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Home My WebLink About204-252CAUTION: 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. 9 038% 37' MPU B-50 2042520 Annual EPA MIT-IA Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1960090 Type Inj I Tubing 1055 1056 1052 1050 Type Test P Packer TVD 4364 BBL Pump 5.7 IA 0 3512 3412 3406 Interval O Test psi 3500 BBL Return 3.0 OA 203 251 251 250 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2042520 Type Inj I Tubing 920 918 912 907 Type Test P Packer TVD 3890 BBL Pump 5.4 IA 17 3513 3447 3417 Interval O Test psi 3500 BBL Return 5.0 OA 147 165 163 161 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 Milne Point / MPU/ B-pad Witnessed waived by Kam St John. Chris Casey 07/20/25 Notes:Class 1 Disposal Well- MIT-IA. Well injects Slurry. Notes: Notes: Notes: B-24 B-50 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity 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. Notes:EPA Class 1 Injection well annual MIT-IA to 3500 psi. Notes: Form 10-426 (Revised 01/2017)2025-0720_MIT_MPU_B-50 9 9 9 9 9 9 9 999 99 9 9 -5HJJ 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. 0LOQH3RLQW8QLW% 37' Milne Point wells B-50 (PTD # 2042520) Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2161390 Type Inj I Tubing 664 662 659 656 Type Test P Packer TVD 3,980'BBL Pump 3.3 IA 276 3712 3662 3653 Interval O Test psi 3500 BBL Return 3.1 OA 160 160 170 170 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2042520 Type Inj I Tubing 1397 1390 1368 1344 Type Test P Packer TVD 3890 BBL Pump 4.9 IA 28 3703 3645 3619 Interval O Test psi 3500 BBL Return 5.4 OA 140 196 198 198 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 EPA Class 1 injection well annual MIT-IA to 3500 psi. AOGCC witness waived by Brian Bixby. Witnessed by EPA's Nick Bruno/James Robinson. Notes: Notes: Notes: Notes: B-50 Notes:EPA Class 1 injection well annual MIT-IA to 3500 psi. AOGCC witness waived by Brian Bixby. Witnessed by EPA's Nick Bruno/James Robinson. Notes: Hilcorp Alaska, LLC Milne Point / MPU / B Matt Ross 07/29/24 Notes: B-34 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: Form 10-426 (Revised 01/2017)2024-0729_MIT_MPU_B-50 9 9 9 9 9 9 999 9 -5HJJ B-50 EPA Class 1 injection well annual MIT-IA to 3500 psi. 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Tuesday, September 12, 2023 2:48 PM To:Darci Horner - (C) Cc:Regg, James B (OGC) Subject:RE: 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 Revised.xlsx; MIT MPU B-34 & B-50 07-19-23 Revised.xlsx Darci, AƩached are revised reports changing the type of injecƟon to “I”, as we include industrial wastewater (instead of water) for Class 1 wells. Please update your copies or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Darci Horner ‐ (C) <dhorner@hilcorp.com> Sent: Tuesday, July 25, 2023 3:53 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brenden Swensen <Brenden.Swensen@hilcorp.com>; Alaska NS ‐ Milne ‐ Wells Foreman <AlaskaNS‐WellsForeman@hilcorp.com>; Alaska NS ‐ Milne ‐ Wellsite Supervisors <AlaskaNS‐Milne‐WellsiteSupervisors@hilcorp.com>; Derek Weglin <Derek.Weglin@hilcorp.com>; Josh McNeal <jmcneal@hilcorp.com>; Alaska NS ‐ Northstar ‐ Field Foreman <AlaskaNS‐ Northstar‐Field‐Foreman@hilcorp.com>; Alaska NS ‐ Northstar ‐ Operations Leads <AlaskaNS‐Northstar‐ OperationsLeads@hilcorp.com>; Alaska NS ‐ Environmental Specialist <mpuenviro@hilcorp.com>; Chuck Wheat <cwheat@hilcorp.com>; apeloza <apeloza@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Sara Hannegan <shannegan@hilcorp.com>; Jess Hall ‐ (C) <Jess.Hall@hilcorp.com>; Matthew Ross <Matthew.Ross@hilcorp.com>; Donald Maxon <Donnie.Maxon@hilcorp.com> 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 All, 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. MPU B-50PTD 2042520 2 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. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2161390 Type Inj I Tubing 626 629 616 606 Type Test P Packer TVD 3,980'BBL Pump 2.1 IA 108 3704 3587 3556 Interval O Test psi 3500 BBL Return 2.1 OA 53 54 54 55 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2042520 Type Inj I Tubing 476 473 468 463 Type Test P Packer TVD 3890 BBL Pump 5.5 IA -7 3692 3626 3607 Interval O Test psi 3500 BBL Return 4.8 OA 124 137 137 136 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 Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Hilcorp Alaska, LLC Milne Point / MPU / B Roger Allison 07/19/23 Notes: B-34 EPA Class 1 injection well MIT-IA to 3500 psi. AOGCC witness waived by Brian Bixby (EPA witnessed). Notes: Notes: Notes: Notes: B-50 Notes:EPA Class 1 disposal well. Annual MIT. AOGCC witness waived by Brian Bixby (EPA witnessed). Notes: Form 10-426 (Revised 01/2017)2023-0719_MIT_MPU_B-50        J. Regg; 10/12/2023 Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 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: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37896 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4557 E-mail: Nolan.Vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 07/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: MPU B-50 CaliperSurvey 07-18- 2023, 07-021-2023 AOGCC TRANSMITTAL Well API # PTD # Log Date Log Company Log Type AOGCC Eset# MP B-50 50029232400000 204252 7/18/2023 READ Caliper Survey Please include current contact information if different from above. T37870 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.24 09:43:07 -08'00' 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW7XHVGD\$XJXVW$0 7R5HJJ-DPHV%2*& 6XEMHFW)Z>(;7(51$/@5(0,7,$VIRU0LOQH3RLQW&ODVVLQMHFWLRQZHOOV%%DQG%DVZHOODV 1RUWKVWDUZHOOV16DQG16 $WWDFKPHQWV0,7038%[OV[ &ƌŽŵ͗ĂƌĐŝ,ŽƌŶĞƌͲ;ͿфĚŚŽƌŶĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂǇ͕ƵŐƵƐƚϮ͕ϮϬϮϮϴ͗ϯϰD dŽ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁Z͗D/dͲ/ƐĨŽƌDŝůŶĞWŽŝŶƚůĂƐƐϭŝŶũĞĐƚŝŽŶǁĞůůƐͲϮϰ͕ͲϯϰĂŶĚͲϱϬĂƐǁĞůůĂƐEŽƌƚŚƐƚĂƌǁĞůůƐ E^ͲϭϬĂŶĚE^ͲϯϮ ,ŝWŚŽĞďĞ͕ zŽƵ͛ƌĞƌŝŐŚƚ͊dŚĞĚĂƚĂƐŚŽƵůĚďĞƐŚŝĨƚĞĚŽǀĞƌƚŽƚŚĞůĞĨƚ͘,ĞƌĞǇŽƵŐŽ͘ ŚĞĞƌƐ͕ ĂƌĐŝ &ƌŽŵ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗DŽŶĚĂǇ͕ƵŐƵƐƚϭ͕ϮϬϮϮϱ͗ϯϳWD dŽ͗ĂƌĐŝ,ŽƌŶĞƌͲ;ͿфĚŚŽƌŶĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗D/dͲ/ƐĨŽƌDŝůŶĞWŽŝŶƚůĂƐƐϭŝŶũĞĐƚŝŽŶǁĞůůƐͲϮϰ͕ͲϯϰĂŶĚͲϱϬĂƐǁĞůůĂƐEŽƌƚŚƐƚĂƌǁĞůůƐE^Ͳ ϭϬĂŶĚE^ͲϯϮ ĂƌĐŝ͕ tŝůůǇŽƵǀĞƌŝĨǇƚŚĞƉƌĞƐƐƵƌĞĚĂƚĂĨŽƌͲϱϬ͍/ƚƐŚŽǁƐƚŚĞƚĞƐƚƚŽϰϱDŝŶ͕͘ďƵƚŶŽWƌĞƚĞƐƚĚĂƚĂ͍ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ĂƌĐŝ,ŽƌŶĞƌͲ;ͿфĚŚŽƌŶĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂǇ͕:ƵůǇϮϱ͕ϮϬϮϮϰ͗ϬϭWD 038% 37' dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх Đ͗:ĞƌŝŵŝĂŚ'ĂůůŽǁĂǇф:ĞƌŝŵŝĂŚ͘'ĂůůŽǁĂǇΛŚŝůĐŽƌƉ͘ĐŽŵх͖dŽĚĚ^ŝĚŽƚŝфdŽĚĚ͘^ŝĚŽƚŝΛŚŝůĐŽƌƉ͘ĐŽŵх͖ƌŝĂŶ'ůĂƐŚĞĞŶ фƌŝĂŶ͘'ůĂƐŚĞĞŶΛŚŝůĐŽƌƉ͘ĐŽŵх͖ůĂƐŬĂE^ͲtĞůůƐ&ŽƌĞŵĂŶфWtĞůůƐ&ŽƌĞŵĂŶΛŚŝůĐŽƌƉ͘ĐŽŵх͖ůĂƐŬĂE^ͲDŝůŶĞͲ tĞůůƐŝƚĞ^ƵƉĞƌǀŝƐŽƌƐфůĂƐŬĂE^ͲDŝůŶĞͲtĞůůƐŝƚĞ^ƵƉĞƌǀŝƐŽƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх͖ĞƌĞŬtĞŐůŝŶфĞƌĞŬ͘tĞŐůŝŶΛŚŝůĐŽƌƉ͘ĐŽŵх͖ :ŽƐŚDĐEĞĂůфũŵĐŶĞĂůΛŚŝůĐŽƌƉ͘ĐŽŵх͖ůĂƐŬĂE^ͲEŽƌƚŚƐƚĂƌͲ&ŝĞůĚ&ŽƌĞŵĂŶфůĂƐŬĂE^ͲEŽƌƚŚƐƚĂƌͲ&ŝĞůĚͲ &ŽƌĞŵĂŶΛŚŝůĐŽƌƉ͘ĐŽŵх͖ůĂƐŬĂE^ͲEŽƌƚŚƐƚĂƌͲKƉĞƌĂƚŝŽŶƐ>ĞĂĚƐфůĂƐŬĂE^ͲEŽƌƚŚƐƚĂƌͲKƉĞƌĂƚŝŽŶƐ>ĞĂĚƐΛŚŝůĐŽƌƉ͘ĐŽŵх͖ dƌĂǀŝƐ^ƉĂƌŬƐфƚƌƐƉĂƌŬƐΛŚŝůĐŽƌƉ͘ĐŽŵх͖dŽŶǇDĂŶŐĂŶŽфƚŵĂŶŐĂŶŽΛŚŝůĐŽƌƉ͘ĐŽŵх͖tŝůůŝĂŵƌĂŬĞ фtŝůůŝĂŵ͘ƌĂŬĞΛŚŝůĐŽƌƉ͘ĐŽŵх͖ůĂƐŬĂE^ͲŶǀŝƌŽŶŵĞŶƚĂů^ƉĞĐŝĂůŝƐƚфůĂƐŬĂE^ͲŶǀŝƌŽŶŵĞŶƚĂů^ƉĞĐŝĂůŝƐƚΛŚŝůĐŽƌƉ͘ĐŽŵх͖ ŚƵĐŬtŚĞĂƚфĐǁŚĞĂƚΛŚŝůĐŽƌƉ͘ĐŽŵх͖ĂƉĞůŽǌĂфĂƉĞůŽǌĂΛŚŝůĐŽƌƉ͘ĐŽŵх͖ĂǀŝĚ,ĂĂŬŝŶƐŽŶфĚŚĂĂŬŝŶƐŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх͖ dŽƌŝŶZŽƐĐŚŝŶŐĞƌфdŽƌŝŶ͘ZŽƐĐŚŝŶŐĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗D/dͲ/ƐĨŽƌDŝůŶĞWŽŝŶƚůĂƐƐϭŝŶũĞĐƚŝŽŶǁĞůůƐͲϮϰ͕ͲϯϰĂŶĚͲϱϬĂƐǁĞůůĂƐEŽƌƚŚƐƚĂƌǁĞůůƐE^ͲϭϬĂŶĚE^ͲϯϮ ůů͕ DŝůŶĞWŽŝŶƚǁĞůůƐͲϮϰ;WdηϭϵϲϬϬϵϬͿ͕Ͳϯϰ;WdηϮϭϲϭϯϵϬͿ͕ĂŶĚͲϱϬ;WdηϮϬϰϮϱϮϬͿƐƵĐĐĞƐƐĨƵůůǇƉĂƐƐĞĚD/dͲ/Ɛ ŽŶ:ƵůǇϭϵ͕ϮϬĂŶĚϮϭ͕ϮϬϮϮ͕ƌĞƐƉĞĐƚŝǀĞůǇ͘ EŽƌƚŚƐƚĂƌǁĞůůƐE^ͲϭϬ;WdηϮϬϬϭϴϮϬͿĂŶĚE^ͲϯϮ;WdηϮϬϯϭϱϴϬͿĂůƐŽƐƵĐĐĞƐƐĨƵůůǇƉĂƐƐĞĚD/dͲ/ƐŽŶ:ƵůǇϭϵ͕ϮϬϮϮ͘ WůĞĂƐĞŶŽƚĞƚŚĂƚWŝŶĚŝĐĂƚĞĚůĂƐƚǇĞĂƌƚŚĞƌĞƋƵŝƌĞĚƚĞƐƚƉƌĞƐƐƵƌĞĨŽƌƚŚĞEŽƌƚŚƐƚĂƌǁĞůůƐŚĂƐďĞĞŶƌĞĚƵĐĞĚĨƌŽŵϯϱϬϬ 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 2042520 Type Inj I Tubing 676 676 672 666 Type Test P Packer TVD 3,890'BBL Pump 4.5 IA 4 3522 3455 3437 Interval O Test psi 3500 BBL Return 4.5 OA 115 130 130 130 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 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 Milne Point / MPU / B Derek Weglin 07/21/22 Notes:Annual Class 1 Injection Well. Virtually witnessed by Tim Myers (EPA). Well shut in for thermal stability. Notes: Notes: Notes: B-50 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 Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0721_MIT_MPU_B-50 9 9 9 9 9 9 9 - 5HJJ Annual Class 1 Injection Well. 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: 10/27/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU B-50 (PTD 204-252) Multi Finger Caliper Log 08/04/2020 ANALYSIS FIELD DATA Water Flow Record Log 08/05/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. PTD: 2042520 E-Set: 34135 Received by the AOGCC 10/27/2020 Abby Bell 10/27/2020 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: 10/27/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU B-50 (PTD 204-252) Multi Finger Caliper Log 08/04/2020 ANALYSIS FIELD DATA Water Flow Record Log 08/05/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. PTD: 2042520 E-Set: 34134 Received by the AOGCC 10/27/2020 Abby Bell 10/27/2020 Hilcorp Alaska, LLC March 18; 2019 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 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 201 -2-02- Post Office Box 244027 Anchorage, AK 99524 3800 Centerpolnt Or Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8560 RECEIVED MAR 2 7 2019 RE: Mechanical Integrity Test Notifications Northstar Class 1 Iniection Wells UIC Permit AK -1I002 -B, General Wastewater, Permit No. 2016DBO01-0020 Milne Point Injection Well UIC Permit AK-II005-B, General Wastewater, Permit No. 2016DBO01-0001 Liberty Class 1 Injection Well UIC Permit AK- 11013-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 -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 -1I005-13; 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 7/7/2017. 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. Ft/t. g--st, Pm Zq-ZszO Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> qq 8/ It-7 Sent: Monday, July 31, 2017 5:21 PM l 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 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 ✓�j MPB-50 Milne Point 2042520 MPB-24 Milne Point 1960090 NS-10 North Star 2001820 NS-32 North Star 2031580 SCANNED AUG 0 8 20r Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska, LLC 0: (907) 777-8547 ( C: (509)670-8001 ( wrivardCthilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reco(e0alaska.00v AOGCC.InspectorsWalaska.00v phoebe.brooksCctalaska.00v chris.wallacel ialaska.aov OPERATOR: Hilcorp Alaska,LLC ' 1 S{j 1-1FIELD/UNIT/PAD: Northstar/NSU/Northstar \ - �l DATE: 07/07/17 OPERATOR REP: Matt Linder AOGCC REP: Well MPB-50 - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2042520 - Type Inj N Tubing 0 -2 ' -3 -3 Type Test P Packer TVD 389p - BBL Pump 6.0 - IA 0 3568 - 3524- 3513 - Interval 0 Test psi 3500 - BBL Return 6.0 - OA 95 - 131 - 131 - 131 _ Result P Annual Class 1 Injection Well EPA witnessed MIT-IA to 3500 psi.Witness waived by AOGCC's Jeff Jones.The well was SI in preparation for the MIT-IA to minimize Notes: pressure fluctuations due to temp changes.The swab valve was inadvertently left shulbelow the(Zing pressure transmitter and was not identified until after the MIT-IA was complete.Based on the IA pressure response and the guaranteed differential at a test pressure of 3500 psi,the decision was made not to retest. 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: 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 OAResult 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 MPU B-50 7.7-17 202{ - IS 2, Oh Nolan Hilcorp Alaska, 2-1c �� GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage, AK 99503 Tele: 907 777-8308 Ililrnrp Ala Pk*,LIC Fax: 907 777-8510 4 9 2017 E-mail: snolan@hilcorp.comJUL DATA LOGGED /2420/7 M. K BENDER DATE 07/19/17 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK ow AUG 0 8 201 99501 DATA TRANSMITTAL MPU B-50 Prints: GR/CCL/Press/Temp/RST: Temperature Log with Warmback Passes GR/CCL/Temp/Press/RST: RST Water Flow Log CD 1: DLIS Data 7/18/2017 7:40 AM File folder LAS Data 7/18/2017 7:41 AM File folder Log 7/18/2017 7:41 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: . 2o4 - 2'2 , • • 1E 11 FEB 2 9 2016 Hilcorp Alaska, LLC r Post Office Box 244027 Anchorage,AK 99524 3800 Centerpoint Dr Suite 1400 CERTIFIED MAIL#7014 0150 0000 6324 9220 Anchorage,AK 99503 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 1200 Sixth Avenue Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue SCAMS 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: HilcorpAlaska LLC (Hilcorp) respectfully ectfull submits the following notifications:ons: 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 ever required q year at the Milne e 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-11013-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 I-Ieebner 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 MIT 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. APA g_�; Pm 26)4 Z,Szo Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> j Sent: Thursday, July 30, 2015 4:59 PM 5� 814(lc To: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); Regg, Jarr et 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-S0(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. eWell Field PTD MPB-50 Milne Point 2042520 MPB-24 Milne Point 1960090 NS-10 North Star 2001820 NS-32 North Star 2031580 Thank You, SCANNED AUG 2 4 2015 Wyatt Rivard I Well Integrity Engineer U: (907) 777-8547 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Hilr.yrp ta*k,a. I.I,': 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to Jim reggaalaska.qov; doa.aoqcc Prudhoe bavC ialaska.gov• phoebe brooks@alaska qov 1 I '4+ OPERATOR: Hilcorp Alaska LLC I FIELD/UNIT 1 PAD: Milne Point/MPU/B DATE: 07/20/15 OPERATOR REP: Kruskie AOGCC REP: Waived Packer Depth Pretest Initial 15 Mtn 30 Min. 45 Min. 60 Min Well MPB-50 - Type In) W - TVD • 3,890' Tubing 1,045 1,047 1,047 1047 Interval 0 P T D 2042520 Type test P Test psi • 1500 Casing 61 3,530 3,522 3,488 P/F F Notes: Class 1 DW Annual MIT witnessed by EPA Thor OA 216 409 413 401 Cutler and Jason Selitsch Waived by AOGCC Bob Noble 0 4 bbls to reach pressure Wellhead temp from 128 9 to 121 degF at—29,000 BWPD Well MPB-50 • Type Inj W - TVD -3,890' Tubing 1047 1,045 1,045 1,047 1,048 1,046 Interval O P T D 2042520 Type test P Test psi 1500 Casing 3,488 3,508 3,433 3,614 3,695 3,660• P/F P ✓ Notes: 3 bbls to reach test pressure.Temp varied from OA 401 380 334 356 388 388 118 deg F to 130 degF at—29,000 BWPD Time/Tem Intial-20 50/118 15min-21 05/125 30min-21 20/133 45min-21 35/132 60min-21 50/130 Well Type In). TVD Tubing Interval P T D Type test Test psi Casing - P/F Notes: OA Well Type In) TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Tubing Interval Well Type In) TVD T g PTD. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dnlling 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 Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 02/2012) MIT MPU B-50 7-20-15 xls , . 0 .., , 0. m 0. . 2., ., a 2 ‘ E a: 1- Lt 0 I- I I I I ammadwai in 0 in o in 0 in m m CV (-A .-1 .-1 0 .-1 - , VW 6E:90:01 !Aid SO:SO:OT lAld ZE:E0:0T lAld 6S:TO:OT LAM SZ:00:0T ir i lAld ZS:8S:6 c 'Aid 1 All All A'11 A 11 A i ddddd T8Z8SS°EETI7T:::::6:ZSL t7SSSSS:::::666666 1 lAld 8S:LV:6 I ININdd TVSt79t7t7:66 lAld 81:Et7:6 : Ln It lAid 1717:T17:6 : `...... INd TT:017:6 0 [ fg d2 IN LE:8E:6 ,..... in Aid 170:LE:6 r. Tr 0 < Its,1"IAjddd 17°LZSE::ZSEEEE::666 II- - vq1Aldd OLTS::06:::66 E ii !! lAivsjiAinv s ji Ail Ail A Jo il LAId dddddddddd 6z9696E9EE 00:::::::::::LIL 001.:TZTT1:::::::::6666666666 111 Ad 019Z6 i CO lAld 9E:17Z:6 CL r! Ilsld EO:EZ:6 2 1D LAM OE:TZ:6 lAld SS:S0:6 LAW ZZ:170:6 [II[ vsjiNdd s6VE::9Z0:86 tai lAjl All Ali A I dddd 8TZS 001 7I:::86IS°SSS:::8868 1 [ ; (A 1A1c1 8Z:ES:8 VW SS:TS:8 lAld TZ:OS:8 Ad 817:817:8 Aid 171:L17:8 , 1Nd 117:S17:8 § o o in § § 0 8J nssam ZUy .2S2 • Post Office Box 24402 Hilcorp Alaska,LLC Anchorage,AK 99524 3800 Centerpoint Dr Suite 1400 CERTIFIED MAIL Anchorage,AK 99503 Phone: 907/777-8300 March 12, 2017 Fax: 907/777-8560 RECEIVED Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement MAR g 2017 U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 *SCANNED . 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) 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 Intel,Test 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 informationP lease 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: Evan Osborne,EPA Region 10 U.S. Environmental Protection Agency g Y 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 r • 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 (Ma be they are required extended up at NS10 every to 3 months two years. with Director Previously done approval) on 7/7/2016. pp ) Northstar NS32 By July 8, Approximately July 5- Coordinate with No Fluid 2017 10, 2017 Milne test date. movement logs are planned as (Maythey are be required eq extended upat NS32 every to 3 months twoY ears. 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. 2nqRECEIVA =Z � W APR 16 2015 Post Office Box 244027 '_Hilcorp Alaska,LLC AOGCC Anchorage,AK 99524 3800 Centerpoint Dr 4 s 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 r✓ 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 1\To. 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-11013-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 annualpermit 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-11005-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 Integri est Notification April 13,2015 Page 2 of 2 4 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 dheebnerrcDhil_corp.com. Sincerely, at4 tik 4eivW— Deborah Heebner Environmental Specialist HILCORP ALASKA, LLC Attachment cc: Thor Cutler, EPA Region 10 'II i i 4 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 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. · . Image Project Well History File Cover Page XHVZE 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. ~ 0 tf - ~ ~ Well History File Identifier ~Sided 11I1111111111111111 Organizing (done) RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettesl No. 2- o Other, Norrype: o Poor Quality Originals: o Other: NOTES: Date 4} J-/ ó 7 Date 4-1 t d-/ D7 x 30 = 1 D + Date LI.j¡ ')-1 D 7 BY: ~ Project Proofing BY: ç Maria;( Scanning Preparation BY: ""~. :=3 Production Scanning Stage 1 q3 (Count does include cover sheet) V YES NO !J VVl Page Count from Scanned File: BY: Page Count Matches Number in Scanning Preparation: ~. Date ifl fa-{ D7 If NO in stage 1, page(s) discrepancies were founa: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed "I II 1111 II II II I III OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: ~ I~IIIIIIIIIII~ 1111/ mP 151 d- = TOTAL PAGES q d- j (Count does not include cover s~eet) t /1/1 151 V r ~ . ""1111111111 It III 151 YES NO 151 III 1/111111111 It III '" 111111 filII It III 151 Quality Checked "' 1111111111111111 10/6/2005 Well History File Cover Page. doc • • Atil.. Pt- um,',(- 0-04- Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, August 09, 2012 2:31 PM � gig(tz' To: Regg, James B (DOA) Subject: RE: July 2012 AOGCC MIT Forms Hi Jim, That is not a typo. The IA pressure did increase 152 psi in the last 15 minutes of the test. It was noted that at the start of the test WHT was 124 deg F. At the 15 minute point, WHT was at 120 deg F and at 30 minutes the WHT was at 128 deg F. The pressure swing appears to be a thermal effect of the fluctuation in the injection temperature. Please let me know if you would like any further information. Thanks, Mehreen Vazir BPXA Well Integrity Coordinator 907 -659 -5102 SCANNED t4AY 0 7 2013 From: Regg, James B (DOA) [mailto:jim.regg@@alaska.gov] Sent: Thursday, August 09, 2012 11:24 AM To: AK, D &C Well Integrity Coordinator Cc: Brooks, Phoebe L (DOA) Subject: RE: July 2012 AOGCC MIT Forms MPB -50 (PTD 2042520); IA pressure at 30min seems odd; is 152psi increase during last 15min of test a typo? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator (abp.com] Sent: Wednesday, August 01, 2012 7:24 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: July 2012 AOGCC MIT Forms Jim, Phoebe, 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) END 3- 17F/K -30 (PTD #2032160) 1 • NS10 (PTD #2001820) EPA Witnessed NS32 (PTD #2031580) EPA Witnessed 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: AKDCWeIllntegrityCoordinator c(DBP.com 2 • • .. .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regoaalaska.gov; doa.aoacc prudhoe.bav @alaska.gov; phoebe.brooksaalaska.00v; tom.maunder(cDalaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT 1 PAD: Milne Point / MPU / B DATE: 07/28/12 OPERATOR REP: Brian Bixby AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPB -50 ' Type Inj. W ' TVD - 3,890' Tubing 1102 1103 ' 1103 1100 Interval 0 P.T.D. 2042520 ' Type test P Test psi - 1500 Casing 26 3520 3394 3546 P/F P Notes: 1 -year EPA MITIA OA 267 371 360 360 EPA Inspection - Thor Cutler witnessed 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 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 dunng Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT MPU MPB - 50 07 - 28 - 12 DATE: 17- May -12 Stephanie Pacillo TRANS#: 5958 y IViakanaK Bender Data Delivery Services Technician , "' Schlumberger Oilfield Services , ,% ' . Lai T-j: A. ., r I I 2U , r Data & Consulting Services SSA VIED JUL U 2525 Gambell St, Ste. 400 !4 - Anchorage, AK 99503 ,r� it: Office: (907) 273 -1770 WELL SERVICE OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR CD's NAME ORDER* DIST DIST DIST DIST I,O4GED PRINK PRINTS C -32C BL PO -00 X L DWG EDIT OF MCNL 117 6- Jul -11 1 1 CD • GC -2E BYS4 -00011 X LDWG EDIT OF RSTIWFL 6- Dec -11 1 1 CD F -06A BSM4 -00011 X LDWG EDIT OF RST 2- Jul -11 1 1 CD 03 -30 BINC -00081 X LDWG EDIT RST 16- Nov -11 1 1 CD F-45B BUTT -00013 X LDWG EDIT OF MCNL 29- Aug -11 1 1 CD A-43 BG4H -00086 X LDWG EDIT OF RST 10- Sep -11 1 1 CD N -16 BCRD -00032 X LDWG EDIT OF RST 5- Jul -10 1 1 CD MPI -18 BG4H -00107 X LDWG EDIT OF IBC 25- Dec -11 1 1 CD li> MPB -50 BCRJ -00096 X LDWG EDIT OF RST/WFL 16- Jul -11 1 1 CD 1- 21/K -25 BG4H -00113 X LDWG EDIT OF RST 18- Feb -12 1 1 CD P -01A BD88 -00193 X LDWG EDIT OF PDC -GR - 15- Jan -12 1 1 CD Y -19 BINC -00091 X LDWG EDIT OF PDC -GR •. 9-Jan-12 1 1 CD S X - X Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 ij S i bp BP Exploration (Alaska) Inc. ,. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 2-b Mr. Tom Maunder ��- Alaska Oil and Gas Conservation Commission ca 0 L 333 West 7 Avenue Ld i fy‘f Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPB -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPB -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPB -Pad 8/22/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor! Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPB-01 1800750 50029204900000 Sealed coductor NA NA NA NA NA MPB-02 1811420 50029206620000 40 NA Need tob job MPB-03 1820560 50029207320000 Sealed coductor NA NA NA NA NA MPB-04A 1821000 50029207480100 Sealed coductor NA NA NA NA NA MPB-05A 1851480 50029207720100 Sealed coductor NA NA NA NA NA MPB-06 1850130 50029212760000 Tanko conductor NA NA NA NA NA MPB-07 1850620 50029213240000 Sealed coductor NA NA NA NA NA MPB-08 1850630 50029213250000 Tanko conductor NA NA NA NA NA MPB-09 1850340 50029212970000 Tanko conductor NA NA NA NA NA MPB-10 1850170 50029212800000 Tanko conductor NA NA NA NA NA MPB-11 1850430 50029213050000 Tanko conductor NA NA NA NA NA MPB-12 1850800 50029213380000 Tanko conductor NA NA NA NA NA MPB-13 1850930 50029213480000 Tanko conductor NA NA NA NA NA MPB-14 1851120 50029213660000 Tanko conductor NA NA NA NA NA MPB-15 1851210 50029213740000 Tanko conductor NA NA NA NA NA MPB-16 1851490 50029213840000 Tanko conductor NA NA NA NA NA MPB-17 1852090 50029214340000 Tanko conductor NA NA NA NA NA MPB-18 1852290 50029214500000 Tanko conductor NA NA NA NA NA MPB -19 1852300 50029214510000 Tanko conductor NA NA NA NA NA MPB -20 1860050 50029215240000 Tanko conductor NA NA NA NA NA MPB-21 1860230 50029215350000 Tanko conductor NA NA NA NA NA MPB-22 1853020 50029215090000 Tanko conductor NA NA NA NA NA MPB-23 1890160 50029219150000 Sealed coductor NA NA NA NA NA MPB-24 1960090 50029226420000 5 NA 5 NA 35.7 8/22/2011 MPB-25 1972330 50029228410000 3.8 NA 3.8 NA 25.5 8/22/2011 MPB-27 2042210 50029232330000 1.6 NA 1.6 NA 15.3 8/22/2011 --"} MPB-50 2042520 50029232400000 2.1 NA 2.1 NA 8.5 _ 8/22/2011 Schlumberger RECEIVED No. 5769 Alaska Data & Consulting Services JUL 2 5 2011 Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Auks Oil fit Gas Cons. CommissiOn Attn: Christine Shartzer ATTN: Stephanie Pacillo Anchorage 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD H -17A BLPO -00119 PPROF W GHOST 10- Jul -11 _ 1 _ 1 _ 14 -04A AV1P -00093 LEAK DETECTION LOG 9-Jul-11 1 _ 1 • E -01A BLPO -00121 PPROF W GHOST 12- Jul -11 1 1 2 -t -,2j l-.MPB -50 BCRJ -00096 RST WFL LOG 16- Jul -11 1 -� "1 / t- f g`/2_ H -14B BD88 -00113 PPROF W/ DEFT & GHOST 2- Jun -11 1 1 OWDW -SW AV1P -00091 RST WFL LOG 16- Jul -11 1 1 06 -02A BL65 -00027 LDWG EDIT OF MCNL 4- May -11 1 1 15 -028 BJOH -00016 LDWG EDIT OF RST 1- Apr -11 1 1 P2 -41 BJOH -00020 _ LDWG EDIT OF RST 11- Apr -11 1 1 �_ W.223 I3CRJ- 00086 LDWG EDIT OF USIT 18- May -11 N/A 1 vvr.20? BM A -00005 LDWG EDIT OF USIT 30- Jan -11 N/A 1 06 -08A BCRD -00089 LDWG EDIT OF RST 6- Mar -11 1 1 • _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: OP H xplor abort (Alaska) Inc_. Alaska Data & Consulting Services Pctroterhnic=al Lola Conte! 1,k2 I [ 2525 Gambell Street, Suite 400 W O !,3erv,on RIO z r ! j.2 � o ` -� 7 l � l Anchorage, AK 99503 -2838 C. & figrtr 1 3 Q om ' - FW: March 2011 AOGCC MIT Forms. • Page 1 of 3 Regg, James B (DOA) Pr() 104 - a From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @ bp.com] Sent: Monday, April 04, 2011 11:05 AM 4 (Ai �( To: Regg, James B (DOA); AK, D &C Well Integrity Coordinator Cc: Brooks, Phoebe L (DOA) Subject: RE: March 2011 AOGCC MIT Forms Attachments: MIT MPU MPB -50 (2) 03- 29- 11.xIs Please see the attachment for the AOGCC witnessed form. The PTD# has been revised. Torin From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, April 04, 2011 10:24 AM To: AK, D &C Well Integrity Coordinator Cc: Brooks, Phoebe L (DOA) Subject: RE: March 2011 AOGCC MIT Forms Please submit test report for MPB -50 (PTD 2042520) on AOGCC form. Also note that PTD # on the EPA form is wrong (extra 5 in string) Jim AOGCC 5 0 7 2011 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, April 03, 2011 8:15 PM To: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: FW: March 2011 AOGCC MIT Forms Jim, Tom and Phoebe, Here are five additional AOGCC MITIA forms for March 2011. MPL -08 (PTD # 1901000) MPL -09 (PTD # 1901010) MPS -04 (PTD # 2030520) MPS -20 (PTD # 2022410) MPS -30 (PTD # 2022360) «March 2011 MIT Forms.zip» Thank you, Torin Roschinger (alt. Jerry Murphy) 4/4/2011 FW: March 2011 AOGCC MIT Forms • Page 2 of 3 Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, April 01, 2011 7:16 PM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)'; 'Regg, James B (DOA)' Subject: March 2011 AOGCC MIT Forms Jim, Tom and Phoebe, Please find the attached March 2011 AOGCC MITIA forms for the following wells: MPB -50 (PTD # 2042520) MPF -84B (PTD # 2001760) MPI -02 (PTD # 1900910) MPL -32 (PTD # 1970650) MPS -33A (PTD # 2061720) 06 -17 (PTD # 1820900) A -05A (PTD # 2061280) A -08 (PTD # 1740040) A-41 (PTD # 1941580) L -105 (PTD # 2020580) NGI -14 (PTD # 1780920) P -02A (PTD # 2000840) R -07 (PTD # 2000100) R -15A (PTD # 1990360) S -05A (PTD # 1951890) S -114A (PTD # 2021980) S -124 (PTD # 2061360) U -04A (PTD # 1920270) W -29 (PTD # 1880710) 4/4/2011 FW: March 2011 AOGCC MIT Forms • Page 3 of 3 WGI -09 (PTD # 2061460) «MIT MPU MPI -02 03- 12- 11.zip» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/4/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaat alaska.00v; doa .aogcc.prudhoe.bay(6alaska.00v; phoebe.brooksCEalaska.aov; tom.maunder(Ealaska.00v OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Milne Point / MPU / B pad DATE: 03/29/11 OPERATOR REP: John Perl AOGCC REP: John Crisp waived test Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPB -50 Type lnj. W TVD 3,890' Tubing 900 920 920 920 920 Interval 0 P.T.D. 2042520/ Type test P Test psi 1500 Casing 70 3540 ' 3610 3660 3560' P/F P Notes: 1-year AOGCC MITIA OA 230 375 395 430 420 Injection fluctuated between 22492 -22600 bpd. Inj Tem was 113° to 124 °. Talib S ed with the EPA witnessed test. