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197-189
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC GNI-03 PRUDHOE BAY UN UGN GNI-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/26/2025 GNI-03 50-029-22820-00-00 197-189-0 N SPT 4589 1971890 1500 272 274 274 266 88 305 307 307 OTHER P Bob Noble 7/17/2025 1 year EPA witnessed MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN UGN GNI-03 Inspection Date: Tubing OA Packer Depth 59 1820 1776 1771IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250718163626 BBL Pumped:3.7 BBL Returned:1.5 Tuesday, August 26, 2025 Page 1 of 1 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:Brooks, Phoebe L (OGC) To:PB Wells Integrity Cc:Regg, James B (OGC) Subject:RE: Hilcorp (PBU) July 2024 MIT Forms Date:Friday, August 30, 2024 9:34:54 AM Attachments:MIT PBU S-11B 07-06-24 Revised.xlsx MIT PBU GNI-2A GNI-3 GNI-4 07-26-24 Revised.xlsx MIT PBU H-13A 07-26-24 Revised.xlsx Hi Ryan, Attached are revised reports as follows: MIT PBU S-11B 07-06-24 – changed the packer tvd to 8439’ MIT PBU GNI-2A GNI-3 GNI-4 07-26-24 – changed the type of injection to “I” for GNI-03 (Class I well) MIT PBU H-13A 07-26-24 – changed the BBL Pump to reflect 20 added initial IA pressure of 1330 per the inspector’s report Please update your copy 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, August 1, 2024 9:22 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Hilcorp (PBU) July 2024 MIT Forms All, 3%8*1, 37' GNI-3 revised reports Attached are the completed MIT forms for the tests completed in July 2024 by Hilcorp North Slope, LLC. Well: PTD: Notes: GNI-02A 2061190 1-year MIT-IA EPA GNI-03 1971890 1-year MIT-IA EPA GNI-04 2071170 1-year MIT-IA EPA H-13A 2090440 MIT-T & CMIT per Sundry 324-234 P2-42 1931430 4-year MIT-IA PSI-01 2021450 2-year MIT-IA per AA AIO 4G.010 S-09A 2140970 MIT-T per Sundry 324-258 S-11B 1990530 2-year MIT-IA per AA AIO 3B.008 S-122 2050810 MIT-T & MIT-IA per Sundry 324-268 V-109 2022020 MIT-T per Sundry 324-042 V-220 2080200 4-year MIT-IA V-223 2080220 4-year MIT-IA X-11A 1990780 4-year MIT-IA Y-07A 2071050 4-year MIT-IA Please respond with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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. GNI-03 1971890 1-year MIT-IA EPA Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2061190 Type Inj N Tubing 276 318 305 304 Type Test P Packer TVD 4537 BBL Pump 5.9 IA 131 1710 1651 1639 Interval O Test psi 1500 BBL Return 1.5 OA 32 42 41 41 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1971890 Type Inj I Tubing 1367 1365 1368 1365 Type Test P Packer TVD 4589 BBL Pump 2.0 IA 15 1736 1907 2050 Interval O Test psi 1500 BBL Return 1.7 OA 0 0 0 16 Result I Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1971890 Type Inj I Tubing 1359 1363 1357 1352 Type Test P Packer TVD 4589 BBL Pump 1.3 IA 8 1725 1789 1847 Interval O Test psi 1500 BBL Return 1.5 OA 0 188 245 307 Result I Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1971890 Type Inj I Tubing 1347 1347 1351 1351 Type Test P Packer TVD 4589 BBL Pump 1.2 IA 4 1730 1748 1776 Interval O Test psi 1500 BBL Return 1.3 OA 75 326 364 396 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2071170 Type Inj N Tubing 286 286 285 285 Type Test P Packer TVD 4461 BBL Pump 5.3 IA 5 1697 1626 1618 Interval O Test psi 1500 BBL Return 1.2 OA 85 104 119 119 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 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:Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA. Increased diesel test fluid to 140° F - Passed per EPA GNI-04 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: GNI-03 Notes: Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA. Produced water injection temp rising - inconclusive Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA. Increased diesel test fluid to 120° F - produced water injection temp still rising - inconclusive Notes: Hilcorp Alaska LLC Prudhoe Bay / PBU / GNI Pad Ryan Holt 07/26/24 Notes: Notes: Notes: Notes:Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA GNI-02A GNI-03 GNI-03 Form 10-426 (Revised 01/2017)2024-0726_MIT_PBU_GNI_3wells 9 9 9 9 999 9 9 999 9 9 9 999 9 9 9 9 -5HJJ 6WLOOEH,QFRQFOXVLYHSHU$2*&&FULWHULD-5HJJ GNI-03 inconclusive nconclusive Passed per EPA GNI-03 GNI-03 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/21/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240621 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 5/17/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 10/19/2023 AK E-LINE PLT END 2-72 50029237810000 224016 6/10/2024 HALLIBURTON RBT Paxton 3 50133205880000 209168 3/14/2023 AK E-LINE GPT/JBGR/RBP PBU E-12A 50029207820100 216127 6/4/2024 HALLIBURTON RBT PBU-GNI-03 50029228200000 197189 5/21/2024 READ CaliperSurvey Please include current contact information if different from above. T38984 T38985 T38986 T38987 T38988 T38989PBU-GNI-03 50029228200000 197189 5/21/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.21 13:35:29 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/31/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240531 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/25/2024 AK E-LINE JB/GR/RBP MPI 2-14 50029216390000 186149 5/8/2024 READ CaliperSurvey MPS-17 50029231150000 202173 5/14/2024 READ LeakPointSurvey PBU GNI-03 50029228200000 197189 5/21/2024 READ PressureTemperatureLog PBU GNI-04 50029233670000 207117 5/22/2024 READ CaliperSurvey PBU GNI-04 50029233670000 207117 5/20/2024 READ PressureTemperatureLog TBU K-12RD2 50733201560200 208088 5/17/2024 READ CaliperSurvey TBU K-17 50733202480000 173001 5/16/2024 READ CaliperSurvey Please include current contact information if different from above. T38865 T38866 T38867 T38868 T38869 T38869 T38870 T38871 PBU GNI-03 50029228200000 197189 5/21/2024 READ PressureTemperatureLog Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.31 13:00:13 -08'00' 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Tuesday, August 1, 2023 1:10 PM To:Brooks, Phoebe L (OGC); Regg, James B (OGC); Wallace, Chris D (OGC) Cc:PB Wells Integrity Subject:Hilcorp (PBU) July 2023 MIT Forms Attachments:July 2023.zip All, AƩached are the completed AOGCC MIT forms for the tests completed in July 2023 by Hilcorp North Slope, LLC. Well: PTD: Notes: 11‐31A 1961830 2‐year MIT‐T & CMIT‐TxIA per CO 736 13‐01 1780600 MIT‐T for P&A Sundry #323‐074 E‐34A 2140960 2‐year MIT‐T & CMIT‐TxIA per CO 736 F‐10C 2130860 2‐year MIT‐T & CMIT‐TxIA per CO 736 GNI‐02A 2061190 Annual EPA MIT‐IA GNI‐03 1971890 Annual EPA MIT‐IA GNI‐04 2071170 Annual EPA MIT‐IA L‐103 2021390 4‐year MIT‐IA L‐117 2011670 4‐year MIT‐IA L‐254 2230300 New Drill MIT‐IA per Sundry #323‐381 M‐28 1860740 4‐year MIT‐IA P2‐29 1931470 4‐year MIT‐IA PSI‐09 2021240 2‐year MIT‐T per CO 736 & 2‐year MIT‐IA per AA AIO 4F.001 PWDW3‐2 2190810 4‐year MIT‐IA V‐100 2010590 4‐year MIT‐IA W‐40A 2221030 IniƟal MIT‐IA for Injector Conversion per Sundry #323‐100 Y‐27 1900280 4‐year MIT‐IA Please reply with quesƟons or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 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, 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. PBU GNI-03PTD 1971890 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2061190 Type Inj N Tubing 314 316 314 314 Type Test P Packer TVD 4537 BBL Pump 5.1 IA 38 1710 1645 1635 Interval O Test psi 1500 BBL Return 2.2 OA 36 45 44 44 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1971890 Type Inj N Tubing 283 286 283 282 Type Test P Packer TVD 4589 BBL Pump 3.9 IA 77 1708 1664 1657 Interval O Test psi 1500 BBL Return 1.5 OA 333 327 318 321 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2071170 Type Inj W Tubing 1493 1494 1492 1493 Type Test P Packer TVD 4461 BBL Pump 3.8 IA 137 1704 1659 1662 Interval O Test psi 1500 BBL Return 1.8 OA 9 25 24 22 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 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 Prudhoe Bay / PBU / GNI Pad Ryan Holt 07/21/23 Notes: Notes: Notes: Notes: GNI-02A GNI-03 Notes: GNI-04 Notes: Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA Annual EPA MIT-IA. Witnessed by Nick Bruno from the EPA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Form 10-426 (Revised 01/2017)2023-0721_MIT_PBU_GNI-pad_3wells 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: 06/20/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230420 Well API #PTD #Log Date Log Company Log Type BCU 04RD 50133202390100 219011 5/16/2023 AK E-LINE Perf BCU 04RD 50133202390100 219011 5/17/2023 AK E-LINE Strip Guns NS-23 50029231460000 203050 4/25/2023 HALLIBURTON MFC PBU GNI-02A 50029228510100 206119 5/30/2023 READ Pressure Temperature Survey PBU GNI-03 50029228200000 197189 5/31/2023 READ Pressure Temperature Survey PBU J-29 50029234860000 213033 4/18/2023 BAKER SPN PBU A-06A 50029201180100 223015 4/6/2023 BAKER MRPM Please include current contact information if different from above. T37770 T37770 T37771 T37772 T37773 T37774 T37775 PBU GNI-03 50029228200000 197189 5/31/2023 READ Pressure Temperature Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.21 13:29:44 -08'00' Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2061190 Type Inj N Tubing 244 300 300 300 Type Test P Packer TVD 4537 BBL Pump 1.4 IA 69 1696 1651 1643 Interval O Test psi 1500 BBL Return 1.3 OA 71 170 174 174 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1971890 Type Inj N Tubing 408 411 408 408 Type Test P Packer TVD 4589 BBL Pump 0.8 IA 137 1734 1706 1702 Interval O Test psi 1500 BBL Return 0.8 OA 79 83 82 84 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2071170 Type Inj W Tubing 1496 1490 1480 1488 Type Test P Packer TVD 4461 BBL Pump 1.3 IA 47 1696 1654 1658 Interval O Test psi 1500 BBL Return 1.3 OA 53 302 291 291 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 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 Prudhoe Bay / PBU / X Pad Oliver Sternicki 07/21/22 Notes: Notes: Notes: Notes: GNI-02A GNI-03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mec hanical Integrity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: GNI-04 Notes: Annual EPA MIT-IA. Witnessed by Ryan Gross from the EPA Annual EPA MIT-IA. Witnessed by Ryan Gross from the EPA Annual EPA MIT-IA. Witnessed by Ryan Gross from the EPA Notes: Form 10-426 (Revised 01/2017)2022-0721_MIT_PBU_GNI-pad_3wells GNI-03 Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU GNI-03 (PTD 197-189) Caliper Survey 06/25/2022 Please include current contact information if different from above. PTD:197-189 T36734 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.29 10:47:57 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU GNI-03 (PTD 197-189) Pressure Temperature 06/25/2022 Please include current contact information if different from above. PTD:197-189 T36734 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.29 10:50:01 -08'00' ICU CI ROOOD111u I TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. GM -03 PRUDHOE BAY UN UGN GNI-03 Sre: Inspector Reviewed B P.I. Supry J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN UGN GNI-03 API Well Number 50-029-22820-00-00 Inspector Name: Guy Cook Insp Num: mitGDC200616070108 Permit Number: 197-189-0 Inspection Date: 6/16/2020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well cNl-a3 Type Inj N TVD 4589 Tubingj 266 275 267 267 PTD 1971890 Type Test SPT Test psi 1500 IA 6 1987 1942 1932, BBL Pumped:. 56 BBL Returned: 1.7 OA 14 17 18 - 18, Interval OTHER p/F P v Notes: Annual Class 1 disposal well EPA test. Testing performed with a Little Red Services pump truck and calibrated gauges. The N2 cap was bled off of the IA and a fluid shot was taken to show the fluid level was approxiamately 180' below surface. The well should take approxiamately 4.6 bbls to fill. Ryan Gross with the EPA witnessed this test remotely via ZOOM from Seattle.,. Wednesday, June 17, 2020 Page 1 of I V I S ProActive Diagnostic Services, Inc. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Marion Kendall LR2 —1 900 Benson Blvd. Anchorage, AK 99508 GANCPDC(&.USAANC.hou.xwh.BP.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907)245-8952 1) Pressure/Temperature Survey 14 -May -19 2) , A? Signed : Print Name: 19`1 89 30952 RECEIVED JUL 0 8 1019 AOGCC Log / CD 50-029-22820-00 Date: v // 4 q PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.8952 E-MAIL: PDSANCHORAGEAMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM hnDs tlreadrasedholo-,nyshaeepofm conJpersonal/diaue__williams_roedeesndhole_oon✓Documents/Daskwp/Bt•_Transnded.urc by tq0-1 %• RECEIVED AUG 10 2017 AOGCC BE Exploration(Alaska)Inc. d���1 900 East Benson Boulevard P.O.Box 196612 Anchorage.Alaska 99519-6612 (907)56l-5111 August 8, 2017 UIC Manager, Ground Water Protection Unit AUG 12P' U.S. Environmental Protection Agency (OCE-127) SCANNED 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 \i()\3 Re: Demonstration of Mechanical Integrity, Prudhoe Bay Grind and Inject, UIC Class I Permit AK-11008-A Dear UIC Manager: This letter is to submit the results of recent fluid movement tests and the annulus pressure test results for the three UIC Class I GNI wells located at the Prudhoe Bay Grind and Inject project operated by BP Exploration (Alaska), Inc (BPXA). The tests are specified as part of the demonstration of mechanical integrity under Part II, C.3 b of EPA UIC Class I permit AK11008-A. The enclosed descriptive and interpretive report contains the results for the following logs and tests as required under Part II, C.3.c(1) of the permit: - Fluid Movement Test: GNI-02A, GNI-03, and GNI-04 (Page 16, Part II, C.3.b(2)) - Annulus Pressure Tests: GNI-02A, GNI-03, and GNI-04 (Page 16, Part II, C.3.b(1)) There was no indication of a loss of well integrity. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Carrie Janowski, Intervention & Integrity Specialist, at (907) 564-5273. Sincerely, j Wendy Bosnians East Area Operating Manager • • Cc: Evan Osborne, EPA Region 10 (letter and report) Chris Wallace, AOGCC (letter and report) Marc Bentley, ADEC (letter and report) Attachments: Demonstration of Mechanical Integrity Report Schlumberger GNI-02A Temperature and Pressure Survey, July 17, 2017 Halliburton GNI-03 Memory Temperature and Pressure Survey, June 27, 2017 Halliburton GNI-04 Memory Temperature and Pressure Survey, July 26, 2017 Annulus Pressure Test Results • • Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project EPA permit AK-1I008-A effective 09/01/07 requires a fluid movement tests in the Prudhoe Bay Unit Class I Grind & Inject wells each calendar year. Approved fluid movement tests (Part II C 3 b (2)) include tracer surveys, temperature logs, noise logs, oxygen activation/water flow logs, borax pulse neutron logs (PNL) or other logs. The permit also requires a standard annulus pressure test (SAPT). Below are the results of logs and tests run recently in the GNI wells. Fluid Movement Tests Wellbore temperatures are affected by the temperature of the injected fluids by conduction and/or convection. When the well is injecting fluids, the wellbore and the adjacent formation reaches a temperature near the injection fluid temperature due to conductive heat transfer. When injection ceases,the wellbore temperature begins to return toward its original temperature. The rate of temperature change of the shut-in well will depend on the original formation temperature, the injection fluid temperature and the rate and cumulative volume of injection. In the GNI wells,the injected fluids are typically colder than the formation temperatures below about 4000 ft TVD. In areas where the injected fluids enter the formation, both conduction and convective heat transfer are involved. The amount of rock cooling is much larger and the rate of temperature change after shut-in is much slower due to the direct contact of the formation with the cold fluid. Channeling adjacent to the wellbore is evident because cooler injected fluids leak off into formations throughout the length of the channel. Several types of logging tools are available to be used to record the temperatures of the wellbore fluids: tools run on electric line with a real-time surface readout and memory tools run on slick line. The results from these instruments are presented in the enclosed logs of borehole temperature and pressure versus measured depth. Typical Shut-In Temperature Survey Procedure EPA permit AK-1I008-A requires fluid movement tests surveys to "... be conducted at injection pressure at least equal to the average continuous injection pressure observed in the previous 6 months." Injection is cycled into the GNI wells on a rotating basis, with one well injecting at a time. The average and maximum injection pressures are reported quarterly on Form 7520-8. The survey procedure generally involves the following steps: • Inject a significicant volume of cold water or slurry at the required pressure followed by a period of stabilized injection. • Shut—in the well after the injection cycle. • After at least 5 days of shut-in time, rig up prepare logging tools • Confirm depth control by comparing to the tie-in log on record. • Run the shut-in temperature/pressure survey • Compare the logged temperatures to previously shut in logs run in the well. The GNI wells normally inject cold slurry or cold water at 50-70 degrees F. The original formation temperature of the target disposal formation was about 115 degrees F. The Shut-In Temperature log technique is commonly used for cement channel detection in • • 11, injection wells on the North Slope of Alaska and has been used to satisfy the GNI fluid movement test requirement as a demonstration of mechanical integrity. GNI-02A Shut-In Temperature Survey Results —reference Schlumberger GNI-02A Pressure and Temperature Survey (GR/CCL/Press/Temp/FBS) from July 17, 2017. The log trace was run from the total depth of the well to the surface. The average daily injection pressure in well GNI-02A over the 6 months prior to its survey was 1261 psi. Wellhead injection pressures exceeded this average pressure during the injection cycle prior to the survey. GNI-02A was shut in for approximately 42 days before the temperature/pressure survey. The shut-in temperature trace indicates increasing temperature with depth to about 7450' feet measured depth (MD) or 6080 feet true vertical depth(TVD). Below that point, temperature starts declining until fill level was reached or just above the perforated interval. Based on this data, there is no evidence of injected fluid movement above about 6080' TVD. GNI-03 Shut-In Temperature Survey Results—reference Halliburton GNI-03 Memory Pressure and Temperature Survey(GR/CCL/Press/Temp) from June 27, 2017. The log trace was run from the fill level in the well to the surface. The average daily injection pressure in well GNI-03 over the 6 months prior to its survey was 1237 psi. Wellhead injection pressures exceeded this pressure during the injection cycle prior to the survey. GNI-03 was shut in for approximately 14 days before the temperature/pressure survey. The shut-in temperature trace indicates increasing temperature with depth to about 6720' feet measured depth(MD) or 6099' feet true vertical depth (TVD). Below that point, the temperature decreases until the fill level was reached or just above the perforated interval. Based on this data, there is no evidence of injected fluid movement above about 6099' TVD. GNI-04 Shut-In Temperature Survey Results—reference Halliburton GNI-04 Memory Temperature Survey(GR/CCL/Press/Temp) from July 26, 2017. The log trace was run from fill level in the well to the surface. The average daily injection pressure in well GNI-04 over the 6 months prior to its survey was 1185 psi. Wellhead injection pressures exceeded this pressure during the injection cycle prior to the survey. GNI-04 was shut in for approximately 15 days before the temperature/pressure survey. The shut-in temperature trace indicates increasing temperature with depth to about 6640' feet measured depth (MD) or 6032' feet true vertical depth (TVD). Below that point, the termperature decreased until the fill level was reached or just above the perforated interval. Based on this data, there is no evidence of injected fluid movement above about 6032' TVD. Annulus Pressure Test Results Annulus pressure tests were performed on UIC Class I Prudhoe Bay Grind and Inject disposal wells GNI-02A, GNI-03 and GNI-04 on July 31, 2017. The tests were performed in accordance with the stipulations of Class I permit AK-11008-A. In each well, the nitrogen cushion normally maintained in the tubing - casing annulus was bled off and displaced with diesel prior to the test. The annulus was then pressured to above 1500 psi with diesel and observed for 30 minutes. The tests were conducted while all of the wells were shut in. The test results were as follows: Tubing Pressure Annulus Pressure psi 1st Half 2nd Half Test GNI Well Start/ End Start 15 Min 30 Min Decline Decline Result GNI-02A 347/345 1802/1752/1743 50 9 Pass GNI-03 250/249 1797/1762/1753 35 9 Pass GNI-04 268/267 1795/1723/1701 72 22 Pass In wells GNI-02A, GNI-03 and GNI-04, the pressure decline was less than 10 percent during the test period, with not more than 1/3 of the total decline in the second half of the 30 minute period. This data shows a stabilizing tendency as specified in EPA Permit AK-11008-A, Part II, C.3.b (1). Annulus pressures were observed on a recording digital test gauge. During the test period, the tubing pressure was essentially constant. The GNI-02A, GNI-03 and GNI-04 annulus pressure tests indicate the casing, tubing and packer are in sound mechanical condition. This is consistent with the absence of any indication of tubing or packer leakage during normal injection oeprations when there is a large pressure differential (>500 psi) between the tubing and the annulus in each of he wells. The tests were witnessed by EPA representatives Evan Osborne and Jason Selitsch. Carrie Janowski, Intervention & Integrity Specialist August 3, 2017 • \IV _ k5C9 bp 179 Certified Mail: 7016 0910 0001 1040 6356 BP Exploration(Alaska)Inc. 900 East Benson Boulevard P.O.Box 196612 Anchorage,Alaska 99519-6612 July 19, 2017 (907)561-5111 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE-127) JUL 2 0 2017 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 AOGCX Re: Demonstration of Mechanical Integrity, Prudhoe Bay Grind and Inject UIC Class I Permit AK-1I008-A GNI-04 & GNI-02A Caliper Dear UIC Manager: This letter is to submit the results of recent tubing inspection logs ran in UIC Class I wells GNI-04, GNI-02A, and GNI-03, located at the Prudhoe Bay Grind and Inject project operated by BP Exploration (Alaska), Inc (BPXA). These tests are specified as part of the demonstration of mechanical integrity under Part II, C.3 b of EPA UIC Class I permit AK11008-A. The enclosed descriptive and interpretive report contains the results for the following logs as required under Part II, C.3.c(1) of the permit: - Tubing Inspection Log: GNI-04 (Page 16, Part II, C.3.b(3)) - Tubing Inspection Log: GNI-02A (Page 16, Part II, C.3.b(3)) - ►. .ingInspection Log: GNI-03 (Page 16, Part II, C.3.b(3)) There was no indication of a loss of well integrity. