 5) and the PQS Memory Multi-Finger Caliper log (attachment 6). ~ Discussion • Mechanical Inteqritv Test (MIT): On August 12, 2009 a MIT-IA was performed on NS10. The inner annulus (4- 1/2" x 7-5/8" casing annulus) was pressurized to 3520 psi with 3 barrels of diesel. During the first 15 minutes of the test pressure dropped 80 psi and in the second 15 minutes the pressure dropped 30 psi. This pressure decline of 3.125% during the allotted 30 minute test period test indicates there is good tubing and casing mechanical integrity. The test was witnessed by EPA representative Thor Cutler. The MIT results are summarized attachment 2, the pressure chart recorded during this test is shown in attachment 3 and the well service report for this work is included in attachment 4. Fluid Movement Loqs fWater Flow Loq (WFL) and Temperature Loql On August 13t , 2009, a Schlumberger Reservoir Saturation Tool Water Flow Log (WFL) was run in NS10. The purpose of the (og was to detect movement of any fluids in vertical channels adjacent to the wellbore and to determine that the confining zone is not fractured. The log was conducted with an injection pressures ranging from 2142 to 2254 psig. Injection rate at the time of logging was approximately 17,000 - 18,400 BWPD of produced water. ~' The WFL bombards water with neutrons and detects gamma rays from the resulting interactions. The tool has a neutron generator and three gamma ray detectors. For this job, the tool was configured to detect the upward movement of water. The neutron generator was placed below the three gamma ray detectors. To detect the movement of water behind pipe, the tool is positioned at the desired depth and the neutron generator is turned on briefly. If there is upward movement of water (e.g. channels behind the casing), the gamma ray detectors see the energized water as it moves up past them. Nine WFL stops were made in NS10. The depths were 7950', 7850', 6050', 5050', 5000', 4950', 4900', 4850' and 4800'. The casing shoe in this open hole completion is at ;' 8029'. The original packer is set at 5015' and the packer from the January 06, 2006 RWO is set at 4960'. No water movement was detected at any of the stops. The WFL results indicate there is good vertical containment of injected ' fluids in the permitted interval. The test was witnessed by EPA representative ~ ` Thor Cutler. The detailed report for the RST Water-flow log is attachment 5 and the well service report for this work is included in attachment 4. • ~ Tubing Inspection Caliper Loq ProActive Diagnostic Services (PDS) was retained to provide a 1-11/16", 40 finger memory caliper tool and interpretation of the results. This tool was run on Schlumberger slickline from the tubing tail back to surface on June 10, 2009. This tool digitally records the internal diameter of the tubing, which is used to determine pipe thickness, and hence metal loss. A rig work-over (RWO) was completed on NS10 January 06, 2006. As a result, the multi-finger caliper data reflects the condition of the tubing string ran in January 2006 (above 4981'); as well as, the original tubing tail ran in January 2001 (below 4981'). The caliper tubing inspection log indicates the tubing is in fair to poor condition. During the 2008 caliper survey an area of poor condition with maximum wall penetration of 72% was located in the original tubing string below the new tubing ran in January 2006. During the 2009 caliper survey the maximum wall penetration found in the lower section of tubing was only 52% and it is likely the 2009 caliper simply missed the 72% pit recorded during 2008. The maximum wall penetration of the tubing string ran in January 2006 is 55% in joint 39 (1,675'), indicating this portion of the tubing is in fair condition. The damage appears mostly in the form of isolated pitting. No significant areas of cross- sectional metal loss or I.D. restrictions are recorded. The detailed report from PDS is attachment 6 and the well service report for this work is included in attachment 4. ~ ~ Attachment 1 ~ fR[~- ABBhFI~f 511~8'~CS$ W~6.HL40s A86~VG~ 11' LQt78(jMt 9G5 A~TlY~7OR = _ ~p .. 5AFE9'1f ~['~: "'~ EPA CL1'~5 t 015?d5AL SMELL *~4 i ~ i c m. a w ~ ~iV = . ss rr _ 39~T (CS 159'~ A' ~ ~ ~ K~7p~ 8~~ ! \ lWutlkn~e:: _ ~4r~~~. _ . _ msurn-ii~ _ __, ___._~ 13574' ~k,~mTVD~ ` _ , , ta~fl'S$ lV~inimum tD =~.6" '~d~ 2t143' I I ~~ ~~ I ~-- - • ~~usEa,~n• srawo,x~tocs ro~~rs~r s~v 4-'l/2'" X lVt~+~L.~ ~rr~,s+a-cs~,s~.sa. t.so eic, :~ - ~ss? ~ ~.ets° Id-1.f2" 7i3G, 12.SM. i..8~ T{#., I A 152 bc~i, D -3.95T` ~cFt.o~~.~~r ~ ~ + t~-.{ eilD~ f"14-~rz°ritz~,o=s~s9~l sa^c~,s~.ar.~aagr~, 8003' a~rr~.t~mae~nuni} S39 6GA. ~ - fl835' t+~71LS7,d3i VY~€: ~1t7 PLi~~IITNa 2D]1520 APJNO: ~!fk~i29-~4~5-110 8EG t t, T13N, ii1 SE,1139r F'ESL& B43' €[!_ ~P' £xpioaxdiatt {Alas kaj C14T£ (&1! 8'Y {X7~6+~l~Ii~ ORTL RL4' 8Y C~AA~Q~"1S ~9f11A0i kGK fJlilt~~FL4LCWiP~E11ON 07107A~ ~ Ff~7T~.N~RRt~7k'7PIS 01143~08 N37~ tbY6 U1~ 575+08 .Ki6'TLH Fit437€Cid~lE NRi.£ SLW SQ' QidY1106 ??TdlF.9{ Oi3.GOli14FfC7DRR~fOMB 1.1~.d271U7 N@?RP:IC SYLiL#f]'tG~f'A7i7N Ek?~R7N 3. ~ Attachment #2 ~ MIT Test Results • ~ STATE OF ALASKq ALASK,4 Oll. ANQ GAS COt~SERVATIt7N COMMISStQN Mechanieal Integrtty Test Email to jim rer~g~afaska gov; tom,maunder~afaska gqv,bob Aeckecisle+nCwa1aaka gov,doa.~agec.pr~dhoe.bay@alaska.gav 1 t1IPE !NJ Gaies ~ d= Dt~tUrtg W&ste ( G - Gas 1 ~ indvsteiall/Vgstewaiee ~ M = NW In~ecirne ` Sl~t =1Nater MIT Rep~t FaTVv ~L t11271(r1 '~YPE 7E5T ~Cadaa -~ = A~~nulus Nlonitanng P= Standstd Pressure Test R= intsrnal RadioBCUve Trac,Er Survey A = Tamp~ature;4r,analy Survey L> = diRerernial Tamperaturt? Test MiT ACT N5 48•12-05 xls ~NTERYAI Codes t= Inibef ~est 4 = Foar Y~r Cyde ~ = Reqw~ed by Variance T = Test dunng Wprkove~r O = Other (descxibe rn n4tes) nPER1lTt?R: BP Expbration ~Aiaska) Inc FIELD ! UNiT t PAD: Prudhne Bay d ACT / NS C~A7E: 08/12/D3 ~ ~.,~~~,. ~,... ..__ ~ ~ ~ , ~ Attachment #3 MIT Test Chart • , ~ ,,/~' ___ - ------ - - _ 1 .. / ~ {~ !.._--55:;,. _ • `~,` ' '` ~ ~ ' ' __ -- ---SCO~ J -- . ~' ~; "`~, / ~ % ` ~ _ / /i ,: -~ , -- - , ` ~ ,'` ' - ' ~ ~~ ~-'~ __ __ -- --4~u0-'~ _ _ • _ ~ , j~~'~ ~ ~ ~ ~' - ~J~ ~ _~.. q000-`/` -.- _ ;'! , _ ~ , , f ;- _,__~-~-- r __ ~,. ~ '~ j ~ / ~ -~ ~ , ! __ Ssoo7-- - __ ` %\' ' '~ ~ . 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' ` ------ ~~~ -~' ,~ . ~\ ~rOGGS- ~ / ~rr. \~~ i ~ ~~ I yi / `~~-'`----- ~ ,-' ~` '_-'_(ii,'CC ---__ i ~:~: e ~--_ I _-~" o~ _. ,' ~_ `---- --- -- - ---- r- N001~1 ~'~ i Attachment #4 ~ Well Service Reports WellServiceReport ~ ~ Page 1 of ~ WELL SERVICE REPORT WELL JOB SCOPE UNtT NS'1 O CALIPER SWCP #01 DATE DAILY WORK DAY SUPV 6/20/2009 DRIFT/TAG; CALIPER TUBING; IN PROGRESS ROCHIN COST CODE PLUS KEY PERSON NIGHT SUPV NSFLDWLIO-M SWCP-HENRY ATKINSON MIN ID DEPTH TTL SIZE 3.725 " 4972 FT 4.5 " ~xxWtLL 5/I UN ARRIVAL'*` (EPA Surveillance) PULLED 4-1/2" PROTECTION SLV C~ 2,010' SLM/ 2043' MD. TAGGED TD ~ 8013' SLM W/ 3.50" CENT. LOGGED PDS 40-ARM CALIPER FROM 8010' SLM TO SURFACE, RECEIVED GOOD DATA. RUNNING IN HOLE TO SET 4.5" PROTECTION SLV IN PROGRESS. '""JOB CONTINUED ON 06/2t/09 WSR"" LOG ENTRIES Init Tb IA OA -> 250 0 0 TIME COMMENT 06:00 TRAVEL TO NS 07:00 ON ISLAND, CHECK AND START EQ 08:15 SPOT UP EQUIPMENT ON NS-10 08:45 REVIEW JSAS, PJSM 09:10 BEGIN RIG UP .125" STAINLESS WIRE " TS: 5' OF 2.625" STEM, OJS, LSS* 10:45 POP CAP, STACK ON WLV, 5' RISER, PUMPN-SUB, PICK LUB, SWING OVER 11:50 TAKE CONTROL OF WIRE & STAB ON LUBRiCATOR. 12:35 HEATER HOSE ON TRACTOR LEAKED COOLANT. ALL COOLANT CONTAINED IN SPILL DIKE. MAKE CALLS , REPAIR HOSE. CLEAN UP. 13:10 CLOSE WLV RAMS, P/T 500#. EQ PSI, PRESSURE LUB TO 500# 14:00 GOOD TEST, RIH W/ QC, 2' OF 1.75" STEM, 4 1/2" GS (brass), SD C~ 2010' SLM, LATCH UP JAR FOR 5 MINS , , TLS COME FREE POOH 14:40 BUMP UP, BLEED LUB. EVAC LUB OF FLUID ` 15:05 OOH W/O SLV, GS SHEARED. RE-PIN GS, STAB ON GAS UP LUB 15:25 RIH W/ QC, 2' OF 1.75" STEM, 4 1/2" GS (steel), SD C~ 2010' SLM, LATCH UP, JAR FOR 10 MINS TLS COME , FREE POOH 16:05 BUMP UP, BLEED LUB 16:25 OOH W/ PROTECTION SLV. C/O TOOL STAB ON GAS UP LUB 16:40 RIH W/ QC, 2' OF 1J5" STEM, 3.50" CENT, 2" G-RING TOOLS Si"ART TO FALL SLOW @ 2200' SLM TAGGED , TD C~ 8013' SLM, PULLED 300# OVER TO GET FREE POOH : 17:45 , BUMP UP, BLEED LUB, REMOVE OJS, ASSEMBLE PDS TLS 18:20 RIH W/ PDS 40 ARM CALIPER C 150 FPM ;; ~ 1~9:18 STOP C~3 8,010' SLM WAIT FOR ARMS TO OPEN ' 19:38 BEGIN TO POOH W/ PDS 40 ARM CALIPER ~ 50 FPM `, 22:08 . BUMP UP WITH CALIPER, STAND BY FOR ARMS TO CLOSE 22;38 . SIBD. ~ 23:03 BREAK OFF CALIPER FOR PDS TO VERIFY DATA ~: 23:42 PDS REPORTED GOOD DATA ~<h 23:45 RIH W/ 4.5" GS & 4.5" PROTECTION SLEEVE ;: , 2~:59 . *"*CONTINUE JOB ON 06/21/09 WSR"'* ~~• ~ ~ Final Tb IA OA -> 550 0 0 ~,,. y~ : d,OB COSTS ~~ ~ SfRVICE COMPANY - SERVICE DAItY COST CUMtJL TOTAL ~$IS ~;~ ~ $2,600 $2,600 HLUMBERGER ~ ~ $0 $0 `~CN~UMBERGER ~~ ' PLUS 15 PERCENT $0 $0 ,~ TOTAL FIELD ESTIMATE: ~ $2,600 $2,600 ~~ ' . ~~~ia SUMMARY t k ~ ,>~ ~ r . ~ ~?;1/annc?_ala~U~ t,,,.~,oh h„,.,.,,,i~.~,,.,.~ ..,on.,~_..:...._---- _,, ,- ,. ~ , .,,~,,,,,.-.r~~,.,.. . ...~ - WellServiceReport WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT NS'1 O CALIPER SWCP #03 DATE DAILY WORK DAY SUPV 6/21/2009 CALIPER TUBING ROCHIN COST CODE PL.US KEY PERSON NIGHT SUPV NSFLDWLIO-M SWCP-MCCAULEY ATKINSON MIN ID DEPTH TTL SIZE 3.813 " 2043 FT 3.958 " SET 4.5" PROTECTION SLEEVE C 2,010' SLM/ 2043' MD. (18" OAL, 2.67" I.D, 4-1/2" G-FISH NECK) LOG ENTRIES Init Tb IA OA -> 570 0 0 TIME COMMENT 00:01 '"'CONT WSR FROM 06/20/09'"* 00:02 CONTINUE RIH W/ 4.5" GS & 4.5" PROTECTION SLV. 18" OAL, 2.67" I.D, 4-1/2" G-FISH NECK 00:44 S/D @ 2,010' SLM. SET 4.5" PROTECTION SLEEVE. 01:15 OOH W/ SHEARED GS. SLEEVE SET. BEGIN RIG DOWN. 01:58 R/D COMPLETE, WELL IS NORMALED UP, TREE CAP TESTED W/ GAS. PAD-OP INFORMED OF TREE VALVE POSITIONS. 01:59 END TICKET Final Tb IA OA -> 570 0 0 JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL ORBIS $1,300 $3,900 PDS $9,622 $9,622 SCHLUMBERGER $0 $0 SCHLUMBERGER PLUS 15 PERCENT $0 $0 TOTAL FIELD ESTIMATE: $10,922 $13,522 FWID SUMMARY NO FLUIDS PUMPED. n,._--„ , , , , , . - - --'------.. --...n,._.°-:------ - . ~ , ~ ,, - ----n_a ncn n cni n~nncnoc~o~ ni~i~nnn We1lServiceReport • ~ WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT NS'1 O ~NATERFLOW LOG LRS 38 DATE DAILY WORK DAY SUPV 8/12/2009 M IT-IA ATKI NSON COST CODE PLUS KEY PERSON NIGHT SUPV NSFLDWLIO-R LRS-CLINE SPILLER MIN ID DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY T/i/0 = 2285/0/60 Temp = Hot EPA MIT IA PASSED to 3500 psi (EPA Witnessed by T. Cutler) Pumped 3 bbls of diesel down IA to achieve test pressure. IA lost 80 psi in the first 15 minutes and 30 psi in the second 15 minutes for a total loss of 110 psi in the 30 minute test. Bleed IA ressure down to 0 si. FWHP's = 2280/0/60. LOG ENTRIES Init-> 2,285 0 60 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 17:00 Start Ticket 17:30 Ri u to IA 18:00 O en new Unit Work Permit 18:27 PT surface line to 4000 si 18:33 0.4 Start Diesel 45`F 2285 0 60 Start into IA with Diesel 18:40 0.3 3 " 2285 3520 70 SD, reached test ressure. Start MIT 18:55 2281 3440 80 1 st 15 min ressures ' 19:10 2284 3410 80 2nd 15 min ressures. 19:11 MIT IA PASSED to 3500 si. 19:15 Bleed IA ressure to 0, Ri down 23:59 End ticket. Final-> 2,280 0 60 JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL ' LITTLE RED $1,155 $1,155 WAREHOUSE $504 $504 SCHLUMBERGER $0 $0 SCHLUMBERGER PLUS 15 PERCENT $0 $0 TOTAL FIELD ESTIMATE: $1,659 $1,659 SU PE >' ;nttlulHtD TEST PRESSURE 3,500 TEST TYPE MIT-IA FLUIDS USED TO TEST DIESEL START TIME: 18:40 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL ~ ~U.BING 2,285 2,285 281 2 2 284 (A 0 3,520 , 3,440 , 3,410 PASS _ ~A 60 70 80 80 down to 0 //~,...,,1 ..i,.-i--'-----'_ ~__ _..__i..--•.__,. __...~i„___.._------ ,~, r ,. . - --n~~ n~rr~~^~~nnr.innnr~n nininni.n We1lServiceReport ~ ~ Page 1 of 2 WELL SERVICE REPORT WELL JOB SCOPE UNIT NS'~ O ~NATERF~OW LOG SWS NS DATE DAILY WORK DAY SUPV 8/13/2009 RIG UP; RST--CARBON / OXYGEN ATKINSON COST CODE PLUS KEY PERSON NIGHT SUPV NSFLDWLIO-R SWS-DECKERT SPILLER MIN ID DEPTH TTL SIZE 2.6 " 2043 FT 4.5 " ""JOB CONTINUED FROM 12-AUG2009'*" (EPA WFL) INITIAL T/I/O = 1500/0/0 RAN WATER FLOW LOG W/ STOP COUNTS PER PROGRAM AND WITNESSED BY EPA REP (THOR CUTLER) FOUND ZERO UPWARD FLOW AT INJ RATE 19000 BWPD, WHP 2254 PSI, WHT 142 DEGF CORRELATED TO SWS JEWELRY LOG DATED 15 JAN 2001 FINAL WHP'S = 1400/0/~ '**JOB CONTINUED ON 14-AUG-2009 WSR'"" LOG ENTRIES Init Tb IA OA -> 1500 0 0 TIME COMMENT 00:00 LOG CONTINUED FROM 12-AUG-2009 00:01 CONTINUE RIGGING UP E-LINE 01:12 SAFETY MEETING 01:26 EC~UIPMENT SPOTTED, PICK UP BOP'S AND PUT ON WELL ` 02:07 BOP'S ON WELLHEAD, STRING LINE THROUGH LUBRICATOR, BUILD LOGGING HEAD 06:00 CHANGE OUT WITH DAY CREW, PJSM, MU TEST TOOLS 08:10 PT LUB 300 LP, 3000 HP 08:40 PT COMPLETED, SHUT IN INJECTION TO RIH ' 09:25 RIH WITH MH22/PBMS/CENTRALIZER/RST TOOLS/CENTRALIZER/WT BAR, 47' X 1.70" OD, 7X3 WK PT, 220# TOOL WT 10:00 PERFORM TOOL CHECK RIH AT 40 FPM 11:00 CORRELATE AND PUT WELL ON INJECTION " 11:48 INJECTION RATE 18400 BWPD, WHP 2254 PSI, WHT 142 DEGF 11:49 WFL STATION S70P 7950' 12:02 WFL STATION STOP 7850' ,'r. 12:20 PUH TO 6050' 12:40 INJECTION RATE 17000 BWPD, WHP 2142 PSI, WHT 142 DEGF ~'' 12:41 WFL STATION STOP 6050' ` 13:03 WFL STATION STOP 5050' ~r;; 13:18 WFL STATION STOP 5000' x°. 13:29 WFL STATION STOP 4950' ~~. ~~~~3:40 WFL STATION STOP 4900' ~~ ~: i3:51 ~4:08 WFL STATION STOP 4850' WFL STATION STOP 4800' ~~~ ,:>s ' 14:24 14:26 CONFIRM ZERO UPWARD FLOW LOG DOWN 120 FPM TO CONFIRM CORRELATION STOPS ~,~ 15:15 SHUT IN INJECTION AND POOH FROM 7990' {.~; 16:51 SWAB SHUT, BLEED LUB ~', . ~7:30 BREAK DOWN TOOLS ~; ; ~ °°i8;00 •a9:34 BEGIN RIG DOWN E-LINE TREE CAP PRESSURE TESTED, CONTINUE RIG DOWN E-LINE ., .23:59 LOG CONTINUED ON 14-AUG-2009 ~~ ' Final Tb IA OA -> 1400 0 0 `. ~ e. ' ~B COSTS '~ERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL ~~~5 $1,300 $1,300 ~HLUMBERGER $24,653 $24,653 ~ , ~ NLUMBERGER PLUS 15 PERCENT $3,698 $3,698 .e ://ar,,,~~ .,t,,..v„ i....__...i. i.... ,.,.,...i.,.~,,...~ ..,on ........:........____~r~-r---'~ -----n.a-n~c~nnnnn~~r~nn~n~ n in innnn We1lServiceReport ~ • Page 2 of 2 WAREHOUSE $0 $504 LITTLE RED PLUS 20 PERCENT $p $792 LITTLE RED $0 $5,115 TOTAL FIELD ESTIMATE: $29,650 $36,061 IVI MHI'i Y aAUS2-alacka hnwPh hn cnm/awurc-wPllcerv;~P,-P,,,,,-+i,aof.,,,lt .,~.,.,7;,a_r~7~2nrnnn~~r~nn~nr~ nininnn., We1lServiceReport ~ ~ WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT NS'1 O WATERFLOW LOG SWS NS DATE DAILY WORK DAY SUPV 8/14/2009 RIG DOWN ATKINSON COST CODE PLUS KEY PERSON NIGHT SUPV NSFLDWLIO-R SWS-DECKERT SPILLER MIN ID DEPTH TTL SIZE 2.6 " 2043 FT 4.5 " *""JOB CONTINUED FROM 13-AUG-2009"`"`" (EPA WFL) WELL LEFT SHUT-IN WITH FREEZE PROTECT WING = C, MASTER = O, SWAB = C, SSV = O, SSSV - PROTECTIVE SLEEVE, VALVES OPEN TO GAUGES. WELL TENDER NOTIFIED OF VALVE STATUS AND DEPARTURE *""`JOB COMPLETE*""* LOG ENTRIES Init Tb IA OA -> 1500 0 0 TIME COMMENT 00:00 LOG CONTINUED FROM 13-AUG-2009 00:01 CONTINUE RIGGING DOWN E-LINE, PREP E-LINE UNIT FOR SHIPMENT TO PRUDHOE BAY 07:00 NIGHT CREW TRAVEL TO PRUDHOE BAY 12:00 DAY CREW TRAVEL TO PRUDHOE BAY Final Tb IA OA -> 1400 0 0 B COSTS RVICE COMPANY - SER HLUMBERGER HLUMBERGER PLUS 15 ~REHOUSE TLE RED PLUS 20 PERC BIS TLE RED ID DAILY COST AL 115 061 7_a~ac~ta },,,.x~Ph h„ r~nminct~rtrc_~s~a~Tcar[~ir~arar~nrt/.7nf'n»1• ~~„v~;~-r7~~nrnon~~r~nn~n~ ni~i~nnn ~ Attachment #5 ~ Schiumberger RST WFL-Up Flow Mode Log ~~ ~ • BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. t>~~-~~ /g S7"' V ~ZJ~~ ~~IS~ ~ ~'~P If vou have anv auestions. olease contact Joe Lastufka at (90715f4-4~91 Date: 09-04-2009 Transmittal Number: 93096 Delive Contents Bottom SW Name Date Contracto Run To De th De th Descri tion WATERFLOW INJECTION NS10 08-13-2009 SCH 1 4760 7950 LOG CD-ROM - WATERFLOW NS10 08-13-2009 SCH INJECTION LOG WATERFLOW INJECTION NS32 08-12-2009 SCH 1 3750 8060 LOG CD-ROM - WATERFLOW NS32 08-12-2009 SCH INJECTION LOG Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center ,~ BPXA ~ , ~ ~w , ~ ,. "~ U, ~~1~ ~~ AOGCC r.~`~ ~~.~. .._ Murphy Exploration DNR MMS Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99~ 19-66 l 2 David Fair Christine Mahnken Ignacio Herrera Corazon Manaois Doug Chromanski • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ,~j zo~- ie z .ti;Or~S-~ ~l,~S-!~ Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~~~ ~~~i~~ t FIELD / UNIT / PAD: Prudhoe Bay / ACT / NS DATE: 08/12/09 OPERATOR REP: Torin Roschinger AOGCC REP: EPA: Thor Cutler Packer Depth Pretest Initial 15 Min. 30 Min. Well NS-10 Type Inj. I~ ND ~ 3,987' Tubing 2,285 2,285 2,281 ~2,284 Interval O P.T.D. 2001820 Type test P Test psi `~3500 Casing 0 ~3,520 -3,440 ~3,410 P/F P Notes: EPA witnessed annual MIT-IA for Class I disposal OA 60 70 80 80 regulatory compliance. Well NS-32 Type Inj. W TVD 4,070' Tubing 1,990 1,991 1,989 2,010 Interval O P.T.D. 2031580 Type test P Test psi 3500 Casing 0 3,540 3,500 3,500 P/F P Notes: OA 0 0 0 0 Weli Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P~F Notes: OA TYPE INJ Codes D = Driiling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test - ..... .,. v ~ <-,w ~.a , ~. . ' T L n' .:a / INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT ACT NS 08-12-09.x1s • .~ ..., ~ !(,.,: ~: _ ~> ~.:~`. ~:,:. ( ., "Pl~.;:).~ ~~~ ~~''~ ~~ ~~~~~ ~ ~, ~ ~-,~ A:%" i~~,~ i ~ ~ %~ ~=''~ ''1~I L T T I~'i ; ~ ',~ ~ ~ ~' ~~ ~T ~ ~./~ ~ ''_I 1 ~~Z, ~i'~~!!~ ~ K i;'i' i'~ yf ~i; i~~ ;'f~'r' ~,I, lv~e. _ C,.L~ 3f~i. 9 '~ ~3_ _ ~v' ~f vo~.a hav~ anv auestions, ~lease ~~ntac~ .~oe ~,astur`~ca a~t (9071~~4-4091 ~ela~~a~y~ C~aaten~s Bottom SW Name Date Contractor Run To Depth Depth Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS S10 06-20-2009 PDS 9 0 8003 SUMMARY CD-ROM - MEMORY MULTI- FINGER CALIPER LOG NS10 06-20-2009 PDS RESULTS SUMMARY NS30 06-04-2009 SCH 1 15687 16170 PERFORATION RECORD CD-ROM - PERFORATION NS30 06-04-2009 SCH RECORD ~` , ~"~~ r' ; ~ v ~/ fr ~ /~ if Please Sign and Return one copy of this transmittal. Thank You, _ - Joe Lastufka Petrotechnical Data Center SPXA David Fair AOGCC Christine Mahnken DNR Corazon Manaois Murphy Exploration Ignacio Herrera MMS Doug Chromanski ~~~'~~~x .Ft',:t ._ ._ ?~u`~ s~~,:e,~; ~.' Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 196612 Anchora~e, AK 995 1 9-66 1 2 • ~ ~ ,: Memary Multi-Finger Caliper Log Results Summary Company: BP Exploration (Afaska), lnc. Well: NS-10 Log Date: June 20, 2009 Field: Northstar Log No. : 10567 State: Alaska Run No.: 9 API No.: 50-029-229$5-00 Pipe1 Desc.: 4.5° 12.6 Ib. L-80 TCII / IBT-M Top Log lntvl1.: Surface Pipe1 Use: Tubing Bot. Log Intvl9.: 8,OOS Ft. (MDj Inspection Type : Camvsion Monitoring Inspection COMMENTS : This log is tied into the VI~EG ~ 8,tM3' (ElMD). This log was run to assess the condition of the tubing with respec# to corrosive and mechanical damage. The caliper recordin~ indicate the 4.5° tubing is in good to poor condition, with a maximum recorded wall penetration of 55% recorded at an isotated pit in joint 39 (1,675'). Recorded damage appears as isalated pitting throughout the interval logged and a line of pits from ~6,000' to -6,5p0'. No significant areas of cxoss- sectianal wall loss or I.D. restrictions are recorded. This is the ninth time a PDS caliper has been run in this wefl, the ninth time fhe 4.5" tubing stub has been logged from 4,981' to 8,003', and the fourtt~ time the 4.5" tubing has been logged from surface to 4,981'. A comparison of the current and previous log (July 10, 2008) indicates an increase in corrosive damage during the ~me between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by- joint basis beiween tfie current and previous log is included in this report. The decrease tn maximum recorded penetrations from -5,10~' ta --6,800' in the included comparison graph appears to be due to the caliper fingers not tracking the same magnitude of damage in the current log as tt-e previous log. - Time to Failure Evaluation graphs of both the replaced tubing (0' - 4,981') and the tubing stub (4,981' - 8,003') are induded in this report. These graphs project a failure date range based on corrosion rates ' calculated from changes in the deepest recorded penetratian in it~e entire well over time. 7'he tubing from surface to 4,981' is projected to fail in as soon as 1.3 years. 1'he iubing stub (4,981' - 8,043') is projected to fail in as soon as 0.2 years. ' MAXIMUM RECORDED WALL PENETRA714NS: Isolated pitting ( 55°~) Jt, 39 ~ 1,675 Ft. {MD) ' Isolated pitting ( 52°/a) Jt. 127 ~ 5,411 Ft. (MD) Isolated piifing ( 52°/fl) Jt. 130 @ 5,519 Ft. (MD) Isolated pitting ( 51 %) Jt. 125 @ 5,339 Ft. (MD) Isolated pitting ( 48%) Jt. 33 c~ 1,407 Ft. (MD) ' MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%) are recorded. ' i.9M'£r`:~1t,~`~~ at ~! ~... : r .t. ~ V U~ MAXIMUM REC4RDED t~ RESTRICT1~NS: No significant I.D. restrictions are recorded. , ,' Field Engineer. G. Etherton Analyst: C. Waldrop Wrtness: 8. Rochin ProActive Diagnostic Services, Ir~c. / F.O. 8ox 1369, Stafford, T,~C 7749 % Phone: {~81) or {SH8) 565-9~85 Fax: {2Sij 565-1369 E-mail: Pt~S~,~amemorylog.com ~ Prudhoe Bay Field O~ce Phone: (907} 659-~30 % Fax: (9Q7) 659-231~ ~ ~ ~s~. ~v - ~~a r ~a~ a ~ • ~~l PDS Multifinger Caliper 3D Log Plot • ~l,J Company : BP Exploration (Alaska), Inc. Field : Northstar Well : NS-10 Date : June 20, 2009 Description : Detail of Caliper Recordings Across 5-1/8" 5 KSI Tree • • Maximum Recorded Penetration ~-1~ ~ Comparison To Previous Well: NS-10 Survey Date: )une 20, 2009 Field: Northstar Prev. Date: July 10, 2008 Company. BP Exploration (Alaska), Inc. Tod: UW MFC 40 Na 213120 CounUy: USA Tubing: 4.S 12.6 Ib L-80 TCII / IBT-M Ove rlav Ma x. Rec. Pen. ( mils) 0 1 00 2 00 3 00 0.1 7 17 27 _ - 37 ~ 47 54 _-_. _ 64 74 84 _ '_ ~, E 94 Z ~ 104 0 ~ 114 117 123 133 143 153 163 173 18 "t - 18y -.-- ^ June 20, 2009 ^)~y 10, 2006 Difference -2 00 -1 Diff, in Max 00 . Pen. (mils 0 1 ) 00 2 00 d E ~ Z c 0 -21 2 -10 6 0 10 6 21 2 App rox. Corros , ion Rate (m py) 7 ,. 17 27 37 47 54 64 74 84 94 104 714 117 -- 123 133 1 163 173 183 ~ w ~ r ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ ^~ ~ ~ ~ Tirne to Failure Evaluation S BP Exploration (Alaska), Inc. Northstar Corrosive Trend: Isolated Pitting Well: NS-10 4.5" Tubing and Overshot June 20, 2009 Years Following Most Recent Log 4.5" 12.6 Ib L-80 TCII (0' - 4,981') p 5 Wali Thickness = 271 mill ~ , , , ~ 260 ~ - i -> ~ 8b°/ Wall Thic ness Safet x~ °~~f ~°,~ ) ~ ~ ~ ~ 240 - - ~ ,~; .,. - ~ ~ I , ~ n 220 .._ - ----- ~- .° ~ i ~ / ~ ~ ~ / / / 2~0 _ _ -- i / ~ ~ / ~ ~ / ~ 180 i - - - ~ ~~ ~~ ~~ ~ ~ ~ ~+ 160 ; - - -- -- - _ _ ~ Y i ~ a~ ! i ~ ----- C ~ ~ _ ~_ ~ 1 C. ~ ~ I / - ! ~ I~ ~ ~ T / ~ i ~' Maximum Wall Penetration in Stub ~ 120 ~~~ ~ ~ i -- Recorded in Jt. 39 ~ 1,676'. ~ 100 ~~ ~~ ~~ 1 17-Ju1y-07 to 03-Jan-06 ~ ~ (Completion Date) = as mpy C~C 80 i ~ ~ ---- _._ ~ ~ ' ~ 20-June-09 to 03-Jan-06 ~ 60 ~~ ~~ ~ ~ (Completion Date) = 43 mpy 40 ~i ~~ ~ ~ 10-Ju1y-08 to 03-Jan-06 ~ ~ (Completion Date) = 34 mpy 20 ~%~ ~ ~~ 1 0 I 0 ' 6 Years Since Well Completion 10 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Time to Failure Evaluation S BP Exploration (Alaska), Inc. Northstar Corrosive Trend: Isolated Pitting Well : NS-10 and Lines of Pits 4.6" Tubing Stub below Ovarshot June 20, 2009 Years Following Most Recent Log 4.6" 12.61b L-80 IBT-M (4,981' - 8,003') 0 b 10 Wall 260 240 _ 220 ~ ~ 200 ~ 180 '~ ~ + 160 a~ c ~ 140 y 120 ~ ~ v 100 ~ OC 80 . ~ 60 ~ 40 20 0 Th _ icknes s = 27 _~. 1 mill ~ i ' : ' I ; / ~ ; -. _ ~ ' ~ ~ ~~ - .__ ~ 85% all Th ckne s Saf ty Fa tor) ~ I ; ~ ' , ~ , ~ - - - -- ~ _ - ~ - - ; ~ I - - > ~ -- ~ ~ I ~ ~ ~ i ~ ~ - _ ----- i ~ i - i I ' ~ ~ -- ----- - f ~ -- t ~ ' ~ , I ~ I __ ---- --- - - - - -- i -- ~ ~ ~ -- -- - -- - - ~ , ~ ~ '; _ ____ ---- - _ ~ ~ ~ ~ ~ __- --- i - - --} I - - - - - ----- _ ---- / , / - ' 1 - - - - - --- -- - ~ _ - - - ~ Maximum Wall Penetration in Stub ~ - - -- -- --- ~ -- - - ~ I Recorded in Jt. 127 ~ 6,411'. ~ -- ~-- -- ~ 10-Ju1y-08 to 11-Jan-01 ~ ~ ~ ; ~ (Completion Date) = 26 mpy ~ ~ ~ ~ 20-June-09 to 11-Jan-01 ~ ~ (Completion Date) = 17 mpy ~~ J i ~ 1 _ 0 6 ~ 10 Years Since Well Completion 16 ~ ~ • Correlation of Recorded Damag ~ Pipe 1 4.5 in (10.2' - 8003.0') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile NS-10 Northstar BP Exploration {Alaska), Inc. USA June 20, 2009 ^ Approx. Tool Deviation ^ Approx. Borehole Profile ~ --- --- ~ I 14 2 ~ ~ ~ I ~~ 1050 50 ( `. ° ~ 2115 75 i ``y _ 3163 ~ ~ `m 100 . 4207 ~ ~ ~ .E Z c • ~ i ~ i ~ o Q 125 I 5305 150 ~ ~~ ~ 6333 175 ` I 7363 1 ' _ 89.4 . _! i __. 8003 0 50 100 Darnage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 189.4 • ~ PDS Report Overview i.. ~ . Body Region Analysis Well: NS70 Survey Date: June 20, 2009 Field: Northstar Tool Type: UW MFC 40 No. 213120 Company: BP Explora6on (Alaska~, Inc. Tool Size: 2.75 Country: USA No. of Fingers; 40 Anal st: C. Waldro Tubing: Nom.OD Wei~t Grade & Thread Nom.ID Nom. lJpset Upper len. Lower len. 4.5 ins 12.6 f L-80 TCII IBT-M 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 200 50 1 00 1 50 ~ 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 203 pene. 0 4 47 loss 9 194 0 134 18 0 0 0 0 Damage Co~guration ( body ) 200 ;----~- 15U 100 50 0 isolated general line ring hole / poss pitting corrosion cortnsion cortosion ible hole Number of'oints dama ed total = 176 176 0 0 0 0 Damage Profile (% wall) ~ penetration body ! metal loss body 0 50 0 47 95 139 189 Bottom of Survey = 189.4 100 Analysis Overview page 2 ~ • PDS REPORT JO INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Weli: NS-10 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Cornpany: BP 6cploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA 5urvey Date: June 20, 2009 Joint No. Jt. Depth (Ft.) Pc~n. UF~sc~t (li~s.) Pen. Body (Ins.) Pen. % Metal Los~ % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 10 c) 0.05 U 2 3.93 PUP 1 14 U 0.08 28 3 3.92 Isolated ittin . 1.1 56 tl 0.07 25 :~ 3.92 PUP Isolated ittin . 1.2 76 l1 0.05 20 1 3.92 PUP Isolated ittin . 1.3 86 t~ 0.04 15 2 3.94 PUP 2 89 (1 0.11 42 1 3.92 Isolated ittin . 3 131 U 0.10 37 1 3.91 Isolated ittin . 4 173 l) 0.10 3£3 1 3.91 Isolated ittin . 5 216 0 0.11 39 1 3.91 Isolated ittin . 6 257 0 0.10 38 3 3.92 Isolated Qittin . 7 299 0.05 0.09 33 2 3.92 Isolated ittin . 8 340 () 0.09 35 2 3.93 Isolated ittin . 9 382 (1 0.07 26 1 3.91 Isolated ittin . 10 423 O OA8 30 2 3.93 Isolated ittin . 11 465 (l 0.09 33 1 3.93 Isolated ittin . 12 507 (1 0.10 35 2 3.92 Isolated ittin . 13 549 ll 0.09 32 2 3.92 Isolated ittin . 14 591 (1 0.09 32 1 3.91 Isolated ittin . 15 633 (1 0.06 "L 1 Z 3.93 Isolated ittin . 16 675 (1 0.08 30 6 3.92 Isolated pittin . 17 717 0 0.06 21 4 3.92 Isolated ittin . 18 759 (1 0.07 25 2 3.92 Isolated ittin . 19 800 U 0.09 35 3 3.92 Isolated ittin . 20 842 0 0.06 24 1 3.92 Isolated ittin . 21 884 0 0.11 39 2 3.93 Isolated ittin . 22 926 0 0.10 36 4 3.92 Isolated ittin . 23 967 0 0.12 42 6 3.93 Isolated ittin . 24 1008 ll 0.09 35 4 3.93 Isolated ittin . 25 1050 0 0.08 29 6 3.94 Isolated ittin~. 26 1091 O 0.11 42 4 3.94 Isolated pittinR. 27 1132 0 0.09 34 4 3.93 Isolated ittinA. ~ 28 1174 0 0.09 34 6 3.94 Isolated pittinR. 29 1216 0.0£3 0.12 45 4 3.92 Isolated ittin . 30 1258 (1 0.12 44 7 3.93 Isolated ittin . 31 1299 0 0.11 41 5 3.93 Isolated ittin . 32 1341 l1 0.12 42 Ei 3.94 Isolated ittin . 33 1383 U 0.13 48 ~ 3.94 Isolated ittin . 34 1424 l) 0.13 48 6 3.95 Isolated ittin . 35 1466 (1 0.06 23 (i 3.94 Isolated ittin . 36 1508 O 0.11 40 6 3.93 Isolated ittin . 37 1550 0 0.09 33 6 3.94 Isolated ittin . 38 1592 U 0.10 37 6 3.95 Isolated ittin . 39 1634 l) 0.15 55 i 3.95 Isolated ittin . 40 1676 O 0.10 36 6 3.95 Isolated ittin . 41 1717 U 0.08 30 5 3.94 Isolated ittin . 42 1759 ll 0.11 39 5 3.94 Isolated ittin . 43 1801 0 0.08 31 6 3.94 Isolated ittin . 44 1843 0 0.09 35 6 3.93 Isolated ittin . 45 1885 0 0.08 30 6 3.93 Isolated ittin . 46 1927 0 0.09 32 6 3.94 Isolated ittin . . Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: Body Wall: 0.271 in Field: Upset Wail: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • -LATION SHEEf NS-10 Nortfistar BP Explora6on (Alaska), Inc. USA June 20, 2009 Joint No. Jt. Depdi (Ft) Pc~n. Ups<~t (Ins.) Pen. Body (Ins.) Pen. % Me~al Loss °i<> Min. I.D. (Ins.) Damage Profile Comments (%wall) 0 50 100 47 1968 0 0.10 37 G 3.94 Isolated ittin . 47.1 2010 O 0.04 15 4 3.95 PUP 47.2 2020 l) 0 0 U 3.81 4.5" X-Ni e 47.3 2022 0 0.03 13 6 3.95 PUP 48 2031 0 0.10 38 6 3.95 Isolated ittin . 49 2073 0 0.11 39 6 3.95 Isolated~ittin~ 50 2115 0 0.07 27 7 3.96 Isolated ittin . 51 2157 ll 0.09 34 6 3.95 Isolated ittin . 52 2199 (1 0.08 31 5 3.94 Isolated ittin . 53 2241 l) 0.07 24 ' 3.95 Isolated~ittin . 54 2284 0 0.07 28 6 3.95 Isolated ittin . 55 2326 U 0.09 31 5 3.94 Isolated ittin . 56 2368 O 0.07 26 6 3.95 Isolated~ittin . 57 2410 O 0.08 30 7 3.95 Isolated ittin . 58 2452 0 0.08 28 6 3.95 Isolated ittin . 59 2493 0 0.06 20 6 3.94 Isolated ittin . 60 2535 (1 0.06 21 6 3.94 Isolated ittin . 61 2577 l) 0.07 27 7 3.95 Isolated ittin . 62 2618 l) 0.07 26 6 3.94 Isolated ittin . 63 2660 0 0.05 19 6 3.94 Isolated ittin . 64 2702 0 0.05 19 6 3.95 Isolated ittin . 65 2744 0 0.07 28 6 3.95 Isolated ittin . 66 2786 0 0.08 30 4 3.95 Isolated ittin . 67 2828 O 0.05 18 5 3.94 Isolated ittin . 68 2869 0 0.07 24 6 3.95 Isolated ittin . 69 2912 0 0.06 24 6 3.95 Isolated ittin . 70 2954 U 0.07 24 7 3.95 Isolated ittin . 71 2996 0 0.07 25 5 3.95 Isolated ittin . 72 3038 0 0.06 21 5 3.95 Isolated ittin . 73 3079 0 0.06 21 5 3.95 Isolated ittin . 74 3121 0 0.05 20 6 3.95 Isolated ittin . 75 3163 0 0.06 22 6 3.95 Isolated itti~ , 76 3204 U 0.04 15 4 3.94 77 3247 0 0.08 29 5 3.95 Isolated ittin . 78 3'189 O 0.05 ZO 6 3.94 Isolated ittin . 79 3331 O 0.05 20 5 3.95 Isolated ittin . 80 3373 0 0.06 20 5 3.95 Isolated ittin . 81 3415 0 0.04 16 6 3.93 82 3457 0 0.05 20 4 3.94 Isolated ittin . 83 3499 0 0.06 21 4 3.94 Isolated ittin . 84 3541 0 0.07 24 5 3.95 Isolated ittin . 85 3582 0 0.07 27 4 3.94 Isolated ittin . 86 3622 0 0.05 19 5 3.95 Isolated ittin . 87 3664 0 0.08 31 6 3.94 Isolated ittin . 88 3706 0 0.09 34 5 3.94 Isolated ittin . 89 3748 0 0.05 20 4 3.94 Isolated ittin . 90 3790 0 0.12 45 5 3.94 Isolated ittin . 91 3832 0 0.05 19 4 3.94 Isolated ittin . 92 3873 ll 0.06 21 5 3.95 Isolated ittin . 93 3914 0 0.06 21 5 3.95 Isolated ittin . Penetration Body Metal Loss Body Page 2 ~ • PDS REPORT JO INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: June 20, 2009 Joint No. Jt. Depth (Ft.) Pe~n. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °io Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 94 3956 0 0.05 18 4 3.95 95 3998 0 0.04 14 4 3.94 96 4040 0 0.03 13 4 3.94 97 4082 0 0.06 20 4 3.94 Isolated ittin . 98 4124 0 0.05 1 B 5 3.95 99 4165 0 0.04 14 4 3.93 100 4207 0 0.04 14 4 3.94 101 4247 0 0.03 9 3 3.93 102 4289 (1 0.05 1£3 4 3.94 103 4331 0 0.04 17 4 3.94 104 4373 ll 0.04 16 4 3.95 105 4415 t) 0.05 18 5 3.94 106 4457 0 0.07 28 5 3.95 Isolate~ittin . 107 4499 0 0.05 19 5 3.95 Shallow ittin . 108 4540 0 0.06 21 5 3.94 Isolated ittin . 109 4583 0 0.04 14 4 3.95 110 4625 c1 0.03 13 4 3.92 111 4667 0 0.11 39 5 3.94 Isolated ittin . 112 4709 ll 0.04 17 4 3.94 113 4750 0 0.05 18 4 3.94 114 4791 0 0.05 19 6 395 Shallow ittin . 115 4833 U 0.04 15 4 3.95 116 4875 0 0.04 16 4 3.94 116.1 4918 0 0.03 10 4 3.96 PUP 116.2 4927 0 0 0 0 3.81 4.5" HES X-Ni le 1163 4929 l1 0.03 9 4 3.95 PUP 116.4 4938 0 0.03 10 3 3.95 PUP 116.5 4948 0 0 0 0 3.88 7.625" x 4.5" Baker Premi m Packer 716.6 4956 l) 0.04 14 7 3.96 PUP 116J 4961 0 0 0 0 3J3 4.5" HES XN-Ni le 116.8 4963 0 0 0 0 4.65 4.5" Uni ue Overshot 117 4968 t).06 0.11 39 S 3.93 Corrosion. 117.1 4993 0 0.07 27 4 3.93 PUP Isolated ittin . 117.2 5002 0 0 0 0 3.88 7.625" x 4.5" Baker S3 Packer 117.3 5007 0 0.12 44 7 3.94 PUP Isolated ittin . 118 5016 ll 0.08 31 6 3.92 Isolated ittin . 119 5058 (1 0.05 20 6 3.91 Isolated ittin . 120 5099 0 0.06 21 7 3.91 Isolated ittin . 121 5141 0 0.06 24 7 3.93 Isolated ittin . 122 5182 O 0.08 2~) 6 3.91 Isolated ittin . 123 5223 !) 0.07 25 6 3.91 Isolated ittin . 124 5264 (1 0.05 18 7 3.92 Isolated ittin . 125 5305 l) 0.14 51 6 3.93 Isolated ittin . 126 5347 0 0.06 24 5 3.92 Isolated ittin . 127 5388 O 0.14 52 i 3.92 Isolated ittin . 128 5429 U 0.06 21 5 3.90 Isolated ittin . - 129 5470 (1 0.08 29 7 3.91 Isolated ittin . i I 130 5511 O 0.14 52 7 3.93 _i Isolated pitting. 131 5552 0 0.09 35 6 3.92 Isolated pittin~. - 132 5593 O 0.06 21 5 3.92 Isolated ittin . __ Penetration Body Metaf Loss Body Page 3 • • PDS REPORT JO INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nomina) I.D.: 3.958 in Country: USA Survey Date: June 20, 2009 Joint No. Jt. Depth (Ft.) f'e~n. UE~set f Ins.) Pen. Body (Ins.) Pen. % Metal I_os~ °i~~ Min. I.D. (Ins.} Comments Damage Profile (%wall) 0 50 100 133 5634 0 0.12 43 ? 3.91 Isolated ittin . 134 5675 0 0.12 44 6 3.92 Isolated ittin . 1 5 5716 0 0.10 37 i 3.93 Isolated ittin . 736 5758 U.1)7 0.07 26 6 3.91 Isolated ittin . 137 5799 O 0.08 30 6 3.92 Isolated ittinA. 138 5840 U 0.12 45 B 3.92 Isolated ittin . _ 139 5882 0 0.09 32 7 3.91 Isolated pittin~. I i 140 5922 U 0.08 29 8 3.91 Isolated ittin . - ~ j ~ 141 5963 U 0.09 32 6 3.92 Isolated ittin . 142 6005 (1 0.08 31 6 3.91 Line of its. 143 6047 ll 0.09 33 6 3.91 Line of its. 144 6088 O 0.08 28 6 3.92 Line of its. 145 6129 0 0.10 37 7 3.92 Line of its. 146 6170 0 0.09 33 3.93 Line of its. 147 6211 l1 0.10 37 7 3.92 Line of its. 148 6252 0 0.10 36 7 3.90 Line of its. 149 6293 t1 0.07 25 i 3.92 Line of its. 150 6333 O 0.09 34 h 3.92 Line of its. 151 6375 t) 0.07 27 5 3.92 Line of its. 152 6417 l) 0.09 32 6 3.91 Line of +ts. 153 6458 O 0.07 24 6 3.90 Line of its. 154 6500 ll 0.08 29 7 3.90 Line of its. 155 6542 tl 0.07 27 6 3.91 Isolated ittin . 156 6583 () 0.06 24 5 3.91 Isolated ittin . 157 6624 (1 0.06 22 5 3.89 Isolated ittin . 158 6665 U 0.05 20 6 3.92 Isolated ittin . 159 6706 U OA5 20 7 3.91 Isolated ittin . 160 6747 U 0.07 26 7 3.92 Isolated ittin . 161 6788 (1 0.06 24 i 3.90 Isolated ittin . 162 6829 t) 0.08 29 5 3.90 Isolated pittinQ. 163 6870 l) 0.06 24 6 3.91 Isolated pittinR. 164 6912 0 0.05 19 7 3.92 Isolated ittin . 165 6953 0 0.06 23 5 3.90 Isolated ittin . 166 6992 0 0.06 21 6 3.91 Isolated ittin . 167 7033 (1 0.05 19 ~ 3.91 Isolated ittin . 168 7074 0 0.06 24 6 3.91 Isolated ittin . 169 7115 0 0.07 25 6 3.92 Isolated ittin . 170 71 % 0 0.06 21 6 3.93 Isolated ittin . 171 7197 U 0.05 19 6 3.91 Isolated ittin . 172 7239 0 0.06 21 5 3.93 Isolated ittin . 173 7280 O 0.07 ZG 5 3.92 Isolated ittin . 174 7322 O 0.07 28 6 3.92 Isolated ittin . 175 7363 l) 0.06 23 5 3.93 Isolated ittin . U6 7404 O 0.06 21 5 3.91 Isolated ittin . 177 7446 O 0.06 23 6 3.92 Isolated ittin . 178 7487 ~1 0.05 19 6 3.94 Isolated ittin . 179 7528 U 0.07 25 6 3.90 Isolated ittin . 180 7569 0 0.07 24 6 3.90 Isolated ittin . 181 7611 0 0.06 23 7 3.92 Isolated ittin . 182 7652 0 0.06 22 5 3.93_ Isolated pitting. ___ __ Penetration Body Metal Loss Body Page 4 ~ • PDS REPORT JO INT TABULATION SHEEf Pipe: 4.5 in 12.6 ppf L-80 TCII / IBT-M Well: NS-10 Body Wail: 0.271 in Field: Northstar Upset Wall: 0.271 in Cornpany: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: June 20, 2009 Joint No. )t. Depth (Ft) Pc~n. ll~~~c~t (In:.~ Pen. Body (InsJ Pen. °/a Metal I_oss %, Min. I.D. (Ins.) Damage Profile Comments (%wall) 0 50 100 183 7693 (1 0.07 24 5 3.91 Isolated ittin . 184 7734 (1 0.07 25 6 3.93 Isolated ittin . 185 7776 ll 0.07 25 5 3.91 Isolated ittin . 186 7817 l1 0.06 22 6 3.91 Isolated ittin . 187 7858 U 0.07 25 3.87 Isolated ittin . 188 7899 l) 0.06 21 5 3.91 Isolated ittin . - 189 794 0 0.08 29 6 3.91 Isolated pitting. _- 189.1 7982 0 0.10 ;8 ~ 3.93 ~ PUP Isolated ittin . 189.2 7991 0 0 0 l) 3.73 4.5" Otis XN-Ni le 189.3 7993 (1 O.Q6 21 b 3.93 PUP Isolated ittin . 189.4 8003 (~ 0 0 ~ 3.96 4.5" WLEG Penetration Body Metal Loss Body Page 5 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~+ ~+~ PDS Report Cross Sections Well: NS-10 Survey Date: )une 20 2009 Field: Northstar Tool Type: UW MFC 40 No. 213120 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin : 4.5 ins 12.6 f L$0 TCII IBT M Anal st C. Waldro Cross Section for )oint 39 at depth 1674.97 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 94 % Tool deviation = 15 ° Finger 26 Penetradon = 0.148 ins Isolated pit6ng 0.15 ins = 55°/a Wall Penetra6on HIGH SIDE = UP r 1 LJ • CrossSectionspage 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~~ Well: NS-10 Survey Date: June 20 2009 Field: Northstar Tool Type: UW MFC 40 No. 213120 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin ; 4.5 ins 12.6 f L-80 TCII IBT-M Analyst: C. Waldr~ Cross Section for )oint 127 at depth 5410.52 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 93 % Tool deviation = 50 ° finger 30 Penetration = 0.141 ins Isolated pitting 0.14 ins = 52% Wall Penetradon HIGH SIDE = UP • ~ Cross Sections page 2 TREE _ ABB-VGI 5-1/8" SKSI ~ SAFETYNO~* ~ACLASS 1 DISPOSALWELL'"`~ NS10 WB.LHEAD= ABB-VGI 11" MtATBOWL SKSi ACTU+4TOR = BAKER KB. ~EV = BF. ~EV = 55.77' . 39.87' (CB 15.9') KOP = g33~ Max Angle = Datum WID - Datum ND - 51 ° @ 4424' 13071• 10500' SS 20" CONDUCTOR, 169#, X-56 ~~' Minimum ID = 2.6" @ 2043' 4-1/2" X NIPPLE ~ 10-3l4" CSG, 45.5#, L-80 BTC, ID = 9.95"? ~ 4938~ 4972' 4-112" TBG, 12.6#, L-80 TGI, .0152 bpf, ~ = 3.958" 41/2" TBG. 12.6#, L-80 BT-M, .0152 bpf, D = 3.958" 7-5/8" CSG, 29.7#, L-80 BTC, .0459 bpf, D = 6.875" OPBV I-IOLE TD I-I 8246' 4-1/2" X N~? ID = 3.813" wlPROT6CTNE SLV** ~"`USE4-1/2" STANDAItD GS TO PULLlSET SLV 4-912" HES X N~, ID = 3.813" ~ 7-5/8" X 41/2" BKR PRgU1 PKR D= 3.875" 4-112" HES XN NP, ~= 3.725" TBG ST1JB (12/27/05) 4-112" UNIQUE OV ERSHOT, ~= 4.654" 7-5/8" X 4-1t2" BKR S-3 PKR, D= 3.875" 4-1/2" OTIS XN NA~, ID = 3.725" 8006~ --+4-1/2" WLEG. D= 3.958" ~ 8003' ~WD TT LOGG~ 06/01l01) DATE REV BY COMNBVTS DATE REV BY COMNENTS 01/11/01 AGK OIi1GINAL COMPLETION 07/07/08 WRRlTLH PROTSLV CORREGTIONS 01/03/06 N33E RWO 01/05l06 JGB/TLH PROTECTNE Nff~PLE SLV SET ff~ 01l21tQ6 ???ITIH DRLG DRAFT CORRECTIONS 11/27/07 WRR/PJG W~LHD/L.OCAl10N CORRECTIONS 06/28108 WRRlPdC DRAW~ CORRECTIONS NORTHSTAR W~L: NS10 PERNAT No: 2001820 API No: 50-029-22985-00 SEC 11, T13N, R13E, 1139' FSl & 643' F~ BP E~cploration (Alaskaj • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ,~ " ~~~ ~~~i~ May 26, 2009 ~I~~~ i1 ~ ~a~~~ ~~;~r~ission ~~~~r~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~.... 333 West 7t~ Avenue ~ ~~ _ ~~ p Anchorage, Alaska 99501 ~ ~ ' / L~ Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~ V~~ ~"~ Andrea Hughes BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) X" "-~\ Date Northstar 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NSi 1 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS14 A 2052020 0.9 na 0.9 na 2.8 5/1/2009 NSi6 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 * na na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 * na na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. L JUN 0 1 2009 by ~ • ,~~~ Jean A. Celestain Ft } ~) ~p Performance Unit Leader -Northstar, Endicott, Badami 4~ L ~l!(` Alaska Consolidated Team (ACT) r, - -.-a By Certified Mail #7007 0710 0001 8620 9879 October 30, 2008 Mr. Michael A. Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 RE: Northstar NS10 Class I Injection Well -MIT Report Permit Number AK-11002-A Dear Mr. Bussell: BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO Box 196612 Anchorage, AK 99519-6612 !907) 564-5111 Phone: (9071564-5107 Fax: (90T1564-4441 Email: CelestJ~bp.com Web: www.bp.com ~,o In order to meet the requirements of the Northstar Class I Injection Well Permit (AK-11002-A) Part II.C.3.b.(1) and Part II.C.3.c.(1), BP Exploration (Alaska) Inc. (BPXA) submits the attached two (2) copies of an interpretive report to the Environmental Protection Agency (EPA). A pressure test of the tubing-casing annulus was performed on the Northstar well NS10 on October 11, 2008. On the day of the test, EPA representative Talib Syed was present to witness that the pressure test passed. The mechanical integrity of well NS10's tubing, packer, and casing was demonstrated. No communication to the tubing or outer annulus was evident. The field report and an interpretive report are enclosed. If you have any questions please call Robert Younger at 907-564-5392. Sincerely, ~~~',- ~~~:~~~~.~ 1~G~' ~. `c 200 Jean A. Celestain Attachments cc: Talib Syed, EPA Consultant Shawn Stokes, ADEC ~ \~`~Jim Regg, AOGCC Jeff Walker, MMS ,~- Alison Cooke, BPXA Northstar File Copy Compliance Matrix Administrator: Matrix ID 8774 • Northstar NS10 Class 1 Disposal Well Mechanical Integrity Test Test conducted by pressurizing the Inner Annulus (the casing by tubing annulus.) Inner Annulus Cumulative Percentage Outer Tubing Description Time Pressure change in change in Annulus Pressure (minutes) (prig) IAP IAP Pressure (prig) (psi) (Psi9) Arrive - 20 - - 50 1980 Begin test 0 3520 - - 50 2090 15 3480 -40 -1.14% 50 2070 End test 30 3480 -40 -1.14% 50 2030 Allowable pressure drop is 5% of 3500 psi, or 175 psi, in 30 minutes. During this test, the total pressure decrease on the IA was 40 psi. EPA Representative, Talib Syed, was present to witness the test. Test conducted on 10/11 /2008. "In order to demonstrate there is no significant leak in the casing, tubing or packer,- the tubing/casing annulus must be pressure tested to at least 3,500 pounds per square inch gauge (psig) for not less than thirty minutes. Pressure shall show a stabilizing tendency. That is, the pressure may not decline more than 10 percent during the test period and shall experience less than one-third of its total loss in the last half of the test period. If the total loss exceeds 5% or if the loss during the second 15 minute period is equal to or greater than one half the loss during the first 15 minutes, the permittee may extend the test period for an additional 30 minutes to demonstrate stabilization. This pressure test is required at a timer interval of no more than 12 months between tests" EPA Class I Permit AK-11002- A,PartIIC3b(1),Page12of16 WellServiceReport • WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT NS'1 O ANN-COMM (REG COMPL) LRS 38 DATE DAILY WORK DAY SUPV 10/11 /2008 MIT-IA TILBURY COST CODE PLUS KEY PERSON NIGHT SUPV NSFLDWLIO-I LRS-ZIMMERMAN UNKNOWN MIN ID DEPTH TTL SIZE 0" OFT 0" T/I/O = 1980/20/50 *""EPA Witnessed MITIA to 3520psi PASSED"" Pressured up w/ 3.4bbls diesel. IA lost 40psi 1st 15min, Opsi 2ns 15min, for a total of 40psi in 30min. Bled IA to zero. FWHP's = 1980/0/50 _ LOG ENTRIES Init-> 1980 20 50 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 06:00 Start Ticket. Travel to N". 09:00 On island. Permit. Start unit. Snow removal. PJSM. Load diesel. 13:38 Rigped up. Pressure tested. DHD rigging up chart recorder. 13:49 0.5 St Diesel 40"F 1980 20 50 Start down IA. 14:01 3.4 2090 3520 50 Shut down. Start test. 14:16 2070 3480 50 15min ressures 14:31 2030 3480 50 30min ressures PASS. Bleed down. 15:29 End Ticket Final-> 1980 0 50 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL LITTLE RED $1,710 $1,710 TOTAL FIELD ESTIMATE: $1,710 $1,710 #1 REQUIRED TEST PRESSURE 3,520 TEST TYPE MIT-IA FLUIDS USED TO TEST DIESEL START TIME: 14:01 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 1,980 2,090 2,070 2,030 IA 20 3,520 3,480 3,480 PASS OA 50 50 50 50 COMMENTS EPA WITNEDDED BY TALIB SYED. http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?ID=591 F75E602... 10/ 16/2008 • ~~ -- . PM ~` . .:.~..~ - -- - ~~'~ 8 ~ '~ r _ -t-- ,- . .f "- ice- ii r._--F-- ~- -y--- _ - S00 `~` ~-- - ~ ~ _ /i _\ `. ~• ' - 3S t c ~ , ~~ ~ ~ ~ /i ~~ , ~ n"~ ~ L y 3000 _ ~'_ - \ / i p,~ O i, i ~ _ ~ 2000_ ~~~ `><~~, ~`~ \ ~`~~ '\ ~/. ~xY gip, ~~- ~ i~~X ,~' - ' ~ ~, _1500 -,~ ~~ ~ ~\ - ~ ~` ~~~:~ '\A / , ~ -' ~~ ~/i~ ~~ ~ ~~~ ~ ~~ ~'l~ ^-~~~` S00 ~.~ ~ Vin;. y~?~ ~ ~\~' ~ A / <~ ~ ~ ~ ~'~' ~ ~( ~ , ~,~/ ,,x./.00 / ~' ~ ~ .. O~ \ 00~ `,, I , ~ ri , 00~, _ ~ , i' ~~~~ '~ ' i I i _ r ~ j r r ~ ~ ~ ..~ t~}-Ji~-fit. ~ ~ ~ ~ .~ r~ fl ~ i Li i '. 1 ~ I i~ ~ i ._ _~` Ir l~' I _ ~ ~ ~' l u I I - ~ ~ 1 i; It rl~ ::~, ~ ~~ r I i I , i ~ ti t i. I t _ 1~ - ~ 1 r~- ~' r T 1 ~~~ ~ , i ~ ~ ~ , ~ 1 , 1,~' ''~ ~ . ~, ~ v OV ,~ O~ _y ~weine ~V~ ~.,~~ ~ ~ ~, , '~ , ~~ t' 1 ~ 1 ' 1 ,1' p\ ~' \~ ` ~O ~'~ O~''\ ~ D~ ` \ ~~ ~'~ ` ~yp-lra0d~ ~~.~y~ ~ OO`.i~~ i ~ ~ ~ ;' ~ /~/~ ~ o o ~ ~ N,-~ti, ~ ~ `"` ,~ ~ ~ ~ ' ~ O ~~ ~ '; , '; ' ~.r' A~ ~ ~ A\ ~ ~ ~ ~ >~ ~ ~ '~ ~~ \~ . , ~~ ~`_ _ '~'-h~ ~~~' ~f ,'lam ~ ~ ~~ C Z' ~ / ~ /y ~,~A v -~ ~ ~' _ ~Z~ - 000 ~~-~- / / ~~~ - s ~~~-i--- --- B L -- - ~ Wd 9 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska) Inc. FIELD /UNIT /PAD: Northstar / NS / NS DATE: 10/11/08 OPERATOR REP: Andrea Hughes AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well NS10 Type In'. D TVD 3,987 Tubing • t1 G~ ~=r;'di' ~.~''f U '~y.c% Interva O P.T.D. 2001820 T pe test P Test si 1500 Casin -~ " 5 u..r.: "~~3G- ;3yar=? P/F Notes: EPA witnessed by Thor Cutler annual MIT-IA OA !~ _.:'~' ~~ =~rJ for re ulator compliance. Well NS32 T e In'. N TVD 4,070' Tubin Interva O P.T.D. 2031580 T e test P Test si 1500 Casing P/F Notes: EPA witnessed by Thor Cutler annual MIT-IA OA for regulator compliance. Well Ty e In'. TVD Tubing Interva P.T.D. T e test Test si Casin P/F Notes: OA Well T pe In'. TVD Tubin Interva P.T.D. T e test Test si Casin P/F Notes: OA Well T e In'. TVD Tubing Interva P.T.D. Type test Test si Casin P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D = Differential Temperature Test nW~ ~ , ~ ~' ~~ t '~ . ~ `~ - .~.~ ~;: ~. _ {~:~ , • ~ '3. Z ~t',~'L :~ ` MIT Report Form BFL 11!27107 '` ,.y ~`~~~, ~t~~,~`'ju `~.~~R MIT NS NS10 NS32 10-11-08.x1s INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunderC~3alaska.gov;bob.fleckenstein~alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Northstar / NS / NS 10/11/08 Andrea Hughes Packer De th Pretest Initial 15 Min. 30 Min. Well NS10 T e Inj. D ND 3,987' Tubin 1980 2090 2070 2030 Interval O P.T.D. 2001820 T e test P Test psi 1500 Casin 20 3520 3480 3480 P/F P Notes: EPA witnessed by Thor Cutler annual MIT-IA OA 50 50 50 50 for re ulato com liance. Well T pe Inj. TVD Tubin Interval P.T.D. T e test Test psi Casin P/F Notes: OA Well T pe Inj. TVD Tubin Interval P.T.D. T pe test Test si Casin P/F Notes: OA Well T pe Inj. TVD Tubin Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well T e Inj. TVD Tubin Interval P.T.D. T pe test Test psi Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT ACT NS10 10-11-08.x1s lvili roans ror ~rti ~.ompiiance: ivor~nstar, tsaaami, raa ~, ~ivi rage i or i • Regg, James B (DOA) ,~ ,.,_ ~ ~ -~. From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, October 17, 2008 9:45 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; Younger, Robert O; Bill, Michael L (Natchiq) Subject: MIT Forms for EPA Compliance: Northstar, Badami, Pad 3, GNI Attachments: MIT ACT NS10 10-11-08.x1s; MIT ACT NS32 10-11-08.x1s; MIT BAD B1-01 10-09-08.xis; MIT PBU GNI-02A, 03, 04 10-07-08.x1s; MIT PBU OWDW-NW, SE, SW 10-08-08.x1s Jim, Tom and Bob, Please see the attached MIT forms for the following wells for annual EPA compliance testing: ~NS10 (PTD #2001820): MIT-IA witnessed by Thor Cutler. NS32 (PTD #2031580): MIT-IA witnessed by Thor Cutler. B1-01 (PTD #1971570): MIT-IA witnessed by Thor Cutler and Talib Syed. GIV~I-02A (PTD #2061190): MIT-IA witnessed by Thor Cutler and Talib Syed. GNI-03 (PTD #1971890): MIT-IA witnessed by Thor Cutler and Talib Syed. GNI-04 (PTD: #2071170): MIT-IA witnessed by Thor Cutler and Talib Syed. OWDW-NW (PTD #1002400): MIT-IA witnessed by Thor Cutler and Talib Syed. OWDW-SE (PTD #1002390): MIT-IA witnessed by Thor Cutler and Talib Syed. OWDW-SW (PTD #1002380): MIT-IA witnessed by Thor Cutler and Talib Syed. «MIT ACT NS10 10-11-08.x1s» «MIT ACT NS32 10-11-08.x1s» «MIT BAD B1-01 10-09-08.x1s» «MIT PBU GNI-02A, 03, 04 10-07-08.xis» «MIT PBU OWDW-NW, SE, SW 10-08-08.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 :~ 4.a.., __ , . ,.. ~ ~ ft 10/17/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Northstar / NS / NS 10/11 /08 Andrea Hughes ~~~ l~ Z~l~"~ Packer Dep Pretest Initial 15 Min. 30 Min. Well NS10 -Type Inj. D TVD • 3, 87' Tubing 1980 2090 2070 2030 Interval O P.T.D. 2001820 Type test P Test psi 500 Casing 20 3520 3480 3480 P/F P Notes: EPA witnessed by Thor Cutler annual MIT-IA OA 50 50 50 50 for regulatory compliance. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test i INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2008-1011 MIT Northstar NS-10.x1s • Date 08- l 1-2008 Transmittal Number:92989 ~~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastufka at (9071564-4091 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion WATERFLOW INJECTION NS10 07-12-2008 SCH 1 4800 7980 LOG CD-ROM - WATERFLOW S10 07-12-2008 SCH INJECTION LOG WATERFLOW INJECTION NS32 07-13-2008 SCH 1 3700 8080 LOG CD-ROM - WATERFLOW NS32 07-13-2008 SCH INJECTION LOG Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center ~~~.~.~~ AUK ~ ~: 2008 BPXA AOGCC Murphy Exploration DNR MMS yza ~..~&~a ~/6~~ v=~ 203 -~5~ ~` /~~a3 c~ David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 ~~~> .~ ,. ~~~ ~ • Date 07-23-2008 Transmittal Number:92988 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf vroi have anv nuectinns_ nlease contact Jne T,astufka at (9071564-4091 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS10 07-10-2008 PDS 8 0 8022 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS10 07-10-2008 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS32 07-09-2008 PDS 5 0 8116 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS32 07-09-2008 PDS RESULTS SUMMARY NS16A 07-04-2008 SCH 1 14100 14376 PERFORATING RECORD CD-ROM -PERFORATING NS16A 07-04-2008 SCH RECORD NS19 06-30-2008 SCH 1 13550 13940 PERFORATING RECORD CD-ROM -PERFORATING NS19 06-30-2008 SCH RECORD NS30 06-28-2008 SCH 1 15890 16197 PERFORATING RECORD CD-ROM -PERFORATING NS30 06-28-2008 SCH RECORD ~~~~~~~ AUG ~_ ~ 2008 Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka ac~'iyi :t/~~s ~ Petrotechnical Data Center ~6~ =ap'1 /(~~ SS' 9 62 ~ o~ / !o(o~~ BPXA ~?' c 2007 < 1j ~~,,,/ lol0 4 / AOGCC ~.~ ~aZ _ 1S-~ ~(~~~~ Murphy Exploration DNR MMS David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 f 9-6612 ~ • Memory MuN~-Fin+~er Caiiper ~~ Lt~ Resuits ~umma 9 ~Y --- _ Company: BP Exploratio~ (Alaska), lnc. WeEt: NS-10 Log Date: July 10, 2~T Field: Northstar Log No. : 8694 ~ Qo:,~.,~~Ec-~o ~ State: Al~ka Run No.: 8 S~o ~ ~U b~~b ~S~ API Plo.: 54-029-22985-00 Pipe1 Desc.: 4.5' 12.6 Ib. L-60 IBT-M ~, Tap Log InNl1.: Sutface Pipe1 Use: Tubing ~~ ~ Bot. Lag lntvil.: 8~022 Fk {MDj Inspec#ian Type : Corrosion Moni~oring /»spection COMMEN'TS : ~.~ a° ~~ c,~, I This ~og is Sed inta tNe N2EG ~ 8,003' (ELMD). i'h~s log vvas run to assess the condi6on of the tubir~ with respec# to corrasive and mechanical damage. ' The caliper recordings indicate that the 4.5" tubing is in good to poor c~ndi~on, with a maocimum wail penetration of 72~6 in joint 139 {~,571'). The damage appears in the forms of isalated and sFrailow ~it6ng above the Overshot and lines of pits with intern~ittent areas of isolated and shallow pi#ing below the ~ Overshot. Na sig~iflcar~t areas of cross-se~ctional wai! I~s (> 796) or !. D. ~estrictions are rFCOrded. This is the eighth time a POS caliper has b+een run on this w~il. A rig wark over in January 200G replaced the tubing from surtace to 4,89i' and left a tubir~ s#ub from 4,891' to 8,003'. The c~liper recorciings indicate an increase in corrasion over the last year in both the replaced tubing and the remaining tubing stub, at a rate of a~oximately 50 miis per year, as shown in the induded comparison to previo~ graph iliustratir~g the diiference in maocimum recorded penetrations on a}otrrt-by joi~ basis of the current and previous log (July 17, 2007). Critical analysis of the caliper recordings from the currer~# and pre~vious !ag indic~tes both better tracking of the damage with the caliper flngerr and an increase in the magnitude anti frequency af pifti~g #rom surface #01,1fi0' and 5,350' #a 6,500' during the titne beM~een logs, Time to Failure ~valuation graphs of ba~h the replaced tubing {0' - 4,89i'j and the tubing stub {4,89i' - 8,003') are included in this report. These graphs project a failure date range lrased on corrosion rates calcuiated from chang~s in ti~ deepest recorded penetration in the entire well over ~me. 7he tubing from surface ta 4,891' is projeded to fail in as soon as 2.2 years. The tubing stub (4,899' - S,fl03') is projeated ta fail as soon as 9.2 years. MAXIMUM RECORDED WAtL PEIVETRAT~NS: Line ofi pits ( 72°6} Jt. 131 ~ 5,571 Ft (MDj Line af pits ( 6196) Jt. 134 ~ 5,758 Ft (M~) Line of pits ( 5696) Jt 137 ~ 5,820 Ft (MD) Line of pits ( 5a96) .tt. 129 (d1 5,483 Ft (MDj Line of pts ( 4896) Jt. 144 ~ fi,131 FL {MD) MAXIMUM RECORDED CROSS-SECTIQNAL METAL LUSS: No significant areas ~ aoss-sectiona{ wafl toss (> 7%) are recorded. MAXIMUM RECORi3ED tD RESTRICTIONS: '~~~~~ A~G ~~ 2D0$ ~ No sign~canti.D. restrietions are recorded. ~ Fiekl Engineer. K Mit/er Anaiyst: C. Wa/drop & M. Lawrence Witne~: M, Harris ProActive Diagnostic Servites, Inc. J PA. Box 13b9, Stafford, TX 77497 Phone: (281) or (888) 555-9085 Fax: (281) 5b5-1369 E-mail: PaS(.n~m~norylog,cor~ ' Prudhoe Bay Field Office Phone: {947) 659-23fl7 Fax: (907) 659-2314 ~ ~~ Jc~` ( U~C. ~arr~a ai~~ r 1~k1 Description i • PDS Multifinger Caliper 3D Log Plot Company : BP Exploration (Alaska), Inc. Field : Northstar Well : NS-10 Date : July 10, 2008 Detail of Caliper Recordings For the 5-1/8" 5 KSI Tree • • ~, .~ Well: NS-10 Field: N orthstar Company: BP Exploration (Alaska), Inc. Country: USA Maximum Recorded Penetration Comparison To Previous Survey Date: July 10, 2008 Prev. Date: July 17, 2007 Tool: UW MFC 40 No. 210357 Tubing: 4.5" 12.61b L-SOIBT-M Overlay Max. Rec. Pe n. (mi ls) 0 5 0 1 00 1 50 2 00 2 50 0.1 -- 7 17 27 37 47 54 64 74 84 .g E 94 0 z ~ 104 a 114 116.8 123 133 143 153 163 173 183 189 4 . ^ July 10, 2 008 ^ July 1 7, 2007 Difference Diff. in Max. Pen. (mils) -50 -25 0 25 50 75 100 125 150 E z "o -51 0 51 102 153 Approx. Corros;on Rate (mpy) 7 I I 17 27 I 37 47 54 64 74 84 94 04 14 I 23 33 i ~ i ~ _ _. ... 43 53 I ~ I ' 63 73 83 ~ ~ ~ ~ IIII~ ~ ~ ~ I~ ~ I~ I~ ~ I~ ~ ~ ~ ~ ~ Time to Failure Evaluation BP Exploration (Alaska), Inc. ~.~, ~ ] Northstar Corrosive Trend: Scattered Pitting Weli : NS-10 4.5" Tubing and Overshot 4.5" 12.6 Ib L-80 IBT- TCII July 10, 2008 Years Following Most Recent Log (0' - 4,981') 0 5 Wall Thickness = 271 mill 260 240 n 220 ~ 200 180 es 160 a 140 120 '~ O 100 U OC 80 60 40 20 0 ' ~ ~ ~ ~ ~~ >:5°/ Wall Thick ess ~afet Factor} '_ ~ ~~ ~ ~ ~ ~, ~ .~ , ~ ~ ~. _ ~ ~ , ~ ~ // 1 i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ' Maximum Wall Penetration in Stub ~ 1 ~ ~ ~ ~ Recorded in Jt. 25 aGd 1,107'. ~ ~ ~ ~ 17-July-07 to 03-Jan-06 ~ / ~ ~ ~ ~ (Completion Date) = 48 mpy ~ ~ ~ ~ / 1 ~ -- 10-July-08 to 03-Jan-06 ~ - (Best Fit) ~40 > ~ - - -- - - mpy ~ ~ % ~ I 1 I 10-July-08 to 03-Jan-06 ,~~ I I (Completion Date) = 34 mpy % ~ ~' 1 1 0 ' S 10 Years Since Well Completion • • Time to Failure Evaluation BP Exploration (Alaska), Inc. ~~ ~ Northstar Corrosive Trend: Isolated Pitting, ~- Well : NS-10 Shallow Pitting, and Lines of Pits 4.5" Tubing Stub below Overshot July 10, 2008 Years Following Most Recent Log 4.5" 12.6 Ib L-801BT-M (4,981' - 8,003') 0 5 10 Wall 260 240 220 ~ 200 180 160 a~ a 140 ~ 120 '~ O 100 v ~ 80 60 40 20 0 Th icknes s = 27 1 mill 85% ali Th ckne s Saf t}r ~a turf 1 1 ~ ~ / ~ ~ / I -y I ~ / ~~ ~ ` - - T ~ -` ~~ - -1 -- ~ - s I I / ( I ~ I ~ 1 ~ I I _ i~ '1 I _ I _ - -- I X ~ '~ j I I __ , ~ ~ 1 Maximum Wall Penetration in Stub - - - ~ - I 1 Recorded in Jt. 131 ~ 5,571', - ~ I 1 10-July-08 to 11-Jan-01 I ~ ~ I 1 (Best Fit) _ ~20 mpy ~ I 1 10-July-08 to 11-Jan-01 ~ 1 (Com letion Date) = 26 m py p / 1 I ; ~ I 0 5 ~ 10 15 Years Since Well Completion • II ~I • • PDS Report Overview ~--~,..-_--~~.. Body Region Analysis Well: NS-10 Survey Date: July 10, 2008 Field: Northstar Tool Type: UW MFC 40 No. 210357 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal sC C. Waldro ~ Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L~0 IBT-M 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ;, metal loss body 150 100 50 0 0 to 1 to 1O to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 203 pene. 0 54 96 41 12 0 loss 95 108 0 0 0 0 Damage Configuration (body ) 80 6O ~I(1 2O 0 isolated general line ring hole / poss pitting corrosion cortosion corrosion ible hole Number of ~oints dama ed total = 69 69 0 0 0 0 Damage Profile (9'° wall) ~ penetration body ~ metal loss body 0 50 100 0_ 47 95 13 ~) 189 Bottorn of Survey = 189.4 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 18T-M Well: NS-10 Body Wall: 0.271 in field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: July 10, 2008 Joint No. Jt. Depth (Ft) I'c~n. 111>tie~i (Ins.) Pen. Body (Ins.) Pc~n. % Metal I oss "~~ Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 36 i~ 0.03 10 z 3.93 PUP 1 41 0 0.05 19 1 3.92 Shallow it6n 1.1 83 0 0.01 4 S 3.90 P P 1.2 104 a 0.01 -1 I 3.92 PUP 1.3 113 (~ 0.01 ~ I 3.90 PUP 2 117 i i 0.03 10 1 3.91 3 159 i~ 0.06 2? I 3.90 Isolated ittin . 4 201 1 ~ 0.04 I _i ? 3.90 5 243 i ~ 0.04 I ~ I 3.90 284 0 0.05 t is i 3.91 7 325 it 0.05 l- I 3.90 8 367 0 0.03 1ti 1 3.91 409 0 0.07 15 1 3.90 Isolated ittin . 10 450 (~ 0.03 13 1 3.90 11 49 t ~ 0.03 1 1 I 3.90 12 534 a 0.06 22 3.90 I lated ittin . 13 576 i~ 0.04 13 3.90 4 617 U 0.08 ?9 I 3.88 Isolated ittin . 5 659 a 0.07 2' 1 3.90 Isolated ittin 16 701 i) 0.03 10 3 3.89 17 74 ~~ 0.03 13 2 .90 18 784 i ~ 0.03 I 1 I 3.89 19 825 i~ 0.06 2a I 3.90 Isolate ittin . 20 867 a 0.04 16 I 3.90 21 09 t~ 004 15 I 3.89 22 950 a 0.06 ~ 1 I 3.91 Isolated ittin . 23 992 i ~ 0.04 16 I 3.92 24 1033 0 0.03 13 1 3.92 25 1074 rl 0.09 32 I 3.91 Isolated ittin . 26 11 5 ii .09 32 1 3.91 Isolate ittin . 7 11 7 it .0 13 1 28 119 i I 0.06 ~ 1 I 3.92 Isolate ittin . 1 l) Iii 1 1 30 12 82 i I 0.04 1 _ ~ 1 3.92 1 3 U 0 6 ~l I s ~t~ 32 13 65 i I 0.04 15 I 3.92 U .05 19 I i ~n 34 1447 0 0. 6 2~ I .92 Isolated ittin . 148 i ~ 0.0 ' ' 1 0l t 36 1531 t~ 0.07 ~'-1 I 3.92 Isolated ittin . 37 157 ~~ 4 15 I 38 1615 i l 0.04 15 I 3.92 3 56 U .0 ~) I 40 1698 ti 0.04 13 I 3.92 1 7 n .0 ? 1 1 so i 42 1781 i l 0.04 15 1 3.92 18 i~ 003 1;' I 3. 2 44 1865 ! ~ 0.04 1 ~ :. 