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. 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 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT MPU MPB -50 (2) 03- 29- 11.xls • S United States Environmental Protection Agency �a Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553 -1673 e -mail: cutler.thor @epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM 204Z.52,° Facility I Well I Permit No. PTD No. BP Alaska - Milne Point Unit Well MPB - 50 AK 1I005 - A 204256g Injector MIT Type Test Type Test Date Class I T X IA " Std. Annular Pressure Test (SAPT) 3/29/2011 Req'd Test Fluid Type(s) used to Packer Depth (ft, Presssure (psi) test TVD) Test Interval / Comments 3,500 Diesel 3,890 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING 900 920 920 920 920 PASS T INNER ANNULUS 70 3540 ' 3610 ' 3660 ' 3560 OUTER ANNULUS 230 375 395 430 420 1 COMMENTS: 4.2 bbls of Diesel to bring up to pressure. Injection fluctuated between 22492 -22600 bpd. Inj Temp was 113° to 124° - T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 2 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: EPA class 1 well test as per permit. Last MITIA done on 4/08/10 with well on injection, Tested OK to 3,500 psi at start and 3,370 psi after 30 minutes. Ran WFL on 6/13/08 (3 year cycle per EPA permit), due summer 2011. NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 5 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 5% 2) Loss during last 15 minute period = or > 50% of loss during fist 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). -- E -mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: / Talib Syed John Crisp Waived Witness John Perl AOGCC MITIA Forms for MPB-S~PTD#2042520) MPF-90(PTD#20121101-08A(PTD#205... Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) ~~~~~ ~~~~t° Sent: Wednesday, June 02, 2010 8:44 AM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: AOGCC MITIA Forms for MPB-50(PTD#2042520) MPF-90(PTD#2012110) 01-08A(PTD#2051950) 03-17 (PTD#1791020) 04-10(PTD#1760420) 16-03(PTD#1810110) 17-08(PTD#1810740) 17-13A(PTD#2050200) NGI-05(PTD#1760140) S-04(PTD#1830790) S-112(PTD#2021350) S-120(PTD#203198 I'm more than a little surprised that EPA reps did not insist on extending the test an additional 15 minutes; that would have been our approach. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Tuesday, June O1, 2010 7:50 PM To: Regg, James B (DOA); AK, D&C Well Integrity Coordinator Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: AOGCC MITIA Forms for MPB-50(PTD#2042520) MPF-90(PTD#2012110) 01-08A (PTD#2051950) 03-17(PTD#1791020) 04-10(PTD#1760420) 16-03(PTD#1810110) 17-08 (PTD#1810740) 17-13A(PTD#2050200) NGI-05(PTD#1760140) 5-04(PTD#1830790) S-112 (PTD#2021350) S-120(PTD#203198 Jim, During the AOGCC/EPA MITIA, the injection temperature and rate increased over the 2nd 15 minute monitor causing the IA pressure to increase as well. I reviewed the MITIA's from the previous two years and found them to act very similar. After a discussion with the plant, they said it's very difficult to maintain a stabile injection rate for any length of time. I will make a note that in the future, changes in temperature and rates need to be reflected on the MIT form. Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~ ~ y tai Y.,~t i\ ~~c-, -s ~ ti ~" - From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, June 01, 2010 11:33 AM To: AK, D&C Well Integrity Coordinator Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: AOGCC MITIA Forms for MPB-50(PTD#2042520) MPF-90(PTD#2012110) 01-08A (PTD#2051950) 03-17(PTD#1791020) 04-10(PTD#1760420) 16-03(PTD#1810110) 17-08 (PTD#1810740) 17-13A(PTD#2050200) NGI-05(PTD#1760140) 5-04(PTD#1830790) S-112 (PTD#2021350) S-120(PTD#203198 6/9/2010 AOGCC MITIA Forms for MPB-STD#2042520) MPF-90(PTD#20121101-08A(PTD#205... Page 2 of 2 Curious about MPB-50 (PTD 204252); shown as a passing test w/EPA witness but test results do not indicate stabilized conditions. What's up with the 220 psi decline after 15 min followed by 90 psi increase at 30 min? Was the test run longer than 30 min to see if pressures would demonstrate stabilization? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, April 30, 2010 7:44 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: MPU, OMS Facility Coordinator; MPU, OMS Field Coordinator Subject: AOGCC MITIA Forms for MPB-50(PTD#2042520) MPF-90(PTD#2012110) 01-08A(PTD#2051950) 03-17 (PTD#1791020) 04-10(PTD#1760420) 16-03(PTD#1810110) 17-08(PTD#1810740) 17-13A(PTD#2050200) NGI-05 (PTD#1760140) 5-04(PTD#1830790) S-112(PTD#2021350) S-120(PTD#2031980) Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: MPB-50 (PTD #2042520) MPF-90 (PTD #2012110) 01-08A (PTD #2051950) 03-17 (PTD #1791020) 04-10 (PTD #1760420) 16-03 (PTD #1810110) 17-08 (PTD #1810740) 17-13A (PTD #2050200) NGI-05 (PTD #1760140) S-04 (PTD #1830790) S-112 (PTD #2021350) S-120 (PTD #2031980) WGI-05 (PTD #1900250) X-23 (PTD #1840610) «April 2010 MIT Forms.zip» Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 6/9/2010 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. ~~~~grlc~ FIELD /UNIT /PAD: Milne Point / Milne Point / B Pad r DATE: 04/08/10 OPERATOR REP: Anna Dube AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well MPB-50 Type Inj. W TVD X3,890' Tubing 1,087 1,085 1,000 999 Interval O P.T.D. 2042520. Type test P Test psi ' 1500 Casing 260 ~ 3,500 3,280 ' 3,370 P/F P Notes: Annual MITIA required for EPA Class I compliance ~ OA 200 440 460 460 ~AOGCC declined to witness. EPA Thor Cutler witnessed. 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 T pe Inj. TVD Tubing Interval P.T.D. Type 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 7 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 MIT MPU B-50 04-08-10.x1s • • Proposed Schedule for 2010 Mechanical Integrity Testing r 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 April 2010 are not required till 2011. i -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 ~~,~ _ 15 ~ summer barge season. Northstar NS10 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer ~~~` ~~~ bar a season. Northstar NS32 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer a~~-~S~ bar a season. Liberty CRI Well N/A September 2010 All logs required to complete the well will ~p ~- ~ ~~ ~~ ~ ~ ~ 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 ~ ~,~ .~a ~ ~. and NW wells 2010 with MIT's. and by Caliper logs in a-~ S November 7, summer/fall 2010. -.a~ ~ 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 for GNI- /Early October, Logs and/or Water 03 ,and GNI-04 02A, GNI-03 and 2010 Flow Logs planned for ~~ ~o' \ ~~ GNI-04. summer 2010. Caliper logs in 1 ~ ' ~ Fs summer/fall 2010. ~~, ~ ~ `, ll ^J,~~. }~'S~y p[ r y ~ 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 ~~ cr ~~~ BP Exploration (Alaska) Inc. P. 0. Box 196612 900 E. Benson Boulevard And~orage, AK 99519-6612 Direct 907 561 5111 Phone: (9071564-4838 Email: Alison.CookeC~?bp.com Web: www.bp.com ~/ FE6 2 4 201x: ~'aslca Oil&~Cops.Conll,, Anchorage 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. 2005D6001-0020 Milne Point Injection Well, UIC Permit AK-11005-A General Wastewater Permit No. 2005DB001-0001 Pad 3 Iniection Wells. UIC Permit AK-1!004-A Wastewater Disposal Permit No. 2005DB0001-0021 Grind and Iniect Iniection Wells. UIC Permit AK-11008-A Area Injection Order No. 4E, General Wastewater, Permit No. 2005D6001-0012 Liberty Class 1 Injection 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 movemert 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 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ ,~~ 5 /I /~~~ Sent: Friday, May 01, 2009 11:15 AM `~ ~~ 1 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; MPU, OMS Field Coordinator; MPU, OMS Facility Coordinator; MPU, Wells Ops Coord ~~ rr~ '~ Subject: April MIT Forms ` ~ r Attachments: MIT PBU 09-12 04-09-09.x1s; MIT MPU B-02 04-14-09.x1s; MIT MPU B-50 04-06-09.x1s; MIT MPU S-07 04-14-09.x1s; MIT PBU L-210 L-220 04-15-09.x1s; MIT PBU NGI 04-29-09.x1s; MIT PBU P-03A 04-10-09.x1s; MIT PBU W-03 W-42 04-10-09.x1s; MIT PBU S-107, S-111 04-30- 09.x1s; MIT PBU W-35 04-18-09.x1s; MIT PBU W-218 04-25-09.x1s; MIT PBU Y-06A 04-10- 09.x1s Jim, Tom and Bob, Please see the attached MIT forms for the following wells: 09-12 (PTD #1770070) M!T-IA post-initial injection; witnessed by Bob Noble. MPB-02 (PTD #1811420) MIT-IA for 4-year UIC compliance; witnessed by Bob Noble. _--~ MPB-50 (PTD #2042520) MIT-IA for annual EPA Class 1 compliance; witnessed by Talib Syed. MPS-07 (PTD #2020720) MIT-IA for 2-year monobore compliance; witnessed by Bob Noble. L-210 (PTD #2031990) MIT-IA for MI service; witnessed by John Crisp. L-220 (PTD #2080470) MIT-IA for MI service; witnessed by John Crisp. P-03A (PTD #1972280) MITIA for variance compliance; witnessed by Bob Noble. NGI-04 (PTD #1750690) MIT-IA for variance compliance; witnessed by Bob Noble. , S-107 (PTD #2011130) MIT-IA to demonstrate tubing integrity post-patch; witnessed by Bob Noble. S-111 (PTD #2050510) M1T-IA for variance compliance; witnessed by Bob Noble. V-211 (PTD #2042200) MIT-IA for 4-year compliance; witnessed by Bob Noble: V-221 (PTD #2050130) MIT-IA for 4-year compliance; witnessed by John Crisp. W-03A (PTD #1971390) MIT-IA for 4-year UIC compliance; witnessed by Bob Noble. W-35 (PTD #1880330) MIT-IA for AA request; witnessed by John Crisp. . W-42 (PTD #1880570) MIT-IA for AA request; witnessed by Bob Noble. , W-218 (PTD #2081740) MIT-IA post-initial injection; witnessed by Chuck Sch~eve. Y-06A (PTD #2042510) MIT-IA for 4-year UIC compliance; witnessed by Bob Noble. «M!T PBU 09-12 04-09-09.x1s» «MIT MPU B-02 04-14-09.x1s» «MIT MPU B-50 04-06-09.x1s» «MIT MPU S-07 04-14-09.x1s» «MIT PBU L-210 L-220 04-15-09.x1s» «MIT PBU NGI 04-29-09.x1s» «MIT PBU P-03A 04-10-09.x1s» «MIT PBU W-03 W-42 04-10-09.x1s» «MIT PBU S-107, S-111 04-30-09.x1s» «MIT PBU W-35 04-18-09.x1s» «MIT PBU W-218 04-25-09.x1s» «MIT PBU Y-06A 04-10-09.x1s» Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 5/1/2009 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 ~~7~rjll ~ j FIELD /UNIT /PAD: DATE: OPERATOR REP: EPA REP Mllne Pomt / MPU / B-Pad 04/06/09 Mel Iveson Talib Syed Packer Depth Pretest Initial 15 Min. 30 Min. Well MPB-50 Type Inj. W TVD 3,890' Tubing 800 800 800 920 Interval O P.T.D. 2042520 Type test P Test psi 3500 Casing 480 3,520 3,450 3,520 P/F P Notes: MIT-IA for annual EPA Class 1 compliance. OA 250 460 420 380 Initial inj rate at 9970 bpd at 115°. Plant increased inj rate to 23,250 bpd at 132° -18 min into test. Restart test. See below. ~ Well MPB-50 Type Inj. W TVD 3,890' Tubing 920 920 920 920 Interval O P.T.D. 2042520 Type test P Test psi 3500 Casin 3,500 3,620 3,660 P/F P ` Notes: 2nd test. PSI increase due to rate change. OA 440 480 520 Pumped 4.1 bbls of diesel to pressure up IA. 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 Casin 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 = Intemal 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 2009-0406_MIT_MPU_B-50.x1s • • by ;,~~,: :~:= BP Exploration (Alaska) Inc. 9Q0 East Benson Boulevard PO Box 196612 Anchorage, AK 99519~66i2 ' (907) 5643111 July 15, 2008 CERTIFIED MAIL ~ ~-aoti - Osso-c~cao~ - od i ~- o~ti S Mr. Michael Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue ~ b ~ ' ~~~`~ Seattle, WA 98101 ~ /n .~ I s I Injection Well - WFL Reoort~~N~~ ~~~ ~ ~ 2008 Milne Point Unit Permit Number AK-11005-A Dear Mr. Bussell: In order to meet the reporting requirements of the Milne Pant Class I Injection Well Permit (AK-11005-A) Part II C.3.b(2) and Part II.C.3.c.(1), BP Exploration (Alaska} Inc., (BPXA) submits the attached two (2) copies of the field report and an interpretive report to the Environmental Protection Agency {EPA). A water flow tog was performed on the Milne Well B-50 on June 13, 2008. Prior to the test, EPA representative Thor Cutler was contacted and he waived the need to witness the water flow logging. The mechanical integrity of well 8-50's production casing, and downhole cement was demonstrated. No flow in vertical channels adjacent to the welt bore and no fracturing in the confining zone were evident. The field report and an interpretive report are enclosed. If you have any questions, please call Laurie Cometl at 907-5645952. Sincerely, Tom V. rshaQ Milne Point Performance Unit Leader • Mr. Michael Russell July 15, 2008 Page 2 Attachments cc: Thor Cutler, EPA Region 10 Taub Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC • } Class I In~ect~on Well MPB-50 WFL Interpretioe Report Prepared for the EPA 7/IS/2UQ8 Purpose: A water flow log (WFL.) was performed on Milne Point Class I injection well, MPB-50, on June 13, 2008. The WFL was performed to comply with the Well Permit (AK-11005-A) Part II C.3.b(2) and Part II C.3.c(1). This report summarizes the findings from the water flow log. Summary: During the WHS., stop counts were taken at 8,050-ft, 8,125-ft, 8,200-ft, 9,510. ft, 9,750-ft, 9,799-ft, and 9,848-ft 1VID. Logging was perForm~ with the well inj~ting at 28,800 bwpd at an injection pressure of 1,000 psi. The minitron was set to detect upwards flow in channels behind the casing with a tninitron on time of 10.0 seconds and a minitron off time of 90.67 seconds. I.og Fge WIZ Detector Stop Depth (ft) Flow Detected Velocity (ft/bin) velocity Error !t/min WFL on tune (s) WFL off time s 27 RST Near 8,050 Unknown 2.5 0.6 10.0 90.67 26 RST Near 8,125 No - - 10.0 90.67 25 RST--Near 8,200 Unlrnown 1.5 0.7 10.0 90.67 22 RST Near 9,510 No - - 10.0 90.67 21 RST-Near 9,750 Unlmown 2.3 0.6 10.0 90.67 19 1tST Near 9,799 No - - 10.0 90.67 17 1tST--Near 9,848 Yes 8.5 0.7 10.0 90.67 15 RST Near 9,848 No - - 0.8 52.27 Ezplanation: During logging, flow was detected at stop depth 8,050-ft, 8,200-ft, 9,750.ft and 9,848-ft. For the first three depths, the flow detected was categorized as unknown. Unknown flow occurs when the velocity error exceeds 20% of the detected flow velocity. The unknown flow at 8,050-ft and 8,200-ft can be explained by turbulence in the tubing due to proximity to the tubing tail. The unknown flow at 9,750-ft is an anomaly in the log data which is not substantiated by analysis of the individual stop count in the WFL field report and is attributed to the sensitivity of the logging tool. Positive flow was detected at stop depth 9,848-ft MD. However, analysis of the individual stop count in the field report does not show a variation in detected CR that would substantiate flow in the region. In addition, log file IS summarizes a repeat stop at 9,848-ft. In order to evaluate the immediate area and isolate any flow in the region, the detection time on the minitron tool was reduced during this stop count. With a decreased evaluation time, no flow was detected. Thus, it was determined that there is no flow at 9,848 ft. In conclusion, the flow detected during the WFL can be explained by tubing geometry, and tool sensitivity or it was eliminated by repeat log runs. Thus, the mechanical integrity of the casing and downhole cement for MPB-50, Class I injection well, has been demonstrated. 7/15/2008 07/03/08 fi `,, i ~~~1~~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Woll _Inh at NO.4768 Company: State of Alaska ~~~~~ JUL ~' ~ ~~~~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ n.. MPB-50 11999019 RST WFL ~ 06/13/08 1 1 M-04 11962601 PRODUCTION PROFILE 06/21/08 1 1 P7-24 12066527 MEM LDL ~D`"' ~ 06/18/08 1 1 04-11A 11975778 LDL ~~, a- / 06/24/08 1 1 M-04 11962601 PRODUCTION PROFILE _ 06/21/08 1 1 12-03 12071857 USIT l~.- j. `(p 06/21/08 1 1 GNI-03 12066530 MEM PRESS/TEMP LOG ~-~ L 06/20/08 1 1 E-10B 40016750 OH MWD/LWD EDIT 04/05/08 2 1 18-13B 11972960 MCNL v~~ (o ~ 12/07/07 1 1 18-13B 12021159 MCNL v"'~.- "' 05/18/08 1 1 BP Exploration (Alaska) Inc. _ .. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: o>a,:. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 / ATTN: Beth 1 , Received by: IC! • • • Maunder, Thomas E (DOA) • Page 1 of 1 From: Easton, John R (DNR) ~_ ~ _._ ~ ~ `~ Sent: Wednesday, June 18, 2008 3:32 PM ~'` To: Schmitz, Steven (DNR); Weaver, Aaron A (DNR); Frazier, Jeanne M (DNR); Davidson, Temple (DNR); Schultz, Gary (DNR); Lynch, Leon C (DNR); Byrne, Laurence C (DNR); Silfven, Laurie A (DEC); Goatley, Margie M (DNR); Maunder, Thomas E (DOA}; Regg, James B (DOA); Cutler.Thor@epamail.epa.gov; ROCKWELL.THEODORE@EPAMAIL.EPA.GOV; Winters, Jack F (DNR); Bettis, Patricia K (DNR); Michiel.E.Holley@usace.army.mil; Woodke, Julie A POA; johnny.aiken@north-slope.org; Ben Greene; gordon.brower@north-slope.org; 'Waska.Williams@north-slope.org'; Easton, John R (DNR) Subject: Milne Point Unit Well B-50 API #50029232400000 Attachments: Public Notice for Private Easement MPU B-50 Injection Well.doc Review Participants, We are conducting a review to create an easement for an existing Milne Point Unit waste disposal well. Public notice is attached, comment are due July 22"d. The application can be reviewed at the following FTP site: ftp:/jftp.dnrstate.ak._us/oilgasjjrejMPU_Class 1_Disposal_Wel![ Thanks. John ~~d~9NE®JUN a ~ 20p~ 6/18/2008 • • STATE OF ALASKA Department of Natural Resources Division of Oil and Gas 550 W. 7th Avenue, Suite 800 Anchorage, Alaska 99501-3560 PUBLIC NOTICE AS 38.05.850 Easement Milne Point Unit Injection Well B-50 USGS 1:63,360 Beechey Point Map B-4 and B-5 In accordance with the provisions of AS 38.05.850 the Department of Natural Resources, Division of Oil and Gas (DO&G) is considering British Petroleum's (BP) application for approval of an easement for an existing Class I Disposal Well situated on State land within Sections 7,8,18 and 19 Township 13 North, Range 11 East, Umiat Meridian. The Division of Oil and Gas approved a plan of operations for the well and activity in 2005. The AOGCC and EPA also approved the well and activity. The well is operating. No change in activity is proposed at this time. The Milne Point Unit no longer contains a portion of the well. The purpose of this action is to reauthorize the well as an easement independent of oil and gas lease or unit status. This action is a re-issuance of the prior agency authorization under 11 AAC 110.830. Additional information is available for download and viewing at fI :lilt .dnr.state.ak.us%oil~as/~re/MPU Class 1 Dis oral ~~°ell/ and related information at htt~~:~i«°~~~v.c~a.gov~''safewatcr.~uac/ind~.x.htnil and http:lf ~vww.state. ak. us/adn~ i nto~;e/liomeo ~c. shtn3l Members of the public and interested parties are invited to comment on this proposal. The Division of Oil and Gas must receive written comments addressed to the attention of Steve Schmitz, Department of Natural Resources, Division of Oil and Gas, 550 W. 7th Avenue, Suite 800 C, Anchorage, Alaska 99501-3560 no later than 5:00 p.m. 07/22/2008. Comments maybe faxed to (907) 269-3484, or e-mailed to Steve.Scl~mitz(a;:alaska.~ov. Comments must clearly explain the facts on which they are based, how they pertain to the action proposed, and reference ADL 418273. The Department's proposed decision on this matter may be modified as a result of information received. Questions maybe directed to the attention of Steve Schmitz: telephone (907) 269-8777. The State of Alaska Department of Natural Resources complies with Title II of the Americans with Disabilities Act of 1990. Individuals with disabilities who may need auxiliary aids, services, or special modifications to participate may contact the TDD number at (907) 269-8411. The Division of Oil and Gas reserves the right to waive technical defects in this notice. • Distribution List: Johnny Aiken/ Ben Greene, NSB Gary Schultz, Leon Lynch, Larry Byrne, ADNR DMLW Jack Winters, ADF&G Margie Goatley, ADNR SHPO Laurie Silfven, DEC Patricia Bettis, ADNR DMLW Tom Maunder, AOGCC Jim Regg, AOGCC Temple Davidson, DOG Thor Cutler/ Ted Rockwell, USEPA Mike Holley/ Julie Woodke USACE J. Andrew Bachner US Post Office, Barrow, AK US Post Office, Nuiqsut, AK US Post Office, Deadhorse AK DNR Public Notice Web Site :7 Anchorage Daily News Arctic Sounder ., ,~~_~~,~ 1 ~, 200? C~lr. Steve Scl~~mi'z Alas}<a Departrn~ent of Natural Resources t~ivision of Uif onto Gas :~~0 W, 7t'' Av~~.. Suite 80+~ Anchorage,>4K 99501-3577 Request for Approval t~,~F~U E-5C) Infection Well AS 3°.05.50 Easen,~ent dear Mr. Schi~~itz BP t=xhloration (Alaska) E~~c. yBP~A~ is submitting a rr~vised Ai~plicatlon for Easement <.~fter discussion with the Alaska Department of fJatural ResourceslG~ivision of Oil & Gas fior the P~~ifne Point [Jnit 13-50 Class l Disposal t~~ell. EPXA received approval fior tote (~9ilne Point Unit (MPU) Class I disposal well, B-50, under LOINS 31-54 dt,tcd May 13, 2005. TIr~ Milne Point t)nit subsequently contracted and the lease (ADL0~7432~ relinquished. The bottom hoie is now .outside the l,[nit bou~~d~ary. Its ceder to pro~ride a record of this asset for a possible new lessee, ADt~~(RIDs'JC reque ;ted that BPXA submit an Easement Application. Figure 2 has been revised to show the full length of trae h~orehole without the `Area of In'terest' that ~,a~as included in t}~e u~evious submittal, ~i his `,eatu~e is in tf~e U.S. EnvirormPntal Protection Agency (EPA} Undergroi.ind li~jecticn Control ap:~lication and permit. Though the figure ~f~~ows the:: full iF~~ngth of the borehole for purposes of the easnn-~Gnt, BPXA has hi-Sighted the portit~r~s of the bo~~ehole that Zee witrun tt-~e ~~tilne Point Unit for future easement fee assessrrient purposes. In si,~pport of our request, enclosed you,~ill fiiici the following: Easement Application for MPUB-SUCIass ! {s}ection'~1Veii, and • Figures fi-~. BPXA has applied for a Priv~.te Easement per the Easement Application form, but would liketo caualify this as a Pri+iateNon-Excusive easement for the record. If you have any questions concerning this ap~~lication or require ~~dditiona{ information, please contact Barbara Manson 41t 564-5u55 ~r email (barn.-u~r,sr~n,~'bp.corn}. • • P,`r_ ~;t~,vc Schrn(tz, .4E~Nw'DOG Just; ', , ?'.:)C8 F'anq , SirtcerE;ly, Kristi« G. Paul, P~ermitfing Adviser F1Sf/, A~a5k~3 Att~C#'it1lE'1115 cc: John Easton, ADf~dR/DOG Temple Davidson, ADNR/DOG ~~~att Raver, ADNRiDOG Katn?rine ~~1~_,ans, AQNFi/>~OG Mr. Steve Schmitz, ADNR/DOG June 17, 2008 Page 3 bCC: w/ attachments File Copy: 553.02A8 / B Pad Expansion w/ attachments Dennis Urban MPU Environmental Advisor Daryl Kleppin Alison Cooke Mike Bill Douglas W ikon • Read File w/o attachments (Kristin Paul} STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES D1VtSION OF MINING, LAND AND WATER ^ Northern Region 3700 Airport Way Fairbanks, AK 99709 Non-refundable filing fee: $100" ~ Southcentral Region 550 W 7th Ave., Suite 900C Anchorage, AK 99501-3577 t;907} 269-8552 APPL1CATtON FOR EASEMENT AS 38.05.850 ADL # (to be filled in by state} Applicant's Name: Bp Exploration (Alaska) lnc. Doing business as: same Mailing Address: p.0. Box 196612 E-Mail address: kristin.paul a~bp.com CitylState/Zip: Anchorage AK 99519-6612 Contact Person: Kristin 0. Paul Message Phone: Work Phone: (g07} 564-5612 Soc. Sec. # and/or Tax ID # Is applicant a nonprofit cooperative association? [ ]yes [X] no. If yes, are you applying for an exemption under AS 38.05.850(b)? [ ]yes [ J no. If yes, please submit proof of nonprofit status (e.g., by-laws, articles of incorporation, tax statement). Location of activity /Legal Descrip#ion: Municipality Meridian: Umiat Township: 13~ Range: 11E Section: 7, 8, 18, 19 _ 114, 114 Township: Range: Section: 114, 114 (attach extra sheets as needed) Total length of applied-for easement {feet): 9300 Acres encompassed by easement: -21 Total width of applied-for easement (feet): 100 (43,550 square feet = 1 acre) Specific purpose of easement (e.g., electric utility, fiber-optic conduit or cable, telecommunications tower, road, bridge, airstrip/airport, driveway, trail, drainage), and type of anticipated traffic (e.g., plane, ruck, heavy equipment): Explain: Portions of the injection well borehole are ou#side Milne Point Unit. No traffic expected. Are you applying for the Division of Mining, Land and Water to reserve a Public Easement? No Are you applying to be granted a Private Easement? Yes (Note: Annual rental fee required for private easement} 'See f 1 AAC 05.Of 0 regarding fees for federaE, state, and focal government agencies ^ Southeast Region 400 Willoughby, #400 Juneau, AK 9980'! Date Stamp: 102-112 (Rev. 10101} 1 w • _t'1te ,~i i r~1 :i,.~ an~J~~r_,~ ~:,d t _i _.h~-i~ c`r cunstt`u: "tier' ° y regulated ~! ~~ .3;_if~ _. ,;i "~'.~ u"il, C'tu ~~~;i:, _,~. , ~1 rc~,~3, r 9':'C--'d IO.i.~, F~~' ~~. 'aftf ; f"~ h-+flrl, C~F'~1'~Y1 ~1COt'iStt•IIC~lO! ~;i fYl iiCFtatlfCc'ti t'q Ui(~ti _r[ (~t~t." ~); ~~e c . ~j!_Ilt; rll'Ot `.O ~~~' u,, t'(j. ~ :). ,i ~~ ~5~). ~. ^ F ". In-~de ~, hydro-axe, D-8}, or esta~;li~hrn~nE by u ~ oniy. W~;I h~~s al~:~,:~,,~~ b,-gin ~:irlled. IS ff~is m ~tis;~_inta taS07 YES tf ye;~, p~UldB dOCllt'(lE.'1llati011'~~`E;ri ;ii~y Exf in0 i;: `~~. ..,UCh f: t.~tst;tn~~nt ~_~f€3S, ai3ir3a~~~t , at!es_inq to u. ~ and < ~i .~~~ ce, picture ~, etc. C'crstructiv~~ tit t ~~:~ir: ~ '-;t~;Y ;~ I~~ ~,~~rt~s~_ruction fo be cacwiet ~' i~~y: pail ~i,(lr C;tF,c,i ~:r~n'1Ets of authou ~sen~ a,~~~IierJ ;or in c~u;ju~~r,ti~tl ~~~iUi ll~.is pro~iur;arci proie;a, I r;s ir~;,~;t c,n ~~ell was pn ,~c,tsh~ ,gut ~ori~i:d under LU; tJ~ ~ ~-54 datr:.1 E; 1. ~05. Th<~ P;lilne Poin? Unit ro ,~..c__:r~ Ord AD~dR!~?OG ~e.~uas' i b ~' r3PXA sukm t ~ar E i.,e n~rf ~i ~~li ~,.'~r f,,r , is ti~elL If this au'hori_ationis rat„ntcd, I same u~ C'On~is'uc± 3fld rr '~ui?;aht tht>, im1.~t,~~~.taFi~ts ~t_ia ~n_ec ii; ~ ~werkr:anlink~: ra~nnE:r, rtntl trt keep the a1'e_i in 3 rtc:3t ~+r :~ ;ar~i!~}ry condikion; t~~ annE~h~ with :.111 ti_t ~ iaw , rul~~s..tn i raqulatiun_~ ~~::rlaining Uicrcto~ ai~~r3 pru.~ired h rfh~~.r :h.-~t tipor~ h.-rmination of t}i • c-~~s~~rnent ft;r r; Lich ':F,pm.:~ti~.~n r~ hf inr~ i~'~:id~-. 1 a,~rr e `o n.t.~nvr ~ r rF;l~.~ ~.~ th~~~ i~ ik~rn~~~< ~ iL~ ;,, :end rc;t~>re the ar<~~ witf,,u..t r:o~! i~~ thr: ~st .te ~7nd t~~ th~~ _, ti_,f~.~:r.ion or the C)ireCto~' ur the ,'~i~i±>n r.1 i~.~inii',l _.:;uj attd dater. i f~ ~ ~ 1 f ~_ - ` __ Fi Ak{~t ~:~nt's t ~n,t_r,~ .>~I .~ _ hl~k Date _ _-__, NC~ i FU%i JN~_. ,.' ~ i~ a~; ~ f,e ct i3^o01 or a statEi status ~'~al ~ w,n,l trio zili r:.~ f t-.; p ,r.t ~,.~~ ~.ne~t, an I + -: n. r-r r .;nLd -~.~ . ',n<,' n ; ~.~ , _ .-oc E ~ .,~ r~;, .vaikon of a pub!- p , c"1~:~ ~ wid ue ~a~mn.~ r~( ~,i„ ., . receipt rt a G ., ~ _I~i -. ~1r,;nil ~ I »lic~r~ .. i c,:~-~. ~ rr ',,'.f , .. ...a;iprov~d, ir3stnlettOnS 4. ~ tip ~.-,n~ie4±at of the plat r/~'~i Le :, ~~~~_I to yt~r:, cr . ~ . ~ ~-_ia ....: a, a n( ^.cr off -~,; ;;1 C5 _. ~,) a.t ] ~rcir• 1c declcSe wfi~;~t ~ ~~'c~rr urn i; .. ^~7cd Fo prxess a^ ~~ .;t;_~ fir tr;e si .~. rf ;t > Ierd .~~-d re nr~~~. lr~~,~; •r,r. ,ar.. ~ i ,.,~ t sr ~. ,~_ {,ublc tand rex;ord5 ;3m1 ~~ines ~ uo'. r_ tntORnattOi~ w~.ri i -. '.r. ? ...'.d 1l ._~ ~ i , ,~ - i I ...~-ia t . , it'^•, Scr i f. ~..~-nl t ..._ . _..,-,_ xt-~)(9?~ ~.lfi,;: nl i ..r_1„ ie.I?. F ~.,II+, lDfamaliQh i l ,~i by y , i . n ,t' _ ~ r. , i!J,Ic. ~,m : ~., f ,_, b)r 1 the f m il. ;;a m~~j°Chail ,~°,.1~ ~ir._ r.nl F.t r!lecy ~,>>td~i l~ttiu 44 4~ ~, ( ~'~.- a .,n~h-n r[=1 ~. ,t Rig eM.dr ^t ~n~a(--, In r~ char n ~. ..,. , .