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. SCpop JUL 2 7 2017 • • If you have questions, please contact Carrie Janowski, Intervention"& Integrity Specialist at (907) 564-5273. Sincerely, sr Wendy Bos an East Area Operating Manager Cc: Evan Osborne, EPA Region 10 (letter and report) Chris Wallace, AOGCC (letter and report) Marc Bentley, ADEC (letter and report) Attachments Demonstration of Mechanical Integrity Report GNI-04 Memory multi-finger caliper log, June 11, 2017 GNI-02A Memory multi-finger caliper log, June13, 2017, and June 28, 2017 GNI-03 Memory multi-finger caliper log, June 26, 2017 • • Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project EPA permit AK-11008-A effective 09/01/07 requires a tubing inspection log in the Prudhoe Bay Unit Class I Grind& Inject wells annually. Approved tubing inspection logs (Part II C 3 b (3)) include pipe analysis logs, caliper logs or other equivalent tests. Tubing Inspection Logs A 40 arm caliper logging tool, supplied by Halliburton, was run on slickline to inspect the interior surface of both the tubing and the casing, on the GNI wells. A memory caliper log was run in well GNI-04 on June 11, 2017 to evaluate the tubing and casing. The 7"tubing looks to be in good to fair condition with a range of damage between 20-36%recorded. The 9 5/8"casing below the tubing tail looks to be in good condition with a range of damage between 15-27%recorded. A memory caliper log was run in well GNI-02A on June 13, 2017 to evaluate the tubing and on June 28, 2017, to evaluate the casing. The 7"tubing looks to be fair condition with a range of damage between 20-34%recorded. The 9 5/8"casing looks to be in decent condidiont with a range of damage between 20-46%recorded. A memory caliper log was run in well GNI-03 on June 26, 2017 to evaluate the tubing and casing. The 7"tubing looks to be in decent condition overall with a range of damage between 20 -40%recorded, with the hightest recorded damage of 53%recorded. The 9 5/8"casing below the tubing tail looks to have moderate ring damage throughout with a range of damage between 40-60%recorded. Below are the observed maximum metal losses observed in the tubing and casing from the caliper logs. Well Date Maximum Wall Penetration Max Cross-Sectional Wall Loss GNI-04 Tubing 06/11/17 36% 19% GNI-04 Casing 06/11/17 27% 6% • GNI-02A Tubing 06/13/17 34% 26% GNI-02A Casing 06/28/17 46% 20% GNI-03 Tubing 06/26/17 53% 27% GNI-03 Casing 06/26/17 50% 22% Enclosed are copies of the Halliburon'Memory Multi-Finger Caliper log results summary for each well. • Overall Conclusions The GNI-04 caliper log indicates the tubing has maximum penetration of 36% but it is suitable for continued injection. The GNI-02A caliper log indicates the tubing has maximum penetration of 34% but it is suitable for continued injection. The GNI-03 caliper log indicates the tubing has maximum penetration of 53% but it is suitable for continued injection. Carrie Janowski, Intervention& Integrity Specialist July 12, 2017 =11/ rv CERTIFIED MAIL# 7016 0910 0001 1040 7001 APR I 3 2011 BP Exploration(Alaska)Inc. April 13, 2017 P.O.Box 196612 900 E.Benson Boulevard Anchorage,AK 99519-6612 USA 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 APR 2 0 2017 SC4HNED Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 RE. Mechanical Integrity Test Notifications Pad 3 Injection Wells, UIC Permit AK-11004-B, Wastewater Disposal, Permit No. 2010DB0001-0021 Grind and Inject Injection Wells, UIC Permit AK-11008-A, Area Injection Order No. 4G, General Wastewater, Permit No. 2010DB001-0012 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notification of well surveillance activities to satisfy demonstration of mechanical integrity requirements for the Class 1 UIC permits mentioned above: 1) SAPT (Standard Annulus Pressure Test) 2) Fluid movement tests 3) Tubing inspection logs. 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. 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. Mechanical Integrity Testification • • April 13, 2017 Page 2 A summary of the proposed annual testing is presented in the attached table. If you have any questions, please contact me at (907) 564-4613 or tom.harvey@bp.com Sincerely, Thomas J Harvey, CHMM Regulatory and Permitting Advisor-Waste/UIC Attachment cc: Evan Osborne, EPA Region 10 Mechanical Integrity Telotification • • April 13, 2017 Page 3 Certification Statement Mechanical Integrity Test Notification I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. 4/11/1-4— Respo ; : Company Official Date Wendy Bosmans East Area Operations Manager BP Exploration Alaska) Inc. Printed Name Title Company Mechanical Integrity Tesstification • April 13, 2017 Page 4 bcc (hard copy, with enclosure): Pad 3 File [1007.01.26] Grind & Inject File [1007.02.01] bcc (electronic, enclosure): Carrie Janowski AK, HSSEE Env Adv Central • Proposed Schedule for 2017 Demonstration of Mechanical Integrity Activities Class I UIC Wells Class I Well Activity Next Deadline 2017 Proposed test Notes (s) /Requirement date Pad 3— Caliper 8/24/18 7/27/17 OWDW-NW&C OWDW-NW, C OWDW-SE (every 2 years) wells have lined and SE Wells tubing Borax-RST 8/31/18 OWDW-SE 7/31/17 Order which wells logging (every 2 years) OWDW-NW 8/1/17 are tested could OWDW-C 8/2/17 change SAPT 8/30/17 8/3/17 Plan to test (Standard (annually, 3 month OWDW-NW, -C, &- annulus grace period at Director SE wells on same pressure discretion) day testing) BP calls MITIA Grind & Inject Tag fill & 2017 GNI-02A 6/3/17 Order which wells —GNI-02A, temperature (each calendar year) GNI-03 6/16/17 are tested could 03, and -04 survey GNI-04 6/28/17 change. Tag fill, memory temperature/ pressure logs and Caliper will be run Caliper 2017 GNI-02A 6/3-6/4/17 on same Slickline (annually, no monthly GNI-03 6/16-6/17/17 rig up if possible. requirement) GNI-04 6/28-6/29/17 SAPT 8/29/17 7/28/17 Plan to test GNI- (Standard (required annually, one 02A, -03, -04 wells annulus month grace period) on same day pressure testing) BP calls MITIA \c\-1-\c O\ 22460 WELL LOG •-S... TRANSMITTAL PROACTIVE DIAfjNOSTIC SERVICES, INC. DATA LOGGED 45/201G itid.K.BENDER To: AOGCC RECEIVED Makana Bender 333 W. 7th Ave Suite 100 AUG.08 2016 Anchorage, Alaska 99501 (907) 793-1225 AOGCC RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2—1 900 Benson Blvd. Anchorage, AK 99508 gancpdc a(�.bp.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Pressure/Temp Survey 21-Jul-16 GNI-03 BL/ Report/CD 50-029-22820-00 2) Signed : p-).,44.......,4,) 6.4.....41, Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE C(�.MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:AAchives\MasterTemplateFiles\TemplatesVDistribution\TransmittalSheets\BP_Transmit.docx Z- cQ0 Q\Aq 0ST;c 000 W PROACTIVE E IAC�NOSTIC SERVICES Static Survey Temperature / Pressure Chart Data G N 03 July 21St, 2016 I • N • N I T __O + co �QE`,�+j5T5 p _ _ co M ji u CO _ c_O O 7.2 biLTJI CV — 0 — I a VA is r C N R O : L __ O . _ C —mI i L - I. 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CI 11 1 0 El M II I1 I M } I I I 44 y It to N III I iII N L II II N 11II I II N 1.44 I � _ �, - iN I O Iili li li O Ills 1 I CO I Il it II I --z, N o 1 1 i I I ,- - Lo CO III i1 i I III 1 Q C3 RS Q o 1 W I I I o o M III � i II I • O m a � ! I I i i ! I I Q 1 Q, ° C 00000000000000000 p <�' O O O O O O O O O O O 0 0 00000000000000000 `k. "1 N-00)0 N-(0 U)VMN� CMOINNNNNOrU)M�6)I�1f)Me- I Q. VI 4 Z O d'Bea VMd I • FOCEIVED APR 2 9 2016 CERTIFIED MAIL#7015 1730 0000 6058 3491' AOGCG ` BP Exploration(Alaska)Inc. P.O.Box 196612 April 26, 201 6 900 E.Benson Boulevard Anchorage,AK 99519-6612 USA 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 RE: Mechanical Integrity Test Notifications Pad 3 Iniection Wells, UIC Permit AK-11004-B, Wastewater Disposal, Permit No. 2010DB0001-0021 Grind and Inject Injection Wells, UIC Permit AK-11008-A, Area Injection Order No. 4E, General Wastewater, Permit No. 2010DB001-0012 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) 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-B and 2) 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. 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) Mechanical Integrityt Notification • April 26, 2016 Page 2 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 e-mail. If you have any questions, please contact me at (907) 564-4267 or Tom.Barrett@bp.com Sincerely, Tom Barrett Environmental Team Lead Attachment cc: Thor Cutler, EPA Region 10 Mechanical Integrity/I, Notification • April 26, 2016 Page 3 Certification Statement Mechanical Integrity Test Notification I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. ice/ -AV y/Xtop G Respon- • - Compa.,.4fficial Date Gary Crawford Logistics/Infrastructure Manager BP Exploration Alaska) Inc. Printed Name Title Company • ! 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? Pad 3— By Mid-September 2016 Yes Borax-RST logs OWDW-NW, C September for each well and SE Wells 21, 2016 for scheduled with NW, C and MIT's SE wells Caliper log in OWDW-SE in (Logging summer/fall may be 2016 extended up to 3 months with Director approval) Grind and Inject By Mid-September 2016 Yes Shut-In —GNI-02A, September Temperature GNI-03 and 20, 2016 for Logs and/or GNI-04 GNI-02A, Water Flow Logs GNI-03 and planned for GNI-04. summer/fall 2016 (May be extended 1 Caliper logs in month or at summer/fall Director 2016 discretion) ! ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jin ReggDATE: Tuesday,October 06,2015 P.I.Supervisor Z t ��Cl SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC GNI-03 FROM: Johnnie Hill PRUDHOE BAY UN UGN GNI-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry::_f -sr__ NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN UGN GNI-03 API Well Number 50-029-22820-00-00 Inspector Name: Johnnie Hill Permit Number: 197-189-0 Inspection Date: 9/20/2015 Insp Num: mitJWH150920193418 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We❑ GNI-03 - Type Inj N' TVD 4589 ,Tubing! 265 . 265 - 265 - 265 , PTD 1971890 ' Type Test SOT Test psi 1500 - IA ' 7 1801 - 1771 - 1763 - .-.- Interval riR IP/F P ✓ OA 28 29 . 29 30' Notes: this was an EPA witnessed test by Thor Cutler 2.97bbls of diesel used , Tuesday,October 06,2015 Page 1 of 1 • ✓ CJ/ I o19W v 1 U) CU 0❑ A- A- A- e- N 00.0 V - N 61 _1 m -AP CID u >o (v (D Q X COL' Q Q Y .. �° Q `^ i' O I-'" N L C Z oao I- > O 7 tI O as 'O O vO ca Z QH 0, co In m ❑ a l7 r , Lo 10 1.0 in 1.11 MI °0 v E .E _1 !� , 0 Cr; Q" j j) > > 7) 3 3 ° ‘n y 15 C C �, ►- Fc_ fi W Q Q Q Q Q "'1 ' Q ' Q , c0 N PO r M 7 O) O -O O- > Z a <; f` l0 N N N 00 �- C co a1 Q 0 Z Q C O u O > Q N Nu v >c i ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 113 v L 6 d J J J J J J J J J J J �, w w w w w w w w w w w c o` )- LL LL LL LL LL LL U. 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LL LL LL LL 0) _C u U 4J L C1 O 1 4, _ C 0 v v O O G�i ,� O" Q) +-, -O O CO0Z O wz c O _cv a — vvY4= C O " ocz p Q v U > u U) ) Cy n " i.u. J J ~ a 0 ~ 0 m Q I- V w a Q1 . 0 0 0 V ..CD CO w N F d N = E. O cc SIn ` cy m U w �— co ol a) t° u, W aCecu o a cu 8 = a '5 Ce a 0 0 0 J O J J 4I - 03 co O z oc 2 2 2 2 G ~j �i cc _- vwi vi w w w w o .e.....0- 111).,....VV Lu a a a a a a a CO m CO m m CO m a Q w w w w w w w 2 0 0 0 0 0 0 0 E E p 2 = S S 2 = = r 0 0 0 0 0 0 0 C) Lu D O = m m Diireccxceccrc re , :i C to a 0 0. a 0. 0 0. 03 0 C7 A a cV J �, w .- c0 rn a) N M M 00 x `0' 0 i. lVQ 0 0 0 a) O 0 M co 0 0 0 O fC O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 " 0a � ceaa w n coC) .S x W 0000000 W Li j H Cr 0 a o co p 0 N 0 0 0 o 50. O 0 0 0 0 c0 O H N O to O to O M r \C In co M N N V CO triN h O el Co V LAO to i N 0 0 O N N O '/N E. N N N N N N N1: rn rn rn o) ae rn rn O pN N N N N N N01 O O O o O O O0 0 0 0 0 0 0to v) v) v) U) to N a+ Oa) 4 u QD y�� M c0 C1 c_0�r1 Z E y >_� Z p yA' K C dI V p�1i Q Cry M a! u e G C1 ri Q om0V N O J O .aY+ +'V1 2 M Z O ', N O Z r c0 a Q L° N 'J O QLL (� d X E Z C)yVI � i Loa RsH a` a )t—• c be CERTIFIED MAIL# 7011 2970 0001 9243 3630 BP Exploration(Alaska)Inc. P.O.Box 196612 April 28, 201 5 900 E.Benson Boulevard Anchorage,AK 99519-6612 USA Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue RECEIVED Seattle, WA 98101 MAY 0 1 2015 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Avenue Anchorage, AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 %AHMED RE: Mechanical Integrity Test Notifications Pad 3 Injection Wells, UIC Permit AK-11004-B, Wastewater Disposal, Permit No. 2010DB0001-0021 Grind and Inject Injection Wells, UIC Permit AK-11008-A, Area Injection Order No. 4E, General Wastewater, Permit No. 2010DB001-0012 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) 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-B and 2) 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. 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) Mechanical Integrityapt Notification • April 28, 2015 Page 2 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 e-mail. If you have any questions, please contact me at (907) 564-4838 or Darren Mulkey at 564- 5229. Sincerely, Alison Cooke UIC Compliance Advisor Attachment cc: Thor Cutler, EPA Region 10 Mechanical Integritylt Notification . April 28, 2015 Page 3 Certification Statement Mechanical Integrity Test Notification I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. C 0e( f Responsib a Compa Date Gary Crawford Logistics/Infrastructure Manager BP Exploration Alaska) Inc. Printed Name Title Company • • Proposed Schedule for 2015 Mechanical Integrity Testing Class I Well (s) MIT Proposed MIT test Flexibility in Fluid Deadline date test date? Movement Logs Planned after MIT? Pad 3— By Mid-September 2015 Yes Borax-RST logs OWDW-NW, C September for each well and SE Wells 18, 2015 for scheduled with NW, C and MIT's SE wells. Caliper log in OWDW-SE in (Logging summer/fall may be 2015 extended up to 3 months with Director approval) Grind and Inject By Mid-September 2015 Yes Shut-In —GNI-02A, September Temperature GNI-03 and 20, 2015 for Logs and/or GNI-04 GNI-02A, Water Flow Logs GNI-03 and planned for GNI-04. summer/fall 2015 (May be extended 1 Caliper logs in month or at summer/fall Director 2015 discretion) P&( C�,Z-o3 PM !97)%.0 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, October 01, 2013 9:45 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks,ghoebe L (DOA); DOA AOGCC Prudhoe Bay r Cc: AK, D&C Well Integrity Coordinator to/7//3 Subject: September 2013 AOGCC MIT Forms Attachments: September 2013 MIT Forms.zip All, Please find the attached MIT forms for September 2013. WELL PTD# NOTES MPE-12 2050670 MPE-26 2002060 MPE-29 2010370 MPG-05 1910230 SCANNED 1: E L; x MPG-19 2041920 r MPS-15 2012450 NK-18 1931770 NK-65A 2050630 09-22 1831730 14-21A 2051070 GNI-02A 2061190 EPA AND AOGCC FORM GNI-03 1971890 EPA AND AOGCC FORM i/ Not-�r 55 AO CC- GNI-04 2071170 EPA AND AOGCC FORM v OWDW-NW 1002400 EPA AND AOGCC FORM OWDW-SE 1002390 EPA AND AOGCC FORM N-23 1970120 NG I-01 1750480 P-03A 1972280 U-05A 2090700 X-29 1931390 Please contact us with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIIIntegritYCoordinator(>bp.com 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(rDalaska.gov; AOGCC.InspectorsCrDalaska.gov; phoebe.brooksCaDalaska.gov chris.wallace @alaska.gov OPERATOR: BP Exploration(Alaska),Inc. /UNIT I PAD: Prudhoe Bay/PBU/GNI 'Zy 1 41/1 3 DATE: 09/23/13 OPERATOR REP: Jack Disbrow AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well GNI-03 ' Type Inj. W ' TVD '4,589' Tubing- 1,212 1,230" " 1,214 "1,206 Interval p P.T.D. 1971890 ' Type test P - Test psi ' 1500 Casing 121 '1,800, - 1,772 "1,758 P/F P Notes:Annual regulatory compliance witnessed by EPA OA 52 ' 60 61 62 Pumped 4.7 bbls of diesel and bled back 2.5 bbls of fluid Well - P.T.D. Notes: Well P.T.D. Notes: 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 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU GNI-03 09-23-13.xls United States Environmental Protection Agency Region 10 r1 1200 Sixth Avenue,Suite 900 Seattle,WA 98101 Thor Cutler-(206)553-1673 e-mail:cutler.thor @epa.gov MECHANICAL INTEGRITY TEST(MIT)FORM Facility [ Well t Permit No. PTD No. BP Alaska-Prudhoe Bay Unit,G&I Wells GNI-03 AK-1I008-A 1971890 Injector MIT Type Test Type Test Date Class I T X IA Std.Annular Pressure Test(SAPT) 9/23/2013 Req'd Test Fluid Type(s)used to Packer Depth(ft, Test Interval/Comments Presssure(psi) test TVD) 1,500 Diesel 4,589 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 9:35 AM PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN P/F S TUBING 1212 1230 1214 1206 T INNER ANNULUS 121 1800 1772 1758 Pass OUTER ANNULUS 52 60 61 62 _ 1 COMMENTS: Pumped 4.7 bbls of diesel S!Ccif t I &PI-04, 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: NOTE:Pressure must show stabilizing tendency: 1)Total pressure loss must be less than 10%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 10% 2)Loss during last 15 minute period=or>50%of loss during first 15 minute period Extend the test 30 minutes to demonstrate stabilization(thermal effects). —E-mail this MIT Test Data Form to EPA Region 10-Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Waived by John Crisp Kevin Parks 01,/ bp • , MECEPIED a - NOV D 3 7x12 �xx; BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561 -5111 November 07, 2012 prED 1 1 1 89 Commissioner Cathy Foerster, Chair Alaska Oil & Gas Conservation Commission SCANNED JAN 2 3 2013 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Grind & Inject Project Annual Performance Report Dear Commissioner Foerster: Enclosed is the Annual Performance Report for waste slurry injection for the Grind and Inject project located near Drill Site 4 in the Prudhoe Bay Unit. This report is submitted to satisfy the requirements of Area Injection Order #4E, Rule 10, as modified by Administrative Approval No. AIO 4C.001 and an Erratum Notice dated July 17, 2009. This requirement is very similar to an EPA report requirement regarding Prudhoe Bay Unit UIC Class I injection wells contained in EPA permit AK- 11008 -A. The report covers the period from October 1, 2011 through September 30, 201 and w as structured to satisfy both the AOGCC and the EPA requirements. Should you have questions concerning the contents of this report, contact