3.93 4.5 1907 0.05 3.93 ~_=l(~ _ I'J4ti 0.03 ;.93 Penetration Body Metal Loss Body Page 1 • PDS REPORT J OINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: July 10, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul~s~~t (Ins.) Pen. Body (Ins.) I'c~n. `i6 Met~il I~>ss ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1990 i) 0.05 17 I 3. 47.1 2031 tt 0.01 -1 I 3.9 PU 47.2 2041 ~t 0 tl U 3.81 HES X-Ni le 47. 2043 i t 0.02 8 I 3.92 P P 48 205 it 0.0 2lt I 3.9 Shallow ittin 49 0 4 it 0.03 1c) I 3.91 50 21 6 i t 0.03 1 1 t 3.91 51 17 1 1 0.0 I i I 3 2 52 2 20 i t 0.04 15 I 3.9 53 22 it 0 04 15 1 .91 54 2 3 04 i t 04 14 3.9 5 346 a 0.03 I O 2 3.92 56 2388 !t 0.04 15 1 3.92 57 2430 ~ t 0.03 13 I 3.92 58 247 i t 0 05 19 t 3.92 Sh I ow itti 59 2513 it 0. 3 11 3.93 60 2554 it 0.02 8 I 3. 3 9 it 0.03 lil I 62 2637 i t 0.04 1 5 I 3.93 63 2679 tt 0. 4 15 ~ 3.92 64 27 1 u 0.04 1;3 I 3.92 5 2763 It .05 17 1 3.9 6 2805 ~t 0.03 10 ~' 3. 3 67 2846 n 0.04 14 I 3.93 6 2888 a 0. 3 111 69 2930 it 0.03 Il 3.93 70 2972 it 0.02 ti I 3.9 71 3014 i t 0 02 U I 3.92 3055 tt 0.04 13 I 3.92 73 3097 it 0. 3 1~t I 3.92 7 I t .04 1 5 I 75 31 i t 0.01 -1 I 3.93 7 tt 1 > 1 77 3264 i t 0.07 ' S 2 3.92 I ated it 'n . 0 u ~~ 1 79 347 It 0.02 E3 ? 3.92 0 U li 1 81 3431 i t 0.03 11 2 3.91 47 it 0 3 111 ' 83 3515 ~t 0.01 ~ .91 557 (t 8 I 85 3598 (t 0.02 6 I 3.91 8 it 0 87 380 tt 0.03 ltt 1 3.91 37 i t ti ' 9 3763 ~ t 0.01 ~~ _' 3.9 ~ ~ -1 I 91 3846 tt 0.0 ~) 3.91 9~ 388 ~ ~ I U 3. 9 3 3929 0.03 3.93 ®Penetration Body Metal Loss Body Page 2 • PDS REPORT J OINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Upset Wa}I: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: July 10, 2008 Joint No. Jt. Depth (Ft.) Nr~n. UL~sc~t (In..) Pen. Body (Ins.) I'en. % '~1crtal loss °'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) D 50 100 94 3 71 ~ ~ 0.02 ~~ 1 .9 95 401 U 0.01 -t 3.9 6 40 4 U 0.01 4 I 3.91 97 4096 U 0.04 15 1 3.92 4138 ~) 0.03 I I 3.92 99 417 ~~ 03 12 I 1 10 221 t~ 0.04 15 1 3.91 101 426 t~ 0.02 c, .91 10 4302 iI 0.01 103 4344 i~ 0.01 4 3.92 104 4386 U .02 ~) 1 3 3 105 4428 t~ 0.0 7 I 3. 2 106 4470 a 0.0 I3 I 3.9 107 451 U 0.01 ~ ~ 3.91 108 4553 U 0. 3 11 s 3.9 109 459 U 0.04 15 I 3.92 1 0 4637 U .0 ti 1 3.90 1 4 t l l U 1 3.9 12 4721 a 0.03 I1 1 3.91 113 4761 U 0.05 I ~~ 3.92 Sh I w itti 114 4803 ~ ~ 0.05 I ; ~ .91 115 48 5 i~ 0.02 ti 1 3.9 116 4887 l~ .04 I5 1 3.91 116.1 4929 0 0.0 is I 3.93 PUP 116. 4 38 U 0 ~~ ~~ 3.81 HE X- 116.3 4940 (1 0.0 ~~ 1 .92 PUP 116. 4950 ~~ 0.01 4 I 3.92 PU 1 6.5 4959 U 0 0 U 3.8 aker PRE Pac er 11 4967 t~ 0. 3 11 1 3.92 PUP 1 6.7 4972 U 0 t~ a 3.73 H S XN-Ni le 49 4 (1 U U 117 498 ~~ 005 ('i , 3.91 Shallo ittin (i ; 117.2 5013 t1 0 t) U 3.88 Baker S-3 Packer 1 5 18 t~ ~S ~ .9 ' solate 't ~n . 118 5027 U 0.04 13 3.91 6 ~~ 4 1 ; 120 51 10 ~ ~ 0.05 1 i ; 3.89 t. De sits 1 2 1 2 (~ 0.0 t3 t, 3.88 Iso ed ittin Lt e its 3 U 1 3~i i 1 5274 +l 0.05 _'(~ S 3.91 Isolat d ittin . 126 357 t).U(~ 0.05 I ti 3.90 Li of i 7 9 tl 1 4-1 90 it . 128 5438 a 0.09 ~_' 3. Li e of its. 4 U 4 Sti 3 i 130 55 0 U 0.11 41 ~ 3.89 Li a of its. 1 56 (~ ; i 560 a .0 19 I .88 Shallow itfin Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINTTABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Fxploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: July 10, 2008 Joint No. Jt. Depth (Ft.) I'r~n. Ul~c~t (Irn.~ Pen. Body (Ins.) Pen. °/, Metal I rns ,~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 133 5644 u.U(, 0.08 2fi 3.88 ine of it 134 5684 tt 0.16 U1 3.89 ine of i 135 5726 U 0.10 37 3.90 Line its. 36 5767 U.I I 0.1 41 3,88 Lin of its. 137 5808 U 0.15 56 3 3.88 Li e of it . 138 5848 tt 0.13 4~ 3.90 Line of its. 139 5890 u.tt<t 0.09 3 3 3.88 Line of ~ts. 4 5930 U 0.10 3t3 -t 3.8 'n of i 141 5972 lt.(1; 0.10 38 3.88 Line of its. 142 6013 tt .11 -ll 1 3.89 Line of its. 14 6055 t t .09 >-} 3.89 Li e of its. 44 6096 I t 0.13 -1t3 3 3.89 Line of its. 145 6137 U 0.09 3 S (, 3.89 Line of its. Lt. a its 146 6178 (t 0.09 3Z 3.89 Line of its. 147 6219 t t 0.09 32 ~ .88 Lie its 148 6260 n .12 4~i 3.8 Line f it . 149 63 0 U 0.11 ~12 3.89 Line of its. 0 6341 a .07 '~ s 3.89 Li e of ~t 151 6382 t~ 0.10 X38 ~3 3.90 Line f its. 152 424 n 0.09 ~ 3.89 Line of i 153 6465 t t 0. 9 32 3 3.89 Line f its. 154 6507 tt 0 8 2i3 3 3.90 Line of its. 155 6548 tt 0.05 1~1 ~ 3.88 Shallow ittin 156 6590 t) 0.0 ZU i 3.89 Isolated i tin 157 6631 a 0.06 Z~ 3 3. 7 Isola ed ~tti 158 6671 t? 0.07 Li ~' 3. 8 Isol ted ittin . 159 6712 tt 0.04 15 ~ 3.87 160 6753 tt 0.05 2U 3 3.89 Shal w ~ttin 161 6794 i t 0.04 13 _' 3.88 Lt. De it . 162 6835 i t 0.03 I U 3.89 6 76 U 1 ~~ 0 i 164 6917 t t 0.04 1 3 3.89 l) I i > 166 6997 n 0.05 1' .89 7 0 t? .0 1 i .8 168 7079 tt 0.03 1 I 3.88 1 9 7 1 U ~ -1 170 7161 U 0.06 ~' I _' 3.91 I lated ittin . 17 0 t t .04 15 ' 172 7244 t t 0.04 I ~ 3.9 17 8 tt .0 lts i 174 73 7 U .05 1'> ? 3.91 Sh I w ittin 7 U l ' 176 7409 t) 0.03 10 3 3.91 177 7450 ~) 0 1 £ -1 9 178 7491 t t 0.04 1 3 i 3.91 7 ~t I ~! 3 i ti 18 7573 (1 0. 5 I~) 3.88 Shall w ittin 81 6 ~ ~ 4 I -4 182 7655 0. 3 i ~ t .91 Penetration Body Metal Loss By dy Page 4 • PDS REPORT JOINTTABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 IBT-M Well: NS-10 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: July 10, 2008 Joint No. Jt. Depth (Ft.) N~~n. Upset (Ins.) Pen. Body (Ins.) Nen. % ~~1et,~l Leis .~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 SO 100 18 7696 t) 0.05 17 3 3. 9 184 7737 ~ ~ 0.05 10 .90 185 7779 ~~ 0.04 15 3 .9 86 7 0 t> 0.0 11 ~ 3.9 187 7861 ~~ 0.03 1t) 3 3. 9 188 7902 U 0.04 1 ~ 3. 9 189 7943 !) D.0 14 s 3.89 189.1 7984 +~ 0.06 ' I i 3.89 P Isolated 't 189. 7993 U 0 U O .73 TI N-Ni le 189.3 7996 t) 0 06 Z 1 7 3.87 PUP Sh Ilow itti L . De i s 189.4 8006 O 0 U ~~ 3.96 WLE gPenetration Body Metal Loss Body Page 5 ~~ ~~ PDS Report Cross Sections Well: NS-10 Survey Date: July 10, 2008 Field: Northstar Tool Type: UW MFC 40 No. 210357 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 ins 12.6 ppf L-80 IBT-M AnaNst: C. Waldron Cross Section for Joint 131 at depth 5570.997 ft Tool speed = 44 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 98 Tool deviation = 54 ° finger 37 Penetration = 0.195 ins Line of pits 0.20 ins = 72% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~~ ~~ PDS Report Cross Sections Well: NS-10 Survey Date: July 10, 2008 Field: Northstar Toof Type: UW MFC 40 No. 210357 Company: BP Exploration (Alaska), Inc. Tool Size; 2.75 Country: USA No. of Fingers: 40 Tubin 4.5 ins 12.6 f L-80 IBT-M Anal st; C. Waldro Cross Section for Joint 134 at depth 5707.55 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 98 Tool deviation = 53 ° Finger 36 Penetration = 0.164 ins Line of pits 0.16 ins = 61% Wall Penetration HIGH SIDE = UP • •i Cross Sections page 2 TREE= ABB-VGI5-1/8" ' ' 20" CONDUCTOR, 169#, X-56 199' Minimum ID = 2.6" @ 2043' 4-1 /2" X NIPPLE wlPROTECTNE SLV 10-3/4" CSG, 45.5#, L-80 BTC, D = 9.95"? 3726' ' 4-1/2" TBG, 12.6#, L-80 TCII, 4977' 1 .0152 bpf, D = 3.958" 4-1/2" TBG, 12.6#, L-80 IBT-M, 8006' ' .0152 bpf, ID = 3.958" 7-5/8" CSG, 29.7#, L-80 BTC, $029' .0459 bpf, D = 6.875" _ ~ 6-3/4" OPEN HOLE TD $Le~.6' S NOTES: ***EPA CLASS 1 DISPOSAL W ELL *,~ NS10 2043 J-14-1/2" HES X NP, D = 3.813" 2043' PROTECTNE SLV, D = 2.6" 4-1/2" HES X NIP, D = 3.813" 4960' I~ 7-5/8" X 4-1/2" 8KR PREM PKR, D = 3.875" 4-1/2" HES XN N6~. D = 3.725" -~-jTBG STUB (12/27105) ~ - I 4-1/2"UNIQUEOVE(2SHOT, D=4.654" 5015' I-~ 7-5/8" X 4-1l2" BKR S-3 PKR, D = 3.875" 7994` I-I4-1/2" OTIS XN NIP, D = 3.725" 4-1/2" WLEG, ID = 3.958" ELMD TT LOGGED 06/01/01 DATE REV BY COMMENTS DATE REV BY COMMEMS 01/11/01 AGK ORIGINAL COMPLETION 01/03/46 N33E RWO 01/05/06 JGB(flH PROTECTNEN~PLESLV SET 01/21!06 ???ITCH DRLG DRAFT CORRECTIONS 11/27/07 WRR/PJC WELLHD/LOGAT~N CORRECTIONS 06/28!08 WRR/PJC DRAWANG CORRECTIONS WELLHEAD = ABB-VGI 11" MULT~OWL' ACTUATOR = BAKER KB. REV = 55.77 BF. REV = 39.87 (CB 15.9') KOP = 833' Max Angle = 51° 4424' Datum MD = 13071' Datum ND = 10500' SS NORTHSTAR WELL: NS10 PERMIT No: 2001820 API No: 50-029-22985-00 SEC 11, T13N, R13E, 1139' FSL &643' FEL BP Exploration (Alaska) MEMORANDUM • 'ro: Jim Regg ~~ 3I D'b P.I. Supervisor ~~ ~~% EROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commi~ DATE: Tuesday, April 01, 2008 SUBJECT: Mechanical Integrity Tests HP EXPLORATION (ALASKA) INC NS- ] o NORTHSTAR UNIT NS-]0 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.1. Suprv~_ Comm Well Name: NORTIISTAR UNIT NS-10 API Well Number: 50-029-22985-00-00 Inspector Name: Bob Noble Insp Num: mitRCN08032s073414 Permit Number: 200-182-0 Inspection Date: 3/21/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --- __ -- - - Well ~ NS 10 Type Inj. N 'I'~7D 3987 IA ~ 20 ~ 3520 3430 3420 ---- - - P T i 2001820 ~ ypeTest sPT Test ps'~ 3s2o pA 1 so ~ so so so ~ _-- - -_ _ orx~ _ - --- Interval ER p/F P ;/ Tubing 9so ~ s9o i s~o s9o ~ - --- - - - ___ - ~_- - L __ _1 - ___1 __ _ L -- Notes• EPA witnessed, annual MIT-IA ~~>~~~~ ~~~e ~~ ZOUt Tuesday, April 01, 2008 Page 1 of I e e bp Date 08-14-2007 Transmittal Number:92897 5 ZOOl ,~." BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~o Log Top SW Name Date Contractor Run Depth Bottom Depth Log Type L>:t~ -/11(;) NS10 07 -21-2007 SCH 1 4800 7975 WATERFLOW INJECTION :tc. C:i3-, ,,4( NS32 07 -20-2007 SCH 1 3760 8075 WATERFLOW INJECTION 8-dò"T NS19 07 -08-2007 SCH 1 13650 13955 PERFORATION RECORD -D3C.. NS11 07 -06-2007 SCH 1 14450 14625 PERFORATION RECORD ),L - ()W_ NS13 07-14-2007 SCH 1 11534 11790 MEMORY PPROF - (~ NS24 07 -15-2007 SCH 1 11774 12476 STATIC BOTTOM HOLE , ø -~:;)3 NS22 07-09-2007 SCH 1 12600 12850 PERFORATION RECORD ~ -08\ NS08 12-23-2005 PDS 1 9006 11406 CORRELATION LOG Od -a ~ NS21 07-02-2005 PDS 1 21590 22249 DEPTH DETERMINATION -" ~~ '8d- NS10 01-01-2006 PDS 1 4497 5497 CORRELATION LOG €J¢O ú f) ~b 9ö&; }( ~ )od. ;) (,) ~\ ~.1L= Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center 5CANNED AUG 112007 Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 e e bp Date 08-15-2007 Transmittal Number:92900 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Log Top SW Name Date Contractor Run Depth Bottom Depth LOQ Type MEMORY CALIPER LOG NS10 07 -17 -2007 PDS 7 0 8006 RESULTS AND CD ROM MEMORY CALIPER LOG NS32 07 -16-2007 PDS 4 0 8103 RESUL TS AND CD ROM (~ ,lJ~ Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petro technical Data Center Ri,', '" "E'" r~,",' E", . ~,\lF . .L¡ ~!jf ""'" 1\\ \G 1 6 2007 hV .... AI_a 01\ r:,'.mmissiOi1 .~,"V Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks MMS Murphy Exploration AOGCC DNR S~NED AUG 1 "12007 u:r:c. e()ù-/td :JJ: is-331 U:r.~ Bc'ß - is-'&' 1t '563;) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 I I I I I I I I I I I I I I I I I I I . . Memory Multt-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: BP Exploration (Alaska), Inc. July 17, 2007 8610 7 4.5" 12.6 lb. L-80 IBT-M Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log Intvl1.: NS-10 Northstar Alaska 5Q-.029-22985-00 Surface 8,006 Ft. (MD) Inspection Type: COMMENTS: Co"osion Monitoring Inspection This log is tied into the WLEG @ 8,006' (Driller's depth). This log was run to assess the condition of the tubing with respect to changes in corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing is in good to fair condition with respect to corrosive damage. A maximum wall penetration of 37% is recorded in joint 120 (5,135'). Wall penetration in excess of 20% are recorded in 27 out of the 211 joint logged. The damage appears to be in the form of Isolated/Shallow Pitting, General Corrosion and Line of Pitting. No significant areas of cross-sectional metal loss or I.D. restrictions are recorded. This is the seventh time a PDS caliper has been run on this well. A comparison between the current log and the previous log run on this well (August 2, 2006) indicates a slight increase in corrosive damage in the 4.5" tubing. The caliper recordings indicate the 5-1/8" 5KSI tree appears to be in good condition, with no apparent damage recorded. A 3-D log plot of the caliper recordings through the tree is included in this report. MAXIMUM RECORDED WAll PENETRATIONS: Isolated Pitting Corrosion Isolated Pitting Isolated Pitting Isolated Pitting ( 37%) ( 35%) ( 32%) ( 31%) ( 30%) Jt. Jt. Jt. Jt. Jt. 5,135 Ft. (MD) 5,020 Ft. (MD) 5,269 Ft. (MD) 4,993 Ft. (MD) 5,762 Ft. (MD) 120 @ 117.3 @ 123 @ 117 @ 135 @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (>4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. S~~~NED AUG 1 '1 î007 I Field Engineer: K. Miller Analyst: B. Qí Witness: B. Rochín ProActive Diagnostic Services, Inc. I P.O. Box 1369/ Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 U':1:(!..goc-1,&,8 ~ 15"'331 I I 4.5 in (22.9' - 8004.0') I I I I I I I .... 100 !1> ..!::I E :::;¡ z .... ,£ .2- 125 I I I I Bottom of SUlvey 189.4 I of Damage to Borehole Well: Field: N5-lO Nor ihsta r BP (Alaska), inc. USA July 1 7, 2007 Country: Survey Date: Approx. Tool DevÎation Approx. Borehole Profile 25 50 75 150 175 189.4 o 50 Damage Profile wail) / Tool Deviation (degrees) 4215 5311 6338 7367 8004 100 27 1063 2126 3173 it r:: I I I I Well: Field: Company: Country: NS-l0 N orthstar BP Exploration (Alaska), I nc. USA I Overlay I o Max. Rec. Pen. (mils) 100 200 I I I I Maximum Survey Date: Prev. Date: Tool: Tubing: -so I ~ ~ E E :J :J Z z 1: 1: :2. :2. I I I I II I I Penetration To Previous July 17, 2007 August 2, 2006 MFC 40 No. 99493 45" 12.61b L-BO Difference Dlff. in Max. Pen. (mils) o SO 100 ~ 0 ~ 1~ Approx. Corrosion Rate (mpy) I I I lubricator Tree Cap Swab Valve I Flow Cross I I Surface Safety Valve Mastel' I Valve I Hanger 4-1/2" Tubing I I North sta r 17, o Detail of 5-1/8" 5KSI Tree I I I We!!: Field: Company: Country: NS-lO Northstar BP USA (Alaska), ¡ne I Tubing: Nom.OD 4.5 ins Weight '12.6 f Grade 8< Thread L-80 IBT-M Penetratiol1 and Metal toss (% wall) I penetration body metal loss body I 200 150 100 50 0 1 to 10% 40 to over 85% 85% I o o I Damage Configuration ( body) 150 100 50 o I isolated general iine ring hole / po$S pitting corrosion corrosion corrosion ¡ble hole o S Report Overview Body Region Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.lD 3.958 ins Nom. Upset 4.5 ins penetration body o o july 17, 2007 MFC 40 No. 99493 2.75 40 B.Qi Upper len. 6.0 ins Damage Profile (% wall) metal loss body 50 47 Analysis Overview page 2 I 95 139 Bottom of Survey = 189A 189 Lower len. 6.0 ins 100 I TABULATION Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in 1.-80 IBT-M Well: Field: NS-lO Nor1hstar BP (Alaska), Inc. USA July 17, 2007 Country: Survey Date: I Joint Jt Depth Pen Pen. PerL 'Metal Min. Damage Profile No. (Ft.) 1.0. Comments (%w all) (Ins.) (Ins.) (Ins.) 0 50 100 .1 23 =+t=;= 4 1 3.89 PUP 'I 27 2 1 3.89 1.1 69 4 ¡ 3.88 PUP 1.2 89 øu 3.89 PUP 1.3 99 . 1 3.91 PUP 2 103 0.D3 1.90 3 146 ) 0.02 ( 1 3.89 4 188 3.89 5 230 ) 0.01 I 3.90 h 272 001 ¿ 1 3.91 7 3D 0.02 ( ! 3.89 8 355 1 3.90 9 397 3.89 10 438 3.QO n 480 0.02 3.90 12 522 0.01 3.90 D 563 0.0 14 605 D 0.01 1 1.89 15 647 0.01 4 I 3.R9 16 689 0.01 4 3.90 17 731 0.03 10 ~ 18 773 0.02 9 19 814 0.0'. 20 856 0.01 3.89 2'1 R98 0.07 3.90 22 939 0.01 3 3.90 23 981 0.04 i.90 Shallow oitlinll. 24 1021 ~I om 3.91 25 1063 3.91 26 1105 3.90 27 1146 3.90 Shallow niUin". 28 1187 0.D3 3.91 Shallow nitlinq. 29 1229 0.03 1 3.89 Shallow oiUinq. 30 '1271 0.05 3.92 Isolated oittinlL 31 13'12 0.07 I =ili1 ~ittil1\:!. 32 1354 ¡ 0,05 1 Shallow niUim:!. 33 1396 0 0.07 3.91 Isolated niWn" 34 1437 0.D3 1 3.92 Shallow nitliru>. 35 'I47R 0.02 9 I 3.91 36 1 '120 0.07 2 1 3.91 Isolated oittinq, 37 1562 0.D3 iir9' 38 1604 0.04 1 3.91 Shallow oittinll. 39 1646 0.04 3.91 Shallow oitlinll. 40 1688 0.05 3.91 Shallow oitlimr. 41 1729 0.05 3.91 Shallow oittimI. 42 1771 O. '5 0.05 1 1 3.91 Sh"lInw niilinc. 43 1813 0.04 ¡ 1 3.91 Shallow "iilinº'. 44 1855 ( 0.03 I I 3.91 Shallow ,,¡dnq. 45 1897 I ) 0.01 1 I 3.92 Shallow nÎt!Înq. 46 1938 ( 0.D3 H 1 3.91 I I I Body I.oss Body Page 1 I I Joint Jt. Depth Pel Pen. Pen, I !\r1elal Min. No. I(::~~(;t Body W. Comments (Ins.) - 47 1980 n 0.03 12 ¡ 47.1 2022 n ¡ 47.2 2031 ~ 2033 '.-.itlin¡;¡. 2043 L- 'ï;hàlïow nitti"º'. 49 2084 0 3.91 50 J126 t L. ~ Sh"lIow nitlin<r. 51 2168 { 0.0 C-.-. Shallow nítlin<r. 52 2210 0.03 51 J2!12 1 1.91 Shallow nittin<r. 54 2294 ! 3.91 "},,,II"'M nit!Ìno. 55 2336 391 5f. J37R 3.91 Sh"lInw nítlin". 57 2420 q q1 S"",lIow nittin"'. 58 ~ <;h;¡!iow nittina. 5q 3. " . 60 ! 3.91 61 2587 I 3.91 Shallow mUnQ. 62 2629 _ ~ nWint!. 63 2670 0 _ Shallow oHlinl'l. 64 2712 0 4 3.91 s¡""l!nw"¡ttin"'. 65 7"'<;4 0.03 ~ Sh.I~ ~üno. 66 'J"Q7 0.ü3 ~ II"", "jtlinº. 67 2 38 g 1 nittirnr. 68 2H79 n . ~ low nítlim!. 69 2q21 3.92 ~ lI~w oittinl'l. 70 2963 3.91 Sallow "itlino. 71 3005 ! 0.04 3.91 Shallow nitlin<>. 72 3047 0.02 ( 3.()1 73 3089 0.03 1 I 3.92 74 3131 0.0 3.92 75 3173 0.0. 3.92 Shallow oit1imz. 76 i4 o~ 2 1* 77 ;6 Shallow mt!Îrnl. 78 HJB ¡~ II 79 !.O 3.91 Shallow nitlírn> 80 3382 3.92 Shallow oWino. 81 3424 i.91 82 3466 O. 3.89 83 3508 I 1 ],91 84 3550 ·1 'I 3.97 Shallow oitiinQ. 85 3591 , I 3.91 86 3(;11 #t 1.91 87 3673 3.91 88 3715 4 1 3.91 Shallow nitlínº. 89 1757 0.0 ¡ 3.91 90 3798 0.03 <) ii& Shallow oitûl1Q. 91 3840 m± 97 3881 3.91 93 3922 ! 3.92 JOINT I 4.5 in 12.6 ppf l-80 IBT-M 0.271 in 0.271 in 3.958 in Wen: Field: WaI!: Upset Wan: Nomina! 1.0.: Country: Survey Date: I I I I I Page 2 I LATION SH NS.lO Northstar BP (Alaska), Inc. USA July 17/ 2007 -0 · Profile o 50 100 I joint jt Depth Pel Pen. ~;~ cun Min. No. (Ft.) \::~~~;t Body !.D. Comments (ins.) (Ins.) 94 3964 0 ,.1 95 4006 0 96 4048 0 .92 97 4089 0 f(j ! 3 98 4131 99 4173 I) ÔJ11 100 4215 0 n.02 101 4254 I) 0.ü1 102 4296 0 0.03 103 4338 0.ü1 '1 1 3.91 104 4380 0.ü1 .ç¡=f 3.92 105 4422 0.03 3.92 106 4464 0.02 =ij392 107 4506 0.02 3.92 108 4548 0.02 3.92 109 4590 0.D3 HI 3.92 110 4632 002 ! 3.91 111 4674 0.02 ( ! 3.92 112 4716 t; I I 3.91 itúno. 113 4756 1~±t 3.92 114 4798 3.92 Shallow"lt6no. 115 4840 0.02 ! J PUP 1H; 4882 0.ü1 116.1 4924 0.ü1 1 H>.7 4934 n r ! 116.3 4936 om I ! 116.4 0.ü1 I ¡ PUP 116.5 4954 0 0 3.88 PACKER 116.6 4961 0.02 3m PUP 116.7 4967 0 3.73 X N NIP 116.8 4971 ikbt 4.65 OVERSHOT 117 4978 3.89 Isolated nittinq, Lt. Denosits. 117.1 4999 0.05 '!'R 3.90 PUP Shallow "iUinO'. 117.2 5008 0 I 3.88 PACKER 117.3 0.09 3.91 PUP Corrosion. 118 5023 o.nA. 3.89 Shallow nìtúnº. 119 5064 1),17 fHI'> 3.88 Sh"U"W' nitún<>. 120 5106 0.10 3.89 !<;obtpc! nittinq Lt. Denosi¡s. 121 5147 0,11', 0.08 3.90 Isolated niWnq 122 5188 0, 16 0.08 3.89 Isolated oittinQ:, 123 52291109 3.68 isoiated "¡uina 124 5270 .08 2 3.90 Isolated "ittinO' 125 5311 .08 2 3.90 Isolated niWnO' 126 5352 0, .05 ' 1 3.90 Sh,.II"\N ..itlin<r. 127 5393 .07 3.90 Isolated nittino 128 5435 .06 3.89 isolated nittin<> 129 5476 OH, 0.07 3.89 Isolated niUina 130 5516 0.07 ;¡¡ 2 ~ Isolated nittino 131 5557 007 :¡ Isolated ..iWno 132 5599 0.05 í 3.90 Shallow ..itlino. I JOINT I I Pipe: Body Wall: Upset WaR: Nominal J.D.: Well: Field: Company: Country: Survey Date: 4.5 in 12.6 ppf L-80 IBT-M 0.271 in 0.271 in 3.958 in I I I I ,I I I I I I Page 3 ULATION NS-lO Norihstar BP Exploration (Alaska), Inc. USA july 1 7, 2007 'n7' \;;>file o \f~d!l1100 ~ fill IiI fill IfI!I Joint Jt. Depth Pen, Pen. Pen~ I i\o\e!al Min. ,~:o Profile No. (Ft.) ,! Body 1.0. Comments '" POWdll} (Ins) (Ins.) (ins.) 0 50 100 133 till' 3.90 isolated nittino 134 56811 3.90 Isol;¡¡ted nittino 135 5n2 ( 1 3.90 Isolated niUino 136 ;; 3.90 Isolated niWno 137 1 3.90 Shallow nitlino. 138 5845 n 0.06 .' 1 ~ line of nittina. 139 5887 0 ! Line of nittina. 140 5928 j 3.89 Isolated nittinu 141 5968 ) Shallow "itlin"'. 142 6010 1 006 Isolated ....¡ttin'" 143 6052 Shallow nitlin"'. 144 6093 90 Shallow "itlincr. 145 6134 90 , -. 'ttino 146 6175 i ~ 'I .90 Shallow nitlino. 147 6216 i 11 0'; I 3.90 itlin<>. 148 6257 ! I 3.91 Is J iWn<> 149 6298 il 17 Shallow nitlin"'. 150 6338 :" ;¡ttîn". 151 6379 .04 1 ;; . tina. 152 6422 0.05 I 1 3.90 iUnu. 153 6463 ~ 3.90 154 650"; O~)6 390 Isolated nittinu 155 6546 0.04 3.89 itlina, 156 6588 0.D3 3.90 jUna. 157 6629 I 0.03 I 11 3.90 i t. Dehosjt<o. 158 ~ 3.91 Shallow <JiUino. 159 6710 ! 3.89 Shallow nittina. 160 6751 {) 0.041 3.90 Sh;'ùlnw nitlinº', 161 6793 0.04 -1 3.90 "h"II"", "itlÎn<>'. 162 6634 i -~: 3.89 163 6875 ¡1)f¡ 11 =±±90 "h"l!"w nittino. 164 6916 ;; .89 """lInw"jtlinu, 165 6957 n ,t. 1 3.89 Shallow nittincr, 166 6996 3.90 167 7037 3.90 Shallow nitlincr. 1»R 7079 1 3.90 Shallow nitlin<1, 169 71:>0 ( 3.90 Shallow nitûn<1. 170 7160 ~,:¡- 3.91 Shallow nitûnQ, 171 7201 n )'1 0.04 if\<} Shallow niUincr, 172 7243 10 1 3'!,}9 173 7284 3.89 Shallow nitûncr, 174 7326 ( 3.88 .. jttincr 17<; 7367 0.04 3,90 176 7408 0.03 3.89 177 7449 0.05 '17 " 't89 ¡·lin.... 178 7490 0,04 nl 3,90 itlincr. 179 7532 0,04 ~ 3.90 Shallow njtûncr, H10 7573 004 I ~~ Shallow nittin<>'. UH ! 7»14 'ttinG 182 7655 0.04 TI ~ 3.89 ¡Un<>', I JOINT u Pipe: ßodyWall: UpsetWaU: Nominal tD.: 4.5 in 12.6 ppf L-80 iBT-M 0.271 in 0.271 in 3.958 in We!!: Field: Count/)': Survey Date: I I I Page 4 I ON SH EIT NS-lO Norlhstar BP Exploration (Alaska), ¡ne. USA July 1 7, 2007 JOINT ULATION SHEET Pipe: Body Wal!: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf 1.-80 IBT-M 0.271 in 0.271 in 3.958 in Well: Field: N5-lO Northstar BP Exploration (Alaska), Inc. USA July 1 7, 2007 I Country: Survey Date: I its. Joint No. Comments sits. I I I I Page 5 I - - We!!: Field: Company: Country: Tubin : NS-10 Northstar BP Exploration (Alaska), tne. USA 4.5 ins 12.6 f L·80 18T·M for Joint 1 Tool 69 NominallO 3.958 Nominal 00 == 4.500 wall area 99 % Tool deviation 66· - - - - s rt ross ons Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: July 17,2007 MFC 40 No. 99493 :U5 40 B. ¡ 5134.93 ft Finger 34 Penetration == 0.1 ins Isolated Pitting .10 ins == 37% Wall Penetration HIGH SIDE == UP Cross SectÎons Pilge 1 - - Well: Field: Company: .. .. .. .. p S Sections rt NS·10 Northstar SF Exploration (Alaska), Inc USA 4,5 ins 12.6 f L-BO IBT-M Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: July 17, 2007 MfC 40 No. 99493 2.75 40 B. i Tubin : Joint 11 Tool '" 68 Nominal fD '" 3.958 Nominal 00'" 4.500 Remaining wall area'" 98 % Tool deviation'" 6 7 0 ft Finger 34 Penetration'" 0.094 ins Corrosion .09 ins'" 35% Wall Penetration HIGH SIDE'" UP Cross SectIons :2 .. .. I I TREE = ABB-VGI 5-1. ~NOTES: W8...LHEAD = ABB-VGI11" NUL TIBOW ACTUATOR = KB. 8...EV = 55.77" BF. 8...EV = 39.87' (CB 15.9') NS10 KOP= Max AnQIe = Datum MD = Datum NO = .. 120" CONDUCTOR, 169#. X-56 199' r ~ ~ 2043' 4-112" X Nf'. ID = 3.813" I , 2043' PROTECTIVE SL V. D = 2.6" (01105106) 1 Minimum ID = 2.6" @ 2043' 4-1/2" X NIPPLE wlPROTECTIVE SLV 110-3/4" CSG. 45.5#. L-80 BTC. D = 9.95"? 3726' ~ ~ I · 4938' 1-14-112" X Nf'. ID = 3.813" I · ~ 'V .J 4960' 7-518" X 4-112" BKR PREMIER PKR. ID = 3.875" ~ ~ I · 4972' 1-14-112" XN Nf'. ID = 3.725" I · . 14-1/2" TBG. 12.6#. L-80 TClI. .0152 bpf. ID = 3.958" 4977' t- 1 . 4981' liTBG STUB (12127105) f - 4986' 1 ---. 4-112" UNIQUEOVffiSHOT.ID=4.654" ~ ~ 5015' I-1SKRS-3 A<R, 10=3.875" I '" I · ',7994' 1-J4-112" OTIS XN Nf'. ID = 3.725" I I " 4-1/2" TBG. 12.6#. L-80 IBT-M, .0152 bpf. ID = 3.958" 8006' J.... I'i --t. 80~ H4-112"WLEG.ID=????" I ,- 17-518" CSG. 29.7#, L-80 BTC. 10 = 6,875"? 8029' ~ .. 1 E3..MJ TT NOT LOGGED? 1 J ) '6-314" OPEN HOLE TO H 8246' I-- ) DATE REV BY COM\,o18\ TS DATE REV BY COMM:NTS NORTHSTAR 01/11/01 AGK ORIGINAL COM PLETION W8...L: NS10 01/03/06 N33E RWO PERMrr No: ~001820 01105106 JGBIlLH PROTECTIVE Nffi.E SL V SET AA No: 50-029-22985-00 01121106 ???IlLH DRLG DRAFT CORRECTIONS BP Exploration (Alaska) I I I I I I I I I I I I I I . . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~~s~;;r~isorKe114tZhID7 DATE: Monday, April 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NS-IO NORTHSTAR UNIT NS-]O Src: Inspector \ Cf;~ ~pO ." FROM: Bob Noble Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .:JB12-- Comm Well Name: NORTHSTAR UNIT NS-IO API Well Number: 50-029-22985-00-00 Inspector Name: Bob Noble Insp N urn: mitRCN0704 I 4 I 3284 I Permit Number: 200- 182-0 Inspection Date: 4/13/2007 Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NS-]O Type Inj. N TVD 997 IA 0 3515 I 3490 3483 P.T.D 200] 820 TypeTest SPT Test psi 35]5 OA 50 50 50 50 Interval OTHER P/F P Tubing 94] 960 948 937 Notes: EPA test on Class I ejector /' 5t,ANNED APR 3 0 2007 Monday, April 23, 2007 Page I of I . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Northstar / NS / NS 04/13/07 Anna Dube d}:)Û /llþr Packer Depth Pretest Initial 15 Min. 30 Min. WelllNS10 I Type Inj. I W TVD I 3,987' Tubing 940 960 948 9371 Interval I 0 P.T.D.12001820 Type test P Test psi I 1500 Casing 0 3515 3490 34831 P/FI P Notes: EPA witnessed annual MIT-IA for regulatory OA 50 50 50 50 I compliance. Weill I Type Inj. I I TVD I Tubing I Interval I p.T.D.1 I Type test I I Test psil Casing I P/FI Notes: OA I Weill Type Inj.1 I TVD I Tubing I Interval p.T.D.1 I Type test I I Test psil Casing I P/F Notes: OA I Weill I Type Inj.1 I TVD I Tubing I Interval P.T.D.I I Type test I Test psi I Casing I P/F Notes: OA I I I Weill Type Inj.1 I TVD I Tubing I Interval I p.T.D.1 I Type test I Test psi I Casing I P/F Notes: OA I TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) SCANNED APR 1 9 2007 MIT NS NS1 0 04-13-07.xls RE: NS 17 (PTD #2021690) 4-year MITIA fOiulatOry Compliance Tom, r;)OO - \~) The MITs on NS10 and NS32 are just the normal IA pressure tests. Talib is flying to the slope on 4/10. His schedule is to go to Milne Point on 4/11 (MPB-50), Badami on 4/12 (B1-01) and then to head out to North Star on the morning of 4/13 (NS10 and 32). It should not be an issue to perform the work on NS17 after the other two wells are complete. Let me know if I can assist you further. Thanks, Andrea Hughes SCANNED MAR 2 9 2007 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.statEC__ak.us] Sent: Thursday, March 29, 2007 9:58 AM To: NSU, ADW Well Integrity Engineer Subject: Re: NS17 (PTD #2021690) 4-year MITIA for Regulatory Compliance Andrea, Further to your request. Is there to be considerable work on NS32 for the MITs or is it just the normal IA pressure test? have a possible schedule of the work? Thanks, Tom NS10 and Do you NSU, ADW Well Integrity Engineer wrote, On 3/29/2007 9:42 AM: Jim and Tom, Currently we are performing coil tubing work on several wells at North Star. Not only does this cause congestion on the island, but it also has tied up the pump truck for several days. An MITIA on NS17 is due on 4/4/07 but we are proposing that we piggy back this work with the MITs for NS10 and NS32 the following week. Is it okay to leave NS17 on injection and perform the MITIA on the same day as the MITs on NS10 and NS32 (scheduled for 4/13 with the EPA)? Thank you, *Andrea Hughes* Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 xl154 1 of 1 3/29/2007 10:25 AM . . '87", 'St' ~J UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION 10 1200 Sixth Avenue Seattle, WA 981 01 OCT - 6 2006 Reply To Attn Of: OCE 127 CERTIFIED MAIL - RETURN RECEIPT REQUESTED Craig L. Wiggs Northstar Perfonnance Unit Leader BP Exploration (Alaska) Inc.(BPXA) 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 ~ÐD-t g~ ct"" þ,. ~,~,~~) ,~];'+.lIr.···- .".. .- ... F' ,,'('t"l-' it .(,' 'jl ~1 ',r;, ¿j; 1, c..uv-;; Re: Mechanical Integrity Test, mc Class I Well Northstar NS-I0, Pennit No. AK-1I002-A Dear Mr. Wiggs: The United States Environmental Protection Agency Region 10 (EP A) is in receipt of the annual mechanical integrity test (MIT) results conducted on BPXA's Northstar NS-I0 well. This annular testing perfonned on August 7, 2006, fulfills the requirements under the underground injection control (VIC) pennit number AK-1I002-A. We concur with the test results that the Northstar NS-l 0 well has successfully demonstrated external mechanical integrity based on the Water Flow Log (WFL) and Caliper Log surveys results. If you have any questions or need more infonnation, please call Thor Cutler at (206) 553-1673. Sincerely, M~ A.Bussell, DÎrecror Office of Compliance and Enforcement cc: John Nonnan, AOGCC, Anchorage Sharmon Stambaugh, ADEC, Anchorage Anita Frankel, EP A, Seattle Marcia Combes, EP A, Anchorage bp . . Date: 09-28-2006 Transmittal Number:92831 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor La De th Bottom De th La T e MULTI-FINGER CALIPER LOG 08-02-2006 PDS RESULTS SUMMARY MULTI-FINGER CALIPER LOG 08-04-2006 PDS RESULTS SUMMARY MULTI-FINGER CALIPER 3D 08-04-2006 PDS DATA VIEWER CD-ROM MULTI-FINGER CALIPER 3D NS32 08-04-2006 PDS DATA VIEWER CD-ROM c iL / ~I.(isf;"e ffkh~I<Æ,^ Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center RECE'VED SEP 2 9 2006 i\1aeb 011 & Gas Cons. commission Anchorage Attn: Howard Okland Doug Chromanski Kristin Dirks Ignacio Herrera ~-. .~~ ~~\,~~~~:';- '"l)i!vir\." '" , "",", f! (,,~ ";.;' ,... .:;óó - /1$ d "* 11-{ / /.{ Þ ;]63 -15'15' :¡:t- I '- II ¿'¡'r Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1Desc.: Pipe1 Use: BP Exploration (Alaska), Inc. August 2, 2006 7088 6 4.5" 12.6 lb. L-80 Tubing Well: NS-10 Field: NorthStar State: Alaska API No.: 50-029-22985-00 Top Log Intvl1.: Surface Bot. Log IntvI1.: 8,006 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the bottom of the 4.5" Tubing @ 8,006' (Driller's Depth). This log was run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damages. The 4.5" tubing logged appears to be in good to fair condition, with a recorded maximum wall penetration of 35% in joint 135 (5,764'). The deeper penetrations are recorded in the interval between 5,000' (below the Overshot Assembly) and 8,000'. The damage appears in the forms of isolated pitting and lines of pits. No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the 4.5" tubing logged. This is the sixth time a PDS caliper has been run in this well. A comparison between the current and previous log (May 12, 2005) indicates a change of the tubing in the top -4,980'. A comparison between the current and the previous log recordings below 4,980' indicates an increase in corrosive damage. A comparison plot illustrating the difference in maximum - recorded penetrations between logs in the interval between 4,980' and 8,006', on a joint by joint basis, is included in this report. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting ( 35%) Jt. 135 @ 5,764 Ft. (MD) Isolated Pitting ( 30% ) Jt. 117.3 @ 5,021 Ft. (MD) Line of Pits ( 28%) Jt. 125 @ 5,353 Ft. (MD) Isolated Pitting ( 27%) Jt. 121 @ 5,149 Ft. (MD) Isolated Pitting ( 25%) Jt. 120 @ 5,107 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: "X" Nipple with Protective Sleeve Minimum 1.0. = 2.60" Jt. 47.2 @ 2,043 Ft. (MD) No other significant 1.0. restrictions are recorded throughout the tubing logged. I field Engineer: Wm. McCrossan Witness: 8. Rochin I RECEIVED Analyst: M. Tahtouh SEP 2 9 Z006 UJ: ~ ~ 900 -l"ðd ~ 1'-/ILftp ~ 011 & Gas Cons. Commission Anchorage I I I Well: Field: Company: Country: NS-lO North Star BP Fxploration (Alaska), Inc. USA I Tubing: Norn.OD 4.5 ins Grade & Thread l-80 Weight 12.6 f I Penetration and Metal loss (% wall) I I metal loss body I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.lD 3.958 ins August 2, 2006 MFC 40 No. 99494 2.75 40 M. Tahtouh Nom. Upset 4.5 ins Upper len. 1.2 ins Damage Profile (% wall) penetration body o o metal loss body 50 I 0 to 1 to 10 to 40 to over 47 1% 10% 20% 85%. 85% pene. 0 loss 0 I I Damage Configuration ( body ) 60 I 40 I 20 o I isolated pitting general line ring hnle / poss corrosion corrosion corrosIon ¡ble hole I o I I 95 Bottom of Survey = 189.4 189 Analysis Overview page 2 I I .. 139 lower len. 1.2 ins 100 I I Pipe 1 I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 4.5 in (25.5' - 8004.6') Well: Field: Company: Country: Survey Date: NS-10 North Star BP Exploration (Alaska), Inc. USA August 2, 2006 Approx. Tool Deviation Approx. Borehole Profile 150 25 50 75 ~ 100 Q) -0 E :;, z E 'õ 125 175 189.4 o 50 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 189.4 I I 29 1062 2126 3173 0' 4217 ::E .,..; u.. !:: ...c '5- Q) 0 5313 6339 7368 8005 100 I I I Well: Field: Company: Country: NS-l0 North Star SF Exploration (Alaska), Inc. USA I I Overlay Max. Rec. Pen. (mils) I o 100 200 117 I 124 I 134 I I I I 174 I 184 I I I I I I Maximum Recorded Penetration Comparison To Previous Survey Date: Prevo Date: fool: Tubing: -100 -82 August 2, 2006 May 12, 2005 MFC 40 No. 99494 4.5" 12.6 Ib 1.-80 Difference Diff. in Max. Pen. (mils) -50 () 50 144 .. .. '" '" .J: .J: E E '" '" Z 154 Z ... 'I: '" :2. 15 164 -41 () 41 Approx. Corrosion Rate (mpy) 100 82 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 4.5 in 12.6 ppf [-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS- 10 North Star BP Exploration (Alaska), Inc. USA August 2, 2006 Joint Jt. Depth Pel Pen. Pen ' \1el.'11 Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 .1 26 0 0.01 5 I 3.89 PUP 1 29 0 0.01 4 I 3.90 [t. Deposits. (TCII Connection) 1.1 70 .0 0.01 'j 2 3.90 PUP 1.2 90 0.01 I 3.89 PUP 1.3 99 0.02 I 3.91 PUP 2 103 Q. 0.D1 I 3.90 3 143 0 0.01 I 3.88 4 188 () 0.01 'J 3.89 ~ 5 229 C 0.01 1 3.90 , 6 271 0 0.02 I 3.90 7 312 0 0.02 7 I 3.90 8 354 0 0.01 1 3.89 9 396 0 0.02 I 3.90 10 437 0 0.02 I 3.90 11 479 0 0.01 1 3.89 12 521 0 0.01 I 3.90 w 13 563 0 0.01 4 I 3.90 14 604 0 0.02 7 I 3.89 15 646 0 0.01 ì 3.91 16 689 J) 0.01 I 3.91 17 730 0 0.01 2 3.90 18 772 0 0.02 2 3.91 IIIii 19 813 0 0.01 I 3.90 20 855 0 0.01 3 I 3.90 21 897 .0 0.01 (; , 3.89 I 22 938 0 0.01 'j I 3.91 IT 23 980 Jl 0.ü3 1 3.91 24 1022 Jl 0.01 I 3.92 25 1062 (J 0.01 1 3.92 26 1104 0 0.01 I 3.90 27 1145 0 0.01 I 3.92 28 1187 0.01 4 I 3.91 29 1229 0.01 I 3.92 30 1271 0.01 2 3.92 31 1311 0.01 2 3.91 32 1353 Q 0.01 I 3.92 33 1395 (J 0.01 I 3.91 34 1436 0.01 ! 3.93 ) 35 1477 0.01 I 3.92 w 36 1520 0.02 7 I 3.91 iIIIii 37 1562 i 0.01 7 I 3.91 38 1603 0.01 I 3.92 39 1645 0.02 I 3.92 40 1687 0 0.02 I 3.90 41 1729 0 0.01 , 3.91 I 42 1770 0 0.D2 7 I 3.91 )Ii 43 1813 U 0.01 4 I 3.92 w 44 1855 0.01 5 I 3.92 45 1896 0 0.D1 4 I 3.92 46 1938 () 0.00 1 I 3.91 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I - PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaIID.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: field: Company: Country: Survey Date: N s.. 10 North Star BP Exploration (Alaska), Inc USA August 2, 2006 Joint Jt. Depth F'en. Pen. Pen. I hv\eldl Min. Damage Profile No. (ft.) Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 47 1979 ( 0.01 4 I 3.90 47.1 2021 ( 0.00 J -¡ 3.90 PUP 47.2 2031 U 0 C Ii 2.60 X Nipple with Protective Sleeve 47.3 2032 0.01 .( ¡ 3.91 PUP 48 2042 C 0.01 iJ ¡ 3.91 49 2084 () 0.01 ,; I 3.90 50 2126 u 0.01 4 I 3.90 ~ 51 2168 C om 'j 3.90 52 2210 I 0.D2 I 2 3.91 IiI' 53 2252 ( 0.01 I 3.91 54 2293 ( 0.01 I 3.92 55 2336 0.01 I 3.90 56 2377 u om 4 1 3.90 ! 57 2421 () 0.02 6 2 3.90 58 2463 0 0.02 ] I 3.90 59 2504 j) 0.01 I 3.89 60 2546 () 0.01 I 3.90 61 2588 0 0.01 I 3.89 62 2629 0 0.01 I 3.89 I 63 2672 J 0.01 4 I 3.89 ~ 64 2713 0 0.02 6 I 3.90 !II 65 2755 () 0.02 ß I 3.90 !III 66 2797 () om I 3.89 67 2839 () 0.01 ( I 3.90 68 2880 () 0.01 ¡ 3.90 69 2922 C 0.02 '1 3.90 pi 70 2964 0 0.01 I 3.89 iii! 71 3006 0 0.01 4 ( 3.90 72 3048 D 0.01 ¡ 3.89 73 3089 0 0.01 ! 3.89 74 3131 0 0.01 J I 3.90 75 3173 () 0.01 I 3.90 76 3214 () 0.01 í 3.90 77 3256 () 0.01 í 3.89 78 3298 () 0.01 I 3.89 79 3342 () om I 3.90 80 3384 lÌ 0.01 ¡ 3.89 81 3426 0 0.00 I I 3.88 82 3468 0 0.01 3 I 3.88 83 3510 0 0.01 4 I 3.89 84 3551 0 om I 3.88 85 3592 0 0.01 I 3.89 I 86 3633 () 0.01 I 3.88 87 3674 () 0.01 I 3.88 88 3716 U 0.01 l 3.88 89 3758 0 om I 3.89 90 3800 0 0.01 ¡ 3.89 91 3842 0 0.01 3 I 3.90 92 3883 U om 3 '1 3.89 93 3924 () om 2 I 3.90 Page 2 Body Metal Loss Body I I I I I I I I I I I I I I I I I I I ~ PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 4.5in 12.6ppf 1.-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-l0 North Star BP Exploration (Alaska), Inc. USA August 2, 2006 Joint Jt. Depth Pel Pen. Pen. 11'.ii/-lill Min. Damage Profile No. (Ft.) Body ID. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 94 3966 U 0.00 1 3.89 95 4008 I) 0.01 ! 3.90 96 4050 () 0.01 3.88 97 4092 I) 0.01 i 3.87 98 4134 I) 0.02 ! 3.88 II! 99 4175 () 0.01 ! 3.89 I 100 4217 I) 0.01 .2 i 3.88 I 101 4256 I) 0.01 3 1 3.88 102 4298 ( 0.01 J 1 3.90 103 4340 I) 0.01 1 3.90 104 4382 I) 0.01 ! 3.90 105 4424 I) 0.01 1 3.90 106 4466 I) 0.01 1 3.90 107 4508 I) 0.01 1 3.90 108 4549 ( 0.Q1 .2 ! 3.90 109 4591 I) 0.01 I 3.90 1 110 4633 I) 0.01 I 3.89 . 111 4675 U 0.01 I 3.90 1 112 4717 I) 0.01 ! 3.89 113 4758 I) 0.01 3.89 114 4800 I) 0.01 / 3 3.88 115 4842 I) 0.01 3 I 3.88 116 4884 I) 0.Q1 J 3.88 116.1 4926 I) 0.02 I 3.89 PUP Lt. Deposits. !III 116.2 4935 I) 0 J I) 3.81 X Nionle 116.3 4937 IJ 0.02 I 3.89 PUP . 116.4 4947 IJ 0.02 ) '¡ 3.87 PUP III 116.5 4957 I) 0 I) I) 3.88 PACKER 116.6 4963 I) 0.03 13 I 3.89 PUP Shallow pitting. III 116.7 4969 I) 0 I) I) 3.73 XN Nipple 116.8 4971 I) 0 I) I 4.65 OVERSI-IOT 117 4979 I) 0.04 16 3.88 Shallow nits. 1 st It. of IST-M Connection. 117.1 5001 I) 0.06 3) 3.86 PUP Isolated oitting. 117.2 5010 I) 0 I I 3.88 PACKER 117.3 5015 I) 0.08 IJ ) 3.90 PUP Isolated Ditting. 118 5024 (I 0.05 19 .2 3.89 Shallow pitting. 119 5066 () )(, 0.06 I 3.89 Isolated oittin2. 120 5107 IJ )7 0.07 ! 3.87 Isolated pitti!Jg. 121 5149 (II \7 0.07 .2 3.89 Isolated oittirm. 122 5190 I 0.06 3 3.89 Isolated oittin2. 123 5231 ( 0.06 3 3.88 Isolated Dittim:!. 124 5272 (I 0.05 I 2 3.89 Line of shallow pits. Lt. Deposi ts. 125 5313 () 0.08 3 i 3.88 Line of Dits. 126 5354 () om 12 2 3.87 Line of shallow pits. 127 5395 () 0.04 1 3.90 I ine of shallow nits. 128 5436 IJ 0.04 j 3.89 Line of shallow oits. 129 5477 () 0.06 2 3.88 Line of nits. 130 5517 () 0.05 ! 3.85 Line of shallow pits. 131 5559 () 0.06 .2 .2 3.89 Isolated pitting. 132 56()0 () 0.04 16 .2 3.88 Shallow pitting. Lt. Deposits. Page 3 Body Metal Loss Body I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS- 10 North Star BP Exploration (Alaska), Inc. USA August 2, 2006 Joint Jt. Depth Pen. Pen. Pen. ;\/\e\,11 Min. Damag e Profile No. (Ft.) Body 1.0. Comments (% wall) ) (Ins.) (Ins.) 0 50 100 133 5641 \) 0.04 I 2 3.89 Shallow pitting. Lt Denosi ts. ~ 134 5682 \) 0.05 2( 3.86 Isolated pitting. Lt. Denosits. 135 5724 \) 0.09 l' 3.89 Isolated pitting. Lt DeDosits. 136 5765 0 0.05 1 3.90 Shallow Dittim!. 137 5806 \) 0.05 19 3.88 Shallow pitting. 138 5846 ( 0.06 2 3.90 Line of Dits. 139 5888 0 0.04 16 3 3.88 Line of shallow pits. 140 5929 0 0.06 22 4 3.88 Isolated pitting. Lt. Deposits. 141 5970 \) 0.02 q 2 3.89 142 6011 \) 0.04 16 3.89 Shallow pitting. 143 6053 0 0.04 13 3.89 Shallow pittir1\!. 144 6094 0 0.04 I;> 3.89 Shallow nitting. 145 6135 U 0.04 15 3.87 Shallow nitting. 146 6176 U 0.04 14 3.88 Shallow Ditting. Lt. DeDosits. 147 6217 \) 0.04 I 2 3.89 Shallow Ditting. 148 6258 I 0.05 1 2 3.89 ~w Ditting. 149 6299 ( 0.04 / ;> 3.87 w pitting. Lt Denosi ts. ¡ 150 6339 I 0.04 1 3.89 Shallow pitting. 151 6381 0.05 1 3.89 Shallow Dittino. 152 6422 ( 0.03 'j '¡ 3.90 , ¡ 153 6464 \) 0.03 10 3.90 154 6505 0 0.05 ¡ 3.90 Shallow oitting. 155 6547 I 0.05 'j 4 3.88 Shallow pitting. 156 6588 ( 0.02 ') 2 3.87 Lt. Deposits. 157 6629 ( 0.04 1 I 3.88 Shallow pitting. 158 6670 ( D.04 I') 3.89 Shallow pittim!. 159 6711 ( 0.03 11 3.88 160 6752 0 0.04 I 3.91 Shallow pittifl\:;. 161 6794 0 0.03 11 3.90 162 6835 0 0.03 11 2 3.87 163 6876 0 0.03 1 3.90 Shallow pitting. 164 6916 0 D.03 II 3.91 165 6958 0 0.03 12 3.91 Shallow pittim2. II 166 6997 ( 0.04 15 3.91 Shallow pitting. 167 7037 0 0.03 1 3.91 Shallow Dittim2. 168 7079 0 D.05 I 2 3.91 Shallow Ditting. 169 7120 0 0.06 2 2 3.90 Isolated Ditting. 170 7161 0 0.04 1 2 3.92 Shallow pitting. 171 7202 0 0.04 1 2 3.90 Shallow pitting. 172 7244 0 0.04 H 3.90 Shallow pitting. 173 7285 \) 0.05 1 3.89 Shallow pitting. 174 7327 0 0.06 24 3.91 Isolated pitting. 175 7368 \) 0.03 10 3.90 176 7409 PI 0.ü3 I 3.90 Shallow Ditting. 177 7450 0 0.04 I 1 3.90 Shallow Ditting. 178 7491 0 0.04 1 I) 3.91 Shallow pitting. 179 7532 0 0.06 2 ;> 3.90 Isolated pitting. Lt Denosits. 180 7574 0 0.05 17 ;> 3.90 Shallow pitting. 181 7614 0 0.03 1 ;> /1 3.91 Shallow oittim:;. " 182 7656 0 0.02 7 ;\ 3.90 PI Penetration Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-10 North Star BP Exploration (Alaska), Inc. USA August 2, 2006 Joint JI. Depth 1\'1 Pen. Pen . MC'lal Min. Damage Profile No. (Ft.) Body 1.0. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 183 7697 0 0.06 21 3.90 Line corrosion. 184 7738 J) 0.03 1 3.90 Shallow pitting. 185 7780 J) 0.05 J.! 3.90 Line shallow corrosion. 186 7821 il 0.05 3.89 Shallowpi tti n,g. 187 7862 -º- 0.03 c ..J 3.90 188 7903 () 0.04 1 ~L ..l 3.90 Shallow..Qjttim:!. 189 7944 () 0.02 (I 3.90 189.1 7985 0 0.06 1 3.89 PUP Isolated pitting. ìII1 189.2 7994 0 0 I 3.73 XN Nipple 189.3 7997 () 0.03 3 3.90 PUP Shallow pitting. ~' 189.4 8005 Jl 0 J Nj_A WUG J Body Metal Loss Body Page 5 ------ ------- - - -- .. - PDS Report Cross Sections Well: Field: Company: Country: Tubin : NS-l0 ,1\J0rth Star BP Exploration (Alaska), Inc. USA 4.5 ins 12.6 f L-80 SUNey Date: Tool Type: Tool Size: No. of Fingers: Anal st: August 2, 2006 MFC 40 No. 99494 :U5 40 M. Tahtouh Cross Section for Joint 135 at depth 5763.547 ft Tool speed = 70 Nominal 10 = 3 958 Nominal 00 = 4.500 Remaining wall area = 99 % Tool deviation = 51 0 Finger 24 Penetration = 0.094 ins Isolated Pitting 0.09 ins = 35% Penetration HIGH SIDE = UP Cross Sections page 1 ------ ------ ---- Well: Field: Company: Country: Tubin : NS-1O North Star BP Exploration (Alaska), Inc. USA 4.5 ins 12.6 f L-80 Cross Section for Joint 117.3 at depth 5021.303 ft Tool speed '= 72 Nominal 10 '= 3958 Nominal 00 '= 4.500 Remaining wall area '= 98 % Tool deviation '= 52 0 .. PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: August 2, 2006 MFC 40 No. 99494 2.75 40 M. Tahtouh Finger 24 Penetration '= 0.082 ins Isolated Pitting 0.08 ins '= 30% Penetration HIGH SIDE '= UP Cross Sections page 2 - - I I I TREE = ABB-VGI 5-1/8" 5 ~NOTES: I WB.LHEAD = ABB-VGI11" MJLTIBOWL AClUA TOR = KB. ELEV = 55.77" SF. ELEV = 39.87' (CB 15.9') NS10 KOP= Max Anale = Datum MD = Datum TVD = .. 120" CONDUCTOR, 169#, X-56 199' r ~ ~ 2043' 4-1/2" X NIP, 10 = 3.813" I - PROTECTIVESLV, D=2.6"(01/05l06) I -, 2043' Minimum ID = 2.6" @ 2043' 4-1/2" X NIPPLE wlPROTECTIVE SLY 110-3/4" CSG, 45.5#, L-80 BTC, II) = 9.95"? 3n6' -µ .. . · 4938' 1-i4-1/2" X NIP, 10 = 3.813" I I ~ ~ -f 4960' 7-5/8" X 4-1/2" BKR PREMIER A<R, 10 = 3.875" . · 4972' -f4-1/2"XNNIP,IO=3.725" I · I 14-112" TBG, 12.6#, L-80 TCII, .0152 bpf, 10 = 3.958" 4977' l- I I 4981' HTBG STUB (12/27/05) I - 4986' 4-1/2" UNIQUE OVERSHOT, 10=4.654" I L ~ ~ 5015' H BKR S-3 A<R, 10 - 3.875" I '" I · ).,.7994' 1-i4-1/2" OTIS XN NIP, 10 = 3.725" I I '\. 4-1/2" TBG, 12.6#, L-80 IBT-M, .0152 bpf, 10 = 3.958" 8006' k VI. 800fK... H4-1/2"WLEG, 10= ????" I t"--J .- 17-5/8" CSG, 29.7#, L-80 BTC, ID = 6.S75"? 8029' -~ ~ I ELr,V TT NOT LOGGED? I ) I 16-3/4" OÆN HOLETD H 8246' I-- DATE REV BY COMvBJTS DATE REV BY COMtÆNTS NORTHSTAR 01/11/01 AGK ORIGINAL COMPLETION WELL: NS10 01/03/06 N33E RWO PERMIT No: ~001820 01/05/06 JGBffiH PROTECTIVE NIPFtE SL V SET AA No: 50-029-22985-00 01/21/06 ???ffiH DRLG DRAFT CORRECTIONS BP Exploration (Alaska) I I I I I I I I I I I I I e e Date: 05-10-2006 Transmittal Number:92787 :;)CD - 115;). BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor LOQ Run Top Depth Bottom Depth Log Type NS05 05-28-2005 SCH 1 13260 13835 PERFORATING RECORD NS05 04-12-2005 SCH 1 13330 13985 PERFORATING RECORD NS05 06-28-2005 SCH 1 13220 13713 PERFORATING RECORD NS05 03-26-2005 SCH 1 11 530 13310 USIT CEMENT LOG NS10 X) 05-25-2005 SCH 1 4750 7960 RST WATER FLOW NS10 )0 05-09-2005 SCH 1 4800 8004 RST W A TERFLOW Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Doug Chromanski Tim Ryherd Ignacio Herrera Howard Okland Cheryl Ploegstra £CAJ\IÁIc:r) Ii P,j .,:, '"'I'nlc-.L, iO: ~c;,;,;;...;> ..J V1 \i J. ':'J.: _U ;,...:J Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us; T om_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC / EPA REP: BP Exploration (Alaska) Inc. Prudhoe Bay / Northstar / Northstar 04/17/06 Anna Dube o/\tõ:J- ð.P Packer Depth Pretest Initial 15 Min. 30 Min. WelllNS10 I Type Inj. I D TVD I 4,023' Tubing 1500 1300 1250 1200 IntervalJ 0 P.T.D.12001820 I Type test I P Test psil 1,500 Casing 0 3500 3495 3520 P/FI P Notes: Annual EPA witnessed MIT-IA to 3500 psi OA 0 0 0 0 Weill NS32 I Tvee Inj. I I TVD I 4,014' Tubing 1900 1900 1900 1900 Interval I 0 P.T.D.12031580 I Type test I P Test psil 1,500 Casing 0 3450 3350 3305 P/FI P Notes: Annual EPA witnessed MIT-IA to 3500 psi OA 0 0 0 0 Weill I Type Ini.1 TVD I Tubing I nterval P.T.D.I I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Ini.1 TVD I Tubing Interval I p.T.D.1 I Type test I Test psi I CasinQ P/F Notes: OA Weill I Type Inj.1 TVD I Tubing I ntervall p.T.D.1 I Type test I Test psil Casing P/FI Notes: OA /' TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4= Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) Gj.! cd 2006-0417 _MIT _Northstar_NS-1 O.xls . . Date: 03-15-2006 Transmittal Number:92763 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the POC at 564-4091 .. ;ÆÐO' 16 ì--. SW Name Date Contractor Loq Run Top Depth Bottom Depth Log Type VISION SERVICE LWD MD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE VISION SERVICE LWD TVD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE NS14 01-07-2006 SCH 1 9900 10300 BRIDGE PLUG SET RECORD NS24 03-26-2005 SCH 1 12150 12478 MEM PSP PPROF NS10 12-26-2005 SCH 1 4800 8025 CHEMICAL CUTTER RECORD NS14 12-22-2005 SCH 1 11500 11867 CHEMICAL CUTTER RECORC NS08 10-26-2005 SCH 1 111 30 11915 CHEMICAL CUTTER RECORD NS19 09-26-2005 SCH 1 13700 13990 PERFORATION RECORD NS27 06-06-2005 SCH 1 10950 11300 PERFORATION RECORD NS31 06-05-2005 SCH 1 10950 11320 PERFORATION RECORD NS24 09-22-2005 SCH 1 11 800 12470 PERFORATION RECORD NS25 10-03-2005 SCH 1 18750 19200 PERFORATION RECORD NS21 07 -31-2005 SCH 1 22050 22225 PERFORATION RECORD NS08 12-16-2005 SCH 1 9500 11244 PERFORATION RECORD NS05 09-19-2005 SCH 1 13210 14002 PERFORATION RECORD NS06 09-17 -2005 SCH 1 13040 13825 PERFORATION RECORD NS18 12-08-2005 SCH 1 16200 16834 PERFORATION RECORD NS17 07 -29-2005 SCH 1 17850 18200 PERFORATION RECORD Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ÍÀD~-IPÀ r:-:(~ BPXA WELL DATA TRANSMITTAL I I I I I I I :iJ (JILl . Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Doug Chromanski Ignaci 0 Herrera Petrotechnical Data Center LR2-] 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . Date: 03-15-2006 Transmittal Number:92763 STATE OF ALASKA RECE\VED ALASK.eIL AND GAS CONSERVATION C&ISSION FEB 212006 REPORT OF SUNDRY WELL OPERATIONS C Commtssion Alaska Oil & Gas ons. a e 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program ---------_._------ o Suspend !HI Repair Well !HI Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Other o Re-Enter Suspended Well o Time Extension 2. Operator Name: 4. Current Well Class: BP Exploration (Alaska) Inc. o Development 0 Exploratory 200-182 3. Address: o Stratigraphic !HI Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22985-00-00 7. KB Elevation (ft): 55.77 9. Well Name and Number: NS10 8. Property Designation: 10. Field / Pool(s): ADL 312808 Northstar Unit 11. Present well condition summary Total depth: measured 8246 feet true vertical 6513 feet Plugs (measured) None Effective depth; measured 8246 feet Junk (measured) None true vertical 6513 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 199' 20" 199' 199' 4260 2590 Surface 3681' 10-3/4" 3726' 3192' 5210 2480 Intermediate Production 7986' 7-5/8" 8029' 6325' 6890 4790 Liner L (:':1 Perforation Depth MD (ft): Perforation Depth TVD (ft): 8029' - 8246' (open hole) 6325' - 6513' (open hole) Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# L-80 8007' Baker Premier Packer Baker S-3 Packer 4960' 5015' 12. Stimulation or cement squeeze summary; Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFt 2 1 2006 Oil-Bbl Re resentative Dail Gas-Mcf Water-Bbl Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run !HI Daily Report of Well Operations !HI Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 0 Development !HI Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 0 GINJ 0 WINJ !HI WDSPL correct to the best 0 my now edge. 17. Printed Name Sondra Stewman Title Technical Assistant Phone l:) ttM . ti 7SD Date 07...·1"-1- Prepared By Name/Number: Sondra Stewman, 564-4750 Submit Original Only e BP EXPLORATION Operations Summary Report Legal Well Name: NS10 Common Well Name: NS10 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 33E I : I From - To i Hours Task Code NPT·· Phase Date 12/25/2005 12:00 - 13:00 1.00 RIGD P 13:00 - 14:00 1.00 RIGD P 14:00 - 16:00 2.00 RIGD P 16:00 - 17:00 1.00 RIGD N 17:00 - 18:00 1.00 RIGD P 18:00 - 19:00 1.00 RIGU P 19:00 - 22:00 3.00 RIGU P 22:00 - 00:00 2.00 RIGU P 00:00 - 03:30 3.50 MOB P 03:30 - 04:30 1.00 MOB P 04:30 - 05:00 0.50 MOB P 05:00 - 07:00 2.00 KILL P 07:00 - 08:00 1.00 KILL P 08:00 - 09:00 1.00 CLEAN P 09:00 - 10:30 1.50 CLEAN P 10:30 - 13:30 3.00 CLEAN P 13:30 - 15:00 1.50 KILL P 15:00 - 18:00 3.00 KILL N 18:00 - 21 :30 3.50 KILL P 12/26/2005 21 :30 - 22:30 1.00 KILL P 22:30 - 00:00 1.50 KILL P 12/27/2005 00:00 - 02:00 2.00 PERF P 02:00 - 03:00 1.00 PERF P 03:00 - 07:00 4.00 KILL P PRE PRE PRE SFAL PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WAIT DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 07:00 - 08:00 1.00 BOPSUF P DECOMP 08:00 - 09:30 1.50 BOPSUF P DECOMP 09:30 - 12:00 2.50 BOPSUF P DECOMP 12:00 - 14:00 2.00 BOPSUF P DECOMP 14:00 - 18:00 4.00 BOPSUF P DECOMP 18:00 - 22:00 4.00 BOPSUF P DECOMP Page 1 of 4 Start: Rig Release: Rig Number: Spud Date: 12/14/2000 End: 12/26/2005 1/3/2006 Description of Operations ________..__._._.._...__..... _0. n....._ . "_"."_ ..._ _. ._.'0__ _.~__.... Disconnect lines in cellar. Clear cellar area for move. Safety meeting. (ATP--Rig move off of NS08) Moved rig 8' south to remove wellhead house on NS11 slot (north end). Grove crane experienced electrical problems and shut down. Wait on repairs to complete wellhead house removal. Completed wellhead house removal and spotted tree stand in cellar next to NS 10. Lay herculite and rig mats for move. Move rig north 28'. PJSM and reviewed procedure to shim stomper beam. Spot rig over NS10. Set berms around rig. Close in cellar area. Install stairs. Install weather seals. Rig accepted at 00:00 hrs. 12/26/2005. Rig up lines from squeeze manifold for bull heading. Pump open actuator on upper master. Take on 9.3 ppg brine into pits for bullheading. Thaw line frozen in pipe rack. Safety meetings for workover overview (pre-spud) and bull heading operations. Pr. tst. lines to 2000 spi, OK. Bullhead 137 bbls 9.3 ppg brine down tubing at 2 BPM and 700 psi with 250 psi on annulus. Annulus pr. dropped to nearly 0 psi by end of pumping. Bled back 9.5 bbls from tubing. Well stable with 0 psi on tubing and annulus. Rig up SWS slick line equipment. RIH and pull nipple protector from X nipple at 2033'. POOH. RIH w/ 3.7" tbg drift on slick line to 8000'. POOH. RD slick line. Bled annulus from 200 psi to 0 psi. Bled-back vol. TSTM. PU SWS E-Line tool to floor. Wait on SWS to prepare and warm logging unit and tools. PJSM. RIH with tbg punch and GR/CCL. Log from 8035' (pickup) to 4800'. Punch 9 holes from 4960'-4962'. POOH and LD same. Fired OK. RIH w/ string shot and shoot from 4970'-4982'. POOH and LD same. Fired OK. PJSM. PU chem. cutter and RIH. Chemically cut tubing @ 4980'. Rig down wireline equipment Disp freeze protection & circulate well bore w/ 9.3# brine Disp freeze protection -Tbg @ 1 BPM - 40psi - IA - 0 psi Circulate well bore - Tbg @ 6 BPM - 530 psi w/ 20 psi on annulus Csg - 0 psi, monitor well for 10 min, well bore static Install TWC & test to 500 psi F/ below, Bleed to 0 psi Blow down all mud lines PJSM, secure well, ND tree NU Adaptor flange & BOPs NU BOPs, connect accumulator hoses Change top P/R to 4.5" X 7.0" variables Middle T blind/shear Bottom 4.5" x 7.0 " variables Connect choke & kill lines Install riser & turn buckles Printed: 1/3/2006 11: 13:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date -.----.----------- 12/27/2005 12/28/2005 e BP EXPLORATION Operations Summary Report NS10 NS10 WORKOVER NABORS ALASKA DRILLING I NABORS 33E From - To I ~~u~~_:__Task i Code I NPT 18:00 - 22:00 4.00 BOPSU P 22:00 - 23:00 1.00 BOPSU P 23:00 - 00:00 1.00 BOPSU P 00:00 - 02:30 Start: Rig Release: Rig Number: I Ph_~~e I DECOMP DECOMP DECOMP DPRB DECOMP 02:30 - 04:00 1.50 BOPSU DPRB DECOMP 04:00 - 05:00 1.00 BOPSU DPRB DECOMP 05:00 - 05:30 0.50 BOPSU DPRB DECOMP 05:30 - 06:30 1.00 BOPSU DPRB DECOMP 06:30 - 07:30 1.00 BOPSU DPRB DECOMP 07:30 - 10:30 10:30 - 12:00 12:00 - 13:30 13:30 - 20:30 3.00 BOPSU N 1.50 BOPSU P 1.50 BOPSU P 7.00 BOPSU P DPRB DECOMP DECOMP DECOMP DECOMP 20:30 - 22:30 SFAL DECOMP 22:30 - 23:00 0.50 BOPSU DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 12/29/2005 00:00 - 02:00 2.00 PULL P DECOMP 02:00 - 02:30 0.50 PULL P DECOMP 02:30 - 04:00 1.50 PULL P DECOMP 04:00 - 04:30 04:30 - 05:30 05:30 - 19:00 19:00 - 20:30 0.50 PULL P 1.00 PULL P 13.50 PULL P 1 .50 PULL P Page 2 of 4 12/26/2005 1 /3/2006 Spud Date: 12/14/2000 End: Description of Operations ______P".A.__._.. .......... ._n'___ Function test BOPs Make up test joint, x-o's, safety valves Make up test joint into tbg hanger, total make up 17 turns, test joint became tight Back out test joint 3 turns, test joint became tight Attempt to make up test joint, can't turn with chain tongs Test joint would not make up properly Lift BOP stack, inspect test joint & tbg hanger (connection not made up properly) Check to see if penetrator for heat trace was an obstruction NU BOPs, install upper riser assembly RU tongs to back test joint out of hanger Back out test joint, LD test joint & X-Os Top .75" of threads was gaulded on X-O Production operations shut in NS 09 before stack lift ND BOPs to inspect tbg hanger profile Move stack to inspect tbg hanger, threads looked OK Dry run landing joint, threads made up to shoulder with no problems Move BOPs over wellhead & nipple up BOPs Make up test joint & rig up to test BOPs Fill stack, repair air boot Test BOPs, choke manifold & floor safety valves Leak On Choke Line Uni-Bolt And Upper IBOP failed to test All BOPs, choke manifold valves & safety valves tested to 250 psi low & 3000 psi BOP test witnessed by WSLs - Darrell Green & Richard Watkins, Tool Pusher - Robert Kennedy AOGCC Inspector John Crisp Waived The Right To Witness The BOP Test During The BOP Test The Choke Line Uni-Bolt Had To Be Retightened And Retested Twice - The Top Drive Upper IBOP Valve Failed The High Pressure Test LD test joint and rig down test equipment Rig up bales, elevators & equipment to LD 4.5" tubing Pull TWC & MU landing joint RU equipment to LD 4.5" tbg, make up landing joint w/ X-Os and TIW safety valve Blow down all mud lines Pull tbg hanger from wellhead, Hanger came free w/145K - 20K over string weight Pump 12 bbls brine to fill hole & establish circulation Circulate 2x Btms Up - thru choke @ 5.5 BPM, Slow rate to 5 BPM Losing brine at rate of 5 to 6 bbls. per hour DECOMP RD circulating lines & blow down mud lines DECOMP RU equipment to LD 4.5" tbg & spool heat trace line DECOMP LD 4.5" tubing - 118 jts - 1 cut off section at 16.69' - Clear rig floor of heat trace and bands *Note* Cut joint - clean uniform cut, no tearing or swelling I DECOMP RD equipment to LD 4.5" tbg & heat trace spooling equipment I Printed: 1/3/2006 11:13:38 AM e BP EXPLORATION Operations Summary Report Run #2 - RIH & pull equailzer prong @ 4942' Run #3 - RIH & pull plug from X-nipple @ 4942' Run #4 - RIH w/3.61" drift, set down @ 4976', top of cut tubing stub Run #4 - RIH w/3.20" drift, set down @ 4976' Run #5 - RIH w/brush & wire grabber, set down @ 4983' POOH, recovered 6' flat electric line guard & 3 bands Run #6 - RIH w/brush & wire grabber to 8030', tubing clear of obstructions WAIT RUNCMP Wait on new wireline crew, crew had worked 16 continous hours Legal Well Name: NS10 Common Well Name: NS10 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 33E Date J.~r~m - To . Hour~J__~.~~k Code NPT: Phase 12/29/2005 20:30 - 00:00 3.50 PULL P DECOMP 12/30/2005 00:00 - 04:00 4.00 PULL P DECOMP 04:00 - 04:30 0.50 PULL DECOMP 04:30 - 05:30 1.00 BOPSU RREP DECOMP 05:30 - 06:00 0.50 BOPSU RREP DECOMP 06:00 - 17:00 11.00 BOPSU RREP DECOMP 17:00 - 18:00 1.00 BOPSU RREP DECOMP 18:00 - 00:00 6.00 BOPSU RREP DECOMP 12/31/2005 00:00 - 02:30 2.50 BOPSU RREP DECOMP 02:30 - 08:00 5.50 BOPSU RREP DECOMP 08:00 - 08:30 0.50 RUNCMP 08:30 - 10:00 1.50 RUNCMP 10:00 - 19:30 9.50 RUNCMP 19:30 - 22:00 2.50 RUNCMP 22:00 - 00:00 RUNCMP 1/1/2006 00:00 - 01 :00 RUNCMP 01 :00 - 01 :30 RUNCMP 01 :30 - 03:30 RUNCMP 03:30 - 05:00 RUNCMP 05:00 - 06:00 RUNCMP 06:00 - 09:00 RUNCMP 09:00 - 12:00 RUNCMP 12:00 - 16:00 RUNCMP 16:00 - 18:00 Page 3 of 4 Start: Rig Release: Rig Number: Spud Date: 12/14/2000 End: 12/26/2005 1/3/2006 Description of Operations PJSM, RU slick line equipment RIH w/ 6.650" gauge ring & junk basket Run #1- Tag @ 4972' SLM, POOH recovered 3 bands Run #2 - started in hole Run 6.650 gauge ring & junk basket Run #2 - Tag @ 4975', 2 bands recovered Run #3 - Tag @ 4978', 1 band recovered Run #4 - Tag @ 4978', 1 band & 1 rubber o-ring recovered Run #5 - Tag @ 4978', 1 band recovered Run #6 - Tag @ 4978', No recovery Make 6 runs, recovered 8 bands RD slickline equipment RU test equipment to test upper IBOP Test upper IBOP TEST FAILED Rig down top drive to change upper IBOP Install upper IBOP Rig up top drive Test upper IBOP TEST FAILED Rig down top drive Remove IBOP & rebuild Rebuild IBOP, install valve & top drive equipment Test IBOP, Test Failed (leaking around valve stem) Change out upper IBOP valve, assemble top drive assembly Test IBOP to 250psi & 3000 psi, Test was successful Blow down all lines, clear rig floor of equipment Install bales & elevators RU equipment to run 4.5" tubing, RU compensator PU 4.5",12.6#, TCII completion assembly Torque turn all connections TCII connection make-up witnessed by Grant Prideco Rep. Space out 4.5" completion, PU - 110K, SO - 110K Land & lock down tubing hanger RU lines to reverse circulate Reverse circulate 20 bbls, 150 psi @ 2.5 BPM, No issues Pressure test tubing hanger to 5000#, (test OK), blow down tset lines Rig down tools and equipment to run 4.5" tubing RU Schlumberger slick line equipment Run #1 - RIH and set plug in "X" Nipple @4942' SLM Test 4.5",12.6#, L-80, TCII tubing to 4200 psi, held test 15 min, test OK Printed: 1/3/2006 11 :13:38 AM e BP EXPLORATION Operations Summary Report Legal Well Name: NS10 Common Well Name: NS10 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 33E I I I e-- Date I From - To ~~~r~J _~:_~~ Code I NPT: Phase 1/1/2006 18:00 - 22:00 4.00 RUNCOI P RUNCMP 22:00 - 23:00 1.00 RUNcorp RUNCMP 23:00 - 00:00 1.00 RUNCor P RUNCMP 1/2/2006 00:00 - 03:30 3.50 BOPSUF P RUNCMP 03:30 - 08:00 4.50 BOPSUF P RUNCMP 08:00 - 09:00 1.00 WHSUR P RUNCMP 09:00 - 10:00 1.00 WHSUR P RUNCMP 10:00 - 12:00 2.00 WHSUR P RUNCMP 12:00 - 15:30 3.50 WHSUR P RUNCMP 15:30 - 16:00 0.50 WHSUR P RUNCMP 16:00 - 18:30 2.50 WHSUR P RUNCMP 18:30 - 20:00 1.50 WHSUR P RUNCMP 120:00 - 23:00 3.00 WHSUR P RUNCMP 23:00 - 00:00 1.00 WHSUR P RUNCMP 1/3/2006 00:00 - 02:00 02:00 - 03:00 2.00 WHSUR P 1.00 WHSUR P RUNCMP RUNCMP I I Page 4 of 4 Start: Rig Release: Rig Number: Spud Date: 12/14/2000 End: 12/26/2005 1 /3/2006 Description of Operations ----- ...........