~~i ~:ef it, and a Harr ~ "rtr .,hnrc r ~. ~c ,., i i be ruched. F61se statarn~~n:; made In sri .u,~'~ ~ ;;hanfor a f3ee~.tit a . ~~ in ~n=,ci.. und~,~,AS 11 b Cr~,_ fit12-'t 12 Rev. 1 t3€~ 1 } 2 • • Milne Point ~,: ;- ; a ~ s ~1-, ~' ~b~~°~UQo ~ ~ havearakPoint ~ 4 ~ ~~ ~~ 4~~ `~~ ~D~~ ~ a q° d 'j ~~ y ~ ~~~ 00 0~y~~JaOCp d MPB-50 Q MPU , np o° ~ a C PAD ° a ~' ~ , ~tJ ;..J °~ a °c o p0 A oQo _ \ nip' J~a~V~ ®° ~, lj ~, ~ ~~°~ ~ ~nO Q MPU _ ~ y \~ ). - a ~ D PAD ti° ~ ~ `%J ~ ~ ~~a1 r~ ~;~ - o i~.G' ~~ r,~ _ ~ ~ - ~ . ~,,y ... . _.. ° ,-~~e °D., ~~. ~ o ~_~~p ~ ~ = ~ .MPU ~- ~ ~ t~~~~ ~ THIS PROJECT ,,, ° ~ ! B PAD ~~, r ° MPU ,u_~a - - o o~~, APAD `\ -, ; ~~~ '•s~ ~ MPU ~ .~, 1' ~ )~db°Q~ °~o ~`. -~ ~ ~ ~ ~ FACILIT ES `~- ~ '~ , -~' ~' a ~©~ o ~-. ~:~;t ~ e Q;.._,l °~ ~, PAD ~ /it e d p~,~! o e fI ba e o Rt ~~ ~,,'`' ADL0~74 _ `~~J~~ q~° - 9 ~U ~r~~ ' ~ ,~ ~~ eo ~ ~~ ~. 4` ', - - -~ ~ -= - MPll ~~ ~ o"v ~ ~ ~.J~ ~ 5~~9 ~ o °°• D ~ E PAD ~~ n o ° L „g r ~ 2S UU"" MPU ~ 26 ft ~ ~ ,~1~R ~~,°l f ~~ P \ ~~~ a ,, G PAD _ This map is based on U.S.G.S. quad Beechey Point (8-5) and on the Unit Operator's Facility Maps. ~~~~ PROJECT LOCATION: MILNE POINT UNIT - B PAD LAT. = 70° 28' 27.45" LONG. _ -149° 24' 42.56" X = 572,006.81 FEET Y = 6,023,428.30 FEET ALASKA STATE PLANE ZONE 4, NAD 27 MPB-50 BOTTOM HOLE LOCATION LAT, = 70° 29' 47.55" LONG. _ -149° 23' 3.82" X = 575,282.82 FEET Y = 6,031,604.69 FEET ALASKA STATE PLANE ZONE 4, NAD 27 SECS. 7, 18, 19 T13N Ri 1 E ADL047438 & ADL047432 DATUM: MEAN SEA LEVEL PURPOSE: DISPOSAL WELL ADJACENT PROPERTY OWNER: STATE OF ALASKA BP EXPLORATION (ALASKA) INC. _ ----- MILNE POINT UNIT B PAD DISPOSAL WELL VICINITY MAP ------ DATE: SCALE; FIGURE: April 2008 1" = 1 Mile 1 pm156~6 figl.dgn • A MPU B-50 Borehole Path 100 Foot Easement Outside MPU Boundary = 11 Acres I ~~ ~ MPU B-50 Borehole Path 100 Foot Easement Inside MPU Boundary = 10 Acres ~, ~ 0 ~~ ~ z c CL~ 0 1 e SS ~o ~~ ~~ Qd~~9~ ~ MPB-50 ~o ~ Q o a~~' O ~ ~ 7.8 Acres _ -- ~ ~~~ 1 J ~ . .: r Klilne Point Unit ~~ g ~ ~ ~ -_ - / :. ;. w - \ ~ ~ ~~ ` ~ t 3.2 Acres per"----~ ~ ~ C~ ~-° ~~ q t ... ~ ~. ~~ ~ i 1' n ~ ~ "~ ; . ~U MPU ^~ ~~ ,. D PAD °~ `~ ~~ a ^' ,J J X11 ~, ,, cJ "" i ~ 1 ~~ ~ ~~ ~ ~ ° ~~ *~ `~ ~~~`°~~ 3.2 Acres `~ ~~ ~ nu o c ~ _~ ~ j / , ~ ~, V ~<~- ° .~ ~~ `~ ? O ~~ ,P ~ g ~ o 3> ~ 3 ~ ~ } ~' '~~ ~> > 6.8 Acres ~ (~ _; Au{ ~~~JJJ ~ t ~ J1 k ~ ~,~ ~' -' _ '~ ~ ~~ ~ M ~ '" ~ ~ 4 ~~~~ - ~ ~ _ ,~~ BPAD ~~ i ~ ~ b = ~ ~ - o ( _ s o, _ ~., ~ ,~ _ RA A N ~ ~ BP EXPLO TION ( LASKA) I C. ~,-~ Q ~ , `, ~~ _ __ _.__. 1 - ... .............._____ _ ._._._ __. \' `a / y J ~ ~.~Jt o MILNE POINT UNIT :a.> ,~ o ~ •~~-, BPAD . ~~ °°°~ U DISPOSAL WELL _~-~~ ~~''~ o~ ~" LOCATION MAP J j ' J~ --_ ____. ........_-_- _ ....... .___ pQ. DATE SCALE: FIGURE: June 2008 1" = 1500' 2 pmt 5646.dgn Recent MITIAs for MPG-17 (PTD #2040130), MPB-50 (PTD #2042520), B1-O1 (PTD #197157... Page 1 of 1 Regg, James B (DOA) • • From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, April 13, 2008 11:13 AM \~~~ 4 f t~ ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA} Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; McLeod, Jennifer D; Younger, Robert O; MPU, IM Field Coordinator; MPU, IM Facility Coordinator; MPU, Wells Ops Coord; MPU, Wells Ops Coord2 Subject: Recent MITIAs for MPG-17 (PTD #2040130}, MPB-50 (PTD #2042520), B1-01 (PTD #1971570), 16- 11 (PTD #1801180), N-08A (PTD #2000090), and W-24 (PTD #1880700) Attachments: MIT MPU G-17 04-12-08.x1s; MIT MPU B-50 04-10-08.x1s; MIT BAD B1-01 04-11-08.x1s; MIT PBU 16- 11 04-09-08 .xls; MIT PBU N-08A 04-09-08.x1s; MIT PBU W-24 04-09-08.x1s Hi Jim, Tom, and Bob, Please find the attached MIT forms for MPG-17 (PTD #2040130), MPB-50 PTD #2042520), B1-01 (PTD #1971570), 16- 11 (PTD #1801180), N-08A (PTD #2000090), and W-24 (PTD #18 .0700) MPG-17: 4-yr UIC Compliance MIT-IA, inspector declined witnessing the test IIPB-50: Annual EPA Class 1 Disposal Well Compliance MITIA, witnessed by Thor Cutler and Talib Syed for the EPA B1-01: Annual EPA Class 1 Disposal Well Compliance MITIA, witnessed by Thor Cutler and Talib Syed for the EPA 16-11: MITIA post initial injection, witnessed by AOGCC Inspector Chuck Scheve N-08A: 4-yr UIC Compliance MITIA and for MI service, witnessed by AOGCC Inspector Chuck Scheve W-24: 4-yr UIC Compliance MITIA and for MI service, witnessed by AOGCC Inspector Chuck Scheve «MIT MPU G-17 04-12-08.x1s» «MIT MPU B-50 04-10-08.x1s» «MIT BAD B1-01 04-11-08.x1s» «MIT PBU 16-11 04-09-08 .xls» «MIT PBU N-08A 04-09-08.x1s» «MIT PBU W-24 04-09-08.x1s» 4/15/2008 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 ~~6' ~) I~)~~ Milne Point /MPU / B-Pad l / 04/10/08 Mel iveson Packer De th Pretest Initial 15 Min. 30 Min. Well MPB-50 , T e In'. W TVD 3,890' Tubing 954 954 954 954 Interval O P.T.D. 2042520 T e test P Test si X1500 Casing 3,580 3,560 3,580 P/F P Notes: MIT-IA for.annual EPA Class 1 compliance. OA 120 370 370 370 Extened test an additional 15 min. T/I/0 = 954/3580!370. Test witnessed b Thor Cutler and Talib S ed for the EPA. Well T e In~. TVD Tubin Interval P.T.D. T e test Test si Casing P/F Notes: OA Well T e In~. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well Ty e In'. TVD Tubin Interval P.T.D. Ty e test Test si Casin P/F Notes: OA Well T e In'. TVD Tubin Interval P.T.D. T e test Test si 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 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 MIT MPU B-50 04-10-08.x1s • • ~, .Y.,,`f ,;'~~ .~-: __ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.~c . . Date 10-26-2007 Transmittal Number:92916 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 REPROCESSED SONIC DT MPB-50 02-21-2005 SCH 1 2794 8206 COMPRESSIONAL CD ROM U~ :Jð({ -.:1<;'";) it IS3c..~ Sf, ~ANNEC OCT 3 1 ZU )f , ,~ ~:,E..l?~'l f::: t) ~.JiA Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petro technical Data Center Attn: Christine Mahnken Kristin Dirks AOGCC DNR Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 .3 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well W-19Al1 17-19A V-04 Z-21A Z-03 05-38 Y -29A B-16 Z-22B Z-14B P2-45A 17-09 F-33 4-08/P-27 3-17F/K-30 MPB-50 S-125 Job# 11890312 11855512 11855513 11594526 11767142 11686787 11855514 11676969 11594525 11849935 11594529 11846820 11661176 11630506 11649961 40011604 40015467 S;cANNED OCT 8 1 2007 log Descrl bon SBHP & TEMP ;::)^~ - ::::)":-=<.~ SBHP SURVEY lo,~-f1ç:z:~ SBHP SURVEY .:-l{)CLJ -l~<:'-/ SBHP SURVEY ~) -I () ¡ lDl I CI"'.J.._~ I lDl ICJL - J {~ DDl ID¡( ð - ""A ( PRODUCTION PROFilE t--::¡c -()/)5 SBHP SURVEY - ~hlA-- ¡:::;¡^,..u, SBHP SURVEY ~. ')(0 --cA"i SBHP SURVEY I C. <:t -tY-I (.1 lDl /1(1- (")C {J MEMORY SBHPS I qú, - (~~ lDl () --rr' I ~ +- - bòtÇ MCNl ~()'?-. -::lIt". -It IIÇ{~/L/ OH MWD/lWD EDIT Ü I (\ !::'JNJ - X;;) 15C".,f...'<. OH MWD/lWD EDIT "'?O":}-()'1f?- t.t ,~{,Q. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Date 09/29/07 09/26/07 09/27/07 10/07/07 10/01/07 09/27/07 09/28/07 10/12/07 10/06/07 10/02/07 10/16/07 10/19/07 10/19/07 10/04/07 04/17/07 02/27/05 07/14/07 NO. 4464 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/25/07 Bl 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 2 2 Color Field: P.Bay, Endicott, Aurora, Miln'~ Pt., pt. Mac CD 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth Received by: . . 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 OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP ACT / Milne Point / B-Pad 04/11/07 Lee Hulme Waived by Chuck Scheve. SCANNED APR 1 7 2007 Packer Depth Pretest Initial 15 Min, 30 Min, Well MPB-50 Type Inj, W TVD I 3,890' Tubing 770 770 769 769 Interval I 0 PTD, 2042520 Type test P Test psi 3500 Casing 13 3,580 3,530 3,522 P/F P Notes: 5,5 bbls 60/40 MeOH to 3580 psi. bled back to 50 psi. OA 231 450 440 445 Class 1 injector, One year MITIIA Injection temp 110 deg, MeOH injected for the test was 45 deg Well Type Ini. W TVD I Tubing Interval P,T,D, Type test I P Test psi Casing P/FI Notes: OA Well Type Inj. W TVD I Tubing Interval PTD, Type test P T est psi! Casing P/F Notes: OA Well Type Inj, TVD Tubing Interval PTD, Type testl T est psi! Casing P/F Notes: OA Well I Type Ini.l TVD I Tubing Interval I PTD, Type test Test psi Casing P/FI 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 6FL 9/1/05 M IT M PU 6-50 4-11-07 ,xis /~ ~ DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042520 Well Name/No. MILNE PT UNIT SB B-50 Operator BP EXPLORATION (ALASKA) INC 5/~ 1?1::¿~.)..ùc,} API No. 50-029-23240-00-00 MD 11370-- TVD 5062 Completion Date 3/12/2005"/ Completion Status WDSP1 Current Status WDSP1 UIC Y ~----_._~.~------~-- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -.---..------..-- --.,----.-- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, IFR/CASANDRA, ACAL, NEW, DEN, SONIC, PWD, Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr e Data Digital Dataset Log Log Run Interval OH/ t: Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 0 11370 Open 4/27/2005 IIFR D Asc Directional Survey 0 11370 Open 4/27/2005 MWD V!o D l:J.FJ.., ~ 13170 I nd uction/Resistivity 88 11334 Open 6/14/2005 MWD: GRlEWR4/CNP/SLD/ACAL [ftpt /BAT 13170 LIS Verification 88 11334 Open 6/14/2005 MWD: GR/EWR4/CNP/SLD/ACAL /BAT ..(Ó C Pdf 13530 Gamma Ray 115 11370 Open 2/22/2006 DGR Dual Gamma Ray BAT Bimodal Acoustic Tool 4 C .ßëf Li'> 13530 Gamma Ray 115 11370 Open 2/22/2006 DGR Dual Gamma Ray c/ BAT Bimodal Acoustic Tool ED C Pdf 13530 Porosity 115 11370 Open 2/22/2006 DGR Dual Gamma Ray SLD Stabilized Litho- Density CTN Compo e Neutron Porosity ACAL Acoustic Caliper \olD C Pdf 13530 Rate of Penetration 115 11370 Open 2/22/2006 ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic fleD Wave Resistivity C .e.ef [..1 S 13530 Rate of Penetration 115 11370 Open 2/22/2006 ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic ~ Wave Resistivity C F2èf ¡,.r) 13530 Porosity 115 11370 Open 2/22/2006 DGR Dual Gamma Ray SLD Stabilized Litho- Density CTN Compo Neutron Porosity ACAL Acoustic Caliper DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042520 Well Name/No. MILNE PT UNIT SB B-50 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23240-00-00 MD .. 11370 TVD 5062 Completion Date 3/12/2005 Completion Status WDSP1 Current Status WDSP1 UIC y ~- Water Flow Blu 8050 9916 5/8/2006 RST/CCL/GRlPRESITEMP ~g 20-Apr-05 Caliper log 5 Col 100 8300 5/8/2006 PMIT/GUCCLlPRESITEMP r' **No Temp** 19-Apr-2005 ~ C.."'" "'" '\ E-fI...~1._ 5 Col 4500 11234 Case 5/8/2006 Ultra Sonic Imager USI Cement Mode Unit 8-Mar- 2005 Well Cores/Samples Information: e Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ...::u..N--' Daily History Received? VN f)/N Formation Tops Analysis Received? 'r1Ñ ~--'---'~'--'-'-" Comments: .------.-"-- ~ -_._-~ Date: J~ fJp~7 e Compliance Reviewed By: RE: NS 17 (PTD #2021690) 4-year MITIA for Regulatory Compliance -- e Tom, The MITs on NS10 and NS32 are just the normal IA pressure tests. Talib JO~-dS-d is flying to the slope on 4/10. His schedule is to go to Milne Point on ~ 4/11 {MPB-501, .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 f¡;.rther. Thanks, Andrea Hughes -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.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 wTote, 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 s·everal 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 follmving 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 Scblumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# 10980545 10980546 N/A 10987542 N/A MPB-50 MPB-50 MPF-93 MPJ-18 MPB-50 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 dc;'d ~/ Log Description MULTI-FINGER CALIPER WFL BHP SURVEY USIT USIT Date 04/19/05 04/20/05 07/23/05 08/16/05 03/08/05 NO. 3789 Company: State of Alaska Alaska Oil & Gas Cons Comm Alln: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color 1 CD 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 05/05/06 . . (,( ¡ q '; 1,,'1.. 0.;\-0 ,. Scblumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# 10980545 10980546 N/A 10987542 N/A MPB-50 MPB-50 MPF-93 MPJ-18 MPB-50 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 {Ç)- "./d d()~ Log Description MULTI-FINGER CALIPER WFL BHP SURVEY USIT USIT Date 04/19/05 04/20/05 07/23/05 08/16/05 03/08/05 NO. 3789 Company: State of Alaska Alaska Oil & Gas Cons Comm Altn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL CD Color 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 05/05/06 t",( ¡q';\/\.o.;\-or . . Sc~lIn~epger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Well MPB-50 MPB-50 MPF-93 MPJ-18 MPB-50 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Job# 10980545 10980546 N/A 10987542 N/A g04 - gCd-. Log Description MULTI-FINGER CALIPER WFL BHP SURVEY USIT USIT Date 04/19/05 04/20/05 07/23/05 08/16/05 03/08/05 NO. 3789 Company: State of Alaska Alaska Oil & Gas Cons Comm Altn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color 1 CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 05/05/06 . . It - 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 OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration ( Alaska) inc. ACT / MPU / B-Pad 03/04/06 Mark O'Malley ( EPA) Tallib Syed '~ê1f ?:/Iq-(¡)G ~ù1..\ 0# ~ 5~ Packer Depth Pretest Initial 15 Min. 30 Min. wellMPB-50 Type Inj. W TVD I 3,890' Tubing 8501 8501 850/ 8501 Interval 0 P.T.D. 2042520 Type test P Test psi 3,500 Casing 3,515 3,496 3,467 P/F P Notes: OA 146 320 284 255 weill Type Inj. I T:~PSil TUbingl I I I Intervall P.T.D. Type test Casing Notes: OA well Type Inj. I T:~PSil TUbing I I I I Interval I P.T.D. Type test Casing P/F Notes: OA weill Type Inj. I T:~PSil TUbing I I I I Interval I P.T.D. Type test Casing P/F Notes: OA weill I Type Inj. I T:~PSil TUbing I I I Interval P.T.D. Type test Casing P/F Notes: Annual EPA MIT of class one injection well OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater 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 SUlvey A = Temperature Anomaly SUlVey 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) MIT MPU B-50 03-04-06-1.xls . . 0J WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 135~ RE: MWD Formation Evaluation Logs MPB-50, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPB-SO: LAS Data & Digital Log Images: 50-029-23240-00 !itA- - ¿V'5 }- , 1 CD Rom û~~ 919l1IDLo BP Milne Point B50 Class I Disposal Well Qtrly Report -- e Thor, ~~ $ d,9lf·-;µS;;¡-~ While compiling the data for the first quarterly report (2Q '05) for our new Class I injection well, we discovered some glitches in the graphs and data tables. We implemented a new automated data collection/reporting system during the quarter, and it has taken a bit of effort to reconcile data collected by the old system when it was still active, and the new system, once it went online. We have held off submitting the quarterly report until all of these glitches were ironed out. As of now, everything is on track with the exception of a possible IA pressure exceedence on May 1 st. The data indicates a reading of 1001 psi, and our permit limit is 1000psi. We are currently investigating this potential exceedence. Hopefully we'll be submitting the quarterly report early next week, and wanted to advise you of the situation and the potentiallA pressure limit exceendence. Based on the progress we've made streamlining the reporting system lately, I'm confident that our next report will go much smoother. If you have any questions, please feel free to call me. Thank you, David Dawley ACT Environmental Advisor 907-670-3382 I of 1 8/8/2005 12:44 PM .. STATEOFALASKA . ALASKA WL AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,... '" 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC25.105 20MC25.110 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , ACAL , NEU , DEN, SONIC, PWD , US IT CASING, LINER AND CEMENTING RECORD SffllNG DEPTH MD SffllNG DEPTHTVD IHoLE Top BOTTOM Top BOTTOM SIZE 35' 114' 35' 114' 42" 35' 2921' 35' 2520' 16" 33' 8296' 33' 3939' 12-1/4" 8154' 11370' 3903' 5062' 8-1/2" o GINJ 0 WINJ a WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 5144' NSL, 4062'WEL, SEC. 19, T13N, R11E, UM Top of Productive Horizon: 1910' NSL, 1374' WEL, SEC. 07, T13N, R11E, UM Total Depth: 3169' NSL, 889' WEL, SEC. 07, T13N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 572232 y- 6022990 Zone- ASP4 TPI: x- 574819 y- 6030341 Zone- ASP4 Total Depth: x- 575286 y- 6031605 Zone- ASP4 18. Directional Survey 0 Yes a No 22. CASING SIZE WT. PER 94# 68# 47# 26# H-40 L-80 L-80 L-80 20" 13-3/8" 9-5/8" 7" 23. Perforations op'en to Production (MD + rvD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5 SPF MD TVD MD TVD 9890' - 10000' 4447' - 4493' 10060' - 10130' 4517' - 4545' One Other 5. Date Camp., Susp., or Aband. 3/12/2005 6. Date Spudded 2/18/2005 7. Date T.D. Reached 3/4/2005 8. KB Elevation (ft): 57.90' 9. Plug Back Depth (MD+ rvD) 11324 + 5043 10. Total Depth (MD+rvD) 11370 + 5062 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. SIZE 7", 26#, L-80 I TCII 25. Revision: (j"7í01J05iStâl1lnjection J\ ;'1 ;; 1b. Well£IáSs:'> , DDevelopment 0 Exploratory o Stratigraphic a .~rvice 12. Permit to Drill Number 204-252 13. API Number 50- 029-23240-00-00 14. Well Name and Number: MPB-50 15. Field / Pool(s): Milne Point Unit I Ugnu & Schrader Bluff Ft Ft 16. Property Designation: ADL 047432 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PULLED 260 sx Arctic Set (Approx.) 533 sx Arctic Set Lite, 304 sx 'G' 212 sx LiteCrete, 577 sx Class 'G' 638 sx Class 'G' RECORD DEPTH SET (MD) 8159' PACKER SET (MD) 8102 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 160 Bbls of Diesel 26. Date First Production: April 21, 2005 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ~ Press. 24-HoUR RATE""" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS 8Ft ,'Iii O~¡[lŒì None "7~?~S-- PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BsL GAs-McF WATER-BsL OIL-BsL Form 10-407 Revised 12/2003 GAs-McF WATER-BsL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) ~f- ~-'."i 28. GEOLOGIC MARKERS. NAME MD TVD BPRF UG3 TUZC MA MB1 MB2 MC SBF2-NA SBF1-NB SBE4-NC SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 2055' 6161' 9020' 984 7' 9862' 10036' 10456' 10560' 10610' 10667' 10705' 10738' 10830' 10900' 10994' 11090' 11172' 1972' 3398' 4139' 4430' 4435' 4507' 4682' 4726' 4747' 4772' 4788' 4802' 4840' 4869' 4909' 4947' 4981' 30. List of Attachments: Post Rig Summary 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ T'tl T h· IAs' t t D t Dl-c""'I-DS Sondra ~ewman F'v~/ ~ µ ~ I e ec nlca SIS an a e . / MPB-50 204-252 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Walter Quay, 564-4178 Permit No. / Approval No. INSTRUCTIONS GENERAL: This fonrn is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this fonrn and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . Well: Field: API: Permit: MPB-50 Milne Point Unit/Ugnu & Schrader 50-029-23240-00-00 204-252 J\¿~èpt: Spud: Release: Rig: 2/17/05 02/18/05 03/12/05 Doyon - 14 POST-RIG WORK 03/29/05 PUMP PRODUCED WATER AND METH DOWN TBG @ STEP PRESSURE PROCEDURE FOR INJECTIVITY TEST. ESTABLISHED FINAL RATE AT 5.2 BPM @ 925 PSI. 04/01/05 TAGGED TD AT 98B2' WLM (- 9908' MD CORRECTED FROM 3/26 TAG). 04/12/05 PRESSURE TEST FL TO 3600 PSI. 04/18/05 FREEZE PROTECT TBG WI 50 BBLS 60/40 METH. 04/19/05 LOGGED TEMPERATURE - PRESS BASELINE FROM SURFACE TO TD. LOGGED MULTI-FINGER CALIPER UP FROM TD TO SURFACE. NO ANOMALIES SEEN. 04/20/05 LOGGED WATER FLOW STATION LOGS AT 9850',9800',9750',9510',8200',8125', AND 8050'. LOGGED TEMPERATURE COOL BACK PASSES FROM TD TO 6100' AT 1.75 HRS AFTER SHUT IN AND 3 HOURS AFTER SHUT IN. 04/24/05 T/I/O=500/440/220. MIT - IA TO 3600 PSI PASSED. (AOGCC WITNESS, JEFF JONES). PRESSURED IA TO 3590 WITH 5 BBLS OF 60/40 METHANOL. STARTED 30 MIN TEST. IA LOST 20 PSI IN THE 1ST 15 MIN AND GAINED 50 PSI IN THE 2ND 15 MIN. EXTENDED TEST AN ADDITIONAL 15 MIN TO SHOW STABILIZATION. NO CHANGE IN lAP. BLED IA DOWN TO 440 PSI. WELL INJECTING 12000 BBLSI DAY, PINCH BACK TO 5000 BBLSI DAYTAGGED TD AT 9918' CMD WHILE INJECTING AT 5000 BBLS I DAY 5/25/05 WELL HAS BEEN ON THE UIC REPORT. PRESSURES INDICATE THAT THE CHANGES ARE A BY- PRODUCT OF INJECTION RATES AND TEMPERATURES. THE IA PRESSURE WAS RAISED FROM 350 TO 500 PSI TO GENERATE A LARGER SPREAD BETWEEN THE IA AND THE OA. ~fSJ 1rT-4~ i ft ~ \_f ~( "R01'é-Ú~~ UNITED~TES ENVIRONMENTAL.PROTECTION_NCY REGION 10 1200 Sixth Avenue Seattle, WA 981 01 Reply To Attn Of: OCE-082 2 6 MAY 2005 CERTIFIED MAIL· RETURN RECEIPT REQUESTED Ms. Janice L. Vosika BP Exploration (Alaska) Inc./BPXA Milne Point Delivery Manager 900 East Benson Boulevard P.O. Box 196612 Apchorage, Alaska 99519 ~L\ - d--S d-- Re: Final Approval to Inject into UIC Class I Milne Point Unit - B Pad Area (MPB-50) Well, UIC Permit No. AK-1I005-A Dear Ms. Vosika: This letter is in follow up to the April 21, 2005 letter of Interim Approval granted to BPXA to commence injection operations at the Milne Point B Pad-50 Class I non-hazardous well (MPB-50) under Environmental Protection Agency (EP A) Underground Injection Control (UIC) Permit number AK-lI005-A. The EPA has reviewed the Completion Report for well MPB-50 submitted by BPXA dated May 7, 2005, as required in Part II C.1 of the EP A UIC perrnit and has determined that it is adequate. BPXA is now being granted Final Approval status for injection into MPB-50. The Class I injection well currently approved under Perrnit Number AK-II005-A is MPB-50. This permit became effective November 2,2004, and will expire midnight, November 2,2014. We appreciate the cooperation of your staff during the planning, permitting, construction, testing and operating phases of the well that serves as an example in leadership for industry in environmental management of waste in the exploration and production field under harsh sensitive environments. Please call Thor Cutler, a member of my staff at (206) 553-1673 if you have any questions or need additional clarification. Sincerely, DelmrcJ, ç: ~ 11 '" Michael A. Bussell, Director r W Office of Enforcement and Compliance cc: Thor Cutler, USEP A Seattle John Norman, AOGCC Anita Frankel, EP A Seattle Theodore Rockwell, EP A Anchorage Marcia Combes, EP A Anchorage Sharmon Stambaugh, ADEC, Anchorage Talib Syed, TSA o Printed on Recycled Paper Tree: Cameron 7", 5_ Wellhead: FMC 11" x M, Gen. 5 wI 13-518" x 7" C Tbg. Hgr. wI T' TC-11 Top & Btm 7" CIW 'J' BPV profile ..g. KB. elev. = . GL. elev.= 23.8' g. DF. elev. = 57.9' MPU B-50i ~ 115' I 20" 92 ppf, H-40 KOP @ 300' Max. hole angle = 63 to 75 deg. fl 2800' to 9,150' Max 80 deg. @ 3609' Hole angle through perfs = 66 deg. 13-3/8",68 ppf, L-80 BTC I 2,921' I- 13-3/8" 68 ppf, L-80, BTC prod. csg. ( drift ID = 12.415", cap. = 0.1497 bpf) 9-5/8" 47 ppf, L-80, BTC-M prod. csg. ( drift ID = 8.681", cap. = 0.0732 bpf) 7" 26 ppf, L-80, TC-11 prod. csg. ( drift ID = 6.151", cap. = 0.0383 bpf) Note: Approx. 5' of mule shoe in tie back Weatherford Float Collar I 8,209' I I Weatherford Float Shoe I 8,296' I ... Perforation Summary Ref log: MWD Drill pipe conveyed Size SPF Interval (TVD) Ugnu MB-01 4.5 5 9,890' - 10,000' 4,447'- 4,492' æ Ugnu MB-02 § 4.5 5 10,060' - 10,130' 4,517'- 4,545 ~ Weatherford Float Collar Weatherford Float Shoe 111,324'1 111,370'1 · 7" HES "R" Nipple ( 5.963" id) I 2,020" Ii 7" HES "R" Nipple ( 5.963" id ) I 8,040' I 9-5/8" x T Baker S-3 Prod. pkr. I 8,102'1 7" HES "R" Nipple ( 5.963" id ) I 8,126'1 7" HES "RN" Nipple (5.963" id) 18,148' 1 ( No-Go 5.770" Id ) 7" Muleshoe I 8,159' I ï 9-5/8" x T Baker Tie Back Slv. I 8, 154' 1 . Baker C-2 ZXP liner top pkr. 18,167' I Baker liner HMC hanger I 8,172' I - ¡¡ ¡¡ DATE 03/12/05 REV. BY COMMENTS MOO Drilled and completed by Doyon-14 MILNE POINT UNIT WELL MPB-50i API NO: 50-029-23240-00 BP EXPLORATION (AK) )ò "1- ~ rÂ MEMORANDUM State of Alaska .,---- TO( ~rr:- Regg ,\) / . ' ~ super;isorl\e.rc¡ 5 (~O5' ~ - , FROM: Jeff Jones Petroleum Inspector Alaska Oil and Gas Conservation commi.· DATE: Tuesday, May 03, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B-50 MILNE PT UNIT SB B-50 Src: Inspector Reviewed By: 1ZSe- P.I. Suprv, , Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB B-50 Insp Num: mitJJ05050212473 I Rei Insp Num: API Well Number: 50-029-23240-00-00 Permit Number: 204-252-0 Inspector Name: Jeff Jones Inspection Date: 4/24/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I B-50 I . I IA ¡Type InJ. I S TVD 3890 I 440 3590 3570 3620 3620 ! P.T. I 2042520 ITypeTest i SPT Test psi 972.5 I OA 220 310 280 300 300 Interval INITAL P/F P Tubing 500 500 500 500 500 Notes: Test held for additional 15 minutes to further demonstrate integrity. I well house inspected; no exceptions noted. Tuesday, May 03, 2005 Page lofl Re: BP Milne Point: B-50 Class I Well Temporary Malfunction ofi... Ron Youngs, ACT Env Advisor Ron, thanks for the heads up on the auto flow meter. I trust that you will be able to find a fix as you successfully work through the initial months of operation at B-50. (It it isn't one thing, it's another, but I have faith that you'll continut to keep on top of it all, like usual) It's good that you are keeping track of the activities while the meter is sporatic. Lets hope that the auto meter is fixed so that you don't have to continue to track things by hand (or on paper) . A suggestion: It may be of value to have a "upper limit" estimate of how much may have flowed past the meter based on known facts (ie typical rates, and period of down time) so that we can, if need be, report order of magnitude volumes that flowed for a given period. Like any shake down cruise, we'll be in the discovery mode for a while. Thank you for keeping me informed like this Ron. later, Thor Cutler 206-553-1673 fax 206-553-0151 cutler.thor @epa.gov "ACT, ENV Advisor" To: talibs@ecentral. com, Thor Cutler/R10/USEPA/US@EPA <ACTENVADVISOR@BP cc: jim regg@admin.state.ak.us, Trevor Fairbanks@dec.state.ak.us, "MPU, . com> Facilities Supervisor" <MPUFacilitiesSupervisor@BP.com>, "MPU, Facility Lead Tech" <MPUFacilityLeadTech@BP.COffi>, "MPU, Field Lead Tech" <MpuFieldLeadTech@BP.com>, "MPU, 05/09/2005 06:35 Operations Manager" <ACTOperationsManager@BP.com>, "MPU, Well Operations Supervisor" PM <welloperationssupervisor@BP.com>, "Cooke, Alison D" <CookeAD@BP.com>, "MPU, Envirotech" <MPUEnvirotech@BP.com>, "Dawley, David M" <DawleyDM@BP.com> Subject: BP Milne Point: B-50 Class 1 Well Temporary Malfunction of injection flow meter lof2 5/10/20059:37 AM Re: BP Milne Point: B-50 Class I Well Temporary Malfunction of i... . . This is a courtesy notification of sporadic, short duration malfunctions (April 26, 27, 29, 30, and May 9, 2005) of the electronic flow meter, which measures flow from the Milne Point process facility to the B-50 Class 1 UIC well. For the April incidents, it is suspected that episodic break out of oil in the produced water being pumped to well B-50 temporarily interfered with the normal operation of the flow meter. A new meter, that is not susceptible to oil interferences, will be ordered and installed. The missing flow data on May 9, 2005, resulted from an automation glitch that occurred while technicians were performing work on the electronic data system. Please give me a call if you have any questions on this courtesy notification. We will also address this issue in the Milne Point Class 1 Well UIC permit quarterly report. RON Ron Youngs ACT! Environmental Advisor Phone: 907-670-3382 (MPU) 907-659-6592 (End) 907-659-0603 907-670-3175 Cell: Fax: 20f2 5/1 0/2005 9:37 AM e . clOL\-d-S~ MECHANICAL INTEGRITY REPORT' '.. ::?UD DA!:::: ~ d-/\'ìs -bCS' .' =.IG RELE;_SE:· ">/~?;-(J~ OPER & FIELD -\:S? ~\\~~ ~ \- k"ELL NUMBER \-\ Y 'ß - sO _JD~~g: ~5/~ ~ '\ TD: \\S~Ò .rID.. St>~:J- TVD; ?BTD: ~\~d\..\ HI) 5043 TVD Shoe: ~ð<1 <0 till -SC; ~<1 TVD; DV: ~ ~ MD ~ ~ ·Tvu ~~LL DATA Ca.sir:g: ::-:'ole: Siz.e Shoe: \\~~D MD Sáb'd-TVD j :CP: .8 \S~ rom S<:JO-S:'.JD Packer %\0:>-· MD TVD¡ See ê.t 'ö\S~ \ ~\I,-\ a.na. <fs \()- P er£3 ~~\:) to \ ÒOOO \ (JÖ'=>O \b\ 'šcJ _:..:-¡e-.: : :-s C?.Þ_NI C;..L INTEGRITY - PART f 1 Annulus Press Test: II' ¡ 15 min 30 min Cot:ì:I8ents: ., x.('<ëC;c;.\-~\ M.\\':::. \-..()..~<è. ~~~ ~~""-~ ,,- :-ŒCHÞ_1\ECÞ..l. INTEGRITY - PART ¡ 2 d \à \.:~c..M- Cement:. Volumes :'. .Amt. Liner CoS%c¡.,~\.? i Csg S'\"'\~,,\.,; DV N~ . C¡:¡:¡t 701 to cover perfs ð'ì.~~"(: G ~O~~~~~, ~~'t ~~ f(\~S 5t:::f::J' . Theorecical Toe \ \Nê'--~\\"\. C~Iè."-~ c-,,,,-;J~ ~~.