me at 564 -4692. Sincerely, Michael L. Bill Senior Staff Engineer Fu? F' FI,QAS • • Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class 1 Permit AK- 11008 -A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2011 through September 30, 2012 This Annual Performance Report documents waste slurry injection on the Surfcote Pad near Drill Site 4 in the Prudhoe Bay Unit for the period October 1, 2011 through September 30, 2012. This report is submitted to satisfy the requirements of both EPA UIC Class 1 permit AK- 11008 -A, Part 11 3 c 7 and AOGCC Area Injection Order (AIO) #4E, Rule 10, as modified by Administrative Approval AIO 4C.001 and Erratum Notice dated July 17, 2009. Additional information requested in a letter from the AOGCC (Regg to Bill 12/22/03) is also included. The report contains a brief description of the current project status, a summary of the disposal well performance data acquired during this period and operational plans for the next year. Project Status The Grind & Inject (G &I) Project at the Surfcote pad was undertaken in 1998 by the owners of the Prudhoe Bay Unit, Initial and Lisburne Participating Areas, and the Kuparuk River Unit to dispose of drilling muds and cuttings stored in reserve pits. Other non - hazardous wastes processed through the G &I Plant included those referenced in AIO #4E, Rule 2 as Class 11 wastes, consisting of RCRA- exempt drill cuttings and oily solids from pipeline pigging, vessel cleanouts and well workovers, and RCRA- exempt liquid wastes such as used drilling mud from on -going North Slope drilling operations. EPA issuedClassJ _UKC_pe i AK 11QQ8 -A_for the Grind &Inject Project effective September 1, 2007. Authorizations to inject Class I substances were received on January 18, 2008 for wells GNI -02A and GNI -03 and on May 6, 2008 for GNI -04. Well GNI -01 remains a Class II only disposal well. All non - hazardous wastes injected for disposal in the GNI wells during the report period are within the description of wastes referenced in EPA UIC Class I Permit AK- 11008 -A, Part 1I C 3 7, the UIC Class 1 permit application submitted in November 2006, or in Area Injection Order 4B, Finding 7 as incorporated in AIO #4E. Several lined pits comprising the "material transfer station" (MTS) at DS 4 were operated to temporarily hold ongoing drilling and oily solids when necessary. On an infrequent basis, flow back liquids from new wells drilled with oil -based mud (OBM) or other wastes were injected directly into G &I wells using temporary equipment staged on the Surfcote pad. As of September 30, 2012, project injection has included 51.8 MM barrels of water, 88.0 MM barrels of slurry containing 5.4 MM tons (6.0 MM cubic yards) of excavated reserve pit material and other waste solids, and 7.0 MM barrels of fluid from ongoing drilling operations. Exhibit 1 summarizes this data. 1 • • Operations Operations during the year were affected by seawater supply interruptions due to high winds, power outages and maintenance work at the Seawater Treatment Plant and the Seawater Injection plant. G &I maintenance activities included an extensive inspection program of the piping and processing equipment within the plant and the pipelines to the wells. Major operations and maintenance activities included replacement or repairs of process valves and piping, ball mill liner and motor, super sucker tent heater, well manifold and valves, and make -up air units. Solids processing in the G &I plant was shut down during the 2011 summer until early February 2012, and from late May 2012 through the present. Disposal of ongoing liquid drilling wastes and water from pit dewatering operations continued during much of the summer shut down period. Solid wastes accumulated during the summer were stored at the MTS and processed when the full plant was in operation. The pace of excavation from the production reserve pits was reduced in 2010 with the concurrence of the Alaska Department of Environmental Conservation and batch processing of solids rather than continuous processing has been used as needed since. Well Operations and Monitoring The four GNI disposal wells are located on the Surfcote pad and continue to be available for disposal. Well GNI -01 has been shut -in due to tubing damage since May 2007, but it could be available for Class II direct injection pending current mechanical integrity testing or for observation purposes if needed. It was replaced for Class I waste and slurry injection by well GNI -04 which began in May 2008. Well GNI -02A was sidetracked to a new bottom hole location in November /December 2006 and is an active Class I waste and slurry injector. Existing Class I well GNI -03 is also active after a workover in December 2009 to replace damaged tubing. Each well is perforated in the Ugnu formation between 6400 and 6600 ft TVD. GNI plant discharge rate, temperature and slurry density, along with well injection pressure and temperature and annulus pressures are continuously monitored in the G &I Plant control room. Injection takes place into one well at a time on a rotating schedule. After each injection cycle, the newly shut in well is flushed with water and freeze protected with new product methanol mixed with water. Exhibit 4 lists the injection cycles and the well work and surveillance activities during the report period. The injection history and performance for each well is shown in Exhibits 1, 2, 3, 5, 6 and 10. Peak slurry injection rates are normally between 25,000 and 35,000 barrels per day with between 1,500 and 3,000 cubic yards per day of solids processed. Injected slurry density averaged about 9.5 ppg when solids were being processed (Exhibit 6). Surface injection pressure is heavily influenced by the slurry injection rate, slurry density and to some extent slurry temperature due to viscosity dependence on temperature and the impact of injection temperature on formation stress. Daily average surface injection and calculated bottom -hole injection pressures (BHIP) are shown in Exhibit 6 for each well. BHIP is calculated to account for the effects of the hydrostatic head and fluid friction of the slurry column. The calculated bottom hole injection pressures in each well have shown relatively stable injection pressures over the last year. All three active wells have maintained good formation injectivity with no sign of formation plugging. 2 • By design, the outer annulus (OA) of each GNI well is in weak pressure communication with the formation adjacent to its surface casing shoe set at about 4000 ft TVD (GNI -03 and GNI -04) and about 2800' TVD in the GNI -02A sidetrack. The surface pressure in each outer annulus is monitored as potential indicator of any significant fluid movement above the approved injection interval. The OA pressure is also quite sensitive to thermal expansion or contraction of the annulus fluids resulting from the injection cycle and injection fluid temperature variations. The inner and outer annuli of each well are closely monitored during a well swap and periods of higher temperature injection and the annulus pressures are bled as necessary. Due to the communication with the formation, OA pressure changes related to thermal effects begin to dissipate within a short time. There have been no significant sustained pressure increases adjacent to the surface casing shoe and no abnormal or unexplained annulus pressures observed during the report period. Each GNI well is equipped with control line tubing open ended within the inner annulus (IA) to about 1000 ft. This line allows several hundred feet of nitrogen cushion to be maintained in the inner annulus (IA) to dampen the pressure changes due to thermal expansion or contraction of the annulus fluid. There has been no indication of tubing or packer leakage observed in any of the GNI wells, although the IA pressure may need to be bled during periods of high temperature injection and re- charged during periods of cooler injection. Exhibit 10 contains daily average tubing, IA and OA pressures for each of the wells. Dates when the annulus pressure was bled or re- pressured are also indicated. EPA witnessed mechanical integrity tests of the inner annulus are required annually under the Class I permit. The AOGCC requires an MIT -IA every two years in slurry injection wells under AIO 4E, Rule 6. Successful MIT -IA tests were performed in GNI wells 02A, 03_ and 04 on September 23, 2012. _ EPA representatives witnessed each of these MIT -IA tests. Memory caliper logs were run in GNI wells 02A, 03 and 04 to inspect the 7" tubing strings in 2012. GNI -01 has remained shut -in since May 2007 due to the level of tubing damage. The following table lists the observed maximum metal loss in the tubing and the casing below the packer from the caliper logs run during the report period. Well Date Max Pit Penetration Max Cross - Sectional Wall Loss Tubing Casing Tubing Casing GNI -02A 07/01/12 34% 26% 23% 15% GNI -03 06/14/12 13% 57% 4% 24% GNI -04 06/20/12 26% 26% 15% 14% After isolation of the tubing with bridge plugs and two way check valves, the trees on each of the wells were replaced and inspected for erosion and corrosion damage. Very little damage was observed on the trees which have been in service since 2010. 3 • Well Surveillance and Testing The cycling of wells on injection generally allows well surveillance and maintenance activities to be scheduled with little disruption to G &I plant operations. To minimize freeze protection concerns, repeat well tests and Togs are usually scheduled in the summer. The shut in temperature /pressure survey results for 2012 and prior years are shown in Exhibit 7. Repeat shut -in temperature /pressure Togs were run in the wells in June and July. Based on the fill tags and the temperature profiles, all injection continues to exit each wellbore through the perforated intervals. The temperature logs have very similar character to the previous Togs in each well. Consistent with the 2011 results, the temperature Togs have shown less than 500 feet TVD of vertical fluid movement. Since the GNI well bores are deviated and the effective depth of investigation of temperature Togs is limited, the full extent of injection through vertical fractures may not be detected by the temperature logs. Observed static reservoir pressures obtained with the GNI -02A, 03 and 04 shut -in temperature /pressure Togs were close to the 2011 measurements: -9 psi in GNI -02A, -11 psi in GNI -03, and +5 psi in GNI -04. Repeat step rate tests (SRTs) were performed in wells GNI -02A 03 and 04 in July and August. Due to facility shut downs, two 2011 step rate tests were actually run after the 9/30/11 data cutoff for last year's report. The analyses for those tests were included in the 2011 report. The repeat SRT procedure included both a step up portion and a step down portion. Each SRT was analyzed using two methods to provide additional insight, a conventional analysis and a superposition method. The step rate test in well GNI -04 exhibited an unusual character with no specific fracture opening /propagation pressure indicated. This has been interpreted as injection into a pre- existing fracture or fracture network possibly held open by injected solids. Exhibit 8 discusses the 2012 step rate test data and analysis results. As in the past, SRT's confirm fractures are the primary disposal mechanism. Repeat surface pressure falloff (SPFO) tests were run in wells GNI -02A, 03 and 04 in June. Surface pressure falloff tests were run in the summer to avoid rate fluctuations due to freeze protection immediately prior to shut in. Also, since a well cannot be shut in while injecting slurry, each repeat SPFO test is run after a period of water injection containing only a small amount of mud liquids. No drilling mud was injected in the 24 hours prior to shutting in the well and the injection rate was stabilized. Normally, the SPFO tests are run after a period of seawater slurry injection. The SPFO tests should be viewed as representing a snapshot in time that may not completely reflect the downhole flow conditions present due to the differences with fluid rheology under actual slurry injection. As with past tests, calibrated surface memory gauges were used to record the pressure falloff data. 4 • • Exhibit 9 discusses the 2012 SPFO test analysis results. Several reservoir flow models were used in an attempt to obtain a type curve match of the data. The SPFO data from each of the wells was best matched using a radial composite double - porosity (RCDP) reservoir model. The tests from each of wells showed evidence of a damaged zone some distance from the wellbore. Storage Mechanism and Disposal Domain As reported in the past, a number of industry studies have been conducted to understand the downhole storage mechanism in slurry injection operations. These include two major industry studies: the Drilling Engineering Associates (DEA) 81 Joint Industry Project (JIP) laboratory study and the Mounds Drill Cuttings Injection JIP field pilot study. Individual operators have also reported monitoring and well testing programs to delineate the storage mechanism and geometry. Many of these studies and monitoring programs agree that multiple fractures are created during periodic injection operations. Step rate tests and pressure falloff tests of the GNI wells have also showed signatures of multiple opening or multiple closure events, indicating multiple fractures from GNI operations. The result is likely a complex disposal domain consisting of a series of fractures developed over time with different orientations. Branching fractures may also be a part of the storage mechanism. This disposal domain allows for the storage of large amounts of solids. Grind and Inject fracture modeling was updated in 2006 using a modified conventional hard rock fracture simulator adjusted for soft rock behavior and assuming the disposal domain described above. The layer description was extended upward and downward to include 22 layers. The updated model runs predicted fractures to be contained below 5900 ft TVD at that time, about 600 ft above the perforations in the original GNI completions. At some point the increasing stress due to solids storage in the fractures of the disposal domain will create conditions resulting in possible additional upward fracture extension. The model results indicate fracture growth to near 5000 ft TVD at some time beyond the year 2020, still well below the top of the approved interval at about 4500 ft TVD. While the primary G &I surveillance techniques (temperature Togs, step rate tests and pressure falloff tests), the results from a prototype bore hole gravity meter reported in 2010 and the model results provide differing inferences as to the size of the fracture system (partially due to the specific conditions of each test), all indicate limited upward movement of the injected material and confinement well within the approved interval specified in EPA UIC Class 1 permit AK- 11008 -A, Part 11 3 c 4 and AIO #4E, Rule 2. Well Plans Well GNI -01 has significant tubing damage and has injected over 1.6 MM cubic yards of waste drilling solids. Well GNI -01 could be available for occasional direct injection of Class 11 materials pending current mechanical integrity testing, and to observe various facets of the slurry injection process if needed. Routine waste injection is expected to continue to be cycled between the three active Class I disposal wells. 5 • . Operational Plans The operational plan for the next twelve months will involve similar activities to those in recent years. Discussions are ongoing with Alaska Department of Environmental Conservation concerning the scope of the remaining production reserve pit closeout activities required by the State of Alaska's Inactive Reserve Pit Closure Regulations. While a significant feed for the G &I plant will be excavated drilling mud and cuttings from exploration reserve pits and well sites, the pace of excavation from the production reserve pits will likely remain reduced. As was the case in 2012, solid waste material will be processed in batches rather than continuously, except when the mill is shut down for maintenance, during well switches and for brief periods due to weather or utility outages. Class II liquids and solids from on -going drilling operations will be processed at the G &I plant on a periodic basis determined by the drilling and well workover activities. Oily solids will be accepted at the material transfer station and processed at the G &I plant during winter months when the material can be handled in a frozen state and mixed with reserve pit wastes. Non - hazardous Class I materials will be processed and injected in the three active GNI slurry injection wells, GNI -02A, GNI -03 and GNI -04. Direct injection of crude oil contaminated with oil based drilling mud from the initial production from new wells and of other non - hazardous wastes will be utilized when necessary. Snow melt accumulating in reserve pits will be injected by the GNI plant in the summer as needed. Each of the three active GNI wells will be used for injection on a rotating schedule as described above. 6 • Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class 1 Permit AK- 11008 -A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2011 through September 30, 2012 List of Exhibits 1. GNI Surfcote Injection Summary 2. GNI Injection Bar Graph 3. a,b GNI Solids Injection Bar Graphs 4. GNI Surfcote Well Surveillance Activities 5. b,c,d GNI Wells Injection Bar Graphs 6. b,c,d GNI Wells Daily Average Data Plots 7. b,c,d GNI Wells Temperature Logs 8. GNI Wells Step Rate Tests 9. GNI Wells Pressure Falloff Tests 10. a,b,c,d GNI Wells TIO Pressure plots 7 1 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg ; ;M , ► ME AUG 0 7 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue c4/9 Anchorage, Alaska 99501 ,Q3 Subject: Corrosion Inhibitor Treatments of GPB GNI lJ N 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB GNI 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 altemate, Gerald Murphy, at 659 -5102. Sincerely, V 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) GNI Date: 03106/2012 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 GNI-01 1972380 50029228450000 0.7 NA 0.7 NA 5.1 3/6/2012 GNI -02A 2061190 50029228510100 5.0 NA 5.0 NA 30.6 3/6/2012 __Ty GNI-03 1971890 50029228200000 5.8 NA 5.8 NA 35.7 3/6/2012 GNI -04 2071170 50029233670000 2.3 NA 2.3 NA 13.6 3/6/2012 DATE: 27- Jul -12 Stephanie Pacillo TRANS#: 6020 CT Data Delivery Services Technician ] Makana K Bender Schlumherger Oilfield Services '''b ' Natural Resources Technician II WIRELINE 13Ska Oil & Gas Consei , -at :cn Coi �:.__s_ic'i 2525 Gambell St, Ste. 400 \ 33 , ; 7.7 7*- r __ :e. 10::; A: :c. c .::',C: Anchorage, AK 99503 it: Office: (907) 2734770 ` WELL `= SERVICE` ;' .OH ' RESERV ; :. CNL = MECH LOG DESCRIPTION DATE B/W COLOR CD `s NAME ORDER# DIST DIST DIST DIST LOGGED PRINTS PRINTS GNI -03 C60O -00012 X MEMORY TEMP PRESS SURVE' 13- Jun -12 1 1 CD GNI -04 COT4 -00019 X MEMORY TEMP PRESS SURVE' 19- Jun -12 1 1 CD MPL -12 BAUJ -00133 X MEMORY LEAK DETECTION LO 8- Jun -12 1 1 CD fli Z -06A C2JC -00021 X SCMT 7" 31- May -12 1 1 CD 14 -33A C5XI -00006 X MEMORY DEPTH DETERMINAT 12- Jun -12 1 1 CD Z-06A C2JC -00021 X SCMT 4.5 31- May -12 1 1 CD 02 -35B C5XI -00008 X MEMORY PPROF W/ GHOST 18- Jun -12 1 1 CD L -04 C5XI -00005 X MEMORY IPROF 10- Jun -12 1 1 CD V -207 C60O -00013 X MEMORY PPROF 15- Jun -12 1 1 CD J -26 BZ81 -00019 X RST WFL LOG 9- Jun -12 1 1 CD MPB -15 C2JC -00028 X PPROF W DEFT 25- Jun -12 1 1 CD MPG -14 C5XI -00007 X MEMORY LEAK DETECTION LO 15- Jun -12 1 1 CD GNI -02A COT4 -00035 X MEMORY TEMP PRESS SURVE' 7- Jul -12 1 1 CD 09 -18 C3NA -00021 X INJECTION PROFILE 14- Jun -12 1 1 CD • X X Please return a signed copy to: _ .., .. , `' `'.'' Please return a signed copy to: BP PDC LR2 -1 ; ;.ti DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 N p �I ;! W bp • BP Exploration (Alaska) Inc. 9 0. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519 -6612 USA Certified Mail # 7011 0110 0000 4759 2705 SIAN October 03, 2011 1i UIC Manager, Ground Water Protection Unit - U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 �} Seattle WA 98101 RE: Demonstration of Mechanical Integrity, Prudhoe Bay Grind and Inject, UIC Class I Permit AK- 11008 -A Ni7 _ ©zik- Zo6ILclo Pak Guy: - c" s 1471,6 Dear Mr. Kowalski: GCs - 04 Pb Ze "7/11 This letter is to submit the results of recent annulus pressure tests for three UIC Class I GNI wells and a tubing inspection log for one well. The wells are located at the Prudhoe Bay Grind and Inject project and operated by BP Exploration (Alaska), Inc (BPXA). The tests and log are specified as part of the demonstration of mechanical integrity under Part II, C.3 of EPA UIC Class I permit AK1I008 -A. The tests and log were conducted in compliance with the permit requirements and were witnessed by EPA representative Thor Cutler. The annulus pressure tests, also known as Mechanical Integrity Tests (MITs) were performed on wells GNI -02A, GNI -03 and GNI -04 on September 22, 2011. The three wells passed the MITs. Detailed information regarding the results of the MITs is contained in the attached descriptive and interpretive analysis of the tests. Enclosed also is a descriptive and interpretive report containing the results of a tubing Inspection Log run in well GNI -02A on September 23, 2011 as required under Part II, C.3.b(3) of the permit. There was no indication of a loss of well integrity. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. UIC Manager • October 03, 2011 Page 2 BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564 -4692. Sincerely, F , Ktharine Fontaine Logistics/Infrastructure Manager Attachments: Mechanical Integrity Test Results Mechanical Integrity Test Forms Cc: Thor Cutler, EPA Region 10 (letter and report) Talib Syed, EPA Consultant (letter and report) Jim Regg, AOGCC (letter and report) Shawn Stokes, ADEC (letter and report) i • UIC Manager October 03, 2011 Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project Annulus Pressure Test Results Annulus pressure tests were performed on UIC Class I Prudhoe Bay Grind and Inject disposal wells GNI -02A, GNI -03 and GNI -04 on September 22, 2011. The tests were performed in accordance with the stipulations of Class I Permit AK- 1I008 -A. In each well, the nitrogen cushion normally maintained in the tubing - casing annulus was bled off and displaced with diesel. The annulus was then pressured to above 1500 psi with diesel and observed for 30 minutes. The tests were conducted while GNI -03 was injecting and the other wells were shut in. The results of the tests were as follows: Tubing Pressure Annulus Pressure psi 1st Half 2nd Half Test GNI Well Start / End Start 15 Min 30 Min Decline Decline Result GNI -02A 265 / 261 1800 ' 1750 1742 50 8 ' Passed GNI -03 885 / 880 1801 1797 1794 4 3 ' Passed GNI -04 250 / 248 1799 1751 1743 48 8 Passed In wells GNI -02A and GNI -04, the pressure decline was less than 10 percent during the test period, with less than 1/3 of the total decline in the second half of the 30 minute period. This data shows a stabilizing tendency as specified in EPA Permit AK- 1I008 -A, Part II, C 3 b (1). In well GNI -03, the pressure decline was also less than 10 percent during the 30 minute test period, in fact less than 0.4 %. The test was extended another 30 minutes to ensure stability and the pressure declined only an additional 6 psi (0.33 %) during that period. Annulus pressures were observed on a recording digital test gauge. During the test period, the tubing pressure was essentially constant in each well. The tests were witnessed by EPA representative Thor Cutler. • • UIC Manager October 03, 2011 Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project Tubing Inspection Log Results EPA permit AK- 1I008 -A effective 09/01/07 requires a tubing inspection log in the Prudhoe Bay Unit Class I Grind & Inject wells each calendar year. Approved tubing inspection logs (Part II C 3 b (3)) include pipe analysis logs, caliper logs or other equivalent tests. Below are the results of the caliper log run recently in well GNI -02A. Tubing Inspection Log A 40 arm caliper logging tool, supplied by PDS (ProActive Diagnostic Services), was run on slickline to inspect the interior surface of both the tubing and the casing. A memory caliper log was run in well GNI -02A on September 23, 2011. The tubing inspection indicated the GNI -02A tubing is in good to fair condition with no significant erosion/corrosion. The tubing was new when the well was completed in December 2006. The casing below the tubing tail is also in good to fair condition. Below are the observed maximum metal losses observed in the tubing and casing from the caliper log. Well Date Maximum Pit PenetrationMax Cross - Sectional Wall Loss GNI -02A Tubing 09/23/11 33% 24% GNI -02A Casing 09/23/11 26% 15% The log was witnessed by EPA representative Thor Cutler. Enclosed are copies of the PDS Memory Multi- Finger Caliper, Log Results Summary for this well. Over All Conclusions I conclude from the successful MIT's that the casing, tubing and packer in wells GNI -02A, GNI - 03 and GNI -04 are in sound mechanical condition. This is consistent with the absence of any indication of tubing or packer leakage during normal injection operations when there is a large pressure differential ( >500 psi) between the tubing and the annulus in each of the wells. The GNI -02A caliper log indicates the tubing has maximum penetration of 33% but it is suitable for continued injection. Michael L. Bill, P.E September 26, 2011 • ' United States Environmental Protection Agency Region 10 . Z.` 7.21( l 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553 -1673 e-mail: cutler.thorrgepa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility I Well ! Permit No. PTD No. I BP Alaska - Prudhoe Bay Unit, G &I Wells GNI -02A AK- 1I008 -A 19;7.890 7.4 ,9 i i l ie Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 9/22/2011 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval !Comments Presssure (psi) test TVD) 1,500 Diesel 4,537 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 10:14 AM PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN PIF S TUBING 260 265 ' 261 261 - T INNER ANNULUS 14 1800 ' 1750 1742 - PASS ✓ OUTER ANNULUS 34 38 ' 38 38 1 COMMENTS: took 1.5 bbls diesel to pressure up T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING T INNER ANNULUS 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 T INNER ANNULUS OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: I NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % 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 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 1 0 0 -- E -mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Waived by John Crisp Jon Arend • .. ^ United States Environmental Protection Agency ii Region 10 J ‘ • 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553 -1673 e -mail: cutler.thor @epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well I Permit No. PTD No. BP Alaska - PBU GNI -03 AK- 11008 -A 1971890 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 9/22/2011 Req'd Test Fluid Type(s) used to Packer Depth (ft, Presssure (psi) test TVD) Test Interval / Comments 1,500 Diesel 4,589 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 12:48 PM PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN P/F S TUBING 887 885 ' 883 880 878 877 ' T INNER ANNULUS 87 1801 , 1797 1794 1790 1788 " PASS OUTER ANNULUS 225 402 406 406 402 398- 1 COMMENTS: 1 bbls diesel to pressure up T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING T INNER ANNULUS 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 T INNER ANNULUS OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: Dedicated G&I solids injection well. Drilled in late 2007 with slurry injection start on 5/22/08. NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % 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 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 0 — E - mail this MIT Test Data Form to EPA Region 10 -, Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Waived by John Crisp Jon Arend • United States Environmental Protection Agency far 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 Facility Well I Permit No. PTD No. BP Alaska - PBU GNI -04 AK- 11008 -A 2071170 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 9/22/2011 Req'd Test Fluid Type(s) used to Packer Depth (ft, Presssure (psi) test TVD) Test Interval / Comments 1,500 Diesel 4,46I' 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 14:54 PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN P/F S TUBING 248 250 - 248 248 T INNER ANNULUS 16 1799 , 1751 1743 - PASS OUTER ANNULUS _ 91 119 - 118 118 1 COMMENTS: Took 1.38 bbls to pressure up 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: Dedicated G&I solids injection well. Drilled in late 2007 with sluny injection start on 5/22/08. NOTE: Pressure must show stabilizing tendency: I) Total pressure loss must be less than 10 % 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 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on - site decision per Inspector). 0 0 — E - mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Waived by John Crisp Jon Arend • Memory Multi-Finger Caliper Log Results Summary Company: BP Exploration (Alaska), Inc. Well: GNI -02A Log Date: September 23, 2011 Field: Prudhoe Bay Log No.: 13006 State: Alaska Run No.: 7 API No.: 50- 029 - 22851 -01 Pipet Desc.: 7 in. 29 lb. L -80 BTC -M Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 5,189 Ft. (MD) Pipet Desc.: 3.625 in. 47 lb. '_-80 -? 1 Top log ntvi.: 3,139 Ft. (MD) Pipe2 Use: Production Casing Bot. Log intvl.: 3,160 Ft. (MD) Inspection Type : Corrosion & Erosion Monitoring Inspection COMMENTS : This caliper data is tied into the WLEG at 5,189 feet (Driller's Depth). This log was run to monitor changes in the condition of the 7 inch tubing and 9.625 inch production casing with respect to corrosive, erosive and mechanical damage as a result of sustained solids injection. The caliper recordings indicate the 7 inch tubing appears to be in good to fair condition. Wall penetrations between 20% and 33% wall thickness are recorded in 131 of the 133 joints logged and cross - sectional wall loss ranging from 15% to 24% metal volume are recorded in 38 of the 133 joints logged. Recorded damage appears as apparent erosion throughout the tubing. No significant I.D. restrictions are recorded. The caliper recordings indicate the 9.625 inch production casing logged appears to be in good to fair condition with respect to corrosive, erosive and mechanical damage. Wall penetrations between 20% and 26% wall thickness are recorded in 72 of the 74 joints logged and cross - sectional wall loss of more than 15% metal volume is recorded in 8 of the 74 joints logged. Recorded damage appears as apparent erosion throughout the production casing logged. No significant I.D. restrictions are recorded throughout the production casing logged. This is the seventh time a PDS caliper has been run in this well and the fifth time this tubing and production casing have been logged. A comparison of the current and previous log (June 30, 2010) of the 7 inch tubing indicates an increase in erosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint-by-joint basis between logs is included in this report. A comparison of the current and previous log (June 30, 2010) of the 9.625 inch production casing logged indicates no increase in erosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint-by-joint basis between logs is included in this report. 7 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : Apparent Erosion ( 33 %) Jt. 13 @ 543 Ft. (MD) Apparent Erosion ( 33 %) Jt. 3 @ 116 Ft. (MD) Apparent Erosion ( 31%) Jt. 52 @ 2,107 Ft. (MD) Apparent Erosion ( 31 %) Jt. 28 @ 1,138 Ft. (MD) Apparent Erosion ( 31%) Jt. 23 @ 936 Ft. (MD) ProActive Diagnostic 5eriices, Inc. / P.O. Sox 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS ©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 559 -2314 0 0 7 INCH TUBING - MAXIMUM RECORDED CROSS- SECTIONAL METAL LOSS : Apparent Erosion ( 24 %) Jt. 5 @ 217 Ft. (MD) Apparent Erosion ( 23 %) Jt. 3 @ 136 Ft. (MD) Apparent Erosion ( 23 %) Jt. 4 @ 149 Ft. (MD) Apparent Erosion ( 23 %) Jt. 7 @ 297 Ft. (MD) Apparent Erosion ( 22 %) Jt. 8 @ 340 Ft. (MD) 7 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. 1325 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS : Apparent Erosion ( 26 %) Jt. 61 @ 7,608 Ft. (MD) Apparent Erosion ( 25 %) Jt. 60 @ 7,569 Ft. (MD) Apparent Erosion ( 25 %) Jt.. 73 @ 8,131 Ft. (MD) Apparent Erosion ( 25 %) Jt. 54 @ 7,348 Ft. (MD) Apparent Erosion ( 25 %) Jt. 29 © 6,359 Ft. (MD) 9 325 INCH CASING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : Apparent Erosion ( 15 %) Jt. 52 © 7,278 Ft. (MD) Apparent Erosion ( 15 %) Jt. 53 @ 7,298 Ft. (MD) Apparent Erosion ( 15 %) Jt. 65 © 7,783 Ft. (MD) Apparent Erosion ( 15 %) Jt. 56 © 7,426 Ft. (MD) Apparent Erosion ( 15 %) Jt. 33 @ 6,509 Ft. (MD) 9,525 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the production casing logged. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: B. Rochin ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 555 -9085 Fax: (281) 565 -1369 E-mail: PDS ©memorylog.corn Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 PDS Report Cross Sections Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 47 ppf L -80 BTC -M Analyst: C. Waldrop Cross Section for Joint 53 at depth 7297.630 ft Tool speed = 52 _ Nominal ID = 8.681 Nominal OD = 9.625 Remaining wall area = 85% �` \:22 Tool deviation = 44° ��� I f \ / Finger = 25 Penetration = 0.089 ins Apparent Erosion 15% Cross - Sectional Wall Loss HIGH SIDE = UP • • rib PDS Report Cross Sections Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 47 ppf L -80 BTC -M Analyst_ C. Waldrop Cross Section for Joint 52 at depth 7277.780 ft Tool speed = 53 Nominal ID = 8.681 i Nominal OD = 9.625 \ / \ Remaining wall area = 85% �_ ''P l `` ,� Tool deviation - 44° � `. / 1 \� / ---.. \ \ \ \ r / 1 \ \ -, -- /7 Finger = 37 Penetration = 0.105 ins Apparent Erosion 15% Cross - Sectional Wall Loss HIGH SIDE = UP • • M. ' — PDS Report Cross Sections Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 47 ppf L -80 BTC -M Analyst: C. Waldrop Cross Section for Joint 60 at depth 7568.950 ft Tool speed = 52 Nominal ID = 8.681 - Nominal OD = 9.625 I Remaining wall area = 87% / ` , � Tool deviation = 49° ,� i \ ', // l :, 1 �:' - r I } i,-- � � \ r i /� Finger = 36 Penetration = 0.120 ins Apparent Erosion 0.12 ins = 25% Wall Penetration HIGH SIDE = UP • — PDS Report Cross Sections Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: _ _ 9.625 ins 47 ppf L -80 BTC -M Analyst: C. Waldrop Cross Section for Joint 61 at depth 7607.650 ft Tool speed = 49 Nominal ID = 8.681 Nominal OD = 9.625 Remaining wall area = 88% z ' — / /� �,,, Tool deviation = 49° `\ \ I I / <, \ / //� \ 1 . _____ ::--e\ ' i i 1 / i \tom / / I \ \, js Finger = 24 Penetration = 0.125 ins Apparent Erosion 0.13 ins = 26 °i° Wall Penetration HIGH SIDE = UP . • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 47.0 rapt L -80 BTC -M Well: GNI -02A Body Wall: 0.472 in Field: Prudhoe Bay Upset Wall: 0.472 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 8.681 in Country: USA Survey Date: September 23, 2011 Joint it. Depth Pen. p Pen. ! PenMetal Min. 1 Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 1 100 1 5189 0.09 ' 0.10 21 12 8.71 Apparent Erosion. 2 5233 0.09 1 0.11 ! 22 14 8.71 Apparent Erosion. 3 5274 0.09 0.11 22 1 13 8.72 Apparent Erosion. 4 5315 0.09 0.10 I 20 I 12 8.71 Apparent Erosion. 5 5354 0.08 0.11 ! 22 ! 13 8.70 Apparent Erosion. 6 5395 0.07 0.10 20 i 13 8.73 Apparent Erosion. 7 5436 0.07 0.09 19 i 12 8.70 ! Shallow App arent Erosion. 1 1 8 5476 0.07 0.09 19 13 8.71 Shallow Apparent Erosion. 9 5516 0.09 0.11 23 14 8.71 T Apparent Erosion. _ 10 5558 0.08 1 0.10 I 20 I 13 8.71 Apparent Erosion. r 11 5599 0.08 1 0.11 ! 22 14 8.74 ] Apparent Erosion. 12 5638 0.07 0.10 I 21 13 8.73 Apparent Erosion. 13 5676 0.09 0.11 1 23 13 8.73 Apparent Erosion. _ 14 5718 0.07 0.10 21 12 8.71 Apparent Erosion. 15 5760 0.08 0.10 I 21 _L 14 8.73 Apparent Erosion. _ 16 5800 0.08 0.11 22 ! 14 8.73 Apparent Erosion. 17 5841 0.11 0.12 24 13 8.692 Apparent Erosion. - 1 18 5883 0.08 1 0.11 23 12 8.71 Apparent Erosion. 19 5924 0.07 0.11 I 23 13 8.70 1 Apparent Erosion. 20 5964 0.09 0.11 ! 22 14 8.73 1 Apparent Erosion. 21 6004 0.08 0.11 I 22 13 8.71 Apparent Erosion. 22 6045 0.09 ! 0.11 ; 22 14 8.72 Apparent Erosion. ' 23 6085 0.11 0.12 1 25 j 14 8.71 Apparent Erosion. I 24 6127 0.09 0.11 I 23 14 8.72 i Apparent Erosion. i i 25 6166 0.08 � 0.10 21 13 8.73 1 Apparent Erosion. 1 I ; 26 6206 0.08 ! 0.10 21 13 8.74 Apparent Erosion. I ; 27 6246 0.07 j 0.10 20 I 14 8.73 Apparent Erosion. 28 6287 0.09 0.10 21 13 _._ 8.71 _ i _ Apparent Erosion. 29 6328 0.08 _ 0.12 ' 25 1 13 _ 8.70 Apparent Erosion. _ _ , 30 6369 0.10 0.12 24J 14 8.71 _. Apparent Erosion. i_ 31 6409 0.09 0.11 1 22 1 14 8.74 Apparent Erosion. 32 0.07 _L 0.10 20 I 14 8.70 i Apparent Erosion. 33 6488 0.11 0.11 22 15 8.75 I Apparent Erosion. 34 _ 6529 0.08 ! 0.11 _ L _ 22 14 8.72 1 Apparent Erosion. I ! 35 6571 0.09 0.10 20 1 13 8.73 Apparent Erosion. 36 6608 _ 0.08 0.10 2222 14 8.75 .4_.. Apparent Erosion. 37 6648 0.09 j 0.11 c 22 14 8.72 Apparent Erosion_ , ! j 38 6686 0.09 0.10 L 20 13 _ 8.73 _ Apparent Erosion. 39 6728 0.09 , 0.12 1 24 14 8.72 Apparent Erosion. 40 6767 0.08 0.11 22 ! 14 8.71 Apparent Erosion. 41 6808 0.10 1 0.11 1 23 1 15 8.74 Apparent Erosion. I 42 6848 0.09 1 0.11 22 1 14 8.72 1 Apparent Erosion. 43 6891 0.09 ! 0.10 21 13 8.73 ! Apparent Erosion. 44 6932 0.07 1 0.11 23 13 8.71 1 Apparent Erosion. I I 45 6968 0.09 0.12 24 14 8.73 ! Apparent Erosion. I ! j 46 7006 0.09 ' '1 0.12 ! 24 13 8.69 Apparent Erosion. j ; 47 7044 0.09 1 0.11 23 14 8.72 Apparent Erosion. 1 I 48 7083 0.10 0.11 23 14 8.73 Apparent Erosion. 1 _ 49 7122 _ _ 0.09 0.11 22 4 _ 14 8.72 _ Apparent Erosion. I 50 7165 0.08 , 0.10 ; 21 I 14 8.70 Apparent Erosion. ; 1_ �.11 I Penetration Body Metal Loss Body Page 1 • • PDS REPORT IOIINIT TABULATION SHEET Pipe: 9.625 in 47.0 ppf L-80 BTC -M Well: GNI -02A Body Wall: 0.472 in Field: Prudhoe Bay Upset Wall: 0.472 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 8.681 in Country: USA Survey Date: September 23, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset I Body ; % Loss I.D. I Comments (% wall) (Ins.) ' (Ins.) I % (Ins.) 100 0 50 51 7204 0.08 0.11 22 ' 15 8.73 I Apparent Erosion ---,TT-77 52 7245 0.10 0.12 24 { 15 8.73 Apparent Erosion _ I ' 53 7284 0.10 l 0.11 l 23 15 8.72 Apparent Erosion. j 54 7324 0.09 0.12 25 14 8.71 Avow- nt Erosion. I 55 7360 0.11 1 0.12 24 I 14 8.71 i Apparent Erosion. 1 56 7400 0.09 0.11 22 15 Apparent Erosion. 57 7441 58 7480 0.0 ' 0.10 20 13 8.72 Apparent Erosion. 59 7522 0.09 ,x 0.12 .24 i13 8.72 Apparent Erosion. 60 7564 0.09 0.12 25 14 - 8.72 Apparent Erosion. 61 1 4 8.70 Apparent Erosion. 7605 _ 0.08 0.13 � 26 � 62 7644 0.09 0.11 L 22 1 14 - 8.72 Apparent Erosion. I 63 7686 0.08 ,_ - 0.11 22 14 8.73 Apparent Erosion. _ 64 7727 0.07 _ 0.11 22 14 8.70 Apparent Erosion. _. 1 T _ 65 7768 0.09 1 0.11 �_23 15 8.72 Apparent Erosion. 66 7809 0.10 10.11_ 22 14 8.71 Apparent Erosion_ 67 7849 0.09 0.11 22 14 8.73 _Apparent Erosion. I 68 7889 0.09 0.11 23 12 8.70 Apparent Erosion. 69 7931 0.09 0.10 21 15 8.75 Apparent Erosion. 70 7969 0.09 1 0.11 22 I 13 8.72 Apparent Erosion. ' 71 8010 0.09 ! 0.12 ! 24 1 14 8.72 Apparent Erosion. 72 8051 0.07 0.10 21 i 13 8.73 I Apparent Erosion. j 73 8090 0.10 0.12 25 I 13 8.56 Apparent Erosion. Lt. Deposits. 74 _ 8132 0.08 0.11 23 1 11 8.51 I Apparent Erosion. Lt. Deposits. _ I I Penetration Body Metal Loss Body Page 2 • • - W PDS Report Overview . Body Region Analysis Well: GNI-02A Survey Date: September 23, 2011 . Field: Prudhoe Bay Tool Type: UW MFC XR 40 \lc 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 47 ppf L-80 BTC-M Analyst: C. Waldrop J , ' Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 9.625 ins 47 ppf L-80 BTC-M 8.681 ins 9.625 ins 6.0 ins 6.0 ins I Penetration(% wall) 1 Damage Profile (% wall) 1 80 r 1 i low Penetration body Metal loss body 1 I 1 0 50 100 60 _, 1 1 - — I 1 , 40 r — 1 11 1 ‘ I 1 20 Jill i 1 1 — r 1 0 1' i — I - 0 to 20 to 40 to over 21 = 1 ; 20% 40% 85% 85% , , . 1 Number of joints analysed (total = 74) 2 72 0 0 Ii , 31 . I --- — Damage Configuration ( body ) r 41 80 f -- 1 ..... i 1 — 60H 51 — 40 1 1 , — ---r. , r , i 1 . I 20 r i 61 — 0 L. I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole I 71 , , 1 _ _ 1 — _Number_oljoints_darnaged (total = 74)_ 0 0 0 74 0 Bottom of Survey = 74 • • Maximum Recorded Penetration Comparison To Previous Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Prev. Date: June 30, 2010 Company: BP Exploration (Alaska), Inc. Tool: UW MFC XR 40 No. 218451 Country: USA Tubing: 9.625" 47 Ib L -80 BTC -M Overlay Difference Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) 0 100 200 300 400 -100 -50 0 50 100 1 I 1 1 11 ' 11 21 �� I 21 31 �� + 31 E E z z 41 1 '0 41 51 51 • I 61 = 61 71 = 71 -81 -41 0 41 81 ■ September 23, 2011 ■ June 30, 2010 Approx. Corrosion Rate (mpy) ! • PDS Report Cross Sections WeII: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7 ins 29 ppf L -80 BTC -M Analyst: C. Waldrop Cross Section for Joint 3 at depth 135.990 ft Tool speed = 51 Nominal ID = 6.184 Nominal OD = 7 ` .