-.-- .-.-....-.-- Run #7 - RIH w/3.61 centralizer & memory log, Log from 5500' to 4500' POOH & read logs, Logs show tubing to be spaced out correctly Run #8 - RIH w/RHC-M Plug & set in "XN" nipple @ 4976' SLM RD wireline equipment Pull & lay down landing joint Set BPV & test from below to 300#, Hole taking fluid while testing BPV ND BOPs ND Riser, BOPE & secure in cradle NU 11" 5K tubing bonnet & 51/8 vetco tree Pull BPV, Fill tbg & tree w/10 bbls brine Install TWC RU test equipment Test tubing bonnet & tree to 5K psi RU equipment to reverse circulate well bore PJSM, pull TWC RU lines to reverse circulate Test lines, repair leaks Reverse circulate 40 bbls inhibited brine @ 3 bpm 190 psi Hot oil unit pumped 142 bbls of heated, inhibited diesel down annulus @ 3 bpm 700 psi U tube diesel in well bore RU lubricator, drop ball & rod Pressure test tubing, Set packer, starting pressure 5100, final pressure 4800 psi after 30 min Pressure anulus, starting pressure 3650 psi, 15 min pressure 3550 psi, 30 min final pressure 3500 psi "OA" pressure was 0 psi during all test MIT test witnessed by EPA Inspector Talib Syed & Co Reps. Darrell Green & Richard Watkins Bleed 1A to 0 psi, Bleed tubing to 350 psi Blow down lines, rig down test equipment RU Lubricator, Set BPV, RD Lubricator Secure NS-10, Install valve handles Release rig from well work on NS-10 at 03:00 hours on 1-3-06 Printed: 1/3/2006 11:13:38AM ABB-VGI 5-1/8" 5 ABB-VGI11" MUL TIBOWL 5 55.77" 39.87' (CB 15.9') NS10 120" CONDUCTOR, 169#, X-56 I Minimum ID = 2.6" @ 2043' 4-1/2" X NIPPLE w/PROTECTIVE SLV 110-314" CSG, 45.5#, L-80 BTC, ID '" n.DS"? I 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 14-1/2" TBG, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 7-5/8" CSG, 29.7#, L-80 BTC, ID - 6,875"? 16-3/4" OPEN HOLE TD H 8246' ~ DATE 01/11/01 01/03/06 01/05/06 01/21/06 COMMENTS ORIGINAL COMPLETION RNO PROTECTIV E NIPPLE SL V SET DRLG DRAFT CORRECTIONS REV BY REV BY AGK N33E JGB/TLH ???/TLH DATE ~NOTE5: ~ 2043' 2043' -14-1/2" X NIP, ID = 3.813"1 l-i PROTECTIVE SLV, 10 = 2.6" (01/05/06) 4938' 1-14-1/2" X NIP, ID = 3.813"1 -17-5/8" X 4-1/2" BKR PREMIER PKR, 10 = 3.875" -14-1/2" XN NIP, ID = 3.725" I -lTBG STUB (12/27/05) I -l4-1/2" UNIQUE OVERSHOT, ID = 4.654" - BKR S-3 PKR, ID = 3.875" I 7994' -l4-1/2" OTIS XN NIP, 10 = 3.725" 1 8006' H4-1/2" WLEG, ID = 'i..n^!" I H ELMD IT NOT LOGGED? I COMMENTS NORTHSTAR WELL: NS10 PERMfT No: "'2001820 API No: 50-029-22985-00 BP Exploration (Alaska) MEMORANDUM 'K~1' Jim Regg 2~l7lo(., P.I. Supervisor e State of Alaska e Alaska Oil and Gas Conservation Commission FROM: Jeff Jones Petroleum Inspector DATE: Thursday, February 16,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA)!NC NS-IO NORTHSTAR UNIT NS-IO O· ~ \C6~ ~O TO: Src: Inspector Reviewed By: P.I. Suprv, í&"'-<--- Comm Well Name: NORTHSTAR UNIT NS-I0 API Well Number 50-029-22985-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060210183821 Permit Number: 200-182-0 Inspection Date: 2/11/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~-, I - I I I Well I NS-10 !Type Inj. i I TVD 4023 IA I 100 3000 I 2850 I 2830 2830 I - , I 2001820 iTypeTest I SPT I I I I P.T. Test psi 1005.75 OA 0 0 0 0 0 ._-~--,- ! I 1----------- Interval !NIT AL P/F P Tubing! 1340 1242 1222 I 1249 1286 ¡ -.. I Notes Post workover initial MITlA 1.4 BBLS diesel pumped. 1 well house inspected; no exceptions noted. NON-CONFIDENTIAL \' Thursday, February 16,2006 Page 1 of 1 ~ ~ ,1.'\ 1ì r;:::¡ i(U, ""\H .''\:~, 1.1",/8,\ 'i¡ I Þ Qd;uuuuLb e (ñ"ì¡'n', ' rr ¡ , ~ ' ., ',' ! 'I ," I' ~,::;:j, I, ,i II '0:!J u e [À\ f LJ ì ln,',' ,,'I !.JU FRANK H. MURKOWSKI, GOVERNOR A."~A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~,,'~""".,¡n, ,.' .,' - ., ," ., '" Re: Northstar NS-10 305-375 .~t~~~t~,¡;;;[, PF C 1 () 2DD5 ~4"tC "'.(te;,¡,.· J ¿~ ~ Dear Mr. Archey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Su perior Court unless rehearing has been requested. DATED thisMay of December, 2005 Encl. q1); I 1,0-5 R~ê' 2./ t¡/WOS e STATE OF ALASKA D¡ I? J?1..0 EIVED ALASKA OIL AND GAS CONSERVATION COMMISsT6N - DEC 0 8 2005 APPLICATION FOR SUNDRY APPRO\CrAlla.Oí/ & G~~ Cons. COmfrllsaiof1 20 AAC 25.280 ¡lbtth\11'agEf' 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program o Suspend I 0 Operation Shutdown II Repair Well 0 Plug Perforations II Pull Tubing 0 Perforate New Pool o Perforate 0 Other o Stimulate 0 Re-Enter Suspended Well o Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. A dress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: D Development D ~xploratory D Stratigraphic ŒrService v:J4A- 9. Well Name and Number: 5. Permit To Drill Number 200-182 /' 6. API Number: 50- 029-22985-00-00 ./ 55.77 NS-10 /' 8. Property Designation: 10. Field / Pool(s): ADL 312808 Northstar Unit 11. Total Depth MD (ft): 8246 PREsEmWELLCONDITIONiSUMMAR¥ Effective Depth MJ(ft): Effective Depth TVD (ft): 8246 6513 Size MD TVD Plugs (measured): None Burst Junk (measured): None Colla se 199' 3681' 20" 10-3/4" 199' 3726' 199' 3192' 4260 5210 2590 2480 7986' 7-5/8" 8029' 6325' 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): 8029' - 8246' 6325' - 6513' Packers and SSSV Type: Baker S-3 Packer Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 5015' Tubing MD (ft): 8007' 12. Attachments: Œa Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: ./ D Exploratory D Development Œa Service 16. Verbal Approval: Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Prepared By Name/Number: (J.,..ct., Phone 5(, ø 03 Date ''-/tJ7 f:) S" Sondra Stewman, 564-4750 Commission Use Onl 12/16/05 Date: / 15. Well Status after proposed work: DOil DGas DWAG DGINJ D Plugged DWINJ /.:: D Abandoned Œa WDSPL Contact Dave Johnson, 564-4171 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity I!f BOP Test ~echanicallntegrity Test D Location Clearance Other: ,,^ 1 T .,-e 0 ....;; T~t toPE to ~ooo pe-.i, R8DMS BFl DEC 1 3 2005 COMMISSIONER APPROVED BY THE COMMISSION Date ORIGINAL e e A " bp BP Exploration Alaska Inc. To: Winton Aubert Date: December 6, 2005 Alaska Oil & Gas Conservation Commission From: David Johnson Northstar ODE Subject: NS10 Sundry Notice Dear Mr. Aubert, The NS10 is one of two EPA Class I disposal weill-at Northstar. These wells handle all of the produced water, sewage plant effluent, drill cuttings and other liquid wastes generated on the island. During normal operations (i.e. no Drilling), only one of these wells is required. However, during drilling operations, both wells are needed. One well is needed for drill cuttings and one for produced and waste water. These streams cannot be combined due to the risk of cutting settlement. / On November 19,2005 several bleeds were required to keep the NS10 IA pressure below EPA permit limit of 500 psi. This behaviour continued and on November 22 the EPA was notified of BP's concerns and plans to diagnose this problem. Starting on November 22, more frequent bleeding became necessary. The decision was made to shut-in NS10 and put NS32 on line on November 24. On November 27 an MIT to 3000 psi was conducted. The first MIT attempt failed and the second attempt barely passed. / In spite of the fact the MIT passed, the well's behaviour indicates there is a tubing leak. A previous caliper run(had shown pitting in the upper portion of the string and it was planned to replace the tubing string above the packer at the conclusion of the 2005 and 2006 drilling program. With the development of a leak, this rig work-over must now be accelerated to facilitate the 2005 - 2006 drilling program. Maximum anticipated surface pressure (full column of gas from TD to surface) is 2199 psi. We will be utilizing Nabors 33e 5000 psi four preventer stack (3 rams and an /' annular) and plan to test them to 3000 psi. ~yy~. The tubing replaeefficflt on N810 doeB not officially r{)quiro 8 Sundry Notioo to be. -¥r -6ubffiiUcd priol to.eommoneing thc ri~ epcmtiona. Due to the fact that NS10is a class 1 \fJ4A:- e e disposal well, we elected to submit the Sundry prior to commencing operations. The NS 10 workover will commence approximately December 16th following the recompletion of NS08. Please find attached the NS10 Sundry information and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-4171. e e bp Northstar NS10 Sundry Notice Replace Tubing Above Packer Scope After observing possible communication between the tubing and inner annulus on NS10, an MIT to 3000 psi was conducted was conducted on November 27th. The first MIT attempt failed and the second attempt barely passed. In spite of the fact the MIT passed, the well's behavior indicates there is a tubing leak. A previous caliper runs had shown pitting in the upper portion of the string and it was planned to replace the tubing string above the packer at the conclusion of the 2005 and 2006 drilling program. With the development of a leak, this rig work-over must now be accelerated to facilitate the 2005 - 2006 drilling program. Ria Operations 1 . Test 7-5/8" pack-off to 5000 psi. 2. Bullhead 9.3 ppg brine down tubing. 3. Run wireline and drift tubing. 4. RIH with tubing punch and shoot holes in the 1 st full joint above the packer. ,/ 5. Chemically cut tubing at +1- 4990' TMD above packer at 5015'. ./ 6. Circulate well clean with 9.3 ppg brine. 7. Install BPV. 8. NU BOPE and test to 3000 psi. / 9. Pull 4-1/2" tubing string 10. Run gauge ring to top of tubing stub. 11. Run and land the 4-1/2" 12.6# 13-L80 TCII tubing string with 7-5/8" X 4-1/2" permanent packer and overshot guide as per completion diagram. 12. Work guide over tubing stub. Pick up 3'. Space out and land tubing. 13. Set the TWC valve in tubing hanger. Nipple down BOPs. Install and test the /' 5000 psi tree. Install all flanges and needle valves. 14. Freeze protect the tubing and annulus to 3000' TMD/TVD. 15. Set 7-5/8" X 4 %" packer. MIT packer and annulus to 3500 psi / 16. Ensure all tree and annulus valves are secured. RD and move off well. Page 1 e e bp Northstar NS10 Sundry Notice Replace Tubing Above Packer General Information Type of Well (producer or injector): Class I Disposal Well N orthstar Slot: NS10 Surface Location: 1139' FSL 643' FEL Sll T13N R13E Umiat Top of Interval: 2845' NSL, 2223' FEL, Sec. 14, T13N, R13E, UM Bottom Hole Location: 2952' SNL, 2263' FEL, Sec. 14, T13N, R13E, UM I AFE Number: I NSD832074 I Rig: I Nabors 33E / I Estimated Start Date: 112/15/2005 1 Operating days to complete: 16 I MD: 18246' II TVDrkb: 16513' I RKB/Surface Elevation: (a.m.s.l.) 155.7'/15.9' I Well Design (conventional, slimhole, etc.): I Slim Hole I I I Ob,jective: I Schrader Bluff Well Name: API Number: BHP: EMW: BHT: 6,500' TVDss Page 2 e e bp Northstar NS10 Sundry Notice Replace Tubing Above Packer o Present Casin2lTubine Hole Casing WtlFt Grade Conn Burst Collapse Top Top Btm BTM Length Size Size TMD TVD TMD TVD 42 20 169 X-56 Weld 0 0 199 199 199 13.5 1 0-3/4 45.5 L-80 BTC 5210 2480 0 0 3726 3192 3726 9.875 7-5/8 29.7 L-80 IBT-M 6890 4790 0 0 8029 6325 8029 TBG 4-1/2 12.6 L-80 IBT-M 8430 7500 0 0 8006 6304 8006 6.75" Open Hole 8029 6325 8246 6513 217 Proposed Tubine: / Hole Casing WtlFt Grade Conn Burst Collapse Top Top Btm BTM Length Size Size TMD TVD TMD TVD TBG 4-1/2 12.6 L-80 TCII 8430 7500 0 0 4997 4010 4997 TBG 4-1/2 12.6 L-80 IBT-M 8430 7500 4990 4000 8006 6304 3016 MUD PROGRAM SUMMARY: The well will be worked over with a 9.3 ppg brine completion fluid. / BOP Test Equipment will be installed that is capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) ~ 5000 psi working pressure pipe rams (2) ~ Blind rams ~ Annular pre venter Based upon the calculations below, BOP equipment will be tested to 3000 psi:/' Page 3 bp e e Northstar NS10 Sundry Notice Replace Tubing Above Packer Maximum Surface Pressure - Full Column of Gas from TD - 0 ~ Gradients - si/ft TVDss Formation Gas Ivishak Production Interval 6297 9.1 0.12 Planned BOP test ressure: 3000 Planned com letion fluid: 9.3 Northstar Nabors Rig 33E Rig Floor Hydril Type 'GK' 28.97' I Double Oate Pipe Ram 32.40' 1- Double Studded Blind Ram 34.27' ~ HCR MAN Mud Cross SiopO'" Pipe Ram 38.03' 4. Doub1eStuclded 39.33 ' Spacer 40.30' Ground Level Spool Tubing MAN MAN Spool Casing 41. 20' Spool 41.26' Page 4 MATERIALS: bp L-80 Completion: e e Northstar NS10 Sundry Notice Replace Tubing Above Packer 5000' 1 1 1 1 4-1/2", 12.6# L-80 TCII 4-1/2" 9CR X-nipple 4-1/2" 7.625 X 4.5 Premier Packer- 9CR 4-1/2" 9 CR XN nipple 4-1/2" UM Overshot Guide Page 5 20", 169# X-56 @ 199' MD - PRESENT COMPLETION PROPOSED COMPLETION bp Date: 07-20-2005 Transmittal Number: #91588NS 10,08,32 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojoh=hsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type rNS19 05-16-2005 POS 1 13700 14080 PRESSURE BUILDUP; I).. - 1 07 NS19 05-16-2005 PDS t.. ~ NS10 05-12-2005 PDS NS-08 05-12-2005 POS '~-G^t u~ ~) '- ¡ ~~ g NS- 05-14-2005 PDS :2/W 0-02 1 13700 14080 PRODUCTION PROFILE 0 8007 MEMORY MULTI-FINGER CALIPER 0 11374 MEMORY MULTI-FINGER CALIPER 0 8105 MEMORY MULTI-FINGER CALIPER 5 2 :' ,/1 ;/ ./ ",,"! ,..1 ¡Zt~¡ /'jiiL / \/ '. t., Pl'ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center .sC.J~NNF~\ ~~~ C~) n ~? ([J r~¡:i ,~I;; ",~' ¡ 'I J ., "',"r-< ':,,} L I' ,_, ~,l "~" \. , Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) ~ ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 --? ~60~~~;(i " STATE OF ALASKA ) ALAS~ .blL AND GAS CONSERVATION COI\,...¡{SSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / NS / NS 04/21/05 Rob Mielke USEPA Talib Syed "'.' ..../ W;Y ~v Packer Depth Pretest Initial Well NS-10 Type Inj. S TVD 4,023' Tubing 1,170 1,150 P.T.D. 2001820 Type test P Test psi 3,500 Casing VAC 3,520 Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. AOGCC representative declined to witness test. Well NS-32 Type Inj. S TVD 4,014' Tubing 1,810 1,800 P.T.D.2031580 Type test P Test psi 3,500 Casing 10 3,510 Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. AOGCC representative declined to witness test. Well Type Inj. TVD P.T.D. Type test Test psi Notes: Tubing Casing 15 Min. 30 Min. 1,190 1,160 Interval 1 3,440 3,430 P/F P 1,810 1,770 Interval 1 3,500 3,540 P/F P Interval P/F Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Deta ils: Interval P/F Interval P/F TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. SCAN¡~Ee M.AY (.) ~ ?O(ii" ')) ~ t:.., ua MIT Report Form Revised: 06/19/02 2005-0421_MIT _Northstar_NS-32.xls F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE c!ds, (j~ ( ff)O-, /'ð ¿ ~)~ Memory Multi-Finger Caliper Log Results Summary Company: log Date: log No. : Run No.: Pipe1 Desc.: Pipe1 Use: BP EXPLORATION (ALASKA) INC. May 3, 2004 5419 4 4.5" 12.6 lb. l-80 Tubing Well: Field: State: API No.: Top log IntvI1.: Bot. log IntvI1.: NS 10 Northstar Alaska 50-029-22985-00 Suñace 8,018 Ft. (MD) Inspection Type: 4th Consecutive Corrosion Monitoring Inspection COMMENTS: This caliper data is tied into the WLEG @ 8,005' ( ELMD). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing logged is ~ good to poor condition, with a maximum recorded penetration of 50% @ 1,237'. 60 of the 201 joints logged have recorded wall penetrations in excess of 20% wall thickness. The damage recorded appears mostly in the form of Isolated Pitting, with some line Corrosion beginning to form. There are no areas of significant Cross Sectional Wall . loss or I.D. restriction recorded throughout the tubing. A comparison between this log and the previous log of this well (March 24, 2003) indicates some increase in corrosive damage over the last year. A Maximum Recorded Penetration Comparison plot, illustrating the change in maximum recorded penetrations on a joint-by-joint basis is included in this report. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. Our engineer noted that information about the tree was requested. We are unable to assess the condition of the tree on this weil, as the ID of the 5" tree on this well exceeds the 24 arm caliper tools' maximum finger extension of 4. 5". MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting ( 50%) ( 49%) ( 48%) ( 40%) ( 37%) Jt. Jt. Jt. Jt. Jt. 29 18 2 13 11 @ @ @ @ @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: MAXIMUM RECORDED ID RESTRICTIONS: No areas of significant cross-sectional wall loss (>6%) are recorded. No significant I.D. restrictions are recorded. I Field Engineer: N. Kesseru Analyst: J. Thompson 1,237 Ft. (MD) 785 Ft. (MD) 89 Ft. (MD) 546 Ft. (MD) 497 Ft. (MD) Witness: T. Norene ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-maii: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: 659-2314 SCJ-\NNE[) NtJV 0 B "2D04 Iclds. Well: Field: Company: Country: NS10 NORTHST AR BP EXPLORA TrON ALASKA USA \ Tubing: Nom.OD Weight 4.5 ins 1 2.6 ppf Grade & Thread L-80 Penetration and Metal Loss (% wall) - penetration body 200 metal loss body 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1 % 10% 20% 40% 85% 85% Number of joints analysed (total = 20"1) pene. 1 14 126 57 3 loss 4 197 0 0 0 0 0 Damage Configuration ( body) 200 150 100 50 0 isolated pitting general corrosion line corrosion ring corrosion hole I poss ihle hole Number of joints damaged (total = 172) 164 1 7 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: NomJD 3.958 ins May 3, 2004 MFC 24 No. 00387 1.69 24 J. Thompson Nom. Upset 4.5 ins Upper len. Lower len. 3.0 ins 0.0 ins Damage Profile (% wall) - penetration body 0 1~ +-- ~' ~\ ..,...-..--..-- ~ ~ 48" I 96~ I: Iiir i!iI!!!!!!i!!:: ~ ri=;:: 144t ~ IlL 192~ Bottom of Survey = 192.4 metal loss body 50 100 Analysis Overview page 2 Q, Well: Field: Company: Country: ( PDS Caliper Maximum Recorded Penetration Comparison NS 10 NORTH STAR BP EXPLORATION ALASKA USA Survey Date: Tool: Tool Size: Tubing I.D.: May 3, 2004 MFC 24 No 00387 1.69 inches 3.958 inches Difference in Maximum Recorded Wall Penetrations between May 3, 2004 and March 24, 2003 J J - . I ~ .c E ::I Z, ... i ---~._,-,..".,.,..--"'. -60 20 -40 -20 Diff. in Max. Pen. (mils) I I 40 60 80 a Well: Field: Company: Country: Survey Date: Percent Probability of Hole 50 P[)S Caliper Statistical Evaluation Report NS10 NORTHSTAR BP EXPLORATION ALASKA USA May 3, 2004 Tool: Tool Size: Tubing I.D.: Tubing 0.0.: Wall Thickness: '00 0.24 85% Wall T~ ickness Sa':ety=ac :or Line ..... ...... ..... ..... ..... ....... ..... .... ..... ..... ........ .......... ......... à---.... ... "'....... 0 "'........ ...... -. "" "'$""" è)-...,..... "-"'Ct- ... ~.O ~ " " 0.19 <II 41 .c: \,I ~ .c: ë. 41 Q 0.14-' .... c: 0.09 0.04 0.1 10 Average Rank MFC 24 No. 00387 1.69 inches 3.958 inches 4.5 inches 0.271 inches Standard Deviation of 0.006 0-- -'-. Maximum Probable Penetration* 0.143 inches (52.9 % Wall Thickness) Percent Probability of Recording a Hole* Less than 1 00/0 ,-- . Derived trom data with average rank value less than or equal to 20. 100 clt:l5, Well: Field: Company: Country: PDS Caliper Minimum Diameter Profile NS10 NORTHSTAR BP EXPLORATION ALASKA USA Survey Date: Tool: Tool Size: Tubing 1.0.: May 3, 2004 MFC 24 No 00387 1.69 inches 3.958 inches Minimum Measured Diameters (In.) 2.09 2.29 2.49 2.69 2.89 3.09 3.29 3.49 3.69 3.89 I 1.69 1.89 1 - 8 13 18 23 28 33 38 43 48 - 50 55 60 65 70 75 80 85 .... cu 90 .CI E 95 = Z 100 "E :g 105 110 115 120 122 127 132 137 142 147 152 157 162 167 172 177? 182 ~ 187 : 192: ......., J.:i 1 ] :t PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: NS10 Body Wall: 0.271 in Field: NORTHST AR Upset Wall: 0.271 in Company: BP EXPLORATION ALASKA NominaII.D.: 3.958 in Country: USA Survey Date: May 3, 2004 Joint Depth Pen. Pen. I Pen. Metal Min. I Damage Profile I No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 40 0.11 0.07 26 4 3.91 Isolated pitting. Lt. Deposits. r I I 1 1.1 70 0 0.04 15 1 3.88 PUP Shallow pitting. Lt. Deposits. 1.2 79 0 0.03 11 1 3.82 PUP Lt. Deposits. 1.3 82 0 0.03 12 1 3.90 PUP Shallow pitting. Lt. Deposits. 2 85 0 0.13 46 3 3.89 Isolated pitting. Lt. Deposits. 3 126 0 0.07 26 3 3.75 Isolated pitting. Deposits. 4 167 0.06 0.07 28 4 3.77 Isolated pitting. Deposits. 5 208 0 0.05 19 3 3.90 Shallow pitting. Lt. Deposits. 6 249 0.06 0.07 26 4 3.83 Isolated pitting. Lt. Deposits. 7 290 0 0.06 23 4 3.79 Isolated pitting. Lt. Deposits. 8 332 0 0.08 31 3 3.73 Isolated pitting. Deposits. 9 373 0 0.06 24 4 3.88 Isolated pitting. Lt. Deposits. 10 415 0 0.07 27 3 3.83 Isolated pitting. Lt. Deposits. 11 456 0 0.10 37 3 3.91 Isolated pitting. Lt. Deposits. 12 498 0 0.05 18 4 3.87 Shallow pitting. Lt. Deposits. 13 539 0 0.11 40 4 3.85 Isolated pitting. Lt. Deposits. 14 580 0 0.06 22 4 3.89 Isolated pitting. Lt. Deposits. 15 621 0 0.09 32 4 3.83 Isolated pitting. Lt. Deposits. 16 662 0 0.05 20 3 3.73 Isolated pitting. Deposits. 17 704 0.14 0.07 27 3 3.82 Isolated pitting. Deposits. 18 745 0 0.13 48 4 3.86 Isolated pitting. Lt. Deposits. 19 786 0.06 0.07 26 4 3.87 Isolated pitting. Lt. Deposits. 20 828 0 0.05 18 3 3.83 Shallow pitting. Lt. Deposits. 21 869 0 0.08 29 3 3.90 Isolated pitting. Lt. Deposits. 22 910 0.06 Ù.06 23 3 3.80 Isolated pitting. Lt. Deposits. 23 951 0 0.07 27 3 3.84 Isolated pitting. Lt. Deposits. 24 992 0.06 0.09 34 4 3.85 Isolated pitting. Lt. Deposits. 25 1034 0 0.08 30 3 3.88 Isolated pitting. Lt. Deposits. 26 1075 0 0.05 17 3 3.90 Shallow pitting. Lt. Deposits. 27 1115 0 0.06 23 3 3.89 Isolated pitting. Lt. Deposits. 28 1156 0 0.05 17 3 3.83 Shallow pitting. Lt. Deposits. 29 1197 0 0.14 50 6 3.89 Isolated pitting. Lt. Deposits. 30 1238 0 0.06 21 3 3.92 Isolated pitting. Lt. Deposits. 31 1280 0 0.05 20 4 3.88 Isolated pitting. Lt. Deposits. 32 1321 0 0.07 26 3 3.87 Isolated pitting. Lt. Deposits. 33 1361 0 0.05 17 4 3.89 Line shallow corrosion. Lt. Deposits. 34 1402 0 0.06 22 4 3.89 Isolated pitting. Lt. Deposits. 35 1443 0 0.05 18 3 3.87 Shallow pitting. Lt. Deposits. 36 1484 0 0.04 16 2 3.90 Shallow pitting. Lt. Deposits. 37 1526 0 0.09 34 4 3.89 Line corrosion. Lt. Deposits. 38 1567 0 0.05 19 3 3.92 Shallow pitting. 39 1608 0 0.05 17 3 3.90 Shallow pitting. Lt. Deposits. 40 1650 0 0.05 20 3 3.90 Isolated pitting. Lt. Deposits. 41 1691 0 0.05 18 3 3.85 Shallow pitting. Lt. Deposits. 42 1732 0 0.07 27 4 3.89 Line corrosion. Lt. Deposits. 43 1774 0.07 0.05 18 3 3.84 Shallow pitting. Lt. Deposits. 44 1815 0 0.06 23 3 3.91 Isolated pitting. Lt. Deposits. 45 1856 0.06 0.05 19 4 3.87 Line shallow corrosion. Lt. Deposits. 46 1897 0 0.05 19 3 3.91 Shallow pitting. Lt. Deposits. 47 1938 0 0.06 23 3 3.86 Isolated pitting. Lt. Deposits. I Penetration Body Metal Loss Body Page 1 (' PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: NS10 Body Wall: 0.271 in Field: NORTHSTAR Upset Wall: 0.271 in Company: BP EXPLORATION ALASKA NominaII.D.: 3.958 in Country: USA Survey Date: May 3,2004 Joint Depth Pen. Pen. Pen. I Metal Min. Damage Profile i No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 48 1979 0 0.05 20 3 3.90 Isolated pitting. Lt. Deposits. 48.1 2020 0 0.04 14 2 3.90 PUP Shallow pitting. 48.2 2029 0 0 0 0 N/A SSSV 48.3 2032 0 0.05 17 3 3.90 PUP Shaliow pitting. Lt. Deposits. 49 2041 0 0.06 21 3 3.92 Isolated pitting. Lt. Deposits. 50 2082 0 0.06 22 4 3.89 Line corrosion. Lt. Deposits. 51 2123 0 0.05 17 3 3.88 Shallow pitting. Lt. Deposits. 52 2165 0 0.07 27 3 3.89 Isolated pitting. Lt. Deposits. 53 2207 0 0.06 21 3 3.86 Isolated pitting. Lt. Deposits. 54 2248 0 0.05 17 4 3.81 Shallow pitting. Lt. Deposits. 55 2289 0.12 0.06 23 3 3.89 Isolated pitting. Lt. Deposits. 56 2330 0.05 0.04 15 3 3.89 Shallow pitting. Lt. Deposits. 57 2372 0 0.04 16 3 3.86 Shallow pitting. Lt. Deposits. 58 2413 0 0.04 14 3 3.85 Shallow pitting. Lt. Deposits. 59 2454 0 0.03 13 3 3.80 Shallow pitting. Lt. Deposits. 60 2495 0 0.06 24 3 3.86 Isolated pitting. Lt. Deposits. 61 2536 0.08 0.06 22 3 3.82 Isolated pitting. Lt. Deposits. 62 2577 0.06 0.05 19 3 3.84 Shallow pitting. Lt. Deposits. 63 2618 0 0.06 21 4 3.85 Isolated pitting. Lt. Deposits. 64 2660 0 0.04 14 4 3.85 Shallow pitting. Lt. Deposits. 65 2701 0.03 0.04 14 4 3.86 Shallow pitting. Lt. Deposits. 66 2742 0 0.05 18 3 3.86 Shallow pitting. Lt. Deposits. 67 2784 0.14 0.04 16 4 3.86 Shallow pitting. Lt. Deposits. 68 2825 0 0.03 13 4 3.87 Shallow pitting. Lt. Deposits. 69 2867 0.05 0.07 25 4 3.82 Isolated pitting. Lt. Deposits. 70 2908 0 0.04 13 3 3.74 Shallow pitting. Deposits. 71 2949 0 0.03 13 3 3.85 Shallow pitting. Lt. Deposits. 72 2991 0 0.05 17 3 3.87 Shallow pitting. 73 3032 0.08 0.06 23 3 3.87 Isolated pitting. Lt. Deposits. 74 3074 0.05 0.07 26 4 3.87 Isolated pitting. 75 3115 0 0.05 18 4 3.77 Shallow pitting. Lt. Deposits. 76 3156 0.09 0.03 11 3 3.88 Shallow pitting. 77 3197 0.05 0.08 31 4 3.87 Isolated pitting. Lt. Deposits. 78 3238 0 0.04 16 3 3.87 Shallow pitting. Lt. Deposits. 79 3279 0 0.04 14 4 3.87 Shallow pitting. Lt. Deposits. 80 3321 0 0.05 17 3 3.88 Shallow pitting. 81 3362 0 0.03 13 3 3.86 Shallow pitting. 82 3403 0 0.05 17 2 3.87 Shallow pitting. Lt. Deposits. 83 3445 0 0.06 22 4 3.85 Isolated pitting. Lt. Deposits. 84 3486 0 0.07 24 3 3.86 Isolated pitting. 85 3527 0 0.05 20 2 3.84 Isolated pitting. 86 3569 0 0.06 21 3 3.88 Isolated pitting. 87 3610 0.14 0.05 17 2 3.86 Shallow pitting. Lt. Deposits. 88 3651 0 0.05 18 4 3.85 Shallow pitting. Lt. Deposits. 89 3692 0 0.07 25 4 3.87 Isolated pitting. Lt. Deposits. 90 3733 0 0.06 22 4 3.83 Isolated pitting. Lt. Deposits. 91 3774 0.08 0.03 10 3 3.87 pitting in upset. 92 3815 0 0.04 17 3 3.89 Shallow pitting. Lt. Deposits. 93 3856 0.05 0.04 15 2 3.83 Shallow pitting. Lt. Deposits. 94 3897 0 0.03 11 3 3.85 Lt. Deposits. I Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: NS10 Body Wall: 0.271 in Field: NORTHST AR Upset Wall: 0.271 in Company: BP EXPLORATION ALASKA NominaILD.: 3.958 in Country: USA Survey Date: May 3, 2004 I Joint Depth Pen. I Pen. Pen. I Metal I Min. I Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 95 3938 0.07 0.05 17 2 3.87 Shallow pitting. Deposits. 96 3979 0 0.03 11 3 3.87 Lt. Deposits. pitting. 97 4020 0 0.03 11 2 3.85 pitting. 98 4061 0 0.04 14 4 3.83 Shallow pitting. 99 4103 0 0.05 19 4 3.84 Shallow pitting. 100 4143 0 0.03 12 4 3.86 Shallow pitting. 101 4184 0 0.04 13 3 3.85 Shallow pitting. 102 4225 0 0.03 12 4 3.88 Shallow pitting. 103 4266 0 0.06 23 3 3.88 Isolated pitting. 104 4306 0 0.04 15 2 3.89 Shallow pitting. 105 4347 0.08 0.05 18 2 3.89 Shallow pitting. 106 4388 0 0.04 16 3 3.87 Shallow pitting. 107 4429 0 0.03 10 3 3.88 108 4469 0 0.05 18 2 3.87 Shallow pitting. Lt. Deposits. 109 4510 0 0.04 16 3 3.85 Shallow pitting. 110 4552 0 0.03 11 3 3.85 Lt. Deposits. 111 4593 0 0.05 17 3 3.87 Shallow pitting. Lt. Deposits. 112 4634 0 0.09 32 3 3.89 Isolated pitting. 113 4675 0 0.04 15 3 3.88 Shallow pitting. Lt. Deposits. 114 4716 0 0.03 12 3 3.87 Shallow pitting. 115 4757 0 0.03 11 4 3.88 116 4797 0 0.04 15 4 3.86 Sha!low pitting. 117 4839 0.10 0.06 21 3 3.86 Isolated pitting. 118 4880 0 0.05 18 4 3.90 Shallow pitting. 119 4922 0 0.04 15 3 3.89 Shallow pitting. 120 4963 0 0.05 20 3 3.87 Isolated pitting. 120.1 5004 0 0.05 17 2 3.86 PUP Shallow pitting. 120.2 5013 0 0 0 0 N/A PACKER 120.3 5018 0 0.08 30 4 3.88 PUP Isolated pitting. 121 5027 0.05 0.03 11 3 3.87 shallow pitting in upset. 122 5069 0 0.04 13 3 3.87 Shallow pitting. 123 5110 0 0.04 16 3 3.B7 Shallow pitting. 124 5151 0 0.04 14 3 3.87 Shallow pitting. 125 5192 0 0.03 13 3 3.85 Shallow pitting. 126 5233 0 0.05 17 3 3.88 Shallow pitting. Lt. Deposits. 127 5274 0 0.03 13 3 3.87 Shallow pitting. Lt. Deposits. 128 5315 0 0.06 22 2 3.87 Isolated pitting. Lt. Deposits. 129 5357 0 0.03 12 2 3.87 Shallow pitting. 130 5398 0.11 0.03 13 4 3.87 Shallow pitting. 131 5439 0 0.02 9 3 3.86 132 5480 0 0.08 31 4 3.86 Isolated pitting. 133 5520 0 0.03 12 3 3.88 Shallow pitting. Lt. Deposits. 134 5561 0 0.08 31 3 3.85 Isolated pitting. Lt. Deposits. 135 5602 0 0.05 17 2 3.87 Shallow pitting. 136 5643 0 0.03 11 3 3.87 137 5684 0 0.02 8 3 3.86 Lt. Deposits. pitting. 138 5725 0 0.09 32 3 3.88 Isolated pitting. 139 5767 0 0.03 13 4 3.85 Shallow pitting. 140 5807 0 0.04 13 3 3.84 Shallow pitting. Lt. Deposits. 141 5848 0 0.06 24 2 3.85 Isolated pitting. I Penetration Body Metal Loss Body Page 3 (' PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: NS10 Body Wall: 0.271 in Field: NORTHSTAR Upset Wall: 0.271 in Company: BP EXPLORATION ALASKA Nominal 1.0.: 3.958 in Country: USA Survey Date: May 3, 2004 I Joint I Depth Pen. Pen. I Pen. Meta! Min. I Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 142 5890 0 0.03 10 2 3.87 143 5930 0 0.07 25 4 3.86 Isolated pitting. 144 5971 0 0.03 11 3 3.86 Lt. Deposits. 145 6013 0 0.02 8 4 3.87 146 6054 0 0.03 13 4 3.87 Shallow pitting. 147 6096 0 0.02 9 4 3.89 pitting. 148 6137 0 0.05 20 4 3.89 Isolated pitting. 149 6178 0 0.05 17 4 3.87 Shallow pitting. 150 6219 0 0.04 15 4 3.85 Shallow pitting. 151 6260 0 0.05 19 4 3.85 Shallow pitting. 152 6300 0 0.04 14 4 3.83 Shallow pitting. Lt. Deposits. 153 6340 0 0.04 13 3 3.85 Shallow pitting. 154 6382 0 0.03 10 4 3.86 155 6424 0 0.03 10 3 3.87 156 6465 0 0.04 13 3 3.87 Shallow pitting. Lt. Deposits. 157 6507 0 0.05 20 3 3.87 Line corrosion. 158 6548 0 0.05 19 4 3.85 Shallow pitting. Lt. Deposits. 159 6590 0 0.03 12 4 3.86 Shallow pitting. Lt. Deposits. 160 6631 0 0.03 11 4 3.84 Lt. Deposits. pitting. 161 6671 0 0.03 10 4 3.86 Lt. Deposits. 162 6712 0 0.03 12 4 3.87 Shallow pitting. 163 6753 0 0.04 14 4 3.87 Shallow pitting. 164 6795 0.06 0.03 11 3 3.88 Lt. Deposits. pitting in upset. 165 6835 0 0.03 12 3 3.89 Shallow pitting. 166 6876 0 0.03 13 3 3.87 Shallow pitting. 167 6917 0 0.03 11 3 3.90 168 6958 0 0.04 13 3 3.89 Shallow pitting. 169 6997 0 0.06 22 3 3.91 Isolated pitting. 170 7038 0 0.05 17 3 3.91 Shallow pitting. 171 7079 0 0.03 10 4 3.92 172 7120 0 0.08 31 2 3.90 Isolated.pitting. Lt. Deposits. 173 7161 0 0.04 15 3 3.92 Shallow pitting. 174 7202 0 0.05 20 4 3.92 Isolated pitting. 175 7244 0 0.03 11 2 3.91 176 7285 0 0.04 16 4 3.90 Shallow pitting. 177 7326 0 0.04 14 3 3.92 Shallow pitting. 178 7368 0 0.03 12 3 3.90 Shallow pitting. 179 7409 0.06 0.03 13 3 3.90 Shallow pitting. 180 7450 0 0.04 15 3 3.92 Shallow pitting. 181 7491 0 0.05 19 3 3.92 Shallow pitting. 182 7532 0 0.05 18 4 3.91 Line shallow corrosion. 183 7573 0 0.05 17 3 3.87 Shallow pitting. 184 7614 0 0.04 15 3 3.91 Shallow pitting. 185 7655 0 0.03 11 3 3.90 186 7696 0 0.06 22 3 3.85 Isolated pitting. Lt. Deposits. 187 7737 0 0.04 16 2 3.90 Shallow pitting. 188 7779 0 0.04 15 3 3.90 Shallow pitting. Lt. Deposits. 189 7820 0 0.03 10 2 3.90 190 7861 0 0.03 10 3 3.88 Lt. Deposits. 191 7902 0 0.04 15 3 3.89 Shallow pitting. I Penetration Body Metal Loss Body Page 4 i( PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS10 NORTHSTAR BP EXPLORATION ALASKA USA May 3,2004 I Joint I Depth I Pen. I Pen. I Pen. Metal Min. 1 Damage Profile I No. (Ft.) Upset Body °/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 192 7943 0 0.02 8 3 3.91 ~ 192.1 7984 0 0.03 11 2 3.92 PUP 192.2 7993 0 0 0 0 3.73 XN NIPPLE 192.3 7995 0 0.00 1 1 3.82 PUP Corrosion. Lt. Deposits. 192.4 8005 0 0 0 0 N/A WLEG I Penetration Body Metal Loss Body Page 5 /~~~~~~....... ,/" .~.. ~~. PDS Report Cross Sections Well: Field: Company: Country: Tubing: NS 10 NORTHST AR BP EXPLORATION ALASKA USA 4.5 ins 12.6 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 3, 2004 MFC 24 No. 00387 1.69 24 J. Thompson Cross Section for Joint 29 at depth 1236.94 ft ~~ Tool speE~d = 53 Nominal 10 = 3.958 Nominal 00 = 4.500 Remaining wall area = 95 % Tool deviation = 16 0 Finger 14 Penetration = 0.136 ins Isolated Pitting 0.14 ins = 50% Wall Penetration HIGH SIDE = UP Cross Sections page 1 cIJ:.~.......... ¡.........~...........;.........'.S..................... . "'. '.:0. :-:.--..". ~-{- ~ ,j:, "-" '''',,--"C: ''-~~..~lil-: PDS Report Cross Sections Well: Field: Company: Country: Tubing: NS 10 NORTHST AR BP EXPLORATION ALASKA USA 4.5 ins 12.6 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 3, 2004 MFC 24 No. 00387 1.69 24 J. Thompson Cross Section for Joint 18 at depth 784.94 ft Tool speed = 58 Nominal 10 = 3.958 Nominal OD = 4.500 Remaining wall area = 96 % Tool deviation = 4 0 Finger 20 Penetration = 0.129 ins Isolated Pitting 0.13 ins = 49% Wall Penetration HIGH SIDE= UP Cross Sections page 2 ~¡dÂS¡.A.. AJ~-/f) ').': .. . 'I... ~ n~Efb\E9N(¡f 5 V:')," 5k~';j H V\iELLHEAöJ\B6-VGI t r J M\'~ti}Ó~¡:~:y#X'~ @\~. MO - ] ~ ,.¡ NS10 L rr -' ~ ~~ :1 i ~ tJ " ~V ¡j j ~ f; I' .t ...'" 10314", 45.S#.1í, l-$ú, 6TC @~12ß< Mr> ~ ...: 1- : ~ ~ ~ ~ 0 .. ; ~ 4-5~. 1iUj¡II«, I.-~{}. cfiT.MOO ¡UaING ID:. <U~Sß~ Ç.W>AÇ.t)")', O,(li~ Biõ\.Æf'¡" l ¡ i . ~ ~ ij :] ~ ~ : ~ . I ~ I ~ ~ ~ ! ¡~ ~_. i ~ I !'! í..J. / ~ .:£~'t: C 11'-~;oJ pð': ,-~ 1 -,¿>,Li úÞ.H3IN.AL R'r EL£V = r;<;.17. ~ B ?=¡ f~T!Ç8_. EU;V ., 4>.)- 2: ~' I" ~ ¡ ~ ~ ~ i (20'l." 'Eiht) ~ ~ --~ "ox' ~~~ @ ;W:;!3' MD ~.813"'!Ù H-L H~a! Y.-nee @ 2318' MO ; ~ ;~ ~ ~ CAfM$L FLEV 15-57' ~ s '" '" !§ , ~ ~ ;,; ~ ,. '" ~ '" ~ 1 , ¡:j .. ... 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Æ . . ...,.._ou.. .~JS$' :- I. . ~. 11Jd" ¡ I . i ~, l t- 22.1:1' (, ' ~ ~~. : ~ ..t" ~ ~ . I. ;"'N. .... J ~ ~ ? ¡ !n~~. !. '.. 3[: !'. ., ~ i . To: ..~... ~ ~. ',. i ;.' U ! ~ ~ ~. .----1 ~ -- I -- ~'~ .... ~ ~ I l. ; ~ "-_~_"n_1II M_I"III. ~ j ~- ~ ~nr.r (w- ct') ....[~ .'1 I... ... i . A . , ,'. .. . . \ 1. R. .......;.~ . -..\ , .'IIo::''''r. "I ! 1119.10" (W - T) .;.:.: ~ ~(.. >~~~~~~;lj~Ç . ..1 :.~ :..' .." GR ."'. .'- <l ~. ...._:~ OUNO ~ ?1 , (4. - 1i'"} 5fl.K I . " , . i i ~ ~ t.mnu._!. -:-L__f'Y:' ;A .. "'" ,..,.,. 7'-(1' {t4.M) ......". ",-:..: r ,.tJ...t. OtMENSIONS ARE. APPROX. . jl.ll.1 ,.,."., MM~~ .~ r I ~ I I I t;u.ðT {w- f'} an". , (8' - ~ ~/1f") ~ ~ . ~ (r-Cf) ð4JMT . . . .. - ~ I ~ ABB VETCO GRAY SYSTEMS ENGINEERING :¡ r'o" 'O::.'u U;,u.:.:;u:.u .. ..U..'. 'nu.... . u.. . ... .:. . . .. n.. ..o':u . =~ , 1 20 X 10-3/4 ): 7-5/8 X 4~ 1 /2 DISPOSAL WELLHEAD ;i \1 ~~,,~_Gray': ~. _. .u WtTH 5" TREE 5,000 .PSt.. ......... I: , f::.¿;~CPO~::zt- =;J':' ~~~:~,;~<'c-'<'~I~;:::~;~j .....,,¡-: bp ij \ if Michael J. Francis, P.E. Senior Petroleum Engineer Northstar BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 Mr. Mike Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency (EPA) 1200 Sixth Avenue Seattle, WA 98101 ~ø- Ic¿ç~ Phone: (907) 564-4240 Fax: (907) 564-4441 Email MichaeI.Francis@bp.com Web: www.bp.com 6/7/2004 Mr. Thor Cutler U.S. Environmental Protection Agency (EPA) 1200 Sixth Avenue Seattle, WA 98101 Re: NS10 - Report on Annual Demonstration of Mechanical Integrity Dear Mr. Bussell and Mr. Cutler: Please find enclosed the Report on Annual Demonstration of Mechanical Integrity for the NS1 0 well, Permit No. AK-11002-A. As stipulated by the permit, two (2) copies of the logs and two (2) copies of the descriptive and interpretive report are being sent to the EPA to your attention. Please call if you have any questions or comments. Sincerely, , / ~~ (~. Michael J. Fran(~ Senior PetroleJX,- E;ineer Attachments cc: Talib Syed, EPA Consultant Oran Woolley, ADEC Jim Regg, AOGCC Jeff Walker, MMS Alison Cooke, BPXA Julie Arin/Pam Pope, Northstar Island File Copy RECEIVE JUN 0 92004 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~1 ~/1z./ùA- P.I. Supervisor FROM: Jeff Jones Petroleum Inspector DATE: Monday, May 10,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NS-IO NORTHSTAR UNIT NS-IO Src: Inspector Reviewed By: P.I. Suprv ~ 5/tz..JOtt- Comm NON-CONFIDENTIAL API Well Number: 50-029-22985-00-00 Insp No: mitJJ040506155454 Inspection Date: 5/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: NS-IO Type Inj. 1 TVD 4023 IA 7 3550 3600 3625 3660 3670 P.T. 2001820 TypeTest SPT Test psi 3500 OA 0 0 0 0 0 0 Interval Other (describe in notes) PIF p Tubing 1592 1597 1599 1599 1601 1602 Notes: Class I waste disposal injection well: EPA compliance. 3.5 BBLS diesel pumped, test continued an additional 30 minutes to further demonstrate stabilization. Monday, May 10, 2004 Page I of 1 BPXA WELL DATA TRANSMITTAL Date: 05-27-2003 Transmittal #92651 Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS23 05-09-2003 SCH 1 0 13981 MWD SURVEy RE, PQRT/HARDCOPY/ DISKETTE NS19 05-03-2003 SCH 1 14012 12550 JEWELRY LOG; NS10 03-25-2003 SCH 1 4850 8015 PST WFL-UP FLOW MODE; NS19 05-05-2003 SCH 1 13140 14000 PERFORATING RECORD; NS06 04-09-2003 SCH 1 13000 13788 PERFORATING RECORD; NS23 05-01-2003 SCH 1 11040 13333 PERFORATING RECORD; NS23 04-29-2003 SCH 1 13340 13212 DEPTH DETERMINATION SAMPLE BAILER;.-, ...... NS06 :04-11-2003 SCH 1 13025 13746 BAKER IBP SET RECORD; INS18 07-17-2002 SPERRY 1' - END OF WELL REPORT/MUDLOG: NS22 01-22-2003 SPERRY 1 - END OF WELL REPORT/MUDLOG: NS24 12-27-2002 SPERRY 1 - - END OF WELL REPORT/MUDLOG: Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp B PXA WELL DATA TRANSMITTAL BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Lisa Weepie Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn: Tim Ryherd MMS Attn: Doug Choromanski Date: 05-27-2003 Transmittal #92651 Attn: Kristin Dirks (DNR) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Re: NS 10 - Annual Rpt of Mechanical Integrity Subject: Re: NS 10 - Annual Rpt of Mechanical Integrity Date: Tue, 13 May 2003 08:09:34 -0800 From: Jim Regg <jim_regg~admin.state.ak.us> ~ c~ Organization: AOGCC To: "Francis, Michael J" <Michael.Francis@BP.com> CC: "Hill, Patricia M" <Patricia. Hill@BP.com>, Winton G Aubert <winton_aubert~admin.state.ak.us> Thanks Mike. I appreciate the info and insight. You hit all the same thoughts I had regarding the temp log anamoly. I would tend to lean toward fluid interface before some integrity concern. Jim Regg "Francis, Michael J" wrote: Jim, We did not include the log in the copies of the report (i.e. the ones that did not go to the EPA). A zipped copy of the PDS file is attached. Let me know if II'all need a hard copy (or a CD of the PDS file) for your records. We noted the same Temp Log anomaly, but did not come up with a good explanation. Our first thought was a tubing leak beneath the packer. However, the caliper log does not support this hypothesis. The WFL showed no indications of up flow, so we do not think it is related to upward movement of fluid in the formation. Another possibility is some type of fluid interface (diesel/water?) in the annular fluid trapped beneath the packer. Any ideas? Regards, Mike ..... Original Message ..... From: Jim Regg [mailto:jim regg~admin.state.ak.us] Sent: Monday, May 12, 2003 2:33 PM To: Francis, Michael J Subject: NS 10 - Annual Rpt of Mechanical Integrity Mike - I've looked over the subject report dated 4/22/03. The copy sent to AOGCC does not include Attachment 5 - WFL Up-Flow Mode Press/Temp; is there information that belongs in Attachment 5? Also, I was curious about the slight anamoly that shows up in all 3 runs of the 3/25/03 Temp Log (summary graph shown in Discussion section of report) - it doesn't correlate with anything else in the various integrity tests~logs. Any thoughts what this is? Jim Regg, AOGCC zipped Schlumberger PDS file. zip (appl i ca ti on~x- zip - compressed) Name: zipped Schlumberger PDS fi 1 e. zip Type: Zip Compressed Da ta Encoding: base64 SEP Z 20113 1 of 2 5/13/2003 8:10 AM Re: NS 10 - Annual Rpt of Mechanical Integrity]'~' Jim Regg <jim_regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration 2 of 2 5/13/2003 8:10 AM bp BPXA WELL DATA TRANSMITTAL Date: 04-14-2003 Transmittal Number:92638 Enclosed are the materials listed below· If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailing to .iohnsoih@bp.com · Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS10 03-24-2003 - - MULTI-FINGER CALIPER LOG RESULTS SUMMARY Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) OCT 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RECEI'VED APR 1 5 200 A~aska 0~i & (~as Con~. (~~ Memory Multi-Finger Caliper Log Results Summary Company: BP EXPLORATION (ALASKA), INC. Well: NS-10 Log Date: March 24, 2003 Field: Northstar Log No.: 4979 State: Alaska Run No.: 3 APl No.: 50-029-22985-00 Pipe1 Desc.: 4.5" 12.6 lb. L-80 IBT-MOD Top Log Intvll.: Surface Pipe1 Use: Tubing Bot. Log Intvll.: 8,006 Ft. (MD) Inspection Type' 3rd Consecutive Corrosion Monitoring Inspection COMMENTS: This log is tied into the WLEG ~ 8,006' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 4.5" tubing is in good to fair condition. Penetrations from 20% to 42% are recorded intermittently throughout the tubing. No significant areas of cross-sectional wall loss are recorded. Deposits restrict the I.D. to 3.34" in joint 107 @ 4,458'. A comparison between this log and the previous log run on this well (August 5, 2002) indicates no measurable increase in corrosive damage over the past ~7.5 months. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS ' Corrosion (42%) Jt. 18 @ 770 Ft. (MD) Corrosion (38%) Jt. 4 @ 191 Ft. (MD) Isolated Pitting (34%) Jt. 9 @ 368 Ft. (MD) Corrosion (34%) Jt. 11 @ 481 Ft. (MD) Isolated Pitting (32%) Jt. 138 @ 5,761 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No areas of significant cross-sectional wall loss (> 7%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS ' Deposits Minimum I.D. = 3.34" Jt. 107 @ 4,458 Ft. (MD) Deposits Minimum I.D. = 3.45" Jt. 191 @ 7,919 Ft. (MD) Deposits Minimum I.D. = 3.70" Jt. 38 @ 1,591 Ft. (MD) Deposits Minimum I.D. = 3.71" Jt. 40 @ 1,648 Ft. (MD) No other significant I.D. restrictions are recorded. Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: J. Boyles RECEIVED ProActive Diagnostic Services, Inc. / P.O. Box 1,369,. Stafford, -IX 77497 APR 1 5 200;~ Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.co?, Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659/~C~ &(~,Ot~iL, (~O~!iffi~ . Body Region Analysis We]): NS10 Survey Date: March 24, 2003 Field: Nmthstar fool Type: MFC 24 No. 00387 Company: BP EXPLORA HON (ALASKA), INC. [oo] Size: t .69 Country: USA No. oi Fingers: 24 Analyst: M. Lawrenqt! 4.5 ins 2 6 ppf L 80 B l-Mod 3.958 ins 4.5 !qs 1.2 ins 1.2 ins Penetratlo~ and Metal Loss (% wail) ~ penetration body 200 1% 10% 2 0% ~ meta) }0% body 20 ~o 40 to over 4()% 85% 85% Number of]oims analysed total = 196) pene. 0 }1 t20 44 1 0 1 t95 0 0 (} 0 Damage Configuratior~ ( body ) 1 O0 50 0 Number oiil)[nls damaged (total = i~l i 2 6 t 7 2 0 0 Damage Profile (% wall) penetration body ~ meta} loss body 0 50 98 148 l O0 Bo[tom of Surx, ey = 192.~ Analysis Overview page 2 Well: Field: Company: Country: Survey Date: NS-10 Northstar BP EXPLORATION (ALASKA) INC. USA March 24, 2003 PDS Caliper Statistical Evaluation Report Tool: MFC 24 No. 00387 Tool Size: 1.69 inches Tubing I.D.: 3.958 inches Tubing O.D.: 4.5 inches Wall Thickness: 0.271 inches 0.24 0.19 0.14 0.09 0.04 0.1 Percent Probability of Hole 10 20 50 00 85% Average Rank 10 Line Standard Deviation of 0.001 100 Maximum Probable Penetration* 0.110 inches (40,7 % Wall Thickness) Percent Probability of Recording a Hole* Less than 10% * Derived from data with average rank value less than or equal to 20. PDS Caliper Minimum Diameter Profile Mi~imum Measured Diameters PDS REP~T JOINT TABULATION SHEE~ Pipe: 4.5 ins 12.6 ppi L 80 IBl'-Mod Well: NS lB Wall thickne%: Body: 0.271 ins Upset - O.27 t ins Field: Northsta/ Nominal I1): 3.958 ins Company: BP EXI%ORAIION (ALASKA), INC.~ penetration body Coul~b~: USA R~ metal loss body Su~ey Da~e: March 24, 2003 No. Upset Other Body jLossCplng {3odv ID lComments (% wall) inchesinches } inches ~% ] % inches ] inc~es inches ~) 5B lB0 5 ~5~' ~i56 ~ ~i~(~ [ ~17 .06 .B8 3.87 Corrosion. 1:],0 0 ~ 06 [ 24 ] 3 [ I~] .05 3.92 PUPIso)aled i 2 , !? ,0 :07 [ 26 [4 ~ :(!7 [:0t! 3:89 [~o!a!ed p!X!~!g: L!: Deposits. ~ B 0 .05i 7 [ 4 0 .09 ~.86 Shalk)w pitting. LI. 4 0 B .I0~ 5 ' ~ .10 ' orrosion. Lt. 3OSitS. 3OSitS. 7 0 0 .06 22 3 { 0 .12 3.88 Isolated 8 0 0 .06 23 4 0 .09 3.88 [Isolated 9 0 0 ~)~ 34 4 () .20 3.82 [Isolated 10 0 0 .05 20 3 0 .08 3.90 [Isolated I 1 0 0 .B9 ~ [ 0~ [ ,0~ 3.88 l Corrosion. Lt. De)osits. 12 0 0 .05 18 3 .05 [ 5)9 3.88 ShaiJow pitdni Lt. Dep 13 0 0 .0(, 4 0 j :0~[ ~] !5~g~e(l p~t~n8: ~L ~pg~ 14 0 B .05 18 3 0 j .08i 3.89 ShaJJow pittin8 It. Deposits. 15 0 16 0 18 0 j .02j .I 1 4 .06 .09 3.9B j Colrosion. LL Deposiis. 20 0 [0 .04 [ 16 4 0 [ .13i 3.85 lShaliow 21 0 [0 .06[ 22 4 0 i .23] 3.74 lCorrosion. )osits. 22 .B2 0 .0623 3 .07 .lBi 3.90 Isolated ~osits. 23 0 .02 .05 18 4 .05 .1t 3.85 Shallow p~[t~ng N: Deposits. 24 0 0 04 13 4 .06 .12 3.85 ]Shallow ~osits. 25 0 ,0 , 05 ~7 ~ 9 :10! 3:88 Shgllo,,vp~tt!n8 L~ ,osits. 26 0 0 .06 22 4 0 .14 3.85 Corrosion. 12. 1)~ )osits. ~7 0 0 .06 23 4 0 .10 3.88 Corrosion. LL D osits. 31 2)7 .06 .B5 4 0 .12 ~.83 }Shallow iosJts. 32 0 0 .04 4 .05 .12 3.85 Shallow ~osits. 3;3 0 .04 .B4 5 238 . I 8 3.84 } Shallow iosits. 34 0 0 .04 15 j 3 B .11 3.87 Shallow corr'osion, t_t. Deposits. J ~6 , 0 .05 18 4 0 .09 3.89 Shallow pit, in)osits. 37 0 0 ~()622 4 0 .12 3.88 ] }sola~ed )osks. 38 0 0 .06 21 4 0 ~3() 3.70 Isolated >osits. 39 0 B .06 4 .06 .11 4B 0 .02 .08 4 .05 .29 3.7I )osits. 41 0 0 .0518 4 0 .12 3.86 J t. Deposi[s. ~ 4 ~ 0 ~ 02 ~ ~ 8 ~ 3 .12 3.87 Lt. Deposits. 43 B B .05 18 4 [ 0 .09 3,89 [Shallow corrosion, t L [)e 44 0 0 .06 21 4 [ 0 .1 t 3.87 Isola ed )osits. 45 0 0 .04 4 [ 0 .10 3.88 )osits. . 4(~. 0 , 0 :~ .~3 4 0 .14 3.83 Shallow >mits. 47 0 0 .05 19 3 j .B6 .09 3.87 }Shallow )[tdng. LL Deposits. PDS REPORT JOINT TABULATION SHEE~ Pipe: 4.5 his 12.6 ppf LB0 t81 Mod Wall thickness: Body = 0.271 ins Upset = 0.27t ins Nominal ID: 3.958 ins Well: N$-10 Field: Northstar Company: BP EXPl ORATION {Al ASKA), INC.~ penetration body Country: USA ~ metal loss body Su~,ev [)ate:March 24, 200~ l) 50 100 48 i 0 0 .062I 3 0 .14 [ 3.86 Isolated ~osits. 48:1,0 ~ (~ o , ?, t!, o o sssv 49 0 0 .06 21 3 0 .06 3.92 Lt. t)eposits. 50 0 0 .06 22 4 0 .13 3.90 Isolated ~osits. 51 0 0 .07 27 4 0 .(t6 j3.91 l lsolated Lt. Deposits. 52 0 0 .07 27 4 0 .10 3.89 Isolated ~osits. 53 0 0 .06 3 .07 .09 3.90 )osits. 54 0 0 .04 16 3 0 .08 3.90 Shallow ~osiis, 55 . (! , 0 , :05 ~ I~} 3 ~ 06~ .14 3.88 [Shallow corrosion. LL De 56 0 0 .04 14 4 0 .10 3.89 [ Shallow pitiing. EL 57 60 0 61 0 62 0 63 0 64 0 65 0 66 0 .04 14 4 .08 28 4 ,06 23 4 .05 18 3 .04 16 j 4 .04 16 4 .04 13 3 .05 .05 0 0 0 0 ,19 3.84 Shallow corrosion. Lt. Deposits. )OSitS. ./1 3.86 Corrosion. { t. De .09 3.88 Corrosion. Lt. D~posits. .1 I 3.90 Shallow .14 3,82 [ Shallow Lt .13 3.87 osits. ,07 3.92 S[~/aliow )osits. .03 11 2 0 .10 3.90 [I t, I)eposits. 6~ ' ~ ' i4 . 4'; 2~';ii ()~ .~;~8~h~llowpiting. L.Deposiis, 68 0 0 .03 10 i 2 0 .13 }:~6 [~ 69 ( ) ( 5 i 3 0 11 3.87 i Shallow pitting. Lt. Deposits. 7t 0 0 ,04 14 4 .09 .11 3.89 Sba]Iow pitSn 75 () 0 .t)3 13 4 0 .17 3.84 [ Shallow 76 8 0 .0519 4 .05 .10 3.90 77 . 8 0 ~ .06[ 23 4 0 .07 ~.90 l lsoiated 78 0 0 .0415 4 0 .12 3.83 l Shallow corrosion. Lt. Dc 79 . (~ .0 ~ .0414 4 .06 .07 3.90 lShallow [ ) ) 06 23 i ~ .08 .17 3.83 [I 81 0 0 .03 10 3 0 .15 3.84 82 0 0 4 .06 .12 3.88 Shalk)w }osits. 83 0 0 .03 4 ~ .06 ,21 L75 Deposits. 84 0 0 .02 8 3 .06 .08 3.89 l.t. De 85 0 0 .05 .06 ,08 3.90 [ Sha}k)w 86 0 0 ,03 ~ 0 .08 3.90 Lt. lie 87 0 0 .03 12 3 .07 .07 L90 Shallow 88 ' f~ ~ i o ;~b' 3.90 89 0 0 .06 [ 23 3 0 .07 3.92 Isolated LL Deposits. 92 0 0 113I2 4 0 .10 3.88 ShMlow 93 0 0 .04I3 3 0 ,08 3.87 Shallow pitting. Lt. Deposiis. 94 0 , )3 .t0 , 4 .06~ .07 ~.8~ LL .07 3.87 iLL Deposits. Pipe tabulations page 2 PDS REP~RT/OINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppi 18,0 IBI Mod Wa}) thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Well: Field: Company: NS 10 NorS~star BP EXPI ORAIION (ALASKA), INC~ penetration body USA ~ metal loss ix)d, March 544, 2003 No. Upset Othel Body { )ssCp]ng Body Il) l Commen s ' illches b/che$inches% % inches i~ c es in¢:hes 97 0 .02 .03 11 3 .08 .06 3.90 iL . 98 0 0 .03 I0 3 .06 .15 384 Lt Deposits ~) 50 100 105 0 0 .03i 11 3 0 .08 3.90 Deposits. [:[ii6 ' i5 'i5 ' i~i:5 ~]~i 4 0 .09 3.9o lShaliow ~osits. 107 0 0 .07] 24 3 .10 .41 3,34 ~,Conosion.,osits. 108 0 0 2 0 .06 3.90 [ Isolated >osits. 3.86 389 ,Shallow ~t(n8. Lt Deposits. 3.81 ]12 0 [0 07 26 2 O 09, 3.85 jlvo~edp~?4. Lt Deposks. I I3 0 0 .03 I0 3 0 .06 3.90 iLL 114 0 ) I 15 0 D [116 0 0 [118 0 0 0 0 120.1 0 0 © 0 122 0 0 123 0 0 124 O 0 il25 0 0 .03 3 .03 10 i 2 .03 I I 3 .05 18 3 .04 .04 .06 0 .02 .03 .03 .04 .04 0 .10 3.89 0 .07 3.90 i Lt. .05 .09 3.88 Lt. .06 .09 3.88 j Sha!!ow p!tt!pg: N. I)eposits. 4 0 . :]0 L91 j~h~!!owpiU!pg: LL D~posits. 13 3 .06 .(39 [ 3.89 Shallow !td!~g: L!_Dcposits. 2 0 .06[ 3.90 Isolated msils. 0 0 0 0 N/A PACKER 9 3 0 .07. 3?0 [ 1 I 2 .06 .06 3.89 l Lt. Deposits. 13 3 .06 .06 3.86 allow pitting. It. 14 3 .06 .13 3.86 Shallow p~tt~ng. L~: )osits. 2 0 .10 3.87 Shallow )osits. Lt. 133 o 0 .03 10 3 0 A0 3.88 il_t. 134 0 0 .0~13 4 0 .07 ~ ~.89 Shallow )itting. L.Deposits. 135 0 0 04 i I ~ t 0 05 3.90 ShaJ]ow [136 0 ~0 = /)312 i 4 , .07 , .12 , 3.86 Shailow~ ing. L.Depos s 137 0 0 .02 7 0 .09 3.87 t_t. 138 0 ) 9 32 3 ) .07 ~.9 )s ) ated )tti ~. Lt. Deposits. 139 ( ) .0310 2 0 .l} 3.87 IL t40 0 0 .03 12 3 0 .08 g.87 Shallow Deposks. 0 0 .06 21 4 0 .08 3.89 145 0 0 .03 2 0 .07 3.89 Pipe labulations page 3 PDS REP[~J~T JOINT TABULATION SHEE~ ....... Pipe: 4.5 ins 12.6 ppf L 80 lB i-Mod Wall thickness: Body- 0.271 ins Upset- 0.271 ins Nominal ID: 3.958 ins Well: NS-lB Field: Norlhs~ar Company: BP EXPI ORA/ION (ALASKA), INC.~ penetralion body Countl¥: USA ~ metal loss body Su~/ev [)ate:M,~rd~ 24, 2003 146 ] 0 0 .02 3 147 [ 0 0 .02 8 4 ,UB . 0 , 0 . :o(, [ 4 149 · 0 , ~? 03 ~, t0 3 ~05 3.91 II.D( .08 3.90 [Lt. .08 3.9 IIsolated .08 3.90 ~osits. 155 0 0 .03 4 [ 0 .06 3.89 156 O .03] .B2 8 3 .07 .06 3.90 LL Deposiu. 157 O 0 .05 18 2 B .06 3.90 Sha!!ow p!t!!qg. ~osits. 158 0 .02 .05 18 4 J .07 .13 3.86 Shalbw ~osits. 159 0 0 .02 8 2 [ .05 .06 3.89 Lt. D( 16(3 0 .03 .03 I I 3 [ .06 .05 3.90 161 0 0 .()3 3 0 .14 3.85 j Lt. Deposits, 162 0 0 .03 I t 3 0 [ .06 3.89 163 0 ]0 ] .04 15 3 0 .07 3.90 164 0 0 .03 11 3 0 [ .!0[ 3.9(3Lt.D~ 165 0 .02 .03 3 .I)5 [ .()7 [ 3.89 Sba[iow t66 0 0 .04 13J 4 0 .06 3.88 Shalio'~, pittMi Lt. Deposits. ,167 ~ 0 ,0 , :03 !2 3 :06 :07 3:9~ S!]a!!c~wp!t!~ng: L~Depos!!s, 168 0 B .04 3 .07[ :0(~ [ 3:90 S!~a]!ow p!tt!!2g_LLI)epos!¢s: 169 0 0 .05 2 0 .06J 3.90 ,osi~s. 170 , 0 0 , :!)4 ~ !6=3 , 0 .09 3.89 Sha)]ow ~osiU. 171 0 0 .03 10 3 0 .04 3.92 173 ~0 ,0 , :03 , 13 :2[ 0 , .06 ~:9J) Shallm,vp!tti~]g: !:[:Deposits. ~osiU. 179 0 0 .03 ] 0 2 0 ,08 3.88 I t. Deposits. 180 0 ~ 0 , 04 ?, 3 [ !3 :!)6 3:90 ]~ha}low p!t?l~ 18 I 0 0 .04 14 3 0 .I 2 3.85 185 0 0 .031I j 2 0 .B6 3.90 186 0 0 .0830 J 4 0 . I 1 3.87 j tsoJated ~osits. tB7 0 0 .0517 4 0 .14 3.87 !88 0 , 0 :!33 [ ? ~ j 4 . o, :0~ 3:90 Lshallow p!t!!n8 L!: Deposits. 19(~ 0 ' .04 .03[I1i 4 .12 ).t6 3.81 jlt. Deposks, 191 0 0 .05[18 3 0 .53 3.45 ~osits. ]192 0 0 .03II 3 0 .13 3.85 [I L Deposits. 192.1 B 0 .026 2 ) ~6 ' ~.8~ PU~ L Depos s i922 0 0 0 0 0 0 3.72 XN NIP 192.3 0 0 0 0 0 O 0 N/A ] WLEG 50 ) 0B Pipe Tabulatioas page 4 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring- damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Line- damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General- damage depth range exceeds 1 * pipe IDand/or extends more than 20% of circumference. Isolated- damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line length = 0.185 feet. Pipe Tabulations 5 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 IBT-Mod Wall thickness: Body-- 0.271 ins Upset ~- 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 1 31.05 22.24 3.996 3.993 3.958 4.500 1.1 53.29 9.63 3.994 3.995 3.958 4.500 ~up 1.2 62.92 2.67 3.992 4.010 3.958 4.500 ~up 1.3 65.59 2.67 3.989 4.005 3.958 4.500 ~up 2 68.26 40.72 3.999 3.996 3.958 4.500 3 108.98 41.10 3.991 3.988 3.958 4.500 4 150.08 41.58 3.995 3.991 3.958 4.500 5 191.66 41.18 3.993 3.991 3.958 4.500 6 232.84 41.24 4.000 3.996 3.958 4.500 7 274.08 41.48 3.999 3.996 3.958 4.500 8 315.56 41.87 4.007 4.004 3.958 4.500 9 357.43 41.70 3.996 3.994 3.958 4.500 10 399.13 41.07 4.002 3.998 3.958 4.500 11 440.20 41.79 4.007 4.002 3.958 4.500 12 481.99 41.05 3.994 3.992 3.958 4.500 13 523.04 40.87 3.998 3.995 3.958 4.500 14 563.91 41.67 4.000 3.995 3.958 4.500 15 605.58 40.96 3.995 3.992 3.958 4.500 16 646.54 41.56 3.997 3.994 3.958 4.500 17 688.10 41.95 3.995 3.992 3.958 4.500 18 730.05 41.40 4.002 3.999 3.958 4.500 19 [ 771.45 41.27 3.997 3.994 3.958 4.500 20 [ 812.72 41.23 3.997 3.994 3.958 4.500 21 [ 853.95 40.97 4.000 3.997 3.958 4.500 22 894.92 41.39 4.008 4.002 ] 3.958 4.500 23 936.31 41.24 4.001 3.997t 3.958 4.500 24 977.55 41.72 3.999 3.996t 3.958 4.500 25 1019.27 41.30 4.001 3.999 3.958 4.500 26 1060.57 40.28 3.999 3.997 3.958 4.500 27 1100.85 40.99 4.010 4.006 3.958 4.500 28 1141.84 41.18 4.003 4.001 3.958 4.500 29 1183.02 41.13 4.007 4.005 3.958 4.500 30 1224.15 41.95 4.001 3.999 3.958 4.500 31 1266.10 [40.97 4.003 3.997 3.958 4.500 132 1307.07[ 40.15 4.001 3.997 3.958 4.500 Well: NS-10 Field: Northstar Company: BP EXPLORATION (ALASKA), INC. Country: USA Survey Date: March 24, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 33 1347.22 40.92 4.003 4.000 3.958 4.500 34 1388.14 41.16 4.003 3.999 3.958 4.500 35 1429.30 41.09 4.001 3.998 3.958 4.500 36 1470.39 41.59 3.997 3.996 3.958 4.500 37 1511.98 41.77 3.997 3.993 3.958 4.500 38 1553.75 41.10 4.002 3.997 3.958 4.500 39 1594.85 41.52 4.009 4.005 3.958 4.500 40 1636.37 41.58 4.003 4.000 3.958 4.500 41 1677.95 41.16 4.003 3.999 3.958 4.500 42 1719.11 41.61 4.006 4.003 3.958 4.500 43 1760.72 41.16 4.006 4.004 3.958 4.500 44 1801.88 40.97 3.999 3.997 3.958 4.500 45 1842.85 41.07 4.003 4.000 3.958 4.500 46 1883.92 41.14 4.008 4.004 3.958 4.500 47 1925.06 41.45 4.006 4.003 3.958 4.500 48 1966.51 41.17 4.009 4.006 3.958 4.500 48.1 2007.68 20.51 N/A N/A 3.958 4.500 ssv 49 2028.19 41.36 4.003 4.002 3.958 4.500 50 2069.55 41.58 4.009 4.004 3.958 4.500 51 2111.13 41.59 4.000 3.997 3.958 4.500 52 2152.72 41.58 3.999 3.997 3.958 4.500 53 2194.30 41.12 3.998 3.994 3.958 4.500 54 2235.42 41.10 4.003 4.001 3.958 4.500 55 2276.52 41.61 3.998 3.995 3.958 4.500 56 2318.13 41.48 3.999 3.997 3.958 4.500 57 2359.61 41.48 4.000 3.997 3.958 4.500 58 2401.09 40.77 3.999 3.997 3.958 4.500 59 2441.86 41.69 3.994 3.991 3.958 4.500 60 2483.55 41.14 3.990 3.988 3.958 4.500 61 2524.69 41.43 4.000 3.998 3.958 4.500 62 2566.12 41.13 4.001 3.998 3.958 4.500 63 2607.25 41.58 3.995 3.994 3.958 4.500 64 2648.83 41.06 4.000 3.996 3.958 4.500 65 2689.89 41.44 4.002[ 3.999 3.958 4.500 66 2731.33 41.58 4.003I 4.000 3.958 4.500 Joint Tally page 1 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 IBT-Mod Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint] Depth Length Modal Mean Nominal Nominal Type No.