\- n~+ \0", ê)~\'\V'G:.r-' . v~ \ '\ ~/~-oç' Cement Bond Log (Yes or No) '<.t> ; In AOGCC File "'\,E-> . CBL -=:valuation, z.one a.bove perfs ~\\ \\~ ~o¥_<t",~\.\~~~ (\ . c. __I 'N~\ \ \0 0 ~'è),,~ \' ~ - "'t S'<::)~ t 1"Cc.. -t-~'ro>';:)S~~~~~ \ \ \~~ \"" ~\ ~ ~ \'ço.~",t~ ~~' ~ <ø6(x)--S~W Produ~tion Log: Type Evaluation . \ í CONCLUSIONS: J ?art . il, "r v:>c..~ ~ov-tð"S~~ ? ar~ : Z: ~::s: ~ ",,,,'B t"C-CÅ..-~~ Æ 'Îfv15IS-oÇ- . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPB-50 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 11,370.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Signed ~L 6W Date t??ldvf~i- Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 25-Apr-05 Åotf-~f'J- . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPB-50 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 11,370.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date;) '11Þp~l- Signed 11~ IJi4 Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 25-Apr-05 /? 6 '-1- ) .C.z. · STATE OF ALASKA .. ALASKA ~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC25.105 20AAC25.110 21. Logs Run: MWD , GR , RES, IFR/CASANDRA , ACAL , NEU , DEN, SONIC, PWD , US IT CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTHTVD HOLE Top BOTTOM Top BOTTOM SIZE 35' 114' 35' 114' 42" 35' 2921' 35' 2520' 16" 33' 8296' 33' 3939' 12-1/4" 8154' 11370' 3903' 5062' 8-1/2" o GINJ 0 WINJ a WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 5144' NSL, 4062' WEL, SEC. 19, T13N, R11E, UM Top of Productive Horizon: 1910' NSL, 1374' WEL, SEC. 07, T13N, R11E, UM Total Depth: 3169' NSL, 889' WEL, SEC. 07, T13N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 572232.... y- 6022990' Zone- ASP4 TPI: x- 574819 y- 6030341 Zone- ASP4 Total Depth: x- 575286 y- 6031605 Zone- ASP4 18. Directional Survey a Yes 0 No 22. CASING SIZE WT. PER FT. 94# 68# 47# 26# GRADE H-40 L-80 L-80 L-80 20" 13-3/8" 9-5/8" 7" 23. Perforations op'en to Production (MD + TVD of TOE and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Gun Diameter, 5 SPF MD TVD MD TVD 9890' - 10000' 4447' - 4493' 10060' -10130' 4517' - 4545' 26. Date First Production: Not on Injection Date of Test Hours Tested One Other 5. Date Camp., Susp.. or Aband. 3/12/2005 6. Date Spudded 2/18/2005 7. Date T.o. Reached 3/412005 8. KB Elevation (ft): 57.90' 9. Plug Back Depth (MD+ TVD) 11324 + 5043 10. Total Depth (MD+TVD) 11370 + 5062 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. SIZE 7",26#, L-80 I TCII RËCË/VËD APR 1 9 2005 Alaska Oìl & Gas C 1b. Well Class:Anchn on.. Con,,'tf$sIo,l o Development Dr~~oratory o Stratigraphic a Service 12. Permit to Drill Number 204-252 13. API Number 50- 029-23240-00-00 14. Well Name and Number: MPB-50 15. Field / Pool(s): Milne Point Unit I Ugnu & Schrader Bluff Ft Ft 16. Property Designation: ADL 047432 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) CEMENTING RECORD 260 sx Arctic Set (Approx.) 533 sx Arctic Set Lite, 304 sx 'G' 212 sx LiteCrete, 577 sx Class 'G' 638 sx Class 'G' TUBING RECORD DEPTH SET (MD) 8159' PACKER SET (MD) 8102 25. A¢ID,FRA¢TURE,iCEME;NT SQUEEZE;, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 160 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL-BsL GAs-McF WATER-BsL PRODUCTION FOR TEST PERIOD .. CALCULATED ...... 24-HoUR RATE-," OIL-BsL Flow Tubing Casing Pressure Press. GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFL APR 2 9 2005 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE (~f :J 28. . GEOLOGIC MARKERS NAME MD TVD BPRF UG3 TUZC MA MB1 MB2 MC SBF2-NA SBF1-NB SBE4-NC SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 2055' 6161' 9020' 9847' 9862' 10036' 10456' 10560' 10610' 10667' 10705' 10738' 10830' 10900' 10994' 11090' 11172' 1972' 3398' 4139' 4430' 4435' 4507' 4682' 4726' 4747' 4772' 4788' 4802' 4840' 4869' 4909' 4947' 4981' 29. .RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed son~~~;~·~~'t>\~J-~"'___ Title Technical Assistant Date ()Li -l ß-C~ 5 MPB-50 204-252 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number Dri/lingEngineer: Walter Quay, 564-4178 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Submit Original Only Tree: Cameron 7", 5. Wellhead: FMC 11" x M, Gen. 5 wI 13-5/8" x 7" FMC Tbg. Hgr. w/ T' TC-11 Top & Btm 7" CIW 'J' BPV profile Orig. KB. elev. = .g. GL. .elev'G.23.8: g. DF. eley. - 57.9 MPU B-50i ) 20" 92 ppf, H-40 I 115' KOP @ 300' Max. hole angle = 63 to 75 deg. f/ 2800' to 9,150' Max 80 deg. @ 3609' Hole angle through perfs = 66 deg. 13·3/8",68 ppf, L-80 BTC I 2,921' I ~ 13-3/8" 68 ppf, L-80, BTC prod. csg. ( drift ID = 12.415", cap. = 0.1497 bpf) 9-5/8" 47 ppf, L-80, BTC-M prod. csg. ( drift ID = 8.681", cap. = 0.0732 bpf) 7" 26 ppf, L-80, TC-11 prod. csg. ( drift ID = 6.151", cap. = 0.0383 bpf) Note: Approx. 5' of mule shoe in tie back Weatherford Float Collar I 8,209' 1 I Weatherford Float Shoe I 8,296' I .. Perforation Summary Ref log: MWO Orill pipe conveyed Size SPF Interval (TVD) Ugnu MB-01 4.5 5 9,890' - 10,000' 4,447'- 4,492' ¡¡¡ Ugnu MB-02 § 4.5 5 10,060' - 10,130' 4,517'- 4,545 ~ Weatherford Float Collar Weatherford Float Shoe 111,324'1 J 111,370'1 . DATE 03/12/05 . 7" HES "Rn Nipple ( 5.963" id) I 2,020' I Ii 7" HES "R" Nipple (5.963" id) 18,040'1 9-5/8" x 7" Baker S-3 Prod. pkr. 1 8,1 02' 7" HES "Rn Nipple (5.963" id) 18,126' I 7" HES "RN" Nipple (5,.963" id) 18.148' I ( No-Go 5.770" Id ) 7" Muleshoe I 8,159' I I 9-5/8" x 7" Baker Tie Back Slv. I 8, 154' 1 . Baker C-2 ZXP liner top pkr. 18,167' 1 Baker liner HMC hanger I 8,172' 1 - - - REV. BY COMMENTS MOO Drilled and completed by Ooyon-14 MILNE POINT UNIT WELL MPB-50i API NO: 50-029-23240-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 2/16/2005 13:00 - 16:00 3.00 MOB P PRE Skid rig floor from drlg position to move position - Move rig off well1B -15A - Install boosters on moving system - Move rig off 1 B-Pad 16:00 - 00:00 8.00 MOB P PRE Move rig from 1 B Pad Kuparuk to Milne Pt B-Pad - Rig at S - Pad junction on Milne pt road @ 00:00 hrs 2/17/2005 00:00 - 05:00 5.00 MOB P PRE Con't move rig from Milne Pt S-Pad junction to Milne pt B-Pad 05:00 - 06:00 1.00 RIGU P PRE Remove boostes - Install heaters - Cellar doors - Hang Annular 06:00 - 08:00 2.00 RIGU P PRE Back rig around manifold building - Spot rig over well MPB-50 - shim rig 08:00 - 09:00 1.00 RIGU P PRE Skid rig floor from move position to drlg position 09:00 - 10:00 1.00 RIGU P PRE Rig up steam - Service all lines - Prep pits for mud 10:00 - 12:00 2.00 RIGU P PRE (Accept rig @ 10:00 hrs) - Nipple up Divertor - Riser - Nipple up divertor line - Load BHA in pipeshed - 5" dp 12:00 - 12:30 0.50 RIGU P PRE ATP with Milne pt production 12:30 - 15:30 3.00 RIGU P PRE Con't nipple up Diverter - Rig up floor to pick up 5" dp - Preform derrick inpection 15:30 - 21:30 6.00 DRILL P SURF PU 5" drill pipe - 192 joints 21 :30 - 22:30 1.00 DIVRTR P SURF Function test Diverter System - Accumulator test - Test all calibration & alarms on gas sensors ok. - Test alarms - Flow meter - PVT - Light failed on trip tank Pason unit - All other alarms operational - Jeff Jones with AOGCC witnessed testing of Diverter System - Gas sensors - PVT - Flow meter - Diverter line 41' - Tom Maunder with AOGCC gave verbal variance to length of diverter line - (Due to high pressure lines buried in compacted snow diverter line was shorten - High pressure water line with 2400 psi & lift gas line with 1300 psi) 22:30 - 23:30 1.00 DRILL P SURF Con't picking up 5" drill pipe additional 15 jts - Total 207 joints 69 stands 23:30 - 00:00 0.50 DRILL P SURF Pick up 5" HWT - Jars - Stand back in derrick 2/18/2005 00:00 - 00:30 0.50 DRILL P SURF Cont' pick up 5" HWT - Stand back in derrick 00:30 - 02:30 2.00 DRILL P SURF Moblize short BHA to rig floor - Pick up BHA - Motor with 1.83 - Hughes MX-1 - FLoat sub - Stablizer - XO 02:30 - 03:30 1.00 DRILL P SURF Rig up Sperry Sun E-line for Gyro surveys 03:30 - 04:30 1.00 DRILL P SURF Pre Spud meeting with Co Man - Crew - Service company rep's - Circulate - Check for surface leaks 04:30 - 06:00 1.50 DRILL P SURF Drill ice from 64' to 115' - Drill from 115' to 220' - WOB 15 to 20 - GPM 450 - PP On 1520 - off 1300 - RPM 60 - TO on 5 - off 3 - PU 78 - SO 78 - ROT 78 06:00 - 06:30 0.50 DRILL P SURF POH @ 220' 06:30 - 09:00 2.50 DRILL P SURF Pick up MWD - UBHO - Orient same - PU flex DC's - Gyro @ 220' 09:00 - 00:00 15.00 DRILL P SURF Directional Drill from 220' to 1199' - WOB 20 - GPM 500 - PP On 1520 - off 1300 - RPM 70 - TO on 5 - off 2 - PU 98 - SO 98 - ROT 98 2/19/2005 00:00 - 14:00 14.00 DRILL P SURF Directional Drill from 1199' to 2094' - WOB 10 - RPM 60 - TO on 4 - off 3 - GPM 500 - PP on 1580 - off 1480 - PU 115 - SO 103 - ROT 110 14:00 - 15:00 1.00 DRILL P SURF CBU 2 X - GPM 500 - PP 1380 15:00 - 16:30 1.50 DRILL P SURF Pump out from 2094' to 756' HWT - Pump at drlg rate 16:30 - 17:00 0.50 DRILL P SURF RIH from 756' to 2000' - Precauctionary wash from 2000' to 2094' 17:00 - 00:00 7.00 DRILL P SURF Directional Drill from 2094' to 2694' - WOB 10 - RPM 60 - TO on 6 - off 4 - GPM 500 - PP on 1620 - off 1540 - PU 120 - SO Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 2/1912005 17:00 - 00:00 7.00 DRILL P SURF 100 - ROT 110 2/20/2005 00:00 - 02:30 2.50 DRILL P SURF Directional Drill from 2694' to 2931' - TD 16" Surface hole- WOB 10 - RPM 60 - TQ on 7 - oft 5 - GPM 500 - PP 1720 - oft 1520 - PU 122 - SO 98 - ROT 111 02:30 - 04:30 2.00 CASE P SURF CBU 2 X - GPM 500 - PP 1571 04:30 - 07:30 3.00 CASE P SURF Pump out from 2931' to 726' - GPM 400 - PP 1020 07:30 - 08:30 1.00 CASE P SURF RIH from 726' to 2931' 08:30 - 11 :00 2.50 CASE P SURF CBU 3 X - GPM 550 - PP 1750 - RPM 80 - TO 6 11 :00 - 14:00 3.00 CASE P SURF Pump out to HWT from 2931' to 726' - GPM 500 - PP 1240 14:00 - 15:00 1.00 CASE P SURF Stand back 5" HWT - Jars - Flex DC's 15:00 - 17:00 2.00 CASE P SURF Flush MWD - Motor - Lay down BHA - Clear rig floor 17:00 - 18:30 1.50 CASE P SURF PJSM - Rig up casing running tools for 13 3/8" casing 18:30 - 00:00 5.50 CASE P SURF PJSM - Pick up shoe joints - Check floats - Run 70 joints of 13 3/8" L-80 68# Buttress casing to 2849' - Break circulation - Wash last joint down to 2889 - Make up landing joint - Land casing @ 2921' - Rig down Franks tool 2/21/2005 00:00 - 00:30 0.50 CASE P SURF Install Schlumberger Cementing head - Make up cementing lines 00:30 - 03:00 2.50 CASE P SURF Break circ @ 3 bpm - 170 psi - Stage up to 5.5 bpm @ 270 psi - Circulate 2 casing vol - conditioning mud for cement job - PJSM with all Service personnel - Drlg crew - Co Man - Tour pusher - EPA personnel while conditioning mud 03:00 - 05:30 2.50 CEMT P SURF Give to Schlumberger - Pump 5 bbls water - 3 BPM 170 PSI Test lines 3000 psi 10 bbls water - 3.5 BPM 192 PSI - (1 Gallon red dye) 20 bbls CW 100 - 4.3 bpm - 200 psi 40 bbls Mud Push mixed at 10.5 ppg - 3.9 bpm 140 psi Drop bottom plug Mix 421 bbls - 531 sxs 10.7 ppg "ASL" - Yield 4.45 cf/sx - 6 bpm 394 psi Mix 63.5 bbls - 310 sxs 15.8 ppg Class G yield 1.17 cf/sx - 2 bpm 105 psi Pump 30 bbls water through tub - 6 bpm 252 psi Give to rig 05:30 - 07:00 1.50 CEMT P SURF Displace with 397 bbls of 9.4 ppg mud - BPM 2.5 to 5 - Bump plug with 1650psi 1000 psi over circ pressure - Held for 3 mins - Bleed oft - Floats holding - 168 Barrels Of Lead Cement Back To Surface - CIP At 07:00 AM 07:00 - 08:30 1.50 CASE P SURF Lay down cementing head - Flush Diverter stack - Riser - Flow line 08:30 - 10:30 2.00 CASE P SURF Lay down landing joint - Casing tools - Clear rig floor 10:30 - 11 :30 1.00 CASE P SURF ND Diverter system 11 :30 - 12:00 0.50 CASE P SURF Install FMC well head and tubing head - Test csg head seal to 1000 psi fpor 10 mins 12:00 - 15:00 3.00 CASE P SURF Nipple up BOP's 15:00 - 16:30 1.50 CASE P SURF Rig up to test BOP's - Set test plug - Open annulus valves 16:30 - 21 :00 4.50 CASE P SURF Test BOP's - Annular to 250 low - 2500 high for 5 mins each test - Pipe rams - Blind rams - Choke manifold - HCR Choke I Kill valves - Manual Choke / Kill valves - Upper I Lower IBOP - Floor safety valve - Floor dart valve - 250 low 3500 high 5 mins each test - Jeff Jones with AOGCC waived witness of test - BOP test witnessed by BP WSL Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 2/21/2005 21 :00 - 21 :30 0.50 CASE P SURF Pull test joint - Test plug - Set wear ring - Close annulus valves - Rig down testing equipment 21 :30 - 22:00 0.50 CASE P SURF Test 133/8" casg to 1000 psi for 30 mins 22:00 - 22:30 0.50 CASE P SURF Change bails - RU 5" handling equipment - PU vendors tools - BHA 22:30 - 00:00 1.50 CASE P SURF PU motor - Make up 12 1/4" bit - Set bend on motor to 1.15 - MUMWD 2/22/2005 00:00 - 01 :30 1.50 CASE P SURF Make up 12 1/4" BHA 01 :30 - 02:00 0.50 CASE P SURF Surface test MWD - 550 GPM - PP 1040 psi - Load Nukes 02:00 - 03:00 1.00 CASE P SURF Con't Make up BHA 03:00 - 03:30 0.50 CASE P SURF Pick up 12 joints 5" drill pipe - Rack back in derrick 03:30 - 06:00 2.50 CASE P SURF Pick up 5" drill pipe from pipe shed to 2848' 06:00 - 08:00 2.00 DRILL P SURF Drill FC @ 2848' - FS @ 2919' - Rat hole @ 2931' - 20' new hole to 2951' - RPM 50 TQ 7k - GPM 520 PP 1500 on - off 1360 08:00 - 09:30 1.50 CASE P SURF Circulate condition mud for FIT - RPM 50 - GPM 520 - PP 1340 - (Clean ECD with out rotation 9.22 ppg - with rotation 9.27 ppg) 09:30 - 10:00 0.50 EVAL P SURF CQAduct FIT test - Test MW 9.0 ppg - MD 2921 - TVD 2522 - PSI 330 - EMW = 11.5 10:00 - 00:00 14.00 DRILL P INT1 Directional Drill from 2951' to 4158' - WOB 10 to 25 - RPM 100 - TO on 9 - off 8 - GPM 570 - PP on 1830 - off 1710 - PU 135 - SO 95 - ROT 110 - ECD 9.9 2/23/2005 00:00 - 08:30 8.50 DRILL P INT1 Directional Drill from 4158' to 4907' - 08:30 - 10:30 2.00 DRILL P INT1 CBU 2 X - RPM 100 - TO 8 K - GPM 575 - PP 1380 10:30 - 13:00 2.50 DRILL P INT1 Short trip - Pump out from 4907' to 2900' - Pump @ drilling rate 13:00 - 14:30 1.50 DRILL P INT1 CBU 2 X - GPM 500 - PP 1380 - Large amount clay balls back - Blinding sclapers - Plug flow line - Circ out from GPM 60 to 500 14:30 - 16:00 1.50 DRILL P INT1 Rig service - Cut drilling line - Service Top drive 16:00 - 17:30 1.50 DRILL P INT1 RIH from 2900' to 4812' - Precauctionary wash to bottom from 4812' to 4907' 17:30 - 00:00 6.50 DRILL P INT1 Directional Drill from 4907' to 5470 - WOB 10 to 25 - RPM 105 - TO on 10 - off 8 - GPM 600 - PP on 2050 - off 1930 - PU 148 - SO 95 - ROT 118 - ECD 9.9 2/24/2005 00:00 - 06:00 6.00 DRILL P INT1 Directional Drill From 5470' to 6034' - WOB 5 - RPM 100 - TO on 15K - off 14K - GPM 600 - PP on 1940 - off 1910 - PU 195- SO 80 - ROT 120 - ECD 9.7 06:00 - 07:00 1.00 DRILL P INT1 Condition Hole clean - RPM 100 - TO 14K - GPM 600 - PP 1900 07:00 - 16:30 9.50 DRILL P INT1 Directional Drill from 6034' to 6791' - WOB 5 to 25 - RPM 100 - TO on 13K - off 12K - GPM 600 - PP on 2160 - off 2000 - PU 195 - SO 85 - ROT 123 - ECD 10.1 16:30 - 19:30 3.00 DRILL P INT1 CBU 3 X - RPM 100 - TQ 14K - GPM 600 - PP - 1940- Shakers clean 19:30 - 23:00 3.50 DRILL P INT1 Pump out from 679' to 2900' - Pump @ drlg rate· No problems on trip out to 3200' - From 3200' to 2900' clay balls - cuttings unloading - @ 5200' Drag decreased 15K ( Ghost reamer depth) 23:00 - 00:00 1.00 DRILL P INT1 CBU 2.5 X - Large clay balls - Shakers loaded - Restricted flowline - GPM 300 to 600 - PP 300 to 1400 - RPM 100 - TO 6K Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 2/25/2005 00:00 - 01 :00 1.00 DRILL P INT1 Con't - CBU 2.5 X - Clean well - Large clay balls - Shakers loaded - GPM 300 to 500 - PP 300 to 1400 - RPM 100 - TO 6K 01 :00 - 02:30 1.50 DRILL P INT1 Flow check - Pump dry job - POH to BHA 02:30 - 03:00 0.50 DRILL P INT1 Stand BHA back 03:00 - 03:30 0.50 DRILL P INT1 PJSM - Down load nukes 03:30 - 04:30 1.00 DRILL P INT1 LD NEU-DENS Sonic tools for servicing - Change out bits 04:30 - 06:00 1.50 DRILL P INT1 Down load 06:00 - 08:00 2.00 DRILL P INT1 Change out pulser on MWD - Change out stabilizer above motor 08:00 - 09:00 1.00 DRILL P INT1 Up load MWD 09:00 - 09:30 0.50 DRILL P INT1 Surface test MWD - Plugged 09:30 - 12:00 2.50 DRILL N SFAL INT1 Pull BHA - Found metal shavings on top of pulser - Clean up pulser - Pump through Sonic tool- Load MWD 12:00 - 12:30 0.50 DRILL P INT1 Surface test MWD - 500 GPM - 830 psi 12:30 - 13:00 0.50 DRILL P INT1 Load nukes 13:00 - 14:00 1.00 DRILL P INT1 Con't make up BHA 14:00 - 18:00 4.00 DRILL P INT1 PJSM - RIH from 772' to 1625' - Make up Ghost reamer - Con't RIH from 1625' to 6200' - Tight spot took all string weight- Wash and ream to 6293' - Back ream to 6200' - RIH with out pump to 6293' - Con't RIH took weight @ 6435' - Break circulation wash and ream to 6474' - GPM 400 - PP 1220- Took no weight with no differential pressure - Back ream to 6379' - Shut down pumps and RIH to 6693' - Precauctionary wash from 6693' to 6790' - Fill pipe @ 2660', 5000' 18:00 - 00:00 6.00 DRILL P INT1 Directional Drill from 6790' to 7220' - WOB 8 to 10 - RPM 100 - TO on 15K - off 14K - GPM 600 - PP on 2170 - off 2080 - PU 190 - SO 95 - ROT 130 - ECD 10.12 2/26/2005 00:00 - 07:30 7.50 DRILL P INT1 Directional Drill from 7220 to 7730' - Log shows Coal section 7345' MD 3710' TVD - Base 7420' MD 3724' TVD -75' MD length 14' rvD length - WOB - RPM - TO on - off - GPM 600- PP on - off - PU - SO - ROT 07:30 - 08:30 1.00 DRILL N DPRB INT1 Lost Detection on MWD - Pump H20 slug to get it going 08:30 - 15:00 6.50 DRILL P INT1 Directional Drill from7730' to 8296' - T.D 12 1/4" hole - WOB 20 to 30 - RPM 100 - TO on 17K - off 13K - GPM 600 - PP on 2400 - off 2270 - PU 200 - SO 95 - ROT 130 - ECD 10.17 15:00 - 19:30 4.50 CASE P INT1 CBU 3 + X - GPM 600 - PP 2270 - Circulate - Condition waiting on orders from town - Pump Hi-vis weighted sweep - Rotate and reciprocate 100 RPM - TO 14K - Flow check - Well static 19:30 - 00:00 4.50 CASE P INT1 Pump out from 8296' to 4625' - Pump at drlg rate - - Work tight spots 7909 to 7750' and 7500' to 7160' - Pump out through these section RIH with out pump - Pump out second time - Con't pump out 2/27/2005 00:00 - 01 :30 1.50 CASE P INT1 Con't pump out from 4525' to 2900' - Pump @ 550 GPM - PP 1500 01 :30 - 02:30 1.00 CASE P INT1 CBU 2 + X - GPM 550 - PP 1560 - RPM 70 - TO 7K - Shakers loaded up with clay balls - coal - (pieces sized 6" X 6" 2" thick and smaller 02:30 - 05:00 2.50 CASE P INT1 RIH from 2900' to 8191 - Precauctionary wash from 8191' to 8296' - Tight spot @ 7345' - Pick up and run back through spot - 7770 tight spot work through - Con't RIH to 8191' 05:00 - 11 :00 6.00 CASE P INT1 CBU 5 X - GPM 600 - PP 2371' - RPM 100 - TO 16.5K - Flow check - Well static 11 :00 - 16:30 5.50 CASE P INT1 Pump out from 8296' to 2900' - Pump @ drlg rate - Hole in Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 2/18/2005 3/12/2005 Spud Date: 2/18/2005 End: 2/27/2005 11 :00 - 16:30 5.50 CASE P INT1 good condition 16:30 - 17:30 1.00 CASE P INT1 CBU 1+ X - GPM 550 - PP 1500 - Hole clean - Flow check- Well static - Pump dry job 17:30 - 18:30 1.00 CASE P INT1 POH from 2900 to BHA @ 773' - Lay down ghost reamer 18:30 - 19:30 1.00 CASE P INT1 Stand back 5" HWT - Lay down 8" Flex DC's 19:30 - 20:00 0.50 CASE P INT1 PJSM - Pull Nuclear sources with Schlumberger Techs 20:00 - 21 :30 1.50 CASE P INT1 Lay down Schlumberger tools - Drain motor - Break off bit 21 :30 - 22:00 0.50 CASE P INT1 Down load MWD 22:00 - 23:00 1.00 CASE P INT1 Lay down MWD tools - Motor 23:00 - 23:30 0.50 CASE P INT1 Clean - Clear rig floor of all BHA jewelery 23:30 - 00:00 0.50 CASE P INT1 Pull I wear ring - Set test plug - Change top rams from 3 1/2" x 6" variable to 9 5/8" casg rams 2/28/2005 00:00 - 01 :30 1.50 CASE P INT1 Change top rams to 9 5/8" - Test door seals to 1500 psi - Open annulus valves - Pull test plug 01 :30 - 03:00 1.50 CASE P INn Rig up casg tools 03:00 - 06:00 3.00 CASE P INT1 PJSM - Pick up float equipment - Check floats - PU / Run 9 5/8" 47# L-80 BTC-M casg to 2885' 06:00 - 07:00 1.00 CASE P INT1 Circulate 1 casing vol - 6.5 bpm - PP 430 07:00 - 11 :00 4.00 CASE P INT1 Con't RIH with 9 5/8" 47# L-80 BTC-M casg to 8261' 11 :00 - 11 :30 0.50 CASE P INT1 PU Landing joint - Break circulation - Precauctionary wash to btm from 8261' to 8296' - 4.1 bpm - PP 325 - PU 325 - SO 90 11 :30 - 13:30 2.00 CASE P INT1 Circulate 1 casing vol @ 4.1 bpm - PP 500 - Reciprocate casing - Stage up pump to 6.5 bpm - PP 650 - Reciprocate 30' strokes - PU 315K - SO 125K 13:30 - 14:00 0.50 CASE P INT1 Rig down Franks fill up tool - Rig up Dowell Schlumberger cementing head 14:00 - 16:30 2.50 CASE P INT1 Circulate condition mud for cement job - Stage pump up to 6.5 bpm - PP 450 - PJSM with - Crew / Service personnel/Co Rep while circulating 16:30 - 18:00 1.50 CEMT P INT1 Give to Schlumberger to pump 5 bbls water - 4 bpm @ 290 Test lines to 3500 20 bbls CW 100 - 5 bpm @ 324 50 bbls Mud Push Mixed @ 10.7 ppg - 6.5 bpm @ 338 Drop btm plug 93.4 bbls (212 sxs "Lite Crete" Yield 2.49 cu/ft sx @ 12 ppg - 6 BPM @ 300 123 bbls (577 sxs Class "G" yield 1.20 cu/ft sx @ 15.8 ppg - 5 bpm @ 150 Drop top plug Kick out with 20 bbls water - 6 bpm @ 91 give to Rig for displacement 18:00 - 20:00 2.00 CASE P INT1 Displace with 581.4 bbls LSND mud - 6.5 bpm @ 400 - Slowed to 3 bpm last 10 bbls pumped - Bumped plug with 1750 psi 1000 over final pumping pressure - Check floats - Floats holding - Reciprocated string through 4400 stks displaced - Final PU 350 - SO 65K - Block wt 50K - CIP 19:30 hrs - Attempt to pick up 350K - Casing moving @ 320K - Slack off to 100K 20:00 - 21 :00 1.00 CASE P INT1 woe . (Clear rig floor - Lay down casing equipment - Flush BOPS with 40 bbls water) 21 :00 - 21 :30 0.50 CASE P INT1 WOC - (Rig down - Lay down - Schlumberger cementing head) 21 :30 - 22:30 1.00 CASE P INT1 WOC - (Change 9 5/8" casing rams to 31/2" X 6" variables- Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 2/28/2005 21 :30 - 22:30 1.00 CASE P INT1 Void 40' of 9 5/8" casing) 22:30 - 23:30 1.00 CASE P INT1 WOC - (Tie onto BOP stack - Nipple down flowline - Hole fill - Bleeder line - Turnbuckles - Prepare to pick up stack) 23:30 - 00:00 0.50 CASE P INT1 WOC- (Mobilize test plug - Running tool - Wear ring to rig floor) 3/1/2005 00:00 - 05:30 5.50 CASE P INT1 Wait on Cement - (Change out tugger line sheave - Moblize short BHA to rig floor - Place BHA in order in pipe shed - Pick up stack - prepare to set slips on 9 5/8" casing) 05:30 - 06:30 1.00 CASE P INT1 PJSM - Pick up 9 5/8" casg 350K - Set casing slips - String weight on slips 300K - Block weight 50K 06:30 - 07:30 1.00 CASE P INT1 Rig up Cameron CSG cutters, cut csg 07:30 - 09:00 1.50 CASE P INT1 Install 9 5/8 X 13 3/8 packoff 09:00 - 10:30 1.50 CASE P INT1 Nipple up BOPS, test packoff and csg spools to 3800 psi for 10 min. 10:30 - 12:00 1.50 CASE P INT1 Test top rams to 250-3500 psi for 5 min. per test, install wear ring. Ram pressure test was witnessed by WSL. 12:00 - 13:30 1.50 CASE P INT1 PJSM, M/U bit and motor,MWD tool, Orient 13:30 - 14:30 1.00 CASE P INT1 Upload MWD tool 14:30 - 15:00 0.50 CASE N SFAL INT1 Reseat Battery in Bat-Sonic tool 15:00 - 16:00 1.00 CASE P INT1 Upload MWD, Pulse test MWD 16:00 - 16:30 0.50 CASE P INT1 Pjsm, load Nuclear sources 16:30 - 17:00 0.50 CASE P INT1 Finish picking up BHA 17:00 - 19:00 2.00 CASE P INT1 Picking up 5' pipe from pipe shed to 2832' 19:00 - 21 :30 2.50 CASE P INT1 Trip in to 4993, fill pipe, attemp to get MWD signal, no signal, circ out high vis mud, checking out tools 21 :30 - 23:00 1.50 CASE P INT1 Cut and slip drilling line, service rig 23:00 - 00:00 1.00 CASE N DFAL INT1 POH to Repair MWD tool 3/2/2005 00:00 - 01 :00 1.00 CASE N DFAL INT1 Finish trip out to BHA 01 :00 - 02:00 1.00 CASE N DFAL INT1 Stand back BHA to MWD tool, change out pulser, test tool, working 02:00 - 02:30 0.50 CASE N DFAL INT1 Rih with BHA 02:30 - 03:30 1.00 CASE N DFAL INT1 Tripping in to 4900 03:30 - 04:30 1.00 CASE P INT1 Tripping in from 4900 to 7810' 04:30 - 06:30 2.00 CASE P INT1 Wash to 8178, Circ bottoms up 06:30 - 07:30 1.00 CASE P INT1 Test csg to 3500 psi for 30 min. 07:30 - 09:00 1.50 DRILL P INT1 Drill float and shoe, 20 ft of new hole to 8316', with 100 spm 1750 psi, 40 rpms 09:00 - 10:00 1.00 CASE P INT1 Circ 2 bottoms up with 130 spm 2330 psi 40 rpms 10:00 - 11 :00 1.00 CASE P INT1 FIT. 512psi, Tvd 3938.9.0 MW, EMW 11.5 11 :00 - 00:00 13.00 DRILL P LNR1 Drilling 8316' to 9776' with 525 gpm, 2500 psi, 100 rpms, Tq 14,000, 8-10K bit wt., AST 1.55 ART 7.15 3/3/2005 00:00 - 04:30 4.50 DRILL P LNR1 Drilling 9776' to 10340' with 525 gpm, 2500 psi, 100 rpms, ECD 11.0 04:30 - 06:30 2.00 DRILL P LNR1 Circ 2 bottoms up to reduce ECD and TQ. went from 15,000 to 20k in last 600 ft., MWD stopped working 06:30 - 08:30 2.00 DRILL N DFAL LNR1 Pumping out to 8296' with full drilling rate 08:30 - 09:00 0.50 DRILL N DFAL LNR1 Circ Bottoms up, at csg shoe 125 spm 2170 psi, 100 rpms 09:00 - 13:00 4.00 DRILL N DFAL LNR1 Tripping out to BHA 13:00 - 13:30 0.50 DRILL N DFAL LNR1 Standing back BHA 13:30 - 15:00 1.50 DRILL N DFAL LNR1 PJSM, Down load Nuclear sources, attemp to down load MWD, wouldn't down load 15:00 - 17:00 2.00 DRILL N DFAL LNR1 Break down MWD switch out Gramma.res tool, Dm collar,Orient to motor Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 3/312005 17:00 - 18:00 1.00 DRILL N DFAL LNR1 Upload MWD tool and test same 18:00 - 19:00 1.00 DRILL N DFAL LNR1 Pjsm, load Nuclear sources 19:00 - 19:30 0.50 DRILL N DFAL LNR1 Run in BHA 19:30 - 22:30 3.00 DRILL N DFAL LNR1 Tripping in to 8272' 22:30 - 23:00 0.50 DRILL N DFAL LNR1 Spot EP mud lube pill in 9 5/8 csg 23:00 - 00:00 1.00 DRILL N DFAL LNR1 Trip to 10340', wash last stand to bottom 3/4/2005 00:00 - 12:00 12.00 DRILL P LNR1 Drilling 10340' to 11370' TD with 525 gpm, 2600 psi, 100 rpms, TO still high 16 to 23 K, pickup wt increasing 10 to 15K on every stand. Pu 315k, S/o 85K.Rtw 145k, AST .81, ART 7.13 12:00 - 14:30 2.50 CASE P PROD1 Circ, three bottoms up with 525 Gþm 2500 psi, 110 rpms, Tq 15k to 25k 14:30 - 18:00 3.50 CASE P PROD1 Pump out to csg shoe with full drilling rate, pump lubetex pill while pumping out, 30k over pull @ 10520, 10480, no packing off 18:00 - 19:00 1.00 CASE P PROD1 Circ bottoms up @ Csg shoe 8296 525 gpm, 2200 psi, 80 rpms 19:00 - 20:00 1.00 CASE P PROD1 Cut drilling line, Service top drive 20:00 - 21 :30 1.50 CASE P PROD1 RIH, washed last stand to bottom 21 :30 - 00:00 2.50 CASE P PROD1 Circ, three bottoms up with 525 Gpm 2500 psi, 110 rpms, Tq 15k to 25k 3/5/2005 00:00 - 02:30 2.50 CASE P PROD1 Pumping out to Csg shoe @ 8296 with full drilling rate, Pump Lubetex pill while pumping out, no tight spots 02:30 - 03:30 1.00 CASE P PROD1 Circ bottoms up from 8296', slug pipe, drop drill pipe rabbit 03:30 - 06:00 2.50 CASE P PROD1 Tripping out to BHA 06:00 - 10:00 4.00 CASE P PROD1 Standing back HWD pipe, laying down BHA 10:00 - 11 :00 1.00 CASE P PROD1 PJSM,rig up to pick up 7" liner 11 :00 - 15:00 4.00 CASE P PROD1 PJSM, Picking up 7" 26# L-80 BTC-Mod liner, total 75 jts, Baker HMC, Baker liner top packer 15:00 - 15:30 0.50 CASE P PROD1 Circ liner Volume 60 spm @ 400 psi 15:30 - 19:30 4.00 CASE P PROD1 Trip in with liner to 8292 19:30 - 21 :30 2.00 CASE P PROD1 Spot EPM lube pill in Csg, P/U 185K, Slo 80K 21 :30 - 23:30 2.00 CASE P PROD1 Trip in with liner to 11276, washed to 11369, 6 bbls min 880 psi 23:30 - 00:00 0.50 CASE P PROD1 Circ and reciprocate linér 25 ft, 6 bbls min 840 psi, P/U 240K, S/O 90K 3/6/2005 00:00 - 00:45 0.75 CASE P PROD1 Circ and reciprocate liner 25 ft, 6 bbls min 840 psi, P/U 240K, S/O 90K 00:45 - 01 :00 0.25 CASE P PROD1 Pickup Baker plug dropping head 01 :00 - 02:00 1.00 CASE P PROD1 Circ and reciprocate liner 25 ft, 6 bbls min 840 psi, P/U 240K, S/O 90K 02:00 - 04:00 2.00 CEMT P PROD1 Cement with Schlumberger, pump 5 bbls Cw100, test lines to 4000 psi,15 bbls CW100,50 bbls mud push mixed @ 10.5, 133 bbls 638 sxs Class G yield 1.17 mixed @ 15.8 pumped 5 bbls min, washed lines,drop plug,kicked out plug with 10 bbls water, displace with rig pumps 6 bbls min. 200-1000 ps, bump plug with 244 bbls mud, 3500 psi, reciprocate1iOer thru out job, full returns, floats held 04:00 - 04:30 0.50 CASE P PROD1 Set hanger with 3500 psi, set 40k on hanger, bleed off pressure, turn 15 rounds, pressure up on pipe to 1000 psi pickup PIU 140k and pumped 30 bbls to move cement up hole, set down 50k on packer and set packer. 