- Remaining wall area = 77% \ ,`��' f ‘\, Tool deviation = 0° _y \ / / '*. \\ ', \ A _ \ . - „ , ,.-- , • , „ 1 ,. 4 ,,, , , . ' u . :,:, i / zi , ,..."04.7./:, i 1 / i� Finger = 27 Penetration = 0.118 ins Apparent Erosion 23% Cross - Sectional Wall Loss HIGH SIDE = UP i • PDS Report Cross Sections Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7 ins 29 ppf L -80 BTC -M Analyst: C. Waldrop Cross Section for Joint 5 at depth 216.680 ft Tool speed = 48 _ Nominal ID = 6.184 -- Nominal OD = 7 �� Remaining wall area = 76% \ i / \ Tool deviation = 0° ■ , i / / v\ \ 7 1_ _ _ / //' / \ \ �� Finger = 36 Penetration = 0.113 ins Apparent Erosion 24% Cross - Sectional Wall Loss HIGH SIDE = UP • PDS Report Cross Sections Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: _ 7 ins 29 ppf_ L -80 BTC -M Analyst: C. Waldrop Cross Section for Joint 3 at depth 116.130 ft Tool speed = 56 Nominal ID = 6.184 Nominal OD = 7 Remaining wall area = 77% K '��` Tool deviation = 0° !� / 7 \ \ \, ,\ ,.-----'\ \ \ i i r Y l p � �� Finger = 26 Penetration = 0.133 ins Apparent Erosion 0.13 ins = 33% Wall penetration HIGH SIDE = UP • 0 A .:;:i:3 PDS Report Cross Sections Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7 ins 29 ppf L -80 BTC -M Analyst: C. Waldrop Cross Section for Joint 13 at depth 542.540 ft Tool speed = 56 - -- Nominal ID = 6.184 Nominal 7 ' - 7L-__---- Remaining g w wall area = 78% I 1 ! Tool deviation = 0° \ � �,� � I / ! � 7.. � / . �/ / / / - \\ \ ' 4 1 1 t d t /?f . • , / - Finger = 26 Penetration = 0.133 ins Apparent Erosion 0.13 ins = 33% Wall penetration HIGH SIDE = UP • • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 29.0 ppf L -80 BTC -M Well: GNI -02A Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: September 23, 2011 Joint Jt. De th Pen. Pen. Pen. Metal Min. : Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments 1 (% wall) (Ins.) ' (Ins.) I % (Ins.) ' 0 50 100 50 2002 0.10 0.12 29 19 6.26 ' Apparent Erosion. i �, � 51 2043 0.09 0.10 I 24 19 6.27 i Apparent Erosion. 52 2083 0.1 0. 13 I 31 19 6.24 I Apparent Erosion. 53 2124 0.10 0.11 i 26 16 6.23 Apparent Erosion. 54 2164 _ 0.09 1 0.11 1 26 16 6.25 ! Apparent Erosion. 1 I 1 55 _ 2203 0.10_1 0.11 28 I_ 19 6.27 Apparent Erosion. 56 _ 2244 0.11 0.11 28 ; 19 6.23 ! Apparent Erosion. , � 57 2284 0.10 0.11 26 16 6.25 Apparent Erosion. 58 2324 0_11 0.11'28 1 18 6.25 Apparent Erosion. 59 2365 0.11 0.11 26 18 6.23 Apparent Erosion. 60 : 2405 0.10-f 0.10 25 15 6.24 L Apparent Erosion. _ L 61 2445 0.10 0.10___24 : 15 6.21 t Apparent Erosion. 62 2485 0.10 ( 0.12 29 18 6.22 Apparent Erosion. 63 2526 0.09 0.09 23 15 6.21 Apparent Erosion. 64 2567 0.10 0.11 28 18 6.23 Apparent Erosion. 65 2608 0.09 j 0.10 24 _ 15 6.24 Apparent Erosion. 66 2648 0.10 +0.10 _, 25 15 6.25 1 Apparent Erosion. 67 2688 0.10 ' 0.11 28 17 6.22 Apparent Erosion. 68 2729 0.09 0.10 25 15 6.23 Apparent Erosion. 1 69 2770 0.10 0.11 26 I 18 6.23 Apparent Erosion. 70 2810 0.09 1 0.09 23 15 6.24 Apparent Erosion. 71 2851 0.11 i 0.12 29 18 6.24 1 Apparent Erosion. 72 2892 0.09 0.10 25 17 6.25 Apparent Erosion. 73 2933 0.09 0.11 28 17 6.25 Apparent Erosion. I (, 74 2973 0.10 0.10 25 14 6.23 Apparent Erosion. ! 75 3014 0.09 0.10 25 16 6.24 1 Apparent Erosion. 76 3055 0.09 1 0.09 23 14 6.24 1 Apparent Erosion. I 77 _ 3096 0.10 0.11 26 1 17 6.24 Apparent Erosion. 78 - 313 7 0.10 _ 1 0.10 25 1 14 6.22 - Apparent Erosion. i _ 79 3178 0.10 0.10 25 I 17 6.23 A parent Erosion. 80 3219 O.090.09 1 22 13 6.20 Apparent Erosion. ! 81 3259 0.091 0.10 f 25 17 6.25 T Apparent Erosion. 82 3300 0. 09 ! 0.09 22 I 13 6.21 Apparent Erosion. 83 3341 0.10 0.10 1 24 17 6.24 I Apparent Erosion. t 84 3381 0.08 0.08 ' 20 14 6.23 Apparent Erosion. � , 85 3460 0.09 0.09 22 Apparent Erosion. I I _ 3420 0.09 _ 0.09 i 23 15 6.23 86 2? L 14� 6.19 Apparent Erosion. 87 3501 _ 0.08 0.09 22 , 13 6.23 Apparent Erosion. ' I 1 88 3542 0.09 0.09 22 ' 13 6.20 ! Apparent Erosion. j ' 89 3583 0.08 0.10 24 ! 16 6.22 Apparent Erosion. + j 1 90 3624 0.08 0.10 24 16 6.23 Apparent Erosion. i ! 1 91 3664 0.08 ! 0.09 23 1 16 6.24 I Apparent Erosion. 1 1 1 92 3705 0.09 ' 0.09 1 23 16 6.21 Apparent Erosion. ` 1 93 3746 0.10 0.10 23 15 6.23 1 Apparent Erosion. 94 3786 0.08 0.09 23 15 6.24 Apparent Erosion. • I ! 95 3826 0.09 0.09 1 23 15 6.21 ! Apparent Erosion. ; I 96 3867 0.09 0.09 1 23 16 6.23 Apparent Erosion. I i . � 97 3908 0.09 ■ 0.10 25 14 6.23 Apparent Erosion. 98 _ 3948 0.08 ! 0.08 I ..20 1 13 6.21 _ Apparent Erosion. 99 __- 3989 1 0.08 1 0.10 24 ._.15 _ 6.24 Apparent Erosion. __- L_I ,i _ __L _ L, Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 7 in 29.0 ppf L -80 BTC -M Well: GNI -02A Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: September 23, 2011 Joint Jt. Depth Pen. Pen. r Pen. Metal Min. Damage Profile . No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 10 50 100• 100 4030 0.08 0.09 22 15 6.24 ' Apparent Erosion. : TT T H 101 4070 0.08 ; 0.08 , 20 13 6.21 ' Apparent Erosion. 102 411 1 0.09 1 0.09 22 12 6.21 i Apparent Erosion. , 103 4151 0.07 1 0.08 20 12 6.21 Apparent Erosion. I i 104 4192 0.08 0.10 24 t 15 6.21 i Apparent Erosion. • 105 4233 0.07 0.08 L 20 13 6.21 i Apparent Erosion. _ 1 I ' 106 4273 0.08 0.08 20 _,_. 12 6.19 _! Apparent Erosion. j_107 4314 _0.09 0.09 i 22 L _13 6.21 Apparent Erosion_ _ . 108 4355 0.09 0.10 i 23 ! 15 6.23 Apparent Erosion -_ • 109 .__ 4396 0.07 0.08 I 20 _.. 6.19 _ I - Apparent Erosion. 110 4436 0.08 0.10 24 � 15 _ 6.22 _ I Apparent Erosion. 111 4477 0.08 0.08 1 20 12 6.20 1 Apparent Erosion. 112 4517 0.08 0.08 1 20 12 6.21 1 Apparent Erosion. _ I j 113 4558 0.08! 0.08_ 20 I 12 6.19 Apparent Erosion. 1 .08 T0 . 09 ' 22 12 6.20 A Erosion. 114 _ 4548 0.08 14 6.23 Apparent Erosion. 1 115 4639 _._ 0.07 116 4680 0.08 ' 0. � _� pa 117 4720 0.08 { 0.08 20 12 6.21 I Apparent Erosion. 118 4761 0.07 0.08 i 20 12 6.20 Apparent Erosion. 119 4800 0.08 1 0.08 i 20 12 6.21 I Apparent Erosion. ' I 120 4841 0.09 0.09 23 1 15 6.21 I Apparent Erosion. • I I 1 121 4881 0.08 0.08 ! 20 12 6.19 Apparent Erosion. . 122 4922 0.08 0.08 ; 20 12 6.21 Apparent Erosion. 123 4960 0.08 j 0.09 23 14 6.23 Apparent Erosion. I 124 5001 0.08 0.09 23 14 6.22 I Apparent Erosion. e 125 5042 0.09 ! 0.09 ! 2 13 6.22 A..arent Erosion. I 1 126 5082 0.07 0.08 19 12 6.21 I Shallow App arent Erosion. 1 126.1 5123 0.08 0.09 22 ! 13 6.23 i Pup Apparent Erosion. 126.2 5133 0_ _ 0 0 0 5.98 7" HES R Nipple 126.3 5134 0.08 1 0.08 20 _ 13 6.20 Pup Apparent Erosion. 126.4 _ 5144 _ 0.10 0.09 22 14 6.23 Pup Apparent Erosion. ' 126.5 5154 0 0 0 , 1 0 6.09 9.625" x 7" Baker S 3 Packer I 8 I „ 126.6 5159 0.07 0 11 6.21 i Pup Shallow Apparent Erosion. - I ( 1 I _ 126.7 5168 0.08 0 0 09 , 22 _ 13 6.22 I Pup Apparent Erosion. ■ 126.8 5178 0 _ ! 0 ' 0 5.98 7" HES R Nipple 1 126 99 _ 5179 Q09 1 0.09 22 14 6.24 Pup Apparent Erosion. __ I ! l 127.1 5189 0 -i 0 _ 0- 0 6.29 1 7" WLEG - - - - - , Penetration Body Metal Loss Body Page 3 • ! PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 29.0 ppf L -80 BTC -M Well: GNI -02A Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: September 23, 2011 Joint Jt. Depth Pen. Pen. Pen. ;Metal Min. Damage Profile No. (Ft.) Upset Body % ■ Loss I.D. Comments (% wall) (Ins.) (Ins.) 1 % (Ins.) � 0 50 100 ' 0.1 15 0.13 0.12 30 . 21 6.29 Pup Apparent Erosion. 1 19 0.11 0.12 30 22 6.28 Apparent Erosion. 2 62 0.11 1 0.12 30 22 6.29 Apparent Erosion. 3 104 0.12 0.13 33 23 6.29 I Apparent Erosion. • i 4 144 0.12 0.13 31 23 6.30 Apparent Erosion. 5183 0.12 0.13 31 24 6.31 Apparent Erosion. 6 __224 0.10 0.12 29 22 6.30 Apparent Erosion. _ 1 7 266 0.11 0.13 ! 31 L 23 6.30 _! Apparent Erosion. 8306 0.12 0.13 ' _ 31 _ _ 6.29 i Apparent Erosion.___ 9 347 0.11 1 0.12 30 L _.. 22 _ _ 6.29 Apparent Erosion. 10 -- 386 0.13 0.12 t 30 I 22 6.28 __4 Apparent Erosion. 11 , , 1 , , 428 0.11 0.12 30 ! 22 _ 6.2 Apparent Erosion. __ _ 12 468 0.10 0.12 29 21 6.28 Apparent Erosion. ; L 13 __. 508 0.12 0.13 33!22 6.28 ! Apparent Erosion. _ 14 548 0.11 ; 0.13 31 22 6.28 � Apparent Erosion. 15 ._ _ 588 0.11 0.12 30 21 6.28 i _ Apparent Erosion. 1 . 16 629 0.12 0.13 31 22 6.29 J Apparent Erosion. 1 - 17 669 0.11 0.12 1 29 ' 22 6.29 Apparent Erosion. j j 18 710 0.11 . 0.12 29 21 6.28 Apparent Erosion. i 1 ; 19 748 0.11 1 0.12 30 21 6.29, Apparent Erosion. j 1 20 789 0.11 0.11 28 22 6.31 Apparent Erosion. I 21 828 0.10 '! 0.12 29 1 21. 6.28 Apparent Erosion. N 1 ' 22 867 0.11 1 0.12 30 22 6.27 Apparent Erosion. 23 908 0.11 ' 0.13 31 22 6.28 A..arent Erosion. 24 947 0.11 0.11 I 26 21 6.29 Apparent Erosion. 25 988 0.11 0.12 30 1 22 6.30 i Apparent Erosion. • 26 1029 0.11 0.12 30 j 21 6.29 � Apparent Erosion. . 27 1068 0.11 0.12 30 , 21 6.28 J Apparent Erosion. 28 1109 0.120.13 31 22 6.30 Apparent Erosion. 29 1151 0.11 ' 0.12 1 29 21 6.28 Apparent Erosion. I . 30 1191 _ 0.11 0.11 28 21 6.27 Apparent Erosion. __ - - -- r 1 31 _ . 1232 0.11 : 0.12 j 29 22 6.28 i Apparent Erosion. - __ 32 1273 0.11- 0.12 29 x 6.27 ) Apparent Erosion. I 1 I 33 1314 0.11 0.12 29 20 i Apparent Erosion. i 34 1354 0.11 0.12 29 21 6.29 Apparent Erosion. _ 1394 _ 0.10 0.11 1 28 20 ! ' 1 35 6.28 Apparent Erosion. I , 36 __.. 1435 0.10 0.12 ' 29 ; 21 6.27 i Apparent Erosion. ; ; 1 37 1475 0.11 1 0.12 29 20 6.27 Apparent Erosion. 38 1516 0.11 0.11 1 28 ' 19 6.27 ! Apparent Erosion. 39 1557 0.10 ! 0.11 28 20 6.27 Apparent Erosion. I 1 40 1598 0.11 1 0.12 I 29 1 21 6.28 ! Apparent Erosion. I I 41 1639 0.11 0.12 30 ' 20 6.27 1 Apparent Erosion. 42 1679 0.10 0.11 26 ' 19 6.29 : Apparent Erosion. 43 1721 0.12 0.11 28 21 6.28 I Apparent Erosion. 1 44 1761 0.10 0.12 29 19 6.25 1 Apparent Erosion. 45 1800 0.10 0.11 i 26 1 19 6.27 Apparent Erosion. i 1 46 1841 0.09 0.11 26 20 6.29 Apparent Erosion. 47 1882 0.10 0.12 29 19 6.26 Apparent Erosion. 0.1 48 1923 _ _ _ _ 0.11 J _ 28 . 19 6.26 _ Apparent Erosion. _ - - , I 49 1964010i0.12 29 18 - __ - 6.25 par _ x Apent Erosion. - L 1_ i_ I Penetration Body Metal Loss Body Page 1 • • PDS Report Overview T1 Body Region Analysis Well: GNI -02A Survey Date: September 23, 2011 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing_ 7 ins 29 ppf L -80 BTC -M Analyst: C. Waldrop__ — Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 1 7 ins 29 ppf L-80 BTC -M 6.184 ins 7 ins 6.0 ins 6.0 ins __ Penetration(% wall) Damage Profile (% wall) 1501 1 Penetration body Metal loss body j 0 50 100 . 100 - 50 --1 — 0 I l ! 0 to 20 to 40 to over 1 20% 40% 85% 85% I Number of joints analysed (total = 13 __ -_� I I I. 50 1 2 131 0 0 1 - I - - Damage Configuration ( body) 1 - 150 ,i = - 1 1 100 = 1 I - H HH H 50 H I --H lc j I o — 1 = 1 ! I Isolated General Line Other Hole / — Pitting Corrosion Corrosion Damage Pos. Hole I = 1 I Number of joints damaged(total = 133 _ - -- i I 0 0 0 133 0 Bottom of Survey = 127.1 i • Maximum Recorded Penetration Comparison To Previous Well: GNP 24 A Survey Date: September 23, 20 Field: Prudhoe Bay Prey. Date: June 30, 2010 Company: BP Exploration (Alaska), Inc. Tool: UW MFC XR 40 No. 218451 Country: USA Tubing: 7" 29 b@aneGM Overlay Difference _ ) ! ! Max. mcP�� ¥ ) i �..M�P�� m I 0 100 200 300 400 | 400 -50 0 50 100 &, ! - 1 { 1 . i 1 10 1, 10 i / 3- I 20 . ! 1 H , 2 ] ! 3 . ] ! ! ! | , «: ) | } ] � � 1 ] \ t . co 1 : } Z 7 ° ! 70 ] } lz I m | | £ : _ | 90 1 « ! ) ƒ ,m . ! !m ; : | } 20 - 0 } \ , l : gQ { ! l ] $ . l . 120 1 ] 120 H ) 126.4 ) { | - ,26 4 1 71 | } -81 -41 0 q 81 | } .s September 23,2u .June 3m 2010 Approx. c Rate 1 • • Correlation of Recorded Damage to Borehole Profile I Pipe 1 7. in (14.9' - 5189.4') Well: GNI -02A Pipe 2 9.625 in (5189.4'- 8131.6') Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: September 23, 2011 Approx. Tool Deviation ■ Approx. Borehole Profile 1 19 25 — 988 50 2002 75 3014 100 ' 4030 E v 125 5042 a v 1 5189 25 6166 50 I 7165 ' I 74 8132 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 74 • TREE = FMC -. SAFETY N : KNOWN AS 4 -62 IN PBAS . 3/8" SS I WELLHEAD = FMC CONTROL LINE STRAPPED TO TOP 1000' OF 7" TBG. ACTUATOR = BAKER C KB. ELEV = 55.2' I i BF. ELEV = 20.9' ' 1 1 KOP = 2832' i Max Angle = 51 @ 7604' C I Datum MD = 8322' ( < I ; ' Datum TVD = 6000' SS . 1 { I 1000' I-I 3 -8" SS CONTROL LINE STRAPPED TO 7" TBG I Minimum ID = 5.963" @ 5132" 7" HES "R" NIPPLE MILLOUT WINDOW (GNI-02A) 2832' - 2864' I 2897' H9-5/8" HES CEMENTER 1 a 5132' I-17" HES "R" NIP, ID = 5.963" I 13 -3/8" WHIPSTOCKI --I 2832' I 5153' —19-5/8" X 7" BKR S -3 PKR, ID = 6.00" I 5177' H 7" HES "R" NIP, ID = 5.963" I • %16" 1 ♦ 113 -3/8" EZSV H 2866' 5189' I- 7" WLEG, ID= 6.184" / r 13 -3/8" CSG, 72 #, L -80, ID = 12.347" - I 3794' I— XO TO 54.5 #, K -55, ID = 12.35" 113 -3/8" CSG, 54.5 #, K -55, ID = 12.35" H 4137' I PERFORATION SUMMARY I REF LOG: SLB USIT /CBL ON 12/08/06 7" TBG, 29 #, L -80, BTC-M, -I 5189' I ANGLE AT TOP PERF: 48 @ 8146' .0371 bpf, ID = 6.184" Note: Refer to R DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 4-1/2" 5 8146 - 8166 0 12/25/06 19 -5/8" CSG, 47 #, L -80, BTC-M, ID = 8.681" I-I 8414' I P i �i �i �i i �i �i� i i i DATE REV BY COMMENTS l DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/13/98 ORIGINAL COMPLETION j 12/25/06 RRD /PAG INITIAL PERFORATIONS WELL: GNI -02A 12/10/06 D14 SIDETRACK "A" ! 07/28/10 ?/ PJC WELLHEAD CORRECTION PERMIT No: 7 2061190 10/30/06 JMF /PAG CIBP / TBG PUNCH / CHEM CUT ; 12/12/10 JNL /PJC SECTION LOCATION UPDATE API No: 50- 029 - 22851 -01 11/05/06 SKB /TLH WAIVER SFTY NOTE DELETED SEC 26, T11 N, R15E, 982' FNL & 681' FEL 11/06/06 DSM/TLH TREE/WH CORRECTIONS 12/14/06 JGR/PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • GNI Area Type Loa GNI -02 Marker TVD GR ss r.- .Perm:. 10 ° °" 110_ 1 mid. 500 S = Shallowest Permitted Class II 4000 = Fluid Injection Interval -4100 - 4 = -4200 = S _ -4300 = -4400 _° Shallowest Permitted Class II -4500 - _- . I N . E 4600 = — Slurry Injection Interval - a7oo ` SV1 ,,_ - - - ,_ E_ 4800 -- -- _ -4900 -- .. - GNI area shallowest possible fracture - _ _ -5000 4 a�, growth based on fracture modeling L--' U 4 - -5100 UG4A -- - -5200 -5300 -5400 �— �. -5500 — . ,. - -5600 �-- GNI area wellbore fracture height UG3 _ growth based on pressure falloff ,, _-_ _ -5700 E tests -5800 F— Shallowest GNI -02A MDT pressure - -5900 s interval where formation pressures were elevated above hydrostatic - = = -6000 -- GNI area near wellbore fracture height 6100 ` * growth based on shut in temperature UG1 - - - -6200 7 ! _ logging - = -6300 _ :1 - M B2 . - i:: 0 . _ 0 =_ Target Slurry _t MC s - = Injection Interval NA — � _ -6600 __ NB = _67 °° Projected TD of GNI -04 well WS1 /O Sds! _ - 6800 1 6600 CM3 Marker: Base of Permitted Class II Slurry Injection Interval Below GNI Well TDs (Projected at -6975' TVDSS in GNI -04 area) • • WELL LOG TRANSMITTAL I ,. PROACTIVE DAAGNOSTC SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerha s LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 # /‘-1? 1) Temperature Survey 29 -Jun -11 GNI -03 1 BL / 1 CD 50- 029 - 22820 -01 2) Signed : '2.1(2)14,j, Date : 3 1 al Z.e ( ( Print Name: hew 6 +► e_ k L PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E-MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives1Dishibution \TransmittalSheets\BP Tiansmit.docx / ct 7 - / •& 9 • • WELL LL TRANSMITTAL PRoAcrivE Diag nostic SERVicES, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 SEP C! y 20L and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Temperature Survey 09-Jul-11 GNI -04 1 BL/ 1 CD 50- 029 - 23267 -00 2) Temperature Survey 29- Jun -11 GNI -03 -1 BL/ 1 CD 3 50- 029 - 228200' I 4IK Signed : ( -\ Date : 3t ( Print Name: k\ "` L PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E -MAIL : PDSANCHORAGE(5 MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmit.docx bp Certified Mail # 7011 0110 0000 4759 1821 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 e , x ;r (907) 561 -5111 ;. . July 28, 2011 r''"+ia JUL 2 9 2011 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle WA 98101 RE: Demonstration of Mechanical Integrity, Prudhoe Bay Grind and Inject, UIC Class I Permit AK- 11008 -A Dear UIC Manager: INCJ�;� This letter is to submit the results of a recent tubing inspection logs and fluid movement tests in UIC Class I wells GNI -03 and GNI -04 located at the Prudhoe Bay Grind and Inject project operated by BP Exploration (Alaska), Inc (BPXA). The tests are specified as part of the demonstration of mechanical integrity under Part II, C.3 b of EPA UIC Class I permit AK11008 -A. The enclosed descriptive and interpretive report contains the results for the following logs and tests as required under Part II, C.3.c(1) of the permit: - Tubing Inspection Log: GNI -03, GNI -04 (Page 16, Part II, C.3.b(3)) GAIN. \ T‘Q\ - Fluid Movement Test: GNI -03, GNI -04 (page 16, Part II, C.3.b(2)) There was no indication of a loss of well integrity. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564 -4692. Sincerely, .#eAtA-4-e-C-L Katharine Fontaine Logistics /Infrastructure Manager Attachments • • UIC Manager July 28, 2011 Page 2 cc: Thor Cutler, EPA Region 10 (letter and report) Talib Syed, EPA Consultant (letter and report) Jim Regg, AOGCC (letter and report) Shawn Stokes, ADEC (letter and report) MINIM . . UIC Manager July 28, 2011 Page 3 Bcc (electronic): (Letter and report) M. Bill MB 7 -5 A. Cooke MB 11 -6 R. Daniel MB 7 -5 J. Murphy /M. Vazir PRB 24 T. Winkel /A. Reyes PRB 42 Compliance Matrix Administrator Bcc: ANC File 1007.02.03 • • UIC Manager July 28, 2011 Page 4 Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project EPA permit AK- 1I008 -A effective 09/01/07 requires a tubing inspection log in the Prudhoe Bay Unit Class I Grind & Inject wells each calendar year. Approved tubing inspection logs (Part II C 3 b (3)) include pipe analysis logs, caliper logs or other equivalent tests. Below are the results of logs run recently in well GNI -03. Tubing Inspection Logs A 40 arm caliper logging tool, supplied by PDS (ProActive Diagnostic Services), was run on slickline to inspect the interior surface of both the tubing and the casing. A memory caliper log was run in well GNI -03 on June 29, 2011. The tubing inspection indicated the GNI -03 tubing is in good condition with no significant erosion/corrosion. The tubing was replaced during a workover in December 2009. The casing below the tubing tail is in fair to poor condition. A memory caliper log was run in well GNI -04 on July 11, 2011. The tubing inspection indicated the GNI -04 tubing is in good to fair condition with maximum wall penetration up to 33% and cross sectional metal loss up to 15 %. The tubing was new when the well was completed in January 2008. The casing below the tubing tail is in fair condition. Below are the observed maximum metal losses observed in the tubing and casing from the caliper log. Well Date Maximum Pit PenetrationMax Cross - Sectional Wall Loss GNI -03 Tubing 06/29/11 19% 4% GNI -03 Casing 06/29/11 52% 24% GNI -04 Tubing 07/11/11 33% 15% GNI -04 Casing 07/11/11 30% 15% Enclosed are copies of the PDS Memory Multi- Finger Caliper, Log Results Summary for these wells. • • UIC Manager July 28, 2011 Page 5 Fluid Movement Tests The GNI wells normally inject cold slurry or cold water at 50 -70 degrees F. The original formation temperature of the target disposal formation was about 115 deg F. The Shut -In Temperature log technique is commonly used for cement channel detection in injection wells on the North Slope of Alaska and has been used to satisfy the GNI fluid movement test requirement as a demonstration of mechanical integrity. A shut -in temperature log was run in Grind & Inject well GNI -03 on June 29, 2011. GNI -03 was shut -in for 12 days prior to running the log. A shut -in temperature log was run in Grind & Inject well GNI -04 on July 9, 2011. GNI -04 was shut -in for 11 days prior to running the log. Wellbore temperatures are affected by the temperature of the injected fluids by conduction or convection. When the well is injecting fluids, the wellbore and the adjacent formation reaches a temperature near the injection fluid temperature due to conductive heat transfer. When injection ceases, the wellbore temperature begins to return toward its original temperature. The rate of temperature change of the shut -in well will depend on the original formation temperature, the injection fluid temperature and the rate and cumulative volume of injection. In the G &I wells, the injected fluids are colder than the formation temperatures below about 4000 ft TVD. In areas where the injected fluids enter the formation, both conduction and convective heat transfer are involved. The amount of rock cooling is much larger and the rate of temperature change after shut -in will be much slower due to the direct contact of the formation with the cold fluid. Channeling adjacent to the wellbore is evident because cooler injected fluids leak off into formations throughout the length of the channel. Several types of logging tools are available to be used to record the temperatures of the wellbore fluids: tools run on electric line with a real -time surface readout and memory tools run on slick line. The results from these instruments are presented in the enclosed logs of borehole temperature and pressure versus measured depth. Shut -In Temperature Survey Procedure - EPA permit AK- 1I008 -A requires tracer surveys to "... be conducted at injection pressure at least equal to the average continuous injection pressure observed in the previous 6 months." Injection is cycled into the GNI wells on a rotating basis, with one well injecting at a time. The average and maximum injection pressures are reported quarterly on Form 7520 -8. - Average daily injection pressure in well GNI -03 over the 6 months prior to its survey was 1169 psi. Average daily injection pressure in well GNI -04 over the 6 months prior to its survey was 1370 psi.Average wellhead injection pressures exceeded this pressure during the injection cycle completed prior to this survey. - The survey procedure involved the following steps: Inject a significant volume of cold water or slurry at the required pressure. Shut -in and freeze protect the well after an injection cycle. After at least 5 days, rig up logging tools and pressure test lubricator. Confirm depth control by comparing to the tie -in log on record. Run the shut -in temperature /pressure survey. Rig down and move off. - Compare the logged temperatures to previous shut in logs run in the well. UIC Manager July 28, 2011 Page 6 GNI -03 Shut -In Temperature Survey Results — reference PDS GNI -03 Temperature Log (UMT- CCL- Press - Temp), 29- June -11. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: casing collar locator, temperature and pressure. The last injection cycle before logging took place between 06/03 and 06/17/11. The shut -in temperature trace indicates uniformly increasing temperature with depth to about 6750 feet measured depth (MD) or 6124 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 6950 feet MD or 6291' TVD. Below that point, the temperature declined until the fill level was reached within or just above the perforated interval. Based on this data, there is no evidence of injected fluid movement above about 6100' TVD, and little or no movement above 6300' TVD. A plot of the temperature log data from 2011 along with other GNI -03 logs is shown below. GNI -03 Shut In Temperature Logs ,3p • +'etta7Jewetry - ^ - 86195 Baseline . • 0622105 5 day Si • 06291055 day St '10 • 06706+07 72day SI • 06720108 lday SI, Cab Shdt 'cc • 06715709 7 day SI 07':1/10 9 day Si •t.y • 06237[[ 12 du • _ �*.! •• a. • 4 • • s 1.fff • • Z: iT 70 •wf11;i $4!.•• • 50 4000 4500 5000 5500 00-00 6600 7000 True Vertical Depth feet GNI -04 Shut -In Temperature Survey Results — reference PDS GNI -03 Temperature Survey (UMT -CCL- Press - Temp), 09- July -11. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: casing collar locator, gamma ray, temperature and pressure. The last injection cycle before logging took place between 06/17 and 06/28/11. • ! UIC Manager July 28, 2011 Page 7 The shut -in temperature trace indicates uniformly increasing temperature with depth to about 6650 feet measured depth (MD) or 6041 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 6850 feet MD or 6218' TVD. Below that point, the temperature declined until the fill level was reached within or just above the perforated interval. Based on this data, there is no evidence of injected fluid movement above about 6040' TVD, and little or no movement above 6200' TVD. A plot of the temperature log data from 2011 along with other GNI -04 logs is shown below. GNI-04 Strut in Temperature Logs 130 i - A FerWewelry — #4 112208 I3L 120 — x - 114 4x2108 8L — 4r - 14 1/27/09 11daSI • 114 6/12;169daSI • #4 116911111deS1 110 10o s I 90 s 12 \I 80 � � R ! E It! ! • , a• •• 70 4a ! O 6 !•6 60 ■ ■ —a ! 4000 4500 5000 5500 6000 8500 7000 True Vertical Depth feet Overall Conclusions The GNI -03 caliper log indicates the tubing has no significant erosion/corrosion damage and is suitable for continued injection. The GNI -03 shut -in temperature log indicates no movement of injected fluids above 6100' TVD. The GNI -04 caliper log indicates the tubing has maximum penetration of 33% but it is suitable for continued injection. The GNI -04 shut -in temperature log indicates no movement of injected fluids above 6040' TVD. Michael L. Bill, P.E. July 14, 2011 by • • 4 BP Exploration (Alaska) Inc. i 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561 -5111 November 15, 2010 Nib Commissioner Dan Seamount, Chairman"'a�e Alaska Oil & Gas Conservation Commission` ' 333 West 7' Avenue, Suite 100 Anchorage, Alaska m 99501 SQ Reference: Grind & Inject Project Annual Performance Report �>nc�aca�a Dear Mr. Seamount: X-r' �� Enclosed is the Annual Performance Report for waste slurry injection for the Grind and Inject project located near Drill Site 4 in the Prudhoe Bay Unit. This report is submitted to satisfy the requirements of Area Injection Order #4E, Rule 10, as modified by Administrative Approval No. AIO 4C.001 and an Erratum Notice dated July 17, 2009. This requirement is very similar to an EPA report requirement regarding Prudhoe Bay Unit UIC Class I injection wells contained in EPA permit AK- 11008 -A. The report covers the period from October 1, 2009 through September 30, 2010 and was structured to satisfy both the AOGCC and the EPA requirements. Should you have questions concerning the contents of this report, contact me at 564 -4692. Sincerely, Q.^ Michael L. Bill Senior Staff Engineer Cc: A. Cooke MB 11 -6 M. McAnulty 2236, 3000 C Street C. Burgh MB 11 -6 H. Engel MB 7 -5 K. Fontaine MB 11 Harrington /Cantrell PRB 42 B. Collver PRB 42 Fagerland /Gogart PRB 42 Winkel /Reyes PRB 42 Well Integrity Coordinator PRB 7 S. Kenshalo, ConocoPhillips P. Bennett, ExxonMobil I • • Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class I Permit AK-1 1008-A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2009 through September 30, 2010 I This Annual Performance Report documents waste slurry injection on the Surfcote Pad near Drill Site 4 in the Prudhoe Bay Unit for the period October 1, 2009 through September 30, 2010. This report is submitted to satisfy the requirements of both EPA UIC Class I permit AK- 11008 -A, Part II 3 c 7 and AOGCC Area Injection Order (AIO) #4E, Rule 10, as modified by Administrative Approval AIO 4C.001 and Erratum Notice dated July 17, 2009. Additional information requested in a letter from the AOGCC (Regg to Bill 12/22/03) is also included. The report contains a brief description of the current project status, a summary of the disposal well performance data acquired during this period and operational plans for the next year. Project Status The Grind & Inject (G &I) Project at the Surfcote pad was undertaken in 1998 by the owners of the Prudhoe Bay Unit, Initial and Lisburne Participating Areas, and the Kuparuk River Unit to dispose of drilling muds and cuttings stored in reserve pits. Other non - hazardous wastes processed through the G &I Plant included those referenced in AIO #4E, Rule 2 as Class 11 wastes, consisting of RCRA- exempt drill cuttings and oily solids from pipeline pigging, vessel cleanouts and well workovers, and RCRA- exempt liquid wastes such as used drilling mud from on -going North Slope drilling operations. EPA issued Class I UIC permit AK- 11008 -A for the Grind & Inject Project effective September 1, 2007. Authorizations to inject Class I substances were received on January 18, 2008 for wells GNI -02A and GNI -03 and on May 6, 2008 for GNI -04. Well GNI -01 remains a Class 11 only disposal well. All non - hazardous wastes injected for disposal in the GNI wells during the report period are within the description of wastes referenced in EPA UIC Class I Permit AK- 11008 -A, Part 11 C 3 7, the UIC Class I permit application, or in Area Injection Order 46, Finding 7 as incorporated in AIO #4E. Several lined pits comprising the "material transfer station" (MTS) at DS 4 were operated to temporarily hold ongoing drilling and oily solids when necessary. On an infrequent basis, flow back liquids from new wells drilled with oil -based mud (OBM) or other wastes were injected directly into G &I wells using temporary equipment staged on the Surfcote pad. As of September 30, 2010, project injection has included 41.8 MM barrels of water, 81.4 MM barrels of slurry containing 5.1 MM tons (5.6 MM cubic yards) of excavated reserve pit material and other waste solids, and 5.9 MM barrels of fluid from ongoing drilling operations. Exhibit 1 summarizes this data. Y S \vc 561 <�A )01jts Operations Operations during the year were affected by seawater supply interruptions due to high winds, power outages, supply pipeline problems, and maintenance work at the Seawater Treatment Plant and the Seawater Injection plant. G &I maintenance activities included an extensive inspection program of the piping and processing equipment within the plant and the pipelines to the wells. Solids processing in the G &I plant was shut down in 2009 during the summer until late December and in 2010 from mid May through the present. Major repairs included replacement of process piping and valves, as well as repairs to the slurry tank, ball mill, metering, and pump electrical systems. Disposal of ongoing liquid drilling wastes and water from pit dewatering operations continued during much of the summer shut down period. Solid wastes accumulated during the summer were stored at the MTS and processed when the full plant was in operation. The pace of excavation from the production reserve pits was reduced in 2010 with the concurrence of the Alaska Department of Environmental Conservation and batch processing of solids rather than continuous processing was used during part of the winter. Well Operations and Monitoring The four GNI disposal wells are located on the Surfcote pad and continue to be available for disposal. Well GNI -01 has been shut -in due to tubing damage since May 2007, but it is available for Class II direct injection and observation purposes. It was replaced for Class I waste and slurry injection by well GNI -04 which began in May 2008. Well GNI -02A was sidetracked to a new bottom hole location in November /December 2006 and is an active Class I waste and slurry injector. Existing Class I well GNI -03 is also active after a workover in December 2009 to replace damaged tubing. Each well is perforated in the Ugnu formation between 6400 and 6600 ft TVD. GNI plant discharge rate, temperature and slurry density, along with injection well pressure and temperature and annulus pressures are continuously monitored in the G &I Plant control room. Slurry is injected into one well at a time on a rotating schedule. After each injection cycle, shut in wells are flushed with water and freeze protected with new product methanol mixed with water. Exhibit 4 lists the injection cycles and the well work and surveillance activities during the report period. The injection history and performance for each well is shown in Exhibits 1, 2, 3, 5, 6 and 10. Peak slurry injection rates are normally between 25,000 and 35,000 barrels per day with between 2,000 and 3,000 cubic yards per day of solids processed. Injected slurry density averaged about 9.5 ppg when solids were being processed (Exhibit 6). Surface injection pressure is heavily influenced by the slurry injection rate, slurry density and to some extent slurry temperature due to viscosity dependence on temperature and the impact of injection temperature on formation stress. Daily average surface injection and calculated bottom -hole injection pressures (BHIP) are shown in Exhibit 6 for each well. BHIP is calculated to account for the effects of the hydrostatic head and fluid friction of the slurry column. The calculated bottom hole injection pressures in each well have shown relatively stable injection pressures over the last year. All three wells have maintained good formation injectivity with no sign of formation plugging. 2 0 • By design, the outer annulus (OA) of each GNI well is in weak pressure communication with the formation adjacent to its surface casing shoe set at about 4000 ft TVD (GNI -03 and GNI -04) and about 2800' TVD in the GNI -02A sidetrack. The surface pressure in each outer annulus is monitored as potential indicator of any significant fluid movement above the approved injection interval. The OA pressure is also quite sensitive to thermal expansion or contraction of the annulus fluids resulting from the injection cycle and injection fluid temperature variations. The OA of each well is closely monitored during a well swap and periods of higher temperature injection and the annulus pressure is bled as necessary. Due to the communication with the formation, OA pressure changes related to thermal effects begin to dissipate within a short time. There have been no significant sustained pressure increases adjacent to the surface casing shoe and no abnormal or unexplained annulus pressures observed during the report period. Each GNI well is equipped with control line tubing open ended within the inner annulus (IA) to about 1000 ft. This line allows several hundred feet of nitrogen cushion to be maintained in the IA to dampen the pressure changes due to thermal expansion or contraction of the annulus fluid. There has been no indication of tubing or packer leakage observed in any of the GNI wells, although the IA pressure may need to be bled during periods of high temperature injection and re- charged during cooler injection periods. Exhibit 10 contains daily average tubing, IA and OA pressures for each of the wells. Dates when the annulus pressure was bled or re- pressured are also indicated. EPA witnessed mechanical integrity tests of the inner annulus are required annually under the Class I permit. The AOGCC requires an MIT -IA every two years in slurry injection wells under AIO 4E, Rule 6. Successful MIT -IA tests were performed in GNI wells 02A, 03 and 04 on September 26, 2010. EPA representatives witnessed each of these MIT -IA tests. Memory caliper logs were run in GNI wells 02A, 03 and 04 to inspect the 7" tubing strings in 2010. GNI -01 has remained shut -in since May 2007 due to the level of tubing damage. The following table lists the observed maximum metal loss in the tubing and the casing below the packer from the caliper logs run during the report period. Well Date Max Pit Penetration Max Cross - Sectional Wall Loss Tubing Casinq Tubinq Casin GNI -02A 06/30/10 29% 26% 20% 16% GNI -03 05/26/10 <10% 42% <3% 24% GNI -04 06/12/10 22% 30% <13% 18% After isolation of the tubing with bridge plugs and /or back pressure valves, the trees on each of the wells were replaced and inspected for erosion /corrosion damage. Well Surveillance and Testing The cycling of injection to the wells generally allows well surveillance and maintenance activities to be scheduled with little disruption to G &I plant operations. To minimize freeze protection concerns, repeat well tests and logs are usually scheduled in the summer. 3 • • The shut in temperature /pressure survey results for 2010 and prior years are shown in Exhibit 7. Repeat shut -in temperature /pressure logs were run in the wells in June and July. Based on the fill tags and the temperature profiles, all injection continues to exit each wellbore through the perforated intervals. The temperature logs have very similar (O character to the previous logs in each well. Consistent with the 2009 results, the '\-1OO�MOp _ temperature logs have shown less tha 500 feet TVD of vertical fluid mo vement. Since the GNI well bores are deviated and the effective depth of investigation of temperature logs is limited, the full extent of injection through vertical fractures may not be detected by the temperature logs. Observed static reservoir pressures obtained from the GNI -02A, 03 and 04 shut -in temperature /pressure logs were slightly higher than the previous measurements: 38 psi in GNI -02A, 11 psi in GNI -03, and 83 psi in GNI -04. Repeat step rate tests (SRTs) were performed in wells GNI -02A, 03 and 04 in July and August. The repeat SRT procedure included both a step up portion and a step down portion. Each SRT was analyzed using two methods to provide additional insight, a conventional analysis and a superposition method. The step rate tests in wells GNI -02A and 03 exhibited an unusual character. This has been interpreted as injection into a pre- existing fracture or fracture network possibly held open by injected solids. Later in the test, the flow appeared to be dominated by a period of pressure dependent leak off from a non - propagating fracture. In the case of GNI -04 with less slurry injection prior to the test, there is a less complicated fracture network due to the lower cumulative solids injection. Exhibit 8 discusses the 2010 step rate test data and analysis results. As in the past, SRT's confirm fractures are the primary disposal mechanism. Repeat surface pressure falloff (SPFO) tests were run in wells GNI -02A, 03 and 04 in July and August. Surface pressure falloff tests were run in the summer to avoid rate fluctuations due to freeze protection immediately prior to shut in. Also, since a well cannot be shut in while injecting slurry, each repeat SPFO test is run after a period of water injection containing only a small amount of mud liquids. No drilling mud was injected in the 24 hours prior to shutting in the well and the injection rate was stabilized. Given these factors, the SPFO tests should be viewed as representing a snapshot in time that may not completely reflect the downhole flow conditions present due to the differences with fluid rheology under actual slurry injection. As with past tests, calibrated surface memory gauges were used to record the pressure falloff data. Exhibit 9 discusses the 2010 SPFO test analysis results. Several reservoir flow models were used in an attempt to obtain a type curve match of the data. The SPFO data from well GNI -02A was best matched using a radial composite homogeneous (RCH) reservoir model and GNI -03 was best matched using an infinite conductivity vertical fracture (IVCF) model. The data from GNI -04 was difficult to match with a single model. To gain insight into this well, the early period data was matched with the IVCF model and the late time data was matched using the RCH model. The tests from each well showed evidence of a "boundary" or damaged zone some distance from the wellbore. In general, the reservoir parameters derived from the tests were similar to those from 2009. A prototype bore hole gravity meter logging tool was run in well GNI -03 in July. The tool was developed by Scintrex Ltd and was run by Schlumberger. The tool was designed to 4 • • measure the gravitational field surrounding the wellbore at various depths and can potentially detect very small changes in formation density as a result of changes in fluid saturation or the accumulation of injected solids. Well GNI -03 was chosen for the test of this tool due to its high cumulative solids injection. A comparison of the results of the log with the original open hole density log showed good agreement except just above the perforated interval. These preliminary results appear to confirm the solids placement in or near the primary disposal injection interval with little upward movement of injected solids. Storage Mechanism and Disposal Domain As reported in the past, a number of studies have been conducted to understand the downhole storage mechanism in slurry injection operations. These include two major industry studies: the Drilling Engineering Associates (DEA) 81 Joint Industry Project (JIP) laboratory study and the Mounds Drill Cuttings Injection JIP field pilot study. Individual operators have also reported monitoring and well testing programs to delineate the storage mechanism and geometry. Most of these studies and monitoring programs agree that multiple fractures are created during periodic injection operations. Step rate tests and pressure falloff tests of the GNI wells have also showed signatures of multiple opening or multiple closure events, indicating multiple fractures from GNI operations. The result is likely a complex disposal domain consisting of a series of fractures developed over time with different orientations. Branching