[ ID ID ID OD feet feet inches inches inches inches 67 I 2772.91 41.64 4.006 4.001 3.958 4.500 68 ] 2814.55 41.60 4.005 4.001 3.958 4.500 69I 2856.15 41.19 4.003 4.002 3.958 4.500 70 2897.34 41.63 3.999 3.998 3.958 4.500 71 2938.97 41.36 4.005 4.003 3.958 4.500 72 2980.33 41.60 3.999 3.996 3.958 4.500 73 3021.93 41.67 3.999 3.996 3.958 4.500 74 3063.60 41.23 4.001 3.999 3.958 4.500 75 3104.83 40.74 4.001 3.998 3.958 4.500 76 3145.57 41.10 4.002 4.000 3.958 4.500 77 3186.67 41.71 3.998 3.994 3.958 4.500 78 3228.38 41.13 4.004 3.999 3.958 4.500 79 3269.51 41.48 3.999 3.998 3.958 4.500 80 3310.99 41.25 4.001 3.997 3.958 4.500 81 3352.24 41.79 3.996 3.994 3.958 4.500 82 3394.03 41.35 3.996 3.994 3.958 4.500 83 3435.38 41.08 3.988 3.987 I 3.958 4.500 84 3476.46 41.56 3.996 3.992 3.958 4.500 85 3518.02 41.39 3.992 3.989 3.958 4.500 86 3559.41 41.26 3.993 3.989 3.958 4.500 87 3600.67 41.24 3.993 3.988 3.958 4.500 88 3641.91 41.49 3.994 3.991 3.958 4.500 89 3683.40 40.56 3.991 3.989 3.958 4.500 90 3723.96 41.66 3.993 3.990 3.958 4.500 91 3765.62 41.21 4.001 3.999 3.958 4.500 92 3806.83 41.22 3.989 3.987 3.958 4.500 93 3848.05 40.66 3.989 3.985 3.958 4.500 94 3888.71 41.05 4.001 3.995 3.958 4.500 95 3929.76 40.78 4.001 3.998 3.958 4.500 96 3970.54 41.12 3.996 3.994 3.958 4.500 97 4011.66 41.29 3.999 3.996 3.958 4.500 98 4052.95 41.64 3.994 3.990 3.958 4.500 99 , 4094.59 40.41 3.987 3.987 3.958 4.500 100 I 4135.00 41.08 3.990 3.984 t 3.958 4.500 1014176.0841.193.9943.9903.9584.500 Well: Field: Company: Country: Survey Date: NS-10 Northstar BP EXPLORATION (ALASKA), INC. USA March 24, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 102 4217.27 41.11 3.990 3.987 3.958 4.500 103 4258.38 40.15 3.998 3.993 3.958 4.500 104 4298.53 40.73 3.995 3.992 3.958 4.500 105 4339.26 41.08 3.999 3.995 3.958 4.500 106 4380.34 41.15 3.992 3.990 3.958 4.500 I 107 4421.49 40.49 3.989 3.944 3.958 4.500 108 4461.98 40.91 3.992 3.988 3.958 4.500 109 4502.89 41.86 3.988 3.985 3.958 4.500 110 4544.75 41.23 3.993 3.991 3.958 4.500 111 4585.98 41.67 3.997 3.992 3.958 4.500 112 4627.65 40.64 3.998 3.994 3.958 4.500 113 4668.29 41.53 3.994 3.992 3.958 4.500 114 4709.82 40.66 3.998 3.995 3.958 4.500 115 4750.48 40.52 3.997 3.992 3.958 4.500 116 4791.00 41.63 3.994 3.992 3.958 4.500 117 4832.63 41.12 3.993 3.991 3.958 4.500 118 4873.75 41.92 4.000 3.996 3.958 4.500 I 119 4915.67 41.18 3.989 3.985 3.958 4.500 120 4956.85 41.05 3.997 3.992 3.958 4.500 120.1 4997.90 23.32 N/A N/A 3.958 4.500 ,acker 121 5021.22 41.62 3.995 3.993 3.958 4.500 122 5062.84 41.54 3.992 3.987 3.958 4.500 123 5104.38 41.58 3.995 3.991 3.958 4.500 124 5145.96 40.64 3.992 3.991 3.958 4.500 125 5186.60 41.14 3.992 3.987 3.958 4.500 126 5227.74 41.04 3.984 3.984 3.958 4.500 127 5268.78 41.29 3.992 3.991 3.958 4.500 128 5310.07 41.05 3.988 3.984 3.958 4.500 129 5351.12 41.03 3.987 3.984 3.958 4.500 130 5392.15 41.16 3.991 3.988 3.958 4.500 131 5433.31 41.27 3.989 3.985 3.958 4.500 132 5474.58 40.65 3.991 3.989 3.958 4.500 133 5515.23 41.08 3.994 3.991 3.958 4.500 134 5556.31 41.02 3.988 3.985 3.958 4.500 135 5597.33 41.10 3.988 3.983 3.958 4.500 Joint Tally page 2 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12,6 ppf L-80 IBT-Mod Wail thickness: Body-: 0.271 ins Upset -- 0,271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 136 5638.43 41.06 3,989 3,986 3.958 4.500 137 5679.49 41.21 3.958 3.985 3.958 4.500 138 5720.70 41.75 3.995 3,993 3,958 4.500 139 5762.45 40.61 3,987 3,983 3.958 4,500 140 5803,06 40.60 3,992 3,989 3.958 4.500 141 5843.66 41,78 3.999 3.996 3,958 4.500 142 5885.44 40.62 3.990 3.987 3.958 4,500 143 5926.06 41.13 3,992 3.988 3,958 4,500 144 5967.19 41.46 3.992 3,990 3,958 4.500 145 6008.65 41.78 3.992 3,988 3.958 4,500 146 [ 6050.43 41,58 3.991 3.989 3,958 4,500 147 6092.01 40.85 3,988 3~.986 3,958 4.500 148 6132.86 41.18 3,985 3.982 3,958 4,500 149 6174.04 41.19 3,988 3.984 3,958 4.500 150 6215.23 41.04 3,986 3.984 3,958 4,500 151 6256.27 40.60 3.984 3.982 3,958 4.500 152 6296.87 40.09 3.984 3.981 3.958 4.500 153 6336.96 41.69 3.985 3,982 3.958 4.500 154 6378.65 41.63 3.979 3.977 3,958 4,500 155 6420.28 41.65 3.980 3,978 3.958 4.500 156 6461.93 41.59 3.979 3.977 3.958 4,500 157 6503.52 41.55 3.992 3,986 3.958 4.500 158 6545.07 41.57 3,977 3.974 3.958 4.500 159 6586,64 41.07 3.980 3,976 3,958 4.500 160 6627.71 40.50 3,981 3,976 3.958 4,500 161 6668.21 41,31 3.980 3,975 3,958 4,500 162 6709.52 40.83 3,987 3,983 3.958 4.500 163 6750.35 41.63 3,985 3.983 3.958 4.500 164 6791,98 41.00 3,990 3.984 3.958 4.500 165 6832.98 41.29 3,978 3,975 3.958 4.500 166 6874.27 40,93 3.989 3,986 3.958 4,500 167 6915.20 41.18 3,990 3,986 3,958 4,500 168 6956.38 39.18 3,988 3,984 3.958 4.500 169 6995.56 41.05 3.993 3.990 3.958 4,500 1170 7036.61 41.18 3,995 3.992 3.958 4,500 Well: Field: Company: Country: Survey Date: NS-10 Northstar BP EXPLORATION (ALASKA), INC. USA March 24, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 171 7077.79 41.16 3.993 3.991 3.958 4.500 172 7118.95 40,89 3.990 3.987 3.958 4.500 173 7159.84 40.99 3,993 3.990 3.958 4,500 174 7200.83 41.52 3.990 3,988 3.958 4,500 175 [ 7242.35 41.06 3.987 3.985 3.958 4.500 176I 7283.41 41.68 3.984 3.981 3.958 4.500 177 7325.09 41,24 3.989 3.987 3.958 4,500 178 7366.33 41.17 3.983 3,982 3.958 4.500 179 7407.50 41.06 3.985 3,980 3.958 4.500 180 7448.56 41.10 3.990 3.988 3.958 4,500 181 7489.66 41.24 3.989 3.987 3.958 4.500 182 7530.90 41.14 3.988 3.985 3.958 4.500 183 7572.04 41.38 3.983 3.982 3,958 4.500 184 7613.42 41.06 3.981 3.978 3.958 4.500 185 7654.48 41,16 3.981 3.978 3.958 4.500 186 7695.64 40.95 3.978 3.974 3.958 4.500 187 7736.59 42.08 3.983 3,980 3.958 4.500 188 7778.67 41.00 3.979 3.977 3.958 4.500 189 7819.67 41.14 3,979 3,976 3.958 4.500 190 7860.81 41.16 3,980 3.977 3,958 4,500 191 7901.97 40.97 3.972 3.970 3,958 4.500 192 7942.94 41,02 3,979 3.974 3.958 4,500 192.1 7983.96 9.72 3,962 3.967 3.958 4.500 )up 192.2 7993.68 12.32 3.725 3,725 3.725 4.500 192.3 8006.00 N/A N/A N/A 3.958 4,500 ~/leg I Joint Tally page 3 PDS Report Cross Sections Well: NS10 Survey Date: March 24~ 2003 Fie]d: Northstar l'ooi Type: MFC 24 No. 00387 Company: BP EXPLORATION (ALASI<A), INC. Too[ Size: 1.69 Country: USA No. of Fingers: 24 )-ubi?g~ 4,5 }ns ] 2.6ppf LB0 ]BT-Mod Aqa]y~ M:/:.wv~'enc~ Cross Section for joint 18 at depth 769.91 ft 'rooJ speed - 49 Nominal ID = 3.958 Nominal OD = 4.500 Remairling wail area = 96 % Tool deviation = 8 ° Finger 13 Penetration = 0. I 14 ins Corrosion 0. I 1 ins = 42% Wa]] Penetration I~IGI t SIDE - UP Ooss Sections page 1 PDS Report Cross Sections Well: NS-10 Survey Dale: Marcl~ 24, 2003 Field: Nortl~star Too/'Type: MFC 24 No. 00382' Company: BP EXPLORATION (ALASKA), INC. Fool Size: 1,69 Countq,,': USA No, of Fingers; 24 ?~b!?g~ 4,5 ins ]~:6 pi)f L:gO [l'~]F-Mod ~na!ysl~ M, ~awrence i Fool speed = 44 Nrm~ina] ID = 3.958 Nominal OD = 4,500 Remaining wall area = 98 Fo()] deviatiorl = 12 ° 1 Finger 13 Penetration = 0.104 ins Cr~rrosion 0,10 i~s = 38% Wall Penetration t IIGI I SIDE = UP Cross Sections page 2 PDS Report Cross Sections Well: NS 10 Survey Date: March 24, 2003 Field: Northstar Tool Type: MFC 24 No, 00387 Company: BP EXPLORATION (ALASKA), INC. Tool Size: 1.69 Country: USA No, of Fingers: 24 'Fubing~ ~L5 ins 12:(~ppl' L:80 ~B]F-M~ Ana?s~ M:~:~w~2~? Cross Section for }oint 107 at depth 4458.24 ft Tool speed = 48 Nominal ID - 3.958 Nomirla] OD = 4.500 Remaining wall area 100 % Fool deviation = 62 ® Finger 12 Proiection = 0,406 ins Deposits Minimum I.D. = 3.34 ins I tlGI I SIDE = UP TREE:ABB-VGI 5 1/8" 5ksi NS1 0 RKB. ELEV = 55.77' WELLHEAD:ABB-VGI 11" KB-BF. ELEV = 39.87' Mulitbow, 5ksi T--~"' ,: ' ~ BASE FLANGE ELEV = 15.9' 20", 169# X-56 @ 199' MD I I - -- --'X' Nipple (~ 2033' MD 1994' TMD 3.813" ID -- -- -- Heat Trace @ 2318' MD 10 3/4", 45.5#/ft,- ___ ,i il, L-80, BTC @3726' MD / Cement 4.5", 12.6#/ft, L-80, IBT-MOD '~--'1 TUBING ID: 3.958" CAPACITY: 0.015 BBL/FT , ~;~ Baker S3 PACKER 3.875"1D @5015' MD 4023' 'I'VD 4.5" 'XN' NIPPL,E, (~ 7994' 6294' TVD 3.725' ID (OTIS) ~ ,~,. ,.~ ~.. 4.5" WLEG, @8006' MD 7 5/8", 29.7#/ff L-80, BTC-M @8029'MD L ~ 6 3/4" open hole TD @8246' MD 6513' TVD DATE REV. BY COMMENTS Northstar 1/11/01 AGK Initial Diagram ~.~[J.I.;_NSl0 9/10/01 EMF Inserted TVD Depths ,APl NO: 50-029-22985-00 12/20/02 EMF Updated KB Information BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Tom_Maunder@admin.state. ak.us; Bob_Fleckenstein@admin.state. ak.us; Jim_Regg@admin.state.ak.us Email to: OPERATOR: BP Exploration (Alaska) Inc. FIELD / UNIT / PAD: Northstar DATE: 03/26/03 OPERATOR REP: Mike Johns AOGCC REP/EPA: Thor Cutler - USEPA / Talib Syed - EPA consultant WellINs-lO P'T'D'I2001820 Notes: Annual MITIA WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type test Type Inj. Typel~. Typel~. Packer Depths (ff.) I Pretest Initial 15 Min. 30 Min. Tubingl Interval 0 Test psiI 35001 I Casin~ll VACI 35001 3430[ 34001 P/FI P Test Details: EPA annual surveillance. Pumped 4 bbls of diesel to pressure IA to 3500 psi. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT NS NS-10 03-26-031.xls Permit to Drill 2001820 MD 8246 TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. NORTHSTAR UNIT NS-10 Operator BP EXPLORATION (ALASKA) INC 6513 Completion Dat 1/11/2001 Completion Statu WDSPL Current Status WDSPL APl No. 50-029-22985-00-00 UlC Y REQUIRED INFORMATION Mud Log No Sample No Directional Survey_ _.._..._J~-___X/_, _/~_____. _. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name iL L L L L L L L L R L L C C R L L L L L L L L R L R Log Log Scale Media ~MD~MudLog 1 ,.~MadL"b"~ 2 2/5 (data taken from Logs Portion of Master Well Data Maint ._C-r~ction/.C,d~,~o ! 5 d.~-r .a'~ r Injection 2 ~'~ent Volume Log 2 ~S 2/5 ~ DLL 2/5 ~_~Res/Acoustic 2/5 ~.~CNL/Litho 2/5 .~I~'-~R 2/5 ~a~ survey ~onal Survey c. usrf 5 ~I~SIT 5 F~jl3a~'~l~Report Interval Run OH I No Start Stop CH Dataset Received Number Comments FI NAL 159 8246 FI NAL 100 6550 FI NAL 100 6550 ~3.724 8036 220 7988 FI NAL 235 8219 100 6550 FINAL 0 8185 FINAL 8450 8246 FINAL 3724 8001 FI NAL 3724 8020 FI NAL 3724 8001 FINAL 3724 8036 FI NAL 3724 8001 FI NAL 235 8219 FINAL FINAL FINAL 3650 7965 FI NAL 400 3660 FI NAL 3724 8036 FINAL 220 7988 FINAL ch ch ch Open Open OH Case CH CH OH OH OH OH OH OH OH OH OH OH OH OH ch 5/14~2001 5114~2001 5114~2001 2/2112001 2/21/2001 2/21/2001 5/4/2001 2/27/2001 2/27/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 2/21/2001 5/14/2001 10045 ~J~87 159-8246 Color Print 100-6550 Sepia~--'-'-'""~ 0~1~_6550 Digital Data 3724-8036 ', ~;3 ~ 235-8219 BL, Sepia 0-8185 BL, Sepia 8450-8246 BL, Sepia 3724-8001 BL, Sepia 3724-8020 BL, Sepia 3724-8001 BL, Sepia 3724-8036 BL, Sepia 3724-8001 BL, Sepia 235-8219 BL. Sepia Dir Survey Paper Copy Dir Survey Digital Data 3650-7965 Color Print 400-3660 Color Print ~'~ 3724-8036 Digital Data 9888//~220-7988 Digital Data Final Well Report Permit to Drill 2001820 DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. NORTHSTAR UNIT NS-10 Operator BP EXPLORATION (ALASKA) INC MD 8246 TVD 6513 L L L L L L Rpt ~,.~C~e e Notes Completion Dat 1/11/2001 *--'l~'rvludLog 2 ,,,,MD MudLog 2 u,ff~/D UudLog I Completion Statu WDSPL Current Status WDSPL FINAL 159 8246 ch 5/14/2001 FINAL 159 8246 ch 5/14/2001 FINAL 159 8246 ch 5/14/2001 1 0 8013 Case 9/3/2002 APl No. 50-029-22985-00-00 UIC Y 159-8246 Color Print 159-8246 Color Print 159-8246 Color Print Memory Multi-Finger Caliper Log results summary Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? y,,/__~ Chips R~"_=!'.'cff? "/:'; -- Analysis ........., ,,, R ~.r~.i v~.cl ? Daily History Received? .~ Formation Tops (~/N Comments: · Compliance Reviewed By: Date: bp Date: 09-03-2002 Transmittal #92568 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Bottom SW Name Date Contractor Log Run Top Depth Depth Log Type NS24 .08-21-2002 ANA I 0 12127 MWD SURVEY REPORT; (HARDCOPY) ~° Ibq MWD SURVEY REPORT; (DISKETTE) NS10 D8-05-2002 PDS I 0 8013 MEMORY MULTI-FINGER CALIPER; (HARDCOPY) ~d~ansmittal Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Doug Choromanski (MMS) Attn: Tim Ryherd (DNR) Attn: Buford Bates (Murphy Exploration) RECEIVED SEP 0 $ 200 Petrotechnical Data Center LR2-1 900'E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp Michael J. Francis, P.E. Senior Petroleum Engineer Northstar BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 0 5/2/2002 Thor Cutler EPA (OW-137) 1200 Sixth Avenue Seattle, WA 98101 Phone: (907) 564-4240 Fax: (907) 564-5200 Email FranciMJ@bp.com Web: www.bp.com RE: NS10 - Report on Annual Demonstration of ,, Mechanical Integrity Dear Thor: In accordance with the requirements of the Northstar Unit Class I injection well permit, EPA UIC Permit AK-11002-A, BP Exploration (Alaska) Inc. hereby submits two copies of the attached annual report on mechanical integrity testing, vertical fluid movement logging and tubing inspection logging. Please feel free to call if you have any questions or comments. Sincerely, Miclgael O. F/fa/hci's, ~'' ' · ' ,~.' . Sen~or Petr~,~ um Engineer Attachment CC: Talib Syed and Associates, Inc. Je'ff Walker, MMS Tom Maunder, AOGCC NS10 file RECF!VED F'I~T 0 5 2002 Alaska 0. ~ u,,~, ~,u.~, [;ommissiPn ~,nch0rage bp Date: 04-29-2002 Transmittal Number:92473 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 Top SW Name IDate Contractor Log Run Depth Bottom Depth Log Type NS10 ,04-08-2002 SCH 1 4850 8015 PRESSURE LOG; TEMPERATURE LOG; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED /~?P, ,",, 0 2002 ~/a~o//&~a~.(~n Petrotechnical Data Center LR2-1 ,900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp NS10 EPA UIC Class I Permit AK-11002-A Part II.C.3.b (1) and (2): Report on Annual Demonstration of Mechanical Integrity April 22, 2002 Michael J. Francis, P.E. Executive Summary: Annual Surveillance on the NS10 EPA UIC Class I disposal well was performed April 6 through April 9, 2002. The scope of work included a Mechanical Integrity Test (MIT), a Water Flow Log (WFL), a Temperature Log and a Caliper Log. The MIT to 3500 psi demonstrated that there is no significant leak in the casing, tubing or packer. The WFL results indicate there is good vertical containment of injected fluids in permitted interval. Seven WFL stops were made starting just above the casing shoe and stopping just above the packer. Fluid movement was not detected on any of these stops. The temperature log also indicates there is good vertical containment of injected fluids in permitted interval. Both the baseline pass and warm-back pass indicate the top of fluid entry is at _+7960' MD. The caliper tubing inspection log indicates the tubing is in good to fair condition with penetrations of less than 20% recorded in the majority of the tubing with intermittent penetrations of 20% to 40% of wall thickness. MIT testing and the WFL and temperature log were witnessed by the EPA's representative, Talib Sayed, P.E.. A wellbore schematic (attachment 1) and a well log (attachment 2) are included for reference. Discussion Mechanical Integrity Test (MIT) A mechanical integrity test was conducted on April 7, 2002. The well was allowed to thermally stabilize for fourteen hours and then the annulus between the 4.5" tubing and 7.625" casing and above the packer was pressured up to 3550 psi. After 15 minutes, the pressure had declined to 3510 psi and after a total of 30 minutes the pressure had declined to 3,500 psi. The total pressure loss for the 30 minute period was 1.429%. The pressure loss during the first 15 minutes was 1.127% and the pressure loss during the last fifteen minutes was 0.285%. The 1.429% total loss was much less than the 10% loss during the test period allowed by the permit. Pressure stabilization was demonstrated with only one quarter of the total pressure loss occurring during the last half of the test. This is less than the one third allowed in the permit. The MIT results are summarized in attachment 3, the pressure chart recorded during the test is shown in attachment 4 and the well service report for this work is included in attachment 5. Fluid Movement Loqs [Water Flow Loq (WFL) and Temperature Log] On April 8, 2002, a Schlumberger Reservoir Saturation Tool Water Flow Log (WFL) and a temperature log were run. The purpose of these logs was to detect movement of any fluids in vertical channels adjacent to the wellbore and to determine that the confining zone is not fractured. These logs were conducted with an injection pressure of 1300 psi. This was the maximum continuous injection pressure observed during the last six months. The injection rate was 3.8 barrels of seawater per minute. The WFL bombards water with neutrons and detects gamma rays from the resulting interactions. The tool has a neutron generator and three gamma ray detectors. For this job, the tool was configured to detect the upward movement of water. The neutron generator was placed below the three gamma ray detectors. To detect the movement of water behind pipe, the tool is positioned at the desired depth and the neutron generator is turned on briefly. If there is upward movement of water (e.g. channels behind the casing), the gamma ray detectors see the energized water as it moves up past them. Seven WFL stops were made in NS10. The depths were 7950', 7900' 7850', 6050', 5000', 4950' and 4900'. The casing shoe in this open hole completion is at 8029' and the packer is set at 5015'. No water movement was detected at any of the seven stops. This indicates the water is all staying well within the permitted injection interval. The temperature log is used to determine which intervals are receiving water injection. Intervals that have water being injected into them experience more cooling than intervals that simply have water being injected down the tubing past them. A baseline temperature log was recorded after iniecting 493 barrels of 41 °F seawater. A second temperature pass (warm-back pass) was made two and one half hours later. Both the baseline and warm-back passes showed a dramatic inflection in temperature gradient at +7960' MD. Above this depth the temperature is increasing +0.01 °F per foot of measured depth. Below this depth the temperature is declining +0.05 °F per foot of measured depth, This indicates a majority of the fluid is entering the interval at or below _+7960' MD. The results are summarized in the plot shown below. NS10 Temperature Log 04-08-2002 Warmback Pass -- Baseline 85 8O t21 ~ 65 ::::::: , ~.~'""~'"¢'-~nt top of fM~ entry I 45 : 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 Depth, MD The WFL/Temperature log (Schlumberger RST WFL-Up Flow Mode Pressure- Temperature) is attachment 6 and the well service report for this work is included in attachment 5. Tubinq Inspection Caliper Lop ProActive Diagnostic Services (PDS) was retained to provide a 1-I 1/16", 24 finger memory caliper tool and interpretation of the results. This tool was run on Schlumberger slickline from the tubing tail back to surface. This tool digitally records diameter, which is used to determine pipe thickness, and hence metal toss, This log indicates the tubing is in good to fair condition with penetrations of less than 20% recorded in the majority of the tubing with intermittent penetrations of 20% to 40% of wall thickness. The detailed report from PDS is attachment 7 and the well service report for this work is included in attachment 5. Attachment 1 · TREE:ABB-VGI 5 1/8" 5ksi NS 1 0 WELLHEAD:ABB-VGI 11" 20", 169# X-56 @ 199' MD L-80, BTC @3726' MD 4.5", 12.6#/ft, L-80, IBT-MOD TUBING ID: 3.958" CAPACITY: 0.015 BBL/FT 4.5" 'XN' NIPPLE, @ 7994' 6294' TVD 3.725" ID (OTIS) 7 5/8", 29.7#/ft L-80, BTC-M @8029'MD TD @8246' MD 6513' TVD ORIGINAL RT ELEV = 55.77' RT/CB. ELEV = 40.2' CB/MSL ELEV = 15.57' Nipple @ 2033' MD 1994' TVD 3.813" ID Heat Trace @ 2318' MD Baker S3 PACKER 3.875"1D @5015' MD 4023' TVD 4.5" WLEG, @8006' MD 3/4" open hole DATE REV. BY COMMENTS Northstar 1/11/01 AGK Initial Diagram 9/10/01 EMF Inserted TVD Depths APl NO; 50-029-22985-00 BP Exploration (Alaska) Attachment 2 NS 10 Log Section BP Exploration Short Well Name: NS10 .W Name: kPl: 500292298500 Spud Date: 14-Dec-2000 ~ole Angle: 3perator:. BPX Measurement REP.. KB Ref. Elevation: 55.77 Latitude: 70.490995 Longitude: -148.693284 Depth Range: -50'-'- o .............. x, ~ ~ ~ GR LLD RiIOB 0 GAPI 150 0.2 OH~ 2000 1.6b G/C3 2.65 : : 3453.1 -29564 3600 ....... · . : : · . . -'~ ~--: 3700 O ' ': '~~:~ ~ ~ ~~~~~:' :' ~ =======?= === ================================:: :~::::::::::: :::~:: 4000 -3300" '~':'~.~ -3400 -- ~----:'- '" "' sv5 · : ~: ..~_ ..;.::.. :: -.:.-:.-...: :.:. ~:'.'~. ]~-35oo ~" ::':~ "' ·: : ..... JL_.. ~-::: .---.," ~ . · :::::::::::::::::::::::::::::::: ~oo -:~oo - ~oo -37oo ' _...., ~ ~ :::~:.::~.~::L~: L.:.~: ~oo -~oo ~:.~ 7~-.~~:,: ....... .". .--~-" .... : ~--: ~.~ ~ .... : -- .... ' .... ~-'"i .~~~.~:~: :: :.~: ~:::.?: .oo - ~ ~---~~ ......... ~-.. ~. '~: :~ : ':' ........... ssoo :::: 2 ....... ~___:~ .... :- ..... 2----.~ _,oo.:....-::._._:.~{__::., __:,_. :___.~ -~oo ~ .-~ ?_ .=~._.___:: ....... , __ ~__.. SVl ... ==================================./.':~ 5~OO~ooo -~oo ' "":~ ~ .... ~: '"'" -'---;"~ --¢-" ~':'.':..=: ....... :: .o; .. ~ ~ ;~j ~ ~;;:;: .oo ~oo ~:::' :'~~--' ....... .:-'7 ..... ' '~::':::'"':' :":::":"::~::::'~::--::o~- ~oo ~":' : ' ~ .:: :: ~oo _~,oo :: ~ 6800 ~.~~~~:::::::: &---~--f' : .... : ........... . ~ .~ .......... ~ -- _: :::.::::::..: :OoO° .---~ '--'TL ........... -~oo-~: ~- '~' :'' .......... ' 7300 ~ _ -. ~ ..~ ~~ .oo _~oo~~:: ~~'--'~'~ ~~ ~= ........ ~--+--':,~~~ ~----~ :::::: ::: ~~"' .. . ~ :: ...... ~ ; ~.:, . . :::::: '::::::::; 77oo -6000 :::::::::' ~ ---'""J '~ ........... ~ ..... : ::~:~ : :~ . .:,. ~_. -., :::..~ ~ ~,:.'.. ,:.: ..:.. ~,oo: _~2oo :::::: :::.:::~+;'~'q .--.----' ~ : ': :'" ::: * / ......... '~-' ~ ...... '-' ~oo -~oo..:~ ..~..~:~ ~ ~=..:~ -..i ___ .....:~.... :.. ~. :.;: ~ . I " : : ': : ,' "; ' ' 'r :: , ': · 8246.0 ~.2 ,- ' "" 'illi' ':" ~ ~ j ' ~ - : , : ' { : ''" : ' :: : ' ' r , Attachment 3 MIT Test Results STA'! )F ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Tes! E-Mail to: Tom_Maunder@ admin.state.ak.us and Bob_Fleckenstein @ admin.state.ak.us OPERATOR: BP Exploration, (Alaska) Inc. FIELD / UNIT / PAD: Northsta/ DATE: 4/7/2002 NUMBER TBG TYPE WELL FIINuJID FLUID NUMBER PTD: 2001820 Diesel Well #: NS-10 SW COMMENTS: Annual MITIA, Class 1 disposal well PACKER TVD MD 4,023 CASING SIZE I WT ! GRADE 5,015 7-5/8"/29.7#/L-80 ITBG I REQ TEST PRESS 3,500 PREI~ST TBG CSG PRESS 7OO START TIME TBG CSG PRESS 622 3,550 15 MIN;:iii:~:::::.:30:MIN :: i TIME : TIME: : :' TBG :::::~::::::YB:G:: : :sTART CSG .:::::: : TIME: PRESS::::' ::::.PRESS 609 602 3,510 3,500 16:12 PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: I I II II I I I I TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: orig- Well File c - Operator c- Database c - Trip Rpt File c- Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 0.00 0.00 0.00 OPERATOR REP SIGNATURE: Tyler Norene , AOGCC REP SIGNATURE: MIT NS-lO 04-07-02.x:ls WELL TEST: Initial 4 - Year Workover Other XX Taiib Syed, P.E. (EPA) (Rev 9/23/99) Attachment 4 MIT Test Chart Y44 Attachment 5 Well Service Reports WELL SERVI'CE REPO, (' Page 1 of 1 F ~iELL 'lOB SCOPE UNIT .... S'10 WATERFLOW LOG UNKNOWN bATE DAILY WORK DAY SUPV 4/7/2002 AC-MITIA ANDERS AFL KEY PERSON NIGHT SUPV NW2101 VEC-JOHNSON MIN ID I DEPTH 'ITL SIZE 0"I OFT 0" DALLY SUMMARY MITIA PASSED to 3500 psi {EPA witnessed) Init Tbg, IA, OA->I 7001 01 01 TIME I COMMENT 08:301T/I/O = 700/VAC/0 MITIA to 3500 psi PASSED (EPA witnessed); initial IA FL at 40' (1 bbl). Installed chart recorder. I Pressured IA to 3500 psi and test lost 40 psi in the first 15 mins and 10 psi in the second 15 mins for a total of 50 I psi in 30 mins. Pum,p, ed 4 bbls of diesel total down the IA. R/D chart recorder and bled IA to 0 psi. Operator started iniection Final WHP s = 650/0/0 FinaITbg~ lAy OA->I 6501 o FLUID SUMMARY SERVICE COMPANY-SERVICE DAILY COST CUMUL TOTAL SCHLUMBERGER .... $0 ..... $31938 UNKNOWN ........................................ $'~301' $100 VECO ....... $650i .................. TOTAL FIELD ESTIMATE: $750 $5 288 .../wellevent_awgs.asp?]~=B33C6002BD7248C88D0244E5602C7A8ClO2C5856CDC7049FC94C41]~4/10/2002 WELL SERVI'CE REPO , (" Page 1 of 1 I WELL JOB SCOPE UNIT NS-lO WATERFLOW LOG SWS NS DATE DAILY WORK DAY SUPV 4/7/2002 DRIFT/TAG NORENE AFE KEY PERSON NIGHT SUPV NW2101 SWS-SEAVEY MIN ID I DEPTH TTL SIZE 2.65"1 2033 FT 4.5" DAILY SUMMARY DRIFT TBG AND TAG PBTD @ 8009' SLM W/2.20" CENT (HARD TAG). ESTIMATE TRUE PBTD TO BE 8049' MD WITH 40' RKB CORRECTION ADDED. NOTE: DID NOT RUN TEL - EOT, TOO CLOSE TO TM. NOTIFY OPERATIONS OF STATUS -DHD REP TO MITIA~ THEN WELL CAN BE POI. InitTb~l, IA, OA->I 8281 o l o l ,TIME I COMMENT 08:301TBSM W/SWS, BP REP, CRANE OPER, DSO. ii bDiii60 I'"BB~iN RIG UP OF LUB AND BoP'S. ' i0i101 PT BOP'S WITH INSERTS CLOSED TO 2500 PSI. TEST LUB TO 300 PSI LOW & 2500 PSI HIGH. 11:221RIH W/1 3/4 TS, JARS, LSS, 2.2 CENT, 8' oF 1 1/2 STEM & 2" BULL_N, OSE ' '12:2i I TAG pBTD @ 8009' SiM (ESTIMATE ~RUE pBgC) TO BE 8034' W/25 RKB CORRECTION ADDED). POOH. ".11_13:2.41ATSO'~'~ACE: ~D SLICKLINE UNIT AND ASSIST MHD WITH MiTIA: Final Tbg, IA, OA:~I ............... 8 6"'l .... Ol ....O l .......................................................................................... I FLUID SUMMARY 11 BBLS DIESEL FOR PT DALLY COST I CUMUL TOTAL ISERVICE COMPANY - SERVICE SCHLUMBERGER JNKNOWN $3,9381 $3,938 $0 $100 IVECO I $ol .../wellevent_awgs.asp?ID= 1849A59EE9464EFC9E 1859D3FEOBEC 1710C8E2407FFA540EDA81 FEI4/10/2002 ~ Page 1 of 1 WELL SERVICE REPOi , I w=,, sco. I NS-10 sws 2 so DATE DALLY WORK DAY SUPV 4/8/2002 CHANNEL DETECTION LOG--BORAX LOG NORENE AFL KEY PERSON NIGHT SUPV NW2101 SWS-DECKERT MIN ID I DEPTH TTL SIZE 2.65"1 2033 FT 4.5" DALLY SUMMARY PERFORMED RST WATERFLOW STOPS WHILE INJECTING 41 DEGF SEA WATER @ 3.8 BPM, WHP 1340 PSI. WFL STOP DEPTHS @ 7950', 7900', 7850', 6050', 5000', 4950', & 4900'. LOG TEMPERATURE & PRESSURE PASSES FROM 4850-8015 @ 30 FPM. START OF BASELINE AND START OF PASS .TWO (150 MINUTES APART). PERFORMED STOP COUNTS @ 8000' AFTER EACH PASS DOWN. FOUND NO INDICATION OF UPWARD FLOW OR TEMP ANOMALIES IN CASING/TUBING. WITNESSED BY EPA REP (TALIB SYED). WELL RETURNED TO OPS FOR INJECTION. Init Tb~l, IA, OA->I 9501 21 01 i COMMENT l,_ 07:29 ... 10;..1......01 11:131 ! i 15i ', I'ii 15:55 l !6;1i110 116:20 116:25 116:30 I'" i6i~'0 16:41 16:55 .. 17:08 ... 17:10 17:25 ,,. 17:32 , 17:40 17:44 .. 17:55 18:05 18:10 20:00 20:06 20:40 22:30 . 22:45 WAIT ON CONSTRUCTION TO MOVE CRANE AND ADJUST RIG MATS. HOLD TBSM W/CO REP, CRANE OPER, SWS PERSONNEL, G & I OPER. BEGIN R/U. :RIH HEAT SOCK, ~FLO-.T..UBES~,.GRE...ASE. SKI.D, COMPRESSOR,, ETC. (IN PROGRESS) TEST WIRELINE VALVES (BO .P..'S) TO 300 PSI LOW / 3000 PSI HIGH. R/U LUB AND TEST TO SAME. RIH WITH RST/PRESS/TEMP, TOOLS 39'X 2.125" OD. PERFORM WEE RIH @80 FPM TOOL CHECK. START INJECTING SEAW.ATER..@3~.76 B..PM, WHP 1260 PSI, FLUID TEMP 41 DEGF, IA 0. 3.78 BPM, WHP 1315 PSI, 59 BBLS AWAY, IA 0 . CORRELATE @EOT PERFORM RST WFL STOP @7950', INJ 3.8 BPM DOWN TUBING 3.8 BPM, WHP 1308, 113 BBLS AWAY, IA 0 PERFORM RST WFL STOP @7900', INJ 3.8 BPM DOWN TUBING 3:~ BPMi WH.p i325; i~0 BBLS ~WAYi iA 0 PERFORM RST WFL STOP @7850', INJ 3.8 BPM DOWN TUBING, SW 41 DEGF 3.8 BPM, WHP 1329, 227 BBLS AWAY, IA 0 PERFORM RST WEE STOP @ 6050', INJ...3.8 BPM DOWN. TUBING 3.8 BPM, WHP 1340, 284 BBLS AWAY, IA 0 3.8 BPM, WH.P 1340, 340 BBLS AWAY, IA 0 . PERFORM RST WEE STOP @5000', INJ 3.8 BPM DOWN TUBING 3.8 BPM, WHp 1349, 397 BBLS AWAY, IA 0 PERFORM RST WFL STOP @4950, INJ 3.8 BPM DOWN TUBING PERFORM RST WFL STOP @4900', 3.8 BPM, WHP 1341,456 BB.LS AWAY. SHUT DOWN PUMP, 493 BBLS SEA WATER 41 DEGF PUMPED. COMPLETED RST STOPS LOG DOWN 30 FPM BASE TEMP FROM 4900-EOT STOP DOWN PASS, PERFORM PRESS/TEMP STOP @8000', PRESS=3906, TEMP 73.8 PUH @120 FPM TO 4800' LOG DOWN 30 FPM PASS 2 TEMP FROM 4900-EOT STOP DOWN PASS, PERFOFI. MPRESS/TEMP STOP @8000', PRESS=3756, TEMP=80.6 POOH 23:30 OOH .................... Final. Y'bg, FLUID SUMMARY 2 BBLS OF DIESEL FOR PT 493 BBLS SEA WATER SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL sCFiLuMBERGER ................... i ....... 'ii i : ' $i 0;~1'i"~" "i ....... i" "iii'.,. ..... UNKNOW.N ..................... $0 ..... $100. VECO $0 $1,250 TOTAL FIELD ESTIMATE: $10,915 $16,203 .../wellevent_awgs.asp?ID=EF73DOCBF9C3499C8115E521CD3C5C7CIDBEA90718431499D8B 1 E54/10/2002 WELL SERVI'CE REPOI~. Page 1 of 1 WELL JOB SCOPE UNIT NS-10 w^-r~.~,ow ,o~ sws us o^,t ~^~[¥ wo.~ o^v su.v 4/9/2002 CALIPER TUBING "ORENE AFL KEY PERSON NIGHT SUPV NW2101 SWS-SEAVEY MIN ID I DEPTH TTL SIZE 2.65"1 2033 FT 4.5" DALLY SUMMARY RUN PDS CALIPER IN 4 1/2" TBG FROM -Ir @ 8006' MD TO SURFACE. GOOD DATA. R/D SLICKLINE UNIT AND RETURN WELL TO OPS FOR INJECTION. InitTb~!,IA, OA->I 95ol o l o l TIME ]COMMENT i... 09i241 BEGIN TO...SPO..'I' E.QUIPMEN!, LUB, AND SLICKLINE UNIT. 10:261 STOP & HOLD TBSM W/CO REP, PDS, CRANE OPER, DSO, & SWS CREW. WIND OVER 20 MPH GUSTING TO 24 MPH - WAIVER SIGNED BY CO REP. DISCOVER THAT NEEDLE VALVE ON BOP'S SHEARED OFF -- LOCATE EASY OUT AND REPLACE NEEDLE VALVE. 12:291 TEST LUB LOW TO 300 PSI / HIGH TO 3000 PSI (BOP'S TESTED 4/7). 12:451RIH WITH I 3/4" TS~ JARS, LSS~ & 1 11/16" PDS CALIPER TOTT @ 8006' MD. 13i1361 POOH W/CALIPER'AT 55 FPM. ' ......... !6;.361 AT SURFACE W/CALIPER (WAIT TO CLOSE), AND BEGIN R/D 17:0~ I P.!?~ S.~S..i.'..G00D DATA". COMPLETE R/D. Final Tbg, IA, OA->I ...... I ........... ! ........... I FLUID SUMMARY I 1 BBL DIESEL FOR PT ISAFETY NOTES OPERATIONS LEAVES FUSIBLE ON WELL. SERVICE COMPANY- SERVICE DAILY COST CUMUL TOTAL .SCHLUMBERGER i ..... ' ............. . ....................... $4,494! ' ......... . $19,347 UNKNOWN $0 $100 ..ViE'C0 i ........... i..iiiiiii ........... iiiiiiiiii ........... ii.....iii ............. i.i.iiii .............. i.i.iii_ ............. iiiiiii .................................................................. ii .............. i.i.". ...... i.'i ........... ". .............. i ........... '-i.i ................ i ........................ $0.. i ........................................................... $.!..,.2.5...0 TOTAL FIELD ESTIMATE: $4~494 $20,697 .../wellevent_awgs.asp?ID=ECE789BD3A7646709CE2742E340ED2211B8FF6294BCEF4321 A936D(4/10/2002 Attachment 6 Schlumberger RST WFL-Up Flow Mode Pressure-Temperature Log recorded April 8, 2002 Attachment 7 PDS - Memory Multi-Finger Caliper Log Results Summary bp Date: 05-4-2001 Transmittal Number:92090 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type ~S10 02-14-2001 SPERRY - - END OF WELL REPORT; NS10 02-14-2001 SPERRY 1,2,3 100.00 ,6550 MUDLOG; (COLOR) 1:600 MD; iNS10 02-14-2001 SPERRY 1,2,3 100.00 6550 MUDLOG; (COLOR) 1:600 TVD; NS10 02-14-2001 SPERRY 1,2,3 100.00 6550 MUDLOG; (SEPIA) 1:600; ~1S10 02-14-2001 SPERRY 1,2,3 100.00 6550 MUDLOG DATA (DISKETTE 1 EA) >~S10 02-14-2001 SPERRY 1,2,3 100.00 6550 MUDLOG; (COLOR) 1:240 MD; :~!~10 02-14-2001 SPERRY 1,2,3 .100.00 6550 MUDLOG; (COLOR) 1:240TVD; Please Sign'and Retum one ~copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc Attn: Buford Bates DNR Attn: Doug Choromanski RECEIVED . omge Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned ~1 Service Class I Waste Disposal Well 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 200-182 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22985-00 __ I , I I ,, 4. Location of well at surface r~ ..... '. ................. : LOC.,~'i1Of~ 9. Unit or Lease Name 1139' FSL, 643' FEL, Sec. 11, T13N, R13E, UM "c'0~' ."L:':'.':?',: :. V~ Northstar Unit At top of productive interval 2845' SNL, 2223' FEL, Sec 14, T13N, R13E, UM ---!-~-/-~.-'*'~' "* I ,.: .... .,., : , .~ 10. Well Number At total depth .,~ I NS10 '~~,,~.: ~ '..]. 2952' SNL, 2263' FEL, Sec 14, T13N, R13E, UM ................. · ,- ...... ,. ~,,.T,~. 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Northstar Unit KBE = 55.77 ADL 312808 12. Date Spudded12/14/2000 113' Date T'D' Reached 114' Date C°mp"-~S-'usp" °-Ir Aband' 115' Water depth' if °fish°re 116' N°' °f C°mpleti°nsl/6/2001 1/,~512001 ~l,' 39' MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey ~ 20. Depth where SSSV set121. Thickness of Permafrost 8246 6513 FTI 8246 6513 FTI [] Yes [] NoI (Nipple) 2033' MDI 1545' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, CNL, DEN, USIT, Sonic 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 169# X-56 Surface 199' Driven None 10-3/4" 45.5# L-80 45' 3726' 13-1/2" 1511 sx PF 'E', 350 sx Class 'G' 7-5/8" 29.7# L-80 43' 8029' 9-7/8" 1057 SX 'G', 314 Sx Silicalite 'G', 570 sx PF 'E' 24. Perforations op. en tq Producti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and intervak size eno numDer~ SIZE DEPTH SET (MD) PACKER SET (MD) 6-3/4" Open Hole 4-1/2", 12.6#, L-80 8007' 5015' MD TVD MD TVD 8029' - 8246' 6325' - 6513' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' (APprox.) Freeze Protect with 63 Bbls of Diesel 27, PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ' January 24, 2001 Other (explain) - Class I Waste Disposal Well Date of Test Hours Tested PRODUCTION FOR OIL-UaL GAs-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. uR, ECEiVE D MAY 1,0 2001 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. SV6 3504' 3045' SV5 "3909' 3315' SV4 4382' 3620' SV3 - 4750' 3852' $V2 - 5007' 4017' SV1 -, 5602' 4403' TMBK - 6140' 4759' Ugnu 3 ' 6816' 5246' Ugnu 1 '- 7408' 5768' Schrader Bluff " 8015' 6312' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys :32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e,,.'~,~./~j~.~_-~'~ ~ ~ Title TechnicalAssistant Date NS 10 200-182 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAl.: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 ANr~ 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM27: Method of Operation: Flowing, GasLift, Rod Pump, Hydraulic Pump, Submersible, Waterlnjection, Gaslnjection,~~EI~ED. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL MAY 1., 0 ZOO 1 · . Alaska 0il & Gas Cons. Commission Anchorage .... , .... "" ~',";",'",:,,,":?::,!',',?,,, I!i',,,,' ,;;1,,,,!,:i,', :l,::;:!',,',l::H'i,il:l,!,,l:,';li,;,I,i;,',,,,:,,,,,",,," ,',,'i' ,',, ",,, , ' ,'"' ;,"',,,,";,'," :,':!,,' I' ,, ,1,,I,,,'~ ' , Legal Name: NS10 Common Name: NS10 "'" '. '?:TeSt.iType....; =;'; ""i::i.i':' ::'"'"""'"';%: '" '"'"':' '":":'"' "'"" ?''':" ":' :' "' ' ...... '"" ............ ...... Te .st.Date""'" :' '" .... '"" '" ....... , . . '. Te~t.,.~ th':(TMI3) .. i?!::i:.i,:::..:.Te~t..De~.~:(:WD)...'" :." ~ AMW..'.. : SUrface Pressure Leak Off Pressure (BHP) EMW I~I; 12/25/2000 LOT 3,726.0 (fi) 3,192.0 (fi) 9.30 (ppg) 730 (psi) 2,272 (psi) 13.70 (ppg) 1/6/2001 LOT 8,029.0 (ft) 6,325.0 (ft) 9.30 (ppg) 770 (psi) 3,826 (psi) 11.64 (ppg) i Printed: 511/2001 1:41:36 PM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12114/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Date From-To Hours Task Code Phase Description of. Operations 11211312000 00:00 - 00:30 0.50 RIGU PRE Pre-Spud Meeting. Accepted Rig ~ 0001hrs on 12/13/00. 00:30 - 03:30 3.00 RIGU PRE . Strap Block Height for Anadril, RU and Blow Air thru Mudline and Top :Drive. Pressure test with sea water to 700 psi - OK. Swivel Packing I leaked at 1500 psi. Blow down Top Drive and Mud Lines. 03:30 - 04:30 1.00 RIGU TDRV PRE PJSM -- Develop procedure and perform hazard risk mitigation to change out swivel packing. 04:30 - 05:30 1.00 RIGU TDRV PRE Change out Swivel Packing and Test -- Still Leaking. Blow down. 05:30 - 10:30 5.00 RIGU TDRV PRE Repair packing, reinstall, grease and rotate top drive. Pressure test mud system to 3100 psi -- OK. 10:30 - 11:30 1.00 RIGU PRE PU Stand of 5" dp and RIH -- tag at 64' in. Break Circ. Fluid leaking past knife valve -- detected immediately thru bull plug port. Blow down top drive. 11:30 - 12:00 0.50 RIGU OTHR PRE Drain fluid from diverter line and stack thru bull plug port in diverter line. 12:00 - 13:00 1.00 RIGU OTHR PRE Continue draining fluids from diverter and stack and check knife valve -- OK. 13:00 - 17:30 4.50 RIGU PRE MU 1 stand of collars and stand back. Continue MU bha and tag up at 64'. 17:30 - 21:00 3.50 RIGU PRE Testing Program Logic Control in SCR Room -- Defects detected and corrected. Working on the 3 way switch in pipe shed - accidently cut wire. Necessary to isolate and repair wire. Attempt to function test switches on 3 Way - unable to backfeed power into G&I. Steam line frozen in cuttings tank -- thawing line. Blow down steam line in sub and replace leaky valve. 21:00 - 00:00 3.00 RIGU OTHR PRE Thawing the frozen steam line in the cuttings tank. Cleaning and organizing rig. 12/14/2000 00:00 - 03:00 3.00 RIGU OTHR PRE Thawing steam line on cutting box. Circulate sea water through shaker room hoses. Clean old mud our of centrifuges. 03:00 - 07:00 4.00 RIGU PRE Peformed Derrick Inspection from Crown to Substructure - No Problems Noted. 07:00 - 08:00 1.00 RIGU PRE Work on Centrifuge #1, Replace 2" Valve in Pits and perform general house keeping. 08:00 - 09:00 1.00 RIGU PRE Conduct D3 Drill - Discuss Spud and Waste Handling with all AIC and Drilling personnel. 09:00 - 10:00 1.00 RIGU PRE Break Circulation and test shakers while pumping 400 to 700 gpm -- Shakers handling flowrate just great. 10:00 - 11:30 1.50 RIGU PRE Tag Ice at 64' and ream down to bottom of 20" conductor at 199' md -- 30 rpm, 900 fi-lb, 600 gpm @ 625 psi. 11:30 - 13:00 1.50 RIGU PRE Drlg f/199'-211' -- 5' fill. Circulate different rate fl400gpm to 720 gpm - fill still present. Decision to drill ahead another stand of 5" at 550 gpm. 13:00 - 14:00 1.00 RIGU PRE Drlg f/211'-300' @ 550 gpm. 14:00 - 14:30 0.50 RIGU PRE MU BH^ & MWD. On the Job Training Floorhands. Rearranged stabilizers. 14:30 - 18:00 3.50 RIGU PRE MU BHA & MWD. Rearranged stabilizers. 18:00 - 00:00 6.00 RIGU PRE Drlg f/300' to 672' at 550 gpm - no fill on connections. Waste Handling is going well. 12/15/2000 00:00 - 12:00 12.00 DRILL SURF Drill from 672' to 1383'. 12:00 - 22:30 10.50 DRILL SURF Drill from 1383' to 2230'. 22:30 - 23:00 0.50 DRILL SURF D3 diverter drill. Printed: 1/2612001 4:36:14PM ,, BP EXPLORATION Page 3 of 10 Operations Summa Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: . . .. Sub Date From - To Hours Task Code Phase · Description of Operations 12/15/2ooo 23:00 - oo:oo 1.oo DRILL SURF Drill from 2230' to 2328'. 12/16/2000 00:00 - 03:00 3.00 DRILL SURF Drill from 2318' to 2518'. 03:00 - 04:30 1.50 DRILL ClRC SURF Change out swab, inspect liner on # 2 pump. 04:30 - 07:30 3.00, DRILL SURF Drill from 2518' to 2800'. 07:30 - 09:30 2.00 DRILL SURF Circulate hole clean, monitor well, pump dry job, blow down top drive. 09:30 - 11:30 2.00 DRILL SURF Short trip from 2800' to 187'. Hole looks good. Hole fill okay. 11:30- 12:00 0.50 DRILL SURF Run in hole from 187' to 1385'. Looks good. 12:00 - 14:00 2.00 DRILL SURF Run in hole from 1386' to 2803'. Ream last stan to bottom. 14:00 - 15:00 1.00 DRILL SURF Wash down last stand. 15:00 - 00:00 9.00 DRILL I SURF i Drill from 2800' to 3557'. 12/17/2000 00:00 - 05:00 5.00 DRILL SURF ~Drlg f/3557' to 3742' TD. 05:00 - 07:00 2.00 DRILL SURF Cir¢ 15 bbl hi-vis sweep & cond mud - dry job 07:00 - 10:00 3.00 DRILL SURF Perform Wiper Trip f/3742' to 728' -- hole in good condition. 10:00 - 11:00 1.00 DRILL SURF Service Top Drive and Clear Rig Floor. 11:00 - 12:30 1.50 DRILL SURF RIH from 728' to 3742' -- hole in good condition. 12:30 - 15:45 3.25 DRILL SURF Circ and Cond Mud for logging/casing -- 2xBU 15:45 - 18:30 2.75 DRILL SURF POOH for logging/casing -- @ BHA. 18:30 - 19:30 1.00 DRILL SURF Lost Fuel Gas to Rig - Island Power Outage. 19:30 - 23:30 4.00 DRILL SURF Lay Down BHA 23:30 - 00:00 0.50 DRILL SURF Clear rig floor in preparation to Wireline Log Surface Hole. 12/18/2000 00:00 - 00:30 0.50 DRILL SURF Clear rig floor after POOH with BHA. 00:30 - 01:30 1.00 DRILL SURF RU Wireline Unit. 01:30 - 10:30 9.00 DRILL OTHR SURF Test Wireline Tools -- Failed test. Trouble shooting: Identified faulty switch in wireline unit. Repaired. Scrapped logging run. 10:30 - 11:30 1.00 DRILL SURF RD wireline unit and tools. 11:30 - 12:00 0.50 DRILL SURF Hang Blocks and Top Drive --Adjust Brakes and Service Drawworks. 12:00 - 14:00 2.00 DRILL SURF Finish Rigging Down Wireline and Move Unit to provide access to the Tool Slide. 14:00 - 17:30 3.50 CASE SURF RU Casing Running Tools and Equipment. 17:30 - 18:30 1.00 CASE SURF Repair Casing Stabbing Board. 18:30 - 00:00 5.50 CASE SURF PJM -- MU shoe track, circulate and continue RIH with casing, 12/19/2000 00:00 - 02:00 2.00 CASE SURF Finish running 10 3/4 Surface casing. Ran total of 3681', (89 its) of 45.5 PPF, L-80, Buttress. 02:00 - 03:30 1.50 CASE SURF R/U 10 3/4 Hanger and land casing. Shoe at 3726. R/D fill up tool and blow down Top Drive. R/U Cement Head. 03:30 - 09:00 5.50 CASE SURF Cir¢ and Condition mud. Slowly break circulation and bring pump rate to 12 BPM. Had cement pre job safety meeting on rig floor. 09:00 - 10:00 1.00 CASE SURF Pump 10 bbls sea water ahead. Drop bottom plug. Reload cementing head with top plug. Test lines to 3,500 PSI. 10:00 - 11:00 1.00 CASE SURF Mix and pump 10.5 PPG Alpha spacer with 10 gallons of 434B. Mix and pump Lead Cememt, 118 bbls, (305 sks) of E Permafrost cement at 12 PPG. Mix and pump Tail cement 71 bbls, (350 sks) Premium with 2 % CaCl2 and .15 Ibs/sk of Super CBL at 15.8 PPG. Drop Bottom Plug. Pump 25 bbls sea water behind. Displace with 325 bbls of mud with rig pumps. Bump plug with 1000 PSI. Float equip ok. 11:00 - 11:30 0.50 CASE SURF Load closing plug. Open ES cementer with 2400 PSI. 11:30 - 16:00 4.50 CASE SURF Circulate and Condition Mud and WOC. Had pre-job cement safety meeting on rig floor. 16:00 - 18:30 2.50 CASE SURF Pump 10 bbls sea water ahead. Pump 75 bbls Alpha spacer at 10.5 PPG with 10 gal 434 B. Mix and pump 466 bbls, (1206 sks) of Permafrost E cement at 12 PPG. Drop plug. Pump 25 bbls sea water behind. Displace with 130 bbls of mud with rig pumps. Bump plug with 1100 PSI. Close cementer with 1500 PSI, Check for flow. OK. Printed: 1/26/2001 4:36:14PM BP EXPLORATION Page 4 of 10 Operations Summa Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Date From-To HOurs Task COde Phase Description of Operations 12/19/2000 18:30 - 23:00 4.50 CASE SURF R/D cement head, remove landing joint, clear floor. 23:00 - 00:00 1.00 CASE SURF Develop procedure to nipple down diveter and annular. 12/20/2000 00:00 - 08:00 8.00 BOPSUF INT1 L/D mouse hole. N/D riser, bell nipple, annular preventer and diverter line. 08:00 - 09:30 1.50 BOPSUF INT1 N/U Vetco Gray 11" Casing spool and test to 1000 PSI. 09:30 - 00:00 14.50 BOPSUF INT1 N/U DSA, spacer spool and 13 5/8 BOP's. 12/21/2000 01:30 - 12:00 10.50 BOPSUF INT1 Finish Nippling up BOP's and choke and kill lines. Modify kill line. Stab riser. Connect Koomey lines to BOP's. 12:00 - 00:00 12.00 BOPSUI~ INT1 Bolt riser on to drip pan. Calibrate gas alarms. Lengthen Koomey hose 'for kill side HCR. Continue to connect Koomey lines to BOP's. 12/22/2000 00:00 - 02:00 2.00 BOPSUI~ INT1 . Function test BOP's. Change Koomey lines on choke and kill HCR's. i Run Test Plug and fill stack and pump through choke manifold with water. 02:00 - 03:30 1.50 BOPSUI~ INT1 Test Annular. Re-torque DSA on Stack and re-tighten uni bolt on kill line. i03:30 - 10:30 7.00 BOPSUI~ INT1 Test BOP's and Choke Manifold as per BP Policy with AOGGC representative. 10:30 - 15:30 5.00 BOPSUI:; INT1 Test standpipe. Upper hammer union o-ring failed. Loosen standpipe clamps. Raise standpipe and change o-ring. Test S.P. to 5000 PSI 15:30 - 18:00 2.50 BoPSUI; INT1 Blow down S.P. Pull test plug. Install wear ring. 18:00 - 23:00 5.00 DRILL INT1 Make up BHA. Pick up 4" DP and RIH to 1578. 23:00 - 00:00 1.00 DRILL INT1 Make up stand of 5' DP. Circ BU 12/23/2000 00:00 - 01:00 1.00 DRILL INT1 RIH to ES Cementer at 1614. Test casing to 500 PSI. OK. Drilll ES Cementer. Test casing to 500 PSI. OK. 01:00 - 11:00 10.00 DRILL INT1 RIH with 4" DP from pipe shed. Tagged cement at 3278. Stand back 13 stands of 4" DP. RIH with 4" DP from pipe shed. 11:00 - 15:00 4.00 DRILL INT1 Drill Cement to Landing Collar to 3639. Drill Cement to 3670. 15:00 - 18:00 3.00 DRILL INT1 Circulate and condition mud. 18:00-22:00 4.00 DRILL INT1 POH. 22:00 - 00:00 2.00 DRILL INT1 R/U Schlumberger wireline to run USlT log. 12/24/2000 00:00 - 04:30 4.50 DRILL INT1 Ran Schlumberger USIT log. 04:30 - 05:30 1.00 DRILL INT1 R/D Schlumberger. 05:30 - 09:00 3.50 DRILL INT1 Re-route chokeline for BOP scaffling usage. Re-test to 5,000 PSI. 09:00 - 13:00 4.00 DRILL INT1 P/U BHA and RIH. 13:00 - 14:30 1.50 DRILL INT1 Had kick while tripping drill then Island evacuation drill. 14:30 - 16:00 1.50 DRILL INT1 Service Top Drive. 16:00 - 18:00 2.00 DRILL INT1 RIH to 3670 18:00 - 18:30 0.50 DRILL INT1 Circulate and condition mud. 18:30 - 19:30 1.00 DRILL INT1 Pressure test casing to 2500 PSI for 30 minutes. 19:30 - 20:30 1.00 DRILL OTHR INT1 Start D5 Drill. Choke line gauge not working. Repair choke line gauge. 20:30 - 00:00 3.50 DRILL INT1 Continue with D5 drill. 12/25/2000 00:00 - 05:00 5.00 DRILL INT1 Drilling cement @ 3671' md, Drlg FC @ 3681' md, Drlg Ceme~nt to FS ~ 3725' md. Note: Cement in shoe track drilled with 15 WOB. Drilled rathole plus 20' of new hole to 3764' md. 05:00 - 06:30 1.50 DRILL INT1 CBU and Condition Mud for Leak-Off Test. 06:30 - 08:00 1.50 DRILL INT1 Performed LOT -- 13.7 ppg EMW. John Spaulding with AOGCC onsite to witness Leak-Off Test. 08:00 - 00:00 16.00 DRILL INT1 Drill and slide from 3764 to 5336 12/26/2000 00:00 - 00:30 0.50 DRILL INT1 Drill and Slide f/5338'-5430'. Printed: 1/26/2001 4:36:14 PM BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub . Date From-To Hours Task Code Phase Description of Operations . .' 12/26/2000 00:30 - 01:00 0.50 DRILL PROC INT1 Unplanned Rig Power Shut down. Unplanned Activation of Emergency Gas Shut Off Valve. Crew reacted reasonably well. 01:00 - 12:30 11.50 DRILL INT1 Drlg f/5430'-6190'. 12:30 - 14:30 2.00 DRILL INT1 Circ and Condition hole for short trip. 14:30 - 00:00 9.50 DRILL INT1 POH. Pulled one stand and had tight hole and had to backream from 6100 to 4771. POH from 4771 to 4298. Had tight hole. Backream from 4298 to 3825. POH to shoe at 3726. Pull 4 more stands to pick up 12 singles of 4" DP and set back in derrick. 12/2712000 00:00 - 02:00 2.00 DRILL TDRV INT1 Repair Top Drive. 02:00 - 04:00 2.00 DRILL INT1 RIH with 12 joints of 4" DP and stand back in Derrick. 04:00 - 05:30 1.50 DRILL INT1 RIH with bit. No hole problems. 05:30 - 00:00 18.50 DRILL INT1 Drill and slide from 6190' to 7039'. 12/28/2000 00:00 - 04:00 4.00 DRILL INT1 Drill from 7039 to 7231 04:00 - 05:30 1.50 DRILL INT1 Circ Weighted and High Vis sweep. No excess cuttings on BU 05:30 - 08:00 2.50 DRILL , INT1 'Short trip 14 stands to 5904. No problems. 08:00 - 23:30 15.50 DRILL INT1 Drill from 7228 to 8044. 23:30 - 00:00 0.50 DRILL INT1 Pump weighted sweep and circulate. 12/29/2000 00:00 - 03:00 3.00 DRILL INT1 Circulate and Condition mud for short trip 03:00 - 06:00 3.00 DRILL INT1 Short trip from 8044 to shoe at 3726. No hole problems. 06:00 - 09:00 3.00 DRILL INT1 Slip and cut drill line. '09:00 - 12:00 3.00 DRILL INT1 RIH to bottom. No hole problems. 12:00 - 14:30 2.50 DRILL INT1 Circulate Hi Vis-Weighted sweep. Circ and condition mud. No excess cuttings on BU. 155 units gas on BU. 14:30 - 22:00 7.50 DRILL INT1 Drop Spery-Sun ESS. POH and SLM. No hole problems. ESS verified Anadrill survey information. 22:00 - 22:30 0.50 DRILL INT1 Clear and clean rig floor. 22:30 - 23:30 1.00 DRILL INT1 Rig up retrieving tool to pull wear ring. 23:30 - 00:00 0.50 DRILL INT1 Pull wear ring. Rig up to make dummy run with 7 5/8 casing hanger and check space out of 7 5/8 anding joint at flow line for 3rd stage cement job. 12130/2000 00:00 - 01:00 1.00 DRILL INT1 Finished dummy run with hanger and verified landing joint will back off one foot above flow line for third stage cement job. 01:00 - 01:30 0.50 DRILL INT1 Install wear ring. 01:30 - 09:00 7.50 DRILL INT1 Rig up for wire line logs. Run GR, Resistivity, Sonic, ND from 8044 to 3726. RiD Schlumberger. 09:00 - 12:30 3.50! DRILL INT1 Pull wear ring. Run test plug. Test Annular to 250 PSI Iow and 3500 PSI High. Test rams, manual valves, HCR's and choke manifold to 250 PSI Iow and 5,000 PSI high. John Spaulding with AOGCC gave dispensation to test BOP's on December 30 and waived witnessing test. 12:30 - 14:30 2.00 DRILL INT1 Repair leaks on BOP test hose. Repair leaks on choke line. 14:30 - 19:30 5.00 DRILL INT1 Finish testing BOP's. 19:30 - 21:00 1.50 DRILL INT1 Blow down kill line and choke manifold. Pull test plug and install wear ring. 21:00 - 22:00 1.00 DRILL INT1 Lay down BHA #3. 22:00 - 23:30 1.50 DRILL INT1 Make up BHA # 4. 23:30 - 00:00 0.50 DRILL INT1 RIH for Wiper Trip. 12/31/2000 00:00 - 02:00 2.00 DRILL INT1 RIH to 3570. 02:00 - 03:00 1.00 DRILL INT1 Circulate BU and condition mud. 03:00 - 05:00 2.00 DRILL INT1 RIH. Break circulation at 5180. RIH to 7930. Wash to bottom at 8044. 05:00 - 08:00 3.00 DRILL INT1 Circulate Weighted High Vis sweep. Circulate. 08:00 - 10:30 2.50 DRILL INT1 POH to 3570 in casing. Printed: 1126/2001 4:36:14 PM BP EXPLORATION Page 6 of 10 Operations Summa Report . . Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub PhaSe Description of Operations Date From-To Hours Task Code 12/31/2000 10:30 - 11:30 1.00 DRILL INT1 Adjust brakes and rollers on brake bands. 11:30 - 13:30 2.00 DRILL INT1 : POH. Lay down stabilizers. 13:30 - 14:00 0.50 DRILL INT1 Clear floor of tools. 14:00 - 15:00 1.00 DRILL INT1 Make up 4" HT TIW valve, pup joint and pump in sub. :15:00 - 18:00 3.00 DRILL INT1 Pull wear ring. Rig up to run 7 5/8 casing. !18:00 - 19:00 1.00 DRILL INT1 PJSM on running casing. 19:00- 21:00 2.00 DRILL OTHR INT1 Repair stabbing board winch. 21:00 - 21:30 0.50 DRILL ;INT1 Run 7 5/8, L-80, 29.7# Casing. Make up shoe joint, FC, one joint, LC and one joint. 21:30 - 22:00 0.50 DRILL INT1 Make up Frank's Fill Up Tool. 22:00 - 00:00 2.00 DRILL INT1 Continue running casing. 1/1/2001 00:00 - 10:00 10.00 DRILL INT1 Ran 194 joints of 7 5/8 L-80, 29.7#, Buttress Casing. Shoe at 8029. 10:00 - 10:30 0.50 DRILL INT1 Lay down Frank's Fill Up Tool. 10:30 - 17:30 7.00 DRILL INT1 Circulate and conditon mud for cement. Reciprocate casing. Found heat trace off on Mud return line in pipe rack to Howco. Line frozen. Make up jumper line from mud transfer line at rig to seawater line to Howco. Used seawater line for mud transfer to Howco. 17:30 - 20:00 2.50 DRILL INT1 Mix and pump first stage cement job. Pumped 10 bbls seawater ahead. Pumped 50 bbls Alpha spacer. Mixed and pumped 587 sks, (120 bbls) of Class G, with .2% CFR3, .5% Hallad 344, .35% HR5. Pumped 25 bbls seawater behind. Displaced with rig pump. Continued to reciprocate casing. Landed casing 500 strokes before bumping plug. Bumped plug with 1600 PSI. Checked float equipment. OK. Opened ES Cementer with 3216 PSI. 20:00 - 00:00 4.00' DRILL INT1 Circulate and condition mud through ES cementer. Cuttings dump hose to outside cuttings tank froze. Thaw hose and continue circulating. 112/2001 00:00 - 01:00 1.00 DRILL INT1 Continue to circ thru ES cementer before pumping 2nd stage cement. Did not see mud / cement interface, but did have have pH increase. Maintain full returns while circulating. 01:00 - 03:00 2.00 CEMT INT1 Halliburton mix and pump 2nd stage cement: 10 bbls SW 50 bbls 10.5 Alpha spacer Lead 1 - Premium G 178 sks 65 bbls 13.1ppg Lead 2 - Premium G 136 sks 49.7 bbls 13.1 ppg Tail- Premium G 118 sks 24.2 bbls 15.8 ppg 25 bbls SW Rig displace with 255 bbls mud POB at 0237 hrs Close ES cementer 03:00 - 08:00 5.00 CEMT INT1 R/D Halliburton cement head and casing elevators. Back out Vetco Gray top section of landing joint. R/U 4" drill pipe elevators. P/U TAM shifting tool for port collar. Continue GIH with 4" drill pipe and engage TAM port collar at 3909'. Shift open port collar. 08:00 - 09:30 1.50 CEMT INT1 Break circulation and circulate 2 bottoms up. Did not see mud / cement interface, but have pH increase. Maintain full returns while circulating. 09:30 - 11:00 1.50 CEMT INT1 Halliburton mix and pump 3rd stage cement: 10 bbls SW 50 bbls 10.5 Alpha spacer Lead - Permafrost E 280 sks 108.3 bbls 12.0 ppg Continue to mix and pump Lead until 12.0 ppg returns at surface. This was witnessed by the EPA. Printed: 1/26/2001 4:36:14PM BP EXPLORATION Page 7 of 10 Operations Summar Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of. Operations ' Date From-To Hours Task Code 1/2/2001 09:30 - 11:00 1.50! CEMT INT1 Tail- Premium G 352 sks 72.1 bbls 15.8 ppg Halliburton displace with 42 bbls SW (under displace by 2 bbls) 11:00 - 12:30 1.50 CEMT INT1 Close TAM port collar. Shear out ball with 2700 psi. Circulate 2 bottoms up in the 7 5/8" casing x 4" drill pipe annulus. Did not see mud ! cement interface, but did have pH increase. 12:30 - 14:30 2.00 CEMT ;INT1 Drain and wash out BOP stack. 14:30 - 18:00 3.50 CEMT INT1 POOH. L/D TAM shift tool. L/D TIW valve and pump in sub made up on single. 18:00 - 19:00 1.00 CEMT INT1 M/U top section of Vetco Gray landing joint. Back out of casing hanger and L/D landing joint. 19:00 - 20:30 1.50 CEMT INT1 MIU BOP wash out tool and wash out BOP's. Function rams to clear ram bodies. Continue washing out. 20:30 - 23:00 2.50 WHSUR INT1 P/U hanger pack-off and setting tool and set pack-off. Run in lock down screws and energize BT seal with plastic. Test to 3500 psi for 15 minutes. Test OK. 23:00 - 00:00 1.00 BOPSUI; INT1 Start to change top equipment for 4" drill pipe and change rams to 4". 1/3/2001 00:00 - 02:30 2.50 CASE INT1 Change out heads for Top Drive torque wrench for 4" HT40 dp. 02:30 - 05:00 2.50 CASE INT1 Thaw out choke and kill lines on mud cross on BOP Stack. 05:00 - 10:30 5.50 CASE INT1 PU 4" test joint, xo, and 2 pups -- MU and run test plug. Test bottom and top pipe rams, dart and TIW valves to 250 psi Iow and 5000 psi high. RD test joint and run wear bushing. 10:30 - 12:00 1.50 CASE INT1 Continue to thaw choke and kill lines in cellar. 12:00 - 13:00 1.00 CASE INT1 RD Wear bushing running tool and change elevators to 4". 13:00 - 13:30 0.50 CASE INT1 i Clear rig floor. Thawing choke line to gas buster and kill line at mud cro$$. 13:30 - 15:00 1.50 CASE INT1 MU BHA#5 - 6-3/4". Continue thawing kill line at mud cross. 15:00 - 16:30 1.50 CASE INT1 Finish thawing out kill line side of mud cross. 16:30 - 17:00 0.50 CASE INT1 Change out cable on skate. 17:00 - 22:00 5.00 CASE INT1 RIH with 4" dp from derrick to 4095'. Continue RIH while PU 4" dp. Tag cement at 5911' md. 22:00 - 22:30 0.50 CASE INT1 Close annular and test casing to 500 psi for 5 min -- chart. Problem getting bag to seal -- 4 cylces and bumped charge pressure from 700 psi to 1300 psi. 22:30 - 00:00 1.50 CASE INT1 Drilling cement from 5911' to 6010' md. 1/4/2001 00:00 - 03:00 3.00 CASE INT1 Drilling cement f/6010' to 6095' md. Drill out ES cementer (~ 6098' md. 03:00 - 03:30 0.50 CASE INT1 Close Annular -- Test Caisng to 500 psi for 5 min -- OK. 03:30 - 04:00 0.50 CASE INT1 Blow down kill line, standpipe and mud line. 04:00 - 07:00 3.00 CASE INT1 RIH PU 4" drillpipe out of pipe shed. 07:00 - 12:00 5.00 CASE INT1 Drilling cement f/7725' - 7975' md (10' above FC). Drilled LC ~ 7946' md. 12:00 - 15:30 3.50 CASE INT1 Circ and cond mud -- pump high vis sweep. 15:30 - 16:00 0.50 CASE INT1 Close Annular -- Test casing to 500 psig for 5 min -- OK. Blow down kill line & mud line. 16:00- 16:30 0.50 CASE INT1 Monitor well--static, pump dry job and blow down mud line. 16:30 - 20:00 3.50 CASE INT1 POOH with 4" HT40 drillpipe. 20:00 - 20:30 0.50 CASE INT1 Handle BHA. 20:30 - 21:00 0.50 CASE INT1 Clear rig floor. 21:00 - 00:00 3.00 CASE INT1 PJM -- RU wireline unit. , 1/5/2001 00:00 - 00:30 0.50 EVAL INT1 PJ M -- Finish rigging up to run USlT log. 00:30 - 07:00 6.50 EVAL INT1 RIH with USlT/DSCL log. Pressure up to 500 psi and log up to 3200' md. Turn off log and POOH. Printed: 1/26/2001 4:36:14PM BP EXPLORATION Page 8 of 10 Operations Summa Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Date From-To Hours Task code Phase Description of operations 1/5/2001 .07:00 - 08:00 1.00 EVAL INT1 Rig down wireline unit. 08:00 - 09:00 1.00 EVAL INT1 Clear rig floor and blow down line. 09:00 - 11:30 2.50 DRILL INT1 MU 6-3/4" rotary BHA with GR/Dir MWD. PU NMDC and stabs. 11:30 - 13:00 1.50 DRILL INT1 Surface Test MWD. 13:00 - 13:30 0.50 DRILL INT1 Blow down mud lines and top drive. 13:30 - 16:00 2.50 DRILL INT1 RIH to 1680' md while PU 48 jts of 4" HT40 drill pipe. 16:00 - 18:30 2.50 DRILL INT1 PJM -- Slip and Cut drill line. 18:30 - 19:30 1,00 DRILL INT1 Service Top Drive 19:30 - 22:30 3.00 DRILL INT1 Rill to 4200' -- fill pipe and finish RIH -- tag cement at 7975' md. 22:30 - 00:00 1.50 DRILL INT1 Circ and Cond Mud for casing test. 1/6/2001 00:00 - 00:30 0.50 DRILL INT1 Position tool joint out of top rams and top drive below windwall, circulate through kill line, close top pipe rams, circulate through choke. 00:30 - 01:30 1.00 DRILL INT1 Close choke & pressure test 7 5/8" casing to 3500 psi & held for 30 minutes. Held okay. 01:30 - 03:00 1.50, DRILL INT1 Circulate through top drive, kill line, & choke line. Close kill line and perform D5 drill. 03:00 - 03:30 0.50 DRILL INT1 Blow down choke & kill line. Drain degasser. 03:30 - 05:00 1.50 DRILL INT1 Drill out cement, float & shoe. 05:00 - 05:30 0,50 DRILL INT1 Clean out from 8027' to 8044'. 05:30 - 06:00 0.50 DRILL INT1 Drill from 8044' to 8064'. 06:00 - 07:00 1.00 DRILL INT1 Circulate bottoms up. 9.3ppg in & out. 07:00 - 08:00 1.00 DRILL INT1 Perform leak off test. LOT 11.6 equivalent. Blow down kill line. 08:00 - 12:00 4.00 DRILL INT1 Drill from 8064' to 8179'. 12:00 - 16:00 4.00 DRILL INT1 Drill from 8179' to 8246' (TD) 16:00 - 17:00 1.00 DRILL INT1 Circulate & condition mud. 17:00 - 17:30 0.50 DRILL INT1 Short trip to shoe. (looked good) 17:30 - 20:00 2.50 DRILL INT1 Circulate & condition mud. PJSM on displacement of 9.8 brine, 20:00 - 20:30 0.50 DRILL 'INT1 Spot viscosified pill in open hole & POH to 7999'. 20:30 - 22:00 1.50 DRILL INT1 Pump sweeps, Chase with 9.8 brine at 80 SPM at 1500 psi while rotating and reciprocating pipe. 22:00 - 22:30 0.50 DRILL INT1 Blow down mud lines & top drive. (9.8 brine) ~22:30- 00:00 1.50 DRILL INT1 POOH. 1/7/2001 I00:00 - 02:00 2.00 DRILL INT1 POOH f/4000' to 172'. 02:00 - 03:30 1.50 DRILL INT1 L/D BHA Grade bit 1-1-VVT-A-E-I-NO-TD. 03:30 - 04:00 0.50 DRILL INT1 Clear Rig Floor. 04:00 - 05:00 1.00 CLEAN COMP MU Bit and Scraper and PU collars and jars. 05:00 - 09:00 4.00 CLEAN COMP RIH with bit and scraper to 5500' - No problems. Had to slow down tripping speed due to hole taking fluid -- slowed down running speed and hole fill was static. 09:00 - 12:00 3.00 CLEAN COMP POOH f/5500' to 132'. 12:00 - 12:30 0.50 CLEAN COMP LD bit and scraper -- stand back drill collars. 12:30 - 13:30 1.00 CLEAN COMP Clear rig floor and perform general housekeeping on rig. 13:30 - 14:00 0.50 RUNCOI~ COMP Pull Wear Ring 14:00 - 15:00 1.00 RUNCOI~ COMP Rig up to Run 4-1/2" tubing completion. 15:00 - 16:00 1.00 RUNCOI~ COMP HSE Meeting with rig crew -- Housekeeping and general rig safety. 16:00 - 16:30 0.50 RUNCOI~ COMP PJM -- Running completion - tail pipe, tubing and packer. 16:30 - 23:30 7.00 RUNCOI~ COMP RIH with 4-1/2" completion to joint 137. 23:30 - 00:00 0.50 RUNCOI~ COMP Prepare to run heat trace -- tour change. 1/812001 00:00 - 0.00 DRILL INT1 119/2001 00:00 - 09:30 9.50 BOPSUI~.WTHR COMP Stand down operations due to phase 3 weather. (general housekeeping on rig). 09:30 - 12:00 2.50 BOPSUI; COMP PJSM- NID BOP's 12:00 - 12:30 0.50 BOPSUI~ COMP PJSM on N/D BOP's. Printed: 112612001 4:36:14PM BP EXPLORATION Page 9 of 10 Operations Summa Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRILL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Date From-To Hours .Task Code Phase Description of Operations 1/9/2001 12:30 - 15:00 2.50 BOPSUF COMP N/D BOP's. 15:00 - 16:30 1.50i BOPSUF COMP PJSM. Lift BOP's. 16:30 - 18:00 1.50 BOPSUI: COMP PJSM. Set BOP's down & secure to rig 18:00 - 18:30 0.50 WHSUR COMP Test heat trace. OK. 18:30 - 19:30 1.00 WHSUR COMP Bring tree into cellar. 19:30 - 20:30 1.00 WHSUR COMP N/U tree. 20:30 - 22:00 1.50 WHSUR ! COMP Pull blank flange / install choke valve on tree. 22:00 - 23:00 1.00 WHSUR COMP Hammer up cap flange & 1502 flange on tree. ,23:00 - 20:00 21.00 WHSUR COMP Rig up lubricator - pull back pressure valve - set two way check valve. 1/10/2001 '00:00 - 02:30 2.50 RUNCOI~! 'COMP R/U & test tree and tubing hangar to 5,000 psi. Okay 02:30 - 03:30 1.00 RUNCOI~! COMP Pull TWC with lubricator. Lay down. Test heat trace. (Okay) 03:30 - 07:00 3,50 RUNCOI~! COMP Rig up to reverse circulate & u-tube & pump down tubing. 07:00 - 08:00 1.00 RUNCOI~! COMP PJSM. Freeze protect. 08:00 - 10:30 2.50 RUNCOI~! COMP Test all surface circulating lines to 3,500 psi for 5 minutes then to 5,000 I psi for 10 minutes. Pump 98 bbls. brine w/correxit down annulus. Pump out trip tank. 10:30 - 12:00 1.50 RUNCOI~ COMP Pump 13 bbls. mineral oil down annulus. 2 bpm at 175 psi. 12:00- 13:00 1.00 RUNCOI~ COMP PJSM on diesel displacement, 13:00 - 23:30 10.50 RUNCOI~ISP COMP Line up to pump diesel. Diesel pump failure at PLQ. 23:30 - 00:00 0.50 RUNCOI~ COMP Pump diesel down annulus. 1/11/2001 00:00 - 01:00 1.00 RUNCOI~ COMP Pump 63 bbls of diesel down annulus @ 3/4 bpm and 500 psi. 01:00 - 01:30 0.50 RUNCOI~ ~ COMP Pump 5 bbls of mineral oil and sweep with 4 bbls of sea water ~ 1/4 bpm to flush lines to wellhead annulus valve. 01:30 - 02:30 1.00 RUNCOI~ COMP Align valves and U-Tube Tubing and Annulus 02:30 - 03:00 0.50 RUNCOI~ COMP Load Ball and Rod between Master Valve and Swab Valve. Open Master Valve and let ball and rod free fall to RHC profile in XN-Nipple. 03:00 - 03:30 0.50 RUNCOl~est COMP Pressure test tubing to 5000 psig. Had a couple of leaky connections to address. 