04:30 - 05:30 1.00 CASE P PROD1 Circ cement off top of liner 10 bbl min, 20 bbls of good cement to surface 05:30 - 09:00 3.50 CASE P PROD1 Circ and condition mud 09:00 - 15:30 6.50 CASE P PROD1 Trip out, laying down excess 5" pipe and 15 jts HWDP, laying Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 3/612005 09:00 - 15:30 6.50 CASE P PROD1 down running tools 15:30 - 16:00 0.50 CASE P PROD1 Pull wear ring and rig up to Test BOPS 16:00 - 20:00 4.00 CASE P PROD1 Testing BOPS and Manifold 250-3500 psi 5 min per test, Annular 250- 2500 psi 5 min per test, Test was. witness by John Crisp AOGCC and WSL, Install wear ring 20:00 - 21 :00 1.00 CASE P PROD1 Test Csg with 3,500 psi 30 min. 21 :00 - 21 :30 0.50 CASE P PROD1 Rig up to pick up 4" pipe 21 :30 - 00:00 2.50 CASE P PROD1 Picking up 6 .125 bit and 7" csg scraper, float sub.4" drill pipe from pipe shed 3/7/2005 00:00 - 00:30 0.50 CASE P PROD1 Picking up 4" pipe from pipe shed, total 98 jts 00:30 - 01 :30 1.00 CASE P PROD1 Rig up to run 5" pipe, pick up 9 5/8 csg scraper 01 :30 - 05:00 3.50 CASE P PROD1 Tripping in to 11161, went in liner lap @ 8154 with no problem, set down 119 ft high 05:00 - 06:00 1.00 CASE P PROD1 Circ bottoms up, call town 06:00 - 08:00 2.00 CASE P PROD1 Drill cement stringers to 11278 08:00 - 09:00 1.00 CASE P PROD1 Circ. bottoms up 09:00 - 11 :00 2.00 CASE P PROD1 Displace well with sea water, 600 gpm 11 :00 - 12:30 1.50 CASE P PROD1 Clean pit fill with sea water 12:30 - 13:30 1.00 CASE P PROD1 Circ EP mud lube full circulation, 600 gpm, P/U before EP 207K Slo 105K, P/u after EP pill 160K S/o 125k 13:30 - 18:00 4.50 CASE P PROD1 POH lay down 9 58 scraper, and 7" scraper and bit 18:00 - 19:00 1.00 CASE P PROD1 Clear rig floor 19:00 - 20:00 1.00 EVAL P PROD1 PJSM, W/ schlumberger, rig up wire line 20:00 - 00:00 4.00 EVAL P PROD1 Running US IT log with Tractor, loggers TD 11250', did not have to use tractor all the time, but use it three of four times for short pulls 3/8/2005 00:00 - 03:00 3.00 EVAL P PROD1 Running USIT log with Tractor, loggers TD 11250', bond log on liner 100%, top of cement in 9 5/8 4700' 03:00 - 03:30 0.50 EVAL P PROD1 Rig down Schlumberger 03:30 - 04:00 0.50 EVAL P PROD1 Service rig, and top drive 04:00 - 04:30 0.50 EV AL P PROD1 PJSM on picking up guns 04:30 - 07:00 2.50 PERFOB N HMAN OTHCMP Started Picking up 4.5 HSD Peforating guns, pick up subs had wrong thread, wait on subs 07:00 - 08:30 1.50 PERFOB P OTHCMP Picking up 4.5 HSD peforating guns 5 spf and firing head 08:30 - 14:00 5.50 PERFOB P OTHCMP Trip in with guns to 10134 MD, 60' per min. running rate, went in top of liner with no problems 14:00 - 19:30 5.50 PERFOB P OTHCMP Rig up Schlumberger and run Correlate log to 3550 and had to pump it rest of the way @ 8 bbls min. 800 psi, Perf gun was on depth Did not have to move pipe. 19:30 - 20:30 1.00 PERFOB P OTHCMP Pjsm on Firing guns, practice pressuring up and bleeding, Fired guns and perf well 9890' to 10000', 10060-10130' 5 spf 20:30 - 21 :30 1.00 PERFOB P OTHCMP Trip out to 9265' 21 :30 - 22:30 1.00 PERFOB P OTHCMP Cut and slip drilling line, monitor weft loss rate 60 ObIs hr. 22:30 - 00:00 1.50 PERFOB P OTHCMP Mix and pump 30 bbl Duo-Vis pill 3# per bbl, pumped @ 5bbl min 250 psi,slow rate to 1 bbI min. when pill was exiting circ sub @ 9011', Total losses last 24 hrs. 137 bbls 3/9/2005 00:00 - 00:30 0.50 PERFOB P OTHCMP Spot Duo-Vis pill, pill hit perf. loss to well went from 60 bbls hr. to 0 00:30 - 14:00 13.50 PERFOB N WAIT OTHCMP Monitor Well - Phase 3 Conditions - Wait On Weather 14:00 - 18:00 4.00 PERFOB P OTHCMP POH Laying Down 5" Drill Pipe From 9,265' To 3,472' 18:00 - 18:30 0.50 PERFOB P OTHCMP RIH With 5" Drill Pipe From Mast To 4,882' 18:30 - 19:30 1.00 PERFOB P OTHCMP POH Laying Down 5" Drill Pipe From 4,882' To 3,440' 19:30 - 21:30 2.00 PERFOB P OTHCMP Change Out Handling Equipment To 4" - POH Laying Down 4" Printed: 3/14/2005 1 :42:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPB-50 MPB-50 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/18/2005 Rig Release: 3/12/2005 Rig Number: Spud Date: 2/18/2005 End: 3/9/2005 19:30 - 21:30 2.00 PERFOB P OTHCMP Drill Pipe From 3,440' To 300' 21 :30 - 22:30 1.00 PERFOB P OTHCMP Hold PJSM With All Personal Regarding Per1oration Guns And Laying Down Operation - Clear Rig Floor - Rig Up Power Tongs And Equipment 22:30 - 00:00 1.50 PERFOB P OTHCMP Lay Down Schlumberger Per1oration Guns - All Shots Have Fired 3/10/2005 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Clear rig floor 01 :00 - 01 :30 0.50 RUNCOMP RUNCMP Pull wear ring 01 :30 - 02:30 1.00 RUNCOMP RUNCMP Change rams to 7", test doors seals to 1500 psi 02:30 - 04:30 2.00 RUNCOMP RUNCMP Change bails, rig up to run 7" Tubing 04:30 - 05:00 0.50 RUNCOMP RUNCMP PJSM with crew and service hand 05:00 - 18:30 13.50 RUNCOMP RUNCMP Picking up 7" 26# L-80 TCII Tubing total 197 jts, Torque turn pipe and use compensator 18:30 - 20:30 2.00 RUNCOMP RUNCMP Space out tubing @ 8159', P/U 185K, Slo 105k 20:30 - 21 :00 0.50 RUNCOMP RUNCMP Make up tubing head and land tubing with TWC installed 21 :00 - 00:00 3.00 RUNCOI'vf\J WAIT RUNCMP Shut down due to phase 3 weather, wait on weather 3/11/2005 00:00 - 06:00 6.00 RUNCOI'vf\J WAIT RUNCMP Shut down due to phase 3 weather, wait on weather 06:00 - 07:30 1.50 RUNCOMP RUNCMP Test TWC to 1000 psi, clear floor, change out bails 07:30 - 10:00 2.50 RUNCOMP RUNCMP Nipple down BOPS, change rams, change out saver sub to 4" 10:00 - 13:30 3.50 RUNCOMP RUNCMP Nipple up FMC 13x7 1/165000# adapter and CIW 7 1/16 5000# tree, test adaper and shell test tree to 5000# psi for ten min per test 13:30 - 15:00 1.50 RUNCOMP RUNCMP Pull TWC, rig up circ line, and test lines 15:00 - 17:30 2.50 RUNCOMP RUNCMP Pump 144 bbls Corrosion inhibitor and seawater, follow with 64 bbls diesel for freeze protection of IA 17:30 - 22:30 5.00 RUNCOMP RUNCMP Bullhead 96 bbls diesel down tubing 2.5 bbls min. 550 psi to freeze protect tubing, Bleed psi off well flow back 96 bbls diesel, pumped 96 bbls diesel back down tubing and rigged up Lubrictor to drop ball and rod 22:30 - 23:30 1.00 RUNCOMP RUNCMP Pressure up on tubing to 3500 to set packer, rod was on packer with out pumping in 10 min. Test tubing with 3,500 psi for 30 min. 23:30 - 00:00 0.50 RUNCOMP RUNCMP Pressure upon fA annulus with 3500 psi for 30 mins. Iioth test were witness by Thor Cutler EPA and WSL 3/12/2005 00:00 - 00:30 0.50 RUNCOMP RUNCMP Pressure up on IA annulus with 3500 psi for 30 mins. 00:30 - 01 :00 0.50 RUNCOMP RUNCMP Bleed pressure off lA, rig down lines 01 :00 - 03:00 2.00 RUNCOMP RUNCMP Rig up Lubricator and install 6" CIW type H BPV, 750 psi on tubing Secure tree, vac out cellar, Flush and clean pits, Rig release to move to MPK 09 @ 3:00 am 3/12/05 Printed: 3/14/2005 1 :42:34 PM Legal Name: MPB-50 Common Name: MPB-50 2/22/2005 3/2/2005 FIT FIT 2,921.0 (ft) 8,297.0 (ft) 2,522.0 (ft) 3,938.0 (ft) 9.00 (ppg) 9.00 (ppg) 330 (psi) 511 (psi) 1,509 (psi) 2,352 (psi) 11.52 (ppg) 11.50 (ppg) . . Printed: 3/14/2005 1 :42:26 PM Halliburton Sperry-Sun Milne Point Unit BPXA MPB-50 . Job No. AKZZ3550394, Surveyed: 4 March, 2005 Survey Report 4 April, 2005 Your Ref: API 500292324000 Surface Coordinates: 6022989.89 N, 572231.76 E (70028' 23.1192" N, 149024' 36.0730" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 - Kelly Bushing Elevation: 57.90ft above Mean Sea Level . SpE!ï'....,~-sul! D Rlï; L. I Nt';;·m:-!!!fe R'V I c: liS!!; A Halliburton Company Survey Ref: svy1511 Halliburton Sperry-Sun Survey Report for MPB-50 Your Ref: API 500292324000 Job No. AKZZ3550394, Surveyed: 4 March, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Dèpth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -57.90 0.00 0.00 N 0.00 E 6022989.89 N 572231.76 E 0.00 CB-SS-GYRO 75.00 0.250 85.000 17.10 75.00 0.01 N 0.16 E 6022989.91 N 572231.92 E 0.333 0.07 166.00 0.500 100.000 108.10 166.00 0.04S 0.75 E 6022989.86 N 572232.51 E 0.293 0.22 257.00 1 .400 35.000 199.09 256.99 0.80 N 1.78 E 6022990.71 N 572233.53 E 1.398 1.37 347.00 4.500 27.000 288.96 346.86 4.85 N 4.01 E 6022994.78 N 572235.73 E 3.466 5.94 . 437.00 6.500 11.000 378.54 436.44 13.00 N 6.59 E 6023002.95 N 572238.22 E 2.780 14.47 528.00 6.750 5.000 468.94 526.84 23.38 N 8.04 E 6023013.35 N 572239.57 E 0.808 24.72 618.00 6.750 8.000 558.31 616.21 33.89 N 9.24 E 6023023.87 N 572240.67 E 0.392 35.00 MWD+IIFR+MS+SAG 698.29 6.560 3.220 638.06 695.96 43.14 N 10.15 E 6023033.13 N 572241.49 E 0.729 44.00 739.48 6.530 3.010 678.98 736.88 47.83 N 10.41 E 6023037.82 N 572241.70 E 0.093 48.49 837.90 6.830 357.680 776.74 834.64 59.27 N 10.46 E 6023049.25 N 572241.65 E 0.699 59.25 933.18 7.550 2.700 871.27 929.17 71.18 N 10.53 E 6023061.17 N 572241.60 E 1.002 70.46 1026.08 8.580 1 .480 963.25 1021.15 84.20 N 10.99 E 6023074.20 N 572241.94 E 1.124 82.85 1125.47 11.340 18.760 1061.15 1119.05 100.87 N 14.33 E 6023090.90 N 572245.11 E 4.064 99.65 1220.30 15.290 22.430 1153.42 1211.32 121.27 N 22.10 E 6023111.37 N 572252.68 E 4.258 121.47 1314.00 19.600 14.500 1242.80 1300.70 147.92 N 30.76 E 6023138.10 N 572261.08 E 5.243 149.47 1407.00 19.000 19.000 1330.58 1388.48 177.34 N 39.59 E 6023167.60 N 572269.63 E 1.724 180.13 1501.55 20.760 7.290 1419.52 1477.42 208.53 N 46.73 E 6023198.86 N 572276.47 E 4.595 211.88 1594.21 25.820 11 .950 1504.61 1562.51 244.58 N 53.00 E 6023234.98 N 572282.38 E 5.808 247.89 1687.68 25.940 14.060 1588.71 1646.61 284.33 N 62.18 E 6023274.81 N 572291.18 E 0.994 288.37 1782.81 25.040 13.520 1674.58 1732.48 324.09 N 71.94 E 6023314.66 N 572300.55 E 0.977 329.06 . 1877.22 26.580 14.110 1759.57 1817.47 364.00 N 81.76 E 6023354.67 N 572309.99 E 1.654 369.91 1970.87 29.990 15.780 1842.03 1899.93 406.86 N 93.24 E 6023397.63 N 572321.05 E 3.738 414.10 2065.78 32.590 16.950 1923.13 1981.03 454.14 N 107.14 E 6023445.05 N 572334.49 E 2.813 463.28 2160.03 35.610 17.370 2001.16 2059.06 504.62 N 122.74 E 6023495.68 N 572349.60 E 3.214 516.05 2246.47 39.010 18.860 2069.90 2127.80 554.40 N 139.05 E 6023545.61 N 572365.42 E 4.070 568.40 2338.04 42.770 20.020 2139.12 2197.02 610.91 N 159.02 E 6023602.31 N 572384.84 E 4.189 628.32 2432.06 47.450 21.100 2205.45 2263.35 673.24 N 182.43 E 6023664.87 N 572407.65 E 5.044 694.91 2526.40 53.230 21.900 2265.64 2323.54 740.78 N 209.05 E 6023732.66 N 572433.61 E 6.161 767.49 2620.31 56.030 20.240 2320.00 2377.90 812.23 N 236.56 E 6023804.38 N 572460.43 E 3.312 844.04 2715.24 59.220 19.540 2370.82 2428.72 887.62 N 263.83 E 6023880.03 N 572486.96 E 3.418 924.20 2809.64 63.870 19.900 2415.79 2473.69 965.72 N 291.83 E 6023958.40 N 572514.20 E 4.937 1007.17 2857.45 65.760 19.780 2436.13 2494.03 1006.42 N 306.51 E 6023999.23 N 572528.49 E 3.960 1050.44 2954.72 66.110 19.490 2475.80 2533.70 1090.07 N 336.36 E 6024083.17 N 572557.52 E 0.451 1139.25 3044.68 71 .200 19.230 2508.53 2566.43 1169.09 N 364.12 E 6024162.46 N 572584.52 E 5.664 1223.00 4 April, 2005· 15:12 Page 2 of 6 Dril/Quest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPB-50 Your Ref: AP/500292324000 Job No. AKZZ3550394, Surveyed: 4 March, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3137.80 73.740 19.400 2536.58 2594.48 1252.89 N 393.49 E 6024246.53 N 572613.07 E 2.733 1311.78 3230.37 69.820 19.160 2565.51 2623.41 1335.87 N 422.52 E 6024329.79 N 572641.29 E 4.242 1399.68 3326.07 68.310 19.310 2599.71 2657.61 1420.26 N 451.96 E 6024414.47 N 572669.92 E 1.585 1489.05 3421.15 70.300 18.160 2633.31 2691.21 1504.48 N 480.52 E 6024498.97 N 572697.66 E 2.379 1577.97 3514.84 76.230 18.400 2660.27 2718.17 1589.64 N 508.66 E 6024584.39 N 572724.96 E 6.334 1667.60 . 3609.78 80.200 20.520 2679.66 2737.56 1677.24 N 539.62 E 6024672.29 N 572755.08 E 4.718 1760.51 3703.56 77.560 19.910 2697.75 2755.65 1763.58 N 571.42 E 6024758.94 N 572786.03 E 2.887 1852.52 3798.09 76.480 21.180 2718.98 2776.88 1849.84 N 603.74 E 6024845.50 N 572817.52 E 1.738 1944.63 3890.98 76.030 21.380 2741.05 2798.95 1933.91 N 636.49 E 6024929.89 N 572849.45 E 0.528 2034.84 3985.57 74.130 21.530 2765.40 2823.30 2018.98 N 669.92 E 6025015.27 N 572882.05 E 2.015 2126.21 4078.57 74.130 20.660 2790.84 2848.74 2102.44 N 702.11 E 6025099.04 N 572913.44 E 0.900 2215.65 4171.50 74.880 21.090 2815.66 2873.56 2186.11 N 734.02 E 6025183.02 N 572944.53 E 0.922 2305.20 4267.18 77.240 22.090 2838.71 2896.61 2272.45 N 768.19 E 6025269.69 N 572977.86 E 2.667 2398.02 4360.57 76.290 22.860 2860.09 2917.99 2356.45 N 802.95 E 6025354.02 N 573011.80 E 1.296 2488.85 4454.59 74.180 22.010 2884.05 2941.95 2440.48 N 837.64 E 6025438.38 N 573045.68 E 2.408 2579.69 4549.76 72.370 22.300 2911.44 2969.34 2524.89 N 872.01 E 6025523.13 N 573079.23 E 1.924 2670.77 4643.57 74.060 22.340 2938.53 2996.43 2607.97 N 906.12 E 6025606.53 N 573112.53 E 1.802 2760.51 4735.88 74.710 21.670 2963.38 3021.28 2690.40 N 939.43 E 6025689.28 N 573145.04 E 0.992 2849.37 4826.54 75.090 21.420 2986.99 3044.89 2771.81 N 971.57 E 6025771.00 N 573176.39 E 0.497 2936.87 4922.03 75.020 20.950 3011.62 3069.52 2857.84 N 1004.91 E 6025857.34 N 573208.89 E 0.481 3029.11 5015.35 76.360 20.780 3034.68 3092.58 2942.33 N 1037.12 E 6025942.15 N 573240.28 E 1.447 3119.53 . 5108.84 74.110 20.990 3058.51 3116.41 3026.79 N 1069.34 E 6026026.91 N 573271.68 E 2.416 3209.92 5203.20 75.020 20.310 3083.62 3141.52 3111.90N 1101.42E 6026112.33 N 573302.93 E 1.189 3300.87 5297.53 74.370 20.240 3108.52 3166.42 3197.25 N 1132.95 E 6026197.98 N 573333.63 E 0.693 3391.85 5390.19 75.080 19.780 3132.93 3190.83 3281.24 N 1163.53 E 6026282.26 N 573363.39 E 0.904 3481.24 5484.56 76.480 20.130 3156.11 3214.01 3367.22 N 1194.75E 6026368.55 N 573393.78 E 1.526 3572.71 5578.26 75.270 20.490 3178.98 3236.88 3452.44 N 1226.29 E 6026454.06 N 573424.49 E 1.344 3663.58 5672.16 74.760 20.150 3203.26 3261.16 3537.50 N 1257.79 E 6026539.43 N 573455.16 E 0.646 3754.28 5766.67 75.020 19.920 3227.90 3285.80 3623.22 N 1289.05 E 6026625.45 N 573485.59 E 0.362 3845.53 5858.91 74.940 19.870 3251.80 3309.70 3706.99 N 1319.37E 6026709.51 N 573515.09 E 0.101 3934.61 5951.81 73.480 20.360 3277.08 3334.98 3790.93 N 1350.11 E 6026793.74 N 573545.01 E 1.652 4024.01 6048.46 72.190 19.320 3305.60 3363.50 3877.79 N 1381.45E 6026880.90 N 573575.51 E 1.685 4116.35 6139.97 71.340 19.190 3334.24 3392.14 3959.84 N 1410.11 E 6026963.23 N 573603.38 E 0.939 4203.25 6238.49 74.320 19.440 3363.32 3421.22 4048.66 N 1441.25 E 6027052.35 N 573633.65 E 3.034 4297.36 6332.68 76.790 19.370 3386.81 3444.71 4134.69 N 1471.55 E 6027138.66 N 573663.11 E 2.623 4388.56 4 April, 2005 - 15:12 Page 3 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPB-50 Your Ref: API 500292324000 Job No. AKZZ3550394, Surveyed: 4 March, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6425.35 76.290 19.340 3408.38 3466.28 4219.72 N 1501.42 E 6027223.98 N 573692.15 E 0.540 4478.67 6519.93 75.850 19.100 3431.15 3489.05 4306.40 N 1531.64E 6027310.95 N 573721.53 E 0.526 4570.46 6615.67 75.710 19.820 3454.67 3512.57 4393.90 N 1562.55 E 6027398.75 N 573751.60 E 0.744 4663.26 6710.41 74.820 18.760 3478.77 3536.67 4480.38 N 1592.82 E 6027485.52 N 573781.03 E 1 .433 4754.87 6805.02 74.060 19.090 3504.15 3562.05 4566.59 N 1622.38 E 6027572.01 N 573809.75 E 0.871 4845.99 . 6899.16 73.370 19.140 3530.54 3588.44 4651.98 N 1651.97 E 6027657.68 N 573838.51 E 0.735 4936.34 6991.79 72.590 19.280 3557.66 3615.56 4735.62 N 1681.12 E 6027741.60 N 573866.84 E 0.854 5024.90 7085.65 72.050 20.560 3586.16 3644.06 4819.69 N 1711.58 E 6027825.96 N 573896.49 E 1.421 5114.33 7181.77 73.350 20.160 3614.75 3672.65 4905.73 N 1743.51 E 6027912.31 N 573927.58 E 1.410 5206.10 7275.93 77.620 20.720 3638.34 3696.24 4991.12 N 1775.34 E 6027998.00 N 573958.58 E 4.571 5297.23 7368.38 79.390 21.020 3656.76 3714.66 5075.77 N 1807.61 E 6028082.96 N 573990.03 E 1.941 5387.81 7461.85 79.260 21.240 3674.08 3731.98 5161.44 N 1840.72 E 6028168.96 N 574022.31 E 0.270 5479.65 7554.69 75.840 21.680 3694.09 3751.99 5245.80 N 1873.88 E 6028253.63 N 574054.65 E 3.713 5570.27 7649.14 73.340 21.400 3719.19 3777.09 5330.49 N 1907.31 E 6028338.64 N 574087.25 E 2.662 5661.29 7741.42 72.180 21.100 3746.54 3804.44 5412.63 N 1939.26 E 6028421.09 N 574118.40 E 1.295 5749.40 7832.08 77.240 23.670 3770.44 3828.34 5493.45 N 1972.57 E 6028502.23 N 574150.92 E 6.215 5836.75 7925.47 76.540 24.090 3791.62 3849.52 5576.62 N 2009.39 E 6028585.75 N 574186.93 E 0.868 5927.51 8022.30 77.110 22.330 3813.69 3871.59 5663.27 N 2046.54 E 6028672.75 N 574223.24 E 1.865 6021.65 8116.17 76.090 21.060 3835.45 3893.35 5748.11N 2080.30 E 6028757.92 N 574256.18 E 1.707 6112.92 8211.57 75.330 21 .020 3859.00 3916.90 5834.39 N 2113.49 E 6028844.52 N 574288.53 E 0.798 6205.36 8299.00 74.770 20.570 3881.55 3939.45 5913.36 N 2143.48 E 6028923.77 N 574317.75 E 0.811 6289.82 . 8396.18 74.750 20.080 3907.10 3965.00 6001 .29 N 2176.05 E 6029012.01 N 574349.46 E 0.487 6383.58 8488.13 74.530 19.690 3931.45 3989.35 6084.66 N 2206.20 E 6029095.68 N 574378.81 E 0.474 6472.25 8583.11 73.640 19.770 3957.50 4015.40 6170.64 N 2237.04 E 6029181.95 N 574408.81 E 0.941 6563.59 8678.61 74.020 20.510 3984.09 4041.99 6256.75 N 2268.62 E 6029268.36 N 574439.55 E 0.844 6655.31 8773.38 73.260 20.290 4010.79 4068.69 6341.98 N 2300.32 E 6029353.90 N 574470.42 E 0.832 6746.24 8866.94 74.160 20.560 4037.03 4094.93 6426.14 N 2331.66 E 6029438.35 N 574500.94 E 1.001 6836.04 8961.60 72.800 20.770 4063.95 4121.85 6511.05 N 2363.68 E 6029523.57 N 574532.14 E 1 .452 6926.79 9054.12 74.600 20.220 4089.91 4147.81 6594.23 N 2394.77 E 6029607.05 N 574562.42 E 2.027 7015.58 9148.44 74.670 20.750 4114.90 4172.80 6679.42 N 2426.60 E 6029692.55 N 574593.42 E 0.547 7106.53 9244.52 71.630 20.530 4142.75 4200.65 6765.47 N 2459.01 E 6029778.90 N 574625.00 E 3.172 7198.47 9338.55 71.420 20.120 4172.55 4230.45 6849.10 N 2489.99 E 6029862.83 N 574655.16 E 0.470 7287.65 9430.81 69.400 19.810 4203.48 4261.38 6930.79 N 2519.67 E 6029944.80 N 574684.05 E 2.212 7374.57 9523.95 66.680 20.100 4238.31 4296.21 7011.98 N 2549.14 E 6030026.28 N 574712.73 E 2.935 7460.94 9616.11 65.870 19.780 4275.39 4333.29 7091.29 N 2577.92 E 6030105.86 N 574740.74 E 0.935 7545.31 4 April, 2005 - 15:12 Page 4 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPB-50 Your Ref: AP/500292324000 Job No. AKZZ3550394, Surveyed: 4 March, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastin9s Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9710.85 65.530 19.660 4314.37 4372.27 7172.57 N 2607.05 E 6030187.42 N 574769.08 E 0.377 7631.65 9803.95 65.320 19.420 4353.09 4410.99 7252.36 N 2635.37 E 6030267.49 N 574796.62 E 0.325 7716.32 9896.10 64.800 19.150 4391.95 4449.85 7331.23 N 2662.97 E 6030346.62 N 574823.45 E 0.624 7799.86 9989.67 66.360 19.910 4430.63 4488.53 7411.52 N 2691.45 E 6030427.18 N 574851.16 E 1.824 7885.05 10085.45 66.140 19.510 4469.21 4527.11 7494.05 N 2721.02 E 6030510.00 N 574879.92 E 0.446 7972.72 . 10178.66 66.140 19.390 4506.91 4564.81 7574.43 N 2749.40 E 6030590.65 N 574907.53 E 0.118 8057.96 10271.17 65.310 21.650 4544.95 4602.85 7653.41 N 2778.96 E 6030669.91 N 574936.31 E 2.401 8142.28 10364.53 64.830 22.120 4584.30 4642.20 7731.97 N 2810.51 E 6030748.77 N 574967.10 E 0.688 8226.90 10459.85 64.150 21.900 4625.35 4683.25 7811.72 N 2842.75 E 6030828.83 N 574998.57 E 0.743 8312.88 10554.19 65.260 22.010 4665.66 4723.56 7890.83 N 2874.64 E 6030908.25 N 575029.69 E 1.181 8398.13 10649.91 64.230 21.650 4706.50 4764.40 7971.19N 2906.83 E 6030988.92 N 575061.10 E 1.129 8484.66 10742.33 65.570 21.010 4745.70 4803.60 8049.15 N 2937.27 E 6031067.17 N 575090.78 E 1.580 8568.33 10838.65 65.330 21.170 4785.72 4843.62 8130.90 N 2968.80 E 6031149.21 N 575121.51 E 0.291 8655.93 10930.55 64.960 20.020 4824.35 4882.25 8208.95 N 2998.13 E 6031227.55 N 575150.09 E 1.205 8739.31 11022.34 66.330 21.450 4862.20 4920.10 8287.15 N 3027.74 E 6031306.03 N 575178.93 E 2.060 8822.93 11117.17 66.050 20.830 4900.49 4958.39 8368.07 N 3059.03 E 6031387.25 N 575209.44 E 0.667 8909.67 11212.04 66.000 19.940 4939.04 4996.94 8449.32 N 3089.23 E 6031468.80 N 575238.84 E 0.859 8996.35 11304.64 65.580 19.620 4977.01 5034.91 8528.80 N 3117.81 E 6031548.54 N 575266.65 E 0.552 9080.81 11370.00 65.580 19.620 5004.03 5061.93 - 8584.85 N 3137.79 E 6031604.79 N 575286.09 E 0.000 9140.32 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. . Global Northin9s and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 20.120° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11370.00ft., The Bottom Hole Displacement is 9140.32ft., in the Direction of 20.078° (True). 4 April, 2005 - 15:12 Page 5 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPB-50 Your Ref: AP/500292324000 Job No. AKZZ3550394, Surveyed: 4 March, 2005 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11370.00 5061.93 8584.85 N 3137.79 E Projected Survey . Survey tool program for MPB-50 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 618.00 0.00 618.00 616.21 11370.00 616.21 CB-SS-GYRO 5061.93 MWD+IIFR+MS+SAG . 4 April, 2005 - 15:12 Page 6 of 6 DrillQuest 3.03.06.008 Re: Milne Point MPB-50 Intermediate caSing_ing Depth e Subject: Re: Milne Point MPB-50 Intennediate Casing Setting Depth From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 28 Feb 200514:50:51 -0900 JO~ d.-S' To: "Quay, Walter (Natchiq)" <QuayWD@BP.com> '. - .. 0/.... CC: JohnsoFC@BP.com Walter, This is as we discussed. The well was designed using the best infonnation you had at the time. You now have better infonnation on the geology/stratigraphy for the real well. Thanks for checking. Good luck with the remainder ofthe well. Tom Maunder, PE AOGCC Quay, Walter (Natchiq) wrote: Tom" As per our conversation of 2/26, MPB-50 reached intennediate casing depth the afternoon of Feb. 26th. The well was TD'ed in shale at 8296' measured depth. This is approximately 1200' measured depth and 290' true vertical depth shallower than the original plan. Correlation with adjacent well logs and cuttings samples indicate the well is in a shale interval. This is the deepest shale interval that can be correlated with confidence above the injection zone and within the confining zone previously identified. Due to the importance of zonal isolation of the intennediate hole section and the desire to set the shoe in a shale it was decided not to drill deeper and risk not finding a deeper shale interval. Walter Quay quavwd@bp,com (907)564-4178 (907)440-8632 - Cell 1 of I 2/28/20052:51 PM Re: Variance For 16" Diverter Line . . éi04- d-S d Subject: Re: Variance For 16" Diverter Line From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Fri, 18 Feb 200509:18:14 -0900 To: "Green, Darrell (Fairweather)" <Daryl.Green@bp.com> CC: "Quay, Walter (Natchiq)" <QuayWD@bp.com>, "Miller, Mike E" <MillerME@bp.com>, "Johnson, Frederick C" <JohnsoFC@bp.com>, Jim Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aogccyrudhoe_bay@admin.state.ak.us> Darrell, Jeff Jones called me last night regarding this matter. In similar situations this variance has been granted and it is appropriate to do so here. It is requested that the need for such variances be recognized "up front" so it can be addressed in the planning process. I think we all recognize that the likelihood of needing to divert is pretty small, although not zero. Flow lines and electrical cables are often proximate to where diverter lines may be pointed. What is BP's HSE guidelines with regard to these situations?? Tom Maunder, PE AOGCC Green, Darrell (Fairweather) wrote: Mr. Tom Maunder Doyon 14 is currently rigged up on well number B-50 at Milne Point. The 16" Diverter line is exiting out the rear of the rig 41 feet and the outlet is positioned at a height between the electrical cable tray's and the flow lines. I would like to get a variance for using the shorter length of 16" diverter line. Darrell W. Green Doyon Rig 14 - Drilling Supervisor Phone (907) 670-3268 Fax (907) 670-3269 1 of 1 2/18/2005 9:22 AM RE: MPB-50 Surface Casing Cementing Contingencies . . Subject: RE: MPB-50 Surface Casing Cementing Contingencies From: "Johnson, Frederick C" <JohnsoFC@BP.com> Date: Tue, 15 Feb 2005 16:08:38 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Quay, Walter (Natchiq)" <QuayWD@BP.com> dOL( - ~Ç). The purpose of the document you refer to is set minimum acceptance criteria with the EPA for surface casing cementing. It does not attempt to state the actual details of how the criteria will be met. We plan to follow all AOGCC requirements with respect to well construction. AOGCC will be notified of any significant deviations from the well plan, especially concerning surface casing cementing and LOT/FIT tests. Thanks for the comments. -----Original Message----- From: Thomas Maunder [maìlto:tom maunder@admin.state.ak.us] Sent: Tuesday, February IS, 2005 3:54 PM To: Johnson, Frederick C Cc: Jim Regg¡ Thor Cutler Subject: MPB-50 Surface Casing Cementing Contingencies Fred, We have received a copy of Ms. Vosika's letter to Mr. Bussell regarding notification of cementing operations on MPB-50. In the attachment, 2 contingencies are listed in the event cement is not circulated on the surface casing. Per usual practice, should cement not be circulated on the surface casing BP should notify the AOGCC Inspector (659-2714) prior to performing any top job or other remedial operation. Also, if it is deemed necessary to change the planned LOT below the surface casing shoe from other than what was submitted in the well plan you should contact us. Please call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 2/18/2005 9:29 AM ~ --------.-- ., . . ~~ o J bp çJ04 - ifS d- By Facsimile BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (9071561-5111 February 8, 2005 Mr. Michael A. Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency (OW-137) 1200 Sixth Avenue Seattle WA 98101 UIC Permit AK-11005-A Milne Point Unit Notification of Cementing Operations Dear Mr. Bussell: The purpose of this correspondence is to formally provide the Environmental Protection Agency (EPA) with notice of the cementing operations, as required by the Milne Point Class I well permit AK-11005-A, Part 11.A.1. BP Exploration (Alaska) Inc. (BPXA) staff have been in close communication with Mr. Thor Cutler and Mr. Talib Syed concerning the drilling schedule and acceptance criteria for cementing and demonstrating integrity of the MPB-50 disposal well. Based on the attached drilling schedule updated on February 3, 2005, BPXA anticipates the disposal well will spud on February 15, 2005; the surlace casing will be cemented on February 18-19; and the intermediate casing will be cemented on February 28 - March 1, 2005. This schedule is subject to change. Updated schedules ,.. Mr. Michael A. BUSS. February 8, 2005 Page 2 . (, will be shared with Mr. Cutler and Mr. Syed as they become available. A pre-spud teleconference was held on January 26, 2005 to review the well plan; acceptance criteria; drilling schedule; and EPA logistics. Attached are the drilling schedule updated last on February 3, 2005 and the document that has been developed to assist in communication of the disposal well acceptance criteria. If you have any questions please call Fred Johnson at 907-564-5427 or Alison Cooke at 907-564-4838. Sincerely, ~7U~ Janice L. Vosika Milne Point Delivery Manager JLV/ADC Attachments cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant - Tom Maunder, AOGCC Trevor Fairbanks, ADEC . . . Well MPB-50 Milne Point Class I Disposal Well Tentative Schedule Drill and Complete Time Period Range for Activity to Commence February 3, 2005 Activity December 16,2004 Transmit well planning documents to EP A Teleconference or Meeting(s) between EPA reps, EPA consultant, & BP reps to facilitate the development and agreement of the acceptance criteria matrix. January 26,2005 (1 hour) February 14, 2005 EP A consultant to meet BP Milne Point Anchorage personnel he will be working with and to review roles, responsibilities, & timings. Obtain Security badge February 9-10, 2005 February 15-16, 2005 NSTC training if required - None Required Fly up to Deadhorse. Milne Point training. February 15, 2005 Spud MPB-50 Well February 15-17,2005 (3 days) Drill, survey, LWD log 16" surface hole February 18-19,2005 (2 days) Run and Cement 13-3/8" surface casing February 20-27, 2005 (8 days) Drill, survey, LWD log 12-1/4" intermediate hole. February 28- March 1 (2 days) March 2- March 6 (5 days) March 7-8 (2 days) Run and Cement 9-5/8" intermediate casing Drill, survey, LWD log 8-112" hole thru injection zone March 9 (1 day) Run and cement 7" liner Run cement bond log across 7" liner and 9-5/8" casing Perforate and complete well March 10-13,2005 (4 days) March 12-13, 2005 (1 day) March 14,2005 (1 Day) March 14 - April 13, 2005 (30 days) Mechanical Integrity test of packer Rig down. Move drilling rig off well April 14-20, 2005 (2-7 days) Install surface well facilities External Mechanical Integrity testing, Step rate test. MPB-50 Class I Disposal Well Informal Guide to Communication Completion Checklist 1. Cement to Surface on Surface Casing Observed 2. Intermediate Casing Cement USIT Bond Log Results 3. Determine Tops and Bases of the Injection Zones from Openhole LWD Logs 4. Injection Packer is within 50'TVD of the Top of the 7" liner 5. Internal Mechanical Integrity Test (Tubing/Casing/Packer) 6. External Mechanical Integrity Test (Fluid movement tests) 7. Baseline Step Rate Test / Baseline ISIP & Shut In Period Check Completed Date . . Page 1 , .