fractures may also be a part of the storage mechanism. This disposal domain allows for the storage of large amounts of solids. Fracture modeling was updated in 2006 using a modified conventional hard rock fracture simulator adjusted for soft rock behavior and assuming the disposal domain described above. The layer description was extended upward and downward to include 22 layers. The updated model runs predicted fractures to be contained below 5900 ft TVD at that time, about 600 ft above the perforations in the original GNI completions. At some point the increasing stress due to solids storage in the fractures of the disposal domain will create conditions resulting in possible additional upward fracture extension. The model results indicate fracture growth to near 5000 ft TVD at some time beyond the year 2020, still well below the top of the approved interval at about 4500 ft TVD. While the primary G &I surveillance techniques (temperature logs, step rate tests and pressure falloff tests) and the model results provide differing inferences as to the size of the fracture system (partially due to the specific conditions of each test), all indicate limited upward movement of the injected material and confinement well within the approved interval specified in A1O #4E, Rule 2. Well Plans Well GNI -01 has significant tubing damage and has injected over 1.6 MM cubic yards of waste drilling solids. Well GNI -01 will be available for occasional direct injection of Class II materials and to observe various facets of the slurry injection process. Operational Plans The operational plan for the next twelve months will involve similar activities to those in recent years. Discussions are ongoing with Alaska Department of Environmental 5 • • Conservation concerning the scope of the remaining production reserve pit closeout activities required by the State of Alaska's Inactive Reserve Pit Closure Regulations. While a significant feed for the G &I plant will be excavated drilling mud and cuttings from old exploration reserve pits and well sites, the pace of excavation from the production reserve pits will likely remain reduced. As was the case for a portion of last winter, solid waste material will be processed in batches rather than continuously, except when the mill is shut down for maintenance, during well switches and for brief periods due to weather or utility outages. Class II liquids and solids from on -going drilling operations will be processed at the G &I plant on a periodic basis determined by the drilling and well workover schedules. Oily solids will be accepted at the material transfer station and processed at the G &I plant during winter months when the material can be handled in a frozen state and mixed with reserve pit wastes. Non - hazardous Class I materials will be processed and injected in the three active GNI slurry injection wells, GNI -02A, GNI -03 and GNI -04. Direct injection of crude oil contaminated with oil based drilling mud from the initial production from new wells and of other wastes will be utilized when necessary. Snow melt accumulating in reserve pits will be injected by the GNI plant in the summer as needed. Each of the three active GNI wells will be used for injection on a rotating schedule as described above. Anticipated major repairs in 2010 include replacement of the mill liner and various piping segments. 6 • 0 Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class 1 Permit AK-1 1008-A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2009 through September 30, 2010 List of Exhibits 1. GNI Surfcote Injection Summary 2. GNI Injection Bar Graph 3. a,b GNI Solids Injection Bar Graphs 4. GNI Surfcote Well Surveillance Activities 5. a,b,c,d GNI Wells Injection Bar Graphs 6. a,b,c,d GNI Wells Daily Average Data Plots 7. b,c,d GNI Wells Temperature Logs 8. GNI Wells Step Rate Tests 9. GNI Wells Pressure Falloff Tests 10. a,b,c,d GNI Wells TIO Pressure plots 7 Exhibit 1 G &I Injection Summary Cumulative Thru September 30, 2010 Total GNI -1 GNI -2 GNI -02A GNI -3 GNI-4 Shut -In P &A Active Active Active ��-\ Q Itz �. Water Injection (MM Barrels) * 41.8 10.2 8.3 6.6 12.7 4.0 Slurry Injection (MM Barrels) ** 81.4 22.6 18.4 8.2 28.2 4.0 Total Injection (MM Barrels)'` ** 123.2 32.8 26.8 14.7 40.9 8.0 Solids Injected (MM Tons) 5.1 1.5 1.2 0.4 1.8 0.2 Solids Injected (MM Cubic Yards) 5.6 1.6 1.3 0.5 2.0 0.2 Drilling Fluid Injected (MM Barrels) 5.9 1.3 1.0 1.0 2.1 0.5 Direct Injection (M Barrels) * * ** 169 38 28 4 99 0 * includes bypass sea water and produced water injected during plant outages and upsets ** includes all fluids pumped from the G &I plant includes slurry, water and direct injection * *'* Includes oil based mud, contaminated crude, other waste and flush water pumped at the well site • J , ,� Eosr 7 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY A REGION 10 1200 Sixth Avenue, Suite 900 Seattle, Washington 981 01 -31 40 c`,jr'q< PFOZE'�O DEC " 2 3 2009 Reply To: OCE -127 DEL 2 g 2009 ommissior ?y y Leg 9N � [� ' '. pig C_f� � �.d �.! . CERTIFIED MAIL - RETURN RECEIPT REQUESTED r:;.a.:; 0 t Arlene Chow BP Exploration (Alaska) Inc. 900 East Benson Blvd. Post Office Box 196612 Anchorage, Alaska 99519 -6612 Re: Underground Injection Control Program Class I Grind and Inject Permit AK- 1I008 -A Interim Approval to Commence Class I Injection Activities at Well GNI -03 Greater Prudhoe Bay, North Slope, Alaska. 7011 Dear Ms. Chow: The U.S. Environmental Protection Agency (EPA) Region 10 has witnessed the well work -over and Class I Well mechanical integrity test (MIT) performed on December 16, 2009, ( 4 - or well GNI -oat the Grind and Inject Project Permit Number AK- 11008 -A performed by BP ' Exploration (Alaska) Inc. Based on the witnessing of the work -over and the MIT, EPA provides interim approval and authorizes BP Exploration (Alaska) Inc. to commence Class I injection activities at the Grind and Inject Project, and specifically, for GNI -03 well to process and inject Class I materials. Final approval for injection activities will be based on the final completion report that EPA will review upon receipt. Your continued efforts to coordinate the scheduling of tests are appreciated. If you have any questions, or need further information, please call Thor Cutler at (206) 553 -1673. Edward J. Kowalski, Director Office of Compliance and Enforcement cc: Jim Regg, AOGCC, Anchorage Susan McNeil, ADEC - Anchorage bp • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 IN10 Anchorage, Alaska 99519 -6612 L (907) 561 -5111 November 13, 2009 Commissioner Dan Seamount, Chairman 1V o v - > (} l3 Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 ; Alas' a �� fia Anchorage, Alaska Ancharalp 99501 Reference: Grind & Inject Project Annual Performance Report Dear Mr. Seamount: Q Enclosed is the Annual Performance Report for waste slurry injection for the Grind and Inject project located near Drill Site 4 in the Prudhoe Bay Unit. This report is submitted to satisfy the requirements of Area Injection Order #4E, Rule 10, as modified by Administrative Approval No. AIO 4C.001 and an Erratum Notice dated July 17, 2009. This requirement is very similar to an EPA report requirement regarding Prudhoe Bay Unit UIC Class I injection wells contained in EPA permit AK- 11008 -A. The report covers the period from October 1, 2008 through September 30, 2009 and was structured to satisfy both the AOGCC and the EPA requirements. Should you have questions concerning the contents of this report, contact me at 564 -4692. Sincerely, Michael L. Bill Senior Staff Engineer Cc: A. Cooke MB 11 -6 R. Bullock MB 11 -6 M. McAnulty MB 11 -6 C. Burgh MB 11 -6 A. Chow MB 3 H. Engel MB 7 -5 Harrington /Cantrell PRB 42 Ohnemus /Fagerland PRB 42 Collver /Dawley PRB 42 Well Integrity Coordinator PRB 7 GPB Environmental Team Leader PRB 7 S. Kenshalo, ConocoPhillips P. Bennett, ExxonMobil Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class I Permit AK-1 1008-A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2008 through September 30, 2009 This Annual Performance Report documents waste slurry injection on the Surfcote Pad near Drill Site 4 in the Prudhoe Bay Unit for the period October 1, 2008 through September 30, 2009. This report is submitted to satisfy the requirements of both EPA UIC Class I permit AK- 11008 -A, Part 11 3 c 7 and AOGCC Area Injection Order (AIO) #4E, Rule 10, as modified by Administrative Approval AIO 4C.001 and Erratum Notice dated July 17, 2009. Additional information requested in a letter from the AOGCC (Regg to Bill 12/22/03) is also included. The report contains a brief description of the current project status, a summary of the disposal well performance data acquired during this period and operational plans for the next year. Project Status In 1998, the Grind & Inject (G &I) Project at the Surfcote pad was undertaken by the owners of the Prudhoe Bay Unit, Initial and Lisburne Participating Areas, and the Kuparuk River Unit to dispose of drilling muds and cuttings stored in reserve pits. Other non - hazardous wastes processed through the G &I Plant included those referenced in AIO #4E, Rule 2 as Class II wastes, consisting of RCRA- exempt drill cuttings and oily solids from pipeline pigging, vessel cleanouts and well workovers, and RCRA- exempt liquid wastes such as used drilling mud from on -going North Slope drilling operations. EPA issued Class I UIC permit AK- 11008 -A for the Grind & Inject Project effective September 1, 2007. Authorizations to inject Class I substances were received on January 18, 2008 for wells GNI -02A and GNI -03 and on May 6, 2008 for GNI -04. Well GNI -01 remains a Class II only disposal well. All non - hazardous wastes injected for disposal in the GNI wells during the report period are within the description of wastes referenced in EPA UIC Class I Permit AK- 11008 -A, Part II C 3 7, the UIC Class I permit application, or in Area Injection Order 46, Finding 7 as incorporated in AIO #4E. Several lined pits comprising the "material transfer station" (MTS) at DS 4 were operated to temporarily hold ongoing drilling and oily solids when necessary. On an infrequent basis, flow back liquids from new wells drilled with oil -based mud (OBM) or other wastes were injected directly into G &I wells using temporary equipment staged on the Surfcote pad. As of September 30, 2009, project injection has included 36.2 MM barrels of water, 77.8 MM barrels of slurry containing 4.9 MM tons (5.5 MM cubic yards) of excavated reserve pit material and other waste solids, and 5.3 MM barrels of fluid from ongoing drilling operations. Exhibit 1 summarizes this data. 1 Operations Operations during the year were affected by seawater supply interruptions due to high winds, power outages, supply pipeline problems, and maintenance work at the Seawater Treatment Plant and the Seawater Injection plant. G &I maintenance activities included an extensive inspection program of the piping and processing equipment within the plant and the pipelines to the wells. Solids processing in the G &I plant was shut down from late May through October for inspections and maintenance. Major repairs included replacement of process piping, as well as repairs to the seawater heater. Repairs were also made to the ball mill, feed hopper, conveyor, slurry tank and injection pumps. Disposal of ongoing liquid drilling wastes and water from pit dewatering operations continued during much of the summer shut down period. Solid wastes accumulated during the summer were stored at the MTS. Well Operations and Monitoring I The four GNI disposal wells are located on the Surfcote pad and continue to be available for disposal. Well GNI -01 has been shut -in due to tubing damage since May 2007, but it is available for Class II direct injection and observation purposes. It was replaced for Class I waste and slurry injection by well GNI -04 which began in May 2008. Well GNI -02A was sidetracked to a new bottom hole location in November /December 2006 and is an active Class I waste and slurry injector. Existing Class I well GNI -03 is also active. Each well is perforated in the Ugnu formation between 6400 and 6600 ft TVD. GNI plant discharge rate, temperature and slurry density, along with injection well pressure and temperature and annulus pressures are continuously monitored in the G &I Plant control room. Slurry is injected into one well at a time on a rotating schedule. After each injection cycle, shut in wells are flushed with water and freeze protected with new product methanol mixed with water. Exhibit 4 lists the injection cycles and the well work and surveillance activities during the report period. The injection history and performance for each well is shown in Exhibits 1, 2, 3, 5, 6 and 10. Peak slurry injection rates are normally between 25,000 and 35,000 barrels per day with between 2,000 and 3,000 cubic yards per day of solids processed. Injected slurry density averaged about 9.5 ppg when solids were being processed (Exhibit 6). Surface injection pressure is heavily influenced by the slurry injection rate, slurry density and to some extent slurry temperature due to viscosity dependence on temperature and the impact of injection temperature on formation stress. Daily average surface injection and calculated bottom -hole injection pressures (BHIP) are shown in Exhibit 6 for each well. BHIP is calculated to account for the effects of the hydrostatic head and fluid friction of the slurry column. The calculated bottom hole injection pressures in each well have shown relatively stable injection pressures over the last year. All three wells have maintained good formation injectivity with no sign of formation plugging. By design, the outer annulus (OA) of each GNI well is in weak pressure communication with the formation adjacent to its surface casing shoe set at about 4000 ft TVD (GNI -03 and GNI -04) and about 2800' TVD in the GNI -02A sidetrack. The surface pressure in each outer annulus is monitored as potential indicator of any significant fluid movement above the approved injection interval. The OA pressure is also quite sensitive to 2 thermal expansion or contraction of the annulus fluids resulting from the injection cycle and injection fluid temperature variations. The OA of each well is closely monitored during a well swap and periods of higher temperature injection and the annulus pressure is bled as necessary. Due to the communication with the formation, OA pressure changes related to thermal effects begin to dissipate within a short time. There have been no significant sustained pressure increases adjacent to the surface casing shoe and no abnormal or unexplained annulus pressures observed during the report period. Each GNI well is equipped with control line tubing open ended within the inner annulus (IA) to at least 1000 ft. This line allows several hundred feet of nitrogen cushion to be maintained in the IA to dampen the pressure changes due to thermal expansion or contraction of the annulus fluid. There has been no indication of tubing or packer leakage observed in any of the GNI wells, although the IA pressure may need to be bled during periods of high temperature injection and re- charged during cooler injection periods. Exhibit 10 contains daily average tubing, IA and OA pressures for each of the wells. Dates when the annulus pressure was bled or re- pressured are also shown. ,EPA witnessed mechanical integrity tests of the inner annulus are required annually under the Class I permit. The AOGCC requires an MIT -IA every two years in slurry injection wells under AIO 4E, Rule 6. Successful MIT -IA tests were performed in GNI wells 02A, 03 and 04 on October 7, 2008 and in wells 02A and 04 on September 28, 2009. EPA representatives witnessed each of these MIT -IA tests. Memory caliper logs were run in GNI wells 02A, 03 and 04 to inspect the 7" tubing strings in 2009. As noted in previous reports, a significant amount of erosion /corrosion related metal loss has been seen in well GNI -03. Due to the unknown rate of metal loss, the operator specified maximum IA pressure has been reduced to 1000 psi. A rig workover to replace the tubing string in GNI -03 is planned for 4th quarter 2009. GNI -01 has remained shut -in since May 2007 due to the level of tubing damage. The following table lists the observed maximum metal loss in the tubing and the casing below the packer from the caliper logs run during the report period. Well Date Max Pit Penetration Max Cross - Sectional Wall Loss Tubin Casinq Tubin Casing GNI -02A 07/01/09 26% 24% 19% <14% GNI -03 11/13/08 60% 34% 49% 20% GNI -03 04/13/09 60% 33% 52% 20% GNI -04 01/27/09 19% 31% 12% 18% After isolation of the tubing with bridge plugs and /or back pressure valves, the trees on wells GNI -02A and 04 were replaced and inspected for erosion /corrosion damage. Well Surveillance and Testing The cycling of injection to the wells generally allows well surveillance and maintenance activities to be scheduled with little disruption to G &I plant operations. To minimize freeze protection concerns, repeat well tests and logs are usually scheduled in the summer. 3 The shut in temperature /pressure survey results for 2009 and prior years are shown in Exhibit 7. Repeat shut -in temperature /pressure logs were run in well GNI -04 in January, GNI -03 in June and GNI -02A in July. Based on the fill tags and the temperature profiles, all injection continues to exit each wellbore through the perforated intervals. The temperature logs have very similar character to the previous logs in each well. Consistent with the 2008 results, the temperature logs have shown less than 400 feet TVD of vertical fluid movement. Since the GNI well bores are deviated and the effective depth of investigation of temperature logs is limited, the full extent of injection through vertical fractures may not be detected by the temperature logs. Observed static reservoir pressures obtained from the GNI -02A and 03 shut -in temperature /pressure logs were slightly lower (20 psi) in GNI -02A and slightly higher (5 psi) in GNI -03 than observed in 2008. Repeat step rate tests (SRTs) were performed in wells GNI -02A, 03 and 04 in May through August. The repeat SRT procedure included both a step up portion and a step down portion. Each SRT was analyzed using three methods to provide additional insight: conventional analysis, multi -rate pressure transient analysis and a superposition method. The step rate tests in all three slurry injection wells exhibited an unusual character. This has been interpreted as injection into a pre- existing fracture or fracture network possibly held open by injected solids. Later in the test, the flow appeared to be dominated by a period of pressure dependent leak off from a non - propagating fracture. In the case of GNI -04 with less slurry injection prior to the test, there may be some connection to the mature fracture network established in offset shut -in well GNI -01. Exhibit 8 discusses the 2009 step rate test data and analysis results. As in the past, SRT's confirm fractures are the primary disposal mechanism. Repeat surface pressure falloff (SPFO) tests were run in wells GNI -02A, 03 and 04 in June through August. Surface pressure falloff tests were run in the summer to avoid rate fluctuations due to freeze protection immediately prior to shut in. Also, since a well cannot be shut in while injecting slurry, each repeat SPFO test is run after a period of water injection containing only a small amount of mud liquids. No drilling mud was injected in the 24 hours prior to shutting in the well. Given these factors, the SPFO tests should be viewed as representing a snapshot in time that may not completely reflect the downhole flow conditions present due to the differences with fluid rheology under actual slurry injection. As with past tests, calibrated surface memory gauges were used to record the pressure falloff data. Exhibit 9 discusses the 2009 SPFO test analysis results. Various reservoir flow models were used in an attempt to obtain a type curve match of the data. The SPFO data from wells GNI -02A and GNI -03 were best matched using fractured reservoir models while the data from GNI -04 was best matched using a homogeneous reservoir model, although there was indication of a small fracture. The tests from each well showed evidence of a "no flow boundary" or damaged zone some distance from the wellbore. In general, the reservoir parameters derived from the tests were similar to those from 2008, but there was no evidence of multiple fractures evident in the 2009 tests. 