03:30 - 04:30 1.00 RUNCOI~est COMP Repair test hose. 04:30 - 07:30 3.00 RUNCOI~I COMP Pressure Test Tubing to 5000 psi for 30 minutes -- OK -- chart. Pressure Test annulus to 3500 psi for 30 minutes -- OK -- chart. MIT witnessed by EPA Inspector. 07:30 - 08:30 1.00 RUNCOI~I COMP PJM -- RU Lubricator, Set BPV and L/D Same 08:30 - 10:00 1.50 RUNCOI~I COMP Blow down lines and RD circulating equipment. 10:00 - 12:00 2.00 RUNCOI~I COMP PJM -- Remove outside valves on 7-5/8" annulus -- Meager Test Heat Trace - OK. Clean Cellar Area. 12:00 - 13:00 1.00 RUNCOI~I COMP Safety Standdown -- Reviewed the recent 7ES incident and highlighted the importance of proper Pre-Job Meetings. 13:00 - 15:00 2.00 RUNCO~I COMP Remove outer wing valves and blocks from tree. 15:00 - 00:00 9.00 RUNCO~I COMP Prepare site and rig for pad move. 1/12/2001 00:00 - 12:00 12.00 DEMOB POST Continue Preparation for rig move - Blow down lines. PJM -- Review rig move procedures. Remove cuttings box. Continue to clear snow and ice around rig and jacking system. Bladed pad -- Survey main beam area over entire rig move area. Finished at 1200 -- evaluated sun/ey. 12:00 - 14:00 2.00 DEMOB POST Removed ramp from east side of cuttings pit and bladed west edge of rig area for rig mat lay down. Surveyed area -- Site Preparatioin is complete. Continue to clear snow around rig and set mats in front of substructure. 14:00 - 00:00 10.00 DEMOB POST Continue rig move preparation and clear snow around rig. Lay hemulite / Stow cattle chute and walkway. 1113/2001 00:00 - 03:00 3.00 DEMOB POST Continue prep for rig move / secure utility hoses @ pipe rack. Lift Printed: 1/26/2001 4:36:14 PM BP EXPLORATION Page '10 of 10 Operations Summary Report Legal Well Name: NS10 Common Well Name: NS10 Spud Date: 12/14/2000 Event Name: DRI LL+COMPLETE Start: 12/10/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Date From-To Hours ,Task Code PhaSe Description of Operations 1/13/2001 00:00 - 03:00 3.00 DEMOB POST stairways and dig additional mats from outside sea wall. 03:00 - 09:00 6.00 DEMOB POST Secure walkways, disconnect gas line @ pipe rack -- Unspool drilling line. Raise cellar door. Begin Move to the NS26 well. Printed: 1/26/2001 4:36:14 PM I Tie-In Station ID Report Date: Client: Field: Structure I Slot: Well: Borehole: UWl/API#: Survey Name I Date: Tort I AHD I DDI / ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: Surve), m~/pe: 0.00 385.52 476.11 565.89 657.37 746.00 833.23 932.53 1027.76 1121.34 1215.21 1310.48 1407.83 1501.19 1596.17 1690,01 1784,56 10202620713 SUrvey Report - Geodetic 18-Jan-2001 BPXA Northstar Northstar PF / NSlO NSIO NSlO 50-029-22985-00 NSIO / January 17, 2001 124.282° / 4900.07 ft / 5.887 / 0.752 NAD27 Alaska State Planes, Zone 04, US Feel N 70 29 27.584, W 148 41 35.82~ N 6030911.600 flUS, E 659832.880 ftU$ +1.23171925° 0.99992902 Final Multistation Analysis Anadrill Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Schlumberger ' Minimum Curvature / Lubinski 201.570° N 0.000 ft, E 0.000 fl KB 55.770 ft relative to MSL 15.670 ft relative to MSL +26.892° 57487.977 nT 80.907° January 17, 2001 BGGM 2000 True North +26.892° CONrlD£NTIAL Well Head Inol 0.00 1.81 1.78 1.65 1.38 0.00 0.00 7,22 385,46 6.16 476.00 9.16 565.74 356,71 657,19 VSec 0.00 -5.88 -8.62 -11.24 -13.52 0,00 0.00 6.02 0,76 8,84 1,09 11.51 1,45 13.91 1,60 I OridC°irdinates I Oe°graphiicoordinates DLS Northing Easting Latitude Longitude (~100,) (,US) {,US) 6030911.60 659832.88 N702927.584 W14841 35.825 0.47 6030917.64 659833.51 N702927.643 W14841 35.803 0.04 6030920.46 659833.78 N 7029 27.671 W148 41 35.793 0.18 6030923.14 659834.08 N 7029 27.697 W148 41 35.783 0.46 6030925.54 659834.18 N 7029 27.721 W148 41 35.778 1.14 259.35 745.81 -14.02 14.82 0.67 2.58 223.80 832.99 -11.74 13.24 -1.55 3.76 218.00 932.14 -6.55 9.05 -5.10 5.92 211.22 1027.02 1.29 2.39 -9.57 7.72 207.37 1119.94 12.31 -7.32 -14.96 2.14 6030926.42 659833.23 N 7029 27.730 W148 41 35.806 2.05 6030924.80 659831.05 N 7029 27.714 W148 41 35.871,,-~ 1.22 6030920.54 659827.59 N 70 29 27.673 W148 41 35.97. 2.34 6030913.79 659823.26 N 70 29 27.608 W148 41 36.107 1.98 6030903.96 659818.08 N 70 29 27.512 W148 41 36.266 8.93 206.15 1212.82 25.84 -19.46 -21.07 10.11 209.19 1306.77 41.50 -33.40 -28.41 11.53 205.75 1402.39 59.67 -49.62 -36.80 12.93 198.54 1493.64 79.41 -67.92 -44.17 13.82 198.79 1586.04 101.34 -88.73 -51.21 1.31 6030891.69 659812.23 N 70 29 27.393 W148 41 36.445 1.34 6030877.60 659805.20 N 7029 27.256 W148 41 36.661 1.60 6030861.21 659797.16 N 7029 27.096 W148 41 36.908 2.22 6030842.75 659790.18 N 70 29 26.916 W148 41 37.125 0.94 6030821.79 659783.60 N 7029 26.711 W148 41 37.332 16.37 203.02 1676.64 125.76 -111.52 19.11 205.10 1766.68 154.53 -137.80 -59.99 -71.77 2.96 6030798.83 659775.31 N 70 29 26.487 W148 41 37.591 2.98 6030772.30 659764.10 N 70 29 26.229 W148 41 37.937 NSIO Final survey.xls Page 1 of 3 1/24/01-4:41 AM 1879.16 1974.26 2067,11 2162.61 2256,19 2351,18 2446,19 2540.31 2634.91 2727.53 2821.92 2917.75 3012.50 3107.88 3202.62 3297.76 3390.96 3485.83 3581.79 3666.88 3760.88 3855.54 3950.41 4045.57 4140.12 4235.21 4328.76 4424,39 4520.13 4615.13 4707.70 4801.06 4897.39 4992.97 5088,27 5182.29 5275.45 537O.49 21,97 27.29 30.32 32.00 35.61 39.06 43.O5 46.00 46.30 44.91 46.16 47.56 48.63 49.13 49.05 48.36 49.13 48.6O 49,15 48.68 48.04 47,52 46,96 50.80 51.00 50.27 49,34 51.33 51,28 50.44 51,12 50.52 49.60 49.98 49.49 49.62 49.71 49,44 205.22 207.89 208.17 202,26 201,12 202.20 202.08 2OO,64 198.10 198,67 199,08 198,22 197.90 197.91 197.63 198.06 198.33 198.85 199.18 199.65 198.47 198.54 199.23 199.28 201.00 200.49 200.00 201.50 201,17 200,47 2O2.7O 202.38 201,59 202,63 201,85 201.46 2O2,37 201.14 1855,26 1941,68 2023.03 2104,77 2182.52 2258.04 2329.66 2396.76 2462.30 2527.10 2593.21 2658.74 2722.02 2784,74 2846.79 2909.58 2971.04 3033,45 3096.56 3152.48 3214.93 3278.54 3342.95 3405.52 3465,16 3525.47 3585,85 3646.89 3706,74 3766.70 3825.23 3884,21 3946.05 4007.76 4069.36 4130.35 4190.65 4252.28 187.66 227.10 271.55 320.82 372.87 430.47 492.85 558.84 627.00 693.08 760.37 830,20 900.59 972.29 1043.73 1115.06 1185.00 1256.35 1328.57 1392.66 1462.84 1532.84 1602.42 1674,03 1747.38 1820.88 1892,32 1965,92 2040.65 2114,32 2186.03 2258.40 2332.25 24O5,24 2477.95 2549,5O 2620.51 2692.86 -167.84 -203.22 -242,71 -287.39 -335.76 -389.29 -447.08 -508.54 -572,89 -635.70 -699.43 -765,69 -832.73 -901.11 -969.28 -1037.32 -1103.88 -1171.61 -1239.94 -1300.43 -1366.83 -1433.31 -1499.22 -1566,88 -1635,76 -1704.51 -1771.55 -1840,37 -1909.98 -1978.85 -2045.53 -2112.38 -2180.86 -2248.48 -2315,79 -2382.29 -2448,17 -2515.37 -85.88 -103.67 -124.69 -145.67 -164,89 -186.17 -2O9,68 -233.69 -256.31 -277.18 -298.97 -321.33 -343.19 -365.28 -387,14 -409,04 -43O.92 -453,69 -477.25 -498,57 -521,52 -543,77 -566,30 -589,94 -615,20 -641,24 -665,97 -692.07 -719.25 -745.44 -771.82 -799.57 -827.22 -854.69 -882.21 -908.62 -935.12 -961.94 3.02 5.72 3,27 3.65 3.92 3.70 4.20 3.31 1.96 1,57 1,36 1.60 1.16 0,52 0.24 0.80 0,85 0,69 0.63 0.69 1.16 0.56 0.80 4.03 1.42 0.87 1.08 2.41 0,28 1,05 2.01 0,70 1,14 0.92 0.81 0.34 0.76 1.03 6030741.97 6030706,21 6030666,29 6030621.17 6030572.40 6030518.43 6030460.15 6030398.19 6030333.37 6030270.14 6030205.95 6030139.24 6030071,74 6030002.92 6029934.29 6029865.80 6029798.79 6029730.60 6029661.77 6029600.85 6029533.98 6029467.04 6029400.67 6029332.52 6029263.11 6029193.83 6029126,28 6029056.91 6028986.74 6028917,33 6028850.10 6028782.68 6028713,62 6028645,43 6028577,55 6028510,50 6028444.07 6028376.32 659750,64 N 70 29 25.933 W148 41 38,352 659733,61 N 70 29 25.585 W148 41 38,876 659713,44 N 70 29 25,197 W148 41 39.495 659693,43 N 70 29 24,758 W148 41 40,112 659675,26 N 70 29 24.282 W148 41 40,677 659655,14 N 70 29 23,755 W148 41 41,303 659632,88 N 70 29 23,187 W148 41 41,995 659610,19 N 70 29 22,583 W148 41 42.702 659588,96 N 70 29 21,950 W148 41 43.367 659569,45 N 70 29 21.332 W148 41 43,981 659549,03 N 70 29 20,705 W148 41 44.622 659528.11 N 70 29 20.054 W148 41 45.280~..~.~ 659507.69 N 70 29 19,394 W148 41 45,92 659487.07 N 70 29 18,722 W148 41 46,573 659466,70 N 70 29 18,051 W148 41 47.216 659446,26 N 70 29 17,382 W148 41 47,860 659425,82 N 70 29 16,727 W148 41 48,504 659404,51 N 70 29 16.061 W148 41 49,174 659382,43 N 70 29 15,389 W148 41 49,867 659362,41 N 70 29 14,794 W148 41 50.494 659340,90 N 70 29 14,141 W148 41 51,169 659320,09 N 70 29 13,488 W148 41 51,824 659298.97 N 70 29 12.839 W148 41 52,487 659276,80 N 70 29 12,174 W148 41 53,182 659253.02 N 70 29 11,496 W148 41 53.925 659228.47 N 70 29 10.820 W148 41 54,691 659205,19 N 70 29 10.161 W148 41 55.418 659180,58 N 70 29 9,484 W148 41 56.186"~. 659154,90 659130,20 659105.26 659O78,96 659052.79 N 70 29 8.800 W 148 41 56.985 N 70 29 8.122 W 148 41 57,755 N 70 29 7.466 W 148 41 58.531 N 70 29 6,809 W 148 41 59.347 N 70 29 6,135 W 148 42 0,161 659O26.78 659000.71 658975.75 658950.67 658925.30 N 70 29 5,470 W148 42 0,969 N 70 29 4,808 W148 42 1.778 N 70 29 4.154 W148 42 2,554 N 70 29 3.506 W148 42 3,334 N 70 29 2,845 W148 42 4,123 NS10 Final survey.xls Page 2 of 3 1/24/01-4:41 AM 5464.32 5559.08 5653.77 5749.32 5843.42 5937.40 6031.76 6124.17 6222.54 6316,56 6411,89 6505.23 6600.34 6695.06 6789.16 6883.86 6979.60 7073.70 7168,93 7262.06 7356,04 7450.34 7544,26 7638,44 7732,30 7827,O4 7920,13 7986.52 8O65.35 8159,62 8217.35 8246.00 49.87 49.26 48.92 49.23 48,81 48.21 47.86 47,22 47,O5 46,78 46.26 45,18 42,98 39.79 35,43 31.38 29.10 27,97 26.36 26.41 26,12 25,96 26,55 26,46 26.53 26.25 26.05 25.70 26.65 3O.79 33.08 33.08 201.84 201,96 201,32 201.96 202.03 202.04 201.58 201.94 202.02 202.31 2O2.6O 2O4,OO 2O4,69 205.38 2O4.67 207.21 205,04 201,37 200.68 200,80 2OO.57 200.38 204.47 204.56 203.73 203.83 202.56 2O3.2O 202.50 200.19 198.87 198.87 4313.02 4374,48 4436.50 4499.O9 4560,81 4623,O7 4686.16 4748.55 4815,47 4879,69 4945,29 5010,45 5078.77 5149.83 5224.35 5303.40 5386.11 5468,78 5553.51 5636.93 5721,21 5805.94 5890.18 5974,46 6O58.47 6143.33 6226.89 6286.63 6357.37 6440.03 6489.O2 6513.03 2764.37 2836.50 2908.05 2980.24 3051.28 3121.67 3191.83 3260.01 3332.10 3400.77 3469,93 3536.73 3602.81 3665.31 3722.62 3774,59 3822,63 3867,54 3911.02 3952.40 3993.99 4O35.37 4076.89 4118,86 4160.69 42O2.76 4243.78 4272.74 4307.51 4352.78 4383.30 4398.92 -2581.91 -2648.83 -2715.35 -2782.45 -2848.32 -2913.57 -2978.71 -3042.03 -3108,89 -3172.48 -3236.41 -3297.79 -3358.07 -3414.80 -3466.82 -3513.71 -3556.97 -3598.25 -3638.83 -3677.54 -3716.45 -3755~23 -3793,60 -3831.84 -3870,05 -3908.58 -3946.29 -3972.99 -4005.03 -4047.23 -4076.01 -4090.80 -988,13 -1015.03 -1041,42 -1068.04 -1094,64 -1121,05 -1147,11 -1172,39 -1199,37 -1225.28 -1251.70 -1278,12 -1305.39 -1331,88 -1356.19 -1378.93 -1400.18 -1417.91 -1433.51 -1448.17 -1462.86 -1477.34 -1493.19 -1510.63 -1527.76 -1544.74 -1560.90 -1572,17 -1585,67 -1602.09 -1612,29 -1617,34 0.73 0.65 0.62 0.60 0.45 0.63 0.52 0,75 0.18 0.36 0,59 1.59 2.37 3.40 4.66 4,52 2,64 2,22 1.71 O,08 0.33 0.19 2.03 0.11 0.40 0,29 O,64 0.68 1,27 4,54 4.15 0.00 6028309.23 6O28241.75 6028174,69 6O281O7,O4 6028040,62 6027974,82 6027909,14 6O27845.3O 6O27777,88 6027713,75 6027649,27 6O27587,34 6027526,50 6027469,21 6027416.69 6027369.32 6027325.61 6027283.96 6027243.06 6027204.05 6O27164,84 6027125,76 6027087,06 6O27O48,45 6027009,89 6026971,00 6026932.96 6026906.03 6026873.70 6026831,17 6026802.18 6026787.28 658900.55 N 7029 2.191 W148 42 4.893 658875,09 N 7029 1,533 W148 425.684 658850.14 N 7029 0,879 W148 42 6,460 658824.97 N 70290.219 W148427.243 658799,80 N 7028 59.571 W148 42 8,025 658774,80 658750,14 658726.24 658700,70 658676.16 658651.13 658626.03 658600.06 658574.80 658551.62 658529,89 6585O9.58 658492,74 658478.02 658464,20 658450.35 658436.71 658421.68 658405.07 658388.77 658372,62 658357.27 658346.59 658333,78 658318.27 6583O8.70 658303.96 N 70 28 58,929 W148 42 8.801 N 70 28 58.288 W148 42 9,568 N 70 28 57.666 W148 42 10,311 N 70 28 57.008 W148 42 11,104 N 70 28 56,383 W148 42 11,866 N 70 28 55.754 W148 42 12.643,._.~,._ N 70 28 55.150 W148 42 13.42' N 70 28 54.557 W148 42 14.222 N 70 28 53.999 W148 42 15.000 N 70 28 53.488 W148 42 15.715 N 70 28 53,026 W148 42 16.384 N 70 28 52,601 W148 42 17.009 N 70 28 52,195 W148 42 17,530 N 70 28 51.796 W148 42 17.988 N 70 28 51,415 W148 42 18,419 N 70 28 51,032 W148 42 18,851 N 70 28 50,651 W148 42 19,277 N 70 28 50,273 W148 42 19,743 N 70 28 49,897 W148 42 20.256 N 70 28 49.522 W148 42 20,759 N 70 28 49.143 W148 42 21.258 N 70 28 48.772 W148 42 21.73,-"~'~-, N 70 28 48.509 W148 42 22.06~ N 70 28 48.194 W148 42 22.461 N 70 28 47.779 W148 42 22.944 N 70 28 47,496 W148 42 23,244 N 70 28 47.350 W148 42 23,392 NS10 Final survey.xls Page 3 of 3 1/24/01-4:41 AM sun BP EXPLORATION ALASKA END OF WELL REPORT NORTHSTAR NS-10/WD-01 BP EXPLORATION ALASKA END OF WELL REPORT Well: Rig: Field: Northstar NS-t0/WD-01 Nabors Alaska Drilling No. 33-E Northstar State: Alaska Date: January. 2001 Job No.: AKAM00307 AFE Number: 83130t APINUmber: 50-029'22985,00 TABLE OF CONTENTS la e e 4~ Sa e e General Information Operational Overview Morning Reports Show Reports Bitrun Summary Directional Survey' Data Mud Reports Formation Tops Formation Evaluation Logs General Information GENERAL INFORMATION . Company: Rig: Well: Field: Borough: State: Country: APl Number: Sperry-Sun Job Number: Job Start Date: Job End' Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical' Section Azimuth: SDL Engineers: Company' Representatives: Company Geologist: Lease' Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS- IO/WD Northstar North Slope Alaska United States 50-029-22985-00. AKAM00307 December t4, 2000 January 6," 2001 True '26.'9'26 deg 80.906 deg 57487.352 nT December 1.4, 20.00 North 70 deg 29 rain 29;591 sec East 148 deg 41 .mi.n 34.77.6 sec 201'.390 deg "Doug Wi]son Mark Lindioff Bernie LeaS "Tom' Mansfield Reg Wilson "Paul Lockwood Joe Polya Ken Lemley 'Northstar 40087 Alaska North Slope Operational Overview Operational Overview THE NS-10/WD WELL COMMENCED DRILLING A 13 1/2" HOLE OUT OF 20" CONDUCTOR PIPE AT 159' ON 12/15/2000. 13, ½" ltOLE SECTION GEOLOGY AND OPERATIONS THIS HOLE SECTION WAS DRILLED FROM 159' MD TO 3742' MD. NO SIGNIFICANT HOLE PROBLEMS WERE ENCOUNTERED IN THIS SECTION. THIS HOLE SECTION PENETRATED FROM SURFACE GRAVELS THROUGH THE PERMAFROST INTO THE SV6 MARKER. NO ABNORMAL OEOLO(}ICAL CONDITIONS WERE ENCOU, NTERED. THE FIRST OCCURRENCE OF GAS WAS 3 UNITS FOUND AT 1308' MD. THERE WAS 17 UNITS OF GAS AT THE. BASE OF THE PERMAFROST AT 1562' MD. AT AROUND 2700' MD, THE GAS INCREASED TO 37 IBqITS ASSOCIATED WITH COAL FORMATIONS. THE MAX~4L~4 OAS SEEN IN THIS .INTREYAL WAS 42 UNITS AT 35.70' MD. THE ia ½" HOLE SECTION REACH~.F) TD AT 3742' MD. A SHORT TRIP WAS MADE TO 728'." SHORT TRIP GAS WAS 24UNITS. 10'~A'' 45.'5 LB/FT CASING WAS SET AT 37:6' MD. LEAK OFF TEST AT 3762' MD WAS 13.7 PPG EMW. 9 7/8" IIOLE SECTION GEOLOGY A ,,I~D:,OPERATIONS' THIS HOLE SECTION WAS DRILLED FROM 3742' MD TO 8044' MD, AT 6164' MD, A SHORT -TRIP TO 10 3/4" CASING SHOE PEq~,LED TIGHT; BAC' .KREAMED EACH .STAND TO SHOE.. THIS HOLE SECTION'PENETRATED FROM'THE SV6'MARKER INTO THE'UG1 FORMATION. NO ABNORMAL.CxF_,OLO(~iCAL CONOI.TIONS WERE ENCOU..NTEREO. FROM 3.7.42' TO.61.5..0.'.MO, .. THE GAS AVEILAGED 35-75.UNITS. AT 6157' MD THE SHORT TRiP GAS WAs.g80 UNITS. NEAR, THE TMBK. FROM 6.150'-7225' MD, THE GAS AVERAGED 40,100 UNITS WITH PEAKS. OF 400 UNITS (6460'..6480' MD),200 UNITS {6545'-6565.'. MD), 200 UNITS.(6620'-6655.' MD), t.09 UNITS (7195'-7200' MD) AND 120 UNITS (7300'-7320' MD) .IN .THE UG3. A SHORT .TRIP AT 7225' .MD YIELDED GAS OF' 165 UNITS. FROM '7320'~8044' MD, 'THE' GAS' AVERAGED' 30-090 UNiTS. 'THE' 9 7/7" HOLE SECTION REACHED TD AT 8044' MD.7 5/8" CASING WAS SET AT 8029' MD.. THE LEAK OFF TEST AT 8064' MD'WAS 12..0 PPG.E.MW. 6.3/4"'HOLE SECTION GEOLOGy.. A',,ND,,,OiPERATtONS,, , . THIS HOLE SECTION WAS DRiL~ FROM 8044' MD TO 8246~ MD. NO.SIGNIF1CANT HOLE. PROBLEMS WERE ENCOUNTERED IN THIS SECTION'. THIS HOLE SECTION PENETRATED 'INTO THE'TARGET INIECTION INTERVAL IN 'THE 'SCHRADER BLUFF FORMATION. NO ABNORMAL GEOLOGICAL CONDITIONS WERE ENCOUNTERED. THE 6 ~A" HOLE SECTION FROM 8044'.,8246' MD SAW.AVERAGEGAS.READIN(}S. OF 20-30 UNITS WlTH..A MAXIMUM OF '. 37 UNITS AT 8130'-8160' MD.' 'THIS INTERVAL OF HOLE'RE'ACHED"TD AT 8246'. ' Morning Reports Mudlogger's Morning Report Current R.O.P. 0 ft/hr Gas* 0 units Temp Out Deg F Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: AKAM00307 24 hr Avg 24 hr Max 167 fi/hr( 359 fi/hr @ 217 ) 0 unit., ( 0 units @ ) ( deg F @ ) Report No.: 1 Date: 1/16/01 0:00 Depth 369 Footage Last 24 hrs: 369 Rig Activity: Drilling Report For: Joe Polya Show? Pump and Flow Data Pump 1 70 spm DH flow 592 gpm Pump 2 70 spm Total flow 592 gpm Pump 3 spm AV @ rsr fpm Pump Pres 580 psi AV @ DC fpm Mud Wt In Mud Wt Out 9.30 ppg Visc 70 secs APl flit ~ml HTHP mi Mud Wt at Max Gas ~ppg 9.30 ppg PV cP YP Ibsll00ft2 Gels ~\ ~ Ibs/100ft2 pH ~Sd ~% Bit No.: 1 Wt On Bit: Bit Type: Mx-C1 Bit Size: 13 1/2 Jets: 12 \ 18 \ 18 \ 18 \ __\ __TFA: 0.8560 5 RPM: 4 Hrs. On Bit: Total Revs on Bit: na Footage for Bit Run 369 Tdp Depth: Short Trip Depth Tight Spots: ft Trip Gas: Mud Cut: .,, ppg Trip CI: ppm 0 ft Short Tdp Gas: 0 Mud Cut: ppg Short Tdp CI: ppm to shoe to to Feet of Fill on Bottom: ,~ ft Current Lithology: 60 % SD 40 ,% GRAV . % __% __%~ ft units ppg ft units ppg ft units ~ ppg Connection Gas and Mud Cut ~ ft __ units ppg ft __ units _---- ppg ft __ units ppg ft __ units ~ ppg ft units ppg ft units __PPg Depth to to to to Drill Rate bef dur aft Drilling Breaks Gas Chlorides . Lithology bef dur aft bef dur aft Sd Sst Sit Cly hr Recap: Drilled F surface T 369. 24 !' I I Logging Engineer: Doug Wilson/Reg Wilson i 10000 units = 100% Gas In Air i ! Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar Rig: Nabors 33E Job No.: AKAM00307 Current 24 hr Avg 24 hr Max R.O.P. 98 ft/hr 250 ft/hr ( 525 fi/hr @ 2330 ) Gas* 10 units 12 unit., ( 28 units @ 2717 ) Temp Out NA Deg F ( NA deg F @ ) Report No.: 1 Date: 12/16/00 0:01 Depth 2718 Footage Last 24 hrs: 1584 Rig Activity: Drillin~l Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 78 spm DH flow 1427 gpm Pump 2 79 spin Total flow 1427 gpm Pump 3 NA spin AV @ rsr NA fpm Pump Pres 1427 psi AV @ DC NA fpm MudWtln 9.30 ppg Visc 67 secs APl flit 5.8 mi HTHP h~ mi Mud Wt at Max Gas 9 ppg Mud WtOut 9.30 ppg PV 19 cP YP 43 Ibsll00ft2 Gels 15 \ 28 Ibs/100ft2 pH 8.30 Sd 1.3 % Bit No.: 1 Bit Type: Smith MA!SL Bit Size: 13 1/2 Jets: 12 \ 20 \ 20 \ \ \ ~ TFA: 0.7640 Wt On Bit: 8 RPM: 30+motor Hrs. On Bit: 25.5 Total Revs on Bit: Footage for Bit Run 2558 Trip Depth: NA ft Trip Gas: ft Mud Cut: ~ ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: ft Mud Cut: ~ ppg Short Trip CI: ppm Tight Spots: to to to ~ Feet of Fill on Bottom: ~ ft CurrentLithology: 80 o,~ SD 20 o~ CLY ~%~ ~% ~% Connection Gas and Mud Cut NA ft units ppg ft units ~ ppg ~ ft .~ units ~ ppg ft units ppg ft ~ units ~ ppg ~ ft ~ units ~ ppg ft units ppg ft units ~ ppg ft ~ units ppg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit Sh tO to to to :24 hr Recap: Drill ahead from 1134'MD to 2718' MD. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. n/a fi/hr Gas* 25 units Temp Out NA Deg F Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar Rig: Nabors 33E Job No.: AKAM00307 24 hr Avg 24 hr Max 180 ft/hr ( 720 fi/hr @ 3120 ) 22 unit.,( # 40 units @ 3560 ) ( NA deg F @ ) Report No.: 2 Date: 12/17/00 0:01 Depth 3742 Footage Last 24 hrs: 1024 Rig Activity: Drilling Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 78 spm DH flow 655 gpm Pump 2 79 spin Total flow 655 gpm Pump 3 NA spm AV @ rsr NA fpm Pump Pres 1427 psi AV @ DC NA fpm MudWtln 9.40 ppg Visc 60 secs APIfilt 5.2 mi HTHP /~ mi Mud Wt at Max Gas 9 ppg Mud WtOut 9.40 ppg PV 17 cP YP 32 Ibs/100ft2 Gels 12 \ 29 Ibs/100ft2 pH 8.30 Sd 0.8 % Bit No.: 1 BitType: Smith MA!SL Bit Size: 13 112 Jets: 12 \ 20 \ 20 \ __\ __\ __TFA: 0.7640 Wt On Bit: 8 RPM: 30+motor Hrs. On Bit: 25.5 Total Revs on Bit: Footage for Bit Run 3582 Trip Depth: Short Trip Depth Tight Spots: NA ft Trip Gas: none ft Mud Cut: ~ ppg Trip CI: ppm ft Short Trip Gas: ft Mud Cut: ~ ppg Short Trip CI: ppm to to to Feet of Fill on Bottom: ft Current Lithology: 60 o/~ SD 40 o/~ CLY % __ %~ __ %~ Connection Gas and Mud Cut NA ft __ units ppg ft __ units ~ ppg ft __ units ~ ppg ft __ units ppg ft __ units ~ ppg ~ ff __ units ~ ppg ft __ units __ ppg ft units .._._._ ppg ~ ft __ units ppg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit Sh to to to to 24 hr Recap: Drill ahead from 112718' to 3742' casing T.D. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units = 100% Gas In Air sper r -sun Mudlogger's Morning Report Current R.O.P. n/a ft/hr Gas* units Temp Out NA Deg F Customer: BP Alaska Report No.: 3 24 hr Avg 24 hr Max fi/hr ( fi/hr @ ) 22 unit,, ( units @ ) ( NA deg F @ ) Well: Northstar NS 10 Date: 12/18/00 0'01 Area: North Slope Depth 3742 Lease: Northstar Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Drilling Job No.: AKAM00307 Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm TotAl flow gpm Pump 3 NA spm AV @ rsr NA fpm Pump Pres psi AV @ DC NA fpm Mud Wt In Mud Wt Out 9.50 ppg Visc 57 secs APl flit 6.2 mi HTHP mi Mud Wt at Max Gas ~PPg 9.50 ppg PV 19 cP YP 31 Ibs/100ft2 Gels 14 \ 30 Ibs/100ft2 pH 8.80 Sd 0.8 % Bit No.: 1 Wt On Bit: Bit Type: SmithMA!SL Bit Size: 131/2 Jets: 12 \ 20 \ 20 \ ~\ ~\ ~TFA: 0.7640 .__J 8 RPM: 30+motor Hrs. On Bit: 31.0 Total Revs on Bit: Footage for Bit Run 3678 Trip Depth: Short Trip Depth Tight Spots: NA ft Trip Gas: ft Mud Cut: ~ ppg Trip Cl: ppm 3742 ft ShortTrip Gas: 24 ft Mud Cut: ~ppg ShortTrip Cl: ppm to to to Feet of Fill on Bottom: ft Current Lithology: 60 o/~ S~D 40 °~ CL~Y ~% % % ' NA ff ff ff units units units Connection Gas and Mud Cut ppg ft ~ units ppg ~ ft ~ units ~ ppg ppg ~ ft ~ units ... ppg ft ~ units ppg ppg ft units ~ ppg ft units ~ ppg Depth to to to to Drilling Breaks Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit Sh 24 hr Recap: Drilled to 3472' MD. Circulated and Conditioned. Short Tripped to 728'. Ran in hole. Circulated. Pulled out of hole. Preparing to run E-Logs at report time. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units =100% Gas ln Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar Rig: Nabors 33E Job No.: AKAM00307 ...... Ii ! ............... !lllll!J. ~1 I~, .l!llllllll.ilil.l.l!l..,!ll [l,~.lllllllllit. ,~ ~ I., I!111 IIIIIII!lllllll .ma~.,~.~.~.~ Current 24 hr Avg 24 hr Max R.O.P. n/a ft/hr fi/hr ( fi/hr @ ) Gas* units unit.~ ( units @ ) Temp Out NA Deg F _ ( NA deg F @ ) Report No.: 4 Date: 12/19/00 0:01 Depth 3742 Footage Last 24 hrs: 0 Rig Activity: Run Casin~l Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 NA spm AV @ rsr NA fpm Pump Pres psi AV @ DC NA fpm Mud Wt In 9.2+ ppg Visc 53 secs APl flit 6.2 Mud Wt Out ppg PV 17 cP YP 29. Ibs/100ft2 mi HTHP Gels 12 \ mi Mud Wt at Max Gas ppg 25 Ibsll00ft2 pH 8.50 Sd 0.3 % Bit No.: 1 Bit Type: Smith MA!SL Bit Size: 13 112 Jets: 12 \ 20 \ 20 \ Wt On Bit: 8 RPM: 30+motor Hrs. On Bit: 31.0 Total Revs on Bit: \ \ TFA: 0.7640 Footage for Bit Run 3678 Trip Depth: ft Trip Gas: ft Mud Cut: Short Trip Depth ft ft Mud Cut: Tight Spots: to to to ppg Trip Cl: ppm ppg Short Trip Cl: ppm Feet of Fill on Bottom: ft Current Lithology: 60 o/~ SD 40 o/~ CLY % % __ %~ Connection Gas and Mud Cut NA ft units ppg ft ~ units , ppg ft . units ~ ppg ft ~ units , ppg ft units ppg ft units ~ ppg ft -units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas Chlorides bef dur aft bef dur aft bef dur aft to to to to Lithology Sd Sst Sit Sh 24 hr Recap: Attempt E-Logs. Did not run. Run 10 3/4" Casing. Landing at report time. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units = 100% Gas In Air I . Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar Rig: Nabors 33E Job No.: AKAM00307 Current 24 hr Avg 24 hr Max R.O.P. n/a ft/hr fi/hr ( ft/hr @ ) Gas* units unit., ( units @ ) TempOut NA Deg F __ ( NA deg F @ Report No.: 5 Date: 12/20/00 0:01 Depth 3742 Footage Last 24 hrs: 0 Rig Activity: Nipple Down Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 NA spin AV @ rsr NA fpm Pump Pres psi AV @ DC NA fpm Mud Wt In 9.30 ppg Visc 47 secs APl flit 9.1 mi HTHP mi Mud Wt at Max Gas ppg Mud WtOut 9.30 ppg PV 14 cP YP 16 Ibs/100ft2 Gels 8 \ 18 Ibsll00ft2 pH 8.60 Sd 0.3 % Bit No.: 1 Bit Type: Smith MA!SL Bit Size: 13 1/2 Jets: 12 \ 20 \ 20 \ ~\ ~ \ TFA: 0.7640 Wt On Bit: 8 RPM: 30+motor Hrs. On Bit: 31.0 Total Revs on Bit: Footage for Bit Run 3678 Trip Depth: ft Trip Gas: ft Mud Cut: . ppg Trip CI: ppm Short Trip Depth ft ft Mud Cut: ppg Short Trip CI: ppm Tight Spots: ~ to to to Feet of Fill on Bottom: ft Current Lithology: 60 o/~ SD 40 o/~ CLY __ % __ % __ % Connection Gas and Mud Cut NA ft units ppg ~ ft ~ units ~ ppg ft ~ units ~ ppg ft ~ units ppg ft units ~ ppg ft ~ units ~PPg ft units ppg ft ~ units .._..._. ppg ft ~ units ~ ppg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit Sh to to to to 24 hr Recap: Set 10 3/4" Surface Casing @ 3726'. Cemented same. Nipple down @ report time. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: Current 24 hr Avg R.O.P. ft/hr fi/hr ( Gas* units unit,, ( Temp Out Deg F ( 24 hr Max fi/hr @ ) units @ ) deg F @ ) Report No.: 6 Date: 12/21/00 0:01 Depth 3726 Footage Last 24 hrs: 0 Rig Activity: Nipple Up Report For: Joe Polya Show? NA Pump and Flow Data 3ump 1 spm DH flow gpm Pump 2 spin Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Visc Mud Wt Out 9.20 ppg PV 45 secs APl flit 9.6 mi HTHP 13 cP YP 22 Ibsll00ft2 Gels 9 · mi Mud Wt at Max Gas ppg \ 16 Ibs/100ft2 pH 8.50 Sd tr % Bit No.: 1 Bit Type: Smith MA!SL Bit Size: 13 1/2 Jets: 12 \ . 20 \ 20 \ Wt On Bit: RPM: Hrs. On Bit: 31.0 Total Revs on Bit: \ \ TFA: 0.7640 Footage for Bit Run 3678 Trip Depth: ft Trip Gas: ft Mud Cut: Short Trip Depth ft Short Trip Gas: ft Mud Cut: Tight Spots: to .___ to . to ppg Trip Cl: ppm ppg Short Trip Cl: ppm Feet of Fill on Bottom: ft Current Lithology: % % % % % Connection Gas and Mud Cut . ft ~ units ~ ppg ft ~ units ._.._._ ppg ft units ppg ft ~ units ppg ft units _----- ppg ft units ._.-...- ppg ft units ppg _ ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas Chlorides bef dur aft bef dur aft bef dur aft to to to to Lithology Sd Sst Sit Sh 24 hr Recap: Nipple down diverter, nipple up BOPs. ling Engineer: Tom Mansfield / Mark Lindloff units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: Current R.O.P. Gas* Temp Out 24 hr Avg 24 hr Max fi/hr fi/hr ( fi/hr @ ) units unit,, ( units @ ) Deg F ( deg F @ ) Report No.: 6 Date: 12/21/00 0:01 Depth 3726 Footage Last 24 hrs: 0 Rig Activity: Nipple Up Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Visc 45 secs APl flit 9.6 mi HTHP mi Mud Wt at Max Gas ~ppg Mud WtOut 9.20 ppg PV 13 cl~ YP 22 Ibs/100ft2 Gels 9 \ 16 Ibsll00ft2 pH 8.50 Sd tr % Bit No.: 1 Bit Type: Smith MA!SL Bit Size: 13 1/2 Jets: 12 \ 20 \ 20 \ ~\ ~\ TFA: 0.7640 Wt On Bit: RPM: Hrs. On Bit: 31.0 Total Revs on Bit: Footage for Bit Run 3678 Trip Depth: ft Trip Gas'. ft Mud Cut: ~ ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: ff 'Mud Cut: ~PPg Short Trip CI: ppm Tight Spots: to ~ to ~ to ~ Feet of Fill on. Bottom: ft Current Lithology: ~ % ~ % ~ % ~ % ~ % Connection Gas and Mud Cut ft __ units ~ ppg ft __ units ppg ft __ units _.._--- ppg ff __ units __...-- ppg ~ ff __ units ~ ppg ft __ units ppg ft units ppg ft units ~ ppg ft units ___._- ppg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur afl bef dur afl bef dur afl Sd Sst Sit Sh tO to to to 24 hr Recap: Nipple down diverter, nipple up BOPs. * umts 100Yo Gas In A~r Logging Engineer: Tom Mansfield / Mark Lindloff - Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: i tiiiii~i~iii!~!~i~i~i~i~i~i~iiii~i~i~ii~i~i~iii~iii~ii~iiii~-~i~-i~!i~liiiiiii~ii~ii~ii~!iii~ii~iii~i~- Current ~.O.P. fi/hr Gas" units Temp Out Deg F 24 hr Avg 24 hr Max fi/hr ( fi/hr @ ) unit~. ( units @ ) ( deg F @ ) Report No.: 7 Date: 12/22100 0:01 Depth 3726 Footage Last 24 hrs: 0 Rig Activity: Nipple Up Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spin Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In Mud Wt Out 9.10 ppg Visc 40 secs APl flit 8.7 mi HTHP mi Mud Wt at Max Gas ~ppg 9.10 ppg PV 8 cP YP 20 Ibs/100ft2 Gels 8 \ 13 Ibs/100ft2 pH 8.40 Sd tr % Bit No.: I Wt On Bit: BitType: SmithMA!SL BitSize: 13112 Jets: 12 \ 20 \ 20 \ __\ __\ .TFA: 0.7640 RPM: Hrs. On Bit: 31.0 Total Revs on Bit: Footage for E~it Run 3678 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Mud Cut: ~ ppg Trip CI: ppm ft Short Trip Gas: ft Mud Cut: ~ ppg Short Trip CI: ppm to to to Feet of Fill on Bottom: ft Current Lithology: ~ % , % ~ % , % , % ft units ft units ft units Connection Gas and Mud Cut ppg ~ ft __ units __ ppg ft __ units . ,. ppg ppg ~ ft __ units __ ppg ft __ units ___-- ppg ppg , ft __ units ~ ppg ft __ units ~ ppg Depth to to to to Drilling Breaks Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit Sh 24 hr Recap: Nipple up BOPs. Testing @ report time. Logging Engineer: Tom Mansfield / Mark Lindloff units = 100% Gas In Air l,.. O'li:! I I__1__ I I~ G S I::: I::t V I I-- E'S Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: Current 24 hr Avg R.O.P. ftJhr ft/hr ( Gas* units unit,. ( Temp Out Deg F ( 24 hr Max ft/hr @ ) units @ ) deg F @ ) Report No.: 8 Date: 12/23/00 0:01 Depth Cs~l @ 3726' Footage Last 24 hrs: 0 Rig Activity: RIH, Drl CMT Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Mud Wt Out 9.20 ppg Visc 40 secs PV 11 cP YP APl flit 9.0 mi HTHP 17 Ibs/100ft2 Gels 7 ,,. mi Mud Wt at Max Gas ppg .... 10 Ibs/100ft2 pH 9.00 Sd tr . % Bit No.: 2 Wt On Bit:. Bit Type: Hucjhes MX-C1 Bit Size: .9 718" RPM: Hrs. On Bit: Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: Footage for Bit Run drl CMT Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to ft Mud Cut: ppg . Trip Cl: ppm ft Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft Current Lithology: % % % % % ft units ft units ft units PPg . PPg PPg Connection Gas and Mud Cut ft __ units ~ ppg ~ ft __ units .__...-- ppg ~ ft __ units ~ ppg ft __ units ___.- ppg ft units ppg ft units __PPg Depth to to to to Drill Rate . bef .dur aft Drilling Breaks Gas Chlorides Lithology bef dur aft bef dur aft Sd Sst Sit Sh ).4 hr Recap: Nipple up BOPs. ",' Test BOPs. P/U BHA & RIH to E drill ES cementer to about 1635'. Test CSG from top of upper cement stage. Preparing to P/U 4' drill pipe @ report time. Logging Engineer: Tom Mansfield / Mark Lindloff * .... units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. fi/hr Gas* units Temp Out Deg F 24 hr Avg Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: I1,,,~,,.", ......... ""u':[~""'"[ltllllllll II!~wt,!i?lJllill li.1.1.~$1 I il i II!1 I ~ ~ Ii Iii 24 hr Max fi/hr ( fi/hr @ ) unit.. ( units @ ) ( deg F @ ) Report No.: 9 Date: 12/24/00 0:01 Depth Csg @ 3726' Footage Last 24 hrs: 0 Rig Activity: Run Bond Loci Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spin AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Visc 40 secs APl flit 9.0 mi HTHP mi Mud Wtat Max Gas ~ppg MudWtOut 9.20 ppg PV 11 cP YP 17 Ibs/100ft2 Gels 7 \ 10 Ibsll00ft2 pH 9.00 Sd tr % Bit No.: 2 Bit Type: Hu~]hes MX-C1 Bit Size: 9 7~8" Wt On Bit: RPM: Hrs. On Bit: Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: ft Mud Cut: . ppg Trip Cl: , ppm Short Trip Depth ft Short Trip Gas: ft Mud Cut: _.__.-- ppg Short Trip CI: , ppm Tight Spots: tO to to Feet of Fill on Bottom: ft % % % % % Current Lithology: ..... Connection Gas and Mud Cut ft units ppg ft ~ units _._._.-- ppg ft ~ units _.._---- ppg ft ~ units ppg ft ~ units ..__-- ppg ft ~ units ppg ft units ppg ft units ..__...-- ppg . ft units ~PPg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit Sh to to to to 24 hr Recap:. Drill cement. POOH. Run cement bond log. Logging Engineer: Tom Mansfield / M Bernie Leas * ~ units = 100% Gas In Air sp=,r r -surn Mudlogger's Morning Report Current R.O.P. ftJhr Gas* units Temp Out Deg F 24 hr Avg Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors33E Job No.: 24 hr Max ft/hr ( ftJhr @ ) unit: ( units @ ) ( deg F @ ) Report No.: 10 Date: 12/25/00 0:01 Depth Csg @ 3726' Footage Last 24 hrs: 0 Rig Activity: Drl float collar Report For: Joe Polya Show? NA Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Visc Mud Wt Out 9.20 ppg PV 43 secs APl flit 4.2 mi HTHP 14 cP YP 19 Ibsll00ft2 Gels 8 mi Mud Wt at Max Gas ppg \ 14 Ibs/100ft2 pH 8.90 Sd tr % Bit No.: 2 Wt On Bit: Bit Type: Hu~hes MX-C1 Bit Size: RPM: Hrs. On Bit: 9 7/8" Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: Footage for Bit Run Trip Depth: Short Trip Depth Tight Spots: to ft Trip Gas: ft Short Trip Gas: tO ft Mud Cut: ppg Trip CI: ppm ft Mud Cut: ~ppg Short Trip CI: ,ppm to Feet of Fill on Bottom: ft Current Lithology: % ~ % % __ % __ % ft units ft units ft units Connection Gas and Mud Cut ~ ppg ft __ units __ ppg _..--- ppg ~ ft __ units , ppg --_-- ppg ~ ft __ units __ ppg ft ~ units , ppg ft units ppg ft units ppg Depth to to to to Drilling Breaks Drill Rate Gas Chlorides bef dur aft bef dur aft bef dur aft Sd Lithology Sst Sit Sh 24 hr Recap: Ran Cmt bond log. RIH. Test CSG. Drilling float collar at report time. Logging Engineer: Tom Mansfield / Bernie Leas * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. 221 ft/hr Gas* 30 units Temp Out Deg F Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: Ill II ii IIIlitll ~11 [lllll ~llllP. lll#lllllillSiiiiiiiiiiiiiiil]m~.mmliilIJlllll~llllllllll~i.~UllllJllJ~ 24 hr Avg 200 ft/hr ( 25 unit,. ( ( 24 hr Max 800 ft/hr @ 4455 ) 68 units @ 5250' ) deg F @ ) Report No.: 11 Date: 12/26/00 0:01 Depth 5430 Footage Last 24 hrs: 1704 Rig Activity: Drillin~l Report For: Joe Polya Show? Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm ^V @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In Mud Wt Out 9.40 ppg Visc 48 secs APl flit 5.6 mi HTHP mi Mud Wt at Max Gas ~ ppg 9.40 ppg PV 16 cP YP 27 Ibs/100ft2 Gels 13 \ 24 Ibs/100ft2 pH 9.40 Sd 0.3 % Bit No.: 2 , , Wt On Bit: Bit Type: Hughes MX-C1 Bit Size: 9 7/8" 25 RPM: 55 Hrs. On Bit: 15.3 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 1704 Trip Depth: Short Tdp Depth Tight Spots: ft Trip Gas: ft Mud Cut'. _.__--ppg Tdp CI: ppm ft Short Trip Gas: ft Mud Cut: ~ ppg Short Trip CI: ppm to to to Feet of Fill on Bottom: ft Current Lithology: 60 % CL_...___~Y 1...._.~_0 % SL~T 2.._..~_0 % SD . % % Connection Gas and Mud Cut ft units ppg ft __ units _._-- ppg ft ~ units . ppg -- ~ ft units ppg ft __ units .__-- ppg ft __ units ~ ppg · , ft -- units ppg ft units .__ ppg ft units ._------ ppg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft 'bef dur aft Sd Sst Sit Sh 4400 to to to to 4505 :24 hr Recap: Drl fit collar, cmt, & 20' of formation to 3762'. Perform leak off test, 13.7 ppg. Drilled formation to 5430' at report time. Logging Engineer: Tom Mansfield / Bernie Leas * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current 24 hr Avg Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: # 150 ft/hr 200 fi/hr ( 360 Gas* 40 units 30 unit., ( 75 remp Out Deg F ( 24 hr Max ft/hr @ 5635 ) units @ 5640' ) deg F @ ) Report No.: 12 Date: 12/27/00 0:01 Depth 6187 Footage Last 24 hrs: 992 Rig Activity: PREP TIH Report For: Joe Polya Show? Pump and Flow Data Pump 1 69 spm DH flow 550 gpm Pump 2 69 spm Total flow 550 gpm Pump 3 spin AV @ rsr fpm Pump Pres 2000 psi AV @ DC fpm Mud Wt In 9.50 ppg Visc 50 secs APl flit 6.4 Mud Wt Out 9.50 ppg PV 17 cP YP 26 .. Ibs/100ft2 mi HTHP mi Mud Wt at Max Gas ~ppg Gels 12 \ 24 Ibsll00ft2 pH 8.80 Sd 0.3 % Bit No.: 2 Bit Type: Hu~]hes MX-C1 Bit Size: 9 7~8" Wt On Bit: 30 RPM: 80 Hrs. On Bit: 17.7 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 2461 Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to ft Mud Cut: ppg Trip Cl: ppm ft Mud Cut: .. ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft Current Lithology: 50 % CLY 20 % SLT 30 % SD % % Connection Gas and Mud Cut ft units ppg ft ~ units ..__- ppg ft units ppg ft ~ units ___-PPg ft units ppg ft units __----PPg ft ~ units .. ppg ft units ppg ft units ppg Depth 5602 to to to to Drilling Breaks Drill Rate Gas bef dur aft bef dur aft 5710 80 3 0 0 1 00 25' 75 2 0 Chlorides bef dur aft Lithology Sd Sst Sit Cly 30 40 30 24 hr Recap: Drilled to 6187'. Short tripped to shoe. Hole pulled tight, back reamed each stand. Worked on top drive. Preparing to run in hole at report time. 24 hr. Max Gas 75u Logging Engineer: Tom Mansfield / Bernie Leas * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: Current R.O.P. 76 Gas* 65 Temp Out 24 hr Avg fi/hr 133 fi/hr ( units 30 unit,. ( Deg F ( 24 hr Max 400 fi/hr @ 6295 ) 400 units (~ 6470 ) deg F @ ) Report No.: 13 Date: 12/28/00 0:01 Depth 7133 Footage Last 24 hrs: 946 Rig Activity: Drillin~l Report For: Joe Polya Show? Pump and Flow Data Pump 1 69 spin DH flow 550 gpm Pump 2 69 spin Total flow 550 gpm Pump 3 spm AV @ rsr fpm Pump Pres 2000 psi AV @ DC fpm Mud Wt In 9.40 ppg Visc 46 secs APl flit 6.4 mi HTHP mi Mud Wt at Max Gas ._.___ppg Mud WtOut 9.40 ppg PV 14 cP YP 28 Ibsll00ft2 Gels 14 \ 30 Ibs/100ft2 pH 8.50 Sd 0.3 % Bit No.: 2 Bit Type: Hughes MX-C1 Bit Size: 9 7~8" Wt On Bit: 30 RPM: 80 Hrs. On Bit: 17.7 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 3407 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Mud Cut: .. ppg Trip CI: ppm 6187 ft Short Trip Gas: 986 units ft Mud Cut: ___..--ppg Short Trip CI: ppm 6100 to shoe to to Feet of Fill on Bottom: ft Current Lithology: 6._..~_0 % CL~Y 3..._Lo %._.. SLT 10 % S.~..._.~D .__---% . % ft units ft units ft units Connection Gas and Mud Cut ppg ft __ units _._---- ppg ~ ft __ units .___-- ppg ~ ppg ~ ft __ units ~ ppg ft __ units ppg '--'"--- ppg ft units __ ppg ft units _.__- ppg Depth 6282 to 6360 6450 to 6500 to to bef 110 100 Drilling Breaks Drill Rate Gas Chlorides Lithology dur aft bef dur aft bef dur aft Sd Sst Sit Cly 40 0 1 3 0 45 90 70 60 20 20.. 25 0 1 5 0 70 400 40 40 30 30 24 hr Recap: Drilled from 6187' to 7133'. 24 hr. Max Gas 400 units @ 6470', Logging Engineer: Tom Mansfield / Bernie Leas * 10000 units = 100% Gas In Air ............................................... Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: Current R.O.P. 0 fi/hr Gas* 0 units Temp Out Deg F 24 hr Avg 24 hr Max 0 fi/hr ( 0 fi/hr @ 0 ) 0 unit,. ( 0 units @ 0 ) ( deg F @ ) Report No.: 14 Date: 12/29/00 0:01 Depth 8044 Footage Last 24 hrs: 0 Rig Activity: RIH Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 0 spin DH flow 0 gpm Pump 2 0 spm Total flow 0 gpm Pump 3 spin AV @ rsr fpm Pump Pres 2100 psi AV @ DC fpm Mud Wt In 9.40 ppg Mud Wt Out 9.40 ppg Visc 46 secs APl flit 6.4 mi HTHP mi Mud Wt at Max Gas ~ ppg PV 14 cP YP 28 Ibsll00ft2 Gels 14 \ 30 Ibs/100ft2 pH 8.50 Sd 0.3 % ,,= Bit No.: 2 Wt On Bit: Bit Type: Hughes MX-C1 Bit Size: 9718" Jets: 12 \ 18 \ 18 \ 18 \ __\ __TFA: 0.8560 0 RPM: 0 Hrs. On Bit: # 0.0 Total Revs on Bit: na Footage for Bit Run 4318 Trip Depth: ft Trip Gas: Short Trip Depth 0 ft Short Trip Gas: 0 Tight Spots: to shoe to Mud Cut: . ppg Trip CI: ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft Current Lithology: 60 %. CL~Y 20 %._ SLT 20 o~ SD % % Connection Gas and Mud cut ft __ units __-- ppg ~ ft __ units ..._.-..-- ppg ft __ units ~ ppg ~ ft __ units ~ ppg ft units ppg ft units ~ ppg ft units ppg ft units ppg ft units ppg Depth 7630 to to to to Drilling Breaks Drill Rate Gas bef dur aft bef dur aft 7670 86 35 6 1 1 0 35 80 50 Chlorides bef dur aft Lithology Sd Sst Sit Cly Z4 hr Recap: POOH, Test BOPS, RIH TO C[I~AN HOLE FOR LOGGING Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors33E Job No.: Current 24 hr Avg 24 hr Max R.O.P. 0 fi/hr 0 fi/hr ( 0 fi/hr @ 0 ) Gas* 0 units 0 unit,, ( 0 units @ 0 ) Temp Out Deg F ( deg F @ ) Report No.: 15 Date: 12130100 0:01 Depth 8044 Footage Last 24 hrs: 0 Rig Activity: TIH Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 0 spm DH flow 0 gpm Pump 2 0 spm Total flow 0 gpm Pump 3 spm AV @ rsr fpm Pump Pres 0 psi AV @ DC fpm Mud Wt In 9.40 ppg Visc 46 secs APl flit 6.4 mi HTHP mi Mud Wt at Max Gas ~ppg Mud WtOut 9.40 ppg PV 14 cP YP 28 Ibs/100ft2 Gels 14 \ 30 Ibs/100ft2 pH 8.50 Sd 0.3 % Bit No.: 2 Bit Type: Hu~lhes MX-C1 Bit Size: 9 7~8" Wt On Bit: 0 RPM: 0 Hrs. On Bit: # 0.0 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 4318 Trip Depth: ft Trip Gas: Mud Cut: ~ ppg Trip CI: ppm Short Trip Depth 0 ft Short Trip Gas: 0 Mud Cut: ~ ppg Short Trip Cl: ppm Tight Spots: to shoe to to ~ Feet of Fill on Bottom: ft Current Lithology: 60 % CLY 20 % SLT 20 % SD ~ % ~ %~ Connection Gas and Mud Cut ft units ppg ft ~ units ~ ppg ft ~ units .___-- ppg ft units ___-_ ppg ft ~ units ~ ppg ft ~ units __..-- ppg ft units ppg ft ~ units ppg ft ~ units ppg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit Cly to to to to 24 'hr Recap: E LOGGING, TIH FOR CLEANOUT PRIOR TO RUNNING CASING Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: Current R.O.P. 0 fi/hr Gas* 0 units Temp Out Deg F 24 hr Avg 24 hr Max 0 fi/hr ( 0 fi/hr @ 0 ) 2 unit,, ( 5 units @ 0 ) ( deg F @ ) Report No.: 16 Date: 12/31/00 0:01 Depth 8044 Footage Last 24 hrs: 0 Rig Activity: Run C..a..sin~l Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 0 spm DH flow 0 gpm Pump 2 0 spm Total flow 0 gpm Pump 3 spm AV @ rsr fpm Pump Pres 0 psi AV @ DC fpm Mud Wt In 9.40 ppg Mud Wt Out 9.40 ppg Visc 46 secs APl flit 6.4 PV 14 cP YP 28 Ibs/100ft2 ,, mi HTHP mi Mud Wt at Max Gas ppg Gels 14 \ 30 Ibs/100ft2 pH 8.50 Sd 0.3 Bit No.: 2 Bit Type: Hucjhes MX-C1 Bit Size: 9 7~8" Wt On Bit: 0 RPM: 0 Hrs. On Bit: # 0.0 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 4318 Trip Depth: 8044 ft Trip Gas: 55 Short Trip Depth 0 ft Short Trip Gas: 0 Tight Spots: to shoe to Mud Cut: . , ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Current Lithology: 60 % CLY 20 % SLT 20 % SD Connection Gas and Mud Cut ft __ units ..___.-- ppg ft __ units ~ ppg ~ ft ~ units ~ ppg ft ~ units ~ ppg ~ ft ~ units .....-___ ppg ~ ft ~ units ~ ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas Chlorides bef dur aft bef dur aft bef dur aft to to to to Lithology Sd Sst Sit Cly 24 hr Recap: CIR B/U, POOH, START RIH WITH CASING MAX GAS CIRC OUT = 36 UNITS Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air I . Mudlogger's Morning Report Current R.O.P. 0 fi/hr Gas* 2 units Temp O~Jt Deg F 24 hr Avg Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: AKAM00307 24 hr Max fi/hr ( 0 fi/hr @ 0 unit., ( 36 units @ 8044 ( deg F @ Report No.: 17 Date: 1/1/01 0:00 Depth 8044 Footage Last 24 hrs: 0 Rig Activity: Cementin~i Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 0 spm DH flow 0 gpm Pump 2 0 spm Total flow 0 gpm Pump 3 spm AV @ rsr fpm Pump Pres 0 psi AV @ DC fpm Mud Wt In 9.50 ppg Visc 48 secs APl flit 9.2 mi HTHP mi Mud Wt at Max Gas ~ppg Mud WtOut 9.50 ppg PV 18 cP YP 48 Ibs/100ft2 Gels 10 \ 29 Ibs/100ft2 pH 10.60 Sd 0.3 % Bit No.: 2 Bit Type: Hughes MX-C1 Bit Size: 9 7~8" Wt On Bit: 0 RPM: 0 Hrs. On Bit: # 0.0 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 4318 Trip Depth: 8044 ft Trip Gas: 35 Mud Cut: . . ppg Trip CI: ppm Short Trip Depth 0 ft Short Trip Gas: 0 Mud Cut: .._...--ppg Short Trip CI: ppm Tight Spots: to shoe to to Feet of Fill on Bottom: ft 60 % CLY 20 % SLT 20 %. SD % % Current Lithology: ..... Connection Gas and Mud Cut ft units ppg ft ~ units ~ ppg ft ~ units ~ ppg · ft ~ units ppg ft ~ units ppg ~ ft ~ units ppg ft ~ units ppg ft units ____- ppg ft units __.....- ppg Drilling Breaks Depth Drill Rate Gas Chlorides Lithology bef dur aft bef dur aft bef dur aft Sd Sst Sit to to to to Cly 24 hr Recap: Finish Casing Run, Circulate to condition Hole for Cementing, Start Cementing 36 MAX UNITS GAS CIRC CASING Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. 0 ft/hr Gas* 0 units Temp Out Deg F Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: AKAM00307 i 24 hr Avg 24 hr Max 0 fi/hr ( 0 fi/hr @ 0 ) 0 unit,,( 0 units @ ) ( deg F @ ) Report No.: 18 Date: 1/2/01 0:01 Depth 8044 Footage Last 24 hrs: 0 Rig Activity: Prep to drill Cement Report For: Paul Lockwood Show? , Pump and Flow Data Pump 1 0 spm DH flow 0 gpm Pump 2 0 spm Total flow 0 gpm Pump 3 spm AV @ rsr fpm Pump Pres 0 psi AV @ DC fpm Mud Wt In 9.50 ppg Mud Wt Out 9.50 ppg Visc 48 secs APl flit 9.2 PV 18 cP YP 48 Ibs/100ft2 mi HTHP mi Mud Wt at Max Gas. .PPg Gels 10 \ 29 Ibsll00ft2 pH 10.60 Sd 0.3 % Bit No.: 2 Wt On Bit: Bit Type: Hu~hes MX-C1 Bit Size: 9 718" 0 RPM: 0 Hrs. On Bit: # 0.0 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 4318 Trip Depth: Short Trip Depth Tight Spots: 8044 ft Trip Gas: 35 0 ft Short Trip Gas: 0 to shoe to Mud Cut: ppg Trip CI: ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft Current Lithology: 60 % CLY 20 % SLT 20 % SD , ,, ,, % % units units units Connection Gas and Mud Cut ppg ft __ units .._----. ppg ppg ft __ units ~PPg ppg ft units ~ ppg ft units ppg ft units ppg ft units ppg Depth to to to to Drilling Breaks Drill Rate Gas Chlorides bef dur aft bef dur aft bef dur aft Sd Lithology Sst Sit Cly 24 hr Recap: Successfuly Complete Cement Job As Per Well Plan, Laying Down Cement Tools, Prep to P/U BHA Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. 0 fi/hr Gas* 0 units Temp Out Deg F Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors33E Job No.: AKAM00307 ~mmum~. ~!~mmfluuu.qlllm ~[tll ~lmm,u, h m# iiiii ~iemmmammmn~ 24 hr Avg 24 hr Max 0 fi/hr ( 0 fi/hr @ 0 ) 0 unit.~ ( 0 units @ ) ( deg F @ ) Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Show? 19 1/3/01 0:00 8044 0 Drill Out Cement Joe Polya Pump and Flow Data Pump 1 0 spm DH flow Pump 2 57 spm Total flow Pump 3 spm AV @ rsr Pump Pres 718 psi AV@ DC 0 238 gpm gpm fpm fpm Mud Wt In 9.40 ppg Mud Wt Out 9.40 ppg Visc 42 secs APl flit 6.0 PV 15 cP YP 15 Ibs/100ft2 ,, mi HTHP mi Mud Wtat Max Gas ppg Gels 7 \ '~'5 Ibsll00ft2 pH 10.00 Sd 0.3 Bit No.: 5 Bit Type: Smith XR+ Bit Size: 6 3/4 Jets: 12 \ 18 \ 18 \ Wt On Bit: 0 RPM: 25 Hrs. On Bit: # 1.0 Total Revs on Bit: na 18 \ \ TFA: 0.4510 ,= Footage for Bit Run 99 Trip Depth: 8044 ft Trip Gas: 0 Mud Cut: Short Trip Depth 0 ft Short Trip Gas: 0 Mud Cut: Tight Spots: ~ to shoe to ~ to ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Current Lithology: 60 % CLY 20 % SLT 20 % SD % % Connection Gas and Mud Cut ft units ppg ft ~ units ~PPg ft units ppg ft ~ units ppg ft units ~ ppg . ft units ~ ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas Chlorides bef dur aft bef dur aft bef dur aft to to to to Lithology Sd Sst Sit Cly 24 hr Recap: P/U BHA, RIH F/Derrick lxl, Tag CMT @ 5911' Test Casing @ 500 PSI, Cont Drill Out Cmt T/6010' Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air rll=lll__l__l ~ I~ SEI::IVICES Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: AKAM00307 Current 24 hr Avg 24 hr Max R.O.P. 0 ft/hr 0 fi/hr ( 0 fi/hr @ 0 ) Gas* 0 units 0 unit., ( 0 units @ ) Temp Out Deg F ( ~ deg F @ ) Report No.: 20 Date: 1/4/01 0:00 Depth 8044 Footage Last 24 hrs: 0 Rig Activity: Drill Out Cement Report For: Joe Polya Show? Pump and Flow Data Pump 1 55 spm DH flow 233 gpm Pump 2 #0 spm Total flow 0 gpm Pump 3 spm AV @ rsr fpm Pump Pres 800 psi AV@ DC fpm Mud Wt In 9.40 ppg Visc 71 secs APl flit 11.0 mi HTHP mi Mud Wt at Max Gas ~ppg MudWtOut 9.40 ppg PV 25 cP YP 30 Ibs/100ft2 Gels 14 \ 32 Ibs/100ft2 pH 11.20 Sd 0.3 % Bit No.: 5 Bit Type: Smith XR+ Bit Size: 6 3/4 Wt On Bit: 5110 RPM: 50 Hrs. On Bit: Jets: 14 \ 14 \ 14 \ 0 \ \ TFA: 0.4510 Total Revs on Bit: na Footage for Bit Run Trip Depth: 8044 Short Trip Depth 0 Tight Spots: ft Trip Gas: 0 Mud Cut: ~PPg Trip Cl'. ppm ft Short Trip Gas: 0 Mud Cut: __._.--ppg Short Trip CI: ppm to shoe to to Feet of Fill on Bottom: ft Current Lithology: 60 % CLY 20 % SLT 20 % SD ~ % ~ %~ Connection Gas and Mud Cut ~ ft __ units __...-_ ppg ft __ units ....._...-- ppg ft __ units ~ ppg ft ~ units ~ ppg ft ~ units ~ ppg ft ~ units ._..._...- ppg ft units ppg ft ~ units ~ ppg ft ~ units ~ ppg Depth Drill Rate bef dur aft to to to to Drilling Breaks Gas Chlorides Lithology bef dur aft bef dur aft Sd Sst Sit Cly 24 hr Recap: Cont Drlg CMT F6010' - T6095', Drill ES Cementer, Test CSG @ 6124' ~ 500 PSI, Test OK ' PU 4" Pipe, Drill CMT F7725' T7975', CBU, POOH, Rig up for Bond Logs. Logging Engineer: Doug Wilson/Mark Lindloff * 100'00 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. 0 fi/hr Gas* 0 units Temp Out Deg F Customer: BP Alaska Well: Northstar NS 10 Area: North Slope Lease: Northstar NS 10 Rig: Nabors 33E Job No.: AKAM00307 24 hr Avg 24 hr Max 0 fi/hr ( 0 fi/hr @ 0 ) 0 unit., ( 0 units @ ) ( deg F @ ) Report No.: 21 Date: 1/5/01 0:00 Depth 8044 Footage Last 24 hrs: 0 Rig Activity: RIH Report For: Joe Polya Show? Pump and Flow Data Pump 1 59 spm DH flow 250 gpm Pump 2 #0 spm Total flow 0 gpm Pump 3 spm AV @ rsr fpm Pump Pres 800 psi AV @ DC fpm Mud Wt In Mud Wt Out 9.40 ppg Visc 60 secs APl flit 10.9 mi HTHP mi Mud Wt at Max Gas ~ppg 9.40 ppg PV 20 cP YP 31 Ibsll00ft2 Gels 12 \ 24 Ibs/100ft2 pH 10.70 Sd TR % Bit No.: 3 Wt On Bit: Bit Type: Smith XR+ Bit Size: 6 314 0 RPM: 0 Hrs. On Bit: Jets: 14 \ 14 \ 14 \ 0 \ \ TFA: 0.4510 Total Revs on Bit: na 'Footage for Bit Run Trip Depth: Short Trip Depth Tight Spots: 8044 ft Trip Gas: 0 Mud Cut: __ ppg Trip CI: ppm 0 fi Short Trip Gas: 0 Mud Cut: ___-ppg Short Trip Cl: ppm to shoe to to Feet of Fill on Bottom: ft Current Lithology: 60 % CLY. 20 % SLT 20 % SD ~ % ~ % Connection Gas and Mud Cut fi units ~ppg ~fi__units ~ppg fi__ fi__units ~ppg fi__units ~ppg fi__ fi units __ppg fi units ._...._.ppg fi units ppg units ppg units ...__.-- ppg Drilling Breaks Depth Drill Rate Gas Chlorides bef dur aft bef dur aft bef dur aft to to to to Sd Lithology Sst Sit Cly 24 hr Recap: Run Bond Logs, PU BHA, PU DP, RIH, Slip & Cut Drill Line, Service Top Drive, RIH T4200 Fill Pipe/Cont RIH T/7975', Cir & Cond Mud For CSG TEST Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air Show Reports NO SHOWS ENCOUNTERED IN THIS WELL. Bitrun - Summary Bitrun Summary Run Time Data MWD Run: Rig Bit No: Hole Size: Run Start: Run End: BRT Hrs: Circ. Hrs: Oper. Hrs: 0100 1 13.50 in 14-Dec-00 10:26 17-Dec-00 04:56 66.50 0.00 0.00 MWD Schematics Drilling Data Start Depth: End Depth: Footage: Avg. Flow Rate: Avg. RPM: Avg. WOB: Avg. ROP: Avg. SPP: (16) 15; 114; :13' Ill (10 (9) (8) (7) (6) (2) (1) Comments 159.00 ft 3742.00 ft 3583.00 ft 650.00 gpm 40.00 rpm 15.00 klb 250.00 fph 1600.00 psig Mud Data Mud Type: Water Based Weight / Visc: 9.30 ppg I 90.00 spqt Chlorides: 41000.00 ppm PV I YP: 25.00 cp / 51.00 Ihf2 Solids/Sand: % / % %Oil/O:W: % I pH/Fluid Loss: 8.50 pH / 0.00 rnptm Max. Temp.: 0.00 degF BHA Schematics Component Length O.D. I.D. (ft) (in) (in) 16. Drill Pipe 2830.00 5.000 4.280 15. HWDP 600.67 5.000 3.000 14. Ddlling Jars 32.96 7.750 2.750 13. HWDP 89.91 5.000 3.000 12. Cross Over Sub 2.05 7.875 2.875 11. Monel collar 30.82 8.000 2.810 10. Monel Stabilizer 5.72 8.000 2.810 09. Monel collar 60.66 8.000 2.810 08. Monel Stabilizer 5.56 8.000 2.810 07. Power Pulse MWD 29.02 8.250 5.125 06. Monel Stabilizer 5.59 8.000 2.810 05. Monel collar 9.53 8.000 2.810 04. Monel Lead collar 10.45 8.000 2.810 03. 3/4 4.5 Stage Mud Motor 26.64 , 9.675 7.875 02. Cross Over Sub 0.90 8.821 2.821 01. Smith MalSL 1.50 13.500 3.240 MWD Performance 13 1/2" HOLE SECTION GAS OCCURENCES, CASING POINT, L.O.T. , BIT HRS 10 3/4" 45.5 LBIFT CASING WAS SET AT 3726' MD. LEAK OFF . TEST AT 3762' MD = 13.7 PPG EMW, BIT HRS - 37.3. FIRST OCCURENCE OF GAS ( METHANE )- 3 UNITS FOUND AT 1308' MD. 17 UNITS OF GAS (METHANE'~ ~,~,, ~,,,,. ) FOUND AT THE BASE OF THE PERMAFROST AT 1562' MD. AT '-2700' MD I ............ GAS INCREASED TO 37 UNITS ( METHANE ) ASSOCIATED WITH COAL I Max. Inc.: FORMATIONS. MAXIMUM GAS IN THIS INTERVAL WAS SEEN AT 3570' MD- 42 I Final Az · UNITS !METHANE ). 13 1/2" HOLE SECTION T.D. AT 3742' MD, SHORT TRIPPED I ' ' TO 728. SHORT TRIP GAS 24 UNITS I Max Op. Press. · Tool'OD/Type: 0.00 · in / MWD Real-time%: 0.00 % / MWD Recorded%: 0.00 % / 0.00 deg / 0.00 deg / 0.00 deg 0.00 psig 0.00 % 0.00 % 0.00 ft 0.00 ft Job No.: AKAM00307 Well No.: Northstar NS-10/WO-0'~ End of Well Report Page 4 Run Time Data MWD Run: Rig Bit No: Hole Size: Run Start: Run End: BRT Hrs: Circ. Hrs: Oper. Hrs: 0200 2 9.88 in 25-Dec-00 00:52 28-Dec-00 23:27 94.58 0.00 0.00 MWD Schematics Bitrun Summary Drilling Data Mud Data Start Depth: End Depth: Footage: Avg. Flow Rate: Avg. RPM: Avg. WOB: Avg. ROP: Avg. SPP: 3742.00 ft 8044.00 ft 4302.00 ft 650.00 gpm 50.00 rpm 15.00 klb 130.00 fph 2400.00 psig Mud Type: Water Based Weight /Visc: 9.50 ppg / Chlorides: 40000.00 ppm PV/YP: 17.00 cp / Solids/Sand: % / %Oil / O:W: % / pH/Fluid Loss: 8.80 pH / Max. Temp.: 0.00 degF 49.00 26.00 0.00 BHA Schematics (11) (10) (9) ~8) (7) (6) Component Length O.D. I.D. (ft) (in) (in) spqt Ihf2 % mptm 11. Ddll Pipe 7213.00 5.000 4.280 10. HWDP 600.67 5.000 3.000 09. Dailey Hydraulic 32.69 6.500 2.750 08. HWDP 89.91 5.000 3.000 07. Monel 31.04 7.000 2.810, 06. Monel 31,01 7.000 2.810 05. Monel Stabilizer 5.70 9.875 2.875 04. Monel 31.15 7.060 2.810 03. Monel Stabilizer 5.70 7.000 2.875 02. Bit Sub w/float 2.13 8.000 4.000 01. HTCMX-Cl 1.00 9.875 4.280 Comments MWD Performance Tool OD/Type: 0.00 in / MWD Real-time%: 0.00 % / 0.00 MWD Recorded%: 0.00 % / 0.00 Min. Inc.: 0.00 deg/ 0.00 Max. Inc.: 0.00 deg/ 0.00 Final Az.: 0.00 deg Max Op. Press.: 0.00 psig 9 7/8" HOLE SECTION - GAS OCCURENCES, CASING, L.O.T., BIT HRS 7 5/8" 29.7 LB/FT CASING SET AT 8029' MD, LEAK OFF TEST AT 8064' MD = 12.0 PPG EMW, BIT HOURS= 98.0. FROM 3742-6150' MD GAS AVERAGED 35-75 UNITS( METHANE ). AT 6187' MD SHORT TRIP GAS WAS 980 UNITS NEAR THE TMBK. FROM 6150-7225' MD GAS AVERAGED 40-100 UNITS WITH PEAKS OF 400 UNITS ( 6460-6480' MD ), 200 UNITS ( 6545-6565' MD ), 200 UNITS ( 6620-6655' MD ), 109 UNITS ( 7075-7085' MD ), 125 UNITS ( 7195-7200' MD ) AND 120 UNITS (7300-7320' MD ) IN THE UG3. A SHORT TRIP AT 7225' MD YIELDED GAS OF 165 UNITS. FROM 7320-8044' MD GAS AVERAGED 30-90 UNITS. 9 7/8" HOLE SECTION T.D. AT 8044' MD. Job No.: AKAM00307 Well No.: Northstar NS-10/WD-01 End of Well Report Page 6 Run Time Data MWD Run: Rig Bit No: Hole Size: Run Start: Run End: BRT Hrs: Circ. Hrs: Oper. Hrs: O3OO 3 6.75 in 06-Jan-01 05:10 06-Jan-01 15:49 10.64 0.00 0.00 MWD Schematics Bitrun Summary Drilling Data Start Depth: End Depth: Footage: Avg. Flow Rate: Avg. RPM: Avg. WOB: Avg. ROP: Avg. SPP: (3) ~ (2) Comments 6 314" HOLE SECTION - GAS OCCURENCES, BIT HOURS. 8044.00 It 8246.00 It 202.00 tt 430.00 gpm 40.00 rpm 15.00 klb 45.00 fph 1300.00 psig Mud Data Mud Type: Water Based Weight I Visc: 9.40 ppg / Chlorides: 38000.00 ppm PV / YP: 20.00 cp / Solids/Sand: % / %Oil / O:W: % / )H/Fluid Loss: 10.70 pH / Vlax. Temp.: 0.00 degF 60.00 spqt 31.00 Ihf2 % 0.00 mptm BHA Schematics Component Length O.D. I.D. (fl) (in) (in) 11. Drill Pipe 7915.11 4.000 3.240 10. Cross Over Sub 2.37' 5.000 2.500 09. DAILEY HYD Drilling Jars 30.16 4.750 2.250 08. MONEL DC 31.04 4.750 2.250 07. MONEL DC 31.04 4.750 2.250 06. Monel Stabilizer 5.77 4.750 2.250 05. MONEL DC 31.04 4.750 2.312 04. MWD SlimPulse 33.82 4.625 2.000 03. Float Sub 2.00 4.750 2.000 02. NB STEEL STAB 4.49 4.750 2.000 01. SMITH xR+ 0.75 6.750 4.280 BIT HOURS= 7.6. MWD Performance Tool OD/Type: 8.00 in / 8 314" INTERVAL FROM 8044-8246' MD SAW AVERAGE GAS OF 20-30 UNITS WITH A MAXIMUM OF 37 UNITS AT 8130-8160' MD. T.D. OF THIS INTERVAL WAS 8246' MD. ~ Real-time%: 0.00 % / 0.00 MWD Recorded%: 0.00 % / 0.00 Min. Inc.: 0.00 deg/ 0.00 Max. Inc.: 0.00 deg/ 0.00 Final Az.: 0.00 deg Max Op. Press.: 0.00 psig % % ft ft Job No.: AKAM00307 Well No.: Northstar NS-10/WD-01 End of Well Report Page 7 Directional Survey Data ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Northstar Well ..................... : NS10 API number ............... : 50-029-22985-00 Engineer ................. : J. Rathert RIG: ..................... : Nabors 33E STATE: ................... : Alaska Survey calculation methods - Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 15.57 ft KB above permanent ....... : Top Drive DF above permanent ....... : 40.20 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 201.40 degrees 6-Jan-2001 16:34:11 Page 1 of 4 Spud date ................ : 14-Dec-00 Last survey date ......... : 06-Jan-01 Total accepted surveys...: 87 MD of first survey ....... : 0.00 ft MD of last survey ........ : 8246.00 ft Geomagnetic data ........... Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 12-Dec-2000 Magnetic field strength..: 1149.75 HCNT Magnetic dec (+E/W-) ..... : 26.92 degrees Magnetic dip ............. : 80.91 degrees MWD survey Reference Criteria Reference G .............. : 1002.69 mGal Reference H .............. : 1149.75 HCNT Reference Dip ............ : 80.91 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections -- Magnetic dec (+E/W-) ..... : 26.92 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.92 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [ (c) 2001 Anadrill IDEAL ID6_lC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 385.52 1.84 7.55 3 476.11 1.82 5.98 4 565.89 1.66 10.40 5 657.37 1.39 358.29 0.00 385.52 90.59 89.78 91.48 6 746.00 1.17 260.29 7 833.23 2.55 224.31 8 932.53 3.72 217.92 9 1027.76 5.88 211.02 10 1121.34 7.69 207.06 88 87 99 95 93 6-Jan-2001 16:34:11 11 1215.21 8.89 206.08 12 1310.48 10.08 208.87 13 1407.83 11.50 205.95 14 1501.19 12.91 198.69 15 1596.17 13.85 198.91 93 95 97 93 94 16 1690.01 16.34 202.99 17 1784.56 19.07 205.14 18 1879.16 21.93 205.17 19 1974.26 27.25 207.78 20 2067.11 30.28 208.07 93 94 94 95 92 Page 21 2162.61 31.97 202.20 22 2256.19 35.57 200.99 23 2351.18 39.03 202.21 24 2446.19 43.02 201.95 25 2540.31 45.97 200.60 95 93 94 95 94 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 26 2634.91 46.27 197.98 27 2727.53 44.88 198.58 28 2821.92 46.13 199.06 29 2917.75 47.53 198.05 30 3012.50 48.60 197.75 2 of 4 DLS (deg/ 100f) Srvy tool type 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 385.45 -6.01 6.14 0.81 6.19 7.55 0.48 MWD 476.00 -8.81 9.01 1.15 9.08 7.30 0.06 MWD 565.74 -11.46 11.71 1.54 11.81 7.48 0.23 MWD 657.18 -13.78 14.12 1.74 14.23 7.04 0.46 MWD .63 745.80 -14.30 15.04 0.82 15.06 .23 832.98 -12.05 13.50 -1.41 13.57 .30 932.13 -6.93 9.38 -4.94 10.60 .23 1027.03 0.84 2.76 -9.35 9.75 .58 1119.95 11.80 -6.92 -14.67 16.22 .87 1212.83 25.28 -19.03 -20.71 28.13 .27 1306.80 40.88 -32.95 -27.98 43.22 .35 1402.43 59.00 -49.13 -36.34 61.11 .36 1493.68 78.70 -67.38 -43.75 80.34 .98 1586.08 100.66 -88.19 -50.84 101.79 .84 .55 .60 .10 .85 .50 .58 .99 .01 .12 125.08 -110.97 -59.63 125.98 153.79 -137.20 -71.39 154.66 186.85 -167.19 -85.47 187.77 226.23 -202.55 -103.19 227.32 270.62 -242.02 -124.12 2'71.99 319.83 -286.69 -145.00 321.27 371.83 -335.05 -164.12 373.09 429.39 -388.55 -185.33 430.49 491.73 -446.33 -208.76 492.74 557.69 -507.80 -232.67 558.57 625.81 -572.15 -255.19 691.86 -634.95 -275.93 759.12 -698.68 -297.66 828.92 -764.94 -319.89 899.27 -832.01 -341.55 94.60 92.62 94.39 95.83 94.75 626.48 692.32 759.44 829.13 899.39 3 354 332 286 244 227 220 216 213 209 208 207 207 207 207 .12 .02 .24 .45 .73 .42 .34 .49 .00 .96 .25 .49 .08 .00 .15 206.83 206.10 205.50 205.07 204.62 204 203 203 202 202 .04 .49 .08 .69 .32 1676.68 1766.74 1855.34 1941.79 2023.17 2104.94 2182.72 2258.27 2329.94 2397.07 2.19 2.00 1.23 2.34 2.00 1.29 1.34 1.56 2.23 0.99 2.88 2.97 3.02 5.71 3.27 3.63 3.91 3.72 4.20 3.29 2.02 1.57 1.37 1.65 1.15 2462.64 2527.47 2593.63 2659.19 2722.51 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001Anadrill IDEAL ID6 lC 08] ANADRILL SCHLUMBERGER Survey Report 6-Jan-2001 16:34:11 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool ~ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 31 3107.88 49.09 197.82 95.38 2785.28 970.94 -900.39 -363.49 970.99 201.98 0.52 MWD 6-axis 32 3202.62 49.01 197.69 94.74 2847.37 1042.36 -968.54 -385.31 1042.37 201.69 0.13 MWD 6-axis 33 3297.76 48.33 198.12 95.14 2910.20 1113.66 -1036.52 -407.27 1113.66 201.45 0.79 MWD 6-axis 34 3390.96 49.10 198.54 93.20 2971.69 1183.60 -1103.00 -429.30 1183.60 201.27 0.89 MWD 6-axis 35 3485.83 48.57 198.97 94.87 3034.14 1254.94 -1170.63 -452.26 1254.95 201.12 0.65 MWD 6-axis 36 3581.79 49.16 198.90 95.96 3097.27 1327.15--1238.99 -475.71 1327.18 201.00 0.62 MWD 6-axis 37 3666.88 48.69 198.56 85.09. 