- - Indicators to assist Communications 1. Surface Casing Cementing Successful Surface Casing Cementing is determined by circulating Cement to Surface as defined below 'Cement to Surface' acceptance criteria is defined by one of the following; · Visual confirmation of red dye from cement spacer · Measured returns with a density of 10.0 ppg or greater · Increase of pH mud baseline to or above 9.0 Contingency: If there are operational problems during the surface casing cementing operations or if cement is not circulated to surface the following operations may be recommended: "( a. Perform a Top Job cement operation with small 1" tubing to cement the surface casing x open hole annulus if the Cement to Surface criteria is not met during the primary cementing operation. ~ b. Perform an FIT test to 11.0 lb/gal after drilling out the surface casing shoe. . 2. Intermediate Casing Cementing 'Intermediate Casing Cement USIT Bond Log' acceptance criteria is defined by the following; · 50' of bonded cement interval, not necessarily continuous but containing one zone of continuous cement bond of 15' or more is required, from the base of the confining zone (TUZC marker at ±9550'md) to the top of the confining zone (UG3 marker at ± 6175' md). · The USIT log will be run with the Schlumberger default for "Acoustic Impedance Threshold for Cement" of 2.6 Mrayls for 15.8Ib/gal Class G cement. This log should be printed out for the EPA consultant onsite and the Schlumberger Engineer should immediately send a PDS file of the log to BP Engineer in town. This log will confirm the presence of cement and will allow us to jointly agree on 50' of non-continuous cement bond within the confining zone. · 'Bonded Cement' is defined as any interval which demonstrates a compressive strength equal to or greater than the input compressive strength referenced above. Any degree of shading, as represented on the USIT log, indicating a compressive strength equal to or greater than the input, will be considered to have cement bond capable of providing zonal isolation. · USIT log can be run with casing pressure, but casing pressure should not exceed 1000 psi. . Top of the Intermediate Casing Cement The basis of design for the 9-5/8" intermediate casing cementing program is to cement the casing from the shoe at ±9518'md up to ± 5675'md which is 500' above the confining zone (defined as the UG3 marker at ±6174'md). While the top of cement is designed to be at ±5675'md, this cement t<?p is not an acceptance criteria for 5 this well. The confining zone interval in this well is a long ±3875' section ofthe well where zonal isolation will be obtained. Page 2 The USIT log will identify the top of LiteCrete lead cement but the Acceptance Criteria for the intermediate casing cementing will be the zonal isolation demonstrated by the USIT log and not the cement top. The USIT bond log will determine the presence of cement by any degree of shading indicating a compressive strength equal to or greater than the input compressive strength. Injection Liner Cementing The entire 7" liner/8-1/2" hole interval in the well has been identified as the injection interval. The purpose of the 7" liner cement job is to provide zonal isolation between individual sands so that a better understanding of reservoir performance can be obtained during the injection operation. This understanding will be useful in determining potential UIC injection well requirements in the future. The 7" liner cement job and the 8-1/2" hole interval are not designed to provide the confining zonal isolation required to prevent upward movement of injected fluids. The 9-5/8" intermediate casing cement job across the designated confining zone is designed to prevent this upward movement of fluids. The 7" USIT log is for information purposes only and is not identified as an acceptance criteria for the well construction. . 3. 'Top & Base of Injection Zones' will be determined from the 8-1/2" open hole L WD logs. The picks will be determined by the Milne Point geologist and will be confirmed by the EP A inspector. The primary purpose of the L WD data is for identification of critical geologic markers. Acceptable L WD data quality is defined as the ability to pick the top and base of the confining and injection intervals. 4. 'Injection Packer is within 50' tvd of the Top of the 7" Liner' will be confirmed by the liner and tubing tallies and the wellbore schematic which illustrate the setting depth of the packer in relation to the Top of the 7" Liner. The 9-5/8" injection packer is to be placed adjacent to the confining zone and as close to the 7" liner as practicable (permit allows 50' tvd). 5. 'Internal Mechanical Integrity Test (Tubing/Casing/Packer)' acceptance criteria is defined as a positive pressure test of the 7" tubing x 9-5/8" casing annulus to 3500 psi for 30 minutes. Pressure shall show a stabilizing tendency. During the test period, the pressure shall not decline more than 10% and shall not experience less than 1/3 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 test period may be extended for an additional 30 minutes to demonstrate stabilization. At the time of the test, the tubing shall be open or the tubing pressure shall be significantly lower than the annulus pressure. . 6. 'External Mechanical Integrity Test' acceptance criteria is defined as Approvable fluid movement tests which reveal no fluid movement above the confining zone. The top of the confining zone is defined as the U03 marker which is estimated to be at 6174'md. Movement above the U03 may indicate a failure to demonstrate external mechanical integrity. Additional Page 3 - - , diagnostics and/or alternate logs or procedures will be required to confirm that the well has external mechanical integrity with no flow movement behind pipe. Approvable fluid movement test include, but are not limited to tracer surveys, temperature logs, noise logs, water flow logs (WFL), borax pulse neutron logs (PNL), or other logs. The survey shall be conducted at the maximum continuous injection pressure observed in the previous six months. A water flow and temperature log will be run to meet the external mechanical integrity 7. 'Baseline Step Rate Test' is defined as a test which will be conducted in order to establish a baseline for future diagnostics. Best information shall be gained by a step rate test followed by an ISIP and a shut in period (30 minutes or longer depending on operational constraints) to determine the break down pressure of the formation. There will be no "PassIFail" criteria. The above list has been prepared is to enhance communication between EPA and BPXA. It does not modify permit number AK- 1l005-A, nor does it relieve BPXA of its obligation to comply with all terms and conditions of the permit. . . Page 4 . ~~!Æ~! lID F !Æ~]~~!Æ . A"#A~1iA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPB-50 BP Exploration (Alaska) Inc. Permit No: 204-252 Surface Location: 5144' NSL, 4062' WEL, SEC. 19, T13N. RIlE, (As-Built) Bottomhole Location: 3618' NSL, 624' WEL, SEC. 07, T13N, RIlE, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced service well. Prior to placing this well in operation, necessary corrections and additions to Area Injection Order No. 10 B ("AID lOB") as described in the Commission's letter to Ms. Janice Vosika dated December 13,2004 must be completed. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t 'tness any required test. Contact the Commission's petroleum field inspector at (907) 659 607 ager). DATED this-1'1 day of December, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 181 Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 5144' NSL, 4062' WEL, SEC. 19, T13N, R11E, (As-Built) Top of Productive Horizon: 1630' NSL, 1466'WEL, SEC. 07, T13N, R11E, UM Total Depth: 3618' NSL, 624' WEL, SEC. 07, T13N, R11E, UM / 4b. Location of Well (State Base Plane Coordinates): Surface: x- 572232 i y- 6022990 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 300' ~ feet Maximum Hole Angle: 75 degrees I STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory 0 Deve~~~ QH &jiMJt~z~mI5~íon o Stratigraphic Test 181 Service 0 Development Gas J;hêtfötlSØá>ne 5. Bond: a Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 MPB-50 6. Proposed Depth: / 12. Field / Pool(s): MD 11886' / TVD 5242' Milne Point Unit / Ugnu & 7. Property Designation:,,&b Schrader Bluff / ~::;"3ß.l! ADL 047432 11.',/,7,0" 8. Land Use Permit: RE. C-'Ehv· -- I:>. ~ I:: '.., ED DEC 2 1 2004 13. Approximate Spud Date: 02/15/05 9. Acres in Property: ."óP 14. Distance to Nearest Property: .~ I UB . .1.r;if -1633' t'Z,'" 18. Casing Program: Size CasinQ 20" 13-3/8" 9-518" Hole 42" 16" 12-1/4" 8-112" WeiQht 92# 68# 47# 26# Specifications Grade Couplinç¡ H-40 Welded L-80 BTC L-80 BTC L-80 BTC-M Lenç¡th 115' 3284' 9518' 2486' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 58.1' feet 3133' away from MPB-24 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 2178 -' Surface: 1671'" $ettingDepth Tòp Bottom MD TVD MD TVD Surface 115' Surface 115' Surace 3284' Surface 2623' Surface 9518' Surface 4228' 9400' 11886' 4242' 5242' 7" (includinç¡ stage data) 260 sx Arctic Set (Approx.) 580 sx Arctic Set Lite, 310 sx 'G' 429 sx LiteCrete, 575 sx Class 'G' 432 sx Class 'G' 19. PRESENTWEI...L CONDITION SUMMARY (To be completed for RedrillANPRt);"entry Opijratiøn~) -Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Depth TVD (ft): Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments a Filing Fee, $100 0 BOP Sketch a Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): a Drilling Program 0 Time vs Depth Plot o Seabed Report a Drilling Fluid Program o Shallow Hazard Analysis a 20 MC 25.050 Requirements Date: Contact Walter Quay, 564-4178 Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Fred Title Senior Drilling Engineer Phone 564-5427 Date Prepared By Name/Number: Sondra Stewman, 564-4750 Permit To Drill " / I API Number: r /. ~ Permit Appr0.xal ,/ See cover letter for Number: ,,).LJ~~ 25"2 50- CS2-9 - 232"'16- CX'.::;¡ Date: / ::J../dJ1/ Or other requirements Conditions of Approval: Samples Required 0 Yes gNo Mud Log Required 0 Yes gNo Hydr en Sulfide Measures 0 Yes ~No Directional Survey Required .EJYes 0 No , \J ~ ~<J V ~~ \-. "'" \', Q <:.ri::~~.~\-~"'H;'- \ ~ ~ \C)<s " . """t-«t~ ~f\.\S ~~S~ 'Ð~ ~o.\\,,>~\(::~ ?\\C\-\'c \'\ú<..\,.....~ \I.)~\\\t'\~~\~\<:f, Date I,JzJl4ct ~b~l/n ;uticate APPROVED BY THE COMMISSION /": ~Ç;t;;l-1 . . bp I Well Name: I MPB-50 Class I Injector Drilling and Completion Plan Summary I Type of Well: I Class 1 Injector Surface Location: (As Built) Distance to Property line Distance to nearest well 5,144' FSL and 4,062' FEL .- Section 19, T13N, R11 E UM E = 572,232' N = 6,022,990' / 1,630' FSL and 1,466' FEL Section 7, T13N, R11 E UM E = 574,730' N = 6,030,060' Z = 4,293' TVD 3279 ' FSL and 843' FEL Section 7, T13N, R11 E UM E = 575,330 ' N = 6,031,715' Z = 5,073' TVD 3618' FSL and 624 ' FEL Section 7, T13N, R11 E UM E = 575,545 ' N = 6,032,056 ' Z = 5,242' TVD -1,633' 3,133' from MPB-24 T1 --Top Injection Zone T2 -- Base Injection Zone BHL I Estimated startl Date: 115 Feb 05 I Rig days to complete: I 33 MD: 111,886' 'I TVD: /5242' 1/ I Max Inc: 1750 Well Design: Class I Injector Objective: Ugnu & Schrader Bluff I KOP: /300' 1/ I KBE:/58.1' Mud Program: 16" Surface Hole 9.0 - 9.4 8-15 20 - 25 9.0-9.5 6-8 < 25 ,,' Page 1 . . Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to D5-4 disposal site " Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. CasinglTubing Program 42 in 20 in* 92# H-40 Welded 115 0' 115' 1115' 16in 13.376 68# L-80 BTC 3284' 0 3284'/2623 12.25 in 9.625 in 47# L-80 BTC 9518' 0 9518' 1 4228' 8.5 in 7.0 in 26# L-80 BTC-M 2486' 9400' 11886' 1 5242' Cement Program: Casing Size Basis Total Cement Volume: 523 bbl Casing Size Basis Total Cement Volume: .312 bbl Casing Size Basis Total Cement Volume: 90 bbl 13-3/8", 68#, L-80, BTC Surface Casing at 3,284' MD Excess from B/Permafrost to Surface = 150% over gauge hole. Use 40% excess below the B/Permafrost. Tail cement = 500' MD. Wash 10 bbl water 20 bbl CW 100 40 bbl of MudPush 459 bbl, 580 sx of Arctic Set Lite: 10.7 ppg and 4.45 fe/sx 64 bbl, 310 sx "G" mixed at 15.8 Ib/gal & 1.17 felsx Spacer Lead Tail 9-5/8",47#, L-80, BTC Surface Casing at 9,518' MD Excess = 40% over gauge hole. Tail cement = 1500' MD above shoe. Top of Tail 500' above Top Confining Zone (-5600' MD) 10 bbl water Wash 20 bbl CW 100 Spacer 40 bbl of MudPush Lead 189 bbl, 429 sx of LiteCrete: 12.0 ppg and 2.47 fe/sx Tail 123 bbl, 575 sx "G" mixed at 15.8 Ib/gal & 1.20 ft;j/sx 7",26#, L-80, BTC-M Intermediate Casing at 11,886' MD Excess = 40% over guage hole. Top of Cement 150' above liner top with DP in the hole. 5-bbl water Wash 20 bbl CW 100 Spacer 50 bbl of MudPush Tail 90 bbl, 432 sx "<3" mixed at 15.8 Ib/gal & 1.17 fe/sx Temp BHST =80°F from SOR Page 2 . Evaluation Program: 16" Section Open Hole: MWD/GRlRES / I FRlCASANDRA, Detection, Mud and . InSite, Mud Logging with Gas Wellsite 12-1/4" Section Open Hole: MWD/GRlRES/ACAUNEU/DEN/SONIC/PWD ,. IFRlCASANDRA, InSite, Mud Logging with Gas Detection, Mud and Wellsite 8-1/2" Section Open Hole: MWD/GRlRES/ACAUNEU/DEN/SONIC/PWD IFRlCASANDRA, Sperry InSite, Mud Logging with Gas Detection, Mud and Cuttings Sampling, Wellsite Geologist Cased Hole: GR 1 US IT (In PDC Mode) to TOC in 9-5/8" Formation Markers: Formation Tops BPRF UG3 TUZC Ugnu-MA Ugnu-MB2 SBF2-NA SBF1-NB TSBD - Top OA SBA5-Base DB MD (ft) 2,040 6,174 9,555 1 0,432 10,563 10,906 10,941 11 ,238 11 ,487 TVD (ft) 1,958 3,388 4,283 4,628 4,683 4,828 4,843 4,968 5,073 Recommended Bit Program: Pore Pressure (psi) 825 1433 1834 1984 2008 2071 2078 2132 2178 EMW (Ib/gal) 8.35 8.35 8.35 8.35 8.35 8.35 8.35 8.35 8.35 1 2 3 16 in 12.25 in 8.5 in Surf - 3,283' 3,283' - 9,555' 9,555' - 11,886' 3,283' 6,272' 2,331 MX-1 Page 3 . . Well Control: Intermediate/Production hole: ,¡ · Maximum anticipated BHP: 2,178 psi at 5,073' TVD (Top of the OB sand) · Maximum surface pressure: /1,671 psi at (Based on a full column of gas at 0.1 psi/ft) · Planned BOP test pressure: 3,000 psi wi" · Integrity tests: FIT to 11.5 Ib/gal 20' below the 13-3/8" shoe. Kick tolerance: 95-bbl with 9.0 Ib/gal mud at below the 13-3/8" shoe. · Integrity tests: FIT to 11.5 Ib/gal 20' below the 9-5/8" shoe. Kick tolerance: Infinite with 9.0 Ib/gal mud at below the 9-5/8" shoe. · Planned completion fluid: Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: · Hydrates have not been reported on B-Pad however nearby pads have seen hydrates to 3000'. ". · Tight hole and stuck pipe due to clays and poor hole cleaning have occurred on B Pad wells. · A coal zone is expected -3600' TVD based on MPB-27. ,/ Lost Circulation · We do not expect losses while drilling this well if there is good hole cleaning.lf seepage and/or losses occur, follow the LOST CIRCULATION DECISION MATRIX in the well plan. Expected Pressures · All Formation are expected to be normally pressured: 8.7 ppg. / Pad Data Sheet · Please Read the B-Pad Data Sheet thoroughly. Hydrocarbons · Hydrocarbons are note expected. Faults · One (1) fault is mapped in the intermediate hole section at ± 4923' MD. Hydrogen Sulfide · MPB Pad is not designated as an H2S Pad, however, low concentrations of H2S has been detected from Kuparuk wells on the pad: MPB-03 28 ppm 9/2004 MPB-04A 9 ppm 9/2004 MPB-06 5 ppm 9/2004 The highest concentration of H2S on MPB: MPB-03 41 ppm 3/2001./ Anti-collision Issues · MPB-50 passes the Major Risk Criteria. Gyro surveys will be required for magnetic interference down to ± 1000 ft MD. Distance to Nearest Property · MPB-50 is -1630ft from the nearest Milne Point property line. / Distance to Nearest Well Within Pool · MPB-50 is 3,133 ft from the nearest sand penetration in MPB-24. / Page 4 . . DRILL & COMPLETION PROCEDURE Pre-Ria Operations 1 . The 20" conductor will be installed pre-rig. .Drillina: 1. MIRT and NU Diverter. 2. Function Test Diverter, PU 5" DP and BHA. 3. Drill 16" surface hole. 4. Run and cement 13-3/8" surface casing. 5. ND diverter, install wellhead and NUlTest BOPE. 6. Drill 12-1/4" intermediate hole to the bottom of the UG3(Confining Zone). 7. Run and cement 9-5/8" intermediate casing. 8. Drill 8-1/2" hole to TD. 9. Run and cement 7" liner. 10. MU Clean Out BHA & Clean out Liner & Casing 11. Displace the well with kill weight brine. lDDP. 12. Run a GR 1 US IT / eel on E-Line. 13. Perforate the Well. 14. Run a 7", completion. 15. ND BOP/NU Tree. 16. Freeze Protect. 17. RD & MO Doyon 14. Page 5 MPB-50 Distlsal Well Proposl Completion Wellhead: 13-5/8", 5K, Big Bore, FMC Tree: 6-3/8" bore x 7-1/6", 5K, 625 Inlay, CIW 115' MD 20"lnsulated Conductor - - 7" HES R Nipple 2000' MD 3284' MD(2623' TVD 13-3/8",68#, L-80, BTC 7", 26#, TC-II, L-80 Injection Tubing 11,487' MD(5073' 11,886' MD(5242'TVD) Top of Cement (Est.) 5675' MD(3256' TVD) 6174' MD(3388'TVD} G3Marker 7" x 5.963" HE5 R Nipple 9350' MD (4228' TVD) 7" x 9-5/8" 53 packer 7" x 5.963" HE5 R Nipple 7" x 5.77" HE5 RN Nipple 7" WLEG 7" x 9-5/8" Baker FlexLock Liner Hanger, ZXP Liner Top packer, and tieback sleev 9518' MD(4273'TVD 9-5/8",47#, L-80, BTC-M TUZC Marker 7", 26#, L-80, BTC-M Date Rev By Comments WDO Version 2 Plan MPB-50 Well Schematic Milne Point Rotary Drilling 12/14/04 \~\ -1\ ~ ~~L------l -0 \ \ b \ 20. ®J . 21 ¡ \ ~ I . 19 I I 18. l .241 , 8. . 12 I \ I \ 7. .141 \ I \ 11. .13Ll~~A~LSI~~ I --..:..:::::,...-:::: \ . 16 í--------~ I 9. I I I I 10. .151 123. : 16. .221 ".-...¡f . 5AI B-27fs-" I 'L -'·1· I!, 17 -26. 3 I -'" SEe 18 Î 25. !::õJ sf(: . . . I tB-50 19 -'. 1 . 4 ¡:!I -- I I ,/ B-PAD I ª .<: I ;" 7~~--W-__d +.,~ ~~ ~l"6 ~'\() / NOTES 1. DATES OF SURVEY: November 6-7, 2004. 2. REFERENCE FIELD BOOK: MP04-04 (PGS. 3- 7) 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS 0.999905887. 5. HORIZONTAL/VERTICAL CONTROL BASED ON MONUMENTS B-1 AND B-2. 6. ELEVATIONS ARE BP MPU DATUM (M.S.L.). LOCATED WITHIN PROTRACTED SEC. 19, T. 13 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=6,023.042.84 N. 1,387.97 70'28'23.661" 70.4732392' 5,199' FSL 26 X= 572,006.48 E. 600.32 149'24'42.682" 149.4118561' 23.7 4,287' FEL 27 Y= 6,023,092.10 N. 1,437.95 70'28'24.147" 70.4733742' 23.3' 5,249' FSL X= 571,997.32 E. 603.88 149'24'42.937" 149.4119269' 4,295' FEL Y= 6,022,989.89 N. 1,279.92 70'28'23.119" 70.4730886' 5,144' FSL " 50 X= 572,231.76 E. 804.99 149'24'36.073" 149.4100203' 23.8 4,062' FEL /' / N 2800 + / ,.,. _.Q:) &/;; C/J.lf/ <..J'<..J 2/::: Q::' .Q:: / / / - . l ~ ~ ií ! ~ ! ¡ j ,¡ ð ! ~ s i i ~ ~ t 0 11/07/04 ISSUEO FOR INFORMATION ~ NO. DATE REVISION . o ~ .... . "- lsf ~ ~ -'Q ~ 5 ...J 0: ~ t1 o "< ...J I -~- I ~ VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOV. 6-7, 2004. LEGEND + AS BUILT CONDUCTOR . EXISTING CONDUCTOR ¡b' DRAWN: Obp Hackleman CHECKED: ONeil OATE: 11/07/04 DRAWING: SHEET: FRB04 MPB 02-00 MILNE POINT UNIT B - PAD i ffJ~~[lJ[t;o JOB NO: SCALE: AS-BUILT WELL CONDUCTORS 1 Of 1 I(M-I MLO DONŒRS AND LAN) StJfrÆ'fORS WELLS B-26, B-27 & B-50 110I '/lEST nRDUO LANE 1" = 400' BY a-tK AHOCIItAG[, ALASKA tll5œ i Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target - -11' I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 - .......... 2 304.10 0.00 0.00 304.10 0.00 0.00 0.00 0.00 0.00 -- Start Dir 1.5/100': 300' MD, 30O'TVD 3 704.10 6.00 5.00 703.37 20.85 1.82 1.50 5.00 20.20 0 " . 4 1404.16 20.00 6.00 1383.80 177.14 17.61 2.00 1.41 172.38 5 1859.47 27.50 19.00 1800.52 354.33 60.06 2.00 41.02 353.37 - Start Dir 2/1 00' : 700' MD, 699.27TVD 6 1919.87 27.50 19.00 1854.10 380.70 69.14 0.00 0.00 381.25 - 7 3099.04 74.65 20.61 2574.25 1218.13 375.38 4.00 2.12 1272.92 - ... .......... 8 9555.79 74.65 20.61 4283.10 7046.20 2566.98 0.00 0.00 7499.20 MPB-5 9 9876.38 65.04 20.47 4393.43 7327.68 2672.46 3.00 -179.26 7799.80 =UI 1;7 EndDir : 1855.37'MD, 1796.42'TVD 10 11486.80 65.04 20.47 5073.10 8695.45 3183.07 0.00 0.00 9259.74 MPB-5 11 11686.80 65.04 20.47 5157.51 8865.31 3246.48 0.00 0.00 9441.05 Start Dir4!100': 1915.77' MD, I 850'TVD 12 11886.80 65.04 20.47 5241.92 9035.18 3309.90 0.00 0.00 9622.36 ~ I 7(' . m.. .m.m.mm1", I EndDir :3094.93'MD,2570.15'TVD - . - . .m ,. , i : 'J' ~W± ....., _ ,m >UJU "J' i ....... -~ : _ .." ..m i , ,m 'Om..m ~ i - ,do ....,..." , - ... 'm ~ , "'" --'" _ '!o - '. , þ51)o : : 'i , : I - r-. - I I .., , - " , .1., : , I-)T~ Start Dir3/100'; 9551.62' MD, 4279'TVD , - m"m i: i - rrflm . : ..... End Dir : 9872.2' MD, 4389.33' TVD _, 'm , t" / _ ..m"" ~. / - . ..... i /~m¡¡ ,.., ¡..:.... únl i i : : , : , ! : ~ f"'- ~I,m ¡ - ... i tt.. , ,." ;......+..m.. I .~m G~ ~,'.'.,.... : , 'm '"",'..".. mm '" ....m:'" , <M,_; I i , ,( - ....,.,. , H ~~¡¡;T=~ Y - i ....... i /1'0 y.- - : I . i i :, i i : ¡ : : i ' . I : , , i : 2¡iii i : 7' i: i . , , i i : ii, , - .. I, i : !i ,T!! "', , m!t! !! ! u ¡, i T! ...: ,t ... ../ I,! , Tnt.. - . .,... ... ¡ ¡ i, i ! i , ; ! ! : - , I , I I I , , , , , , I I I I J , , , I I I I , , COMPANY DETAILS BP Amoco bp CaJculøtioo Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Waming Method: Rules Based CASING DETAILS No. TVD MD Name Size 2623.10 3283.63 133/8" 13.375 4273.10 9518.01 9 5/8" 9.625 5241.58 11886.00 7" 7.000 o 1100 " ~ 2200 0 ::: -S ¡¡. 0 .. <.> '€ " > " 2 F- 3300 4400 5500 o 1100 REFERENCE INFORMATION Co.-ordioate (N/E) Reference: Well Centre: MPB-50 Plan, True Nroth VerticaJ(fVD)Referenœ: 34.3+23.858.10 Section(VS)Reference: Slot- (O.OON,O.OOE) Mew;ured Depth Reference: 34.3 + 23.8 58.10 Calculation Method: Minimwn Curvature SURVEY PROORAM Plan: MPB-50 wp03 (MPB-50 PlanlMPB~50) Created By: Digital Business Qient User Dale: J J1l9/2004 Depth Fm Depth To Survey/Plan 34.30 1404.10 Planned: MPB-SO wp(I3 V18 1404.10 11886.80 Planned: MPB-50 wp03 VI8 Tool CB-GYRO-SS MWD+JFR+MS Check.ed: Date: ReViewed: Date: FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1958.10 2039.87 BPRF 2 3388.10 6174.11 UG3 Top Confining Zone 3 4283.10 9555.79 TUZC Top Injection Zone 4 4628.10 10432.40 MA 5 4683.10 10562.72 MB2 6 4828.10 10906.29 SBF2-NA 7 4843.10 10941.83 SBFI-NB 8 4968.10 11238.01 TSBD- Top OA 9 5073.10 11486.80 SBA5 Base Injection Zone WELL DETAILS N_ +N/·S +EI·W Northing """"s Laütude LÐngitude Slot MPB-SO Plan 1437.07 470.13 6022989.89 572231.76 70"28'23.119N 149°24'36.073W N/A TARGET DETAILS Name TVD +N/-S +EI-W Northing Easting Shape MPB-50 T\ rev 4283.10 7046.20 2566.98 6030060.00 574730.00 Circle (Radius: 200) MPB-50 T2 rev 5073.10 8695.45 3183.07 6031715.00 575330.00 Circle (Radius: 200) SECTION DETAILS 2200 3300 4400 5500 6600 7700 8800 9900 Vertical Section at 20.12° [lIOOftlin] . o T\ rev o T2 rev . I I I I I Plan: MPB-SO wp03 (MPB-SO PlanlMPB-SO: Tool Created By: Digital Business Client User Date: II/J 9/2004 CB-GYRO-SS Checked: Date_ MWD+IFR+MS WELL DETAILS N""" +N/-S +EI-W Northing ""'"'" Latitude Longitude Slot MPß..50PIan 1437.07 470. 6022989.: 572231 70"28'23.119N 149'>24'36.073W NIA SURVEY PROGRAM Depth Fm Depth To SurveylPlan 3430 1404.10 Planned: MPß..50 wp03 VI 1404.10 11886.80 Planned: MPB-SO wp03 VI .; REFERENCE INFORMATION Co-ordinate (NÆ) Reference: WeJl Centre: MPB-SO Plan, True Nonl Vertical (fVO) Reference: 34.3 + 23.8 58.10 Section (VS) Reference: Slot - (O.OON,O.OOE) Meas~~~~~; ~~.~~IO COMPANY DETAILS BP Amoco Calculatioo Method: Minimum CI.I1"\IIIture furor System: ISCWSA Scan Method: Tmv Cylinder North ErrorSurfàce: Elliptical+Casìng Warning Method:· Rules Based See I 2 3 4 5 6 7 8 9 10 11 12 TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape MPB-50 Fault 1 3058.10 2275.87 985.46 6025275.00 573195.00 Polygon MPB-50 Tl rev 4283.10 7046.20 2566.98 6030060.00 574730.00 Circle (Radius: 200) MPB-50 T2 rev 5073.10 8695.45 3183.07 6031715.00 575330.00 Circle (Radius: 200) SECTION DETAILS Ine Azi TVD +N/-S +E/-W DLeg TFaee VSec Target 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 . 0.00 0.00 304.10 0.00 0.00 0.00 0.00 0.00 6.00 5.00 703.37 20.85 1.82 1.50 5.00 20.20 20.00 6.00 1383.80 177.14 17.61 2.00 1.41 172.38 27.50 19.00 1800.52 354.33 60.06 2.00 41.02 353.37 27.50 19.00 1854.10 380.70 69.14 0.00 0.00 381.25 74.65 20.61 2574.25 1218.13 375.38 4.00 2.12 1272.92 74.65 20.61 4283.10 7046.20 2566.98 0.00 0.00 7499.20 MPB-50 Tl rev 65.04 20.47 4393.43 7327.68 2672.46 3.00 -179.26 7799.80 65.04 20.47 5073.10 8695.45 3183.07 0.00 0.00 9259.74 MPB-50 T2 rev 65.04 20.47 5157.51 8865.31 3246.48 0.00 0.00 9441.05 65.04 20.47 5241.92 9035.18 3309.90 0.00 0.00 9622.36 MD 34.30 304.10 704.10 1404.16 1859.47 1919.87 3099.04 9555.79 9876.38 11486.80 11686.80 11886.80 " .,.. ~'1¡ 9000 7500 . Size 13.375 9.625 7.000 No. TVD MD Name I 2623.10 3283.63 13 3/8" 2 4273.10 9518.01 95/8" 3 5241.58 11886.00 7" FORMATION TOP DETAILS No. TVDPath MDPath Fonnation BPRF UG3 Top Confining Zone TUZC Top Injection Zone MA MB2 SBF2-NA SBFI-NB TSBD-Top OA 't'1A':;;: Un..", T~t;9'í1 ~~ //"'1'_ /1/ "'f>-- /~~11~ / i/ 1/ ¡./¡ ,.{ V ,/ i ,/ "'... )^ ...y..... ~ i ~.~..~ 1 // ,/1' f/t:~/}/L/f )<...... /)<~/ ,...~, :/~",><)~""'>l"'i . . /' /i )-' ;.-' i / ¡ /1 X,.~:(' ...~",/ ~K" / ........ / ~'-)~... ~ ",/"~J" i;< /:' ì' ,;...~~ ) ".,,></...~><... /)<''''~:>,(;<''':-h ~ "" "', /i,/' /r)( -/"./ "'''<' Y"./ "v __ I /"//( J J"'y ..........>< )<""" /"........../..." ><'~,L 1ft, ~ ,,' j i /V~'''/' ",'¿:,,- /:><..."..... / ......,.< ,/ 4t¡, ~ / /1//(/'",>/"">( ~.><.......... //"'>( )/, ~ /" //L/"~,>« ".....><...:'~:>('''''''></^...;>(:... "», ~ ~/ ,o', / ",c, .,"" ,,/ ',.( /.....;/ r, -" >z / ",,/ ...< ~ "., -" --... ~ //"-"y-" :-:/,,"-</"...,>'(( ~':y-::..., 7~ ~-- /'< /', / ", /', .y '''-<-'''<.'';;>( /)'.....~?