3153.17 1391.22 -1299.74 -496.31 1391.27 200.90 0.63 MWD 6-axis 38 3760.88 48.03 197.79 94.00 3215.63 1461.36 -1366.48 -518.22 1461.45 200.77 0.93 MWD 6-axis 39 3855.54 47.54 197.88 94.66 3279.23 1531.33 -1433.22 -539.69 1531.47 200.63 0.52 MWD 6-axis 40 3950.41 46.98 198.59 94.87 3343.62 1600.90 -1499.40 -561.50 1601.08 200.53 0.81 MWD 6-axis 41 4045.57 50.80 198.46 95.16 3406.18 1672.49 -1567.37 -584.27 1672.73 200.44 4.02 MWD 6-axis 42 4140.12 51.02 201.01 94.55 3465.80 1745.84 -1636.43 -609.05 1746.10 200.41 2.11 MWD 6-axis ~3 4235.21 50.29 200.72 95.09 3526.09 1819.37 -1705.15 -635.24 1819.63 200.43 0.80 MWD 6-axis 44 4328.76 49.34 200.45 93.55 3586.45 1890.83 -1772.05 -660.37 1891.10 200.44 1.04 MWD 6-axis 45 4424.39 51.35 201.24 95.63 3647.47 1964.45 -1840.85 -686.57 1964.72 200.45 2.20 MWD 6-axis 46 4520.13 51.27 200.63 95.74 3707.32 2039.17 -1910.65 -713.27 2039.44 200.47 0.50 MWD 6-axis 47 4615.13 50.43 199.95 95.00 3767.30 2112.83 -1979.74 -738.82 2113.11 200.47 1.04 MWD 6-axis 48 4707.70 51.14 203.08 92.57 3825.84 2184.54 -2046.45 -765.13 2184.81 200.50 2.73 MWD 6-axis 49 4801.06 50.54 202.70 93.'36 3884.79 2256.90 -2113.14 -793.29 2257.13 200.58 0.72 MWD 6-axis -50 4897.39 49.59 201.04 96.33 3946.63 2330.76 -2181.68 -820.81 2330.97 200.62 1.65 MWD 6-axis 51 4992.97 49.97 202.32 95.58 4008.35 2403.73 -2249.49 -847.77 2403.94 200.65 1.10 MWD 6-axis 52 5088.27 49'.51 201.68 95.30 4069.94 2476.45 -2316.92 -875.01 2476.65 200.69 0.70 MWD 6-axis 53 5182.29 49.61 200.82 94.02 4130.92 2548.01 -2383.61 -900.95 2548.20 200.71 0.70 MWD 6-axis 54 5275.45 49.70 201.96 93.16 4191.24 2619.01 -2449.72 -926.84 2619.19 200.72 0.94 MWD 6-axis 55 5370.49 49.45 200.71 95.04 4252.87 2691.36 -2517.11 -953.17 2691.54 200.74 1.04 MWD 6-axis 56 5464.32 49.89 201.87 93.83 4313.59 2762.89 -2583.75 -979.14 2763.06 200.75 1.05 MWD 6-axis 57 5559.08 49.24 201.28 94.76 4375.05 2835.01 -2650.83 -1005.66 2835.18 200.78 0.83 MWD 6-axis 58 5653.77 48.94 201.27 94.69 4437.06 2906.57 -2717.51 -1031.63 2906.74 200.79 0.32 MWD 6-axis 59 5749.32 49.23 201.98 95.55 4499.64 2978.77 -2784.63 -1058.24 2978.93 200.81 0.64 MWD 6-axis 60 5843.42 48.83 201.95 94.10 4561.34 3049.82 -2850.52 -1084.81 3049.97 200.84 0.43 MWD 6-axis [(c)2001 Anadrill IDEAL ID6 lC 08] ANADRILL SCHLUMBERGER Survey Report 6-Jan-2001 16:34:11 Page 4 of 4 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 61 5937.40 48.20 201.10 93.98 62 6031.76 47.88 200.94 94.36 63 6124.17 47.22 202.23 92.41 64 6222.54 47.04 201.21 98.37 65 6316.56 46.80 200.91 94.02 66 6411.89 46.26 201.59 95.33 67 6505.23 45.17 203.06 93.34 68 6600.34 43.01 203.92 95.11 69 6695.06 39.80 205.36 94.72 70 6789.16 35.43 203.44 94.10 71 6883.86 31.40 207.22 94.70 72 6979.60 29.07 204.33 95.74 73 7073.70 27.98 201.51 94.10 74 7168.93 26.35 200.16 95.23 75 7262.06 26.44 200.67 93.13 76 7356.04 26.11 199.12 93.98 77 7450.34 25.98 199.68 94.30 78 7544.26 26.58 204.12 93.92 79 7638.44 26.46 204.59 94.18 80 7732.30 26.56 203.41 93.86 81 7827.04 26.25 204.03 94.74 82 7920.13 26.06 201.95 93.09 83 7986.52 25.69 203.62 66.39 84 8065.35 26.65 202.66 78.83 85 8159.62 30.79 200.17 94.27 86 8217.35 33.08 -198.95 57.73 projected to TD 87 8246.00 34.20 198.40. 28.65 4623.59 4686.68 4749.06 4815.98 4880.20 4945.79 5010.96 5079.27 5150.31 5224.83 5303.87 5386.58 5469.26 5553.99 5637.41 5721.68 5806.40 5890.62 5974.89 6058.88 6143.74 6227.30 6287.04 6357.78 6440.44 6489.43 6513.28 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 3120.22 -2916.02 -1110.65 3190.39 -2981.51 -1135.82 3258.57 -3044.92 -1160.90 3330.66 -3111.89 -1187.58 3399.33 -3175.98 -1212.25 3468.52 -3240.46 -1237.33 3535.32 -3302.27 -1262.70 3601.45 -3362.96 -1289.07 3663.99 -3419.90 -1315.16 3721.32 -3472.17 -1338.92 3773.32 -3519.31 -1361.13 3821.37 -3562.69 -1382.13 3866.28 -3604.06 -1399.64 3909.75 -3644.69 -1415.12 3951.15 -3683.49 -1429.56 3992.73 -3722.60 -1443.72 4034.11 -3761.66 -1457.47 4075.66 -3800.21 -1472.98 4117.66 -3838.52 -1490.33 4159.51 -3876.79 -1507.37 4201.61 -3915.36 -1524.31 4242.62 -3953.13 -1540.34 4271.58 -3979.84 -1551.56 4306.33 -4011.81 -1565.21 4351.61 -4053.99 -1581.69 4382.13 -4082.77 -1591.90 4397.98 -4097.80 -1596.98 3120.37 200.85 3190.53 200.85 3258.71 200.87 3330.80 200.89 3399.47 200.89 3468.65 200.90 3535.44 200.93 3601.55 200.97 3664.06 201.03 3721.37 201.09 3773.36 201.14 3821.39 201.20 .3866.30 201.22 3909.77 201.22 3951.17 201.21 3992.76 201.20 4034.14 201.18 4075.69 201.19 4117.68 201.22 4159.53 201.25 4201.62 201.27 4242.63 201.29 4271.59 201.30 4306.34 201.31 4351.62 201.31 4382.14 201.30 0.95 0.36 1.25 0.78 0.35 0.77 1.62 2.36 3.53 4.81 4.79 2.87 1.84 1.83 0.26 0.81 0.29 2.19 0.26 0.57 0.44 1.01 1.23 1.33 4.57 4.12 4397.99 201.29 4.05 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD SP SP SP MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_IC_08] Mud Reports Baroid REPORT NUMBER: 1 DRILLING MUD REPORT IDate I Depth 12/13/001 199 ft [MD] I ~IWSLLIStatelC°~tY I Well 1S/~ Spud Dare,Present Activity me~ IslOlol~/91~l~lBislslol~ ~/1~/OOl P~-~ING TO SPUD OPE~TOR ICO~C~OR RIG ~ER ADW INABORS 33E REPORT FOR IREPORT FOR SECT,TWNSHP,RNG JOE POLYA/ MIKE DINGER I FINKBINDER/ ASHT. FY Sll T13N R13E WELL NAME AND NUMBER IFIELD OR BLOCK NSlO CLASS I DISPOSAL WELLINORTH STAR BIT DATA lin. DRILLING STRING ft ~ ~i~ ~ 5 ID 4.276 L~. 199 I Punp ,ak,~el ~i~ ~ ID Mn. in. ft Size 6 X 12 [Eff. 96.001 V/st ~i~ OD ID Mn. 20 Set @ 199 [ s~ 150 ]bbl/,in 15.1 ] [ IollatOD ID Len. in. OPEN HOLE ~ot Noz tzea [Size I~n. TFA [Size Len. ]'si~e ~n. ~Size ~n. ]size ~. ft COUNTY, PARISH, OS. AREA[ST/PRV NORTH SLOPE AK CASING CIRCULATION DATA [ l~p Hake ./MoO__el Set @ Size 6 X 12 ]l~f. 96.00] V/st Set @ l spin 0 ]bbl/uin 0.0 Set @ [ eu~p ,~k~/Model [ Size X [l~f. 0.001 V/st [sp~ 0[bbl/.in ' 0.0 ] Tot. Vol./nih 635 ~pu 15.1 [ ~ ~ine 4 [~ ~in 72 ~EA~NTS Set @ 2 3 Set @ Set @ Set@ Essential Pro~am 0.1 0.1 0.0 properties as per p:o~'an as ckill out Eton under conducto~ COST REFLECTS, 4 ENOIIIEERS ITTRRDll~ TRUE ~HNIIIG,,. PLUS EliGI'HEERIliG CIIAIEES 01{ LOCAtiON S~CS 11/21/00 COST REFLECTS HUD UP ~ILL ~ RUD PLUS COST OF HUD UP OF KCL l:q)LYll~lt tlUD SYST~! RIG ACTIVITY up and test equipment- hud up Preparations to spud mud check 1 shows mud in active mud check 2 shows kill et mud stored in Gt: l~oid re,ired to raise ~t of 1500 bbl by PlXI; 880 sk. current inventor}, 14328 sk. NAT~aIAL~ USED ~uct Used Cost AU)ACIDS O - 55 GAL. Dm( 1 1281.07 BARABRIHE DKFOAN - 5 GAL. CAll 5 509 ;75 BA~ 5 - 50 LB. BAG 70 1321.~0 B~R 700 - 5 G~L. CUi 20 1658.80 BUbI~.IN-D PLUS - 25 LB. BAG 81 12316.86 BAROID - 100 ~. BAG 1176 19992.00 CLAYSE~L - 55 O~L. Dml 12 7894.20 Corrosion cupons - I ~. F~ 1 235.00 ~oduct EZ-IIUI) DP - 14 GAL. CAN 32 1558.40 KCL-DoweZ1 - 50 LB. SI 256 3650,56 ,ud Iaboratory- 1 ~. 23 575.00 POYL.qSIUH ClILORID! - 50 LB. 168 2395.68 Senlud - 50 LB. BAG 324 5012..28 ~IlA-I~ C0AP~E - 50 LB. BAG 42 785~40 X-oide 207 - 6 LB. ~ 4 424.40 caustic soda - 50 LB. BAG 8 226.08 4 0~h,r Pr_,~__,_~-CS in Inventory 466.54 FRACTURE DEXTRID LT - 50 LB. BAG 36 1949.04 MUD MANAGEMENT . / RI~,.'OLOGY AND MUD VOLUME bb] MUD TYPE [ HYDRAULICS Hole I 67 25 Active Volune ,1092 ~er~-'ve j ?oral 500 / 1592 Lo~ C, rav~ vo~ ~ 2.? ppb 24.30 ~ ~av, vol ~ 0.0 ppb 0.~ ~ 2.12 ~ill ~tti~ 0 Dilution Rate 0.~ ~1~ ConSol ~f 70.~ ICL POLYMER 1600 fps 83 ~ oo~,rlOm 1300 rpn 64 tDDITIONS bbl 1200 rpn 56 Oil 01100 rpl 44 ~ine ~ater 0 6 rpn, 21 Drill ~atar 500 3 rp~ 18 Sea .Water 1000 Pressure Units: ~hole l~d 0 ' Water Depth Calc. F. ~rad Leak Off Test M~x. Diff. Press PPg Batite 93 che.ica~ o LOSSES bbl Dumped 0 Lost 0 VOL ~1I~/LO,~ 1593 Press Drop. DP 20 Press Drop, BIT 0 Pres~ Drop, ~ 3 ~ctual Circ. Press 0 tV, DP ft/min 48 ~V, DC ft/min 0 SOLIDS 0.0 0,0 DEVIATION INFO 9.2 9.2 0 MD 199 ft ~VD 199 Et Angle 0.00 Direction 0 ZVt [iser ft/min aoriz. Displ 0 ' O~iCE/~14~, z ANc--_.O-R_~GE/'ROSI{ TRY,~PI{OlfE 907-275-2627 W~SE ~Og BAY ~,~O~E 659-2422 DATL¥ CO~T ~ CIB~]r~TIVE 0 S 62252.6 $ 62252 The recommendations made hereon sh~l not be consT~-ued as anthori~.ing the infringement of any valid patent, and ate ~ade without assumption of any liability by BAROID DRILLING FLUIIB, INC. or its agents, and ate statements of opinion only. REPORT ~(BER: 2 DRILLING MUD REPORT I Date . Depth 12/14/OO{ 860 £t [MD] [ ~L IState{ Counti { ~ell ~. ] Spud Date[Present tctivit¥ lslololz/slalalglslslolO[ 12/13/00 J DRIT.T.ING OP~TOR ] CO~'r~"~R RIG ~~ ~W ~ N~O~ 3 3E ~PORT FOR ~ ~T FOR SE~, ~S~, ~G JOE POLYA/ MI~ DINGER J FI~IND~/ AR~.~y Sll T13N R13E NS10 C~SS I DIS~S~ ~~NOR~ ST~ ~NORTH S~PE ]~ BIT DATA [~. DRIVING S~ING ft ] ~SING ~ C~R~T~ON DATA ~i~ 0D 5 ~ 4.~6 ~. 549 O~_~.T~ U~ ~ Size 13.5 T~pe Jets ~ i~ ~ ] ~ I '1~I1~ ~. OP~ HOT,~ ft Tot Noz ~ [ Size 13 1/2 ~. 661 Size Size size ~ PRO~Ti~S 2 3 ft 1' oP ,32nd vol Sandt ~tt S~t~ S~t~ ~tl ~t~ ~t ~ SetO O.lOl o.o . I~¥~P.,? _.AT ..~ USED ~~-5~.~ ~ 1~.~ ~V D - ~ ~. ~G ~ 933.~ ~-D~-~. ~O 35 53~.10 DE~ L~ - ~ ~. ~ 6 324.84 ~-~ ~ - 14 ~. '~ ~ 535.~ hud ~A~~ i NOD VOL~ ~] ~ TYPE ' I ~m~ bbl I 0~1 01 Active Voluae 689 Low Gray, vol t 4.7 ppb 42.41 Si~h ~rav, vol t 0.0 o.~ 2.& Dillon ~ 0.61 Si~ ~a~ol ~f 70.~ Drine ~ater Drill Water Sea Wato~ Whole Mud Barite VOL an/LOSS noted 200'+ of roll pea (1/2,) ~:avof coarse sams and mall ~avels dou to 800' still notieq ~i,!!tr forntion Barotd ~ to raise ut af 150O bbl by 1 ppg; 880 sk. current inventolT 14328 ~OLOGY~D HYDRAULICS ~0 zlm 101 97 ~ ~p~ 65 60 .0O rpa 51 45 0 6~pl 24 25 0 Units: psig 0 Pt'ess Drop. DP 238 0 ~ Drop, BIT 530 300 I~V, ~ f't/~h 43 10O _~!~2 ft/ml. ~ater Depth Cnlc. F. Grad 0.0 Leak Off Test 0.0 C~j. Sbee 9.7 TD 10.0 Nax. Diff. 1)tess 0 DEVIATION INFO ~ 860 f~ TVD ~50 ft tz~l.e lO.OO Dkection lloriz,, n4~l 0 ~ u925.3~ ~ 76167., ~e reco~.ndations nde hereon shall not be oonstrued as authorizing the infrinqe~t of any valid pa_teat, ~d ~re nde without assuspt~on of any LlabLl~ty by B~OID D~u.~ tq, UIDS, I]C. or its agents, and at~ stateMnte of opi~fion only. RIG ACTIVITY gravel out of exl~xe~ced so~ fill 1S' to 20'- ~P dec~med from ice and ute~ in ~i~ ~ IT from 45 ~ 0.0 13.6 bb! 11 51 MUD as per start to rela~ tward 40 to 45 range (~00') a~sY AI)JUSTIIS~T D~ ~,135.~, ~ ~ lgl~ ~. I ~2/z5/°° I 2078 I Ip! ~ I state J County J Hell IS/~ I Spud DateI Present Activity mm~ 15lolol2191212191815loloj I z2/~3/ool D~ZT.T.T~G OP~TOR ! COB'i'~CTOR RIG-~~ ~W I N~ORS 3 3E ~PORT FOR ~ ~PORT FOR SECT, ~S~, ~G JOE POLYA/ MI~ DING~ ~ FI~IND~/ AS~.RY Sll T13N R13E NS10 C~SS I DISPOS~ ~ NORTH ST~ I NORTH S~PE CASING CIRC~TION DATA Size 13.5 in. [Pipe OD 5 ID 4.276 Len. 1767 Ho. Jets JPipe OD ID Len. ~ets $2nd inch ~ollar oD 8 ID 2.875 Man. 3~! 12 J 20I 20~ollarOD ID Man. ' I J ' ! in. OPEN HOLE ft Pu~p ~e~.~el · oI!~.r.U.700 PI' Size 6 I 12 [~'f, 96.00[ V~$t 0.1~ S])l 150t bbl/"in 15.1 mp P~_-_~__,~_el nrT~.~mJ. 11700 t~ ze axv_ ]=~. ga.ooIWst o.~ sp o I ~/~ o.o Sise ~ [~f. o.~ v/~t o.o s~a . o { bbl/=/~ "0.0 TOt. Vol./~ 635 ~ 15.1 ~b ~RA~NTS pl~ to ~ up ~ ~ ~i~ Uip ~ ~y ~d low~ ~ ~n~t Tot lloz Area I Size size Size Size Size MUD PROPERTIES The De~th ft FY e ~0 D~ ft 20 Set ~ 199 Set @ Set @ 15 ]./2 Len. 1879 Set ~ Lan. Set@ Man. Set ~ Man. Set@ Man. Set @ 2 3 l)rog~am < 8.8 40 4.0 < 2.f < 8.0 9.' vol Alk RIG ACTIVITY fzou 860 to 2078, past 24 ht's ~o problem eltb drop tn ~ to 45+/- and Increase in Imp froa 550 to 630 9Pa Pin viper trip at ~00' ~o 'hydrates seea as drilled < Baroid required to raise ~t at lSO0 bbl by SIJl~lTa 1 ppg; 880 sk. our~ JJ~to~ 14328 MA'x'J~L<I~ff~S US~ I SOLIDS EnUIPI~NT ~AT~-~ USed COSt l~Muct Used Cost]~Device Nak~ S:/ ~'~. ~ '~.m ~ / I ~ym VOL~ ~ ~ ~Z l HYD~ICS I~ ~P~ I ~ 24 ~e In~ / ~m~ ~m 81 72 I~o.L~ 0.o I~ o 37~ . !. 630 I ~~I~l~. 62 ~ I~Xf~t o.o I~ o ~l!vo~ / ~~ b~ p~. 5~ ~? I~ P~ 'ls~.m o .. ~z / o~ 0~ 40 35 I' ~.~ 9.6 ~ O l6 . 18 9.8 o / 1~2 ~l~Na~ 01 3~a 16 15 ~x.D~f.~ 0 ~ 0 ~ ~av, vol I 5.8 ~ ~ ~ ~e ~: ~i~ . ~ ~ 0 '~ ~v, vol t 0.0 ~i~ 0 ~ ~p, ~ 654 D~IATION INFO ~= ~ 0 ~ppb 0.~ ~~ 0~~p,~ ~ I' ~ ~78 ~ ~ o 2.39 ~ ~I ~~c.~ !8~ ~ ~ ~34 ft ~ 0 ~in~ U6 ~ 187~V, DP ~t/~. 48 I ~ 30.~ ~ c Dillon hte 0.41 ~t 0 ~V, ~ ~/~ 132 f~on ~8 A~ ~P' 5E Sl~ ~n~ol iff 70.~ VOL ~/~ 313 ~Vr ~ ft/~ . I Hori:. P!s~! 278 ft I, DRILL ~ MUD REPORT I Date I Depth -- 12/16/00i 3661 ft [MD] I APX W~Lt. [State I Co.,ty { Well ~/~ Spud' Date I present Activity I ~ 151°{°12.J9121219{8{51016~ 12/13/00~ DRIT.T.ING OP~-RATOR I COhTKACTOR RIG NUMBER ADW NABORS 33 E R!~_PORT FOR REPORT FOR SECT, TWNSHP, RNG JOE POLYA/ MIKE DINGER FINKBIND~R/ ASWLFY Sll T13N R13E NS10 CLASS I DISPOSAL W~nT. NORTH STA~ I NORTH SLOPE BIT DATA i~. DRItT.!NG S'~KING ft size n.5 in. ~ mUSL -- Ho. Jets ;ret; 3~ ~ P~OD 5 D 4.276 Len. 3350 C~ll~ bo 8 D 2.875 i~a. ~ hi. OPEN HOT.W. ft { Size 13 1/2 r~_n, 3462 TFA I size Size Size lan. Size /au. hUD PROP~(TI~$ 2 3 CASING [ CIRcunAT~0N DATA __= ______ ~~IZ 11700 PT ~ x n ut. 96.oo v/s~ o.io: 20 Sett ~ s, ~ bbU,,n ...... ~a ..... set @ Set ~ .... _ Set O IE Ti~e 361TC Ti~e huu TREAT~3NTS as per S~ened up tuo slakers afte~ uipe~ t~ip to < help out sand content Plan to puap high vis sweep at TI)- ctmLlat bole olean- wiper trip ove~ lap last trip- B=oid re~Lt~ to raise ~t at L~O bbl by 1 PlX{l 880 s~. c~ent inventory 14328 s~. ~VD-~. ~ ~ 933.~ ~~-1~. i ' ~.~ ~ ~LT-~. ~G ~ 1~4.~ ~mUc~-~ ~G 4 113.04 ~mt ~~ - ~ ~. D{~ { 4~.76 ' ~~- 1 ~. 1 7B.~ ii. ~0o ~IA~NT" / ~OL~Y ~D l~'~C'ru~ G~DII:NU ~UO VOL~ '~l, ~D TYPE · HYD~ICS I ~a~ ~p~ Hole I fi~ ~ ;~~ 16~ 6~" 71 72 { ~lc.~.~ 0.0 n42 Oil 0 i~ ~i 30 33 34 . ~ 9.6 470 J ~6~2 ~ ~2~ 0 3~ ~ 23 Z4 ~x. a2ff. ~ 0 ~ ~v~ YO~ ~ 6.0 ~ ~ ~ ~ ~e ~: psig Drop, BIT 752 ~eSS Drop, AN~ 72 ~ Ci~. Prm.~ 1850 {V, DP ~t/tin 51 }V, ~ ft/~Lu ' ppb 54.42 gnole ~ud Sigh Gray, vol t 0.0 Barite ppb O.OO ~ 2.48 II.ES Drin ~ ~2 D~lon ~ 0.64 SI~ ~ol ~f 70.~ VOL ~l~_~ 0 0 0 b~l 563 0 -13 , D~'~VIATION !NFO ~ 3661 T~ ~le Direction Horiz. _~pl ~07-275-2627 The reooeneudatiom made hereon shall not be construed ~ autho.riziu~ the hifrin~enent ot any valid ~tmt, m4 are nde without assumption of any liability by BAIIOD _nmTu.ru; IqfflDS; ~m;. or its a~ents, and are statements of opiition only. Baroid REPORT NUMBER: 5 DRILLING MUD REPORT [Date I Depth ' I 12/17/001 3742 ft [MD] I APl W~JA [State l C~unty I ' Well ~/~, I Spud Date Present Activity mm~ 151OlO12/~1212191SlSlo161 I ~2/~3/oo TD S~AC~./LOGGING O~,a~ATOR I CONT~tAC~)R RIG NUMB~ ADW I NABORS 3 REPORT FOR I R~PORT FOR SECT, TWNS~P, P. NG JOE POLYA/ MIKE DINGER I FINKBINDER/ A_RR?.~.y Sll Ti3N W~z.L N~ ~D N~R NSIO C~S I DISPOS~ W~ NORTH ST~ NORTH SLOPE ft ~ CASING CIRC~TION DATA Set~ BIT DATA {ia. DRILLING S'~ING Size 13.5 in. IPi~e OD ID Le~. Ty~e ~Ust ~'ipe oD ~ 32 [[ ~ { 20~oll~OD D h. OPEN HOLR Tot No% ~ea I Size 13 1/2 ~.. 3~3. T~A ! Si~e 8i~e Si~e Size Nuu PROP~RTIES ~ime ,taz ! 200 ,il/;.;a~ % by vol and % by vol Set .@ Lea. Set @ Len. Set~ ~. Set @ Set ~ 2 3 Progtan < 8.8 40 15 4.0 size x I=E o.oolv/sto.ooo spm o [ bb!/nln 0.0 Tot. Vol./mia 0 ~--- 0.0 bbl BI] Time 0ITC Time 0 TREATI~NTS necessaq as log Dtlutat 1T to 30+/.- prior to T0~ for Wated holes ia shaker screens- chnqed out Other co~tibutio~ to ~d ut imcre~e; fiaes piokat up followi~ viler trip- also some formtion d~lll~d in lo, er sur~a~ int~al RIG ACTIVITY T~ 3742'- to build section- HH- circulate and condition- ~ for logging operations- no problems .ith ny t~i~- no. losses noted USED 90 bbX ~ IIUD 11 I)}{Y ,,'CBS; 3 TAIl'S ::~_= MA'-',.',tIAT..~ US~n ;'-'-"-'~ ~ ."'.al ~-t ~V D ' 50 LB. BA~ 10 466.60 ~D PLUS - 25 LB. BAG 16 2432.96 ~ LT - 50 LB. BAG 7 378,98 I~Ili~/]IG - 1 F~. 1 715.00 ~ - 14 C~L. C~ 5 243.50 c~m~- 2 m. I 1ll5.00 ~'La~Nll C~OHDE - 50 LB. 56 798.56 207 - 6 L~. ~ 6 636.~ DtUD NANAGEI~NT UD VOLUIiR bb! MUD TYPE le695 [ Pi~40 Active Volume 1235 serve Total _4!0 W ~'av, vol t 6.6 ppb ~o.~5 ~h ~rav, vol % 0.0 ppb o.oo ~ }-.56 ~u cutti~ ~4 Lution hte 1.23 is Control ~ff ?0.00 ~D ~/ ~ CO~UMPTIOH ADDIYIO~S Oil atiae Water Drill Water 100, Sea Water 0; Whole Mud 90~ Barite 0 ~i~ls 0 ll)SS~ ' ~ 157 Lost 0 VOL ell'l{/Tn~q 33 < 60.4 lmmid re~Lted to raise ut of 1~0 bbl 1 p~; 880 sk, current inveitoty 14328 0 0: 6rpl 14 13 J SOLIDS RQUIPlWa__.NT ~-~% used co~ I ~c ~ - ~ ~. ~ 3 84.78 ~ ~:~ I~ UOl UOlU~ ~ ~:~ I D~ ~.~1 ~/~ ~ t:: I D~ ~/I ~/~ , il J ~OLOGY ~D [F~c'i'u~ O~ T' I~ "' J [ HYD~ICS j Wat~ ~p~ ~ 4.~ ~ ~ 49 ~ ~fT~ 0.0 J~ 42 42 J ~ p~ S~.~G 1.~ {1~! 32 30 /~. b 0.0 p~L~re 12 32 Units: psig tess l)top. DP 0 tess Drop, BI~ 0. tess Drop, ANN 0 ctual Circ. Press 0 &?, DP ft/min 0 IV~ DC ft/mia ' 0 &v, mi~r f~/,i. 0.0 FISHINg Max. Diff. Press 0 DEVIATION INFO ll3gffllg 0.00 ~ (~l 0.00 CORE 0.00 BACI REalM 0.00 RgaMllg 0.00 T~I~ 0.00 OTH~ L00 AV~AGE ~OP 20.25 [DAILY COST~96.91 'CUIIULITIVB COST MD 3742 f't: TVD 3202 ft An~le 48.30 Dir~ion 198.12 .~oriz. ~ispl 1447 it 907-275-2627 659-2422 ; reconendations nde hereon shall not be co~ as authorizing the inf:~jement of any va~id patent, and ate made without mption of any liability' by BAROID DPTYJ.IqIG FLIFI~, 11C. or its a~, aAd ere statements of opidion only. ( Baroid REPORT NUMBER: 6 DRILLING MUD REPORT Date I Depth . i~-/iS/00 { 374~. ft I API ~LL [StateI County I Nell ~/~ Spud Date lPresent Activity I m~ lslOlOl~.191~l~.lglslslolol 12/13/ooI RU~ 10-3/4" CSG OPF~RATOR I CON'-'KACTOR I RIG NUMBER JOE POLYA/ MIKE DINGER I FINKBINDER/ A~T.Ry ~Sll T13N R13E W~.'LL NAME AND NLu~B~R I FIELD OR BLOCK I COUNTY, PARISH, OS. AREA,ST/PRY BIT DATA lin. DRILLING ~'~i~ING ft Size ~3.5 in. IPipe 0D ID Len. ~y~ HUSL pipe oD ~ ~. ~o. Je~ ~i~ ~ ~ ~. ~e~ 3~ ~ I~ OD 10.75 ~ 9.95 ~. 3742 12 ~ ~ OD ~ ~. ~, OPEN HOLE ft ~t Soz ~ I Size 13 1/2 ~. 3543 CASING in. CIRCULATION DATA Ptmp ~e/aodel O~t~ff~t kWO0 Pr ft size ~ x 12 IE~f' ~-0ol v/s~ 199 spa 1~o I bbl/.{. 12.1 20 Set ~ Set ~ set ~ Size. size size size huu PROP~KTIES set@ · Set@ 1~. Set @ I~m. set@ Len. set~ 2 3 Pro,tam 0.101 0.101 15 4.0 pump ~ke/Sodel si:e x J sff. o.ooI v/st o.ooo spm oI bbl/}{~ 0.0 'Tot. Vol./ui. 508 .n. 12.1 bbl ~ Tine 23 {~ Tine ,r- 94 < < 8.0 2.1 MUD TRRATNRNTS · casing on bottom- break cJzcu/atton at 2 bpm- slowly raise rate to 4 bpa and C~- then ira=ease rate to 8 bpm and CI~- then raise tat. to cemmtlng rate of 10 to ~2 bpm and C~O- ~ i~T~ AT 25 ~H A~ CO~ITIO~ ~ ~ am- pr,tx.st with Bicatb & Pll-6 Store 150 bbl nd in G~I p~ocessing pits in prepmmtion for fkst s~age mud returns- expect 274 bbl back to pits RIG ACTIVITY P~bl~s w~th l~n~ t~- deoessio~ ~ to abort lo~i~ operations- ltl]l with ca~j Hud Labontory - 1 EA. l~'i'~s US2~ Used Cost Ptmduct 1 7~,~ 1 ~/5.~ 1 B~roid ~ to raise ~t of 1500 ~1 by ppg; 880 sk, cun~nt inventor7 14328 ak. SOT.TDS . HUD MANAGF~NT ' MUD VOLUI~ Active vohm 1135 410 1545 ~ ~v, ~1% 4.2 ppb 38.31 ~ ~v, vol % 0.0 ~b o.~ ~ 2.~ ~in ~ o D~l~on ~te 0.~ MUD TYPE , [(2 POLYI~t ADDITIOifS bbl oil o Brine ~ater 0 nrU/~ater 0 Sea Uate~ 0 ~ole Hud 0 ~OLOGY AND HYDRAULICS 600 rim 63 30o rpa 46 20O tpl 38 l~rpm 29 rim 14 3 rpm ~2 Barite 0 ~e~ Drop, BIT 414 Cheaicals 0 ~ ~p, ~ ~5 [~ ~1 ~ ~. ~ 0 ~ l~v,~ ~/~. o ~L ~ -~m ~V, .{~ IOmUF~ ~~f~ I~"'~ ] ~ater DePth talc. F. Grad 0.0 f Test 0.0 9.6 10.3 Max. Diff. ~e~ 0 DEVIATION INFO D 3742 ft ~D 3202 ft Aagle 48.30 Direction 198.12 Sori:. Pispl 907-275-26~ 659-2422 ~ 0.0O ~ o.oo ~ 12.0O S~V. HG 0.00 SI~Y, 0.0O ~T.~n~ 0.00 ~ 10.00 mi cs~ 2.00 CO~ 0.00 BACK ~ 0.0O ~ 0.0O ~ 0.00 OT~ 0.0O AV~6~ ~P 0.00 1447 ft { DALLY COS~ ~ CU~LATIVE ~0ST ~ 855. $ 133433.2, Yhe recomndations rode hereon shall not be construed as autbo;izinq the int~in~eaent of an}, valid patent, and are nde vithout assusptton of any liability by BAIt0ID l);ru.m; F, JHDS, IBC. or Its a~ents, and ate statesente of opikion only. ( Baroid DRILLING MUD REPORT IDate12/19/O0 I ~IWELL StatelCoanty I Well IS/~ Spud Date ,0~ I~10 012/91212191el510I~ 12/13/00 OPERATOR I CONTt(ACTOR ADW iNABORS REPORT FOR I REPORT FOR JOE POLYA/ Steve ~ FINKBINDER/ ASBT.RY REPORT NUMBER: Depth 3742 ft [MD] Present Activity ND DIVERTER/NU BOP RIG NUMBER 33E SECT,TWNSHP,RNG Sll T13N R13E Tot Noz Area I Size I Size I size I size WELL NAME AND NUMBER IFIELD OR BLOCK NSiO CLASS I DISPOSAL WELLI NORTH STAR BIT DATA lin. DRILLING STRING ft I Size in. IPipe OD ID Lan. No. Jets IPi~ OD ID Len. Jets 3~d inch ~llar ~ ID ~n. ~ ID L~. in. OPEN HOLE ft ~n. ~n. ~n. lqOD PROPERTIES 2 3 Source FL Temp Gels API Fi.lt. .','~. @ 200 Cake a)I/u:z~ 32nd ¢~-~.~)1id6 % ~y vol 6il vox IW'T Llk. llud I NORTH SLOPE COUNTY, PARISH, OS. AREA I ST/PRV CASING in. ft II0 3/4 set @ 3742 set @ Set @ Set @ set @ set @ set @ ( 8.8 40 15 4,0 < 8.0 360OO MAT,.',~AT.~ USED Piou~ Used Cost Product Mud Laboratory- i EA. I 25.00 bicarbop~te of soda - 50 LB. 14 330.82 citric acid anhydrous - 50 LB 21 2047.50 I CIRCULATION DATA Pump Wake/Hudel OIL~SLL A/700 PT size 6 x12 I ur. 9~.~1 v/st O.lOl I spa 0 ]bbl/lin 0.0 Pump H~k~/Hodel OT!,WRT,L ~1700 PT Size 6 X 12 IF, ff. 96.001 V/st 0.101 I sp. o I bbl/min 0.0 IPu~p P__~e/Hudel Size X BYf. 0.001 V/st spy o bbl/nin 0.0 Tot. Vol./,i, 0 9ps 0.0 BU ?in, 0 I~ Ti~e 0 0.000 bbl MUD TREATMENTS nu bop and prepare for next interval: centrif~e mud in surface system clmnge mud cleaner shaker s~roens clean up pit rooms arees- clear vith C~I for use of vac systsm to vac sumps with rig wash ~tite .dnm crush procoedu:e, for safety precausions to ct-ash all collected drues AO~ xcide to all ~ stored pits of _~.~_. to active RIG ACTIVITY ~an 10 3/4' caninq and cemented as per pro,rum- 12.0 PiN ceme~ to surface- than pumped wiper plu~ to clear casing- currently le diverter/BU BOP Drill surface; vaste to dyke: 1500 bbl Stage 1 cement job: 180 bbl Stage 2 cement job: 370 bbl TOTAL ESTIMATED WASTE TO DATE: 2050 left to SOLIDS MUD MANAGEMENT MUD TYPE ' KCL POLYI~R MUD CONSUHPTIOli ADDITIONS bbl Oil 0 Brine .Water O: Drill Water 0 Sea Water 250 Whole Hud O' Barite o Chemicals 775 LOSSES bb~s0 RHEOLOGY AMD HYDRAULICS 600 rpi 50 300 rpl 36 200 rpm 30 100 rpl 22 6 rpi 10 3rpl 8 Pressure Units: Press Drop. DP Press Drop, BIT Press Drop, ANN ~ctual Circ. Press AY, DP ft/min 0 0 0 0 0 MT3D VOLUME bbl~ ~ole I Pits ,, 3~o I 400 / Active volume | .. , 760 / Reserve I Total 8GO I 1G20 Low ~rav, vol % 6.0 ppb 54.42 Hi~ Gray, vol % 0.0 ppb 0.00 .LSG 2.40 Drill Cuttings 0 Dilution Rate . 0.00 Lost 0 AV, DC ft/min 0 FRAC'~'URE GRADIENT Water Depth ~alc. F. Grad 0.0 Leak Off Test 0.0 F~D plxJ Csg. Shoe 0.0 TI) 0.0 Hax. Diff. Press 0 DEVIATION INFO ~ 3742 ft T~D 3202 ft Angle ' 48.30 Direction 198.12 DRLG 0.00 ClRC 8.00 TRIPS 0.00 SlaV. RIG 0.00 SURV~ 0.00 FISHING 0.00 MX]GLqG 0.00 R~ C~ 16.00 CORE 0.00 RF~q]{~ 0.00 TESTI~ o. oo O~ 0.00 AVERAGZ ROP O. O0 Slds Control Elf 70.00 VOL GA/It/LOSS 75 AV, ILiser ft/min Horiz. Displ 1447 ft ~AIiOID R~PP~?~arrATIVE }OFFICe/HOME 'A~o_~GB/_.~_'SE {T~.~O~ 907-275-2627 {'DAILY ~ST ~ ~TIVE ~T {Er~/ ~D {W~8/ PR~E ~Y {T~T.~ 659-2422 {S ~535.3~ $ 135968.60 ~e r~o~endations made h~n sh~l not ~ ~ as a~rizi~ ~e i~r~t of ~y valid ~tent, and ~e a~ption of ~y liability by ~D DRI~ ~UI~, ~. or i~ a~, ~ ~e s~temen~ of opiuion Baroid REPORT ~FU~ER: 8 12/20/00 3742 ft { 'APl WELL [State{ County { Well {S/~ Spud Date Present Activity I mmn 151OlOl2/9121219lel5lolo{ 12/13/00 NU BOP/ T~ST OPE~TOR { CON'r~C~OR {RIG N~ER ~w I N~o~s { 3 3~ ~_~o~ ~o~ I~o~ ~o~ I s~c~,~s~,~ JOE POLYA/ Steve W~LL NME AND NUMBER }FIELD OR BLOCK NS10 CI~SS I DISPOS~L ~LLINORTH ST~ BIT DATA Size in. Yype No. Jets Jets 32nd inch ?or Noz Area TFA HUD PROPERtiES FL ~pth ft , _~ ___ ~@ 60~ PV~O FoP APl Filt. ~,-~ t by vol __ )2nd vol ~uO in. DRILLING STRING Pipe OD ID Len. Pipe OD ID Len. Ipipe OD ID ~n. ~ollar OD ID {$n_, OD ID T~_., in. OPEN HOT.~. ft Len. 2 3 ft ~0 3/4 set ~ set @ Set @ set ~ set @ Set~ set @ sets set @ COUNTY, PARISH, OS. AREA[ST/PRV NORTH SLOPE AK CASING ft 3742 < 8.8 40 15 4.0 < 2.r ( 8.0 CIRCULATION DATA Pump Na~e/Model OIT_.WRLL A~700 Size 6 X 12 left. 96.001 v/st 0.1( spin 0 ] bb!/min 0.0 Pump Make/Model o! T_3I{LT~. Size 6 X 12 {Elf. ~.00{ V/st 0.1, SpI 0{ bbl/m~n 0.0 pump m~_~/~.-_~l size X }iff. 0.~{ v/st o.o, ~rnm- 0 [ hhl/~in 0.0 ~ot. Vol./mia ---0 BO Time O}YC Ti~ 0 MUD Wo necessat7 at this tim. circulate mud through surface sustem and ru centrifuge to lower wt LAP fork lift o~erator move pallets to ~in better a~e~s to IZi{, mainly Barofibre mIBOP RIG ACTIVITY Up after cement Ba~oid requ~ed to wt up 1~00 bbl by 1 PlXl; $a0 dr, current inveatory, 14328 dr. , MA'X'~RIALS USED { SOLIDS EQUIP~5:~T ~':~'~ ' Used Co6t P~ct ~sed Coati ..Devic:l ..l~ke I Sz/Sc~ X-cide 207 - 6 LB. CAI{ 6 63~.~0 ~ ILl Dff fig 1251 125/12~ I~ ~ I~"~; nol uo/nq ~n,* ,*:L I D~, 230/I 23o/23{ F~-n,t ,,L I S~lC0 I I t NUD MANAGElq. ENT I RHEOLOGY AND I FRA~'.t'tlRE GRADIENT ~'rlq]iI MUD VOLUME bb! Nuu TYPE I HYDRAULICS ~ Water Depth ~ 0 Hol?_ I Pits _ KCL POtYM~ {4O0 rpm 4~ | Cal¢. F. Gr~d 0.0 Cl~C 0 :~eo t400 MUD CX~]*OM 1300 rpm 35] [ ~dr Off ,~st 0.0 TRIPS 0. x~cive Volume -- ADDITXOWS bbl 200 rpm 2~ ppq S~V. RI~ 0 760 0il 0100 ~1~ 22 ] ~9. Shoe 0.0 SUI{V]{Y 0 Reserve { Total - Brine Water 0 6 rpm 10 . 0.0 HSI{I]IG 0 860 { 1620 Drill Water 0 3 rpm 8 {Max. Diff. Press 0 ~]]G 0 LSw Gray, roi { 5.0 Sea Water 0 P~essure Units: psig RU]! CS(; 0 45.59 Whole Mud 0 Press ~op. DP 0[ CORS 0 Hi'%ay, vol % 0.0 Barit~ 0 pre~s ~op, BIT 0 VIATION INFO BACK R]~ 0 { o o ASG 2.44[ L(36SES bbl Actllal circ. press 0 TVl) 3202 .ft T~TING 0 I)rill Cuttings 0 Dumped 0 AV, DP ft/min 0 lm~le 48.30 0THIR 0 Dilution Rate 0.00 Lost 0 AV, DC ft/min 0 DirectiOl} 198.12 AV]iRAGE ROP 0 Slds Control Elf 70.00 VOL calw~./Rlic_S 0 AV~ }i~r ft/min Horiz. Displ 1447 ft . W~_'N,___~'tg]/ ~IIJ]i~)OD [w~i~E-- P~a~3E BAY LT~.i _~L_F. 659-2422 ~ 13660~, The recommendations made hereon shall not be construed as 'authorizing the infringement of any valid patent, ~ are made without asstmption of any liability by BAROID DHLLIIg FLUIDS, l]i~. or its a!lents, and a~e statements of opinion only. (' Baroid REPORT NUMBER: 9 DRILLING MUD REPORT [Date I Depth ~ 12/21/001 3742 ft [MD] I API ~ELL I S~ate ! Comity I ~ell ~/~ I Spud Date Present Activity m~a 1'~101012/9121~-191~(510101 I 12/13/,00 TEST BOP OPERATOR ~ COhTKAcTOR RIG NUMBER ADW I NABORS 33 E R~PORT FOR R~PORT FOR SECT, TWNSHP, RNG JOE POLYA/ Steve FINKBINDER/ JIM WOODS Sll T13N R13E ~ ~ ~ m. ~.. ft size 6 x u ~f' ~.~1 vt~ I~i~e ® m ~. ~o 3/4 set ~ ~74z ~ o ~b~/,~, ' o.o OPeN HOLE ft ~t ~ sp~ 0 I bbl/,~, 0.0 Size in. No. Jets Jets 32nd inch ill. Tot ~z Ar~ Isize set ~ set @ o.: TFA ISi~e Size Size Size MUD PROP.:KTIES Tim. ft FVe60 APl flit. nn~ @ 200 D~ Cake ~/~,~ ~.Soltds' t by vol o~/~ ~ by vol Sond t by vol Tau0 2 3 MAT~IALS USED set~ Si,.e X I Eff. 0.ooI v/st s~. o I bbl/,~. 0.0 set @ Tot. Vol./Bin 0 ~pa 0.0 set ~ ~ Ti~ o I~ ~!,e MUD TREATM~_.NTS Ool 8.8 9.~ 40 15 4.0 Add 2 pallets KCL Add 10 ]Licarb to lo, er calciut and pretrea to d~ill cetent fork lift still needs to gain access to LC set out 6 pallets of Barofiber ( < 36O0O RIG ACTIVITY last ~eport to sim no engineerin~ cost cernc~ ad~ast~t of overcha~ 880 sk, current inventor, 14328 sk. SOLIDS ~OU MANAG~NT NUU VOLUME bb~ MUD TYPE ltole I Pits { KCL POLYI~R 360 I 1100 Active Volume i DDFrlONS bbl 1460 ~ Oil 0 16O | lf~O ' Low Grey, vol % 4.4 ei~p~V, volt° ~o1 Dilution Rate 0.00 Slds Control iff 70.00 RHEOLOGY AND HYDRAULICS SO0 rpl 36 IQO rpm 28 )O0~m 24 LO0 rpl 19 Water Depth Calc. F. Grad Leak Off Test PP~ 0.0 0.0 0.0 DRL~ S~RV. HG SURVEY mine ~ater 0 XiU ~ 0 Sea Water ~hole Hud 0 ~arite 0 c~eBic~ LO~F~ bbl ~ o 6rp~ 8 ~Bits: ~ig Press Drop. DP 0 k~sS Drop, BIT 0 ~ctual Circ. ~ess 0 &V, DP ft/lin 0 ~V, ~C ~/min 0 ~V, Riser ft/uin TD 0,0 liax. Diff. Press 0 DEVIATION INFO MD 3742 ft TVD 3202 ft An~le 4~.3o Direction 198.32 Lost 0 VOL C~HI{/LOSS 0 Hori:. Disp! 1447 ft ~ ~~o~ ~ ~n ~ not ~ ~ ~ a~iz~ ~ ~9~t of ~y v~d ~t, ~ ~e ~ wi~ ~on of ny li~ility by ~ ~ ~, ~. or i~ ~, ~ ~e sbt~ ~ op~on o~y. DRILLING MUD REPORT ~Date 12/22/00 I APl ~LL I Statol Com~7 I ~ ~ Spud Date~ I m~n 151010121912121918151010] 12/13/00 oP, ,TOa I CoNTRACTOa ADW I REPORT FOR I REPORT FOR JOE POLYA/ STEVE CHRISTIAN [ FINKBINDER/ JIM WOODS Depth 3742 ft [MU] Present Activity T:iH/DRILL ES/PU DP RIG NUMBER 33E SECT, TWNSHP, RNG Sll T13N R13E WF~LL NAME AND NUMBER [FIELD OR BLOCK NS10 CLASS i DISPOSAL WELL[ NORTH STAR BIT DATA I'.~. DRILLING STRING ft Size 9.875 in. ~ipe 01) 4 19 3.240 Len. 2~ Type HZ-C1 ~i~e OD 5 19 4.276 Len. 820 Uo. Jets ~'ipe OD 19 Len. Jets 32nd inch K:oiZa~ OD 7 19 2.8125 Len. 220 12 I 18 I 181CollagOD 19 Len. 18 in. OPEN HOLE ft i COUNTY, PARISH, OS · AI~ I ST/PRV NORTH SLOPE ] AK CASING ] CIRCULATION DATA in. ft Size 6 XU .ooI v/st O.lO 10 3/4 Set @ 3742 sp! 120 12.1 Set @ I Pulp Hake/Bode/ OXUIELL )/?OD PT sere Isize 6xu l Ur. 96.00Iv/st ~e sp~ o i bM/L~ o.o Tot lloz Anm Size Leu. Size Lee. Size Leu. Size Len. Size Zen. TFA MUD PROPERTIES Fve6o Sandt vol SULFITa TauO 2 3 MA'£~a~IALS USED bic=toMte of soda - 50 LL 9 212.~7 set e size I v/st set ! sp! o o.o set @ Tot. Vol./sin 508 ~pi 12.1 Set @ B~ TiM 23 ITC T~e 120 MUD TREATMENTS bbl to treat calciu~ nd pretreat foz mxj~ driUlq ce~nt 8.8 9.t 40 15 4.0 RIG ACTIVITY 8.0 36OOO Plan to ctrcuints bole cleu and ~ to nm bom logs SOLIDS MUD VOLUME 332 14~0 160 LOW Gr~v, VO .3 ai~h ~rav, vol t 0.0 ~ o.~ ~ 2.59 ~ ~ o ~on ~ o.~ Sl~ ~1 ~ 7o.~ w~n,tff,,,*'x'tzn/1~1 roans [~ POLm gbole gad ~rite L~S~S HYDRAULICS bbl rpa23 0 fps 17 0 6rpl 7 0 ~n~ts: psi~ 0 ~ ~p. ~ 7~ 0 ~ ~, ~ 62 0 ~AV, ~ ~/~ 0~,~ ~/~' 249 !~ 0.( 0.0 ~ 2.( Leak Off Test 0.0 TLIPS 10.( ECD lqx] S~L'V. HO 0.( Csq. ~oe 9.5 SURVff 0.( TD 9.5 l$__~ 0.( Max. Diff. Pt'ess 0 '~ 0.( (~Z 0.( DEVIATION INFO ~AC[ ~ 0.( ~ 3742 ~ ~ 0.( on 1M.~ A~ ~ 0J ~orh. D~I 1447 The reco~ndations ~le ~on ~ not be co~r~ed ~s authorizinq the h~r~t of any valid l~_tsnt, mx] a~e ude without assumption of an~ linbU/ty by ]~019 ~m,~ FLF19S, lie. or its agents, and are statsunts of opinion only. ( Baroid REPORT NUMBER: 11 DRILLING MUD REPORT IDate I Depth I 12/23/001 3742 ft ~I);ELL~Stabl~ I ~ell ~/~ ISPud DatelPresent Activity ~IIB~ {5[010[2{912121918{5(0{6{ ( 12/13/00[ D~T?.r. CI4T/ BOND LOG OP~KATOR ]CO~T~ACTOR )RIG N-u~F~ R~POR~' FOR IREPORT FOR ISECT,TWNSHP,RNG JOE POLYA/ STEVE CHRISTIAN I FINKBINDER/ JIM WOODS ISll T13N R13E WELL NAME AND NUMBER IFIELD OR BLOC~ ICOUHTY, PARISH, OS. A/~EAIST/PRV NS10 CLASS I DISPOSAL WELL INORTH STA~ INORTH SLOPE IAK BIT DATA [in, DRILLING S~RING si:e 9,875 in, I~pe o~ zo ben, 12 I 18! 181Co11~0D 18 in. OPeN HOT.R ~t ~z ~ [ Size TFA ~ S~ze Size Size Sl~e MUD PROPER'~IES -'my 200 Cake 32~d SULEXT]~ 2 3 ft10 3/4in'CASING ~l~@Set @ 37 CIRCULATION DATA set @ JEff. 96.ooI v/st Set @ I bb~/min 0.0 Set @ Sets Set @ Sets PI~ #aep/lm4e_~_! OTT~,L k~700 1~ Si,.e ~I~2 I Eff. ~.001 ~/s~ 0.~ spin o I bb:l./.i,, o.o ap M~/lfodel OZU~r_. A/700 ~ ze 6 X 12 o.~( 0 Pump M~ke-/lk~el She X JEff. 0.00! ~/st O.OC s~m 0I bb~/min 0.0 ~ot. Vol./.in 0 ~a 0.0 bb: ~ Tie O I~C ?ine 0 MUD TR~.ATN~.NTS st~ace systet tim L pits and m < 8.8 40 Add 6 Barazn D 10 Mcarb ef soda 36 ~trid 10 ~d 4 aa~ 4.0 < 2.4 < 36OOO Treat calcit~ and lower ~ I~wet WI, and reestablish product _m_~n__~!'atj. o~s Of .eta1@ inhlhlt~ RIG ACTIVITY lO' of shoe- circ~la~ csasiaq ~lean and Wa to nm ~S~ (bond) md looked qood as ~im~ated prio~ to · iili~ ~meat- as ~il~ ~ ~ staye constant at 18- ~L slier incr~se dee to sta~ co@ting out on mment ~- no adveme effect f~om cement contmination MUD HYDRAULICS 4 [CZ POL~ rim 42 F. &tad 0.0 CIRC 4 360 :pi 30 ~ ~f T~t 0.0 ~ 14 1~ O~ 0 ~1 19 ~.-- 0.0 ~ 0 1~ Xi~ 0, 3~ 6 ~. Diff. ~ 0 0 ~ ~av, vol % 4.3~ ~ ~ 0 U~: ~i9 ~ ~ 0 38.86 ~le ~ 0, ~op. ~ 0 ~ 0 o.o . o. m o o ~b 0.~ ~ 0 ~ 0 3742 ~ 0 ~ 2.59 ~ bbl ~ 0 ~ 3202 ft ~ 0 XiU ~ 0 ~ ~ m ~/~ 0 ~le 4~.30 ~ 0 Pillion ~te 0.~ ~t 0 ~ 0 Dk~ion 198.~ A~ ~P 0 Sl~ Cobol ~ 70.~ -1~ I Horiz. 1447 ft $ 3042, ] 14257?. ~e reco~ndations nde linc@on slmll not be constnmd as authoriziw the inf:inge~e~t of '~ ulid patent, ~i are Md@ vi~u~ assumption of any liability by BAROID Ecru.mi ff~fI)S, lie. or its agents, and ate statements of opidion only. ( (' Baroid REPORT ! iBER .' 12 DRILLING MUD REPORT IDate I Depth [ 12/24/001 3742 ft [MI)] ~= Slo 0 9 212191s1510 [ 12/13/001 DRIVING O~ SHOE OP~~ ~ CON~CTOR I RZG ~~ ~W ~ N~OaS ~ 33E ~RT FOR I ~RT FOR SECT, ~S~, ~G JOE ~LYA/ ST~ C~ISTI~ I FI~IND~/ JIM W~DS Sll T13N R13E ~ N~ ~D --~ I FIELD OR BLOCK I CO~Y, P~ISH, OS. ~IST/PRV NS10 C~SS I DIS~S~ ~ NOR~ ST~ ~NOR~ S~PE BIT DATA I~. DRIVING S~ING ft ~SING I CI~C~TION DATA .o. ~ ~i~ ~ ~ ~. 20 3/4 ~t e 3742 ~e~ 3~ &~ ~ ~ 7 ~ 2.8~ ~. 272 18 t~)t lio~ Jrea ~ ID Lea. m. OPEN HOLE ft I size Lea. size Lea. Size ten. Size Lea. Size Mm. MUD PROPERTIES Souse The ~T e 6O ~ AP1 FLIt. Corr. Sollds % vol vol F~ dmK! 6O 2 3 set e I sete I "I set @ set @ set e set~ 8.8 40 15 4.0 15.C < 2.( < 8.4 8.O 36OOO < 0.10: 0.10, bbl RIG ACTIVITY (bond log) casing- ~.a to c~in ~ 880 sk, CULT~t hlvento~ 14328 sk. sOr. TDS MUD MANAGEMENT ~03 1/63 16O ~ Grd~, VOl t 4.3 39.40 ~g~-G~aY~ Yo! % 0.0 o.oo 2.59 ~in ~ o )~oa ~ 0.~ sl~ ~n~l ~f 7o.~ TYPE lOmC~/im~ HYDRAULICS ~ 55 rpl 40 Rim 34 ~ O.C F. GL'ad 0.0 CIIIC O.C Leak Off Test 0.0 ~ 12.C ]~3) ppg SERV. HG O.C Ol 6~p. n Ol 3~ 2o o ~ ~nU:s: psig o ~ D~'op. DP 965 o ~ '~, ~ ~ 0 b~7 ~ ~' ~ 1~ ~v,~ ~/~ , i~ .uo~v,7 ~ ~/~ 2~ ~v, ~ ~/~ 9.7 LOG~ O.C 9.70 O.C ~az. Diff. Press 12.C C~gCS~ DEVIATION INFO I RACK ~ 0.0 ~ 3742 ~ I ~ 0.C ~ 3~ ltl ~ 0.c ~ 48.3o ~ ~ . o.~ D~on 198.~ J i~ ~ o.o Hori:. M~] 1447 ~ I 65~24~ I~ ~,d.,~ ~ i4~3.~ ~be ~ecoaemtatio~s ~e hereon shall not be construed as a~c~orizi~g t~e i~zi~ of any vaLLd ~z~c, ired ~'e Mdc vithout ~u~ion of any .LiebUity by ~C)D I~TT.T.T~. FLI~, I]lC. or its agents, and are statemnts of opinion only. . Baroid DRILLING MUD REPORT Date 12/25/00 I API k~LLlStatelCo~ty I ,ell ~/~ Spud Date ,um~ 15101012/9121219lSl51010l 12/13/00 ADWOPERATOR I CONTRACTOR NABORS PurPORT FOR REPORT FOR JOE POLYA/ STEVE CHRISTIAN FINKBINDER/ JIM WOODS REPORT NUMBER: 13 Depth 5430 ft £MD] Present Activity DRILLING INTERN~.DIAT RIG NUMBER 33E SECT, TWNSHP, RNG Sll T13N R13E W~ NAME A~D NumBER I FIELD OR BLO~ NS10 CLASS I DISPOSAL WELL [NORTH STAR BIT DATA IL. DRILLING STRING f~ CASING Si:e 9.875 ~. ~il~' OD 5 ID 3.240 Leu. 5258 ~o. Jets ~ipe 09 ID Lea. 10 3/4 se~ @ Jets 32nd bF.h ICoUar 00 7 ID 2.8~ zen. 172 set e u I 18! 281coUar00 ID Le~. 18 J~. OPEN HOLE ft Tot aoz Area I Size 9,875 Lmm. 1~ TFA I Size Len, Size Len, Size Len, Size Lei, hud ~ROP~/~<T~ES 2 3 Set ! se~! Set@ set! ICOUNTY, PARISH, OS. A~EAIST/PRV NORTH SLOPE AK 3742 FV @ 70 Dec PV e 7o necjF cP APl FUt. .,ae 0250~ Co=.SoUds t vol vol 7O TauO HA'J.'~IALS USeD Pr0~i 3742 9.0 40 10 15 3,0 10.¢ < 2,( 8.0 9.! 36OOO < PL*Oqh~ BABAC{It 700 - 5 GAL, CAB {umi.qClV D - 50 LB, BAG P,i~AeAU-D PLUS - 25 LB. BAG D~TII21) LT -. 50 LB. BAG DRIll-SLIDE - 55 GAL, DItUH ~ad COSt 30 2488.20 30 1399.80 28 4257.68 4 263h40 20 1082.80 4 2484.88 5 243.5O 1 U/5oO0 1 25,00 l)vodu~ POYASSlUN CIff,ORIDE - 5O LB. CIRCULATION DATA 6xu I". ~.OOlV/st o.2, ~-., x4o I bbi/.in '14.2 O~ A1708 PT Ifil. 96.001 v/st o.1, spl 0 I ~!/.in 0.0 Size x Ifil. 0.00! v/st sim oI ~!/~n o.o Yot:. voL /mia 593 ~ 14.1 BU TJ]e 27 I YC ~i.~ 82 MUD as per proc~am, hcomndations as pe 2 a... (12/26/00) lm .a~ at 25 bbls./hou~ AM 2 sks. Banzan-D each Ad~ 2 s~s., Del=id each ha= Add 1 pal/EZ-nd em7 ~ Add I pa]/e~ o~ KCL ~]d 1o l)aUs of ~,-r-7oo 0.0 (Currently no la~ses - no problems) 880 sk, cu~geat 1~ 14328 sk. 112 1597.12 8 4~J0.06 SOLIDS 439 1159 [CZ, HYDRAULICS zpl 59 53 ~pl 43 39 rpl 36 32 100 9 L~ ~rdV, vol t 6.0 rGrav 54.87 ~i , vol t 0.0 ppb o.oo t~G 2.60 Dilution Rate 0.15 Slds Con~l ~f ?O.O0 BAi~ ~ru~xvs OF x'pl 28 24 ]~ine wate~ Ol 6 rl)u u 1o ~.LUWater Ol 3L'i)u n 8 sea h~.r 2~ p~ss=e ~nits: psig ,hole ~d lOO ~ l~o~. DP 1878 Barite 0 IPL'eSS la'Op, Bi'T 4~ Cbm.ica.]~ 0JP:ess l)n~)., Ami 165 l)u~oed 420iAV, DP f'c/LLu 196 Lost 0JAV, z)C ~/LLn 30O I"a~L~.~ ~-~ BAY l~ Grad 0.0 ~ 2, Leak Off Test 0,0 TRIPS 4. BCD ppg SERV, ILIG 1. Csg, Shoe 10.0 smtvff 1. TI) 10,0 H,qI[iIG O. HaL Diff. ~ 0 LO(~]iG O. CORE 0. .DEVIATION INFO ' Bt(I[I~Ill 0. 5430 fl: ]{UE31~ 0. TV]) 4191 ft TEST]:~ 0. ~A~e 49.70 ~ 0. · ~on ~1.~ l~ ~ 1~. Hofiz. n4~1 ~lq ~-~27 '--]~Y ~ t ~ ~ Baro~d DRILLING MUD REPORT Date 12/26/'00 I ~ "~ I statol count:y I m~u ISA Spud Date men 151olol2/912121918151oloI 12/13/00 ' OP~ATOR ADW ~ NABORS Pu~0RT FOR I P~ORT FOR JOE POLYA/ STEVE CHRISTIAN I FINKBINDER/ JIM WOODS REPORT : ~BER: 14 Depth 6186 ~t [MD ] Present Ac=ivity DRIL~TNG/WIPER TRIP RIG ~~ SECT, TWNSHP, RNG Sll T13N R!3E W~.'L,L NAME AND NUMB~ ~FIELD OR BLOCK NS10 CLASS I DISPOSAL WELLI NORTH STA~ BiT DATA ['.~. DRILLinG ST~ING ft CASING size 9.875 in. ~.pe OD 5 ID 3.240 Len. 6014 Ho. Jets ~'il~ o~ ID Leu. Jets 32nd inch Eol.lar OD 7 ID 2.8125 Lea, 172 Set: e u I 18I ~8~UaroD ID Leu. ~, 18 in, OPF, H HOLE ft Set i ~ot lioz Area I Size TFA ] Size Size Size Size hub ~O~T~S T~ I COUNTY, PARISH, OS. AREAl ST/PRV NORTH SLOPE [ AK CIRCULATION DATA nTT~.T_. Al.700 PT in. ri: I~, 96.ooI v/st o.lo. 10 3/4 set e 3742 I hh~/~in 14.:t O_T!,m~TJ, Al700 PT Tm) lbs DEITY/D LT - 50 LB. RAG 17 920.38 I)RIL-J-~, - 55 ~, ~ 4 2484,88 F3-BOD I)P - 14 GAL, CAll 4 194,, ! EA. 1 25,00 uu ~e Gray, vol t 6.3 ~.~7 I/~ ~nv, vol t 0.0 ppb 0.o0 2.66 ~l~on ~ o.~o ~1~ ~n~l ~f 7o.~ 9,875 Len. 2444 Len, Lan. Set e Sere Sere Lea, ; Set@ Lea, e sate 2 3 PUBp Size 6 l 12 sim 140 Pulp size ~u ]=~. 9~.oo] ~/s~ o.lo ~ o I _,,_,,~_/~n o.o Pu~p ~kqliodel Size X {Elf. 0.001 V/St 0.00 sis o I ~_/~ o.o Tot. Vol./lin 593 mu 14.1 BO 'tim 31 ITC The ~r- 86 HUD TREATM~.NTS chnlato ~fface syste~ ~d r~n w~le ~ben back on bottom add the follouing: 1 l~llet K(~ add 3 berof~ h~ly 48 Bannex as (~ill ~ 4 clayseal I Bardzan D hrly 2 Dextrid hw'ly lO ~_~_~ 700 RIG AcTIvITY back to shoe- T~GHT BOLE after 3 stds out- PU~ GUT ABD BA~ REAN ALL ~lg NAY TO THE SlD~- no l~ck off problms- no losses 3742 9.0 40 10 15 3,0 ( 8,0 3600O < 60.~ MA'r~IALS USgD 0sed Co~t ~ 1 12~1.07 ~ CE~/D! - ~0'UI. 20 165~.~0 l-tide 207 - 6 LB. fAIl HYDRAULICS rpl 43 44 ~ 36 37 ltl 27 28 6rpa 11 13 Units: psig Press D~. ~ 2176 Dress D~0p, BIT 416 PreSS l~.p, ANN 182 &V, Dl) ft/nln 196 ~i,~,/~_, I~. _m~___' ~ITI~S bbl 0il 0 ~he ~er 0 ~ill ~ate~ 0 Sea~ ~00 ~bole l~d 0 Bgite 0 Cheatcals 0 UFOS bbl lmped 339 Lost 0 VOL GAII~ -39 Ban)id t'ec~ to vt up 1500 bbl by 1 m 880 sk; cun'evt hiventory 14328 sk. 112 1597,12 4 424.40 12.0 ~ 3.0 TRIPS 9.0 SmV. HO 0.0 SI]iNff 0.0 N.,urr~ 0.0 itUll CSG 0.0 ~ 0.0 ~ 0.0 ~ 0.0 A~ ~ 63.0 SOT.TDS ~ reco,~htions ~de he~eon shall not be ~ as autborifin~ the i~~t of any vnl/d ~tsnt, ~ are nde vitbout ~sstmption of any 1/abtJ./~ by BAI~ID ~r.T.'ruG FIJII~, ~lC, or its agants, and ~ statements of ol)iiion only. DEVIATION INFO HD 6186 ft TVD 4791 ft ~_le 47.22 DiA, ct~on 202.96 Horiz. Displ 314_ ft 907-275-~_~ 659-'2422 F. Grad 0.0 Lea~ Off Test 0.0 ~. Shoe 10.0 T9 10.1 NaY. Diff. Press 0 [ DALLY C~14613.7~ CUJIULATX~ COS' . . 8aroid DRILLING MUD REPORT Date i2/28/oo I ~I~LLIStatel~t~ I ~ell ~ Spud Date an 1~lolol2/~12121~1815lolol i2/i]/oo, OPERATOR {CONTRACTOR ADW INABORS REPORT FOR IREPORT FOR JOE POLYA/ STEVE CHRISTIAN ~ FINKBINDER/ JIM WOODS REPORT NUMBER: 16 Depth 8044 ft [MD] Present Activity DRILG TD INTERMEDIA~ WELL NAME AND NUMBER [FIELD OR BLOCK NSIO CLASS I DISPOSAL WELLI NORTH STAR BIT DATA Ii. ri. DRILLING STRING ft size 9.875 in. ~i~ OD 5 D 3.240 Imm. 7872 ~o. ~ets IPi~ ® ~ ~. 3ets 32~ inch EoLlar OD 7 Il) 2.8125 Len. 172 12 118I 18 [Collar 01) ID ~e~. 18 in. OPEN HOLE ft Tot Noz Area ~ Size 9.875 Man. 4302 TFA I Size Len. Size Man. Size Len. Size Len. MUD PROPERTIES 2 3 Time m Temp ~veso Cake l~i/:~ 32nd Co~T.Solids t by vol oi~/wa~ % by vol send ~ by ye! METER e 70 TauO RIG NUMBER 33E SECT, TWNSHP, RNG Sll T13N R13E lCOUNTY, PARISH, OS. AREAI ST/PRV NORTH SLOPE AK CASING in. ft lo 3/4 ~et @ 3742 ~et~ set@ Set@ set @ set@ set~ Set~ set~ 3742 9.0 40 ~0 3.0 CIRCULATION DATA ~mp ~ake/~odel Size 6 X 12 I~ff. 96.ooI v/st o.: spa size 6 x n {=f. 96.~I v/st o.: spin o I bbl/~n o.0 size x {~f. o.~{ v/st o.t spin 0J bbl/dn 0.0 : ~t. Vol./gn 85 ~m B.1 bi '~ Time 38 I~ Ti~ 93 ~D ~~NTS ~le When back on bottom, add: Wate~ at 25 bbl l~ hr; lo,er ~P <20 ,1 pa11~ [c~ 10 B~ascav D 12 Baraco~ 700 < < 8.0 36O0O RIG ACTIVITY to TD of 8044'- pu~ed wted hi~ v sweep- cinmlatsd 1~00 strokes (:3+ anula volues)- Curm~y wll~ t~ip to shoe- no problem, no tiqifc hole so far (15+stds ou MATERIALS USED Pnm~ct 0sed Cost BA~AC0~ 700 - 5 GAL. CA~ 14 1161.16 BACArdi - 50 LB. BAG 144 8553.60 BA~-D PLUS - 25 LB. BAG 7 1064.42 CLAYS~L - 55 8A~. ~1~ 8 5262.80 DEXTRID LT - 50 LB. BAG 31 1678.34 EZ-JiUD DP - 14 GAL. ~ 10 487.00 Hud Laboratory - 1 EA. I 25.00 POTASSIUM CE,0RIDE - 50 LB. 112 1597.12 MUD MANAGEMENT 1°1.50 50 MUi) CONSUMPTION Active Volume ! ADDITIONS bbl ,esem.1400 lt~1400 { Oil o To Brine ~ate~ 0 DfiU ~ater 0 Low Gl:av~ vol % 6.4 Sea ~at~ 400 iiipl~gh- 58.60 ~ole ~ 0 G~ev, vol % 0.0 Barite . 0 ppb 0.00 C~cals 0 A~G 2.67 LOSSES bbl Drill Uuttings 95 ~mpa4 268 Dil~tion Pate 0.40 kmt 0 Sl~s Control ~ff 70.00, VOL GAI~/~ ~32 BAROID ~J~r~i.riV,. ]OFHCE/HOME {~3RQ-TR]]{ II - 55 GAL. DRUH X-cide 207 - 6 LB. call Baroid required to ~t up 1500 bbls by &90 sk; cun~t 14328 SOLIDS 8 4750.96 8 848.80 1 28.26 RHEOLOGY AND HYDRAULICS 000rpm 53 57 300 z~m 3~ 42 200 z])m 31 35 [00rpm 23 26 6 rpm 10 11 3=pm 9 9 Pressure Units: psig P~ess Drop. DP 3106 ~es~ Drop, BIT 478 P~ess Drop, A~ 210 &ctual Circ. Press 2400 ~V, DP ft/lia 2i0 &?, IX: ft/IJm 32i &V, lise~ AHCSORA~Z/~Z ~ater ~epth talc. F. ~ad 0.0 Leak Off Test 0.0 ~C~ pp~ Csg. Shoe 10.0 TI) 10.0 Itu. Diff. Press 0 DEVIATION INFO MD 8044 ft TV1) 6339 ft A~le 25.69 Direction 203 Hori:. Displ 4242 ft 9O7-275-2627 659°2422 S~. HO , ( L~ING ( REAMING T~ < OTHER ( A~E~AGE ~ 62 DAILY COST ~ C~ULATIVE ( $ 26572.4 ~ 2316~. The reco~ndat/ons Bade hereon slmll not be' construed as antho~izin~ %be i~~t of any valid patent, and are lade without ~ump~ion of any liability by HaROlD DRY~ Furms, mc. or its a~ents, an~ am s~atoments of opinion only. Baro~Q ~EPORT ~ BER.' 17 DRILLING MUD REPORT I Date ~ Depth ! 12/29/'001 8044 Et [MD] I APl W~LL I State~ County I Well ~S/~ I Spud Date Present Activity mmmt 15101012~9121219181510101 I ~2/~3/00 LOGGZNG OP~ATOR I COh'~'~A¢'~R ~[e NU~E~ ADW I NABORS 3 3E P~O~T FOR I P~POR'~ FOR SECT, TWNSHP, RNG PAUL LOCKWOOD/ CHRISTIAN J FINKBINDER/ JIM WOODS Sll T13N R13E W,LL NAHE AND Nu~K I FIELD OR .LOC~ iCOUNTY, PARISH, OS. AREAi~/p,v NS10 CLASS I DISPOSAL WELL NORTH STAR NORTH SLOPE CASING CIRCULATION DATA BIT DATA b~' DRILLING STKING ft ~'~'e' 9.8~5 hi. IP.~LM OD 5 LD 3.240 Lell. Ho. Jm pipe OD ~ zen. Jets 32nd Inch Eol,ar OD 7 ~D 2o8125 Leu. 172 18 11~ OD ID Len. 18 in. OPEN HOT.I~. Tot ]Joz Az~a I Size 9.875 Len. 4302 TFA [ Size Len. S~ze Lan. S~ze Lan. S~ze Leu. kuu PROPF~TFES 2 3 PV F ~P 32M vol Sadt~ k~na @ 70 ~k. SUL~LTE ol'um~ A1700 P~ ~n. ft 61 12 Eft. Se~ @ 3742 ~ sero Set@ 6X12 fl set~ o 0.101 15.1 0T.L.~m. ~700 ~ I,%.,? 0.0 0.101 Set 9 X S ff. 0.000 Set 8 0 0.0 Set ~ 635 15.1 bbl Set @ 38 89 MUD and Progra. SULYace sys~ and ~n cen~]~ugas 3742 Add to surface syste~: 9.0 2 l~eaneez ~a~/- 40 2 l~ Der~id 10 I sk Caus~c ~ 9+/- 15 7 l~b ECL C~ 4OOOO +/- 1 dna ~dacide 3.0 ilben ~ on botto~ for final condition fo~ casing; repeat above tns~unt. H20 25 bl/nr ' ItT~ ACTIV/TY < < to shoe- c~t etd sUp d~int~ line- fl~- no probleas- ~ eted seee~ cadtttoa fo~ lo~s- ~-. M problem- hole seeas In qo~xl shape- hole took 30q- bbl nd as trip ad ~ to loq 3f~O0 NA.z.A~IALR US~i] B~7OO-5OAL. CUI 12 995.28 X-cide2OT-6LB. CAlf BABASCAV D -. 50 LB. BAG ].8 8~9,88 cab-tic soda - 50 LB. BAG BAI~ALII-D PLUS - 25 LB. BAG i L~..O~ Ct:Bff~ - 5~ GAL. DRUH 2 787.96 DE.lID LT - 50 LB. BAG ]. 54.].4 2. 'EA. 1 2S.O0 ~uD MANAGEMENT mn'rantly ~ .lth logs, 0300 hr 12/30 Sa~oid ~ to ~ up L~O0 bbl by 1 ppg 880 Sk; ~=L'ent Invefcory 14328 sk. SO?.TDS ~ 4 424,40 I 28.26 [~ 'Gray, vol t 6.4 v, vol % 0.0 o.oo 2.67 ~in o,~ngs o 0.0 4.0 16.0 1.0 1.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 2.0 0.0 ~ recomuda~ons nde be~e~n sMLt not be constmmd es autterhiw the J~'-=~ of any valid pa_~fc, and a~e nde vithout ~mption of any Uab~ty by BAiO~ ~ FUmS, ~C. or l~ agents, ad are state~nts of opihion only. HYDRAULICS DRL; Grad 0.0 ~ Leak Off Test 0.0 TRIPS 9.9 ] ~ HaL Diff. Pt'e~s 0[ ~ " DEVIATION INFO BA~ REAH TVD 6339 ftI TES~ DhoW/on 202 AVenGE BOP 907-2'/5-2627 I ~AZLY (:0$T60~ 8~ ~ CO~ (' (' Baroid REPORT NUMBER: 18 12/30/00 8044 ft [MD ] I API ~LL I Statel ~ounty I ~.11 ~/~ Spud Date Present Activity ~m ]5101012~91'2]219}815]010~ 12/13/00 TIH C?.RAN OUT RUN ADW NA_~OR$ 33 E REPORT FOR R~PORT FOR SECT, TWNSHP, RNG FINKBINDER/ JIM WOODS Sll T13N R13E PAUL LOCKWOOD/ CHRISTIAN WELL NAME AND NU]~BER I FIELD OR BLOCk NS10 CLASS I DISPOSAL WELL I NORTH STAR Size 9.875 in. ~iDe OD 5 I9 3.240 I~_,, 7814 Tylm ~X-Cl ~'ipe OD ID {i~, in. No. Jets ~i~e oD ID {~, lo 3/4 set ~ 37 Jets 32nd inch ~ollar OD 7 ID 2.8125 {~, 23O set @ 12 t 18I 18pllar0~ ID '~"-. ~t@ 18 in. OPEN HOLR ft Set @ Tot Coz Area I Size iSize Size She Size TFA NuD PROPERTi~S FL Tel~ Da 200 32nd vol 9.875 Lea. 4302 ~t @ Lea. set ~ 2 3 ICOUNTY, NORTH 3742 9.0 40 10 15 PARISH, OS. AREAIST/PRV SLOPE AK CIRCULATION DATA pH ~z.~ @ 70 ll~. i;m; Uk. Chlorides ~/1 Low 3.0 l~p Nake _/~_l O!T_.~.T_. A1700 PT si:e 6 xl2 I=f. 96.ooI v/st Si:e 6 ! 12 I=f. 96.~)I V/st S~! 0 I bbl/.i. 0.0 si:e x Eff. 0.001 V/st spa 0 bbl/,in '0.0 Tot. Vol./i~n 635 ~! 15.1 BU tile 3717~ ?~ 88 MUD TREA~NTS asper pro, au When back on botto~ for clen out trip- final condition far casin~: 9.~ pup eted hi~ vis sueep circulate ainimm of 18000 strokes nm vuter at 25 bbl per hr inside ~L, ~L, and ~P are in line 10.( < 2.( < 8.0 36000 0.14 O.OI RIG ACTIVITY bm logs to ao problem- tested BO! cun'ently TH for fimtl dram out and condition fo~ riming 7 5/8' casing Baroid reguited to et up 1500 bbls by 1 p~ 880 ak~ current inveutoL7 14328 ak. . . NUU MANAgeMeNT I RHEOLOGY AND huu VOLUME bb~ MUD TYPE I HYDRAULICS Hole I Pi= | ~ POLI~R |~0 Zla 50 648 I. 68~ / HUD ~I01~.~ rp~ 34 A~ti~e voiu~e | DDITIGHS bbl L200 rpt 28 _ 1328 | Oil _ . 0 100 rpI 20 aesem ITo~ / ~wa~ o 6~ 8 / n28 / ~rill Ware: o 3 ~p~ 7 Low Grav~ ~o! ~ 6.2 / Sea ~ter 0 ?t~su~e ~t~: ~g Gray, ~o! % 0.0I Barite · 0 Press l)rop~ BIT 478 ppb 0.00 Che~ca~ 0 P~ess Drop, ~]i 168 ~ 2,&T ~ bM A~ C~c, ~ 24~ ~ ~t~ 0 ~ 0 AV, ~ ~t/~ O~on h~ 0.~ I ~ 22 AV; ~ ft/~ ~ ~n~ ~ 70.~ [ N~ter l)el~ talc. F. (kad 0.0 I~ Off T~t 0.0 ~C~ p~ ~. ~ 9.9 TI) 9.9 Max. Diff. l~ess 0 DEVIATION INFO ~ 8044 Et TVD 6339 ~ ~o~le 25.69 Direction 203 ~oriz. Displ 4242 ft 907-275-2~27 } DAILY C 659-2422 { $ DH~; o ClRC 0 TR/?S 8 SERV. RIG 0 ~ 0 HSHHG 0 Ilia;IR; 8 IL'Ill CSG 0 COlU: 0 BACK IW,~! 0 P, EANIIG 0 ~ 8 ~ 0 AVERAGE ~ 0 10708.6 $ 245297 The recom=latio~ nde hereon shall not be cemtmed ~s authori:in~ the htrin~ent of any valid patent, ~nd are ~de vithout ass~tion of a.y li~ilit~ bi ~II~OID ~ ~IIDS, liE. or its a~ts, ~d are state, ts of opiiion only. Baroid( REPORT I' ~ER: 19 DRILLING MUD REPORT [Date I Depth } ~2/~/'001 8044 I ~um, Ls~..~ I ~-~ I ~u ~So~ i Spud Date i ~re,e.t A~t£v~t¥ I~l°l°l~-I~l~-I~-I~lSlSl° I ~/~/OOl a~ ~ ~/s" ~NG OP~TOR [ CO~T~Oa a~G ~w I N~ 3 3 E ~RT FOR J ~T FOR SE~, ~S~, ~G PA~ ~OOD/ ~ISTI~ ~ FI~IND~/ JIM W~DS Sll T13N R13E ~= N~ ~D ~0~ I~iELD O, ,LO~ I CO~Y, P~ISH, OS. ~Al~/p,v NS10 C~S I DIS~ ~ NORTH ST~ NOR~ BIT DATA ~. DRIVING STKING ft ~ ~SING [ CIRC~m~TION DATA ~}~ ~ ~. ~. ~t ~ze 6xu I'~, 9G.~I v/~ ~1~ ~ ~ ~. lO 3/4 ~ e 3742 ~ 0 I~!/~ o.o ~ ~ ' ~ ~. ~t e set~ 0.]L~I 9.875 ~. O~EN HO~ ~ i ~: ~ I Size 9.875 ~. 4302 I J Size ~. ' Size NOD PROPiK'2~S 2 3 Tiae LDI Flit. G,~.~ol/ds % vol vol send t by vol AI~. AI~. Set! 3742 9.0 40 10 15 3.0 si_,,_ 6 x u [~, ga.oo[ v/st spu o i~i/~ o.o size z I S~. o.~lv/~ o.~ sp o I _hbi,~ 0.0 Tot. voi./~in 0 ~- o.o b_hl ckculation slouly (as per stroke schedule) stae, tng up pups to 8 to lO bb! per ain condl~oning nd and hoXe addl ppb Mcerb .5 ;pb wate~ at 25 bbl per ]= to love~ store h~O bbl iud hi ~I FOR 1st stage RIG ACTIVITY md ~d bole for cashx~ no losses noted- no pt'oble~s as TCH- c~y mmV'7 5/8, X-cld~ ~07 - 6 m. CiJ caustic soda - 50 Za. ~G )[A'rJsj~T~T~ USeD 10 ~.60 1 1~.06 ~J 1~.~ 1 1115.00 1 34 3607.40 1 28.~ IMrold L~plnd to vt up' lSO0 bbl by 1 ~ 88o ~M; m=~nt Jmm~7 ~328 K. 767 1447 Total ~ { 1447 Wv, ~o! t 6.3 rGrav~.06 , vo~ ~ 0.0 O.ffi ~ilffiO~ ~ 0.~ ~1 ~f ~.~ ADDITICmS bbl 0J.1 0 Rrine Water 0 Drill Nat= 0 i ~ 219 Nbole l~d 6O ~ite 0 Cbaic~ 0 LOSSES bbl ])u~Ded Lo~ 0 ~oz, &mf~ u9 ?. Grad 0.0 Leak Off Test 0.0 KD ppg c~. ~oe o.o TI) 0.0 ~u. Mfr. Press 0 DEVIATION INFO 8044 ft 6339 2~.69 2O3 ~ri:. PL~! 4242 ft the ~co~J~iat. ions ~de he~eon shall not be construed as authori:i~ the i~~ of an~ valid Patent, and are Bade without resumption of any liab/lity by B~0D m~TI._TU; FUJIDS, IIC. Gr its agents, and a~e statesen~ of opikion only. REPORT NUMBER: 20 Baron" DRIL~._..G MUD REPORT Date o~/o~/o~ 12/13/00 ~w I N~ 3 3 ~RT FOR I ~~ 'FOR SE~, ~S~, PA~ ~~D/ ~ISTI~ I FI~I~ JIM WOODS Sll T13N R13E ~ N~ ~ --~ IFI~ OR B~CK ICO~Y, P~ISH, OS. ~IST/PRV NS10 ~S I DIS~S~ ~ NORTH ST~ NOR~ SLOPE BIT DATA Size 9.875 in. CASINGft lo 3/4 ~t ! 75/8 sece 8044 in. OPEN HOLE ~ot ~o: Azea ~Size ta~. Set: ~A ~si~e ~. ' laze ~. l~e ~. ~ ~ ~OP~TIES 2 3/42 9.0 P~ e 7o Decj~ cP ~o vol vol H~Pdo DeplLh 8044 £t [MD] Present Acl~ivity INTER CSG CMT JOB MAT~I .ALS USED '~A. 1 25.00 bi(~d)enate o~ soda - .SO ~. 37 874.31 citric acid anhydrous - ~o LB 20 ~rL~o 3.0 CIRCULATION DATA ~p &~d~ om~ ~76o ~ o I bM/.~ o.o 6xu I Ly~. 96.6o[ v/st oa s~ o I~/~ o.o after olmi=j ~S ce~te~ follo~i=l 1st < 2,1 < 8.0 ~66O0 progm, m 24328 SOLIDS 369 1049 £CL 1~ off HYDRAULICS ~pl 38 9 L'pl H 24 L6O~pl 22 17 6Z~l 8 6 27O l~]/Ua~ 0 7 5 ~ Gt~, .4 Sea later 16O ~nits: psig l)Pb ~.o~ I ~ole ~1 o L=nss l)t'op. ~ 0 si~ ~rav, vol t o.o I Barite 0 ~ k,c~, SIT o _ ~ o.6o I _~__i<a~s 26o ,Pt'ess ~.~, ~n o m:~u ~ o l zmped · UO ~, DP ~/,h 0 ~en late 0.001 LoK 3~ ~V, DC ~c/~n' 0 ~rad 0.0 Leak Off Test 0.0 ~C~ ppg ~Csgo Shoe 0.0 0,0 llal. Diff. ~ 0 -DEVIATION INFO %'VD 6339 ft D.~en 25.69 203 ~a'iz. D~sp! 4242 ft 907-275-2~__Z~ I DHL~ 0 ~ 0.6O CIIC $.6o TllPS 0.6O SglY. RIG 0.00 SURV~ 0.00 LOOOZIK ~ 0.6O BA(~ ~rdla o.oo ~ o.~ 84.8 ~ 25~9.52 .~e zecomndations sade bezeon shall not be conslzued as auth~i:inq the in~t of anl valid patent, and are lade vj/~i)ut ~s.~on of any Lbbi2i~ by BAi~O~ ~n.tnq FLUZ~, IE. oz its agents, and are sta~un~ of opiaien only. ( ( Baroid DRILLING MUD REPORT oP~o~ I co~c~o~ ADW ~ NABORS REPORT FOR ~REPORT FOR JOE POLYA/ HIK~ DING~R ~ PAGe/ ASHLEY N~LL N~ ~D N~B~ ~P~LD OR BLOCK NSIO C~SS ~ DlSPOS~ ~{NORTH S~ BIT DATA [JLn. DRILLING STRING ft CASING Size 6.75 in.'~i~ 0D 4 ID 3.240 ~. 7846 -~'~ ige 0D ID ~n. in. ft Size ~o. oe~ ]~i~ OD ID ~n. 10 3/4 set ~ 3742 sps Oe~ 32nd inch ICo~hr OD 6 ID 2.25 ~. 129 7 5/8 ~t ~ 8044 14 [ 14I 141Co11,, ID ~. Set~ Size in. OPEN HOLE ft ~t ~ spn To~ ~o~ ~ea ~ Size L~n. ~t ~ ~p TFA ~ Size ~n. Set ~ Size ~ Size ~. ~t ~ ~ Size ~. ~t ~ ~ Size L~. ~t ~ REPORT ~BER: 23 ]Date[Depth 01/04/01 8044 ft [MD] Spud Date Present Activity 12/13/O0 RU TO R~ LOGS RIG N~BER 33E SECT,~SHP,RNG Sll T13N R13E ICOUNTY' P~ISH' OS' ~AiST/PRVNoRTH SLOPE ~ CIRCULATION DATA aake/M~el np:~.~_, nTOO ~r 6 X 12 JEff. 96.00[ V/st 0.101 55 [ bbl/nin 5.5 Make/Mode.1 OXL~ELL UTO0 ~ 6~n ~=~. ~.~lv/st o.zm 0 J bbl/~in 0.0 ~e/~el X In.. o.~1 v/~t o.o~ 0 ~ bbl/~h 0.0 Tot. Vol./~i. 233 ~a 5.5 bbl ~ T~e 43 ~ T~m~ 208 MUD PROPERTIES 2 3 SOt~Ce Tine Proven FL Tesp Depth ft 3742 ~ei~t 9.0 1~ @ 60 40 PV ~ 70 F eP 10 ~P 15 APl Flit. 3.0 ¢orr.Solids thy vol ',oii,~ater t by vol Sand % hy vol '< 2.( _'__ pa m~t~ ~ 70 8.o 9.,_ 2. ~ (~'). AlL fi!tr. (Pi/Hi) ~lorides ~/1 36000 ( 60.~ TauO lbs MA'~.'RIALS USED PrOu~% ~sed Cost Product BAEAZAII-D l%US - 25 LB. BAG 1 152.06 =inee~im] - 2 EA. 1 1115.00 '~a~rat~ry- 1 EA. i 25.0O bi~rbomte of s~da - 5o r... 46 1086.98 ciUic acid anhydrous - 50 LS 36 3510.00 MUD TRRATMRNTS l~eat cement contamination vith bicarb (2 ppb) and citric acid (1.5 PI)b). Pluming to drill reni~ler of cement w/kill vt hud (discerding retunm) to r~ f~ coment ~n~nation of K~/~lNer ~d. ~ill a~ ~x~id, ~, nd ~az~ to brinq ~ up to s~ ~ ~r proart prior to ~i11~ ~v rotation. RIG ACTIVITY cement from 6010'-6095', drill ~S ceaente:. Test csg at 6124'- 500 psi. Pg 4" DP, drill cenent .from 7725' to 7975', citc and condition, test csg, POOIL Riggin~ ~ to run bond lo~s. Baroid recNired to vt up 1500 bbls of mud 1 . ppg- 880 spas, current inventory- 14,328 sics SOLIDS MUD MANAGEMENT Active Volvme 1158 ~eserve [?ora 150 I 1308 Lov ~av, vol % 6.3 ppb 57.69 aigh ~av, vol ~ 0.0 pp~ o.oo ~ 2.53 Drill Cuttings 0 Dilution Rate 0.00 Slds Control Mf 70.00 ICL POLYI(ER HUD CONSUNF~IO# ADDITIOHS bbl Oil 0 Brine ~ater 0 Drill ~ater 0 Sea ~ater 0 Waole Hud 0 Barite 0 Chemicals o LC~ bbl RItEOLOGY AND HYDRAULICS FRACTURE 60~ rpm 67 80 300 ~m 47 55 200 ~m 38 46 100 ~n 27 33 6 ~n 11 12 3 rpm 9 10 Press Drop. DP 561 Press Drop, BIT 229 Prens Drop, AH~ 476 Actual ci~'c. Press 1000 AV, DP ft!min 183 AL D~ ft/min 50? ~;ater Depth Calc. F. ~rad 0.0 Leak Off Test 0.0 ~ pp~ Cs~. Shoe lO.S ~ 10.5 ~ax. Diff. Pr~ 0 DEVIATION INFO ~D 8044 ft TVD 6339 ft D~ 112 ~gle 25.69 L~st 0 Direction 203 ~OL a~ru/I~SS -u~ Horiz. Displ 4242 ~ , J OFF~/~ ~7-275-2627 ' I~sE 659-2422 DltLG 8.00 ~ 3.50 THPS 4.50 SERV. RIG 0.00 SRV~Y 0.0O FI~ ~ 0.00 R~ ~ O.OO ~ o.oc ~ ~ 0.~ ~ o.oo ~ 7.00 A~gg ~ 0.0~ ]DAILY COS~889. Ol CUI~LA?IVE COST ~ $ 274771.54 l%e recoanendations ~ade hereon shall not be construed as aut~rizi~ ~ infringement of any valid patent, and are nde without assumption of any liability by BAI~OID DILILLIIlG FLOIIB, INC. or its agents, and are statements of opinion only. Baroid DRILLING MUD REPORT mmm Islolo12/912121918151oIo1 OPE~TO~ iCO~x~C~OR ADW INABORS REPORT FOR IREPORT FOR JOE POLYA/ MIKE DINGER I PAGE/ WELL NAME AND NUMBER IFIELD OR BLOCK NS10 CLASS I DISPOSAL WELLI NORTH STAR BIT DATA lin. DRILLING S'£KING ft Size 6.75 in. ~i~ OO 4 ~ 3.240 Len. 7846 T~e ~t~n X~ Kip OD ID Lan. No. Je~ ~i~ OD D ~n. Je~ 32nd in~ [~11~ OD 4.75 ~ 2.~ L~. 172 14 I 14 I 14Ioll~OO ID ~n. in. OPEN HOLE ft Tot Noz ~ea {Size 6.75 ~n. TFA { Size Imm. Size ~n. Size Ian. Size L~. MUD PROPERTIES 2 3 Source ~'im~ ~ th ft Pv i 7o Decj~ cp ~els l~s APl t'f~ ~ 200 Cake 3~nd Co~. vol Oil/~te % by vol ~ ~ by vol lbs REPORT NUMBER: 2 4 Date I Depth 01/05/01[ 8044 ft [MD] Spud Date[ Present Activity 12/13/001 RIB TO ORL RIG NUMBER' 33E SECT, TWNSHP, RNG Sll T13N R13E [COUNTY,NoRTH SLoPEPARISH' OS. AREA[ AKST/PRV in. ft 10 3/4 Set @ 3742 75/8 Set@ 8029 CASING CIRCULATION DATA Pump Make/Model OI~ 11700 PT size 6 x ~2 [ur. 96.ooI v/st spm 59 ] bbl/min 6.0 Pump Wake/Model OIT_.._'~_T.r_. 11700 PT Set @ Size 6 X 12 {Eff. 96.001 V/st Set @ spm 0 [bbl/nin 0.0 Set @ Pump P_~ke/Model Set @ Size X [Fir. 0.00{ V/st Set @ spm 0[ bbl/min 0.0 Set @ 'Tot. Vol./min 250 ~]pm 6.0 Set @ BU Tim_~ 41 [TC Time 194 MUD TREATMENTS Pro,ram 3742 9.0 9.f 40 10 15 3.0 10, < 2.( < 8.0 9.'~ ( 60, 0.101[ 0.101 0.000 bbl AT R~IK)RT TIM~, CIRCULATIIE TO TEST CASING. TR~AT WITH CITRIC ACID ~R C~HERT CONTAMINATION, ADDING DEXTHD TO LOWER FILTRATE ~0~S, KCL ~ BaRA2~ ~ l~ED ~R SPECS PER PlI(XIRAM. i~TER TI) ~ S~O~T THP/CI~C ~LE C[~JI,PIAIi TO SPOT VISOOSIFI~ ~ PILL I~ OPEN HOLE, ~ ~ TO CASTI(G SHOE, KX ~ ~ CA'TIC ~u_x3W~l) BY 9.8 PF~ nUTnE, PUT 16 RIG ACTIVITY l~ ~0~ L0~S, ~ EIA, ~ 48 ~TS DP AHO ST~ ~A=, ~ I~, SLIP AND CUT DH~ BARI)ID RB~UIRMD TO NT UP 1500 BBL~ OF MUD 1 P1~880 SKS. ~ INVENTORY-14,328 SKi MAT~RIA?..~ USED DEXTHD LT - SO I~. BAG 2 ].08.28 Rn~inenrin~ - 2 ~. ! ~iB.OO ~TA~I~ ~HDE - 50 ~. 56 798.~ civic acid ~Y~ - 50 ~ 17 1657.~ MUD MANAGEMENT I RHEOLOGY AND MUD VOLUME bbl MUD TYPE { HYDRAULICS aol_e_. I Pits KCL pOLmn {6oo rpm 71 68 · 32.4 .. J, 832 ~am~io~ '13oo r~, 52 48 ac~zve vo,ume ADDITIONS bbl 12oo rpm 42 39 , 1155 0il 01100 rpn 3O 28 Re~erve { Tol~nl90 ' B~ Water 0 6 rpm 12 ~3~ Drill Water 20 3 rpm 20 Low ~rav, vol % 6.2 ppb 56.15 Hiqh ~av, vol % 0.0 ppb O.oo ASG 2.52 Drill Cuttinq~ 0 Dilution Rate 0.oo Sld~ Control Rff 70.00 · ~OD REPRESERTAtiVI~ Sea Water 45 pressure Units: psiq Whole Hud 0 Press Drop. DP 655 Barite 0 Pre~s Drop, BIT 264 Ctmmicals 0 Press Drop, ANN 501 LOSSES bbl Aotual Circ. Press 1300 Dumped 83 AV, DP ft/~n 1~6 LO~t 0 AV, DC ft/~n 248 VOL C~/[I)SS -18 AV, I~i.~1: ft/min I W~d-- ~O-,io~ BaY [SOLIDS EQUIPP-NT ~ IDA ,,~0/I ~ent Im~ I / [F~CT~ G~D ~ 'TI Wat~ ~p~ D~ 0.~ ~. F. Grad 0.0 C~ 0. ~ ~f T~t 0.0 ~ 4. ~' p~ S~V. RIG ~.~ ~. S~ 10.6 S~ 0.~ TI) 10.6 Max. Diff. Press 0 DEVIATION INFO MD 8044 ft ~]) 6339 ft Xn~le 25.69 Direction 203 Horiz. Displ 4242 ft 907-275-2627 659-2422 FIH~II{G 0.00 LO~I~ 7.oo RUN ~ O.oo (}ORE 0.00 Ba(X REAM 0.00 REAMING 0.00 TESTI]iG 0.00 Oil{El{ 12.00 AVERAGE ROP 0.00 CO~T '~ CUMULATI~ COST DAILY S. 3679.3 S 278450.88 The recommendations made hereon shall not be construed as authorizi~ the ~nfriwement of any valid patent, and are nde without assumption of any liability by BaROID DRILLI~ FLUIDS, I~. or its agents, and a~e statements of opinion on2y. Formation Tops I I I I I II NSlO Formation tops KB 55.77 ' I Pre- Drill Estim(~..ed DeptksIActual Depths Formation I Top Permafro,st 1,150 1205 1205 1139 1195 1195 Base Permafrost ,1,500 15.,55 1561 1449 . 1505 1512 SV8 2,559 2615 2840 2554 2610 2845 i i SV7 2,709 2765 3073 2708 2764 3074 SV6 - Top upper confining zone 3,009 3065 3539 2989 3045 3504 103/4" casins .3~149 .,. 3205,_ 3757 .3,136 3t92 .. 3?26 SV5 - Base upper confinins zone 3~299 335.5 3989 3259 3315 3909 SV4 3,559 3615 4392 3,564 ,, . 362,0 4382 , SV3 3~.8..39 3895 4827 3796 ,, 385,2 ,4750 .SV2--Top upper injeCtion interval 4,000 40~5 5076 3962 4018 5007 SV1. . 4,3.,69 .4425 . .5650 4348 4404 ~02 'Top Major Barrier / Base upper inject!9n interval 4438 4494 5741 , TMBK. Top lower injeCtion in[ervai 4,,749' 4805 ' 6240 4704 -' ,4,,760 " 6140" Ugnu (UG3) ...... 5,199 5255 ,684,3 5192 , 524,8 6816 "', , , U~nu(UG1) ,5,750 5805 , ,7467 , ,57'11 5767 ,, 7408 Top.Schrader BlUff 6,300 6355 8078 6257 6313 6015 . 7 5/8" ca~in~ .... 6,.300. 63~6 ,. 8079 .... 6.2.69. 632.5 .. 8029 . current Depth 6457 6513 8246 Total Depth - Base lower injeCtion ......... ..... !nte,rvai .... 6,500 . 65.55,' 8300 ....6457 65ta 6a46 !,roJected.Top .Lower confining Zone 6,895 6951 7868 6840 &596 Formation Logs LOCATED IN THE APPENDIX UI WFL UI IPR LOG ~]'~CALIPER SURVEY UI VOLAN UI CURVE DATA UI STRATIGRAPHIC HIGH RESOLUTION DIPMETER Gl OTHER: %/. pRo%'~.0'~ Reply To Attn Of: OW- 137 UNI 'Tiu STATES ENVIRONMENTAL PROTECTION AGENCY REGION 10 1200 Sixth Avenue Seattle, WA 98101 April 18, 2001 Mr. George R. Snodgrass Environmental Manager BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Dear Mr. Snodgrass: This letter is in response to the April 5 facsimile notification for a mechanical integrity test (MIT).at the Northstar Class I injection well facility. The letter was addressed to Randall.Smith, 'dated April 5, 2'001, and was received at our office in hard copy format on April 11, 2001. We have 'also received a telephone call from a member of y0ur Staff, Alison Cooke, requesting approval to perform the'MIT on or about April 26, 2001. Therefore EPA has effectively received notice twenty-one (21) days prior to the proposed MIT. date. Approval is granted to BPXA by EPA to commence the MIT at the Northstar Class I well under EPA UIC Permit ~ AK-11002-A for this'MIT test only. In the future BPXA must comply with the permit Dart 11,C,3;c, (3) which requires the permittee to notify the Director of intent to demonstrate mechanical integrity at least 30 days prior to the MIT. In order to avoid potential future.timing problems and the associated expenses to BPXA and EPA, we suggest scheduling of future MIT's farther in advance. I have asked Thor Cutler to' call your office to discuss next year's MIT schedules. Please" call Thor at (206) 553-1673 .if you have any questions. cc: Sincerely, Randall Smith~ Director Office ..of Water Pete McGee, 'ADEC Cammy Oeschli-Taylor, AOGCC RECEIVED Alaska Oil & Gas Cons. Commission Anchorage O Pr/nte~ on Recycled Paper bp Date: 02-01-2001 Transmittal Number:91901A BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NS10 01-16-2001 SCH 1 8040 8450 R.A. TRACER INJECTION LOG NS10 ,01-15-2001 SCH 1 0 8185 INJECTION LOG P~ease Sign and Return o[~e copy. of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center AOGCC Murphy Exploration (Alaska), Inc. Division of Natural Resources Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp (' ( BPXA WELL DATA TRANSMITTAL Date: 02-01-2001 Transmittal Number:91901 Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Bottom ~lame Date Contractor Log Run Top Depth Depth Log Type NS10 12/30/2008 SCH I 3,724 8,001 BHPRO;GEOMETRY ~NS10 12/30/2008 SCH I 3,724 8,001 CNL;NUCLEAR (NEU) e LDT;NUCLEAR (DENS) NS10 12/30/200(3 SCH 1 3,724 8,001 DLL;RESISTIVITY NS10 12/30/200(3 SCH 11 8,036 RESIST;RESISTIVITY 3,724 AC;ACOUSTIC / LWD (GE); LWD GAMMA RAY NS 10 12/30/200C SON I 3,724 8,036 SONIC;ACOUSTIC,, NS10 01/07/2001 SCH 3 7,988 LWD (GR); LWD GAMMA RAY; / 222 (CD ROM) ROP; LWD AUXILLARY; (CD ROM) ~S10 12/30/2000 SCH I 3,724 8,036 BHCS; ACOUSTIC (CD ROM)' HALS; RESISTIVITY (CD ROM) / 235 LWD (GR); LWD GAMMA NS10 12/14/2000 SCH 1 8,219 RAY(MD) ! 235 LWD (GR); LWD GAMMA NS10 1 2/14/2000 SCH 1 8,219 RAY(TVD) ~1S10 '12/24/2000 SCH 1 400 3,660 USIT;CEMENT EVALUATION NS10 1/5/2001 SCH 1 3,650 7,965 USIT;CEMENT EVALUATION 8,246 SURVEY REPORT; PAPER; NS10 DIRECTIONAL SCH 0 8,246 SURVEY REPORT;DISKETTE NS10 DIRECTIONAL SCH 0 3.5; Please Sign py of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP- Ken Lemley M83-6 BP- Jim Seccombe MB 12-3 AOGCC Murphy Exploration (Alaska), Inc. Division of Natural Resources MMS Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Julie Heusser, ~'~- ~f~ DATE: Commissioner ~?~ Tom MaUnder, ~/~~SUBJECT: P. i. Supervisor"~0~ ~ ~ ~°X . John H SPaulding, Petroleum .I nspector Dec.23, 2000 Leak Off Test BPX I Northstar Well NS-10 .'.: "PTD 200-182 ' December'23, 2000.: I traveled'via BPX chartered helicopter from Deadhorse to 'North Star Island. I witnessed the Surface Casing Test as well as the Leak off. ' Test at. the surface casing shoe. .: .. ,. I arriVed on location with plentY.of time to"'spare as they were 'not even close to · being readY. At this time them.is no ice road and one must.rely on company .. ' chartered aircraft or"track vehicles,, these, .do not operate after 8 pm, unless there of course there is an emergency. .. .' ' ,, casing was tested to.2500 psi for 30 'minutes and held good: New 'form'ation'.was drilled until, n° cement contaminated material. Was noted 'on the shakers. The leak off test. went well and is attached fOr reference'.. ,,, .SUMMARY:. I Witnessed'the succesSful Casing and' leak off'test On BPX's- NOrthstar well .NS-10, a ClaSs '1 disposal well. ... .. .. Attachment: CaSing and leak.off spread sheets ,, Do Not Modlf7 Worksheet - Fill in oni~, the gray boxes · Use 'edit", "clear contents, or "del" to {:::ARIN(~ AND LEAK-OFF FRACTURE TER'TS Well Name: N'~-I0 Date: "{~/25/00 Supervisor: :Polya/Christiafl Oaslng Size and Description: 1___~3/4:', _45_.$_~_L_-Bp_ ...... Casing Setting Depth: Mud Weight; ' ':"'9",~:"~!ppg EMW e I.O = '~:.'!:7~(~i 0,052 x TVD I LOT = 13.7 (calculate from gray oell entries) Pump. ' ,.u. ,.owed RECEIVED TVD ': U 9 001 + Oil & Gas Cms. Hole Dep~ (~)= '~: . '~'Bbls . Pump ou~ut = ;,=[,..q';bps .. --e--LEAR-OFF DATA --I-- C,A~NG TEDT DATA 3500 1500' ,, I=.,., ..i .... , ... ', , ! ,l~",l, i,''t ' '41 I ',, ' I , , , ', },, ilt ,~ ".'".~l' :':~.' "" '. · ' ' ' ~" ',' · ~ : ,~. , ,~. ,.:, ., "'.' . . ·: =',. ., : i ', , · :' ' ' ,~, ,~ ' , . , ',l' · ~, ,i, : , ,. , : , · ' '~1'.' ', '~' ::i~l'., '. I,.'. , : '.. "'J'~ ..'"' . '.'.' ... :~ "~';,.. ;l~.;,,. ,., · :~ '.~[" ,.'. i,.. f:,' .... ';, . ;.. .,,,....., . " ".!'.:..':.."::....: . i, . . .... ,:' . [;', . . ' ..: ,.' .., " · I ' ,' ,., ~ i ,h ' : "; " · ,.. ,,. , .~,.,, . , . .., :' .; ; ::~. '., ' , ' /,'. ! ,' · ~l -" ,:.. :.? . ' i . . . .: · ' I ' ~',,'. , .. .,, ,1.,..'., , · ',:" . , .:~.'. ' I" ' ' ' "'".": "' : !.i~!::::'~,:: :: _ : ' , :,:-. ~: ?:'!'"; ,~:~::' .'. ..'" '~ ,' :!r~l., ."h.""' ",.'"." ...', ~.r'. ..... ' .. · .':ii. ~...' i' ~=..',~,~.'.'! ' ,. ' =F,':'..~,": ' ~:.. '.'.' '"';4.' =;.'" , ~: ,,t, · h:.;..." ,,~! '~'.~.1'..,,,'~ · , Il I,S i ,,' ~ :lei I' . ' l?:' ,,/,....' .1:,/ , .~::.:I1:'4 '.".' ' '~".'..I.'.t:..'','' ,~',!*: . .~i..~.r ..:". · x ....................... ~ ........................................ 0 10 20 30 dO 'Strokes (# oD --e-. LEAK-OFF DATA -I- CASING TEST DATA I ,. 0 · .10' 21) '30 .. 11me (MlnuleS). Paasword = drilling' ~:$~A P · (~(Z~ Only use spar.~s provlede. Do Not add or delete rows from the tables. If you have mom data than spaces LEAK-OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Here Enter Strokes Enter Pressure Here Here 1:. ,, Enter Holding Enter Holding Time Here Pre~$ure Here .... ,0'.,". '7,': ,'." 1020,: ' .",,o'.. . ," ' ...,',:2J;:;'..": ,' ].,,,'~,i:.:L.,.",,: 870' ',,. ,'i:".,; I~~ ?'% -- .'u, ~.. ,:., ~'.'.?~.i, ,-..~ --~--- -----. -.-.-- .... .*,'...'y'--' --..', .'~'""., -~.i','.' ' .'~, ~-'~,x-.:.-,. '["I' ~. ,>'i',' ~ '~"'~"'o',; · ' ~,, ? ' · · ,, 1 , ! · ~-,~___: --%. ',.. :'.'...'i ':::ii,:$.1,....."".. r;;::.'.' ~ .. ,;'.'1'.~,~i ......~<':'~ 'J '.' ' ~'". ' ~' ;1." "." ~.' '.' , ' ;~'~ .... ~ I: ,,, ~ ,,-- ~,,,,, , %:-',, ,~- , .,,' ,,, , ~ ?.% '..,'p.'... ,..~ ....,: ,~ .... ,. . .'" '.,".,.. ~I' .' ':"%:/:"' ? ~1 ,, '' ! 1 ..... ! . '' "" ' ' '-, '~" ,' ,1',.. ' ' ~"' ".","" .... "i". ' ~..L.'..':'.... , I ~' '.;.t ",':,!" ' I ~ ;.v' i-,..; ,, I. · ~' "'1 .' -.- °- - , - ,,i ,'.. ., Entor Holding Enter Holding Time Here Pressure Here !:i,'~, ", .: "'i'1'. .4. , :. ~L'I~,' '." · ' .' · ~ ' m ~ : .l :)'~.: .:".1 .. ~ ' , ,...,: ,~..~,. ~A~,I,,:: ' ~. ~ -, ,.~ . ~, .,,.; ,, .... ~v.. '!,' ,~, ~'" ', , .... *,', "~',' '"( r.' . . lO ............ ~,. 2480. 1,, .... .."." '-.I ":" !' ~ '.'.2':...r~.u.:.~;[ ;.', .,i: ~~.1:.i; ' "" ' ~' "~""' ':' ~' '," "' )AKh' .,,:., ...., ~',: :._,,.. .... , , ,' :.' 2450 ,.,,,: . ,, .d ~,,,, ,. ,. · ~ , '~ '~'. . :!i':li~:', i~.l ~' ~'~'.#*.'~ :,,. · ,,', ; ~',,t.~,[, ,..,I~,~,, ?,,h',%, ,1t ll,g", ' · '" ,! ., . .. ,.. ,. . ~..,.';.., .,'. --: .~,. "' · ,'",.,'." , ." '"',"' .". ~. ii;. ;' "' ... ~r . ,., ' ' m ' ~ ,....,.' ' . . - ., .' . , :" : '...... , ., , .. .,; .~.::':,.:.'..:' . :..,.: i~.~I ' . . ...:,, ,. i, .; .. ., · ,..' i,:':,. ': , , ' ! " ,'"N ~. , . .... ~,,, :.:,.... :' ,'.,..... :, ..:v.:i'.., ', '".;:"!/~i~,;::. i. '.. '~:. %.., ~', ',q4., , ' ' ,r. ~. ~,: ",7 .'" ~:' '~.':.~°'.;',?" .,'~ J..'... ," |P, ,~,'~.,' .... '.. ,', '" I., ~ :. ':. :':: , "1..i ,.. , ....,I, p' , .I..: .,...,. ,,~ .:. · : .. ,=: ,, :, ,:..,., .::..., .; ..:, ~..., :~,.: ..., ,.., :~. ":'.~:\: !' ~~ , .. , ' ~' ' - ' "/""~':"" n't use all data points. D , 0.9 2001 Well Name: i;i~ S!~:10 Date: Supervisor: !i~!~a / Christian Casing Size and Description: !!i~I:D-3/4', 45.5# L-80 Casing Setting Depth: ' 3726 TMD Mud Weight: ' 9.3. PPg EMW ~ LO = !LOT = !3.7 (calculate from gravy ce!! entries) 730 0.052 x TVD Fluid Pumped ~!':~/25/00 TVD + MW Hole Depth (md)= P,,-~p output = ..... ~;~,~! bps I+1 FAK-OFF DATA --~-C, ASING TFST DATA I 4000 '1 I' I I I I 35ooi ~ I I i I I ', ~uuu '1"7 ................................. ~ 7 ............... I I 2500 't ................ I I I 20001 ............... I I 1500 5OO Strokes (# I+LEAK-OFF DATA ~CASING TEST DATA I I ~5oo ~"' , ..... :":'. "E'."~':7;'''.'. "::;::?i: ::?. :.:..:";' :':;:.';: :::1T;i.;':'..": :; !~.::;':";:.. 1 I .... ~!:~,..:~::~?~;~;i?~:!:.;;~;~`:!~;;~&~::.:;~y~:;~::~::i:,~:*ii;¢~:?~!;~+~:!...~:?:!:;~p;?;:~::~;:~.:.::~ ~ooo I.. :.:,,";..':..,:...::..::.::"..:;I ?:;.': ':.',..i::,.,,. :.d:'~i?:.,::~:::,:?;::::.:~?J: ~?;.:: (?-'-;:,:::.:. . .i ~::::~.~.i~?/.;~.~!:,~,?~:~1:!:~¥~:~;;?~:~:;~;~!?;:~?~::?~:~.;~:~,;%~i,:~:;?;~:!.i~¥~:~.~,;.:~.:~ .'.1 · i.' '.: ', .: :.','..,.....,i.,,:.: '.' '... ~.., ..:., ...'; J..,.,,,,,: ...':,.,: ;: =...,.,, J...~; ;~:, =.., ....... .1 I" ;.'.; ':':;::"::.'J?," .' '"?..:; :~?" ..?':'""?fi' :!',:~.:.:.t: '.'". :':'.':."1 i .'""' I ....... 2000 I ': .... '.,:... :...,'L ...... ....: .... ';1':.;;~'.'.'.:.:.;'..:. ';.'~1'.'"'..'.' t I ]5oo I.." "."':L" I '.;.' .. '.:'::...' ',';.1 ' .".'":":.'"" ... ,.F :: ::' " .. , "'"".d;'"¥:'??' :,"...'.. I I: '. '.:'"" '";" ,'.:t,." :, ::'~':;:.,:.':; '. :",:' :. 'il..:. ",' ..,.: .?...?J,:'t,i;:i.;:..~;t< ;..':.~ ... :. ..I 11~:: .;'""?! "-- 'J" :,;' :.;'.." ::;; :..:i".::;~; ;1 ;.? ;;;.",: T:.'. :, .: ?l¢;;:;:?'.'t';?.:,. ;. I 000 I..:.;~J.:'.';."' :" I.' 500 I.' '.".~.f.,;." :..I I I .... '.'. I I' "' .... ..:':.'1'.. · ' ":.'",..;.q-'" "':;:';.,;'..'::..:::':.:t:¥':":'::"?"::'..I o I' .' '. :'.. ",,"']'"::"'"" ': "'" '" I.;' !'..' ,.'".'., :;: t:" .."' ?" '" .I 0 ! 0 20 30 40 Time (~i.ute$) Password: drillin8 JAN I 6 2001 Alaska (>il & Gas Cons. Commission Enter Strokes Enter Pressure Here Here · . '., "0 '".'' ~ "." O, ' ' .:'' .'~.¥:~: i"::.;.,:!:: :i:::80'......: Enter Ho, ding 'Enter Holdi,~g' Time Here Pressure Here i' .::..';:.,...;....O .'..,'..,..".: .i': ... ",,i0201=..: '. .... :'"i ;:".' "h":;~":.L: '~;' .r' '.'.'" ';.':'.' '..", i -"?:,~'Z!:F:;.~:':',L'~'' '/: ."-'.,.".: :" l:;.~...:'...,..;;:;::c.. ': ,.~i L!'. i~:!.:':.C::: ,:i.::::::;~!.'::':'::.',:.::~ :"::':; I" '::'"'.::::'"¥:~::"..~'~:". ::. :"i": ..'!; .::":': :i :: ~ :":':' :': !';! "7~:~:~i':".:' ~' "::' ".:l i:? ?. ':::!."?i::'.:':~./': ~ ? .:w::.? i ::'..?'~ ;: :.:?:::. :'~..,.:; ":' '": '""'":':i 1. ",-:: .:..:' ~: ~:.:..,~::.:,: :.:::::;::~,i. :".~!'.,';,'.:. l: '.!'::': ::>.:::::' ~'.=? :'i.!-.'...:::': :',!!-. ,' :' .:::..'::: :'8'?: :.:?':'~'.'1 1... !'.;/- :?'":6:"~::?.."~ ,..'~.:;i:'=? (?:i:i.7.~..?.:;i::. ~'..i':..' .'.':l i./..i,i.:,.;.; :.' !'.':,'8..~' :....-..:':i';i;~:.'.',..`. ?::..=.7~'...~:::': :::.'i' '1 I'";":"~.:/'{':"'.;.,'~"~.,=:' ;'.~"i" :" ....... .'7~o,'...::,,-; .'1 I.' ". 'm.: .." '- i.'. ,.z3o~'."."::.'.l Enter Strokes Enter Pressure Here Here I .;, · ..... · ........ ':'...'.;i'."";:",...'",': ..... ~'." ..:.":"I ~,,,e, Holding Enter .... d,,,~ Time Here Pressure Here I...... .',',. '.: t.~';,",' ; .......... .~ ........ .'~"~,': ".. "%,. ~ ;;' :" :;-; i':~'~':'"'.Y,..'~;L-;F t':T'.";'=.':' ' ~ ;'~'L';.':' '~,"' ' '~ , , .' :.%.,.,: ':,. ,,,',,~ ',~. ::;,', :%:.,. ,.',, ,.=~: ~ ,:;', :., :, .~: :: ~",' ': >..."~'.: :'.~':'...'.?~' ~.':.~.: :.'.'.:"~.'.'-:...: ~,'.~. :-z~.'~.'~" ~..:'..: .. ! ...... ' '"'"~'"'? ' '" L' .; 'D ;' ;' "";. "? '':'~ ':!'~ ': ~ ' "' "" "'L' .' ';'2' '~' :~ ,' ~.."~;" :' .'/';.. I? (:; ?:?'; ~:'; ~:~'.~:'./4~?~F~i' ~' :::~'?: ;: :'.""~:~';"::"~' ? ': ~ ..., ,,, ..,~ ~;:.::... ~ _:"' ':':? ;~':: ~'~5~ ":~':'::: ':'""'i:" .'"' ~' ~;?.';.::'??,'~,:' '! ~':~ :~;~. '. - ,;. ,, ,,. _,.'~ ..': .'~ ':,,.:y..'~.~,.,...:.;., , _ .......... , ..... ~i." '"" .... 2 .... " ~ ~?: '"~':::"':" ,,,...~,. ,,. ~.: ..... . :,.,,,. :~ ,.., ,,:.,~..,~ .. ,?' "~-::'~. :'," :.:':." .i' ?:.' .'.?'?/': ?': :l ,....,, .. :". .... ,,..,:.~ '~ ,.,; .. ........ '"".',,.'. : .:".. ., ..... :.: ,.'. ::'.'~': '::.~'i::. :::~..'. ". ..... '.,.',',.;. ':'..' .I ,,:~,~,..,....-..;., [" "'"':'::':':::':;'"~'~':.'""'"'::/' ~'i .... ' '/':~:' :. ,'":' ':: [ I~": ::':.:'.' .'....'.;:... : ;~.'.,.i..:" :.;': ::'. :.;': ':..'.'.:. ~1 I .... .. "':" .... ,:':':" ~ "'~"~.::'¥i''~' :"~.:" '"" .:.':~'":;.?' ~': :.'.'.;'.'-.'.' .:~.' ;':"'"""' ~':'.~' '"'"' ' ' ..... "'.:~..?:':"' I !'''~'''': ....... ¥--:-'"~'"-: ......... :-~.':-..:i:?"'--~ ..... :'"'-'.'~:'-' ...... ~": ··'1 , ""' "~":;.. "'" '.". L' .."'. .... '.:'~ ~': "~:." ~'. '. · . .... . I' .'~ ~':'" · ~'' ........ :'.'.:~:'.I;:'~':,".' · ..."'. '. .... .' I .: ~ .. ': , ;..; .,'""," '%': ,~"' ,, . ]~.,..., ...:.,. ::... ?.;.'.-~..'.:, ....-..~.:.:...~,...... ::.:'.:,.).~.';.: ...., RECEIVED I. I I I I I I I I I I I I I I I I I I I I I I I I I I I I I Alaska ~l & Gas Cons. Commission Anchorage bp f" By Facsimile December 18, 2000 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. Tim Hamlin Unit Manager, Groundwater Protection Unit U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Deviation of Surface logging Program UIC Area Permit AK-11002-A Northstar Development Project Dear Mr. Hamlin: The purpose of this letter is to document the conversation you had with BP Exploration (Alaska) Inc. (BPXA) drilling and environmental staff this morning concerning a deviation of the Northstar Class I well surface hole logging program. In Appendix F of the Northstar permit application, BPXA proposed to run the following open hole logs: DIL/GR/SP/Caliper. Due to a malfunction of the logging tool on site only the gamma ray (GR) log data has been obtained. The primary purpose of running surface hole logs at Northstar was to ensure that the surface casing shoe is set into the confining zone. The Northstar gamma ray log demonstrates that the casing shoe is set approximately 150 feet into the confining zone. For surface casing intended to protect underground sources of drinking water (USDW) a resistivity, spontaneous potential and caliper are required before the casing is installed (40 CFR 146.12 (d) (1) (i) (A). However, at Northstar, the Environmental Protection Agency has determined that there are no USDWs beneath the Northstar Unit. BPXA neglected to revise the open hole logging program in the surface hole or to state that it was optional in Appendix F when the EPA made the no USDW determination for Northstar. At this time any further delays to run additional suface logs may compromise the integrity of the Class I well. BPXA has demonstrated with the GR log that the casing shoe is set into the confining zone. Based on our discussions with yourself and Mr. Talib Sayed, the EPA contact inspector on site, BPXA will make no more attempts to collect the DlL/SP/Caliper data and will proceed with running casing. Mr. Tim Hamlin December 18, 2000 Page 2 Please call Ms. Alison Cooke at (907) 564-4838 or Mr. Floyd Hemandez at (907) 564- 5960 if you have any questions. Sincerely, George R. Snodgrass, Environme ger HSE Alaska GRS/ADC Mr. Tim Hamlin December 18, 2000 Page 3 cci Jonathan Williams, EPA Region Thor Cutler, EPA Region 10 Talib Sayed, EPA Consultanl_ Blair Wondzell, AOGCC /O~~ Pete McGee, ADEC R C Iv D An~. C°n~rrtission ALASILA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Northstar Unit NS 10 BP Exploration (Alaska) Inc. Permit No: 200-182 Sur Loc: 1139'FSL, 643'FEL, Sec. '11, TI3N, R13E, UM Btmhole Loc. 2323'FSL, 2250'FEL, Sec. 14, T13N,'R13E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the aboVe referenced well. The permit to drill does not exempt you.from obtaining additional permits required by law from Other governmental agencies, and does not authorize conducting drilling operations until all other required ' permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC.25.035; and the. mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.41'2 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below.the surface casing shoe, must be given so that a representative of thc COmmission may witness the tests. Notice may be given by contacting the Commission petroleum field insPector on the North Slope pager at 659-3607. Sincerely, J. M. Heusser' Commissioner BY O,RDER OF THE COMMISSION DATED this ~,~'~_-~" day of November, 2000 dlf/Enclosures cc: Department of Fish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '* .ALASK,~i .L AND GAS CONSERVATION COM..,' 31ON PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 55.77 Northstar Field / 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ~'/2-:7~'J~ ~, ADL 312808 4. Location of well at surface 7. Unit 6~'~'roperty Name 11. Type Bond (See 20 AAC 25.025) 1139' FSL, 643' FEL, Sec. 11, T13N, R13E, UM Northstar Unit At top of productive interval 8. Well Number 4125' FSL, 1518' FEL, Sec 14, T13N, R13E, UM NS10 Number 2S100302630-277 At total depth 9. Approximate spud date 2323' FSL, 2250' FEL, Sec 14, T13N, R13E, UM 12/01/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) ADL 312799, 981' MDI No Close Approach 3432.92 8301' MD / 6556' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 800' MD Maximum Hole Angle 49.9 ° Maximum surface 2275 psig, At total depth (TVD) 6500' / 2925 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casin_a Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 20" 169# X-56 Welded 159' Surface Surface 199' 199' None 13-1/2" 10-3/4" 45.5# L-80 BTC 3717' 40' 40' 3757' 3205' 1646 sx PF 'E', 347 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 8039' 40' 40' 8079' 6356' 704 sx 'G', 260 ex Silicalite 'G', 336 sx PF 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ProductionRECEIVED Liner ! 3V 0 7 Perforation depth: measured NI~ 0il & ~S C0flS. Collr~issioll true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time ve Depth Plot [] Refraction Analysis [] Seabed Report [] 20 A^C 25.050 Requirements Contact Engineer Name/Number'. Andy Kfleger, 564-5390 Prepared By Name/Numbec Sondra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd Hemande~;:)'~ [.~.,. ~ Title Senior Drilling Engineer Date ///5/0 0 , ~ I I ~ ! , ' ! ' [" ' ' I ~ll~ Permit Number APl Number Approval D~3te See cover letter ~-/~,~- 50- O~-- ,2..2.-~"~''- ~ l/"t'~/~-'~0 for other requirements Conditions of Approval: Samples Required l~ Yes [] No Mud Log'Required I~'Yes [] No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required J~'Yes [] No Required Working Pressure for DOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~3.5K psi ~ Other: ~,\'~'"~C~.~w~(z~,.-~(~.,.3~\','~"-t~o~, ', by order of Approved By ORIGINAL SIGNED BY Commissioner the commission Date /~-'~-.~--.~ ~ Form10-401 Rev. 12-01-85 '"' IGINAL SubmitlnTriplicate NS10 Permit to Drill I Well Name: INS10 ,, -CEIVED ~' ~'~,' 0 7 £009 Drill and Complete Plan Summe C s. Type of Well (producer or injector): I Class I Waste Disposal Surface Location: X = 659,833 / Y = 6,030,912 1139' FSL 643' FEL Sll T13N R13E Umiat Target Location: X = 659,009 / Y = 6,028,600 4125' FSL 1518' FEL S14 T13N R13E Umiat Bottom Hole Location: X = 658,317 / Y = 6,026,783 2323' FSL 2250' FEL S14 T13N R13E Umiat I AFE Number: 1831301 I Estimated Start Date: I 12/1/00 I I MD= 18,30~' I I~VD= 1~55S' I I Well Design (conventional, slimhole, etc.): I Rig: I Nabors 33E Operating days to complete: I 32 I Cl~/MSL 115.57' I I RKB: 155.77' I Slimhole IObjective: Serve as the Class I Waste Disposal Well for Northstar. The well will initially serve as the injector for cuttings, Class I Waste, and produced water. Mud Program: Surface Hole Mud Properties: Inhibited KCl 13-1/2" Hole Section From Surface to -3756' MD / 3206' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tau0 Gel APl FL pH (ppg) (seconds) 10 sec Initial 8.8 - 9.0 200 - 300 45 - 70 > 9 25 - 40 15 - 20 8.5 - 9.5 from -1800' *9.0 - 9.5 100 - 200 30 - 45 > 7 15 - 25 4 - 10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 - 100 20 - 35 > 7 10 - 25 4 - 10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Inhibited KCl 9-7/8" Hole Section From Surface Casing Shoe to 8079' MD / 6356' TVD (-top Schrader Bluff). Interval Density (ppg) PV YP Taus APl FL pH Initial 9.0 - 9.2 10 - 25 20 - 28 4 - 7 6 - 10 8.5 - 9.5 Final < 9.5 10 - 25 20 - 25 4 - 7 4 - 6 8.5 - 9.5 Injection Hole Mud Properties: Inhibited KCl 6-3/4" Hole Section From Casing Shoe to 8301' MD / 6556' TVD Interval Density (ppg) PV YP Tau0 APl FL pH Initial < 9.5 10 - 25 20 - 28 4 - 7 4 - 6 8.5 - 9.5 Final < 9.5 10 - 25 20 - 25 4 - 7 4 - 6 8.5 - 9.5 NSIO Permit to Drill Directional:(wP6) KOP: I 800' MD Maximum Hole Angle: Close Approach Well: Survey Program: RECEIVED :' :,'....' 0 7 £003 Alaska 0il & Gas Cms. Surface - 49.9° In Tangent Interval 2686' to 3757' Mil~.ol'_age Intermediate - 49.9° In Tangent Interval 3757' to 6210' MD Injection - 25.8° In Tangent Interval 8079' to 8301' MD No close approach issues exist for NS10. Standard MWD Surveys from surface to TD. No gyros will be needed for surface kick-off. Logging Program: Surface Hole Section Intermediate Hole Section Injection Hole Section Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Drilling: Open Hole: MWD ! GR Mud Logging: Gas analysis/detection, show kit with indexed bottles, lithology samples GR/Res/SPICaliper (TD to 500' MD) USIT bond log from 10 3~,, shoe to 500' MD MWD / GR Mud Logging: Gas analysis/detection, show kit with indexed bottles, lithology samples. GR/Res/Den/Neu/Sonic USIT bond log from 7 5/8" shoe to 10 3~" shoe MWD / GR Mud Logging: Gas analysis/detection, show kit with indexed bottles, lithology samples. None Formation Markers: Formation Tops MD TVDss Comments Top Permafrost 1206' 1150' Base Permafrost 1562' 1500' SV8 2841' 2560' Est. pore pressure 1152 psi (8.65 ppg EMW) SV7 3074' 2710' Est. pore pressure 1219 psi (8.65 ppg EMW) SV6 3539' 3010' Est. pore pressure 1354 psi (8.65 ppg EMW) SV5 3990' 3300' Est. pore pressure 1485 psi (8.65 ppg EMW) SV4 4393' 3560' Est. pore pressure 1602 psi (8.65 ppg EMW) SV3 4828' 3840' Est. pore pressure 1728 psi (8.65 ppg EMW) SV2 5076' 4000' Est. pore pressure 1800 psi (8.65 ppg EMW) SV1 5651' 4370' Est. pore pressure 1966 psi (8.65 ppg EMW) Top Ugnu TMBK 6241' 4750' Est. pore pressure 2137 psi (8.65 ppg EMW) UG3 6844' 5200' Est. pore pressure 2340 psi (8.65 ppg EMW) UG1 7468' 5750' Est. pore pressure 2588 psi (8.65 ppg EMW) Top Schrader Bluff 8079' 6300' Est. pore pressure 2835 psi (8.65 ppg EMW) Proposed TD 8301' 6500' Est. pore pressure 2925 psi (8.65 ppg EMW) Casinq/Tubinq Proqram: Hole Size Csgl Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD Driven 20" 169# X-56 Weld 159' Surface 199'/199' 13-1/2" 10-3/4" 45.5# L-80 BTC 3717' -40'/40' 3757'/3205' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 8039' -40'/40' 8079'/6356' 6-3/4" Open Hole 222' 8079'/6356' 8301 '/6556' Tubing 4-1/2" 12.6# L-80 IBT-Mod 8041' -38'/38' 8079'/6356' NS10 Permit to Drill RECEIVED ".'.,':' 0 7 2000 Cement Calculations: The following cement calculations are based upon a two stage job using a stage tool. Nlch0rage Casin9 I 10-314" Surface Basis: Stage 1: Lead: Based on 1407' of 13 1~,, open hole x 10 3~,, csg. with 30% excess. Lead TOC: -1600' Tail: Based on 750' of 13 ~" open hole x 10 3~,, csg. with 30% excess + 80' shoe joint. Tail TOC: At -3007' MD {2723' TVD) Stage 2: Lead: Based on 1600' of 13 ½" open hole x 10-3/4" csg. with 250% excess + csg capacity. Lead TOC: Surface Stage I Total Cement ! Spacer Stage 2: Total Cement I Spacer Preflush Spacer Lead Tail Preflush Spacer Lead 10 bbl sea water 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 119 bbl / 308 sk of 12.0 ppg Type 'E' Permafrost Cement. 2.17 cf/sk, BHST 60° / BHCT 55°, TT = 6.0 hrs 71 bbl / 347 sk of 15.8 ppg Premium 'G'. 1.15 cf/sk, BHST 60° / BHCT 55°, TT = 3.0 hrs None 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 517 bbl* / 1338 sk of 12.0 ppg Type 'E' Permafrost Cement 2.17 cf/sk, BHST 60° / BHCT 55°, TT = 6.0 hrs * 2 gal Red dye in 1st 5 bbls The following cement calculations are based upon a three stage job using a stage tool and a port collar. Casin9 ~7-5/8" Intermediate I Basis: IStage 1: Stage 1: Lead: Based on 1979' of 9 7/8" open hole x 7 5/8" csg with 30% excess + 80' shoe joint. Lead TOC: At -6100' MD (4715' TVD) Stage 2: Lead: Based on 1900' of 9 7/8" open hole x 7 5/8" csg with 30% excess Lead TOC: At -3800' MD (2334' TVD) Tail: Based on 400' of 9 7/8" open hole x 7 5/8" csg with 30% excess Tail TOC: At -5700' MD (4457' TVD) Stage 3: Lead: Based on 3257' of 7 5/8" x 10 3A" csg Lead TOC: Surface Tail: Based on 44' of 9 7/8" open hole Tail TOC: At -3257' MD (2883' TVD) Total Cement / Spacer Preflush Spacer Lead IStage 2: Total Cement / Spacer ISta~le 3: Total Cement / Spacer Preflush Spacer Lead Tail Preflush Spacer Lead Tail x 7 5/8" csg with 30% excess + 500' of 7 5/8" x 10 ~" csg 10 bbls sea water 50 bbl Alpha Spacer weighted to 1.0 ppg over mud MW 102 bbl / 498 sk of 15.8 ppg Premium 'G'. 1.15 cf/sk, BHST 130° / BHCT 105°, TT = 3.0 hrs None 50 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 95 bbl/260 sk of 13.1 ppg Silicalite Premium 'G' 2.05 cf/sk, BHST 95° / BHCT 85°, TT = 3.0 hrs 20 bbl/98 sk of 15.8 ppg Premium 'G'. 1.15 cf/sk, BHST 95° / BHCT 85°, TT = 3.0 hrs None 50 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 30 bbl / 336 sk of 12.0 ppg Permafrost 'E' !.17 cf/sk, BHST 60° / BHCT 55°, TT = 6.0 hrs 22 bbl/108 sk of 15.8 ppg Premium 'G' 1.15 cf/sk, BHST 60° / BHCT 55°, TT = 3.0 hrs NS10 Permit to Drill Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi. Diverter, BOPE, and drilling fluid system schematics attached. Intermediate/Production Section- ~, ~ffF-'~l~ ~ · Maximum anticipated BHP: 2835 psi @ 6300' TVDss - Schrader Bluff · Maximum surface pressure: 2205 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) _ · Maximum anticipated BHP: 2925 psi @ 6500' TVDss- Schrader Bluff · Maximum surface pressure: 2275 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 3500 psi 9.8 ppg NaCI / 6.8 ppg Diesel Drilling Hazards/Contingencies: RECEIVED HYDROGEN SULFIDE - H2S Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A-03 exploration/appraisal wells. Reference: 1) Northstar/Nabors 33E H2S contingency plan. 2) Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. DRILLING CLOSE APPROACH: · No close approach issues exist for this well. SURFACE HOLE SECTION: · No significant drilling problems have been identified in the surface hole interval (0-3500' TVD) based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. · Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. · Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals. · Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. · Hole stabilization in the shallow unconsolidated intervals can be problematic if mud properties are relaxed. Hi viscosities as used elsewhere on the North Slope should be sufficient to control any potential running gravels. · Gas hydrates may. be present near the base of the permafrost. Mudloggers will be used continuously on NS10 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. NSIO Permit to Drill INTERMEDIATE/INJECTION SECTION: · Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. Mudloggers will be used continuously on NS10 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted shallow gas to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. · The shallow intervals beneath Northstar are not interpreted to be faulted. Seismic discontinuities from 2900' TVD to 6300' TVD are interpreted to be the artifact of rapid velocity changes and the probability of faults existing is Iow. If faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. · Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. · The kick tolerance for the 9-7/8" open hole section would be 69 bbls assuming an influx from the Schrader Bluff interval at -8079' MD. This is a worst case scenario based on a 9.15 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 10-3/4" shoe, and 9.5 ppg mud in the hole. Disposal: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be temporarily stored at Northstar. During ice road access, the stored cuttings will be hauled to grind and inject at DS-04 and/or disposed of in the Northstar Class I Waste Disposal Well after the well has been commissioned. Fluid Handling: Any drilling and completion fluids or other Class II wastes will be stored at Northstar and allowed to freeze. This material will be recovered and hauled to DS-04 for injection during ice road access and/or disposed of in the Northstar Class I Waste Disposal Well after the well has been commissioned Any non-hazardous Class I waste generated .will be stored at Northstar and disposed of in th~ Northstar Class I Waste Disposal Well upon commissioning or taken to Pad 3 during ice road access. RECEIVED Alaska Oil & Gas Cons. Comm ion Anchorage NS10 Permit to Drill SUMMARY DRILLING OPERATIONS Pre-Riq Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. 2. Install 7' x 7' cellar. 3. Rig up and commission Nabors 33E and service module. Ri~ Ooerations: 1. Nipple up and function test 21-1/4" diverter system. PU 5" DP as required and stand back in derrick. 2. MU 13-1/2" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3757' MD / 3205' TVD. The actual surface hole TD will be +/-150' TVD below the top of the SV6 marker. 3. RU Schlumberger E-line unit and run open hole logs (GR/Res/SP/Caliper) from TD to 500' MD. Use caliper results to confirm surface cement volumes. 4. Run and cement the 10-3/4", 45.5# surface casing to surface in 2 stages using a stage tool at +/- 1600' MD. 5. ND diverter system and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 9-7/8" cleanout assembly and RIH to stage tool closing plug. Drill plug and RIH to float collar. Clean out cement to 10' above the casing shoe. Test the 10-3/4" casing to 500 psi. 7. POOH with 9-7/8" cleanout assembly for cement bond log. 8. RU Schlumberger E-line unit and run USIT bond log from TD to 500'. 9. MU 9-7/8" drilling assembly with MWD/GR and RIH. 10. Tag cement and test the 10-3/4" surface casing to 2500 psi for 30 minutes. 11. Drill out remaining 10' of 10-3/4" shoe joint. Drill 20' of new formation below 10-3/4" shoe and perform Leak Off Test. (FIT/LOT procedure attached) 12. Drill 9-7/8" intermediate interval to 7-5/8" casing point at approximately 8079' MD / 6356' TVD. (Top Schrader Bluff) 13. RU Schlumberger E-line unit and run open logs (GR/Res/Den/Neu/Sonic). POOH and RD Schlumberger. 14. Run and cement the 7-5/8", 29.7# intermediate casing to surface in 3 stages using a stage tool at +/- 6100' and a port collar at +/- 3800'. 15. MU 6-3/4" cleanout assembly and RIH to stage tool closing plug. Drill plug and RIH to float collar. Clean out cement to 10' above the casing shoe. Test the 7-5/8" casing to 500 psi. 16. RU Schlumberger E-line unit and run USIT bond log from TD to 500' MD above the 10-3/4" surface shoe while holding 500 psi on the well. 17. MU 6-3/4" drilling assembly with MWD/GR and RIH. 18. Tag cement and test the 7-5/8" casing to 3500 psi for 30 min. 19. Drill out remaining 10' of 7-5/8" shoe joint. Drill 20' of new formation below 7-5/8" shoe and perform Leak Off Test. (FIT/LOT procedure attached) 20. Drill 6-3/4" injection interval to TD at approximately 8301' MD / 6556' TVD. 21. POOH and PU casing scraper on 6-3/4" cleanout assembly. 22. RIH and displace well to 9.8 ppg NaCl brine. POOH. 23. Run the 4-1/2", 12.6#, L-80 IBT-Mod completion assembly with heat trace to +/- 2250'. 24. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 25. Freeze protect the well to -2000' with diesel. 26. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 27. Rig down and move off. RECEIVED Ala~ Oil & Gss Cons. Commis~n Anchorage NSIO Permit to Drill Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC profile from 'X' nipple below the new production packer. 2. Conduct tracer injection logging program and step rate injection test per EPA requirements. Estimated Spud Date: 12/1/00 Andy Krieger Operations Drilling Engineer 564-5390 RECEIVED !',:'~)\,," C)7 ~v3 Aladm 0il & Gas Cons. ~ornmi~on Anchorage NS10 Permit to Drill NS10 Ri site Summary of Drillin.q Hazards POST THIS NOTICE IN THE DOGHOUSE Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS10 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. Mudloggers will be used continuously on NS10 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted shallow gas to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. The shallow intervals beneath Northstar are not interpreted to be faulted. Seismic discontinuities from 2900' TVD to 6300' TVD are interpreted to be the artifact of rapid velocity changes and the probability of faults existing is Iow. If faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. Northstar is not a designated H2S pad. CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION RECEIVED ~a,aka Oil & Gas Cats. Commission ared rvices rilling NS10 Proposed Well Profile - Geodetic Report Report Date: October 11, 2000 Client: BPXA Field: Northstar ~'lruoturu I Slot: Northstar PF I NS10 Well: NS10 Berehole: NS10 UWilAPI#: 50-029- Survey Name I Date: NS10 (P6) I October 11, 2000 Tort I AHD I DDI I ERD ratio:74.118° 14399.63 ff 15.616 / 0.671 Grid Ccerdinate System: NAD27 Alaska State Planes, Zone 04, US Feel Locetion L~Long: N 70 29 27.584, W 148 41 35.82~ Locellen Grid N/E WX: N 6030911.600 ftUS, E 659632.880 ftU~ Grid Convergence Angle: +1.23171925° Gild 8cele Faefor: 0.99992902 Gurvey I DL$ Computation Mothod:Minimum Curvature I Lubinski Vertical Seotion Azimuth:201.390° Vet'tled Seefion Origin: N 0.000 ft, E 0.000 fl TVD Reference Datum: KB TVD Reference Elevation:55.77 tt relative to MSL Magnetlo Declination: 26.931 ° Total Field Strength: 57487.251 nT Magnetio Dip: 80.906° Da~llnation Date: December 05, 2000 Magnotio Declination ModeI:BGGM 2000 North Roterunce: True North Total Corr Mag North ..> True North~26.931 ° Locel Coordinates Referenced To.'WeJl Head Sclllumberger Grid Coordinates Geo~lraphlc Coordinates I Station ID i MD I ,=, I =m I TVD I ,. I N/.S I E .W I DLS Northlng JEaating I.atltudeI Longitude (ft) (0) (0) (fi) (f9 (f9 ~} (0/t0~} (ftus} (ftus) KB 0.00 0.00 202.00 0.00 0.00 0.00 0.00 0.00 6030911.60 659832.88 N 70 29 27.584 W 148 41 35.825 KOP Build 1/100 800.00 0.00 202.00 800.00 0.00 0.00 0.00 0.00 6030911.60 659832.88 N 70 29 27.584 W 148 41 35.825 900.00 1.00 202.00 899.99 0.87 -0.81 -0.33 1.00 6030910.78 659832.57 N 70 29 27.576 W 148 41 35.835 1000.00 2.00 202.00 999.96 3.49 -3.24 -1.31 1.00 6030908.33 659831.64 N 70 29 27.552 W 148 41 35.864 Build 2/100 1050.00 2.50 202.00 1049.92 5.45 -5.06 -2.04 1.00 6030906.50 659830.95 N 70 29 27.534 W 148 41 35.885 Top Permafrost Build 2.5/100 1100.00 3.50 202.00 1099.85 8.07 -7.48 -3.02 2.00 6030904.06 659830.02 N 70 29 27.510 W 148 41 35.914 1200.00 5.50 202.00 1199.54 15.91 -14.76 -5.96 2.00 6030896.72 659827.24 N 70 29 27.439 W 148 41 36.001 1206.26 5.63 202.00 1205.77 16.52 -15.32 -6.19 2.00 6030896.15 659827.02 N 70 29 27.433 W 148 41 36.008 1300.00 7.50 202.00 1298.89 27.23 -25.25 -10.20 2.00 6030886.14 659823.23 N 70 29 27.336 W 148 41 36.126 1400.00 10.00 202.00 1397.72 42.44 -39.36 -15.90 2.50 6030871.91 659817.83 N 70 29 27.197 W 148 41 36.293 Build 3/t00 Base Permafrost 1500.00 12.50 202.00 1495.79 61.95 -57.44 -23.21 2.50 6030853.68 659810.91 N 70 29 27.019 W 148 41 36.508 1540.00 t3.50 202.00 t534.76 70.95 -65.79 -26.58 2.50 6030845.26 659807.72 N 70 29 26.937 W 148 41 36.608 1561.63 14.15 202,00 1555,77 76,12 -70.58 -28.52 3.00 6030840,43 659805,89 N 70 29 26.890 W 148 41 36,665 1600.00 15.30 202.00 1592,88 85.87 -79.62 -32.17 3.00 6030831,31 659802,43 N 70 29 26.801 W 148 41 36.772 1700.00 18.30 202.00 1688,60 114.77 -106.42 -42,99 3.00 6030804.29 659792.19 N 70 29 26.537 W 148 41 37.090 WD-01 (P6) report.xls Page 1 of 3 10/11/00-11:43 AM Grid Coordinate. Geographlo Coordinates I ~tatlonlD I "' I '"' I I""1 ""' I "wl°''(,,, ,°) (°) ,,,) (.) (., (°,,-.) "°""'"° I "'""(.-) (.-, "'"""° I 1800.00 21.30 202.00 1782.67 148.63 -137.82 -55.68 3.00 6030772.63 659780.18 N 70 29 26.229 W 148 41 37.464 End Build 1840.00 22.50 202.00 1819.79 163.55 -151.65 -61.27 3.00 6030758.68 659774.89 N 70 29 26.093 W 148 41 37.628 Build 4/00 2001.04 22.50 202.00 1968.57 225.18 -208.79 -84.36 0.00 6030701.06 659753.03 N 70 29 25.531 W 148 41 38.308 2100.00 26.46 201.66 2058.62 266.17 -246.85 -99.59 4.00 6030662.68 659738.63 N 70 29 25.156 W 148 41 38.756 2200.00 30.45 201.39 2146.52 313.81 -291.17 -117.06 4.00 6030618.00 659722.11 N 70 29 24.720 W 148 41 39.270 End Build 2300.00 34.45 201.18 2230.88 367.46 -341.16 -136.53 4.00 6030567.61 659703.72 N 70 2924.229 W 148 41 39.843 2400.00 38.45 201.02 2311.30 426.86 -396.58 -157.92 4.00 6030511.75 659683.53 N 70 29 23.684 W 148 41 40.472 2500.00 42.45 200.87 2387.38 491.72 -457.16 -181.10 4.00 6030450.69 659661.66 N 70 29 23.088 W 148 41 41.154 2600.00 46.45 200.75 2458.76 561.73 -522.61 -205.98 4.00 6030384.72 659638.20 N 70 29 22.444 W 148 41 41.886 2686.31 49.90 200.66 2516.30 626.03 -582.76 -228.71 4.00 6030324.10 659616.77 N 70 29 21.853 W 148 41 42.555 SV8 SV7 Siesmic Discon. SV6 (Top Conf. Zone) 10-3/4" Csg Pt 2840.73 49.90 200.66 2615.77 744.15 -693.29 -270.39 0.00 6030212.71 659577.47 N 70 29 20.766 W 148 41 43.781 3073.61 49.90 200.66 2765.77 922.27 -859.97 -333.24 0.00 6030044.73 659518.23 N 70 29 19.126 W 148 41 45.630 3368.59 49.90 200.66 2955.77 1147.89 -1071.09 -412.85 0.00 6029831.96 659443.18 N 70 29 17.050 W 148 41 47.972 3539.37 49.90 200.66 3065.77 1278.51 -1193.33 -458.94 0.00 6029708.77 659399.73 N 70 29 15.848 W 148 41 49.328 3756.72 49.90 200.66 3205.77 1444.76 -1348.89 -517.60 0.00 6029551.99 659344.43 N 70 29 14.318 W 148 41 51.054 SV5 (Base Conf. Zone) SV4 (Seismic Discon.) SV3 SV2 (Target) 3989.60 49.90 200.66 3355.77 1622.88 -1515.57 -580.45 0.00 6029384.01 659285.18 N 70 29 12.679 W 148 41 52.903 4393.25 49.90 200.66 3615.77 1931.62 -1804.49 -689.39 0.00 6029092.84 659182.49 N 70 29 9.837 W 148 41 56.107 4827.96 49.90 200.66 3895.77 2264.12 -2115.62 -806.71 0.00 6028779.28 659071.89 N 70 29 6.777 W 148 41 59.558 5076.36 49.90 200.66 4055.77 2454.11 -2293.41 -873.75 0.00 6028600.11 659008.69 N 70 29 5.028 W 148 42 1.529 5153.99 49.90 200.66 4105.77 2513.49 -2348.97 -894.70 0.00 6028544.11 658988.94 N 70 29 4.482 W 148 42 2.145 5200.00 49.90 200.66 4135.41 2548.68 -2381.90 -907.12 0.00 6028510.93 658977.23 N 70 29 4.158 W 148 42 2.510 5300.00 49.90 200.66 4199.82 2625.16 -2453.48 -934.11 0.00 6028438.79 658951.79 N 70 29 3.454 W 148 42 3.304 5400.00 49.90 200.66 4264.23 2701.65 -2525.05 -961.10 0.00 6028366.66 658926.35 N 70 29 2.750 W 148 42 4.098 5500.00 49.90 200.66 4328.64 2778.14 -2596.63 -988.08 0.00 6028294.52 658900.91 N 70 29 2.046 W 148 42 4.891 5600.00 49.90 200.66 4393.05 2854.62 -2668.20 -1015.07 0.00 6028222.39 658875.47 N 70 29 1.342 W 148 42 5.685 SV1 5650.80 49.90 200.66 4425.77 2893.48 -2704.56 -1028.78 0.00 6028185.75 658862.55 N 70 29 0.985 W 148 42 6.088 5700.00 49.90 200.66 4457.46 2931.11 -2739.77 -1042.06 0.00 6028150.26 658850.03 N 70 29 0.638 W 148 42 6.479 5800.00 49.90 200.66 4521.87 3007.60 -2811.35 -1069.05 0.00 6028078.13 658824.58 N 70 28 59.934 W 148 42 7.272 5900.00 49.90 200.66 4586.28 3064.08 -2882.92 -1096.04 0.00 6028006.00 658799.14 N 70 28 59.230 W 148 42 8.066 6000.00 49.90 200.66 4650.70 3160.57 -2954.49 -1123.03 0.00 6027933.87 658773.70 N 70 28 58.527 W 148 42 8.859 Drop 2.5/100 Top UGNU TMBK 6100.00 49.90 200.66 4715. t 1 3237.06 -3026.O7 -1150.O2 0.00 6027861.73 658748.25 N 70 28 57.823 W 148 42 9.653 6200.00 49.90 200.66 4779.52 3313.54 -3097.64 -1177.00 0.00 6027789.60 658722.82 N 70 28 57.119 W 148 42 10.446 6209.70 49.90 200.66 4785.77 3320.97 -3104.58 -1179.65 0.00 6027782.61 658720.32 N 70 28 57.050 W 148 42 10.524 6240.51 49.13 200.74 4805.77 3344.40 -3126.50 -1187.93 2.50 6027760.52 658712.51 N 70 28 56.835 W 148 42 10.768 WD-01 (P6) mport.xls RECEIVED Alaska0il&Gas Coas. Page 2 of 3 10/11/00-11:43 AM Grid Coordinates Geo~ral)hlo Coordinates I Station ID I MD I In~l I Azim I TVD I VSo~ [ N/'S I E/'W IDLs(~) (0) (o) Ut) Irt) , ~) (°/lOOft}N°rthlng I Eaating (ftU6} (flUS, Lat.udeI Longitude 6300.00 47.65 200.88 4845.27 3388.87 -3168.07 -1203.73 2.50 6027718.62 658697.61 N 70 28 56.426 W 148 42 11.232 6400.00 45.16 201.14 4914.22 3461.29 -3235.67 -1229.70 2.50 6027650.48 658673.10 N 70 28 55.761 W 148 42 11.996 6500.00 42.66 201.43 4986.26 3530.63 -3300.29 -1254.87 2.50 6027585.34 658649.33 N 70 28 55.126 W 148 42 12.736 6600.00 40.17 201.74 5061.25 3596.78 -3361.80 -1279.20 2.50 6027523.33 658626.33 N 70 28 54.521 W 148 42 13.451 6700.00 37.68 202.09 5139.03 3659.61 -3420.09 -1302.65 2.50 6027464.55 658604.14 N 70 28 53.947 W 148 42 14.141 6800.00 35.19 202.48 5219.48 3718.99 -3475.05 -1325.16 2.50 6027409.12 658582.82 N 70 28 53.407 W 148 42 14.802 UGNU 3 6844.11 34.10 202.67 5255.77 3744.07 -3498.21 -1334.79 2.50 6027385.76 658573.69 N 70 28 53.179 W 148 42 15.085 6900.00 32.71 202.92 5302.42 3774.82 -3526.57 -1346.70 2.50 6027357.16 658562.39 N 70 28 52.900 W 148 42 15.436 7000.00 30.22 203.42 5387.72 3826.98 -3574.55 -1367.23 2.50 6027308.75 658542.90 N 70 28 52.428 W 148 42 16.039 7100.00 27.74 204.01 5475.19 3875.39 -3618.91 -1386.70 2.50 6027263.98 658524.39 N 7028 51.992 W 14842 16.612 End Drop 7177.86 25.80 204.53 5544.70 3910.41 -3650.88 -1401.11 2.50 6027231.71 658510.67 N 70 28 51.677 W 148 42 17.035 UGNU 1 7467.84 25.80 204.53 5805.77 4036.44 -3765.71 -1453.52 0.00 6027115.79 658460.74 N 70 28 50.548 W 148 42 18.576 7-5~8" Csg Pt 8078.75 25.80 204.53 6355.77 4301.96 -4007.62 -1563.93 0.00 6026871.58 658355.57 N 70 28 48.169 W 148 42 21.822 Top Schrader Bluff 8078.75 25.80 204.53 6355.77 4301.96 -4007.62 -1563.93 0.00 6026871.58 658355.57 N 70 28 48.169 W 148 42 21.822 8223.15 25.80 204.53 6485.77 4364.72 -4064.80 -1590.02 0.00 6026813.86 658330.71 N 70 28 47.606 W 148 42 22.589 TD 8300.90 25.80 204.53 6555.77 4398.51 -4095.59 -1604.08 0.00 6026782.78 658317.32 N 70 28 47.303 W 148 42 23.002 Legal Description: Surface: 1139 FSL 643 FEL Sll T13N R13E UM SV2 (Target): 4125 FSL 1518 FEL S14 T13N R13E UM BHL: 2323 FSL 2250 FEL S14 T13N R13E UM No~hina(Y)[ffUS1 Eastino(X)rffus1 6030911.60 659832.88 6028600.10 659008.69 6026782.78 658317.32 WD-01 (P6) mport, xls Page 3 of 3 10111100-11:43 AM ~ ~hared trices 1000 2000 u ~ 3000 8 '~ 4000 I-- 5000 6000 7000 VERTICAL SECTION VIEW ChLen~: BPXA Well: NS10 (P6) Field: NorthsEar Structure; Nerthstar PP Secg~on At: 201.39 deg Date; Ocgober ii~ 2000 2250~ 20200~az 164deaart~re :'i4~90~ 2006~az 1445dep&~tum '* ;Sn~ UGNU ~ 7a ~,4D ~4}(}a IV~ ~ 8079 MD 6356 TVD 258&~ 204 53~ ~ 4302 de~dure 0 1000 2000 3000 4000 Vertical Section Departure at 201.39 deg from (0.0, 0.0). (1 in = 1000 feet) ~ ~]nargd Fvlces ,~i~,~, ~rilling Alaska ~ -1000- Well : NSi0 (P6) Field: Northstar Struc '~re: NoFthsh ar PF Scale: i i;l = !000 ft Date: ii -Oct 200O -4000 -3000 -2000 -1000 1000 .......... [~[ I .............. L o- 11 rY -2000- 0 z -3000- V -4000- V V -5000- -6000- WD.01 6500ss Wd01 4000ss Ddlkcr's TGT 100'r 6500ss TO 830! MD 6556 TVO 2580' 20453' az 4096 S 1604 W 3~05S ~iS0W 0 1000 '1000 '0 --3000 --4000 --5000 --6000 -4000 -3000 -2000 -1000 0 1000 <<< WEST EAST >>> TREE.'ABB-VG, 5 1,8" 5k,, .( NS10 ('" ',G,NA, KB. E,EV = 55.77' WELLHEAD:ABB-VGI 11" .~. ELEV = 40.2' 20", 169#X-56 @ 199' MD ' I ~j - -- --'X' Nipple (~ 2000' MD 3.813" ID i I ~ - -- ~ Heat Trace ~ 2250'MD 10 3/4", 45.5#1ff, L-80, BTC @3757' MD 4.5", 12.6#/ft, L-80, TUBING ID: 3.958" CAPACITY: 0.015 BBL/FT ~ ~ Baker S3 PACKER -- 3.875"1D ~5026' MD 4.5" 'XN' NIPPLE, ~ 8058' 3.813" ID (OTIS) ~ I I 4.5" WLEG, (~8079' MD 7 5/8", 29.7#/ff L-80, BTC-M @8079'MD ~ 6 3/4" open hole TD 1~8301' MD DATE REV. BY COMMENTS Northstar 10/18/00 Krieger Initial Diagram ~.~_NSl 0 APl NO: BP Exploration (Alaska) c~ Frac Gradients Seal-A-01 Seal-A-0~2 OH Seal-A-02 RD Seal-A-03 Seal-A-04 North Star 1 Northstar 2 Res Prs from Mud Wgt · Seal-A-01 Seal-A-02 OH Seal-A-02 RD · Seal-A-03 Seal-A-04 North Star 1 Reservoir Prs from DST Seal-A-01 A Seal-A-02 OH A Seal-A-03 North Star 1 11,000 H 1 ? g 4 0 4 ~, 10/17/00 O0176404 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET __ 101200 CK101200 100. O0 100. O0 PYMT (',OMMENTS: PERI liT TO DRILL lrEE HANDEl NG INST: S/H SONDRA X4750 pAV.~m' FO. rm.s OF. SCm.~O AaOW. ~ 100. O0 100. O0 A'rrACHED CHECK IN .:. :~BP.EXPLORAT:IQ,N (ALASKA)i:]NG, '.:~,i::.,'.:...'AN~HO~AG~E,'.'.;iiA~S~i!~99519-6612 !i!.ii!i!if? '~:~'~:'~ .... ":':~:: [:.':;'?,': :.:,,,..,:::~:.;. :,~.::,.: :..:~::,~ ,~.:~ ...~;~:.:. ::. ::... .~j,.:~'.~;:: ::%:. ,':::,,": ~:~:~:: :.::.::." ~:~..:,. ,.',....':..,..~ .,. :,,..,,::,: .:.::::'~ ...... ~:..:,: , ,:::'. : :."':,~ ~.',:,d' ':? ~:~. 'E~:L,.,:,.~. ',".:f":: :":: ,~..,'.~:. .':':." ~ '.:,::':::..:::?': ":.::::',~.~ ',' .~':::: ::',' ,'~: ,:,'.: .: ':': ~:::~'~ :::.; :~' ":"~."?,~: ' ~::: :~.:2.~:;:~' ' :..~:.:".:' '::::[:,".':':~" ';'...:':.' ":,':.~':::~::::. DATE ::.:':'::.. ":;~::~?':.f':~:::" ,~ ".' ~i~:?.:?~OUNT · ,' I I I J 'oeb~~' ':::~:: ?~o~e~:'.;' ?;~." ~'~ ?'"~':..' '::::'"":. : ;~?~ ........ ',:'.'::" ':?~:.::::.:::.~,.'.. '::'::~{::.,..::':'.? :/.'. :::?:.~':,?: ?'...?: ,~:.~O~..:f~ORCUP z~?O~z~',~: ~,:~:~::~::.:~ ~ :~:.::;;.' '~:¥,:~..;~:~:~:' ~;::::,:.;:~..~::,;,::?e'~.:.'::'':`' ".? :~.... .::.r.~.:..:: ..... :?.;~.: '~?::.,?.' :. ~' :,.? .'~ /' :" . ~: ' ' . .:. :':::~:k":::, ..:' ADMINIST._~~TION 1. Permit fee attached. N 2. Lease number approl~ri;at~."~".'.~.' ~~.'~.'.~.~.'.~/.'~.'..-.'~.'/ )N ~ ~.~'~,"/',~.~% ~ --~ ~' ,~- -,-~-~/c.,c.~... ~. -/~ t,,',~ ~ ,,~.c~/_. 3. Unique well name and number .................. N ' ~' ' ' ' - APPR DATF~ ENGINEERING , 5. 6. 7. 8. 9. 10. 11. 12. 13.. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... 'N Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... 14. Conduclur string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet regulation ................ 26. DOPE press rating appropriate; test to '~"(~r,,.~ psig. 27. Choke manifold complies w/APl RP-53-(May 84) ..... '... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. y .GEOLOGY 30. Perrr, it can be issued w/o hydrogen sulfide measures ..... 31. _Da!a presented on potential overpressure zones'? ...... ~ ,/~_ ~~ 34. Conta~ name/phone forweekly progress repo~s [~plo~to~ only] Y N ANNULAR DISPOSAL35. With proper cementing re~s, this plan . (A) will contain waste in a suitable receiving zone~ ....... Y N ~~~ ' APPR DATE (B) will not ~ntaminate freshwater; or cause drilling waste... Y N -- ~ ~~rg~:~~l i~tt~o:f~elI used for disposal; Y N ~ ~. g ' ' pair re~ve~ from a Y N ~ ~. pool; and ~ . ~ _ c:~msoffi~wordian~diana~checklist (rev. 11101//00) ,. 0 Z 0 ( Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. ( 11111111111111111111111111111111111111111111111111111111111111111 10202716838 Memory Multi-Finger Caliper Log Results Summary :::r)èt:.-I~">-- Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: BP EXPLORATION (ALASKA) INC. May 12, 2005 5753 5 4.5" 12.6 lb. L-80 Ibt-MOD Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: NS10 NorthStar Alaska 50-029-22985-00 Surface 8,007 Ft. (MD) Inspection Type : 5th Consecutive Corrosion Monitoring Inspection COMMENTS : This caliper data is tied into the WLEG @ 8,006' (Drillers Depth). This log was run to monitor the condition of the tubing with respect to changes in internal corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing logged is in good to poor condition, with a maximum recorded penetration of 46% @ 906'. Wall penetrations ranging from 20-46% wall thickness are recorded in 42 of the 201 joints logged. The damage recorded appears mostly in the form of Isolated Pitting, as well as Lines of pitting. There are no areas of significant Cross Sectional Wall loss or 1.0. restriction recorded throughout the tubing. A comparison between this log and the previous log of this well (May 3, 2004) indicates some increase in corrosive damage in· the top 40 joints, a shallow line on pits is recorded in the bottom 50 joints that has not previously been recorded. It appears that some of the isolated pits recorded over the interval-1,600' to -5,400' in the previous caliper log have been masked by light deposits or scaling. A graph illustrating the comparison of maximum recorded wall penetrations between caliper log runs is included in this report. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Isolated Pitting ( 46%) Jt. 21 @ 906 Ft. (MD) Isolated Pitting ( 44%) Jt. 23 @ 985 Ft. (MD) Isolated Pitting ( 43%) Jt. 2 @ 96 Ft. (MD) Isolated Pitting ( 42%) Jt. 28 @ 1,1 96 Ft. (MD) Isolated Pitting ( 41%) Jt. 20 @ 844 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>5%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: ~;';iJ'" .I~ ~ k ~ i .~-::'"~, 'ì {' f'· ''1'1; fì '.. ßj ,.1 ~.' 1'1 t: :~,~~,.ç'~rJ'!)~:~"~Iç;:,~:/, t))"J" Ü &1 (\..1 U~¡ No significant I.D. restrictions are recorded. I Field Engineer: N. Kesseru Analyst: J. Thompson Witness: M. Harris ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Q" Maximum Recorded Penetration Comparison To Previous Well: Field: Company: Country: NSlO NORTHSTAR BP EXPLORATION ALASKA INC USA Survey Date: Prevo Date: Tool: Tubing: May 12, 2005 May 3, 2004 MFC 40 No 99494 4.5" 12.6 Ib L-80 IBT- MOD Overlay Difference 0 100 200 1 ~ =< 8 -< ~ 18 -< ':! ::¡ 28 ::¡ ::¡ -<- 3ß -- =: 48 ;- ~ 55 ~ ~ 65 =----- '~ 75 ::'- - .. 85 "" ~ ~ ~ E = 95 ==-- Z =- 'E 105 ~ i ==- = 115 - : 122 ~ - 132 =r-- ==- ::::::.. 142 3--- 152 =----- ==- =e:æ::- 162 -= =- 172 ~ ::;---- -<....--- ==- 182 ~ ~ ======- 192 ~ -100 Diff. in Max. Pen. (mils) -50 0 50 1-1: 100 Max. Rec. Pen. (mils) 8 :::----.-- ---i-H-c ._._____.._ _.._-28~::;:::C::=_:---' - -"'-3~ ······-;:-2f8~ ... c i -~ .:::-:~ '-1)~ ·~7-5~ -::::::c==:ãs;ê ~~~-_... J@ ~~~i 12~1 fi2~ .. cu .Q E = z - -+:1~::~ 1421=:-:' 152 ~==_. 162 f=.' " 1 r2::-j_~ T8T~~---- -98 192 ~;:=- -49 0 I 49 98 \_ May 12, 2005 _ May 3, 2004 I Approx. Corrosion Rate (mpy) !clds. Well: Field: Company: Country: NS10 NORTHST AR BP EXPLORATION ALASKA INC USA ,------------------------- Tubing: Nom.OD 4.5 ins Weight 1 2.6 ppf Grade & Thread L-80 IBT- MOD Penetration and Metal Loss (% wall) _ penetration body 200 ¡¡¡;ft~.l;:'\l1 metal loss body 150 1:: ~....:i, _E~_-~=~~~= o to 1 to 10 to 20 to 40 to over 1 % 1001<;) 20% 40°/r) 85% 85% Number of joints analysed (total = 2(1) pene. 0 55 104 37 5 0 loss 18 183 0 0 0 0 Damage Configuration ( body) 150 100 .. 50 o isolated pitting general line ring hole / poss corrosion corrosion corrosion ihle hole Number or joints darn aged (total = 135) 101 0 34 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Hngers: Analyst: Nom.lD 3.958 ins May 12, 2005 MFC 40 No 99494 2.75 40 J. Thompson I ------1 Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 4.5 ins Damage Profile (% wall) _ penetration body o 1 =-- r~·"'-"D ~:-:~:'·-:u·.:-G:· ..-.:, ;.j ,\, - .--.'- 1"-.-- :\~,.., ~ "....." ~.. 481' f 96t l::- i 1MI E- 192~ Œ~¡ metal Joss body 50 100 Bottom of Survey = 192.4 Analysis Overview page 2 , t PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 IB1- MOD 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS10 NORTHST AR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint Jt. Depth PCIl. Pen. Pen. Mctùl Min. No. (Ft.) Upset Body % Loss 1.0. Comments (IllS.) (Ins.) 'Yo (Ins.) 47 0.07 0.06 24 2 3.90 Isolated pitting. ____L.l___ _~.zZ_.___ _ () 0.05 _1ß~__L____~~l___PUP.5.b1!!!º_W_pitting. 1.2 86 () 0.03 10 1 3.91 PUP 1.3 89 0 0.03 10 1 3.91 PUP 2 92 () 0.12 43 :~ 3.90 Isolated pitting. 3 132 0 0.07 24 2 3.89 Isolated pitting. 4 173 0 0.08 30 .3 3.89 Isolated pitting. 5 215 0 0.06 23 2 3.90 Isolated pitting. 6 256 0 0.10 35 2 3.90 Isolated pitting. 7 297 0 0.09 32 2 3.89 Isolated pitting. 8 338 0 0.10 38 2 3.90 Isolated pitting. 9 380 0 0.08 31 .3 3.90 Isolated pitting. 10 422 0 0.07 25 2 3.90 Isolated pitting. 11 463 () 0.10 37 .3 3.89 Isolated pitting. _..____.12._____.____5._º~____.. 0 O~º_ª__._~º_ 2 3.89 Isolated.Qitting. 13 545 0 0.10 37 .3 3.88 Isolated pitting. 14 586 () 0.09 33 2 3.89 Isolated pitting. 15 628 0 0.06 23 .3 3.88 Isolated pitting. 16 669 0 0.06 24 .3 J.88 Isolated pitting. 17 710 0 0.07 27 2 3.88 Isolated pitting, 18 752 0 0.08 31 4 3.90 Isolated pitting. 19 793 0 0.11 39 2 3.90 Isolated pitting. 20 834 0 0.11 41 2 3.91 Isolated pitting. 21 875 0 0.12 46 .3 3.90 Isolated pitting. 22 916 0 0.10 38 2 3.89 Isolated pitting. 23 957 0 0.12 44 .3 3.90 Isolated pitting. _.___.1.1:._____ 999 __º_~__O.QJ~ 30 .3.. 3,90 Isolated pitting, 25 1040 0 0.09 32 ..·--2-..-----·-i90..--lsolated pitting. 26 1081 0 0.08 29 .3 3.91 Isolated pitting, 27 1'121 0 0.08 30 .3 3.91 Isolated pitting. 28 1162 0 0.12 42 2 3.92 Isolated pitting. 29 1203 0 0.10 37 .3 3.92 Isolated pitting. .__..._3J2_____. __.1.2.1_4_____ ______,(2..._____. _.__º=QfL.....__22..__. __.___.L____ _.1.'--~J..__. _ Isota..1ß...Q12Lttiog...___________________..______________ 31 1286 0 0.05 20 .3 3.90 Isolated pitting. 32 1327 0 0.05 18 2 3.90 Shallow pitting. _.11..___ 1367 0 0.08 30..2.""..._..~.,1:.9._Q~.._"JsoIÇl.!eq pitting. 34 1408 0 0.07 24 2 3.89 Isolated pitting. 35 1449 0 0.07 24 2 3.90 Isolated pitting. 36 1490 0 0,04 13 2 3.90 Shallow pitting. 37 1531 0 0.05 20 2 3.90 Isolated pitting. 38 1573 0 0.05 18 'I 3.91 ShaJlowpitting. 39 1614 0 0.04 14 2 3.91 Shallow pitting, 40 1656 0 0.04 13 2 3.89 Shallow pitting. 41 1697 () 0.04 15 2 3.91 Shallow pitting. 42 1738 0 0.04 16 3 3.90 Shallow pitting. deposits. 43 1779 0 0.03 13 2 3.91 Shallow pitting, 44 1 H20 0 O.OS 18 2 3.90 Shallow pitting. 45 1861 0 0.04 17 3 3.90 Shallow pitting. 46 1902 0 0.03 10 2 3.91 47 1943 0 0.02 9 2 3.91 Page 1 I Damage Profile . (% wall) o 50 100 I Penetration Body " I Metal Loss Body ( PDS REPORT JOINT TABULATION SHEET Pipe: 45 in 12.6 ppf L-80 IBT- MOD Well: NS10 Body Wall: 0.271 in Field: NORTHSTAR Upset Wall: 0.271 in Company: BP EXPLORATION ALASKA INC NominaII.D.: 3.958 in Country: USA Survey Date: May 12, 2005 Joint Jt. Depth Pcn. Pen. I Pen. I Metal Min. Damage Profile -. No. (Ft.) LJ psct Body % Loss I.D. Comments (% wall) (! n s.) (Ins.) (X, (Ins.) 0 50 100 48 1985 0 0.05 17 2 3.91 Shallow pitting. 48.1 2026 () 0.03 11 I 3.92 PUP 48.2 2034 0 0 0 0 -.1&._ ~_b!lPP LE 48.3 2037 0 0.04 13 4 3.90 PUP Shallow pitting. 49 2046 0 0.05 18 :~ 3.91 Shallow pitting. __.,5Q. 208Z 0 0.04 15 3 3.89 Sb-ª.!Low pitting. S·, 2129 0 0.03 13 3 3.89 Shallow pitting. 52 2170 0 0.03 12 2 3.90 Shallow pitting. 53 2212 0 0.03 11 2 3.89 .54 22.53 () 0.01 12 3 1.90 Shallow pitting. 55 2294 0.09 0.03 11 3 3.90 Shallow pitting. .._.._~f?_._. __2JJ_.?___ h..___º-___ _._.º-'-Q:2___.__JL._ __J___.__3.Jt8 -----_.__._--------_._,-,-_._"~"~'. 57 2377 () 0.03 12 3 3.88 Shallow pitting. 58 2418 0 0.03 11 2 3.88 59 2459 0 0.02 9____.~_ 3.88 60 2500 0 0.05 18 3 3.88 Shallow pitting. 61 2541 0 0.04 14 3 3.91 Shallow pitting. 62 2582 0 0.03 13 2 3.90 Shallow pitting. 63 2624 0 0.03 9 4 3.88 64 2665 0 0.03 11 4- 3.89 65 2706 0 0.03 11 3 3.89 Shallow pittinJ;?;. 66 2747 0 0.02 .8 2. 3.90 67 2789 0 0.03 11 3 3.89 68 2830 0.06 0.02 8 3 3.88 pittins;!; in upset. ___J?.9.._.__ _ 2872 0 0.05 18 3 3.89 Shallow pitting. .~--~---_._--~.._-----,_.__...- 70 2913 0.06 0.02 8 2 3.90 pitting in upset. 71 2954 0 0.02 8 2 3.91 72 2996 0 0.04 13 2 3.90 Shallow pitting. 73 3037 0 0.03 13 2 3.89 Shallow pitting. 74 3079 0 0.05 19 4 3.90 Shallow pitting. 75 3120 0 0.03 9 3 3.90 76 3160 0 0.02 8 :3 3.91 77 3201 0 0.07 27 :3 3.91 Isolated pitting. 78 3243 0 0.03 10 1 3.90 79 3284 (J 0.03 9 :3 3.90 80 3325 0 0.04 16 1 3.90 Shallow pitting. 81 3366 0 0.02 8 2 3'.9'0 ..._....._..!!2.___....__ì4QJi.____.____lL 0.02 ..__ª_....._..__..__J..._. 3.90 83 3449 0 0.02 6 2 3.89 84 3490 0 0.01 4 '). 3.88 .) 85 3532 0 0.04 13 3 3.89 Shallow pitting. 86 3573 0 0.03 10 2 3.89 87 3614 0 0.03 10 2 3.89 88 3655 0 0.02 9 2 3.90 89 3697 0 0.05 17 3 3.90 Shallow pitting. 90 3737 0 0.04 13 2 3.90 Shallow pitting. 91 3779 () 0.02 7 3 3.88 92 3820 () 0.03 11 2 3.91 _._-~-- 386 C_._ 0 _..Q..02_._L._..1_______;t9-º_ Deposits. 94 3901 0 0.05 18 4 3.88 Line shallow corrosion. I Penetration Body . . Metal Loss Body Page 2 \( PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: -1.5 in 12.6 ppf L-ßO IBT- MOD 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NSIO NORTHST AR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint J1. Depth Pen. Pen.' Pen. Met<11 Min. No. (Ft.) Upset Body % Loss 1.0. (Ins.) (Ins.) (:'~) (Ins.) 95 3942 0 0.04 14 3.92 Shallow pitting. _..____~þ_______.l9J~1___ _____JL_ __ _ O. O~___ ___.-2_ _....l___1'-8._9___.______ _______._______._________________ 97 4024 () 0.01 5 3 3.90 98 4065 0 0.03 10 3 3.89 99 4106 0 0.03 10 3 3.91 __J_Q-º_._ _____:41:lZ________._.cL______-º_'º-~__ ___ __9______L_.__ _ 3. 9Q____ _______.__.____________________ ______________ ---.------ --- 101 4188 () 0.03 10 2 3.90 Deposits. 102 4229 0 0.01 5 3 3.90 103 4270 () 0.04 15 3 3.90 Shallow pitting. 104 4310 () 0.03 10 2 3.90 .JQ,5... _..____~U2L O.Q.Q.2 .7 ..1J.9J 106 4392 0 0.02 6 2 3.89 107 4433 0 0.01 4 2 3.90 108 4473 0 0.03 12 2 3.89 Shallow pitting. ___1_º:~L_.______~L1:_____..