< ~·7.. ~ '-( '>:, " ',o ~ 4' ~ .....;::-()/ ",> 4:fþ ..,. ., >___7" , ., "ift, 2039.87 6174.11 9555.79 10432.40 10562.72 10906.29 10941.83 11238.01 'l1W'\VO 1958.10 3388.10 4283.10 4628.10 4683.10 4828.10 4843.10 4968.10 50'1 10 1 2 3 4 5 6 7 8 ~ 6000 4500 500 West(-)/East(+) [1500ft/in] 3000 o -1500 6000 '¡;' :§ o o '" + ~ 4500 ~ ..c: :; o '" 3000 500 o . . BP-GDB BP Planning Report Plan: MPB-5O wp03 wp03 corrected asbuilt location Principal: Yes Date Composed: Version: Tied-to: 7/29/2004 18 From Well Ref. Point Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: M PI B Pad TR-13-11 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6021548.49 ft 571775.55 ft Latitude: 70 28 Longitude: 149 24 North Reference: Grid Convergence: 8.986 N 49.895 W True 0.55 deg Well: MPB-50 Plan Slot Name: Well Position: +N/-S 1437.07 ft Northing: 6022989.89 ft Latitude: +E/-W 470.13 ft Easting : 572231.76 ft Longitude: Position Uncertainty: 0.00 ft Casing Points 3283.63 2623.10 13.375 17.500 13 3/8" 9518.01 4273.10 9.625 12.250 95/8" 11886.00 5241.58 7.000 8.500 7" Formations 70 28 23.119 N 149 24 36.073 W 2039.87 6174.11 9555.79 10432.40 10562.72 10906.29 10941.83 11238.01 11486.80 1958.10 3388.10 4283.10 4628.10 4683.10 4828.10 4843.10 4968.10 5073.10 BPRF UG3 Top Confining Zone TUZC Top Injection Zone MA MB2 SBF2-NA SBF1-NB TSBD-Top OA SBA5 Base Injection Zone 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Targets MPB-50 Fault 1 3058.10 2275.87 985.46 6025275.00 573195.00 70 28 45.501 N 149 24 7.090 W -Polygon 1 3058.10 2275.87 985.46 6025275.00 573195.00 70 28 45.501 N 149 24 7.090 W -Polygon 2 3058.10 6693.36 1823.45 6029700.00 573990.00 70 29 28.944 N 149 23 42.413 W -Plan out by 592.54 at 3058.10 2868.32 995.92 6025867.47 573199.71 70 28 51.328 N 149 24 6.781 W MPB-5O T1 rev 4283.10 7046.20 2566.98 6030060.00 574730.00 70 29 32.412 N 149 23 20.530 W -Circle (Radius: 200) -Plan hit target MPB-50 T2 rev 5073.10 8695.45 3183.07 6031715.00 575330.00 70 29 48.630 N 149 23 2.378 W -Circle (Radius: 200) -Plan hit target . . BP-GDB BP Planning Report Plan Section Information 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 304.10 0.00 0.00 304.10 0.00 0.00 0.00 0.00 0.00 0.00 704.10 6.00 5.00 703.37 20.85 1.82 1.50 1.50 0.00 5.00 1404.16 20.00 6.00 1383.80 177.14 17.61 2.00 2.00 0.14 1.41 1859.47 27.50 19.00 1800.52 354.33 60.06 2.00 1.65 2.86 41.02 1919.87 27.50 19.00 1854.10 380.70 69.14 0.00 0.00 0.00 0.00 3099.04 74.65 20.61 2574.25 1218.13 375.38 4.00 4.00 0.14 2.12 9555.79 74.65 20.61 4283.10 7046.20 2566.98 0.00 0.00 0.00 0.00 MPB-50 T1 rev 9876.38 65.04 20.47 4393.43 7327.68 2672.46 3.00 -3.00 -0.04 -179.26 11486.80 65.04 20.47 5073.10 8695.45 3183.07 0.00 0.00 0.00 0.00 MPB-50 T2 rev 11686.80 65.04 20.47 5157.51 8865.31 3246.48 0.00 0.00 0.00 0.00 11886.80 65.04 20.47 5241.92 9035.18 3309.90 0.00 0.00 0.00 0.00 Survey 34.30 0.00 0.00 34.30 -23.80 0.00 0.00 0.00 6022989.89 572231.76 CB-GYRO-SS 100.00 0.00 0.00 100.00 41.90 0.00 0.00 0.00 6022989.89 572231.76 CB-GYRO-SS 200.00 0.00 0.00 200.00 141.90 0.00 0.00 0.00 6022989.89 572231.76 CB-GYRO-SS 300.00 0.00 0.00 300.00 241.90 0.00 0.00 0.00 6022989.89 572231.76 CB-GYRO-SS 304.10 0.00 0.00 304.10 246.00 0.00 0.00 0.00 6022989.89 572231.76 Start Dir 1.5/1 400.00 1.44 5.00 399.99 341.89 1.20 0.10 1.50 6022991.09 572231.85 CB-GYRO-SS 500.00 2.94 5.00 499.91 441.81 5.00 0.44 1.50 6022994.90 572232.15 CB-GYRO-SS 600.00 4.44 5.00 599.70 541.60 11.41 1.00 1.50 6023001.31 572232.65 CB-GYRO-SS 700.00 5.94 5.00 699.29 641.19 20.42 1.79 1.50 6023010.32 572233.35 CB-GYRO-SS 704.10 6.00 5.00 703.37 645.27 20.85 1.82 1.50 6023010.75 572233.38 Start Dir 2/100 800.00 7.92 5.34 798.56 740.46 32.42 2.88 2.00 6023022.33 572234.32 CB-GYRO-SS 900.00 9.92 5.56 897.34 839.24 47.85 4.35 2.00 6023037.77 572235.65 CB-GYRO-SS 1000.00 11.92 5.71 995.53 937.43 66.69 6.21 2.00 6023056.63 572237.32 CB-GYRO-SS 1100.00 13.92 5.81 1092.99 1034.89 88.93 8.46 2.00 6023078.89 572239.35 CB-GYRO-SS 1200.00 15.92 5.89 1189.62 1131.52 114.54 11.08 2.00 6023104.52 572241.73 CB-GYRO-SS 1300.00 17.92 5.95 1285.29 1227.19 143.48 14.08 2.00 6023133.49 572244.45 CB-GYRO-SS 1400.00 19.92 6.00 1379.88 1321.78 175.72 17.46 2.00 6023165.76 572247.51 CB-GYRO-SS 1404.16 20.00 6.00 1383.80 1325.70 177.14 17.61 2.00 6023167.17 572247.64 MWD+IFR+MS 1500.00 21.48 9.44 1473.42 1415.32 210.75 22.20 2.00 6023200.82 572251.91 MWD+IFR+MS 1600.00 23.09 12.56 1565.95 1507.85 247.95 29.46 2.00 6023238.10 572258.81 MWD+IFR+MS 1700.00 24.76 15.30 1657.36 1599.26 287.30 39.26 2.00 6023277.53 572268.22 MWD+IFR+MS 1800.00 26.47 17.70 1747.53 1689.43 328.73 51.56 2.00 6023319.07 572280.12 MWD+IFR+MS 1859.47 27.50 19.00 1800.52 1742.42 354.33 60.06 2.00 6023344.76 572288.37 End Dir : 1855 1900.00 27.50 19.00 1836.48 1778.38 372.03 66.15 0.00 6023362.51 572294.29 MWD+IFR+MS 1919.87 27.50 19.00 1854.10 1796.00 380.70 69.14 0.00 6023371.21 572297.19 Start Dir 4/100 2000.00 30.70 19.23 1924.11 1866.01 417.52 81.90 4.00 6023408.15 572309.60 MWD+IFR+MS 2039.87 32.30 19.33 1958.10 1900.00 437.18 88.78 4.00 6023427.87 572316.29 BPRF 2100.00 34.70 19.47 2008.24 1950.14 468.49 99.80 4.00 6023459.28 572327.00 MWD+IFR+MS 2200.00 38.70 19.66 2088.40 2030.30 524.79 119.81 4.00 6023515.77 572346.46 MWD+IFR+MS 2300.00 42.70 19.82 2164.20 2106.10 586.15 141.83 4.00 6023577 .33 572367.89 MWD+IFR+MS 2400.00 46.70 19.96 2235.27 2177.17 652.28 165.76 4.00 6023643.68 572391.17 MWD+IFR+MS 2500.00 50.70 20.08 2301.26 2243.16 722.85 191.47 4.00 6023714.49 572416.19 MWD+IFR+MS 2600.00 54.70 20.18 2361.85 2303.75 797.52 218.84 4.00 6023789.42 572442.83 MWD+IFR+MS 2700.00 58.69 20.28 2416.75 2358.65 875.92 247.74 4.00 6023868.09 572470.97 MWD+IFR+MS 2800.00 62.69 20.37 2465.69 2407.59 957.67 278.03 4.00 6023950.12 572500.46 MWD+IFR+MS 2900.00 66.69 20.46 2508.43 2450.33 1042.38 309.56 4.00 6024035.13 572531.16 MWD+IFR+MS 3000.00 70.69 20.53 2544.76 2486.66 1129.63 342.17 4.00 6024122.68 572562.92 MWD+IFR+MS 3099.03 74.65 20.61 2574.24 2516.14 1218.12 375.38 4.00 6024211.48 572595.27 End Dir : 3094 3100.00 74.65 20.61 2574.50 2516.40 1218.99 375.71 0.03 6024212.36 572595.59 MWD+IFR+MS . . BP-GDB BP Planning Report Survey 3200.00 74.65 20.61 2600.97 2542.87 1309.26 409.65 0.00 6024302.94 572628.65 MWD+IFR+MS 3283.63 74.65 20.61 2623.10 2565.00 13B4.74 438.04 0.00 6024378.69 572656.30 13 318" 3300.00 74.65 20.61 2627.43 2569.33 1399.52 443.60 0.00 6024393.52 572661.71 MWD+IFR+MS 3400.00 74.65 20.61 2653.90 2595.80 14B9.78 477.54 0.00 6024484.10 572694.77 MWD+IFR+MS 3500.00 74.65 20.61 2680.37 2622.27 1580.05 511.48 0.00 6024574.68 572727.84 MWD+IFR+MS 3600.00 74.65 20.61 2706.83 2648.73 16i'0.31 545.42 0.00 6024665.26 572760.90 MWD+IFR+MS 3700.00 74.65 20.61 2733.30 2675.20 17fiO.57 579.37 0.00 6024755.84 572793.96 MWD+IFR+MS 3800.00 74.65 20.61 2759.76 2701.66 18EiO.84 613.31 0.00 6024846.42 572827.02 MWD+IFR+MS 3900.00 74.65 20.61 2786.23 2728.13 1941.10 647.25 0.00 6024937.00 572860.08 MWD+IFR+MS 4000.00 74.65 20.61 2812.70 2754.60 203,1.36 681.19 0.00 6025027.58 572893.15 MWD+IFR+MS 4100.00 74.65 20.61 2839.16 2781.06 212'1.63 715.14 0.00 6025118.16 572926.21 MWD+IFR+MS 4200.00 74.65 20.61 2865.63 2807.53 2211.89 749.08 0.00 6025208.74 572959.27 MWD+IFR+MS 4300.00 74.65 20.61 2892.09 2833.99 2302.15 783.02 0.00 6025299.32 572992.33 MWD+IFR+MS 4400.00 74.65 20.61 2918.56 2860.46 2392.42 816.97 0.00 6025389.90 573025.39 MWD+IFR+MS 4500.00 74.65 20.61 2945.03 2886.93 2482.68 850.91 0.00 6025480.48 573058.46 MWD+IFR+MS 4600.00 74.65 20.61 2971.49 2913.39 2572.94 884.85 0.00 6025571.06 573091.52 MWD+IFR+MS 4700.00 74.65 20.61 2997.96 2939.86 2663.20 918.79 0.00 6025661.63 573124.58 MWD+IFR+MS 4800.00 74.65 20.61 3024.43 2966.33 2753.47 952.74 0.00 6025752.21 573157.64 MWD+IFR+MS 4900.00 74.65 20.61 3050.89 2992.79 284:3.73 986.68 0.00 6025842.79 573190.70 MWD+IFR+MS 4927.24 74.65 20.61 3058.10 3000.00 286a.32 995.92 0.00 6025867.47 573199.71 MPB-SO Fault 1 5000.00 74.65 20.61 3077.36 3019.26 293:3.99 1020.62 0.00 6025933.37 573223.77 MWD+IFR+MS 5100.00 74.65 20.61 3103.82 3045.72 3024.26 1054.56 0.00 6026023.95 573256.83 MWD+IFR+MS 5200.00 74.65 20.61 3130.29 3072.19 3114.52 1088.51 0.00 6026114.53 573289.89 MWD+IFR+MS 5300.00 74.65 20.61 3156.76 3098.66 3204.78 1122.45 0.00 6026205.11 573322.95 MWD+IFR+MS 5400.00 74.65 20.61 3183.22 3125.12 3295.05 1156.39 0.00 6026295.69 573356.01 MWD+IFR+MS 5500.00 74.65 20.61 3209.69 3151.59 338!¡.31 1190.33 0.00 6026386.27 573389.08 MWO+IFR+MS 5600.00 74.65 20.61 3236.15 3178.05 :347Ei.57 1224.28 0.00 6026476.85 573422.14 MWD+IFR+MS 5700.00 74.65 20.61 3262.62 3204.52 356~i.84 1258.22 0.00 6026567.43 573455.20 MWD+IFR+MS 5800.00 74.65 20.61 3289.09 3230.99 :365fi.10 1292.16 0.00 6026658.01 573488.26 MWD+IFR+MS 5900.00 74.65 20.61 3315.55 3257.45 374Ei.36 1326.11 0.00 6026748.59 573521.32 MWD+IFR+MS 6000.00 74.65 20.61 3342.02 3283.92 3836,.63 1360.05 0.00 6026839.17 573554.39 MWD+IFR+MS 6100.00 74.65 20.61 3368.49 3310.39 :1926.89 1393.99 0.00 6026929.75 573587.45 MWD+IFR+MS 6174.11 74.65 20.61 3388.10 3330.00 :1993.79 1419.15 0.00 6026996.88 573611.95 UG3 Top Con' 6200.00 74.65 20.61 3394.95 3336.85 4017.15 1427.93 0.00 6027020.33 573620.51 MWD+IFR+MS 6300.00 74.65 20.61 3421.42 3363.32 4107.42 1461.88 0.00 6027110.91 573653.57 MWD+IFR+MS 6400.00 74.65 20.61 3447.88 3389.78 4197.68 1495.82 0.00 6027201.49 573686.63 MWD+IFR+MS 6500.00 74.65 20.61 3474.35 3416.25 4287.94 1529.76 0.00 6027292.07 573719.70 MWD+IFR+MS 6600.00 74.65 20.61 3500.82 3442.72 4378.20 1563.70 0.00 6027382.65 573752.76 MWD+IFR+MS 6700.00 74.65 20.61 3527.28 3469.18 4468..47 1597.65 0.00 6027473.23 573785.82 MWD+IFR+MS 6800.00 74.65 20.61 3553.75 3495.65 4558..73 1631.59 0.00 6027563.81 573818.88 MWD+IFR+MS 6900.00 74.65 20.61 3580.21 3522.11 4648.99 1665.53 0.00 6027654.39 573851.94 MWD+IFR+MS 7000.00 74.65 20.61 3606.68 3548.58 4739.26 1699.48 0.00 6027744.97 573885.01 MWD+/FR+MS 7100.00 74.65 20.61 3633.15 3575.05 4829.52 1733.42 0.00 6027835.55 573918.07 MWD+IFR+MS 7200.00 74.65 20.61 3659.61 3601.51 4919.78 1767.36 0.00 6027926.13 573951.13 MWD+IFR+MS 7300.00 74.65 20.61 3686.08 3627.98 5010.05 1801.30 0.00 6028016.71 573984.19 MWD+IFR+MS 7400.00 74.65 20.61 3712.55 3654.45 5100.31 1835.25 0.00 6028107.29 574017.25 MWD+IFR+MS 7500.00 74.65 20.61 3739.01 3680.91 5190.57 1869.19 0.00 6028197.87 574050.32 MWD+IFR+MS 7600.00 74.65 20.61 3765.48 3707.38 5:280.a4 1903.13 0.00 6028288.45 574083.38 MWD+IFR+MS 7700.00 74.65 20.61 3791.94 3733.84 5:371.10 1937.07 0.00 6028379.03 574116.44 MWD+IFR+MS 7800.00 74.65 20.61 3818.41 3760.31 5461.:36 1971.02 0.00 6028469.61 574149.50 MWD+/FR+MS 7900.00 74.65 20.61 3844.88 3786.78 51551.153 2004.96 0.00 6028560.19 574182.56 MWD+IFR+MS 8000.00 74.65 20.61 3871.34 3813.24 5Eì41.139 2038.90 0.00 6028650.77 574215.63 MWD+IFR+MS . . B:P-GDB BP ]>]anning Report Survey 8100.00 74.65 20.61 3897.81 3839.71 57:32.15 2072.84 0.00 6028741.35 574248.69 MWD+IFR+MS 8200.00 74.65 20.61 3924.27 3866.17 58:22.42 2106.79 0.00 6028831.93 574281.75 MWD+IFR+MS 8300.00 74.65 20.61 3950.74 3892.64 59'12.68 2140.73 0.00 6028922.51 574314.81 MWD+IFR+MS 8400.00 74.65 20.61 3977.21 3919.11 6002.94 2174.67 0.00 6029013.09 574347.87 MWD+IFR+MS 8500.00 74.65 20.61 4003.67 3945.57 6093.20 2208.62 0.00 6029103.67 574380.94 MWD+IFR+MS 8600.00 74.65 20.61 4030.14 3972.04 6183.47 2242.56 0.00 6029194.25 574414.00 MWD+IFR+MS 8700.00 74.65 20.61 4056.61 3998.51 62i73.73 2276.50 0.00 6029284.83 574447.06 MWD+IFR+MS 8800.00 74.65 20.61 4083.07 4024.97 631>3.99 2310.44 0.00 6029375.41 574480.12 MWD+IFR+MS 8900.00 74.65 20.61 4109.54 4051.44 641>4.26 2344.39 0.00 6029465.99 574513.18 MWD+IFR+MS 9000.00 74.65 20.61 4136.00 4077.90 6544.52 2378.33 0.00 6029556.57 574546.25 MWD+IFR+MS 9100.00 74.65 20.61 4162.47 4104.37 66:14.78 2412.27 0.00 6029647.15 574579.31 MWD+IFR+MS 9200.00 74.65 20.61 4188.94 4130.84 6125.05 2446.21 0.00 6029737.73 574612.37 MWD+IFR+MS 9300.00 74.65 20.61 4215.40 4157.30 68115.31 2480.16 0.00 6029828.31 574645.43 MWD+IFR+MS 9400.00 74.65 20.61 4241.87 4183.77 6905.57 2514.10 0.00 6029918.89 574678.49 MWD+IFR+MS 9500.00 74.65 20.61 4268.33 4210.23 69H5.84 2548.04 0.00 6030009.46 574711.55 MWD+IFR+MS 9518.01 74.65 20.61 4273.10 4215.00 7012.09 2554.15 0.00 6030025.78 574717.51 95/8" 9555.72 74.65 20.61 4283.08 4224.98 7046.13 2566.96 0.00 6030059.94 574729.98 Start Dir 3/100 9555.79 74.65 20.61 4283.10 4225.00 7046.20 2566.98 0.00 6030060.00 574730.00 MPB-50 T1 rev 9600.00 73.33 20.59 4295.29 4237.19 7085.97 2581.93 3.00 6030099.92 574744.56 MWD+IFR+MS 9700.00 70.33 20.55 4326.48 4268.38 717'4.92 2615.31 3.00 6030189.17 574777.07 MWD+IFR+MS 9800.00 67.33 20.51 4362.59 4304.49 726i2.23 2648.00 3.00 6030276.80 574808.92 MWD+IFR+MS 9876.30 65.04 20.47 4393.40 4335.30 7327.62 2672.43 3.00 6030342.41 574832.71 End Dir : 9872 9876.38 65.04 20.47 4393.43 4335.33 7327.68 2672.46 3.00 6030342.47 574832.73 MWD+IFR+MS 9900.00 65.04 20.47 4403.40 4345.30 7347.75 2679.95 0.00 6030362.60 574840.03 MWD+IFR+MS 10000.00 65.04 20.47 4445.61 4387.51 7432.68 2711.66 0.00 6030447.83 574870.91 MWD+IFR+MS 10100.00 65.04 20.47 4487.81 4429.71 7517.61 2743.36 0.00 6030533.06 574901.78 MWD+IFR+MS 10200.00 65.04 20.47 4530.02 4471.92 7602.54 2775.07 0.00 6030618.29 574932.66 MWD+IFR+MS 10300.00 65.04 20.47 4572.22 4514.12 7687.47 2806.78 0.00 6030703.52 574963.54 MWD+IFR+MS 10400.00 65.04 20.47 4614.42 4556.32 7772.41 2838.48 0.00 6030788.74 574994.42 MWD+IFR+MS 10432.40 65.04 20.47 4628.10 4570.00 7799.93 2848.76 0.00 6030816.36 575004.42 MA 10500.00 65.04 20.47 4656.63 4598.53 7857.34 2870.19 0.00 6030873.97 575025.30 MWD+IFR+MS 10562.72 65.04 20.47 4683.10 4625.00 7910.61 2890.08 0.00 6030927.43 575044.66 MB2 10600.00 65.04 20.47 4698.83 4640.73 7942.27 2901.90 0.00 6030959.20 575056.17 MWD+IFR+MS 10700.00 65.04 20.47 4741.04 4682.94 8027.20 2933.60 0.00 6031044.43 575087.05 MWD+IFR+MS 10800.00 65.04 20.47 4783.24 4725.14 8112.14 2965.31 0.00 6031129.66 575117.93 MWD+IFR+MS 10900.00 65.04 20.47 4825.45 4767.35 8197.07 2997.02 0.00 6031214.88 575148.81 MWD+IFR+MS 10906.29 65.04 20.47 4828.10 4770.00 820:2.41 2999.01 0.00 6031220.24 575150.75 SBF2-NA 10941,83 65.04 20.47 4843.10 4785.00 823:2.60 3010.28 0.00 6031250.54 575161.72 SBF1-NB 11000.00 65.04 20.47 4867.65 4809.55 828:2.00 3028.72 0.00 6031300.11 575179.69 MWD+IFR+MS 11100.00 65.04 20.47 4909.85 4851.75 8366.93 3060.43 0.00 6031385.34 575210.56 MWD+IFR+MS 11200.00 65.04 20.47 4952.06 4893.96 8451.86 3092.14 0.00 6031470.57 575241.44 MWD+IFR+MS 11238.01 65.04 20.47 4968.10 4910.00 8484.15 3104.19 0.00 6031502.96 575253.18 TSBD-Top OA 11300.00 65.04 20.47 4994.26 4936.16 85315.80 3123.84 0,00 6031555.80 575272.32 MWD+IFR+MS 11400.00 65.04 20.47 5036.47 4978.37 862'1.73 3155.55 0.00 6031641.02 575303.20 MWD+IFR+MS 11486.80 65.04 20.47 5073.10 5015.00 86915.45 3183.07 0.00 6031715.00 575330.00 MPB-50 T2 rev 11500.00 65.04 20.47 5078.67 5020.57 87015.66 3187.26 0,00 6031726.25 575334.08 MWD+IFR+MS 11600.00 65.04 20.47 5120.88 5062.78 879'1.59 3218.96 0.00 6031811.48 575364.95 MWD+IFR+MS 11686.80 65.04 20.47 5157.51 5099.41 88615.31 3246.48 0.00 6031885.46 575391.76 MWD+IFR+MS 11700.00 65.04 20.47 5163.08 5104.98 8871>.53 3250.67 0.00 6031896.71 575395.83 MWD+IFR+MS 11800.00 65.04 20.47 5205.28 5147.18 896 '1.46 3282.38 0.00 6031981.94 575426.71 MWD+IFR+MS 11886.00 65.04 20.47 5241.58 5183.48 H034.50 3309.64 0.00 6032055.23 575453.27 7" 11886.80 65.04 20.47 5241.92 5183.82 !9031i.18 3309.90 0.00 6032055.91 575453.51 MWD+IFR+MS Name +N/..s MPB-50 Plan 1437.07 -80 -75 -63 -so -38 -25 -13 -0 -13 -25 -38 -so -63 -75 -80 +E/·W 470.13 30 I, 270; ; ~ \ [\:~,\~ \; \\\~J ' \)(\ \ \ M ~~\\ 240~ WELL DETAILS ANTI-COLLISION SETI1NGS COMPANY DETAILS Northing 6022989.89 Easting 572231.76 Latitude Longitude Slot 70°28'23.1 t9N 149°24'36.073W N/A ÐP Amoco Interpolation Method:MD Interval: 25.00 Depth Range From: 34.30 To: 11886.80 Maximum Range: 1385.25 Reference: Plan: MPB-50 wp03 CaJculation Method: Minimum Curvature &ror System: ISCWSA Scan Metbod: Trav Cylinder North Error Surface: EllipticaJ+Casiog Warning Method: Rules Basoo o ~'i RO Fr~~ , ~ 33 0 1000 :::"... 1500 ødf!f¡;j;;·::;::::::~~..· "l~~>~S~%"-..~ 250~ /Y~"'<"">:.«:-:::. t...- .....:,.,.;: ~~~~~~~1;'·<~<'::: :::0 ø\/; ¿:ff:)}i?"'::~~~~~~~~:-- 1~0 /:~/ :~:\ý¿¿:~:/~~::j;U:~\'''i...¥:.>..\.,y.~'??~~>: i~i , ~~ 600~ (>~.. ;\;/>~ 0":/~J§''';:~.~ ;'hi,' S~~~~i ~<':~~ I~~~~ / i />: :.t:;; :',:--->,....... ....... ..... ~ ~~~~ ~<\' 12000 ¡ i/ì :;~ ..~.. ~%~'ii. »" .....~~ "~::$ ~t\ w,~:,~ !//il // >: ?;;::;::::::>:::i:> ,','\. <\ i\ 0 '/I 'i )>s»).~;:::;:;;.. ..>.... >' Ii'}:'; ~:<' i \ , " 0 .~ /; />;: '%:;:; ,::::::::~>:~ \ \ 'Xi \ \~~W\ 0 i,~;~¡;:; "/\< ,>.-/~,=3:~~ .\\ :<\, \\\\\\~~\\\ 0 !;~ >;;;/~',":;::;:..,\'<::::::::::>Ý~ \ \ :\\\.\', \'\\\\\\\ \ \ / , l~;i?/ :;I;~:" ;/::j/ !/' (~~/ß;"~Jf:p;~!'·:.~~:,~~~~i~~~ ....\ .~~I\ \\\ \ \. \' \ \ \ \ \ \ : " \ Ii i,I'" ." IJtI {~~ / ....',' \ .\\\. \' / ., 1/,1 l! I¡ i/;"i,/ ,//'1':":"::":'1\ i, ! :! ;'::'\\i;" i(, :':f(\((\..·:X')) I} :!0"\ '\¡,." !~ ,\ .;', j ',\ '. I, \, '\ '. \ \. \'11>;;;> i!; ; . '/'1 j \ ,\\:\.\ \\\\ ,\~~~:\<\\:I\;:;';;;; //11;/// li!/ II!;'!/ 'i \\.\ ,\ ,,~> i::...:::::'·>::; >;:>; :/! ì~ /i//. : 7~1// 1/; \\ \ \ ~~,~::j:".\ I ~ ' / / / 1t!,;1,1 / / /ij>?¡j,~ /// 1\ ,.;:,' ~~ ~< ¿~~:::¿ ïF ///ì!/ liI/'lliiil i ~ ~\~~~,\/ N '/¡/> / / I ì\;' ~~ ~\\i ; '0 /;;!~'/ . .' ;~ ~'S ~ ~ ;;:..;a :~~ ~.;<~; ,~ ;~~ ~ ",~~ " >;; ;;ç¿;;;:,. î ~ -;,;; 'ø:..~: ~ ?¿ ;;;;;:: /;;>:;~~~ 3/ ,;::;: ø ?:;;;: 50 j/~~20 o ~~ ..... ~iL' 21 s~ MD SURVEY PROGRAM Depth Fm Depth To SurveylPlan 34.30 1404.10 Planned: MPB-50wp03 VI8 1404.10 11886.80 Planned: MPB-50 wp03 VI8 Colour ToMD 500 1000 1500 2000 2500 3000 4000 5000 6000 8000 10000 12000 14000 165000 o o o o o o Rig: Ref. Datwn: Tool CB-GYRO-SS MWD+IFR+MS WELLPATHDETAlLS MPB-50 V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 20.12° 0.00 0.00 34.30 34.3 + 23.8 58.10ft LEGEND - Beren (Plan 8eren), Major Risk - MPB-01 (MP8..Qt), Major Risk = ~~~~B~J>:~gERRORS --== MPB-03 (MP8-03 Minor 11200 ~ ),MajorRisk - MPB-04 . - MPB-05 00 - ~:~ ~=: Major:= - MPB-I3(MPB-13),MajorRisk - MP8-14 (MP8-14), Major Risk = ~:=~~~:=~~:~j:~ = ~::ii in: ~:~ - MPB-22 22), Major Risk - MPB-24 24), Major Risk - MP8-25 25), Major Risk (MPB-26 LI Contingency), Major Risk - ~~~~~~(~~~6_Ll),MajorRisk - t'1aD MYli-ló (IIrU'li-Zô), MajOr Risk - Plan MP8-27 (MPB-27), Major Risk - MPB-50 "'-' MPB-50 wpU] SECTION DETAILS 1 34.30 0.00 0.00 34.30 0.00 0.00 2 304.10 0.00 0.00 304.10 0.00 0.00 3 704. to 6.00 5.00 703.37 20.85 1.82 4 1404.16 20.00 6.00 1383.80 177.14 ]7.61 5 1859.47 27.50 19.00 1800.52 354.33 60.06 6 1919.87 27.50 19.00 1854.10 380.70 69.14 7 3099.04 74.65 20.61 2574.25 1218.13 375.38 8 9555.79 74.65 20.61 4283.10 7046.20 2566.98 9 9876.38 65.04 20.47 4393.43 7327.68 2672.46 10 11486.80 65.04 20.47 5073.10 8695.45 3183.07 11 11686.80 65.04 20.47 5157.51 8865.31 3246.48 12 11886.80 65.04 20.47 5241.92 9035.18 3309.90 18 "",$ ......, 90 "" An TVD +N/-S +EI-W DLeg TFace VSec Target 0.00 0.00 0.00 0.00 1.50 5.00 2.00 1.41 2.00 41.02 0.00 0.00 4.00 2.12 0.00 0.00 3.00 -179.26 0.00 0.00 0.00 0.00 0.00 0.00 . e 0.00 0.00 20.20 17238 353.37 381.25 127292 7499.20 MPB-SO T1 rev 7799.80 9259.74 MPB-50 T2 rev 9441.05 962236 . . BP-GDB Anticollision Report GLOBAL SCAN APPLIED: AIl weDpaths within 200'+ 100/1000 of reference Interpolation Method: MD' Interval: 25.00 ft Depth Range: 34.30 to 11886.80 ft Maximum Radius: 1385.25 ft Reference: Error Model: Scan Method: Error Surface: Plan: MPB-50 wp03 & NOT PLANNED PROGRA ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points 3283.63 9518.01 11886.00 2623.10 4273.10 5241.58 13.375 9.625 7.000 17.500 12.250 8.500 13 3/8" 95/8" 7" Plan: MPB-50 wp03 wp03 corrected asbuilt location Principal: Yes Date Composed: Version: Tied-to: 7/29/2004 18 From Well Ref. Point Summary MPlBPad Beren Plan Beren V2 Plan: Un 1092.07 1100.00 201.51 23.83 177.68 Pass: Major Risk MPlBPad MPB-01 MPB-01 V1 422.04 425.00 193.57 9.78 183.79 Pass: Major Risk MPlBPad MPB-02 MPB-02 V4 1255.06 1250.00 248.03 29.09 218.94 Pass: Major Risk MPlBPad MPB-02 Plan MPB-02A VO Plan: 1503.42 1525.00 88.41 0.00 88.41 Pass: NOERRORS MPlBPad MPB-03 MPB-03 V1 1080.94 1075.00 27.25 No Offset Casings M PI B Pad MPB-04A MPB-04A V1 424.18 425.00 26.18 9.77 16.41 Pass: Major Risk MPlBPad MPB-04 MPB-04 V1 399.27 400.00 31.18 10.11 21.07 Pass: Major Risk MPlBPad MPB-05A MPB-05A V1 1342.00 1325.00 44.63 No Offset Casings M PI B Pad MPB-05 MPB-05 V1 1342.00 1325.00 44.63 No Offset Casings MPlBPad MPB-06 MPB-06 V1 1243.13 1225.00 336.65 31.16 305.49 Pass: Major Risk MPlBPad MPB-13 MPB-13 V3 2003.33 2000.00 116.17 58.67 57.50 Pass: Major Risk MPlBPad MPB-14 MPB-14 V1 2410.83 2250.00 380.01 48.85 331.16 Pass: Major Risk MPlBPad MPB-15 MPB-15 V1 1604.57 1600.00 104.39 49.49 54.90 Pass: Major Risk MPlBPad MPB-16 MPB-16 V1 2107.84 2025.00 238.62 41.23 197.39 Pass: Major Risk M PI B Pad MPB-17 MPB-17 V1 699.64 700.00 215.43 15.00 200.42 Pass: Major Risk MPlBPad MPB-21 MPB-21 V1 2264.70 2325.00 413.28 77.48 335.80 Pass: Major Risk MPlBPad MPB-22 MPB-22 V1 1333.15 1325.00 179.47 37.55 141.92 Pass: Major Risk MPlBPad MPB-24 MPB-24 V1 3455.92 2950.00 184.56 89.74 94.82 Pass: Major Risk MPlBPad MPB-25 MPB-25 V1 349.71 350.00 212.11 7.15 204.96 Pass: Major Risk MPlBPad MPB-Disposal#1 Plan MPB-Disposal#1 V3 10865.78 9826.85 487.02 0.00 487.02 Pass: NOERRORS MPlBPad MPB-Disposal#2 MPB-Disposal#2 V3 Plan 3850.75 3300.00 141.37 0.00 141.37 Pass: NOERRORS MPlBPad MPB-Disposal#3 Plan MPB-Disposal#3 V5 300.00 300.00 60.46 0.00 60.46 Pass: NOERRORS MPlBPad Plan MPB-26 MPB-26 L 1 Contingency 1087.46 1100.00 195.72 23.73 171.99 Pass: Major Risk MPlBPad Plan MPB-26 MPB-26 L1 VO Plan: MPB 1087.46 1100.00 195.72 23.73 171.99 Pass: Major Risk MPlBPad Plan MPB-26 MPB-26 V3 Plan: MPB-26 1087.46 1100.00 195.72 23.99 171.74 Pass: Major Risk MPlBPad Plan MPB-27 MPB-27 V9 Plan: MPB-27 1476.83 1500.00 85.60 31.09 54.51 Pass: Major Risk MPlBPad Plan MPB-Disposal v\@lan MPB-Disposal Well 837.36 850.00 179.27 0.00 179.27 Pass: NOERRORS Site: MPlBPad Well: 8eren Rule Assigned: Major Risk WeDpath: Plan Beren V2 Plan: Undefined Inter-Site Error: 0.00 ft 50.00 50.00 50.00 50.00 0.04 0.06 285.48 285.48 12.250 224.45 1.69 222.77 Pass 75.00 75.00 75.00 75.00 0.09 0.12 285.48 285.48 12.250 224.45 2.28 222.17 Pass 100.00 100.00 100.00 100.00 0.15 0.18 285.48 285.48 12.250 224.45 2.88 221.58 Pass 125.00 125.00 125.00 125.00 0.24 0.26 285.48 285.48 12.250 224.45 3.64 220.82 Pass 150.00 150.00 150.00 150.00 0.32 0.34 285.48 285.48 12.250 224.45 4.40 220.06 Pass 175.00 175.00 175.00 175.00 0.41 0.43 285.48 285.48 12.250 224.45 5.16 219.29 Pass 200.00 200.00 200.00 200.00 0.50 0.51 285.48 285.48 12.250 224.45 5.92 218.54 Pass 225.00 225.00 225.00 225.00 0.55 0.56 285.48 285.48 12.250 224.45 6.50 217.96 Pass 250.00 250.00 250.00 250.00 0.61 0.62 285.48 285.48 12.250 224.45 7.08 217.37 Pass 275.00 275.00 275.00 275.00 0.67 0.67 285.48 285.48 12.250 224.45 7.66 216.79 Pass . . BP-GDB Anticollision Report Site: M PI B Pad Well: Beren Wellpath: Plan Beren V2 Plan: Undefined Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 300.00 300.00 300.00 300.00 0.72 0.73 285.48 285.48 12.250 224.45 8.24 216.21 Pass 325.23 325.23 325.00 325.00 0.77 0.77 285.48 280.48 12.250 224.42 8.77 215.65 Pass 350.50 350.49 350.00 350.00 0.82 0.81 285.46 280.46 12.250 224.31 9.29 215.02 Pass 375.76 375.76 375.00 375.00 0.86 0.85 285.43 280.43 12.250 224.12 9.81 214.32 Pass 401.03 401.02 400.00 399.99 0.91 0.89 285.38 280.38 12.250 223.86 10.32 213.54 Pass 426.29 426.27 425.00 424.99 0.95 0.90 .285.29 280.29 12.250 223.52 10.74 212.78 Pass 451.54 451.50 450.00 449.99 1.00 0.91 :285.13 280.13 12.250 223.09 11.16 211.94 Pass 476.78 476.72 475.00 474.99 1.05 0.92 :284.91 279.91 12.250 222.58 11.57 211.01 Pass 501.99 501.90 500.00 499.98 1.09 0.93 :284.61 279.61 12.250 221.99 11.99 210.01 Pass 527.18 527.06 525.00 524.98 1.13 0.94 :284.25 279.25 12.250 221.33 12.37 208.96 Pass 552.35 552.18 550.00 549.97 1.18 0.94 :283.85 278.85 12.250 220.63 12.76 207.87 Pass 577.50 577.27 575.00 574.97 1.22 0.94 :283.41 278.41 12.250 219.88 13.16 206.71 Pass 602.61 602.31 600.00 599.96 1.27 0.95 :282.90 277.90 12.250 218.93 13.57 205.36 Pass 627.68 627.29 625.00 624.94 1.32 0.96 :282.32 277.32 12.250 217.78 13.99 203.79 Pass 652.70 652.21 650.00 649.92 1.36 0.98 :281.68 276.68 12.250 216.43 14.42 202.00 Pass 677.67 677.07 675.00 674.89 1.41 0.99 280.98 275.98 12.250 214.91 14.86 200.05 Pass 702.60 701.87 700.00 699.85 1.46 1.01 280.22 275.22 12.250 213.40 15.29 198.10 Pass 727.48 726.61 725.00 724.82 1.51 1.04 :279.40 274.30 12.250 211.91 15.79 196.12 Pass 752.30 751.26 750.00 749.78 1.56 1.08 :278.52 273.32 12.250 210.46 16.28 194.18 Pass 777.06 775.83 775.00 774.75 1.61 1.11 :277.56 272.28 12.250 209.05 16.77 192.29 Pass 801.77 800.31 800.00 799.71 1.66 1.14 :276.53 271.18 12.250 207.71 17.26 190.45 Pass 826.40 824.69 825.00 824.68 1.72 1.18 :275.43 270.02 12.250 206.43 17.78 188.66 Pass 850.96 848.97 850.00 849.65 1.78 1.21 :274.26 268.79 12.250 205.24 18.29 186.95 Pass 875.46 873.15 875.00 874.61 1.83 1.25 :273.01 267.49 12.250 204.15 18.81 185.34 Pass 899.87 897.22 900.00 899.58 1.89 1.28 :271.69 266.13 12.250 203.18 19.33 183.85 Pass 924.21 921.17 925.00 924.54 1.96 1.32 :270.30 264.70 12.250 202.34 19.88 182.45 Pass 948.46 945.01 950.00 949.51 2.03 1.35 268.85 263.21 12.250 201.64 20.43 181.21 Pass 972.62 968.72 975.00 974.47 2.10 1.39 ~~67 .32 261.65 12.250 201.11 20.98 180.13 Pass 996.70 992.30 1000.00 999.44 2.17 1.42 ~~65.73 260.03 12.250 200.75 21.52 179.23 Pass 1020.69 1015.76 1025.00 1024.41 2.26 1.46 ~~64.08 258.35 12.250 200.60 22.11 178.50 Pass 1044.58 1039.08 1050.00 1049.37 2.34 1.50 262.37 256.62 12.250 200.66 22.69 177.98 Pass 1068.37 1062.26 1075.00 1074.34 2.42 1.53 ~!60.61 254.83 12.250 200.96 23.26 177.70 Pass 1092.07 1085.29 1100.00 1099.30 2.51 1.57 .!58.81 253.00 12.250 201.51 23.83 177.68 Pass 1115.66 1108.19 1125.00 1124.27 2.60 1.58 .!56.95 251.13 12.250 202.32 24.36 177. 