__Q___. _-º:.º~__ß____. __.L_______.1.2Q...... ____.____ 110 4556 0 0.03 9 3 3.9'( 111 4596 0 0.01 6 2 3.89 112 4638 0 0.06 21 2 3.91 113 4678 0 0.03 10 2 3.90 114 4720 0 0.02 8 3 3.90 115 4761 0 0.02 6 2 3.90 116 4801 0 0.04 14 2 3.91 Shallow pitting. 117 4843 0 0.04 15 2 3.90 $hÇlllow Iiliting. 118 4884 0 0.03 10 2 3.90 119 4925 0 0.03 10 2 3.92 120 4966 0 0.04 16 3 3.91 Shallow pitting. __12_º_,L_. ..___5-º_º2_____..J2.__.__ ___º-,-Q_;L_ .._ 11 3 ___3_,9.1__.__ PUp_____.__..._._._....._._____.__..__....._._._..__.__..______ 120.2 5017 0 0 0 0 3.88 PACKER 120.3 5021 () 0.06 21 3 3.91 PUP Isolated pitting. .__.__L~~L._ _~9J.L_..___.__Q______ .__..Q.:QL_ ___~_______~____ __.J_~º..__ _____.__._________.____.__.______.____________.._..____._----.-- ___1.22__.__..5-ºZ2_______Q__-º,,º-2.._ ......2_._ ___.L_.2:.2.L.. -_________.__._._ 123 5114 0 0.04 15 1 3.90 Shallow pitting. 124 5155 0 O~03 12 3 3.90 ShallowpiUing; 125 5196 0 0.04 17 3 3.88 Line shallow corrosion. 126 5237 0 0.03 12 2 3.90 Shallow pittin~. 127 5278 0 0.03 10 :3 3.89 '128 5319 0 0.04 14 2 3.90 Shallow pittinj!,. 129 5360 0 0.04 13 2 3.90 Shallow pitting. 130 5401 0 0.02 8 3 3.90 111 .5441 0 0.04 15 2 3.89 Shallow Line of pitting. 132 5482 0 0.05 19 :3 3.91 Shallow Line of pitting. _.J.JJ_.__._.____5 523 _..!2______ o. 01_.__J.2___ __.__.J____~,_9J:L__._..s_b.Çl.J.[Qw_li.t:Le_ºf-ºiUÌlJg'___.._._._.__..__..._ 134 5564 0 0.07 24 2 3.90 Line of pitting. 135 5605 0 0.05' 18 '1 3.90 Shallow Line of pitting. 136 5646 0 0.04 16 3 3.90 Shallow Line of pitting. 137 5687 0 0.03 11 1 3.90 Shallow Line of pitting. 138 .5728 0 0.07 24 2 3.90 Line of pitting. 139 5770 0 0.04 16 3 3.90 Shallow Lineof pitting. 140 5810 0 0.03 12 3 3.91 Shallow Line of pitting. 141 5851 0 0.04 16 3 3.89 Shallow Line of pitting. Comments , Darnage Profile . (% wall) 50 100 o 1-' . ~I .......,..",,"....-................................,.. _~_,' r Isolated pittin~. Page 3 I Penetration Body ~.: Metal Loss Body t , PDS REPORT JOINT TABULATION SHEET Joint 'Jt. Depth PCIl. Pen. Pen. Mctall Min. No. (Ft.) Upsct Body % Loss 1.0. (IllS.) (Ins.) %¡ (Ins.) T 42 5893 () 0.04 14 3 3.89 Shallow Line of pitting. _._H2._._ _.._.~~3 3 .______.Q._____º'-Q?__ _._2.º--____1__ 3. 90 _~hallillV_'=_~!l~ of pitting. ___.____..._______.__ 144 5974 0 0.04 14 1 3.89 Shallow Line ofpitting. 14S 6015 () 0.02 8 2 3.90 146 6057 0 0.03 11 :~ 3.91 Shallow Line of pitting. 147 6098 0 0~06 21 1 3.92 Line of pitting. 148 6139 () 0.04 16 2 3.91 Shallow Line of pitting. _. 149_____~1ª-º__..._Jl_._ .__º,--ºª_____lZ_.__ _._l____.__~t2º.__ Shall<iW Line of pittih~~___.___..._____._~_.... 150 6221 () 0.04 15 :~ 3.89 Shallow Line of pitting. 151 6262 0 0.05 18 2 3.91 Shallow Line of pitting. .. _152 6303 0 0.04 17 :3 3.87 Shallow Line of pitting. 153 6343 0 0.05 18 2 3.90 Line shallow pitting. 154 6384 0 0.05 18 2 3.92 Shallow Line of pitting. 155 6426 0 0.03 9 2 3.92 156 6468 0 0;02 9 2 3.92 157 6509 0 0.05 19 2 3.91 158 6551 () 0.03 10 2 3.91 ·159 6592 0 0.03 12 2 3.90 Shallow Line of pitting. . _..l§Q_.._ .._.§þ}'?_ __. _____Q. .___º~º~__. .J2_...._n_~L.._._)~_~Q__ __.~ll.ª.H-º~JJ.Q~_QÍJ=!!lL.!ng~____ ...... .... ___._.__...__..____.___. 161 6674 0 0.03 13 3 3.91 Shallow Line of pitting. 162 6714 0 0.04 13 2 3.90 Shallow Line of pitting. 163 6755 0 0.04 15 2 3.91 Shallow Liocofpitting. 164 6797 () 0.03 11 2 3.91 165 6838 0 0.03 11 2 3.89 166 6879 0 0.04 13 2 3.92 Shallow Line of pitting. 167 6920 () 0.03 11 3 3.91 168 6961 ______.._º-_.__ 0.04 _.3.1:_._._-1._.._..___ 3.90 Shallow Line of pjtting,__.._______.._...____._.___....______ 169 7000 0 0.03 11 2 3.91 170 7041 0 0.04 14 2 3.90 Shallow Line of pitting. 171 7082 () 0.02 8 1 3.92 172 7123 0 0.06 24 3 3.91 173 7163 0 0.04 13 2 3.93 __.JZ1__.___._EW4._..__. __Jl.__.__Q,.Q1L._ ___JJL.... ._._._L__.____T.92_ 175 7246 0 0.04 15 1 3.90 176 7287 0 0.04 16 2 3.90 177 7328 0 0.06 21 2 3.93 178 7369 0 0.03 10 1 3.92 179 7410 0 0.04 17 1 3.90 Shallow pitting. 180 7452 0 0.04 16 3 3.89 Shallow Line of pitting. __.ill:l......_...__]1_~.2~..._ __...--.I.L_..__._-º-, 03 1 0 ....__)....___ ._...._:L9..L 182 7533 0 0.07 24 3 3.91 IsolatecIp-itting. 183 7574 0 0.05 18 2 3.91 Shallow pitting. 184 7616 0 0.04 14 3 3.92 Shallow pitting. 185 7657 0 0.02 7 2 3.91 186 7698 0 0.05 20 3 3.90 187 7739 0 0.04 15 2 3.91 188 7781 0 0.04 14 :3 3.90 189 7822 0 0.03 13 1 3.90 __.J9Q_. 7863 _._-º____.__º~04~ 15 3 3.88 191 7903 0 0.04 15 3 3.88 Pipe: Body Wall: Upset Wall: Nominal 1.0.: -1.5 in 12.6 µµf L-80 IBT- MOD 0.271 in 0.271 in 3.958 in \^/efl: Field: Company: Country: Survey Date: NSIO NORTHST AR BP EXPLORATION ALASKA INC USA May 12, 2005 Comments Damage Profile (% wall) o 50 100 Shallow line of pitting. Isolated pitting. Shallow pitting. S ha II ow pitti 1)..&.._____._.___.____.__.________..______.___.______ Shallow pitting. Shallow pitting. Isolated pitting. Shallow pitting. Shallow pitting. Shallow pitting~ Shallow pitting. __~hi!!.lQ~I;!¡!!ing~ Deposits. ____..._....______.__._ Line shallow corrosion. Deposits. I Penetration Body Metal Loss Body Page 4 {" PDS REPORT JOINT TABULATION SHEET ¡ l Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 IBT- MOD 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS10 NORTHSTAR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint Jt. Depth Pcn. Pen.! Pen. 1\1etlll Min. No. (Ft.) Upset Body % Loss 1.0. Comments (Ins.) (Ins.) % (Ins.) __J~J.__~945 __ __JL___ º=-Qß__.__l~______1___1.90 _____lJDg shallow corrosio.lL_Deposits. _____ 192.1 7985 () 0.03 13 2 3.73 PUP Shallow pitting. Deposits. 192.2 7995 () 0 0 0 3.88 XN NIPPLE _J~t2.,-L_ ._--Z~9-Ji_._ __ ____.'O'.___.__Q,º~L ___2__Q ____ _m5____ ___l,~L__ _J)J.!J:)__LÌ!Le_~ba I [ º_w.,.ǺJIº.sjºn,__Q~p-º~iJ.s-"-__ 192.4 8006 0 0 0 () N/ A WLEG Page 5 Damage Profile (% wall) o 50 100 --~ " oj _m - --1 I Penetration Body 1~~:1 Metal Loss Body PDS Report Cross Sections "" Well: Field: Company: Country: Tubing: NS1Q NORTHST AR BP EXPLORATION ALASKA I/'\C USA 4.5 ins 12.6 ppf L-80 18T- MOD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 12, 2005 MFC 40 No 99494 2.75 40 J. Thompson Cross Section for Joint 21 at depth 906.13 ft Tad! speed = 67 Nominal 1:0 = 3.958 Nominal 00 = 4.500 Remaining wall area = 99 % Tool deviation = 4 <> Finger 9 Penetration = 0.124 ins Iso1ated Pitting 0.12 ins = 46% Wall Penetration HIGH SIDE = UP Cross Sections page 1 PDS Report Cross Sections I.. Well: Field: Company: Count~y: Tubing: NS 1 () NORTHST AR BP EXPLORATION ALASKA INC USA 4.5 ins 12.6 ppf b80 I BT- MOD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 12, 2005 MFC 40 No 99494 2.75 40 J. Thompson Cross Section for Joint 23 at depth 984.93 ft Tool speed = 66 Nominal 10 = 3.938 Nominal 00 = 4.500 Remaining wall area = 98 % Tool deviation = 4' ~'" Finger 10 Penetration = 0.118 ins Isolated Pitting 0.12 ins = 44% Wall Penetration HIGH SIDE = UP Cross Sections page 2 TREE:ABB-VGI 5 1/8" 5ksi WELLHEAO:ABB-VGI 11" Mulitbowl 5ksi I 20", 169# X-56 @ 199' MD - ~ 10 3/4", 45.5#/ft, L-80, BTC @3726' MO 4.5", 12.6#/ft, L-80, IBT -MOO TUBING 10: 3.958" CAPACITY: 0.015 BBUFT NS10 ~ ~ ~ .. 3 4.5" 'XN' NIPPLE, @ 7994' 6294' TVO 3.725" 10 (OTIS)------' 7 S/8", 29.7#/ft'" r L-80, BTC-M @8029'MO TO @8246' MO 6513' TVO OATE 1/11/01 9/10/01 12/20/02 REV. BY AGK I::.MI- EMF COMMENTS Initial Diagram Inserted iVD Depths Updated KB Information \ ~ ~ -~ . ~ ~ .g , ~ ~ RI(B. ELEV = 55.77' if 3F. ELEV = 39.87' BASE FLANGE ELEV = 15.9' ~ 'X' Nipple @ 2033' MO 1994' TVO 3.813" 10 Heat Trace @ 2318' MO Cement Baker S3 PACKER 3.87S"10 @S01S' MO 4023' TVO 4.S" WLEG, @8006' MO 6 3/4" open hole Northstar WFJ J : NS10 API NO: 50-029-22985-00 BP Exploration (Alaska) ( , Memory Multi-Finger Caliper Log Results Summary (" NS10 Northstar Alaska 50-029-22985-00 Suñace 8,002 Ft. (MD) Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: BP EXPLORATION (ALASKA) INC. April 9, 2002 4606 1 4.5" 12.6 lb. Tubing L-80 I Company: Log Date: Log No. : Run No.: Pipe1 Desc. Pipe1 Use: Co"osive & Mechanical Damage Inspection Inspection Type COMMENTS This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 4.5- tubing is in good to fair condition, with penetrations of less than 20% wall thickness recorded in the majority of the 4.5- tubing. Penetrations from 20% to 40% wall thickness are recorded intermittently throughout the 4.5- tubing. The damage appears in the forms of General Corrosion with deeper Isolated pitting near the coupling regions of the tubing joints. No areas of significant cross-sectional wall loss are recorded throughout the 4.5- tubing. A significant accumulation of deposits is recorded on the low side of the tubing over the interval 3,100' to 3,113'. The minimum measured ID within this deposit interval is 3.52-. The distribution of penetrations is illustrated in the Body Region Analysis Page of this report. A cross-sectional drawing of the pipe at the location of the deposit @ 3,108' and a Minimum Diameter Profile page are also included in this report. . (MD) (MD) (MD) (MD) (MD) 1,231 Ft. 3,197 Ft. 480 Ft. 5,764 Ft. 200 Ft. MAXIMUM RECORDED WALL PENETRATIONS @ @ @ @ @ 29 77 11 138 4 Jt. Jt. Jt. Jt. Jt. ( 40%) ( 37%) ( 34%) ( 32%) ( 31%) Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting 4.5" TUBING 4.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS throughout the 4.5- tubing. > 5%) are recorded No areas of significant cross-sectional metal loss (MD) (MD) (MD) (MD) 3,108 Ft. 1,381 Ft. 342 Ft. 2,659 Ft. @ @ @ @ 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS 74 33 8 64 Jt. Jt. Jt. Jt. Min. I.D. = 3.52- Min. I.D. = 3.72- Min. I.D. = 3.79- Min. I.D. = 3.79- Deposits Deposits Deposits Deposits Witness: T. Norene ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Analyst: M. Lawrence D. Cain Field Engineer Well: NS!0 Field! Northstar Company: BP [XPEORATION (ALASKA); Country: usa Tubing: Nom.OD Weight Grade& Thread 425 ins 1226 ppf U80 To01 Typei Tool Sinai ~i g~ Fingers: Analyst: APri! 9 2002 ~FC2~ N6 99628 1!69 M: Lawrence Nom:lD Nora; Upset Upper len. Lo~er len. 3J958 ifi~ 4:5 ihs 1:2 ins 1:2 ins Penetration and Metal Loss (% wall) ~ penetration b0dy ~ ,;~; metal 10ss b6dy 200 ~ 0 0 to 1 to 10 to 20 t0 1% 10% 20% 40% 85% 85% Number of j_oi_nts an~ly~s~d (total -= 1 ~9~ pene. 3 52 115 29 0 0 toss 8 191 0 0 0 0 I Damage Configuration ( body ) 1507 100 50 0 isolated general i!pe pitting corrosion corrosion corrosion ibte hole Number of joints dam_aged]total-- 131 ) 124 7 0 0 0 Damage PrOfile (% W~ll) ~ penetratibfi b0dy ?~¢ metal 16S~ bod~ 0 50 1 48 97 BOttom Of surve9 = 192i3 100 Analysig ©gerview page 2 Well: Field: Company: Country: NS10 Northstar gP EXPLORATION (ALASKAI INC. USA PDS Caliper Statisitical Evaluation Report Survey Date:4/9/2002 Tool: MFC24 No. 99628 Tool Size: 1.69 inches Tubing LD.: 3.958 inches 0.24 0.19 0.14 0.09 0.04 0.1 Percent Probability of Hole 20 50 Average Rank Standard D~viatifin 100 Maximum Probable Penetration* (Ltl 1 it~ches Percent Probability of[ Recording a Hole* Less tbar~ 10% ~ DerK,ed from data WetE Field: Company: Country: N S I 0 Northstar BP EXPLORATION (ALASKA) USA PDS Caliper Minimum Diameter Profile Survey Date:4/9/2002 Tool: MFC24 No. 99628 Tool Size: 1.69 inches Tubing LD,: 3,958 ii~ches Minimum Measured Diameters (In.) 225 275 325 ® PDS REPORT JOINT TABULATION SHEET Pipe: 4,5 ins 12.6 ppf L-80 Well: NS10 Wale thickness: Boor ~ 0.271 ins Loset = 0.271 ins Field: Northstar Nominal ID: 3.958 ins Company: BP EXPLORATION (ALASKA), ]NC.~ penetration body Countrv: USA metal loss bodv Survey Date: April 9, 2002 Joint Penet~0n ~letal P~ojecti~n ~i'n~um Damage Profile No. Upset !Bd@Up[ Bod~ _oss ICplng i3ody ~ ID Comments (O/~wal[l inches [ inches I inches % % inches [ inches] inches 50 100 ~ 0 0 .05 19 4 .06 .12 3.86 Shallow corrosion Lt. Deposits. 1.1 0 0 .02 7 2 0 .09 3.92 PUP Lt. Deposits. 1.2 0 0 .03 10 ~ 0 .04 3.94 PUP 1.3 0 .03 .03 9 I 13 .05 3.91 PUP 2 0 0 .03 Il 3 0 .08 3,90 Shaliow pitting. Lt. Deposits~ 3 ( 0 ,05 18 4 0 .10 3.89 Shallow pitting. Lt, Deposits. 4 0 .08 .08 31 3 05 .09 3.89 Isolated pitting. Lt. Deposits. 5 0 0 ,05 17 3 0 .08 i 3.90 Shallow pitting. Lt. Deposits, ~ ~3 0 .05 17 2 06 .10 3.87 Shallow pitting. Lt. Deposits. 0 .05 .04 14 3 06 .08 3.89 Shallow pitting. Lt. Deposits. 8 C 0 .07 24 3 0 ,15 3.79 Isolated pitting. Lt. Deposits. 9 0 0 .04 16 3 0 .12 3.85 Shallow pitting. Lt. Deposits. 10 0 .02 .05 17 3 07 .11 3.89 Shallow pitting. Lt. Deposits. ~ ~ 0 0 .09 34 3 ,06 .08 3.91 Isolated pitting. Lt. Deposits. 12 0 0 .03 11 3 0 .10 3.84 Lt. Deposits. 13 0 0 ,03 11 3 0 .08 3.89 Lt. Deposits. 14 0 0 .03 10 2 .06 .07 3.91 Lt. Deposits. 15 0 0 .07 27 3 0 .10 3.90 ~Corrosion Lt. Deposits. 16 0 0 .03 13 3 .05 .08 3.89 Shallow pitting. L[, Deposits. - 0 0 .03 13 3 .06 .06 3.90 Shallow pitting. Lt. Depos~[s. 18 0 0 .08 30 3 0 .08 3.91 Isolated pitting. Lt. Deposits. 19 32 0 .04 15 2 .07 .07 3,89 Shallow pitting. Lt. Deposits. 20 0 0 .05 17 4 .05 .09 3.88 Shallow pitting. Lt. Deposits. 21 0 .05 .07 25 3 0 .09 3.90 Isolated pitting. Lt. Deposits. 22 C 0 .06 21 3 .05 .16 3.81 Isolated pitting. Lt. Deposits. 23 0 .03 .03 12 2 .08 .14 3.84 ~ Shallow pitting. Lt. Deposits. 24 0 0 .04 13 3 .07 .10 3.88 Sha[lowpitting. Lt. Deposits. 25 0 .04 .05 1 - 3 .09 .11 3.87 Shallow pitting. Lt. Deposits. 26 0 0 .04 13 3 0 .11 3.88 Shallo~v pitting. ~[. Deposits. 27 C 0 .04 13 3 .06 .17 3.82 Shallow pitting. Lt. Deposits. 28 0 0 .04 14 3 ,05 .13 3.84 Shallow pitting. Lt. Deposits. 29 0 0 .11 4C 5 .08 .10 3.87 Isolated pitting. Lt. Deposits. 30 0 0 .05 17 3 .10 .07 3.89 Shallow pitting. Lt. Deposits. 3I 0 0 .04 13 4 .11 .13 3.84 Shallow pitting. Lt. Deposl[s. 32 0 0 .05 17 3 0 .10 3.86 Shallow pitting. Lt. Deposits. 33 0 0 .03 12 3 0 .25 3.72 i Shal[ow pitting. Deposits. 34 0 0 .03 10 3 .06 .12 3.86 Lt. Deposits. 35 0 .05 .05 18 3 .08 .11 3.85 Shallow pitting. Lt. Deposits. 36 0 0 .02 8 3 .05 .12 3.86 Lt. Deposits. 37 0 .03 .08 29 3 .06 .11 3.87 Isolated pitting. Lt. Deposits, 38 0 .06 .06 22 3 .05 .12 3.88 Isolated ~)ittlng. Lt. Deposits. 39 0 0 .04 15 3 .06 .18 3.83 Shaltowpitting. L[. Deposits. 40 0 0 .03 ] I 3 0 .15 3.81 Lt. Deposits. 4] 0 0 .05 18 4 .07 .08 3.89 Shallow pitting. Lt. Deposits. 42 0 0 ,08 31 3 0 .09 3.88 Isolated pitting. Lt. Deposits. 43 0 0 .04 16 4 0 .12 3.89 Shallow pitting. Lt. Deposits. 44 0 0 ,06 23 3 0 .12 3.88 Isolated pitting. Lt. Deposits. 45 0 0 .04 15 3 .06 .08 3.90 Shallow pitting. Lt. Deposits. 46 0 0 .03 12 i 3 0 .08 3.90 'Shallow pitting. Lt. Deposits. 47 0 0 .03 10 3 .06 .09 3.89 Lt. Deposlm. Pipe Tabulations page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4~5 ]ns ~2.6 ppf L-80 Well: NS10 'v'~;a~l thickness: Body ~ 0.271 ins Upset = 0.271 ins Field: Northstar Nominal ID: 3.958 ins Company: BP EXPLORATION/ALASKAL INC.~ penetration body Country: USA ~netal loss body Survey Date: April 9, 2002 joint Penetratioe ~4e~a[ ~-P-r-~jectJon Minimu n Damage Profile No. Upset 8d@Upl Bod'. Loss Cpbg J3ody D Comments (% wall~ inches [inches inches % L Yo i mches inches/ Inches 50 100 48 0 0 .03 11 3 0 .08 3.90 Lt. Deposits. 48.1 0 0 0 [ 0 0 0 0 N/^ SSSV 49 0 ) .02 ] 8 3 0 .06 3.89 Lt. Deposits. 50 0 ) .04 [ 14 4 .06 .07 3,87 Shallow pitting. Lt. Deposits. 51 0 0 .03 '~ 10 2 0 .06 3.88 t_~. Deposits. 52 0 0 .03 10 3 0 .10 3.88 ct. Deposits, 53 0 0 .05 20 3 i .06 ,06 3.88 Isolated pitting. Lt, Deposits. 54 0 0 ,05 17 4 0 .07 3.90 Shat]ow pitting. Lt. Depostts, 55 0 0 .04 [ 16 3 0 .09 3.90 Shallow pitting. Lt. Deposits, 56 0 0 .03 [ 9 4 0 .06 3,91 L[. Deposits. 57 0 0 .04 15 3 0 .07 3.86 Shallow pitting, Lt. Deposits. 58 0 0 .03 j 10 3 0 ~08 3.89 Lt. Deposits. 59 0 0 .03 11 2 0 .11 3.87 Shallow pitting. Lt. Deposits, 60 0 0 .06 21 3 0 .06 3.89 [Isolated pitting. Lt. Deposits. 61 0 0 .05 20 3 ~06 .08 3.91 isolated pitting. Lt. Deposits. 62 0 0 .04 15 t 2 ,05 ! 1 3.85 [Shallow pitting. Lt. Deposits, 63 0 0 .04 15 4 .06 .08 3.87 Shallow pitting. Lt. Deposits. 64 0 0 .04 15 3 0 .17 3.79 Shallow pitting. Lt. Deposits. 65 0 0 .04 14 I 4 ~05 07 3.89 Shallow pitting. LL Deposits. 66 0 0 .03 10 ~ 2 0 .08 3.90 Lt. Deposits. 67 0 .06 .05 · 18 3 0 .13 3.83 Shallow pitting. Lt. Deposits. 68 0 0 .03 10 3 0 .04 3.91 69 0 0 .08 28 3 0 ,09 3.90 Isolated pitting. Lt. Deposits. 70 0 0 .03 12 2 0 .09 3~90 Shallow pitting. Lt. Deposits. 71 0 0 .03 10 3 0 .05 3.92 Lt. Deposits. 72 0 0 .03 10 3 0 .10 3.87 Lt. Deposits. 73 0 0 ,04 15 3 0 ,11 3.90 Shallow pitting. Lt. Deposits. 74 0 .04 ~07 25 3 .24 43 3.52 Corrosion. Deposits. 75 0 .02 04 16 3 .08 .08 3.88 Shallow pitting. Lt. Deposits. 76 0 0 .03 11 2 0 .06 3.91 LL Deposits. 77 0 0 10 37 3 0 .08 3.88 [Isolated pitting~ Lt. Deposits. 78 0 0 .03 10 3 0 .09 ] 3.85 Lt. Deposits. 79 0 0 .03 10 4 0 .10 3.86 Lt. Deposits. 80 0 0 .05 20 ~ 2 .05 .07 3.90 Isolated pitting. Lt. Deposits. 81 0 0 .03 10 4 0 .08 3.89 L[. Deposits, 82 0 .03 02 8 3 .07 05 J 3.91 83 0 0 ,03 10 3 0 .05 3.89 84 0 0 .02 3 0 .06 3.88 L[. Deposits. 85 0 0 ~05 18 3 0 .06 3.90 Shallow pitting. Lt. Deposits. 86 0 0 .03 13 2 0 .06 [ 3.89 Shallow pitting. _t. Deposits. 87 0 0 ~04 15 2 0 .07 3.89 iSha[low pitting. Lt. Deposits. 88 3 0 .04 15 4 0 .07 3~91 ] Shallow pitting. Lt. Deposits. 89 0 0 .08 29 4 .07 12 3.86 isolated pitting. Lt. Deposits. 90 3 0 .05 18 ~ 2 0 .10 3.86 Shallow pitting. Lt. Deposits. 91 3 ~02 ~03 9 I 2 .08 05 3.92 92 3 0 .04 15 I 2 0 09 3.87 ]Shallow pitiing. Lt. Deposits. 93 0 0 .04 16 3 0 .09 3.87 Shallow pitting. Lt. Deposits. 94 0 0 .03 11 a 0 .04 3.91 95 0 0 .04 15 2 0 .05 3.92 Shallow pitting. 96 0 0 .04 16 3 0 .06 3.89 ~ Shallow pitting. Lt. Deposits. Pipe Tabulations page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins ]2.6 ppf b80 Well: NS10 Wall thickness: god', = 0.271 ins Upset: 0.271 ins Fieio: Northstar Nominal ID: 3.958 ins Company: BP EXPLORATION {ALASKAL I NC.~ penetration boav Country: USA metal loss body Survey Date: April 9. 2002 loire Penetra~o~n iM~taJ ] P~-~je~ti~n ~i-~m Damage Profile NO. [Upset I Bd@Upl Bod~ Loss CpJng }3ody ~ID Comments [o/~ wail/ inches [ inches , inches ]% 1% inches I inches [ inches 50 100 97 0 0 .03 10 2 0 .13 3.89 L[. Deposas. 98 0 ) .02 8 ~ 3 0 .08 3.89 Lt, Deposns. 99 0 100 101 102 103 104 105 106 107 108 109 110 lll 112 113 114 115 116 ll7 118 119 120 t20.1 121 t22 123 124 125 126 I27 128 129 130 131 132 133 134 135 136 137 138 139 140 14l 142 I43 144 145 .09 3.86 Shallow pitting. Lt, Deposits. .07 3.89 Lt. Deposits. .05 3.90 .06 i 3.90 LI Deposits. .06 3,89 Shallow pitting. Lt. Deposits, .06 [ 3.92 Shallow pitl/ng. Lt. Deposits. .08 i 3.87 LL Deposits. .11 3.86 Shallow pitting. Lt. Deposits. .08 3.88 Shallow pitting. Lt. Deposits. ,09 3.88 j Shallow pitting. Lt. Deposits. .08 i 3.88 Shallow pitting. Lt. Deposits. .03 12 4 0 .02 9 2 0 .02 8 3 0 ,03 10 4 0 .04 15 I 0 .04 15 2 0 ,03 11 2 0 .04 13 3 .03 12 3 0 .04 14 2 0 .04 14 ', 2 0 .03 12 3 .05 10 3.84 i Shallow pitting. Lt. Deposits. ,04 15 2 0 .07 ' 25 3 0 .05 ~04 16 2 0 0 .03 10 4 0 0 .03 12 3 0 0 .04 I5 2 0 .05 .07 25 4 0 0 ,05 19 3 0 0 .O3 11 3 0 0 .05 17 3 0 0 0 0 0 0 0 .02 9 3 0 .07 3.89 iShallow pitting. Lt. Deposits. .06 3.90 Isolated pitting. Lt. Deposits, ,07 3.91 Shallow pitting, Lt. Deposits. .05 3.91 ,05 3.91 Shallow pitting. ,06 3.91 Shal[owpitting. Lt. Deposits. ,09 3.90 Isolated pitting. Lt. Deposits. .07 3.91 Shat[ow pitting. Lt. Deposits. 11 3.87 Lt. Deposits. ,07 3.90 Shallow pitting. Lt. Deposits. 0 N/A PACKER .06 3.87 Lt. Depostts. .04 ' 14 3 .05 06 3.91 Shallow pitting. Lt. Deposits. .03 10 3 .07 08 3.90 Lt. Deposits. .04 14 4 0 11 3.87 ~:Shallow pitting. Lt. Deposits. .04 13 3 0 ,I 4 3,84 Shallow pitting. Lt. Deposits. .06 21 3 0 10 3.87 Isolated pitting. Lt. Deposits. .03 10 3 0 .09 3.88 Lt, Deposits, .05 20 3 0 I0 3.86 'Isolated pitting. Lt. Deposits, ,03 I0 3 0 ~09 3.88 Lt. Deposits. .02 9 3 0 .08 3.89 Lt. Deposits. .02 8 I 0 .05 3.91 .06 23 3 .06 07 3.92 Isolated pitting. Lt. Deposits. .04 14 3 0 .06 3.91 Shallow pitting. Lt. Deposits. .08 28 3 0 .08 3.87 Isolated pitting. Lt. Deposits. .05 17 2 0 .08 3.88 Shallow pitting. _[. Deposits, .03 11 3 0 13 3.84 Lt. Deposits, .02 8 3 .06 17 3.83 Lt. Deposas. .09 32 3 0 .08 3.91 Isolated pitting. Lt. Deposits. .04 14 3 .09 08 3.88 Shallow ~itting, Lt, Deposits. ,02 8 2 0 .08 3.86 Lt. Deposits. ,05 17 3 0 I 0 3.87 Shallow pitting. Lt. Deposits. .04 13 2 .09 09 3.87 Shallow pitting. Lt. Deposits. .07 25 3 0 .07 3.89 Corrosion. Lt. Deposits. ,03 11 2 .07 I 3.85 Lt. Deposits .02 2 .06 07 3.90 Lt. Deposits. Pipe Tabulations page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 4,5 ins 12.6 ppf L-80 Well: Wall thickness: Bodv= 0.271 ins Upset = 0.271 ins Field: Nominal ID: 3.958 ins Company: Country: Survey Date: April 9 2002 Jom~ Penetration Metal Projection Mm mum No, Upset I gd@Up Bod'~ Loss Cplng Body ID Comments inches ~ inches inches I% % inches[inches inches 146 0 147 0 148 0 149 0 150 0 151 0 0 152 0 .03 153 0 0 154 0 0 155 0 0 156 .02 0 [57 0 ,05 I58 0 0 159 0 0 160 0 0 161 0 0 162 0 0 163 0 0 164 0 0 165 0 0 166 0 0 167 0 .03 168 0 0 169 0 0 170 0 ,06 171 0 0 172 0 0 173 0 .03 I74 0 0 175 0 0 176 0 0 178 0 0 179 0 .03 180 0 0 I8 0 0 182 0 0 183 0 0 184 0 .03 185 0 0 186 0 0 187 0 0 188 0 0 189 0 0 190 0 0 I91 0 ,03 192 0 0 192.1 0 0 192.2 0 0 192 3 0 0 0 ,04 14 3 0 .03 10 4 0 .05 17 3 0 .04 13 3 0 ,04 15 3 .04 16 3 .03 ] 1 3 ~04 I4 3 .03 9 3 ~03 9 2 .02 8 3 .08 28 2 03 11 4 02 8 3 02 7 3 .02 8 [ 2 .04 13 . 4 03 13 3 03 12 3 02 9 2 03 10 4 04 13 3 04 15 3 05 20 3 ,05 18 2 02 8 3 06 23 3 .05 I7 3 .06 21 3 03 10 3 04 16 3 .04 16 3 03 11 2 .02 9 3 03 12 4 05 18 3 05 18 4 .07 24 3 .05 18 4 ~03 13 3 .08 28 4 .O5 20 3 .04 16 4 .03 10 3 03 13 3 .04 16 4 ,04 13 3 0.03 : 9 1 i 0 0 0 0 0 NS10 Northstar BP EXPLORATION [ALASKAI, INC.~ penetration bodx USA metal toss body .05 07 3,91 Shallow pitting. Lt. Deposits. 0 12 3.89 Lt. DeposiTs. 0 ,07 3.90 Shallow pitting. Lt, Deposits, 0 .07 3.89 Shallow pitting. Lt. Depos~s, .07 .12 3,85 Shallow pitting. Lt. Deposits. 0 1 ' 3.86 Shallow pitting. Lt. Deposits. .05 .07 3.89 Lt. Deposits .06 .05 3.91 Shallow pitting. Lt. Deposits. 0 .07 3.89 Lt, Deposns .06 .07 3.90 Lt. DeposiTs ,06 .07 3.90 Lt. Deposits 0 ,09 3.91 Isolated pittieg. Lt. Deposits. 0 13 3.86 Lt. Deposits .05 ,06 3.90 Lt. Deposits ,08 .08 3.89 Lt. Deposits. 0 ,08 3.88 Lt. Deposits. 0 12 3.90 Shallow pitting. Lt, Deposits. 0 ,07 3.93 Shallow pitting, Lt. Depoms. 0 08 3.91 Shallow pitting, Lt. Deposits. 0 06 3,92 Lt. Deposits. 0 12 3.87 Lt. Deposits .07 .11 3.90 Shallow pitting. Lt. Deposits. 0 08 3.92 Shallow pitting, Lt, Deposits. 0 06 3.91 Shallow pitting. Lt, Deposns. 0 06 3,90 Shallow ~itting, Lt, Deposits. ,05 .05 3.91 Lt. Deposits, 0 06 3.90 Isolated pitting. Lt. Deposits. .06 .08 3,92 i Shallow pitting. Lt. Deposits. .06 .07 3.92 Isolated pitting. Lt. Deposits. 0 08 3.90 _[. Deposits, 0 I0 3.91 Shallow pitting. Lt. Deposits. 0 05 3.93 Shallow pitting. Lt. Deposits. 0 13 3.88 Lt, Deposits, .06 .09 3.91 Lt. Deposits. 0 08 3.92 Shallow pitting. Lt. Deposits. 0 07 3.93 [ Shallow pitting. Lt, Deposits. 0 08 3.89 ~Shallow pitting. Lt. Deposits. 0 09 3.91 Isolated pitting. Lt. Deposits. .06 .16 3,83 Shallow corrosion. _t. Deposits. 0 08 3.92 Shallow corrosion. Lt. Deposits. 0 14 3,83 Isolated pitting, Lt. Deposits. 0 06 3.93 Isolated pitting. Lt. Deposits. .08 .10 3.90 Shallow corrosion. Lt. Deooslts .06 .11 3.87 Lt, Deposits. ,06 .07 3.92 Shallow pitting. Lt. Deposits. .07 .09 3.89 Shallow pitting. Lt. Deposl[s. 0 08 3.89 Shallow pitting. Lt. DeposiTs, 0 0 3,95 PUP 0 0 N/A XN Nip 0 0 N/A WLEG Damage Profile (% wall/ O 50 100 Pipe Tabulations page 4 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Une- damage depth range exceeds .5 * pipe ID, but extends less than 20% of drcumference. General - damage depth range exceeds 1 * pipe IDand/or extends more than 20% of drcumference. Isolated- damage depth range does not exceed $ * pipe ID or extend more than 20% of drcumference. Damage reporting threshold ~ 30 thou inches deviation in body, $0 thou in coupling. Modal line length - 0.237 feet. PDS Report CrosS secti°ns Well: NS10 Survey Date: April 9, 2002 Field: Northstar Tool Type: MFC24 No, 99628 company: Bp EXPLORATION (ALASKA), iNC~ T0ol size: 1.69 countrY: USA No~ Of Fingers: 24 Tubi!2g:- ~:~5 ins 12.6 ppf L-80 Analy?: M. Lawrei~ce CROSS section for joint 29 at depth 1231102 ft T0~] ~p~fd --56 N6min~l iD ~ 3958 R~m~i~ing ~;~ii ar~ ~ 95 % Finger 4 Penetration -- 0.i08 ins o isolated Pit o.i 1 ins --40 '/o Wall Penetration HIGH SiDE ~ UP Cross sections page 1 PDS Report CrOss secti°ns Well: NS10 Survey Date: Apri! 9, 2002 FJeJd: Norfl]star To01 TypeI MFC24 No; 99628 C~mPany: BP EXPLORATION (ALASKA), INC. Tool Size: 1.69 Count!y: USA No. of Fingers: 24 TuBing: ~.~5j)%s_~ .J~.§_Epf L-80 Analys~t_: M. Lawreoce ;CROSS section forjoint 74 at deptt~ 3108.4 ft T001 ~peed 5 60 Nomin~i :ID ~ 3;958 99% TOOl de~i~tiOfi 52 ~ Finger 20 Projection ~ ;0.426 ins Heavy Dep0sits Minimum LD. ~ 3152 ins HIGH SIDE ~ UP Cross sections page 2 PDS :: R: O.RT'i:jO_i.NT .TAL LY. S H E ET PiPei--4;5 inS-.--.-' :i2~6:-ppf'.- !£-8b Wall :thickness: ..:: BpdY i:.--'" 0.27.1:. jnS.-.f?:UlS~&[:~.:0~ .27.i:.:i'0~-: Nominal !Di-' 3~958.ins. NS10 Norihstar .... .- BP EXPLORATION (ALASKA), INC. .- .. USA APril' 9; .2002 :::j°int: ' DePth.. ':' [eiigth~' ;MOdal .-;-.M'e&ii!~:' :N'6nii~iA|~- Nb~i~al~!-::-T~e '.':'.:N°'--~ '"!.--i:::? i-;::':.."..:..-:: '.-/::'_'-!'~: '_:i-:~. :.';iD' ~:i~:iiD.:!'i;i:i;~i ~?:~i-~iib~i:.I ~:~ii::-~'~ ......... ' f~t~"-:.:-:-:.".'-~e~t:~:: ~j~S ~.i'~::~:- ::~:~:~es~.::~: :-~"'.'1~::' :[- ::' ".:'..20,19-.~ :;.43:.3'!.::~: ':'-'::: ~3~993--;-: ~;:::~3~98.9~:: ':~:::~3~958".;~: :.-.'t.;i~ :";:-;.:::.63L50 _-~':-9:63¢:-.j:~:=:~3;99:9::~ ~..:';,.:3~9~C :~;~3~-9~8~: ~.~;:~,SOD-~::;~ pup ;~--:.'1~3-: -::,.::--:75:.86.~ ::.--::2'.~2:: ..~:;:~3~a8::. ~.;-::a;Oi:~:. ~':~.~;~3~9~ ~'~.:::~;f~Oo~: pup .::.;:.'2:.-.:~: -~':. ::~-:-Ta~a~:; :~6~;- ':-:/?-4:003~-:.:'[:;,.;.;:?a~00'0~ t~f~;~a:~-. '~:?'-3-'':':. :>-'-' :lJ 9;t4~'~' .;;~:907~:?~3:~9~0:;; ~;- ::-~3~g~:~: ?~3~,9S8~.~ -J0int.::':.'!..DePth:(.-Lehgth .Modal Mean Nominal Nominal iType ":-'No,i:' .i....: .:'."~'-: ~!:::'... :." .::':.: :':. :... ."- ID ID ID OD feet ' "feet:..- . inches inches inches inches '~' :33_'----i::" :-.-1355~8.8:'"4.'2~14 3.994 3.990 3.958 4.500 :'.:'3~-:!i _~:~:1398:02.:' "-44~8Z'.. --' .: 3.994 3.99.1 3.958 4.500 :- ::: ::35;% -~.;;:1~42:~897, '40:91 ,-". '3.993 3.989 3.958 4.500 :~-:36/~: :i;:1:483-;80:' :'4-1:67 .... .3.990' '3.986 3.958 4.500 .:i-:37:i-::'!~::' :::.'i~!52:5~47_-:-:- ~'4:1.65 :-:'-'3.989' 3,986 3.958 4.500 :...~:38~::~',:- -'-_-;.i ~'7~12:- :'.41 ~28'' ;. 3:994 3~990. 3.958 4.500 :~:39:_::-'~.': --!::1608~40 ~i ::,42',30-: -~-- 4;001' 3.998 3.958 4.500 ;'~-~O::-~;::r:';J650;70:~:!~41:~45:' ::--.-,3.996 ..3.993 -3.958 4.500 i:'-.:At: ~:~: !':?il 69-2:_15.~=' !~:39;:i .1.-i_= .~: 3.993-- 3.990 3.958 4.500 742:'~:!: ::-!:-1:--731~:;-'2&i, :':::.3'-~,18'.' % 3.998- . 3.993 3.958 4.500 '-!::~3:~_:~ :::::;i117-.68~:'; "-41:i30.!" ;-:3:999 _ 3.997 3.958 4.500 :~.~'-~i:¢~ ~:i::;1:~9'~:Z41- .-_~,i::08.: -' "3;989 '3'.987 3.958 4.500 ;;'::'45~!~=.'-';~ .~::~:i850~82~.- -41,;41::. --:-.--'3.,997-, -'3.992' 3.958 4.500 ~i46::?~ .'71:892~23~i;:::41~16. '~ 4~000.- - 3.997 3.958 4.500 ';::~-~7:.:~? ?'.:193::~::~::~'-~1.~7-2 -" 3.998 : 3.995 3.958 4.500 !'.~:-~8:'_:-'!!~ :'.::~i9_"~1t~:: i::40:96' .-:-- 3.994-. 3.993 3.958 4.500 ~-~48~i-:.i :72:_0!6i0Z::~i i20~50,..-:'N/A:. N/A 2.640 4.500 ;sv i.i~49'i~:~i ;;~203E~:~-::.i'~ ;',~i1:i06:::: ;:-'?-3~986 3.985 3.958 4.500' i~:::S0:?~ :~!-'--207_..~3::_! 'i~!-~§3:'-~. ;-- S"3,990 3.987 3.958 4.500 !i~1i'~;~ i:~!:2:1~::i.9:~262: ~:4:i'~:,-;:i! ;~;3.986 .3;980 3.958 4.500 i:~:5~-:~i :~i~21~_0.-~90:~: ~:~2~::---:~-':-~ 3.984- -'.3.982 3.958 4.500 i:!!.5~!~¥? ~-:!::2202:~:i:2::-: -:-~1~:12'::' i:73.984.: '1.3.981 3.958 4.500 ~ ~i:.'.:22~3~24.;:.';'-40~86:~ i:-~-'-3:985' ' 3.985 3.958 4.500 ~-~5:5~? :::-!1'228:~I'0:': _-.::4~i~:5:9 :,:~i~::3:~985 - 3.982 3.958 4,500 ?:-_56~:~: ?'23:2'5~: ~';42~1:3'-. ::':3;981: ' 3.983 3.958 4.500 !!-:5.?~ ::!:2-~67;B21~" =~-1-:62_:: :i':..3;985, 3.981 3.958. 4.500 !-/:~58:~i~ -':-::~:2~09~:-'.~:.~ i:40~98." ~'::-: 3-:9.9-1-:' :': 3.988 3.958 4.500 i~::~59:.:.~ i:._:--:2.:~150742!~: ~.-':4~,-.,.'~4:; i-:::. 3;990-. "3.985' 3.958 4.500 :::._:60:~!:i :.:72492~3.6:--!~1;01..---- ~:-. :-3.978 3.975 3.958 4.500 :!.;6~.-:~i~ :::'.~2~!33~:~':~ !74_:1~:10:-:- ?.-: 3::989 ' 3.987 3.958 4.500 -i:i;627::?.: :-!'25~'_4~7=-::~i;:;4t716:: :::'" 3,984 '3.9'80 3.958 4.500 !?-'63-~;L: i:~:261:-:5~-:3:~!:_ i:~:4i~3-8'::.: .~.::::-3.984' 3.981 3.958 4.500 ~ili'--~zi-'~-~-'---:;!: :~i~265-7:":0i!.i~::.'::_4_1.~23- .~:'7:'-3:988' '3.983 3.958 4.500 :i::;;:6'5~!~!.:.i-72698;2:.4-;i:-~:4i-;67.': '" 3'.982..'. 3.980 3.958 4.500 -i:~'6~i?~'--~73'~:9j;!~ :f:41-'-::3t)~: ~'~:-3~985 '3.981 3.958 4.500 .PDS. REPORT_jOiNT=TALLY; SHEET Pipe.~: 4;5':ins ¥:12~6 ppf...?'L--80 Wall :thiC~esS:-...Body.=.O;27 l'-.h~s-: Ups~i~ 0~2:7! i. ins. NOminal. ID :.-. 3;958. ins.- ':-'= i.' i.'i Welli- .... . --'Field: 'i' :'.i --.:.:company,, :!. :. '.~".:: ~...Su~vey:Datei'; NS10 NoUhstar BP-EXPLORATION (ALASKA), INC. USA April 9,-2002 :-joint' .' D~pth..'. '"-..~'L&hgth:'- '-Modal ;. No,...,.. ...... -:.-/,-: ~t: .... feet.;. ~' i~'~eS ::~2-~-:-~ ;~:~988~75~:: :.~i::~47 -: :~ '" .75:;.:.~ ~;:;3}t3~i:8:.~ '.-4;]~:0:~ 777:,:?-~;-~-3i:95~4-7~-;. ::4i~5=1~~ ~;-;':~3~9~:~ ::=. 78:~:'~-~::~3236;9&.:-:'41L02:_-. :~-' .'~;~::.'" ;-:: '~3484;-5'0:~:~:: ::'74.i:~': :'~f /!01;::~.- :-:-:/4t8~:23:/::.--:~ ~a~: 'joint!-.'-DePth..'.::. t:en.-'Ph'- MOdal Mean Nominal Nominal Type /No;i:!-!'.:'--:.:..-:'.-'.'.:.'.'..:.': :'.'- ':' ID · ID ID OD ' - ' f~j(-' '.':-feet' inches inches inches inches ;~02. ":' -':422-5.69..--: '41':06 '."i 3.988 3.983 3.958 4.500 .1.03.: ' .:.-4266~75":i':40,.~7-" .-:.:'.3,997 3.992 3.958 4.500 .104~.!-(' ~430~i52:~-~.-'a0;43:';_ :":..3.994 3.990 3.958 4.500 ::105-/'i':-_-'a347-'~:95'-: ?i1'-:16."~.~:'.'" 3.993 3.990 3.958 4.500 --106-'~.!-i !-'~:4389;:i:!-~.~ .L42.00'::.i,-..--'3;992 3.988. 3.958 4.500 .107~!-:':!I-.-'::-4431~1].~: :39;81~:" '. -' 3.980" ~3.980 3.958 4.500 .108 ._~I':-.;4470~92-~ ~'3.9::99:-~ ":';:' 3~9973.990 3.958 4.500 :-!09=_:~ ~:-:_4~10;91.::- .:.':41:65;-: :.':'.-3.986.3.981 3.958 4.500 1-_i0i. i~ ::'i=.4.S52;;56~-:-40;79::".'::::.i 3.990' 3,986 3.958 4.500 i1:1~::~:.~ :-:-74593:35'.'--'4:i~91::;. ::.~:--3;991· 3.987 3.958 4.500 :1:12:--:; :_.'.46.3:5;26~: '_40:76:: :':' 4.004- 3.997 3.958 4.500 .1:i13!:?! .:~4~76~02:.~ :42::'~3':, -::--3-.997- . 3.992 3.958 4.500 1-1-4~-:-.'~ ::.:~4'7:--18~.I:5:::!740_'~46''- --::-3:992-.' 3.990 3.958 4.500 i;-!t5.::;;:~ .:'~:4758,611~'? ::40~64:: :i .:~i :-3.995.- -3~990 3.958 4.500 :.1ii6:-.~! ~:'4799:25i-: !:=~1 ~87 :.~ .~::; 3~99 i_' -3.990 3.958 4.500 =~:1::7~-:-~! ~::::484ii:~12:::~ +40~97:~'. :- -':- 3,994 '3.990 3.958 4.500 -1.!8'.:i~ ~:~4882'~09~L: ::'41'~-34:. ::-~- 4.00.! . - 3.998 3.958 4.500 ~1.:1~i:'.:~!~ '::~4t~23~3~;~::/~1~$4:. .::~:: 3.992 -' 3.990 3.958 4.500 7120:~:~ !~!-::~9~:9~!~ i:-"-40~96:':: ~--~' 3~994-.- . :'3.988 3.958 4.500 !i20~J!~ i!-i5005_-;93:!~:: :23~42i:-: '::"-N/A.' :. N/A 3.875 4.500 )acker :12i-::-..-_:-'~'.':'!:5029:35':!'::;~;1!1='_-;9~:!i :-~':,.._3',990 -' 3.987 3.958 4.500 ,?:.:_1_22::-.:~- !i:-.--507=..-!~i32-~:- ~:~1:-;~37 ":::/~ 3:99! ' ' 3.988 3.958 4.500 :~J:2!3i!::~. !~-:i.:5~;!~55~:::'.-:.'4~,~.~ :,~'._-:3:996 3;993 3,958 4.500 :!:2~-----'-:~ !::i:~5:1:S:4:49-~'-.:4i:~22:- :';:::'3~988: '-- 3.991 3.958 4.500 t:25:::L~ ~;::~5~19[i?~1'i ~ -'4:1:.:--':1:7~-- .-.--3~986' ' ~ .-3.986 3.958 4.500 ::!26:-:.'.::~:-i ~-';':.!~23.'6_;~I -:41:~05.:~ ::::-!.3;993:' 3.985 3.958 4.500 ~!:22~;:---:~ :~752~r~-7---~9~: ~:_'-4'I:0i-.::[=:"':: 3-.994 '" 3.990 3.958 4.500 ';i.28ii!;'f::~ :!:/53-];8:9:~ :'.~1~22-~:I-: :: ::"3:992 ' 3.988 3.958 4.500 :i:~:9!'-:~-::?::53~i6i;:: '::39~.93 ~.' -'~-. 3:990 .3,987 3.958 4.500 :1301!'.ii ~?'5=.400~09::--: :!~1.:06 ::'"?-3~995:: '- 3.989 3.958 4.500 :13 li~ ~i :!_-:-!5~'i:~ii:5-~'- '-:~53:::i- -';:.-'.'3.992- 3.989 3.958 4.500 :.i/:'3_2i~.:-~ i--::~:-5~.~!1:,687 .40~35'.:/-=:":':3:992 '3.990 3.958 4.500 :;133:!':::~ -?'5522:03 :: :-.4i ~96-~- :';?3.9983.994 3.958 4.500 :t34~::~ i:i'5563~99'=. ~4!t;.'!25"~. ::---'3:990 : . 3.986 3.958 4.500 it35i:'-_:'! 75605:24--: -4~1~1i;4"':'~';3:990 : 3.987 3.958 4.500 PDsi RERORT:::J.OI'N .TALLYI.$HEET '..PiPei:.4;SihS :. i-' ].2-:.6:PPf:' .'.: 1430 Wail-ithiCkness: i iBOdy.;i~.0,2.71.i :i'ns_.' i.__.-IJ- pset Nominal' ID;. 3.958.ins :: .-!::!"/:-?-:. '~/.:' .sUrVey. Datei': Ns'i 0 Northstar. BP EXPLORATION (ALASKA), INC. uSA APril' 9,. 2002 feet feet inches inches inches 'inches 136 5646.38 41.25 3.990 3~987 3.958 '4.500 137 5687.63 41.06 3.996 3.992 3.958 4.500' 138 5728.69 4.1.59 4.003 4.000 3.958 4.500 139 5770.28 40.23 .3.990 3.986 'i 3.958 4.500 140 5810.51 40.91 .3.996 3.987, ' 3.958 4.500 141 5851.42 4.1.59 4.002 3.998 3.958 ..4.500 142' 5893.01 .40.84 3.996 "3..991' 3.958 ...4.500 143 ,5933.85 41.34 3.992 '3.987 ' 3,958.' . 4.500 144 5975.19 41..57 3.996. 3.991' '3,.958." ~ 4.500 145' '6016.76' 4.1.73 3~993 ' 3.989' 3.958::' '.."'4.500' 146.. 6058.49 41.33 .3.99.3 "3.992. ..,3'.958.. 4..500 147' 6099.82 40.74 .3.997" .3~993' ..'3.958 4.500 :148 6140.56 41.12 3;992 I' '3.987. . .3;958,"' "4~500 149 6181'68 41.29 3.995 '3.989 3.958.., 4:500 150", 6222.97' 41.02 3.999" 3.995' ~3.9581 .... 4.500 151. 6263.99 40.66 3.991 .3.989' ~'.3.958. .4.500' 152 6304.65. 39.85 3.994, 3.990'. 3.958' 4.500 153 6344.50' '41:41 4..000 3{995 ... 3.958 "4.'500~ 154:, 6385.91 42.32 .3.989 3;986:'. ' 3.958:" 155 6428.23 42.23 .3:985.'. "3.981.. ' "3,'958 ".4,500 156 6470.46 4'1.84 '3.99i' 3.987' '. '3'.958'4.500 157" 6512.30 .4.1:48 4.001' '~'. '3;997-. .'3.'958' ., 4.500' 158.' . . 6553.78- 41.36 3.98.8 ~. 3.984' .. 3,958"..' !.'4..~00. 159 6595,14 40.64 . 3.992 3.986' r.' '.'3;9~8 ::i ..:...4;500: !~'~8~';:::! ;;:6~6~4~2~-~ !;:!39~'{' i---[.-~0:03:!:; i~:~~! ~~ ~~.-'--'~;i~ j_oint~... ...~pth: :'-Lensth.· Modal Mean Nominal Nominal Type ;-NO~':-' .:-'.:'.~.-'i:; ':i-'/:'i.."L-'. :.'-. :..' ID ID ID OD ~t .... -feet- '-_-inches inches inches inches 171'~ '--": ':i. 7085~45~;;-40~66'!..' 4,008"'4,006 3,958 4,500 ;!72--"::~: _-'-7126~1~1':i-.;40i66:'. '".: 4~007 4,004 3,958 4,500 -:1--73:.~:i~ ;':.-71~7_7" 40,98 ' -4.010 4.007 3.958 4.500 .1:714:'. :=.-'-::.! .:-..:7~Z07~75~' :4-1~08:- " :_4.007 4;005 3.958 4.500 ':=i:~5::~:;=i:::c72~!8~83;'. '.~2;00 [' !'--4.0044.001 3.958 4.500 :1.:76!-..~iii-':7290;83} 41:i,0:-. c}-. 4,006 4.003 3.958 4.500 'i:77:'~ii';, ~33_'1';93_-. "41!~05.~ :.':.-:'4;012 .4.009 3.958 4.500 :;1~:78~-:-'_-_-'i'~' ~::73~2~98;-' 40;6i?: -.:-'-. 4~007. .. 4.003 3.958 4.500 ,~79::._--/~ ~:~-..7:_4:1;3~59::? ~:.42;077 ("::4;004 ' 4.001 3.958 4.500 ~i':80~:}' '-_'-:~'7455~66t..i .-:_41~05-~:.'-::::-~4;0:13 - '4.008 3.958 4.500 ~1:8!~t~:- ~7496:-71:c: ~tl;;20.~i '"'.::4.0.11 .4,008 3.958 4.500 182i=-'~ -7537~91.;;:;::41~04--.:'--i. 4.0'10 4.005 3.958 4.500 :~183:;!i?: ::-.~7578;95-::'~ :-41~_08:-~ :=~':-.4~009-4.006 3.958 4.500 :.!'~.-i:'i -'_-'7620~03~:_ 4i-;53.~':'4,006- '. 4,002 3.958 4.500 :-185~'~:i :_~.7661~56~i}41-i~42:.' :: 4.004 '4.001 3.958 4.500 ~i:86~'_-=-~ !.:::7703~03} -:4~!:33.':: :'. 4;000 :' ' ~ 3,998 3.958 4.500 -18~::i:~: /~7~ii.:"'"4i'~57~:..:'' _4.008' .' 4.007 3.958 4.500 il-88~:~',!:-~7~85~3}:-.i.i~1::~6 ,;: "'--4.006 '4.001 3.958 4.500 ;}~1:89._¥:{ 77_ 8-' -2~1:9~: :::~:1:~;1'2' L-; :::4;009--: ~ 4.004 3.958 4.500 ~'i-:9.b;:-':~ _;=::-~i'3'i~. ':40;92:'.. ?;~ 4:.007 "'4.004' 3.958 4.500 !~i9i~::~'~:'}7~23i~: ~.~'2_'-~59.:: /---:'~.'_3.993- ': 3.991 3.958 4.500 !!-9~i:'_':~;:;~779'-51i~2:~!';~3;7.--~7:01~:. .-?.4,009 "4.000 3.958 4.500 ~.i:92;1; :~;?~8~,52:-:i :'!~:::7.~52:/ '-_:-~3;992.' -, 3.996 3.958- 4.500 ~p ~i:92}~i!:;~997.;0~4.~~'-~;$2,:i[!I::;'N/A-':: -' N/A' 3.725 4.500 :n 1192~ii-'.?~_c~9.~:$6--:'~ :.NJA?- !'~-.--:.'N/A-'.': .iN/A '3.958 4.500 de8 Memory Multi-Finger Caliper Log Results Summary Company: BP EXPLORATION (ALASKA), INC. Well: NS10 Log Date: August 5, 2002 Field: Northstar Log No.: 4782 State: Alaska Run No.: 2 APl No.: 50-029-22985-00 Pipe1 Desc.: 4.5" 12.6 lb. L-80 BTC-M Top Log Intvll.: Surface Pipe1 Use: Tubing Bot. Log Intvll.: 8,013 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 4.5" tubing is in good to fair condition. Penetrations from 20% to 41% are recorded intermittently throughout the tubing. The damage appears in the form of General Corrosion with deeper Isolated Pitting. The remainder and majority of the tubing logged is in good condition with respect to corrosive damage. No significant areas of cross-sectional wall loss are recorded. Deposits restrict the Minimum I.D. to 3.63" in joint 135 @ 5,618.' A comparison between this log and the previous log run on this well (April 9, 2002) indicates no increase in corrosive damage. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (41%) Jt. 29 @ 1,231 Ft. (MD) Isolated Pitting (37%) Jt. 77 @ 3,235 Ft. (MD) Corrosion (35%) Jt. 18 @ 777 Ft. (MD) Isolated Pitting ' (34%) Jt. 11 @ 489 Ft. (MD) Isolated Pitting (33%) Jt. 138 @ 5,768 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 3.63" Jt. No other significant minimum I.D. restrictions are recorded. 135 @ 5,618 Ft. (MD) Field Engineer: D. Cain Analyst: M. Lawrence Witness: S. Farris ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-maih PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 PDS Report Overview Body Region Analysis Well: NS10 Survey Date: August 5, 2002 Field: Northstar Tool Type: MFC 24 No. 00387 Company: BP EXPLORATION (ALASKA), INC. ]'ool Size~ 1.69 Country: USA No. of Fingers: 24 Ana!yst~ M: ! awre~)ce 7 ubii~g: Nora. OD Weight ~ade a Thread ~om.tD ~NomJ Up'et 4.5 ~ns 1~:6 ppf L-80 B'FGM 3:9S8 !~)s 43 ins 1.2 !ns Penetration and Metal Loss (% wa[[) ~ penetrati( n body~ metal loss body 200 150 100 50 0 0 to t to 10 to20 to 40 to over 1% I0% 20% 40% 85% 85% ] pene. 4 53 114 28 1 0 loss 9 19l 0 0 0 0 Damage Profi[e (% wale 5( 100 Damage Configuration ( body ) 150~ 100 5O 0 N~m~r of i0ints ct~m~ed iiot2i = i 2a) 121 3 0 0 0 97 146 0 Bottom of Survey = 191,3 Analysis Overview page 2 Well: NS10 Field: Northstar Company: BP EXPLORATION (ALASKA), INC. Country: USA PDS Report Overview Body Region Analysis Survey Date: August 5, 2002 Tool Type: MFC 24 No. 00387 Tool Size: 1.69 No. of Fingers: 24 Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread 4.5 ins 12.6 ppf L-80 BTC-M Nom.ID Nom. Upset Upper len. Lower len. 3.958 ins 4.5 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) penetration body ~ metal loss body 200 150 100 50 0 I. 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 200) pene. 4 53 114 28 I 0 loss 9 191 0 0 0 0 Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 124) 121 3 0 0 0 Damage Profile (% wall) penetration body ~ metal loss body 0 50 100 48 97 146 0 Bottom of Survey = 191.3 Analysis Overview page 2 Well: NS10 Field: Northstar Company: BP EXPLORATION (ALASKA) INC. Country: USA PDS Caliper Statisitical Evaluation Report Survey Date: August 5, 2002 Tool: MFC 24 No. 00387 Tool Size: 1.69 inches Tubing I.D.: 3.958 inches 0.24 0.19 0.14 0.09 0.04 0.1 Percent Probability of Hole 1 u 20 50 oo [ Standard Deviation 1 10 100 Average Rank Maximum Probable Penetration* 0.113 inches (41.7 % Wall Thickness) Percent Probability of Recording a Hole* Less than 10% * Derived from data with average rank value less than or equal to 20. PDS RE?ORT JOINT TABULATION SHEET Pipe: 4-.5 ins 12.6 ppf L80 BTC-M Well: Wall thickness: Body = 0.271 ins Upset = 0.271 ins Field: NO~Tlhlat ID: 3,958 ins Company: NS10 Northstar 8P EXPLORATION (AMxSKA), tNC,~ penetration body 1.2 Country: USA Survey Date: August 5, 2002 PenetrafioH MelalPro action x4111lmufl Bd@Ua Bod~ (-ping ~odv ID Comrnenl ~ 0 4 0 5 6 10 12 0 13 14 18 20 21 .O5 20 2 0 .03 12 a C .04 14 .09 34 0 0 )3 .05 .04 15 3 0 .uo _ 3.84 Shallow pitting. Lt, .08 30 3 O .10 3.82 Corrosion Lt. Deposits. ~O4 t 4 3 0 ·I 2 3.82 Shallow pitting, l.t. Deposits. .06 21 ~ .09 3.86 Isolated pittiHg. LI, .04 16 _ (: 07 _ 3.84 Shallow pitung. Lt. Deposits. .04 15 i C .03 12 3 .04 I5 3 .08 29 .03 12 3 .03 tt) 2 .10 35 2 ,06 24 3 .04 16 3 08 31 3 .06 3.85 Isolated pitting. Lt. Deposits. .0h 3.86 Shallow pitting. Lt. Deposits. .O8 3.85 Shallow pitting. .06 3.87 Isolated p~ttlng. Lt. Deposits_ O7 3.86 Shallow pitting. Lt. .07 3.87 ~-naHow pitting. Lt. Deposits. C .09 ~.85 Shallow p*ttmg. Lt. 07 .I 3.83 iso~a~en p~mng. Lt. Deposits. .10 3.82 Shallow pitting. Lt. Deposits. 38 .07 3.84 LL Deposits. O 09 3.82 Corrosion. lt. Deposits. 10 .1 J 3.77 Isolated p~ttmg, Lt. Deposits. C .08 3·83 Shallow corrosion. Lt. Deposits .07 .11 3.82 Isolated pitting. J t. Deposits. 22 ) 0 05 18 4 _ .1 ¢.80 Shallow pitting, lt. Deposits. 23 _ C .03 12 C .IO J.83 Shallow pitting. Lt. Deposits. ~ 0 .03 1 ] 3 35 .09 3.82 LL Deb)sm z2 3 C 05 19 2 t .09 3.85 Shallow pitting, Lt. Deposib. 26 0 C .03 13 .3 C .08 3.83 Shallow pmm~ Lt. Deposits. 27 ] ]2 .05 18 3 .05 .09 3.82 Shallow pitting, Lt. Deposits. 28 0 £ .04 a 2 135 .14 3.80 Shallow p~tting. N. Deposits. 29 38 .11 '~ ~ £ .11 3.81 related pitting. Lt. Deposits, 30 C .04 I6 3 ( .10 3.82 Shallow pitting, Lt. Deposits. 31 0 C .u4 14 3 0 .08 3.79 Shallow pi2ing. Lt. 32 ~b 21 3 0 .07 g.84 lso~a[ea pitting, Lt. Deposits. 33 .04 14 3 _ .14 3.80 Shallow pitting. Lt. Deposits. 34 03 C .04 L* ~ .08 .12 3.80 Shallow pit'ting, Lt. Deposits. 35 ,04 .05 19 4 .1 t 08 1.83 Shallow pitting Lt. Deposits. 3E 0 ')2 03 I0 3 .Of> .08 3.83 Lt. Dins)sits 37 0 C .08 28 3 .07 ~ 3.82 Isolated pitting, Lt. Deposits. 38 0 _ .05 20 2 .06 .08 3.84 Isolatec pitting. Lt. Deposits. 39 0 0 06 23 ~ 0 .09 3,84 solatec pitting, rt. Deposits. 40 0 .03 .03 13 4 .06 .10 3.81 Shallow pitting. Lt, 41 0 ( .04 I4 ~ 0 l 1 A82 Shallow pitting, it. l)eposits. 42 .02 .05 iT ~ .06 .It) 3.8l Shallow piie~g, lt. Deposits. 43 0 0 .04 15 3 .05 .07 3.86 Shallow pitting. LI. Deposits. ~.4 0 ~. t !3 3 0 .09 3.82 Shallow pitting. Lt. Deposits. 45 O 0 '04 15 4 .1(' 3.83 Shalto¥~ piing 4t 0 0 .03 t 1 3 .08 .06 3.84 LL Deposits 47 0 .03 .03 l 1 2 ,05 .06 3.85 Lh Deuoslts. ~ metal loss body Damage Profile (% wall) 50 t00 Pipe Tabulations page I PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins ~ 2.6 ppf L-80 BTC-M VVdl: NSIO Wail thickness: Body = 0.2.7l ills Upset = 0.271 ins Fie[d: Northstar Nominal ID: 3.958 ins Company: BP E×PLORATJON (ALASKA), JNC.~ penetration body Country: USA ~ meta[ Joss body 54 ~ ) 34 3 3 0 37 3.85 ShaJlog piing Lt. DeposiU. J6 0 0 33 0 3 36 3.87 Lt. Deoos~ts 73 0 O 34 16 3 0 .07 3,85 Shallow pitting, LL Deposits. 7b ( 0 J4 14 3 0 .08 3.85 Shatlo~ piing. L[, Deposits. 70 0 )2 9 3 0 .05 3,89 ~u 0 .03 12 2 )7 ,07 3.84 Shallow p~ttmg. L[. Deoos~[s, q5 ~ .04 I3 2 0 .09 3.84 Shallow p~amg. L~. Deposits Pipe Tabubtions page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 12,6 ppf L-80 BTC-M Well: NS10 Wall thickness: Body = 0.271 ins Upset = 0,271 ins Held: Northstar Nominal iD: 3.958 ins Company: BP EXPlORATiON (ALASKA), INC.t~?e~ penetration body Country: USA ~ metal loss bocly Survey Date: August 5, 2002 No. umse~ Bd@UB Body Loss Cphtg Bod~ D Comments % wall % inchesrochesmoues S0 [00 97 C ) 03 /( 2 ) )5 3.86 ~t 0:: 9 3 ,06 .05 3.8( 99 C 3 .04 14 a )7 3.85 gha]lo~ pitting LL Deaoslm. 100 0 .0- [0 3 3 l l 3.84 Lt, Deposits 10 £ .0: 1 ( 2 ) U4 3.87 102 0 J .02 8 o ) 36 3.85 Lt. IJeoost{s 10: .0) 12 3 ) ,07 3.86 Shallow JIt[Nlg. Lt. Deposits. 104 C ) .03 l( 2 3 )4 3.89 105 £ ~, ,0 13 _ ') J0 3.8 Shallow ~J~ing. Lt. Deposits. !06 0 .03 [2 ~ 3 )7 3.85 Shallow pitting. L Deposits. 107 J .05 3 0 .08 3.86 Lt. Deuosns. 108 C 0 05 18 3 3 36 3.82 Shallow pitting. EL Dq; ~slts, 109 t) 04 15 2 0 }5 3.84 Shal[m~ pdting 1 l0 C ) 3: l£ 3 J )5 ~.o~ l t ( ) ,03 12 3 .07 .06 3.87 Shallow pimng. Lt. ue= )sits. l l 2 £ 3 )b 23 2 3 35 3,87 sola[ea plmng. 1t3 0 .06 .0B 2l J 08 3.88 Shaltox5 plt~ng, t. Degoslls. 114 ( 32 [ 4 0 34 3.87 It5 C 0 3~: 11 ~ 0 35 3.87 l 16 ~ 03 t 3 ? ~7 L86 Shallow pitting, t. Deposits. 117 C 3 )6 21 2 3 35 3.86 isolated plmng. 1 t [ C ) 35 l 7 2 .04 3.87 alqallo¼ oitt ng t 19 C ) )~ I I 2 0 .06 3.87 Lt. D~. 3oslts, 120 ( 3 34 6 2 0 .05 3.86 Shallow pitting. 120.I C ) 0 0 C 0 0 3.88 PACKER t2 02 = 3 .0b 3.87 122 ( 3 J2 8 2 0 .07 3.86 Lt. Deposits. t2' £ ) 03 2 0 .08 3.85 it. I)eoosl[s. 124 t ) 34 1 ( 3 07 )( 3.84 Shallow pitting. L t. Deposits. ) J )~ l 2 0 .05 3.87 Lt. De ~os~ts. 126 0 3 06 2 3 0 [0 3.83 solated pitting, t[, Deposits. 127 ~ .03 .u. I ~ 2 .05 )5 3.87 Shallow p~ulng. Lt. Doposits. 128 0 } ,05 20 3 0 39 3.84 Isolated pitting Lt Deposits. J 0 3 ( 0 ( 0 0 3 ( 0 0 3 { 0 ( 0 )~ l( 3 0 .05 3.80 _t. Deoosl[s 02 9 2 0 .12 3.79 Lt. Douoslts. 32 8 2 0 .08 3.84 Lt. ue ooslts. 34 13 2 0 ,06 3,86 Shallow pitting Lt. DeDosiU. 32 8 3 0 .07 3.86 Lt. Deoosits. 36 -;~ 3 O ,06 3.84 lsolatea plttm8. t. Deposm 04 16 ,z 05 33 3.63 Shallo,~ plmng De[:as~ts. 33 3 0 .08 3.84 Lt. De 0os~is. 32 9 3 0 .07 3,84 rt. Dcoos~m. )9 3_ 2 .05 ,07 3.87 isolated pitting. Lt. Deposits. )4 14 3 0 .08 3.86 Shallo, p~mng [, Deaos~ts. 3: 3 0 .07 3.86 tr. De aDS[re. I42 143 0 0 36 24 4 ,09 [44 ; ,03 l0 2 0 145 ,u~ o 3 0 0 34 15 3 .0/ ~.87 ~hallo~ pitting. ,03 11 3 .06 ,08 3.85 Lt. Demoslm. 12 3.8l Isolated p~mn8. L[ Deposits. .10 3.87 Lt. Deooslts. .06 3.88 Pipe Tabulations page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppf L-80 BTC-M Well: Wall thickness: Body = 0.271 ins Upset = 0.271 ins Field: Nominal ID: 3.958 ins Company: Survey Date: omi Penetration Metal Proiection I'*oUDSe[ Bdg~)tJ[) Body LOSS CDt7 -~ 8od E Comments incnesii~ches inches% % 146 .04 13 3 .07 .04 3.88 Shallow ~-'7 0 ( .02 8 3 .06 3.90 _. Deposits. 48 ~ .04 13 3 £ .09 3.87 Shallow pltling. LL De[)os~ts. 49 0 C .03 13 _ [ 08 1.85 Shallow pining. L[, Deoosl[s 150 0 C .04 16 ' .05 06 3.89 Sl~aibw pitting .... Del 151 .06 24 4 .08 .07 L89 Isolated pitting Lt. Deoosits. 152 0 C .03 13 2 ( .06 3.90 Shallow p~mng. Lt. DeDos~[s. 153 0 0 .0b 18 3 0 .08 3.88 Shallow p~mng. Lt. De[)oslts. 154 £ .03 I0 2 0 08 t.9( LL De~)os~ts 155 0 : 8 3 ( .12 3.8E L~. Depos~[s 15~ 0 C .02 9 ~ £ .0[ 3.89 L~. Deposits 0 ( .06 21 2 0 .u~ 3.89 Isolated pltllng Lt. Degoslts. 0 0 .03 10 4 0 .10 3.9C L1 D~ ~osl[s 0 .02 9 3 0 .21 3.75 ~aepos~[s 0 C 04 14 3 0 .lf- ~.82 ShalIo~ plmng Lt. Deposns. 0 £ .03 t0 3 0 .Oe 3.9£ Lt. Deoos~ts 0 l .03 12 3 .06 .04 1.89 Shallow p[nln8 157 158 159 I60 I61 162 163 164 165 166 167 168 165 17C 172 173 I74 175 17~ 177 I78 79 .03 12 .u4 t 5 .03 10 .03 12 .03 12 .04 13 .05 18 04 .03 10 .06 2 I .05 18 .05 18 .02 9 .04 [4 03 10 .uo L91 Shallow pitting, Lt. Dm3osits. .06 3.91 Shallow pit[lng Lt. Deposits. .t ! 3.88 Lt. Deposits .1C 3.87 Shallow p~mng Lt. Depos~[s. .04 3.91 ShaiIo~ pimng .08 3.87 Shallow plttmg. Lt. Deposits. .0c 3.88 Shallo~ plumg Lt Deoost[s .11 3.84 Shallow pilting Lt Deoosl~s. .0b 3.92 .07 3.92 Isolatec pitting. Lt. Deposits. .08 3,9 Shallo,~ alttmg _. Deooslts .05 3.90 Shallo,a pitting. Lt. Deposlts. 07 3.9£ Lt. Deposits. .13 3.84 5hallow plmng. Lt. Deposits. 1( 3.91 Lt. De~ osits .07 3.89 Shallow p~tttng Lt. Deoos*ts. .07 3.92 t~. Deoost[s. I80 0 .03 I2 3 ,05 10 3.90 Shallow p~thng. Lt. Deposits. 181 0 O, .06 22 2 .06 ~ 3.84 sotatea pitung It Deooslts. I82 0 0 .05 17 ~ 0 .07 3~92 Shallow plttmg. Lt. Deuosits. 183 0 .05 .05 20 I .07 .09 3.92 Shallow pitting. Lt. Deposits. 184 t~ 0 .03 12 3 .07 24 3.74 Shallow p~tfing. Deposus. 185 0 ( .03 lC 2 ) .06 3.92 Lt. Deposits. I86 0 .03 .05 20 ~ .08 .11 3.89 tsobted pitting, Lt. Depos~[s. 187 .0(.21 0 .07 3.92 Isolated pitting. Lt. Deposits. lgf ~ .05 '- i ,07 .06 3.92 Shailow pining, t.t. Deposits. [B(~ 0 0 .03 10 3 .14 .10 3.88 Lt. Deposits. 19C 0 0 .03 I 1 ~ .06 .07 3.91 Lt. Deposits. 191 0 .02 04 16 3 .05 .10 3.9C Shallow pi~.ing. 12. Demosits. 192 0 0 .02 c a 17 3,83 Det]osns. 192.1 0 .02 6 ) 0( 3.95 PUP L[. Deoosns 192.2 0 0 0 ( ) 0 ~.72 XN NIP 192.3 0 0 3 C (~ 0 t. 3.98 A/LEG NS10 Northstar BP EXPLORA~[JON (Al ASKA), tNC.~e~? penetration body USA ~ metal loss body August 5, 2002 Damage Profile ~ wall/ 0 5C 100 Pipe Tabulations page 4 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 1 * pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference. Damage repo~n§ threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line lehigh = 0.268 feet. Pipe Tabulations 5 PDS Report Cross Sections Well: NS10 Survey Date: August 5, 2002 Field: Northstar Tool Type: MFC 24 No. 00387 Company: BP EXPLORATION (Al ASKA), INC. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tub!iTg 45 52.6 ppf L-80BPCM Ana!yst~ M. Law~e!~ Cross Section for Joint 29 at depth 1230,9 ft Tool speed: 66 Nominal tD = 3.958 Nominal OD = 4500 Remaining wall area = 96 % Tool deviation = 9 o Finger 23 Penetration: 0,11 ins Isolated Pitting 0,11 ins = 41% Wall Penetration HIGH SIDE = UP Cross Sections page PDS Report Cross Sections Well: NS10 Survey Date; August 5, 2002 Field: Northstar Tool Type: MFC 24 No, 00387 Company: BP EXPI~ ORA FION (ALASKA), INC. Tool Size: 1.69 Country: USA No. of Fingers: 24 [ L~2!ng~ 4:5 !ns t2:6 F~t?f ! -~ BTC:M Apa!),s~i M ~>ylepce Cross Section for Ioint 135 at depth 5-618.14 ft Tool speed '= 62 Nomil~al tD = 3?=58 Nominal OD = 4,500 P, emaining wall area =, 98 % Too! deviation = 37 ° Finger 24 Proiection = 0.332 ins Deposits Minimum I.D. = 3.63 ins ttlGlt SIDE = UP O-oss Sections page 2 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BTC-M Wall thickness: Body -~ 0.271 ins Upset -- 0.271 ins Nominal ID: 3.958 ins I Joint Depth Length Modal Mean 'Nominal Nominal Type ~ No. ID ID ID OD feet feet inches inches inches inches 1 28.60 31.18 3.954 3.9491 3.958 4.500 1.1 59.78 9.47 3.952 3.954I 3.958 4.500 pup 1.2 69.25 3.08 3.954 3.976 3.958 4.500 pup 1.3 72.33 3.17 3.944 3.972 3.958 4.500 pup 2 75.50 41.72 3.956 3.953 3.958 4.500 3 117.22 40.98 3.944 3.939 3.958 4.500 4 158.20 41.58 3.942 3.940 3.9.58 4.500 5 199.78 41.05 3.942 3.939 3.958 4.500 6 240.83 40.93 3.947 3.943 3.958 4.500 7 281.76 41.36 3.948 3.943 3.958 4.500 8 323.12 41.99 3.956 3.954 3.958 4.500 9 365.11 41.38 3.949 3.944 3.958 4.500 10 406.49 41.31 3.953 3.950 3.958 4.500 11 447.80 41.51 3.953 3.952 3.958 4.500 12 489.31 41.02 3.944 3.943 3.958 4.500 13 530.33 41.12 3.949 3.945 3.958 4.500 14 I 571.45 41.34 3.949 3.944 3.958 4.500 15I 612.79 40.99 3.940 3.935 3.958 4.500 16 653.78 41.61 3.944 3.940 3.958 4.500 17 695.39 41.63 3.940 3.935 3.958 4.500 18 737.02 41.15 3.945 3.940 3.958 4.500 19 778.17 40.91 3.934 3.930 3.958 4.500 20 819.08 41.10 3.933 3.930 3.958 4.500 21 860.18 41.18 3.932 3.928 3.958 4.500 22 901.36 41.58 3.938 3.934 3.958 4.500 123 942.94 40.89 3.932 3.928 3.958 4.500 I 24 983.83 41.76 3.929 3.926 3.958 4.500 25 1025.59 43.40 3.936 3.933 3.958 4.500 I 26 1068.99 40.31 3.933 3.9311 3.958 4.500 27 1109.30 40.83 3.941 3.937I 3.958 4.500 28 1150.13 41.10 3.938 3.936 3.958 4.500 29 1191.23 40.97 3.939 3.938 3.958 4.500 i 30 1232.20 41.71 3.935 3.933 3.958 4.500 31 1273.91 41.08 3.935 3.930 3.958 4.500 132 1314.99 39.89 3.935 3.932 3.958 4.500 Well: Field: Company: Country: Survey Date: NS10 Northstar BP EXPLORATION (ALASKA), INC. USA August 5, 2002 Joint Depth Lensth Modal Mean Nominal Nominal Typ~- No. ID ID ID OD feet feet inches inches inches inches 33 1354.88 41.20 3.936 3.933 3.958 4.500 34 1396.08 40.94 3.940 3.933 3.958 4.500 35 1437.02 40.79 3.937 3.934 3.958 4.500 36 1477.81 41.43 3.935 3.933 3.958 4.500 37 1519.24 42.34 3.934 3.931 3.958 4.500 38 1561.58 40.88 3.940 3.934 3.958 4.500 39 1602.46 41.98 3.944 3.940 3.958 4.500 40 1644.44 41.23 3.939 3.936 3.958 4.500 41 1685.67 40.89 3.938 3.935 3.958 4.500 42 1726.56 41.56 3.942 3.939 3.958 4.500 43 1768.12 40.61 3.944 3.942 3.958 4.500 44 1808.73 40.96 3.935 3.932 3.958 4.500 45 1849.69 41.63 3.938 3.933 3.958 4.500 46 1891.32 41.11 3.944 3.938 3.958 4.500 47 1932.43 41.60 3.944 3.93 7 3.958 4.500 -- 48 1974.03 40.44 3.944 3.940 3.958 4.500 -- 48.1 2014.47 20.88 2.640 2.640 2.640 4.500 ~sv 49 2035.35 41.15 3.938 3.936 3.958 4.500 50 2076.50 41.17 3.942 3.939 3.958 4.500 51 2117.67 41.52 3.933 3.930 3.958 4.500 52 2159.19 40.89 3.938 3.935 3.958 4.500 53 2200.08 41.39 3.937 3.934 3.958 4.500 54 2241.47 41.30 3.942 3.938 3.958 4.500 -- 55 2282.77 41.98 3.942 3.939 3.958 4.500 56 2324.75 41.24 3.945 3.942 3.958 4.500 57 2365.99 41.71 3.946 3.941 3.958 4.500 58 2407.70 40.40 3.942 3.938 3.958 4.500 59 2448.10 41.87 3.938 3.935 3.958 4.500 60 2489.97 41.16 3.933 3.930 3.958 4.500 61 2531.13 41.63 3.946 3.943 3.958 4.500 62 2572.76 40.45 3.946 3.944 3.958 4.500 63 2613.21 41.69 3.943 3.940 3.958 4.500 64 2654.90 40.52 3.948 3.945 3.958 4.500 65 2695.42 41.85 3.944 3.942 3.958 i 4.500 66 2737.27 41.17 [ 3.946 3.943 3.958I 4.500 ---- Joint Tally page 1 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BTC-M Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins J°int I DepthNo. I Length ModaliD MeaniD NominaliD NominaIOD Type I feet feet inches inches inches inches 67 . 2778,44 42,07 3,945 3,943 3,958 4,500 68 12820.51 41.85 3.946 3.944 3,958 4,500 69[ 2862.36 40.67 3.941 3.939 3.958 4.500 70 2903.03 42.12 3.944 3.941 3.958 4.500 71 I 2945.15 41.22 3.949 3.944 3.958 4.500 72 I 2986.37 41.68 3.943 3.938 3.958 4.500 73 13028.05 41.40 3.944 3.941 3.958 4.500 74 3069.45 40.62 3.948 3.945 3.958 4.500 75 3110.07 40.66 3.946 3.943 3.958 4.500 76 3150.73 44.28 3.946 3.944 3.958 4.500 77 3195.01 41.35 3.944 3.941 3.958 4.500 78 3236.36 40.77 3.947 3.945 3.958 4.500 79 3277.13 41.85 3.951 3.950 3.958 4.500 80 3318.98 41.11 3.948 3.945 3.958 4.500 81 3360.09 41.72 3.946 3.944 3.958 4.500 82 3401.81 41.55 3.946 3.945 3.958 4.500 83 3443.36 40.60 3.940 3.938 3.958 4.500 84 3483.96 41.62 3.950 3.947 3.958 4.500 ~ 85 3525.58 41.58 3.948 3.942 3.958 4.500 i 86 3567.16 41.18 3.950 3.945 3.958 4.500 87 3608.34 40.83 3.947 3.942 3.958 4.500 88 3649.17 41.85 3.941 3.941 3.958 4.500 89 3691.02 40.70 3.947 3.943 3.958 4.500 90 3731.72 41.38 3.945 3.942 3.958 4.500 91 3773.10 41.03 3.950 3.947 3.958 4.500 92 3814.13 40.93 3.939 3.936 3.958 4.500 93 3855.06 40.99 3.945 3.940 3.958 4.500 94 3896.05 40.81 3.954 3.951 3.958 4.500 95 3936.86 41.16 3.953 3.950 3.958 4.500 96 3978.02 41.46 3.950 3.946 3.958 4.500 97 4019.48 41.32 3.949 3.947 3.958 4.500 98 4060.80 41.86 3.949 3.946 3.958 4.500 99 4102.66 40.28 3.942 3.940 3.958 4.500 [100 4142.94 40.75 3.944 3.940 [ 3.958 4.500 [101 4183.69 40.85 3.949 3.945 [ 3.958 4.500 Well: NS 10 Field: Northstar Company: BP EXPLORATION (ALASKA), INC. Country: USA Survey Date: August 5, 2002 Joint~ Depth Length Modal Mean Nominal iNom~nal Type No. ID ID ID I OD feet feet inches inches inches inches 102 4224.54 40.83 3.947 3.944 3.958 4.500 103 4265.37 40.41 3.951 3.947 3.958 4.500 104 4305.78 41.11 3.950 3.946 3.958 4.500 -.. 105 4346.89 41.20 3.953 3.948 3.958 4.500 106 4388.09 41.31 3.945 3.941 3.958 4.500 107 4429.40 40.13 3.940 3.938 3.958 4.500 108 [4469.53 40.55 3.945 3.940 3.958 4.500 109 i 4510.08 41.78 3.939 3.935 3.958 4.500 110i 4551.86 41.32 3.946 3.943 3.958 4.500 111 4593.18 41.56 3.943 3.943 3.958 4.500 112 4634.74 40.73 3.953 3.948 3.958 4.500 113 I 4675.47 41.81 3.952 3.946 3.958 4.500 114 4717.28 40.86 3.951 3.948 3.958 4.500 115 4758.14 41.23 3.945 3.943 3.958 4.500 116 4799.37 41.61 3.946 3.944 3.958 4.500 -- 117 4840.98 40.80 3.948 3.943 3.958 4.500 118 4881.78 41.81 3.953 3.951 3.958 4.500 119 4923.59 41.12 3.941 3.940 3.958 4.500 120 4964.71 41.18 3.947 3.943 3.958 4.500 , 120.1 5005.89 23.21 3.875 3.875 3.875 4.500 )acker 121 5029.10 41.44 3.944 3.943 3.958 4.500 122 5070.54 41.45 3.946 3.941 3.958 4.500 123 5111.99 41.85 3.953 3.947 3.958 4.500 124 5153.84 40.33 3.947 3.945 3.958 4.500 125 5194.17 41.09 3.946 3.940 3.958 4.500 126 5235.26 40.87 3.937 3.935 3.958 4.500 127 5276.13 41.16 3.950 3.944 3.958 4.500 128~ 5317.29 41.03 3.939 3.938 3.958 4.500 129 15358.32 41.05 3.942 3.938 3.958 4.500 130 [ 5399.37 41.60 3.950 3.944 3.958 4.500 131 5440.97 40.94 3.944 3.943 3.958 I 4.500 132 5481.91 40.83 3.950 3.944 3.958I 4.500 I Joint Tally page 2 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BTC-M Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 136 5646.09 40.90 3.956 3.953 3.958 4.500 137 5686.99 41.48 3.958 3.953 3.958 4.500 138 5728.47 41.04 3.967 3.964 3.958 4.500 139 5769.51 41.58 3.960 3.956 3.958 4.500 1140 5811.09 40.40 3.965 3.962 3.958 4.500 141 5851.49 41.51 3.977 3.973 3.958 4.500 '142 5893.00 40.71 3.972 3.968 3.958 4.500 1143 5933.71 41.30 3.974 3.970 3.958 4.500 J 144 5975.01 41.42 3.980 3.976 3.958 4.500 145 6016.43 41.75 3.982 3.979 3.958 4.500 146 6058.18 41.54 3.986 3.984 3.958 4.500 147 6099.72 40.74 3.984 3.981 3.958 4.500 148 6140.46 41.38 3,985 3.982 3.958 4.500 149 6181.84 41.42 3.987 3.984 3.958 4.500 150 6223.26 40.85 3.991 3.988 3.958 4.500 151 6264.11 40.49 3.987 3.985 3.958 4.500 152 6304.60 39.79 3.990 3.988 3.958 4.500 153 6344.39 41.36 3.997 3.994 3.958 4.500 154 6385.75 41.47 3.990 3.986 3.958 4.500 155 6427.22 41.16 3.990 3.988 3.958 4.500 156 6468.38 41.141 3.990 3.988 3.958 4.500 157 16509.52 43.22J 3.998 3.995 3.958 4.500 3.9943.9903.9584.500 i158 6552.74 41-31I 1596594,0541.043.9903.9873.9584.500 1606635.0939.783.9903.9863.9584.500 11616674'8741'0913'9913'9883'9584'500 4.500 162 I 6715.96 41.56 3.999 3.994 3.958 1163 6757.52 41.42 I 3.993 3.992 3.958 4.500 41.02I 4.001 3.994 3.958 4.500 164 6798.94 165 6839.96 39.95 3.990 3.992 3.958 4.500 · 166 6879.91 41.62 3.996 3.993 I 3.958 4.500 3.995I 3.958 4.500 167 I 6921.53 42.00 4.007 168I 6963.53 39.09 3.992 3.989 3.958 4.500 169 7002.62 41.42 3.995 3.992 3.958 4.500 [ 170 [ 7044.04 41.20 I 4.002 3.996 3.958 4.500 Well: Reid: Company: Country: Survey Date: NS10 Northstar BP EXPLORATION (ALASKA), INC. LISA August 5, 2002 Joint Depth Length Modal Mean !Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 171 7085.24 41.13 4.000 3.997 3.958 4.500 172 7126.37 40.13 3.994 3.992 3.958 4.500 173 7166.50 40.74 3.996 3.993 3.958 4.500 174 7207.24 42.10 3.996 3.990 3.958 4.500 -- 175 7249.34 41.26 3.987 3.986 3.958 4.500 176 7290.60 41.69 3.995 3.990 3.958 4.500 177 7332.29 40.89 4.004 3.999 3.958 4.500 178 7373.18 41.24 3.999 3.995 3.958 4.500 179 7414.42 41.56 3.997 3.993 3.958 4.500 180 7455.98 40.15 4.005 4.001 3.958 4.500 181 7496.13 40.03 3.998 3.995 3.958 4.500 182 7536.16 40.74 4.001 3.999 3.958 4.500 183 7576.90 40.77 4.008 4.002 3.958 4.500 --. 184 7617.67 45.11 3.997 3.996 3.958 4.500 -- 185 7662.78 42.70 4.002 3.998 3.958 4.500 186 7705.48 35.75 3.997 3.994 3.958 4.500 187 7741.23 43.04 4.009 4.005 3.958 4.500 188 7784.27 42.11 4.002 4.000 3.958 4.500 189 7826.38 42.02 4.007 4.002 3.958 4.500 190 7868.40 40.64 4.010 4.005 3.958 4.500 191 7909.04 40.80 3.995 3.992 3.958 4.500 192 7949.84 41.69 4.008 4.004 3.958 4.500 192.11 7991.53 8.03 3.991 3.994 3.958 4.500 pup ____ 192.2[ 7999.56 6.85 3.725 3.725 3.725 4.500 ~n _. 192.3I 8006.41 N/A 3.958 3.958 3.958 4.500 ~leg____ -- Joint Tally page