96 Pass 1139.15 1130.93 1150.00 1149.23 2.70 1.60 .'55.07 249.23 12.250 203.41 24.89 178.52 Pass 1162.53 1153.52 1175.00 1174.20 2.80 1.61 253.16 247.30 12.250 204.80 25.41 179.38 Pass 1185.74 1175.89 1199.93 1199.10 2.90 1.62 :;~51.23 245.35 12.250 206.49 25.92 180.57 Pass 1208.93 1198.20 1225.00 1224.13 3.01 1.62 :;~49.25 243.36 12.250 208.59 26.40 182.20 Pass 1231.89 1220.23 1250.00 1249.10 3.13 1.63 :;~47.25 241.34 12.250 211.19 26.88 184.31 Pass 1254.66 1242.04 1275.00 1274.06 3.25 1.63 2~45.22 239.29 12.250 214.31 27.34 186.97 Pass 1277.26 1263.62 1300.00 1299.01 3.36 1.63 2~43.17 237.24 12.250 217.97 27.79 190.18 Pass 1299.65 1284.96 1325.00 1323.96 3.48 1.63 2:41.13 235.19 12.250 222.18 28.21 193.96 Pass 1321.85 1306.05 1350.00 1348.90 3.54 1.63 239.11 233.15 12.250 226.94 28.49 198.45 Pass 1343.90 1326.95 1375.00 1373.84 3.60 1.64 237.14 231.17 12.250 232.12 28.75 203.37 Pass 1365.80 1347.66 1400.00 1398.78 3.66 1.64 235.22 229.24 12.250 237.68 29.00 208.68 Pass 1387.57 1368.19 1425.00 1423.72 3.72 1.64 233.36 227.37 12.250 243.62 29.25 214.37 Pass 1409.08 1388.41 1450.00 1448.66 3.77 1.64 231.57 225.38 12.250 249.93 29.46 220.47 Pass 1430.08 1408.12 1475.00 1473.60 3.77 1.65 229.90 222.93 12.250 256.62 29.56 227.06 Pass 1450.99 1427.70 1500.00 1498.54 3.77 1.65 228.32 220.59 12.250 263.70 29.67 234.04 Pass 1471.81 1447.15 1525.00 1523.48 3.77 1.66 226.83 218.36 12.250 271.15 29.78 241.37 Pass . . BP-GDB Anticollision Report Site: M pt B Pad Well: Beren Wellpatb: Plan Beren V2 Plan: Undefined Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 1492.52 1466.46 1550.00 1548.42 3.78 1.66 :225.42 216.24 12.250 278.95 29.90 249.05 Pass 1513.13 1485.63 1575.00 1573.36 3.78 1.67 :224.09 214.22 12.250 287.08 30.03 257.06 Pass 1533.63 1504.66 1600.00 1598.30 3.78 1.67 :222.85 212.31 12.250 295.53 30.15 265.38 Pass 1554.03 1523.55 1625.00 1623.23 3.79 1.68 :221.67 210.49 12.250 304.29 30.29 274.00 Pass 1574.33 1542.30 1650.00 1648.17 3.79 1.69 :220.57 208.77 12.250 313.33 30.43 282.90 Pass 1594.52 1560.91 1675.00 1673.11 3.80 1.69 :219.54 207.13 12.250 322.65 30.57 292.08 Pass 1614.60 1579.37 1700.00 1698.05 3.81 1.70 :218.57 205.58 12.250 332.23 30.72 301.51 Pass 1634.57 1597.68 1725.00 1722.99 3.81 1.71 :~17.66 204.11 12.250 342.07 30.88 311.19 Pass 1654.43 1615.85 1750.00 1747.93 3.82 1.72 :~16.82 202.72 12.250 352.14 31.04 321.11 Pass 1674.18 1633.87 1775.00 1772.87 3.83 1.73 :~16.02 201.40 12.250 362.45 31.20 331.25 Pass 1693.82 1651.74 1800.00 1797.81 3.84 1.74 :115.28 200.14 12.250 372.98 31.36 341.62 Pass 1713.34 1669.46 1825.00 1822.75 3.85 1.75 :114.59 198.95 12.250 383.72 31.53 352.19 Pass 1732.75 1687.03 1850.00 1847.69 3.86 1.76 :113.94 197.82 12.250 394.67 31.71 362.97 Pass 1752.05 1704.45 1875.00 1872.63 3.87 1.77 :113.33 196.74 12.250 405.82 31.88 373.94 Pass 1771.23 1721.72 1900.00 1897.56 3.88 1.78 ~112.77 195.72 12.250 417.16 32.06 385.10 Pass 1790.28 1738.82 1925.00 1922.49 3.89 1.79 ~~12.21 194.73 12.250 428.64 32.23 396.41 Pass 1809.18 1755.75 1950.00 1947.40 3.91 1.81 ~~11.64 193.73 12.250 440.22 32.40 407.82 Pass 1827.93 1772.48 1975.00 1972.26 3.92 1.82 ~!11.05 192.73 12.250 451.90 32.57 419.33 Pass 1846.53 1789.04 2000.00 1997.09 3.93 1.83 :;!10.44 191.72 12.250 463.67 32.74 430.93 Pass 1865.84 1806.18 2025.00 2021.86 3.95 1.84 :;!09.81 190.81 12.250 475.54 32.91 442.63 Pass 1887.12 1825.06 2050.00 2046.61 3.97 1.85 2'09.16 190.16 12.250 487.47 33.14 454.33 Pass 1908.40 1843.93 2075.00 2071.36 3.99 1.87 2~08.54 189.54 12.250 499.46 33.37 466.09 Pass 1927.12 1860.52 2100.00 2096.12 4.00 1.88 2~07.96 188.94 12.250 511.53 33.55 477.97 Pass 1942.68 1874.25 2125.00 2120.87 4.02 1.90 2~07 .40 188.33 12.250 523.85 33.69 490.16 Pass 1958.03 1887.72 2150.00 2145.62 4.03 1.92 2~06.86 187.75 12.250 536.44 33.83 502.61 Pass 1973.19 1900.93 2175.00 2170.37 4.05 1.93 206.35 187.19 12.250 549.30 33.96 515.34 Pass 1988.14 1913.88 2200.00 2195.13 4.06 1.95 205.86 186.66 12.250 562.42 34.09 528.33 Pass 2000.00 1924.11 2225.00 2219.88 4.08 1.97 205.39 186.16 12.250 575.81 34.20 541.60 Pass 2017.43 1939.04 2250.00 2244.63 4.10 1.99 204.94 185.66 12.250 589.42 34.36 555.05 Pass 2031.77 1951.24 2275.00 2269.38 4.12 2.01 204.51 185.20 12.250 603.28 34.50 568.78 Pass 2045.92 1963.21 2300.00 2294.14 4.14 2.03 204.10 184.75 9.875 617.38 34.53 582.85 Pass 2059.87 1974.93 2325.00 2318.89 4.16 2.05 203.71 184.33 9.875 631.70 34.66 597.04 Pass 2073.62 1986.41 2350.00 2343.64 4.17 2.07 203.33 183.92 9.875 646.25 34.79 611.46 Pass 2087.17 1997.66 2375.00 2368.39 4.19 2.09 202.97 183.53 9.875 661.01 34.93 626.08 Pass 2100.00 2008.24 2400.00 2393.15 4.21 2.11 202.62 183.16 9.875 675.99 35.05 640.93 Pass 2113.71 2019.48 2425.00 2417.90 4.23 2.13 202.29 182.80 9.875 691.16 35.19 655.97 Pass 2126.70 2030.04 2450.00 2442.65 4.25 2.15 201.98 182.46 9.875 706.54 35.32 671.22 Pass 2139.49 2040.39 2475.00 2467.40 4.27 2.17 201.67 182.13 9.875 722.11 35.45 686.67 Pass 2152.11 2050.53 2500.00 2492.15 4.30 2.19 201.38 181.81 9.875 737.88 35.57 702.30 Pass 2164.53 2060.45 2525.00 2516.91 4.32 2.21 201.11 181.51 9.875 753.82 35.70 718.12 Pass 2176.78 2070.16 2550.00 2541.66 4.34 2.23 200.84 181.23 9.875 769.95 35.83 734.12 Pass 2200.00 2088.40 2575.00 2566.41 4.38 2.26 200.59 180.93 9.875 786.37 36.04 750.34 Pass 2200.00 2088.40 2600.00 2591.16 4.38 2.28 200.34 180.69 9.875 802.72 36.07 766.65 Pass 2212.46 2098.09 2625.00 2615.92 4.40 2.30 200.11 180.43 9.875 819.36 36.20 783.16 Pass 2224.01 2107.01 2650.00 2640.67 4.43 2.32 1B9.89 180.19 9.875 836.16 36.32 799.84 Pass 2235.38 2115.74 2675.00 2665.42 4.45 2.35 1B9.67 179.95 9.875 853.12 36.44 816.68 Pass 2246.59 2124.28 2700.00 2690.17 4.47 2.37 1 B9.46 179.73 9.875 870.23 36.56 833.67 Pass 2257.64 2132.65 2725.00 2714.93 4.50 2.39 1B9.27 179.51 9.875 887.49 36.68 850.81 Pass 2268.52 2140.83 2750.00 2739.68 4.52 2.42 1H9.08 179.31 9.875 904.90 36.80 868.10 Pass 2279.24 2148.84 2775.00 2764.43 4.54 2.44 1B8.90 179.11 9.875 922.45 36.92 885.54 Pass 2300.00 2164.20 2800.00 2789.18 4.58 2.46 1B8.72 178.91 9.875 940.24 37.10 903.14 Pass . . BP-GDB AntiicoIlision Report Site: M PI B Pad Well: ßeren Wellpath: Plan Beren V2 Plan: Undefined Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 2300.00 2164.20 2825.00 2813.94 4.58 2.49 198.55 178.73 9.875 957.97 37.14 920.83 Pass 2300.00 2164.20 2850.00 2838.69 4.58 2.51 198.39 178.57 9.875 976.02 37.19 938.84 Pass 2320.56 2179.21 2875.00 2863.44 4.64 2.54 '198.24 178.39 9.875 994.02 37.37 956.65 Pass 2330.52 2186.41 2900.00 2888.19 4.66 2.56 198.09 178.23 9.875 1012.23 37.48 974.75 Pass 2340.33 2193.45 2925.00 2912.94 4.69 2.59 ~197.94 178.07 9.875 1030.57 37.59 992.98 Pass 2349.99 2200.34 2950.00 2937.70 4.71 2.61 1197.81 177.92 9.875 1049.03 37.70 1011.32 Pass 2359.51 2207.09 2975.00 2962.45 4.73 2.64 1197.67 177.77 9.875 1067.60 37.81 1029.79 Pass 2368.89 2213.69 3000.00 2987.20 4.76 2.66 1197.55 177.63 9.875 1086.29 37.92 1048.37 Pass 2378.14 2220.15 3025.00 3011.95 4.78 2.69 1197.42 177.50 9.875 1105.09 38.02 1067.07 Pass 2400.00 2235.27 3050.00 3036.71 4.83 2.71 197.31 177.35 9.875 1124.13 38.21 1085.92 Pass 2400.00 2235.27 3075.00 3061.46 4.83 2.74 197.19 177.24 9.875 1143.03 38.25 1104.77 Pass 2400.00 2235.27 3100.00 3086.21 4.83 2.76 197.08 177.12 9.875 1162.15 38.30 1123.86 Pass 2400.00 2235.27 3125.00 3110.96 4.83 2.79 196.97 177.01 9.875 1181.50 38.34 1143.16 Pass 2422.38 2250.49 3150.00 3135.72 4.90 2.81 196.87 176.89 9.875 1200.68 38.53 1162.14 Pass 2430.84 2256.18 3175.00 3160.46 4.93 2.84 196.77 176.78 9.875 1220.10 38.63 1181.46 Pass 2439.10 2261.69 3200.00 3185.16 4.95 2.87 196.66 176.66 9.875 1239.69 38.74 1200.96 Pass 2447.15 2267.03 3225.00 3209.79 4.97 2.89 196.54 176.53 9.875 1259.47 38.84 1220.63 Pass 2454.97 2272.19 3250.00 3234.34 5.00 2.92 196.41 176.38 9.875 1279.43 38.94 1240.49 Pass 2462.58 2277.18 3275.00 3258.80 5.02 2.95 196.26 176.22 9.875 1299.55 39.04 1260.51 Pass 2469.98 2282.00 3300.00 3283.17 5.04 2.98 196.10 176.05 9.875 1319.83 39.14 1280.70 Pass 2477.16 2286.65 3325.00 3307.43 5.06 3.01 195.93 175.87 9.875 1340.27 39.24 1301.03 Pass 2500.00 2301.26 3350.00 3331.59 5.13 3.04 195.75 175.67 9.875 1361.02 39.43 1321.59 Pass 2500.00 2301.26 3375.00 3355.63 5.13 3.07 195.56 175.48 9.875 1381.61 39.49 1342.12 Pass Site: M PI B Pad Well: MPB-01 Rule Assigned: Major Risk Wellpath: MPB-01 V1 Inter-Site Error: 0.00 ft 34.60 34.60 34.60 34.60 0.00 0.00 245.51 245.51 189.94 1.29 188.65 Pass 50.00 50.00 50.00 50.00 0.04 0.03 245.51 245.51 189.96 1.66 188.30 Pass 75.00 75.00 75.00 75.00 0.09 0.09 245.52 245.52 190.05 2.25 187.81 Pass 100.00 100.00 100.00 100.00 0.15 0.15 245.52 245.52 190.24 2.84 187.40 Pass 125.00 125.00 125.00 125.00 0.24 0.18 245.53 245.53 190.49 3.45 187.04 Pass 150.00 150.00 150.00 150.00 0.32 0.20 245.54 245.54 190.74 4.00 186.74 Pass 175.00 175.00 175.00 175.00 0.41 0.21 245.55 245.55 190.96 4.56 186.41 Pass 199.99 199.99 200.00 199.99 0.50 0.22 245.55 245.55 191.17 5.11 186.06 Pass 224.99 224.99 225.00 224.99 0.55 0.24 245.55 245.55 191.35 5.58 185.78 Pass 249.99 249.99 250.00 249.99 0.61 0.26 245.55 245.55 191.53 6.05 185.48 Pass 274.99 274.99 275.00 274.99 0.67 0.27 245.56 245.56 191.69 6.51 185.18 Pass 299.99 299.99 300.00 299.99 0.72 0.29 245.56 245.56 191.85 6.98 184.87 Pass 324.49 324.49 325.00 324.99 0.77 0.33 245.56 240.56 192.03 7.50 184.53 Pass 348.88 348.88 350.00 349.99 0.81 0.40 245.52 240.52 192.29 8.08 184.21 Pass 373.27 373.27 375.00 374.99 0.86 0.47 245.44 240.44 192.63 8.66 183.97 Pass 397.66 397.65 400.00 399.99 0.90 0.54 245.32 240.32 193.06 9.25 183.81 Pass 422.04 422.02 425.00 424.99 0.95 0.59 245.17 240.17 193.57 9.78 183.79 Pass 446.40 446.37 450.00 449.99 0.99 0.63 244.97 239.97 194.15 10.28 183.87 Pass 470.76 470.71 475.00 474.99 1.03 0.67 244.73 239.73 194.79 10.77 184.02 Pass 495.10 495.02 500.00 499.99 1.08 0.72 244.45 239.45 195.51 11.27 184.24 Pass 519.43 519.31 525.00 524.99 1.12 0.77 244.13 239.13 196.30 11.81 184.49 Pass 543.74 543.58 550.00 549.99 1.16 0.84 243.78 238.78 197.18 12.39 184.79 Pass .--.......---.......-.-- I I I I I I 1 I 1 I I 1 I I I I I I I 1 1 1 1 1 I" I ~ 1 ~ 121 +' 1:<:' :~ 1 i 1 á5 1 1 I I I I I 1 1 1 I I I I 1 I I I I I 1 1 1 I I '--------- --Øltfflf1fN~...IijØII~-- t:~f~!¡.<_ANyDFr"HM ---- 0000 ~ I , - ~ '...... - - '..... - - - - --- - -- - - - I ~tR.~ "'".."" - '" - I 5000- - - , - 25w (~ PH-] - - - - - - -- - - - - : ! J 2500 - ttl=i ¡:;. J-- i -- - - 5000 == -- - ! II , , , , , , , , ¡ , ¡ ¡ , ¡ 1\ , I ¡ , ¡ , ¡ \1 ¡ , , ¡ I ¡ ¡ ¡ , ¡ ¡ , , , 11 ¡ ¡ , -10000 -7500 -5000 0 5000 ~ --........--.......---.......--............ -......--.............------ -------------------......-.......--- ---------------- ----------------------- :0tJRV¥è¥ pí%.t'Ìti.ftiÍd~;j: wiii l nÏttAtL~ , ......, ......' ......' ......' ..U' u..' ..u' n-..' ......, u", ......., ..."." LEGEND MPB-01 (MPB-Ol) MPB-02 (MPB-02) MPB-03 (MPB-03) MPB-04A (MPB-04A) MPB-04 (MPB-04) MPB-OSA (MPB-OSA) MPB-OS (MPB-05) MPB-06 (MPB-06) MPB-07 (MPB-07) MPB-08 (MPB-08) MPB-OS (Plan MPB-08A) MPB-09 (MPB"09) MPB-lO (MPB-lO) MPB-ll (MPB-Il) MPB-12 (MPB-12) MPB-13 (MPB-13) MPB-14(MPB-14) MPB-IS (MPB-lS) MPB-16(MPB-16) MPB-17 (MPB-17) MPB-lS(MPB-18) MPB-19(MPJ:H9) MPB-20 (MPB-20) MPB-21 (MPB-21) MPB-22 (MPB-22) MPB-23 (MPB-23) MPB-24 (MPB-24) MPB-2S (MPB-1S) Plan MPB"16 (MPB"16) MPB-SO MPB-SOwp01 S 1 ) RE: MPB-50 . . Subject: RE: MPB-50 From: "Quay, Walter (Natchiq)" <QuayWD@BP.com> Date: Tue, 28 Dec 2004 08:48:11 -0900 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> CC: "Johnson, Frederick C" <JohnsoFC@BP.com> Tom, 1. The top of the Lead is planned for 500' above the Top Confining Zone (5600' ) . 2. The formation pressures are as per the table on page 3. The 8.7 on page 4 should be deleted. Walter Quay quaywd@bp.com (907)564-4178 (907)440-8632 - Cell -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, December 27, 2004 2:36 PM To: Quay, Walter (Natchiq) Cc: Johnson, Frederick C Subject: MPB-50 Walter and Fred, I am looking at the application for MPB-50 and had a couple of questions. 1. Where is the TOC planned for the 9-5/8" casing?? It appears that more than sufficient cement is planned, but there is a statement that the planned TOC for the TAIL is 500' above Top Confining Zone (-5600'). It does not appear that sufficient tail is being pumped to accomplish what you state. 2. What formation pressures are expected?? It is stated on page 4 that the expected formation pressures are 8.7 EMW, however when the numbers from the table on page 3 are "crunched", I get about 8.3 EMW. Thanks, Tom Maunder, PE AOGCC 1 of 1 12/28/2004 9:02 AM o o o -õ !'? q, "" ------J I 149 28 00 W I 1492600W 'I I 149 24 00 \If ! 149 22 00 W ! 1 49 20 00 W I 1 49 18 00 W MPU B-50 2042520 SFD 12/27/2004 -4 <::> (,.¡ "" <::> o z N F~et o . SONQRADSTEWMAN . . BPEXPI.2QBATIQNAI<.INC .'iMastercàrdCneck" 'PO' BOXi196612··'MB7~5 ANCHORAGE,AK99519-p617 89-6/1252 118 DATE 11...- ·tk-,â4 6~~J~grE.·..·~C~CX'~ ~~.~t~æ~~~Jð= :~~;9ß: 5.o.c ~>("J?~ $..\~..~"'-- '>i ,:\.;~\~J D.OLLARS -= .: J. 2S2DDObOI:G.GJ....··lb 22 7··'J.SbL.n· OJ.~8 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# Development /' Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL (If API num ber last two. (2) digits are between 60-69) ;17Pt/. ß-SZ) ZVLf- 2-. S- 2- Exploration Stratigraphic ~'CLUE"· Tbe permit is for a new wellbore 'segmeDt of existing well, J . Permit No, .. API No. Production. should continue to be reponed as a function' of tbe original API number. stated above. . HOLE )n accordance with· 20 AAC 25.005(f), all records, data and logs acquired for tbe pilot hole must be clearly differentiated 'in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name OD permi1). PD...OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance witb 20 AAC 25..0SS~ Approval to peñorate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. {Company Name) assumes tbe liability of any protest to the spacing .eJception tbat may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are fint caugbt and ] 0' sample inter:vals through target zones. D D Well bore seg Annular Disposal On Program SER On/Off Shore 11328 Unit Well Name: MILNE PT UNIT SB B-50 SER I PEND GeoArea 890 lie within Je_ase _Unit. interval &rDwi !h_e_Milne Poiot lease .t\OL 047~38; li~s pytside oU~ut ¡¡¡djac~IJUo, injeçtjo_n Syrface Ipçation withjn_ Milne Ppint Unj .t\OL 04]432~ which is ;:¡_BPJea_se th;:¡t . 1987, governs Section 19 of T13N, R11 E, UM. 2_3. 2002govemsS.19, T13N, R11E, UM. jS$ued_Apri Aquifer Exemption Order 2, issued July 8, .t\rea InjectiollQrder Np. 10-B, ~on_e_ Yes Y~s Y~s No Yes Yes Y~s Yes Yes Y~s _Y~s Y~s Yes Yes Y~s No_ NA Initial ClasslType 525036 MILNE POINT, UNDEFINED WDSP BP EXPLORATION (ALASKA) INC Permitfee attachep Field & Pool Company _Lease number appropriate_ _U_nique welt IQcated IQcated proper distance IQcated pr_oper _distance Sufficient ~ . in_drilliog ynjt If devi¡¡¡tec IJcJuped from driJling unitb_oUlJd_ary_ from other w~lJs ~cre¡¡¡ge_avail;:¡ble js wellbQre plat n_ame _and ol!mb_er in a definepppol Wel Well WeJ O-p~rator onl}' affect~d party _O-p~rator has_apprppriate_ Qond inJorce Permit Permit Can permit Well IQcated within area and_strata authorized by I[1jectiplJ co_nserva_tipn order administratille apprpval be approved before can be iSSl!ed wjthQut can be iSSl!ed wjthQut Order # (putlO# hc_omments) (For 5-day wait AJI welJs_ withtn JI4J'uite_area_of review jdeoUfi~d (Fpr ~ervj~well pnl}') Pre-prpdu_ced inj~ctor: pur;:¡tio_nof pre-propuctiPIJ I~ss than 3 mpnths_ (Forservlce well onJy) 2 3 4 5 6 7 8 9 10 11 12 13 14 15 6 7 PTD#: 2042520 Administration Date Appr SFD 12/27/2004 Conslstency_ De!eJmln¡¡¡tion no longer _ha~ an_ impact on iss;ujng a permit tp drj .t\Il aq_uifers ex_empted,AEQ 2. Syffjcjent cem_entpJa_nned tp cover co_nfining_zpnes, weUs_. J NQ reseJllepjt-planlJed, All waste to_Class Rig js equipped with steeLpits. ßyros !i~e!yjn su_rface_ ho!e~ I?rp~imlty- an;:¡lysis perf_orme_d, Traveling c}'linder path calcu!a!e_d . Plann~d MWs9~0 -9A ppg._ Maximyn_expectedJormatjo_npre_sSl!re 8.3 EMW. 1671 psi, 30QO_pstpJoposed, M.t\SP çalcuJa!eda! 1-12S hasnpt b_e~1J reportep jn SB. There are no wells wjthilJ 1/~ mile pf the intendepcpmpletion zon_e, Yes NA Yes No _Yes Yes Yes NA Yes Y~s Yes Yes Yes Yes Yes No NA Con$i$tency has been j~sued_ fpr_ this pr_oject ACMP findjngof Conductor stringprQvid~d known USQWs _CMT v_ol adeQl!ate_ to circ_utate_o_n_cpnductpr tie-ill IQng _string to surf ~g SurfacecasingpJQtect~ al 8. surfC$g CMT vol ad~Q u_ate_ to kIJOWll-PfO_ductive hQrizon_s CMT will coveraJ Casing designs; ad_eQyate fpr C,T, B_&_permafrost JtaJ~-drill, has_a_ 10,,403 fQr ;:¡bandonment beeo apprQved _Mequ;:¡te wellbore ~eparatjoll_propp~ed 8 9 20 21 22 23 24 25 26 27 28 Engineering Apequ;:¡teJan_kage_oJ reserve pit Jtdjv~rter required, dQes jt meet r~gulatipns_ Drilliog fJujd_program sch~matic_& eC1-uiplist adequate incpmm~nts) BOPEs,do _B_OPE_press test to Chp~emanjfold cQmplie~ w/API RP-53 (May 84) WQrk will pccur withpyt psig (put r~gulatiplJ raiiog appropriate; they meet Date TEM 12/27/2004 29 1r'Þ?»1 \)./)"") ~~ Appr _operatjonshytdown H2S gas_ prOQabl~ Mechanical cPlJdjUon pf I~ pre~ence_ Qf 32 33 34 Rig is_e~uippepwjth sensors ;:¡lJd alarms. UgnJJ _or wells within AOR verified (Fpr_s_e[Vic~ welJ only) Yes _Yes NA NA NA ca[1 be iSSl!ed w/Q hydrogen sulfide m~as_ures Permit _D_ata_pres~lJted on_ pote_ntial PveJpre~sure _zpne$ shaJlow gas_zpoes 35 36 Date 37 12/27/2004 38 39 Geology Appr SFD 9.4 ppgml!d, - be drilled with 9.0 ß.7 _ppg EMW. Wi _B-pap, _reported at Exp~cted_ pressures are _nprma! I-I}'drates have 1J0t bee_n _(if Qft-s;hore) _Selsmicanalysjs Qf _Seabed _condjtjpo Sl!rvey CQnta_ct Date Iýz.-~oy we~kly prpgres;sreports [explQratpryonly] Date Engineering Commissioner name{phoneJor t¿¡ 2 !J} 4- Date: Geologic Commissioner: Dre¡ . . Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 12 14:00:26 2005 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ..... ......... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments.. .............. .STS LIS . I · eÓ' fJ £, J (PVIS ... løvv wI 0 f;nfttÝ it ~ot(- 25 2-- J ) /70 Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number... ...01 Previous Tape Name.. .....UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPB-50 500292324000 BP Exploration (Alaska) Inc. Sperry Drilling Services 12-APR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003550394 C.A. DEMOSKI D. GREEN MWD RUN 2 MW0003550394 C. ZAWADZKI D. GREEN MWD RUN 3 MW0003550394 C. ZAWADZKI E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003550394 J. BOBBITT E. VAUGHN MWD RUN 6 MW0003550394 J. BOBBITT E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 13N 11E 5144 4062 MSL 0) # WELL CASING RECORD OPEN HOLE CASING 57.90 23.80 DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 16.000 12.250 8.500 SIZE (IN) 20.000 13.375 9.625 DEPTH (FT) 115.0 2921.0 8296.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-6 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE-WHILE DRILLING (PWD). MWD RUNS 2,5,6 ALSO INCLUDED ACOUSTIC CALIPER (ACAL). MWD RUNS 5 & 6 ALSO INCLUDED STABILIZED LITHO-DENSITY (SLD); COMPENSATED THERMAL NEUTRON (CTN); AND BI-MODAL ACOUSTIC TOOL (BAT). 4. NO PROGRESS WAS MADE ON MWD RUN 4 DUE TO A TOOL MALFUNCTION. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER TELEPHONE CONVERSATION BETWEEN DENNIS URBAN (BP GEOSCIENTIST) AND ROB KALISH (SPERRY DRILLING SERVICES) ON 30 MARCH 2005. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2,3,5,6 REPRESENT WELL MPB-50 WITH API#: 5Q-029-23240-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11370'MD/5062'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (ACAL-DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . DTCP = COMPRESSIONAL WAVE INTERVAL TRANSIT TIME, POST-WELL PROCESSED. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. . . PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record..65535 File Type........... .....LO Previous File Name. .... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD FET RPX RPS RPM ROP CALA NCNT NPHI FCNT RHOB DTC PEF DRHO $ 1 ACAL-DERIVED (8.5" BIT) 9.1-9.2 PPG 500 PPM CHLORIDES 5000 PPM CHLORIDES 1. 0 G/CC 2.65 G/CC SANDSTONE and clipped curveSj all bit runs merged. .5000 START DEPTH 88.0 100.0 100.0 100.0 100.0 100.0 115.5 2900.5 8192.0 8192.0 8192.0 8205.0 8207.0 8297.0 8297.0 STOP DEPTH 11334.5 11327.0 11327.0 11327.0 11327.0 11327.0 11370.5 11280.5 11278.5 11278.5 11278.5 11291. 5 11252.5 11291.5 11291. 5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 5 6 MERGED MAIN PASS. $ MERGE: TOP 8E.0 2931.0 6790 .0 8296.0 10340.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........... ......Down MERGE BASE 2931.0 6790.0 8296.0 10340.0 11370.5 . Optical log depth units........ ...Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.......... ........ ....-999 Depth Units. . . . . . .. . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN INCH US/F Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 56 60 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF CALA DTC MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 88 11370.5 5729.25 22566 88 11370.5 ROP MWD FT/H 1. 58 653.45 143.375 22511 115.5 11370.5 GR MWD API 16.92 131.6 67.9173 22494 88 11334.5 RPX MWD OHMM 0.86 2000 20.1523 22455 100 11327 RPS MWD OHMM 0.67 2000 21.578 22455 100 11327 RPM MWD OHMM 0.85 2000 26.4443 22455 100 11327 RPD MWD OHMM 0.57 2000 31.1206 22455 100 11327 FET MWD HOUR 0.21 92.4 1. 59622 22455 100 11327 NPHI MWD PU-S 7.38 68.46 36.3211 6174 8192 11278.5 FCNT MWD CNTS 601.78 4884 1012.56 6174 8192 11278.5 NCNT MWD CNTS 122061 230425 144853 6174 8192 11278.5 RHOB MWD G/CM 0.186 2.839 2.19226 6174 8205 11291.5 DRHO MWD G/CM -2.813 0.276 0.0361758 5990 8297 11291. 5 PEF MWD BARN 0.87 11.1 2.16341 5990 8297 11291. 5 CALA MWD INCH 8.47 14.59 10.7815 13425 2900.5 11280.5 DTC MWD US/F 45 152 113.686 6092 8207 11252.5 First Reading For Entire File......... .88 Last Reading For Entire File... ....... .11370.5 File Trailer Service name......... ....STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/04/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name..... .... ..STSLIB.002 Physical EOF File Header Service name. ........... .STSLIB.002 Service Sub Level Name... . version Number...... .....1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPD RPM RPX FET ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 88.0 100.0 100.0 100.0 100.0 100.0 115.5 STOP DEPTH 2886.5 2879.0 2879.0 2879.0 2879.0 2879.0 2931.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 20-FEB-05 Insite 66.37 Memory 2931.0 115.0 2931. 0 166.0 65.8 TOOL NUMBER 149206 63122 16.000 115.0 Spud Mud 9.30 130.0 8.3 600 8.4 5.000 5.270 4.500 5.500 72.0 68.0 72.0 72.0 EWR FREQUENCY (HZ): . . # REMARKS: $ # Data Format Specification Record Data Record Type....... ......... ..0 Data Specification Block Type... ..0 Logging Direction...... ......... ..Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 88 2931 1509.5 5687 88 2931 ROP MWD010 FT/H 1. 58 653.45 146.595 5632 115.5 2931 GR MWD010 API 24.56 111.13 60.6053 5598 88 2886.5 RPX MWD010 OHMM 1. 93 2000 62.4198 5559 100 2879 RPS MWD010 OHMM 1.65 2000 66.9454 5559 100 2879 RPM MWD010 OHMM 1.48 2000 73.0355 5559 100 2879 RPD MWD010 OHMM 1.56 2000 76.1069 5559 100 2879 FET MWD010 HOUR 0.24 4.06 0.829685 5559 100 2879 First Reading For Entire File..... .....88 Last Reading For Entire File...... .....2931 File Trailer Service name. ........... .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name........ ... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ... .STSLIB.002 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPX RPS FET RPM GR CALA ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 2879.5 2879.5 2879.5 2879.5 2879.5 2887.0 2900.5 2931.5 STOP DEPTH 6733.5 6733.5 6733.5 6733.5 6733.5 6741.0 6752.0 6790.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 ACAL $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 Acoustic Caliper # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 24-FEB-05 Insite 66.37 Memory 6790.0 2931.0 6790.0 66.1 80.2 TOOL NUMBER 149206 63122 143780 12.250 2921. 0 LSND 9.20 56.0 9.0 450 6.8 4.500 3.120 4.000 5.000 60.0 89.6 60.0 60.0 . Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units....... ... .Feet Data Reference Point... ....... ....Undefined Frame Spacing....... ...... ........60 .1IN Max frames per record..... ........Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 CALA MWD020 INCH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2879.5 6790 4834.75 7822 2879.5 6790 ROP MWD020 FT/H 2 521.77 128.766 7718 2931.5 6790 GR MWD020 API 20.01 126.4 71.4787 7709 2887 6741 RPX MWD020 OHMM 1. 75 21.85 8.47294 7709 2879.5 6733.5 RPS MWD020 OHMM 0.67 20.98 8.87578 7709 2879.5 6733.5 RPM MWD020 OHMM 1. 22 38.65 9.24692 7709 2879.5 6733.5 RPD MWD020 OHMM 5.31 2000 13.3019 7709 2879.5 6733.5 FET MWD020 HOUR 0.36 56.69 1.57647 7709 2879.5 6733.5 CALA MWD020 INCH 10.98 14.59 12.1086 7704 2900.5 6752 First Reading For Entire File.... ..... .2879.5 Last Reading For Entire File.... ...... .6790 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name....... ... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number. . . . . . . . . . .1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD header da~for each bit run in separate f~S. 3 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD FET RPX RPM RPS GR ROP $ START DEPTH 6734.0 6734.0 6734.0 6734.0 6734.0 6741. 5 6790.5 STOP DEPTH 8245.0 8245.0 8245.0 8245.0 8245.0 8252.5 8296.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ..... ...........0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet 27-FEB-05 Insite 66.37 Memory 8296.0 6790.0 8296.0 72.1 79.4 TOOL NUMBER 149206 63122 12.250 2921.0 LSND 9.45 59.0 8.5 400 6.6 5.400 4.190 5.400 5.200 68.0 89.6 68.0 68.0 . Data Reference Point... ........ ...Undefined Frame Spacing.... ...... ......... ..60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6734 8296 7515 3125 6734 8296 ROP MWD030 FT/H 3.32 422.81 124.547 3012 6790.5 8296 GR MWD030 API 19.28 118.41 69.5791 3023 6741.5 8252.5 RPX MWD030 OHMM 1.96 20.24 5.35924 3023 6734 8245 RPS MWD030 OHMM 1.9 23.71 5.57556 3023 6734 8245 RPM MWD030 OHMM 1. 83 24.4 5.82147 3023 6734 8245 RPD MWD030 OHMM 1. 85 29.89 6.33364 3023 6734 8245 FET MWD030 HOUR 0.34 26.43 1.69736 3023 6734 8245 First Reading For Entire File...... .., .6734 Last Reading For Entire File......... ..8296 File Trailer Service name........ .....STSLIB.004 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.005 Physical EOF File Header Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type........ ...... ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT 5 header data for each bit run in separate files. 5 .5000 START DEPTH 8192.0 STOP DEPTH 10245.5 . . NPHI 8192.0 10245.5 NCNT 8192.0 10245.5 CALA 8194.5 10024.0 RHOB 8205.0 10259.5 DRHO 8205.0 10259.5 PEF 8205.0 10259.5 DTC 8207.0 10231.0 RPM 8245.5 10297.0 RPS 8245.5 10297.0 FET 8245.5 10297.0 RPD 8245.5 10297.0 RPX 8245.5 10297.0 GR 8253.0 10305.0 ROP 8296.5 10340.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN BAT SLD ACAL $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 COMP THERMAL NEUTRON Bi-modal Accostic STABILIZED LITHO DEN Acoustic Caliper # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 03-MAR-05 Insite 66.37 Memory 10340.0 8296.0 10340.0 64.8 74.5 TOOL NUMBER 132482 10505932 179954 175796 143749 143749 8.500 8296.0 LSND 9.15 55.0 9.0 500 5.8 2.800 2.010 3.500 2.000 70.0 100.4 70.0 70.0 . Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing.... ...... ......... ..60 .1IN Max frames per record.. ......... ..Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF CALA DTC MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 Name DEPT ROP MWD050 GR MWD050 RPX MWD050 RPS MWD050 RPM MWD050 RPD MWD050 FET MWD050 NPHI MWD050 FCNT MWD050 NCNT MWD050 RHOB MWD050 DRHO MWD050 PEF MWD050 CALA MWD050 DTC MWD050 Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN INCH US/F Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN INCH US/F Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 56 60 Min 8192 9.97 16.92 0.86 0.87 0.87 0.57 0.21 15 601.78 122061 0.186 -4.073 1. 32 8.47 45 Max 10340 269.73 114 . 97 2000 2000 2000 2000 92.4 68.46 2889.68 200040 2.839 0.276 13 .6 9.91 152 Mean 9266 183.365 59.5369 4.29855 5.04731 22.4844 35.8824 2.73823 38.845 966.467 142395 2.13588 -0.0568063 2.71163 8.93095 116.385 First Reading For Entire File... ...... .8192 Last Reading For Entire File....... ....10340 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Nsam 4297 4088 4105 4104 4104 4104 4104 4104 4108 4108 4108 4110 4110 4110 3660 4049 . First Reading 8192 8296.5 8253 8245.5 8245.5 8245.5 8245.5 8245.5 8192 8192 8192 8205 8205 8205 8194.5 8207 Last Reading 10340 10340 10305 10297 10297 10297 10297 10297 10245.5 10245.5 10245.5 10259.5 10259.5 10259.5 10024 10231 . File Header Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/04/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE DTC FCNT NPHI NCNT CALA DRHO RHOB PEF RPX RPS FET RPD RPM GR ROP $ 6 . header data for each bit run in separate files. 6 .5000 START DEPTH 10231.5 10246.0 10246.0 10246.0 10250.5 10260.0 10260.0 10260.0 10297.5 10297.5 10297.5 10297.5 10297.5 10305.5 10340.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN BAT ACAL $ # STOP DEPTH 11252.5 11278.5 11278.5 11278.5 11280.5 11291.5 11291.5 11291. 5 11327.0 11327.0 11327.0 11327.0 11327.0 11334.5 11370.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON Bi-modal Accostic Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 04-MAR-05 Insite 66.37 Memory 11370.0 10340.0 11370.0 64.2 66.3 TOOL NUMBER 138654 121079 125704 185446 3 143749 8.500 8296.0 LSND 9.20 . MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 52.0 7.0 600 5.2 . 3.400 1.960 3.400 3.500 55.0 100.4 55.0 55.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... .......... ...Down Optical log depth units....... ....Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value........ ......... .....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MWD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 CALA MWD060 INCH 4 1 68 56 15 DTC MWD060 US/F 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10231.5 11370.5 10801 2279 10231.5 11370.5 ROP MWD060 FT/H 3.55 193.8 137.482 2061 10340.5 11370.5 GR MWD060 API 39.06 131. 6 88.731 2059 10305.5 11334.5 RPX MWD060 OHMM 0.96 22.5 3.09091 2060 10297.5 11327 RPS MWD060 OHMM 0.9 19.49 3.10249 2060 10297.5 11327 RPM MWD060 OHMM 0.85 32.8 3.22491 2060 10297.5 11327 RPD MWD060 OHMM 0.97 42.21 3.29217 2060 10297.5 11327 FET MWD060 HOUR 0.26 20.49 1.31504 2060 10297.5 11327 NPHI MWD060 PU-S 7.38 39.48 31.3025 2066 10246 11278.5 FCNT MWD060 CNTS 761 4884 1104.2 2066 10246 11278.5 NCNT MWD060 CNTS 127963 230425 149741 2066 10246 11278.5 RHOB MWD060 G/CM 2.02 2.689 2.30453 2064 10260 11291.5 DRHO MWD060 G/CM -0.036 0.245 0.0411628 2064 10260 11291.5 . . 10260 PEF MWD060 BARN 0.87 3.23 1.90663 2064 11291.5 CALA MWD060 INCH 8.48 10.86 9.10693 2061 10250.5 11280.5 DTC MWD060 US/F 48 137 108.337 2043 10231.5 11252.5 First Reading For Entire File......... .10231.5 Last Reading For Entire File..... ..... .11370.5 File Trailer Service name........ .....STSLIB.006 service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation..... ..05/04/12 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name........ ... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/12 Origin.................. .STS Tape Name........ ...... ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments. ............... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name..... ...... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name...... ... ..UNKNOWN Comments.......... ..... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File