4 • • Storage Mechanism and Disposal Domain As reported in the past, a number of studies have been conducted to understand the downhole storage mechanism in slurry injection operations. These include two major industry studies: the Drilling Engineering Associates (DEA) 81 Joint Industry Project (JIP) laboratory study and the Mounds Drill Cuttings Injection JIP field pilot study. Individual operators have also reported monitoring and well testing programs to delineate the storage mechanism and geometry. Most of these studies and monitoring programs agree that multiple fractures are created during periodic injection operations. Step rate tests and pressure falloff tests of the GNI wells have also showed signatures of multiple opening or multiple closure events, indicating multiple fractures from GNI operations. The result is likely a complex disposal domain consisting of a series of fractures developed over time with different orientations. Branching fractures may also be a part of the storage mechanism. This disposal domain allows for the storage of large amounts of solids. Fracture modeling was updated in 2006 using a modified conventional hard rock fracture simulator assuming the disposal domain described above. The layer description was extended upward and downward to now include 22 layers. The updated model runs predicted fractures to be contained below 5900 ft TVD at that time, about 600 ft above the perforations in the original GNI completions. At some point the increasing stress due to solids storage in the fractures of the disposal domain will create conditions resulting in additional upward fracture extension. The model results indicate fracture growth to near 5000 ft TVD sat some time beyond the year 2020, still well below the top of the approved interval at about 4500 ft TVD. While the primary G &I surveillance techniques (temperature logs, step rate tests and pressure falloff tests) and the model results provide differing inferences as to the size of the fracture system (partially due to the specific conditions of each test), all indicate limited upward movement of the injected material and confinement well within the approved interval specified in AIO #4E, Rule 2. Well Plans Well GNI -01 has significant tubing damage and has injected over 1.6 MM cubic yards of waste drilling solids. Well GNI -01 will be available for occasional direct injection of Class II materials and to observe various facets of the slurry injection process. Well GNI -03 has significant tubing damage and has injected about 2.0 MM cubic yards of waste drilling solids. A rig workover to replace the tubing string in GNI -03 is planned for 4th quarter 2009. Operational Plans The operational plan for the next twelve months will involve similar activities to those in recent years. Discussions are ongoing with Alaska Department of Environmental Conservation concerning the scope of the remaining production reserve pit closeout activities required by the State of Alaska's Inactive Reserve Pit Closure Regulations. While a significant feed for the G &I plant will be excavated drilling mud and cuttings from reserve pits and from old exploration well sites, the pace of excavation from the 5 production reserve pits may be reduced. This winter solid waste material may be processed in batches rather than continuously, except when the mill is shut down for maintenance, during well switches and for brief periods due to weather or utility outages. Class II liquids and solids from on -going drilling operations will be processed at the G &I plant on a periodic basis determined by the drilling and well workover schedules. Oily solids will be accepted at the material transfer station and processed at the G &I plant during winter months when the material can be handled in a frozen state and mixed with reserve pit wastes. Non - hazardous Class I materials will be processed and injected in the three active GNI slurry injection wells, GNI -02A, GNI -03 and GNI -04. Direct injection of crude oil contaminated with oil based drilling mud from the initial production from new wells and of other wastes will be utilized when necessary. Snow melt accumulating in reserve pits will be injected by the GNI plant in the summer as needed. Each of the three active GNI wells will be used for injection on a rotating schedule as described above. Anticipated major repairs in 2009 include replacement of the mill liner and various piping segments. 6 0 0 Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class I Permit AK- 11008 -A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2008 through September 30, 2009 List of Exhibits 1. GNI Surfcote Injection Summary 2. GNI Injection Bar Graph 3. a,b GNI Solids Injection Bar Graphs 4. GNI Surfcote Well Surveillance Activities 5. a,b,c,d GNI Wells Injection Bar Graphs 6. a,b,c,d GNI Wells Daily Average Data Plots 7. b,c,d GNI Wells Temperature Logs 8. GNI Wells Step Rate Tests 9. GNI Wells Pressure Falloff Tests 10. a,b,c,d GNI Wells TIO Pressure plots 7 Exhibit 1 G&I Injection Summary Cumulative Thru September 30, 2009 Total GNI -1 GNI -2 GNI -02A GNI -3 GNI-4 sl ®k --,, 4�1= p.- 4 f - ® n Water Injection (MM Barrels) * 36.4 10.2 8.3 4.3 11.7 1.9 Slurry Injection (MM Barrels) ** 77.8 22.6 18.4 6.8 27.2 2.8 Total Injection (MM Barrels) * ** 114.2 32.8 26.8 11.1 38.8 4.7 Solids Injected (MM Tons) 4.9 1.5 1.2 0.4 1.8 0.1 Solids Injected (MM Cubic Yards) 5.5 1.6 1.3 0.4 2.0 0.2 Drilling Fluid Injected (MM Barrels) 5.3 1.3 1.0 0.7 1.9 0.3 Direct Injection (M Barrels) * * ** 169 38 28 4 99 0 * includes bypass sea water and produced water injected during plant outages and upsets ** includes all fluids pumped from the G &I plant * ** includes slurry, water and direct injection * * ** Includes oil based mud, contaminated crude, other waste and flush water pumped at the well site o7n3/io J ,/ 1J u Schtu~mb~rger Alaska Data & Consulting Services 2525 Gamball Street, Suite 400 Anchorage, AK 99503.2535 ATTN: Beth Well Job # N0.5561 Company: State of Alaska Alaska Oil ~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date 8L Color CD N•09 3-27/M-33 GNF03 BCZ2-00013 BB6M-00024 AY1 M-00049 PRODUCTION PROFILE PRODUCTION PROFILE STATIC PRESSURE SURVEY 7/09/10 07/08/10 07/10/10 1 1 1 1 1 1 C-20C BAUJ-00009 MCNL 03/07/10 1 1 02-10B BCRJ-00013 RST .- 05/07/10 1 1 F-28A BD88-00002 MCNL ~ (, ~ 03/20/10 1 1 BP Ezpioration (Alaska) Inc. -__~• . V . V•V,-...~ ^•.V .`~ ~...."•.w V~-~ Vvr ~ ~..~~ ~ V~ Petrotechnical Dala Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suile 400 Anchorage, AK 99503-2938 ,Y• ~.,, .r i l~ ~ry'~i ~ ~ ~ ;., !1.1._ ~ ~ 2Q1~3 Certified Mail # 7008 3230 0000 2496 ' ~ ~'~ ~' ~~ ~ ~ ` ~ ; ~+~~s ?~~~~r July 21, 2010 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE-127 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 ~1 ~ t~.'.. i ~ ~'4 ~`'~ BP Exploration (Alaska) Inc. ~ P. 0. Box 196612 900 E. Benson Boulevard Anchorage, AI: 99519-6612 Direct 907 561 511'7 ~~n Re: Demonstration of Mechanical Integrity, Prudhoe Bay Grind and Inject, UIC Class I Permit AK-11008-A ~- Dear Mr. Kowalski: This letter is to submit the results of a recent fluid movement test in UIC Class I well GNI-03 located at the Prudhoe Bay Grind and Inject project operated by BP Exploration (Alaska), Inc (BPXA). The test is specified as part of the demonstration of mechanical integrity under Part II, C.3 b of EPA UIC Class I permit AK11008-A. The enclosed descriptive and interpretive report contains the results for the following test as required under Part II, C.3.c(1) of the permit: - Fluid Movement Test: GNI-03 (page 16, Part II, C.3.b(2)) There was no indication of a loss of well integrity. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, ~~~ Katharine Fontaine Logistics and Infrastructure Manager Attachments • Cc: Thor Cutler, EPA Region 10 (letter and report) Talib Syed, EPA Consultant (letter and report) Jim Regg, AOGCC (letter and report) Shawn Stokes, ADEC (letter and report) • • • Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project EPA permit AK-1I008-A effective 09/01/07 requires tests to detect movement of fluids in vertical channels adjacent to the wellbore and to determine that the confining zone is not fractured in the Prudhoe Bay Unit Class I Grind & Inject wells each calendar year. Approved fluid movement tests (Part II C 3 b (2)) include tracer surveys, temperature logs, noise logs, oxygen activation/water flwo logs, borax pulse neutron logs or other logs. Below are the results of a temperature log run recently in well GNI-03. Fluid Movement Test The GNI wells normally inject cold slurry or cold water at 50-70 degrees F. The original formation temperature of the target disposal formation was about 115 deg F. The Shut-In Temperature log technique is commonly used for cement channel detection in injection wells on the North Slope of Alaska and has been used to satisfy the GNI fluid movement test requirement as a demonstration of mechanical integrity. A shut-in temperature log was run in Grind & Inject well GNI-03 on June 10-11, 2010. GNI-03 was shut-in for 9 days prior to running the log. Wellbore temperatures are affected by the temperature of the injected fluids by conduction or convection. When the well is injecting fluids, the wellbore and the adjacent formation reaches a temperature near the injection fluid temperature due to conductive heat transfer. When injection ceases, the wellbore temperature begins to return toward its original temperature. The rate of temperature change of the shut-in well will depend on the original formation temperature, the injection fluid temperature and the rate and cumulative volume of injection. In the G&I wells, the injected fluids are colder than the formation temperatures below about 4000 ft TVD. In areas where the injected fluids enter the formation, both conduction and convective heat transfer are involved. The amount of rock cooling is much larger and the rate of temperature change after shut- in will be much slower due to the direct contact of the formation with the cold fluid. Channeling adjacent to the wellbore is evident because cooler injected fluids leak off into formations throughout the length of the channel. Several types of logging tools are available to be used to record the temperatures of the wellbore fluids: tools run on electric line with areal-time surface readout and memory tools run on slick line. The results from these instruments are presented in the enclosed logs of borehole temperature and pressure versus measured depth. Shut-In Temperature Survey Procedure - EPA permit AK-1I008-A requires tracer surveys to "... be conducted at injection pressure at least equal to the average continuous injection pressure observed in the previous 6 months." Injection is cycled into the GNI wells on a rotating basis, with one well injecting at a time. The average and maximum injection pressures are reported quarterly on Form 7520-8. - Average daily injection pressure in well GNI-03 over the 6 months prior to its survey was 1195 psi. Average wellhead injection pressures exceeded this pressure during the injection cycle completed prior to this survey. - ~'C~e survey procedure invol`~ed the following stel>>• Inject a significant volume of cold water or slurry at the required pressure. Shut-in and freeze protect the well after an injection cycle. After at least 5 days, rig up logging tools and pressure test lubricator. Confirm depth control by comparing to the tie-in log on record. Run the shut-in temperature/pressure survey. Rig down and move off. - Compare the logged temperatures to previous shut in logs run in the well. CaNI-3 Shut-In Temperature Survey Results -reference Schlumberger GNI-03 Static Pressure Pass, Press-Temp-CCL-GR-CCL/Ciradio, 10-July-2010. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: gamma ray. casing collar locator, temperature, pressure and well fluid density. The last injection cycle before logging took place between 06/ 19 and 07/02/ 10. The shut-in temperature trace indicates uniformly increasing temperature with depth to about 6750 feet measured depth (MD) or 6124 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 6950 feet MD or 6291' TVD. Below that point, the temperature declined until the fill level was reached within or just above the perforated interval. Based on this data, there is no evidence of injected fluid movement above about 6100' TVD, and little or no movement above 6300' TVD. A plot of the temperature log data from 2010 along with other GNI-03 logs is shown below. GPII-03 Shut In Temperature Logs r --- - - _ - ^ Perfs/Jewelry ~, -6/6/98 Baseline ~ 120 - - ~- 06/22/05 5 day SI j ~' • 06/29/06 5 day SI 110 ~---- -~ -e_ 06/06/07 t 2day SI I - - ' 06/20/08 7day SI, ', Calib Shift '. 100 ~----- --, • 06/15/09 7day Sl ~ -------- LL d • 07/11/10 9 day SI ~ ~ i '° 90 --- - - - - a ' H i ~ 80 ------ _ _ _ i 70 - ^.^-• ~~~~~ 1 ~! .••••~~I~~•••. x ~• ~. oR~+~• 60 "a ---- -----_-a-... - •~'~ --i --- - / tr~Rls. ••••~' ~• •• ~ -- - -- 500 - -- 4500 -- -- 5000 - 5500 _._ ----~ - 00 True Vertical Depth feet -' - -- ~ i ~••. I ~ ^• ;~ -~i I ~ - --~ -1 ~ --~-- 6500 7000 Overall Conclusions ~~ The GNI-03 shut-in temperature log indicates no movement on injected fluids above 6100' TVD. Michael L. Bill July 20, 2010 by ~ cE~~b ,~ ~~ - JUN422010 Certification # 7008 3230 0000 2496 4631 AIBSke Otl & ~~ ~• Ern (Alaska) Inc. P. 0. Box 196612 Anchorage 900 East Benson Boulevard Anchorage, AK 99519-6612 May 28, 2010 UIC Manager, Ground Water Protection Unit ~ ~ ~ ~-f~~ U.S. Environmental Protection Agency 1200 Sixth Avenue, Suite 900 ~~ `~ r- ~, ~~ Seattle; WA 98101 RE: Demonstration of Mechanical Integrity, Prudhoe Bay Grind and Inject, UIC Class I Permit AK-i 1008-A Dear Mr. Kowalski: This letter is to submit the results of a recent tubing inspection log in UIC Class I well GNI-03 located at the Prudhoe Bay Grind and Inject project operated by BP Exploration (Alaska), Inc (BPXA). The test is specified as part of the demonstration of mechanical integrity under Part II, C.3 b of EPA UIC Class I permit AK11008-A. The enclosed descriptive and interpretive report contains the results for the following logs and tests as required under Part II, C.3.c(1) of the permit: - Tubing Inspection Log: GNI-03 (Page 16, Part II, C.3.b(3)) There was no indication of a loss of well integrity. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, ~;~ Katharine Fontaine Logistics and Infrastructure Manager Attachments v ~l' Cc: Thor Cutler, EPA Region 10 (letter and report} Talib Syed, EPA Consultant (letter and report) Jim Regg, AOGCC (letter and report) Shawn Stokes, ADEC (letter and report) • Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project Well GNI-03 EPA permit AK-1I008-A effective 09/01/07 requires a tubing inspection log in the Prudhoe Bay Unit Class I Grind & Inject wells each calendar year. Approved tubing inspection logs (Part II C 3 b (3)) include pipe analysis logs, caliper logs or other equivalent tests. Below are the results of a log run recently in well GNI-03. Tubing Inspection Log_ A memory caliper log was run in well GNI-03 on May 26, 2010. The 40 arm caliper logging tool, supplied by PDS (ProActive Diagnostic Services), was run on slickline to inspect the interior surface of both the tubing and the casing. The tubing inspection indicated the GNI-03 tubing is in good condition with no significant erosion/corrosion. The tubing was replaced during a workover in December 2009. The casing below the tubing tail is in fair to poor condition. Enclosed is a copy of the PDS Memory Multi-Finger Caliper, Log Results Summary. Below are the observed maximum metal losses observed in the tubing and casing from the caliper log. Well Date GNI-03 Tubing 05/26/10 GNI-03 Casing 05/26/10 Overall Conclusions Maximum Pit Penetration Max Cross-Sectional Wall Loss <10% <3% 42% 24% The GNI-03 caliper log indicates the tubing has no significant erosion/corrosion damage and is suitable for continued injection. Michael L. Bill May 27, 2010 Memory Multi-Finger Caliper Log Results Summary -~,. Company: BP Exploration (Alaska), Inc. Well: GNI-03 Log Date: May 26, 2010 Field: Prudhoe Bay Log No.: 8816 State: Alaska '~ Run No.: 8 API No.: 50-029-22820-00 Pipet Desc.: 7" 29 Ib. L-80 Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 4,971 Ft. (MD) Pipet Desc.: 9.625" 47 Ib. L-80 Top Log Intvl1.: 4,971 Ft. (MD) Pipet Use: Production Casing Bot. Log Intvl1.: 7,312 Ft. (MD) Inspection Type : Corrosion & Erosion Monitoring Inspection COMMENTS This caliper data is tied into the WLEG @ 4,971' (ELA9D). ~~ ~ ~~ ~ ~~~5 1 ~ i ~ ~~3~ ~ This log was run to monitor changes in the condition of the 7" tubing and 9.625" production casing with respect to corrosive, erosive and mechanical damage as a result of sustained solids injection. The caliper recordings indicate the 7" tubing appears to be in good condition, with no significant wall penetrations, areas ~ l `3 of cross-sectional wall loss or I.D. restrictions recorded. cis ®& `t l°~-o` `~ 3~ ,tc, MK b~\s o~ w~,.s~ '+•~~~. The caliper recordinos indicate the 9.625" production casinq_looaed appears to be in fair to poor condition with respect to corrosive, erosive and mechanical damage. Wall penetrations ranging from 29% to 42% wall thickness and cross-sectional wall loss ranging from 19% to 24% metal volume are recorded throughout the production casing logged. Recorded damage appears as apparent erosion. No significant I.D. restrictions are recorded throughout the production casing logged. This is the eighth time a PDS caliper has been run in this well and the first time the 7" tubing has been logged since the RWO on December 17, 2009. A comparison of the current and previous log (A rip 113, 20091 of the 9.625" production casing indicates an increase in erosive damage during_the time between logs, A graph illustrating the difference in maximum recorded penetrations on a joint-by-joint basis of the 9.625" production casing between logs is included in this report. y ~3o-~C w y(~o ~~ t ` `A~1 ~~~~J~~ 7" TUBING -MAXIMUM RECORDED WALL PENETRATIONS : hpc'~t~ ..3~ Mt~~~\~ R~, ---. No significant wall penetrations (> 10%) are recorded. 'J~~r~~ a ~ "mac ~ ~ ~(~ ~ ~~ ~~`S ~ ~ s ~ , `~ 7" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 3%) are recorded. 7" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. 9.625" TUBING -MAXIMUM RECORDED WALL PENETRATIONS Apparent Erosion (42%) Jt. 70 @ 7,080 Ft. (MD) Apparent Erosion (42%) Jt. 71 @ 7,112 Ft. (MD) Apparent Erosion (39%) Jt. 72 @ 7,138 Ft. (MD) Apparent Erosion (38%) Jt. 49 @ 6,226 Ft. (MD) Apparent Erosion (38%) Jt. 67 @ 6,975 Ft. (MD) ProActive Diagnostic Servi ces, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail; PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • 9.625" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Apparent Erosion (24%) Jt. 26 @ 5,285 Ft. (MD) Apparent Erosion (23%) Jt. 52 @ 6,371 Ft. (MD) Apparent Erosion (23%) Jt. 66 @ 6,927 Ft. (MD) Apparent Erosion (23%) Jt. 31 @ 5,488 Ft. (MD) Apparent Erosion (23%) Jt. 29 @ 5,418 Ft. (MD) 9.625" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the production casing logged Field Engineer: K. Miller & T. Thompson Analyst: C. Lucasan Witness: W. Cissell ProActive Diagnostic Services, Inc, / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1359 E-mail: PDS@memorylog.com Prudhoe Bay Field Gffice Phone: (907) 659-2307 Fax: (907) 659-2314 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 7. in (10.6' - 4971.0') Well: GNI-03 Pipe 2 9.625 in (4971.0' - 7301.5') Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: May 26, 2010 4 Approx. Tool Deviation ^ Approx. Borehole Profile 1 14 25 1000 50 2024 75 3051 ~. iv ~ LL ~ c ~ •- Z 100 4077 a c v ~O Q 25 5242 50 6258 75 7260 76 7302 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 76 PDS Report Overview Sr. Body Region Analysis Well: GNI-03 Survey Date: May 26, 2010 Field: Prudhoe Bay Tool Type: UW MFC 40 Ext. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 29 f L-80 6.184 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~e penetration body ~ metal loss body 150 100 i 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 129 pene. 5 124 0 0 0 0 loss 106 23 0 0 0 0 Damage Configuration (body ) 30 20 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of oints dama ed total = 26 26 0 0 0 0 Damage Profile (% wall) ~ penetration body ~ metal loss body 0 50 100 0 50 100 Bottom of Survey = 1 19.2 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 29.0 ppf L-80 Well: GNI-03 Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: May 26, 2010 Joint No. Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 11 0 0.03 7 3 6.18 PUP 1 14 0 0.03 7 2 6.15 2 56 0 0.03 7 1 6.13 3 98 0 0.04 9 2 6.15 Shallow ittin . 4 139 0 0.03 8 2 6.14 Shallow ittin . 5 180 0 0.04 9 2 6.15 Shallow ittin . 6 221 0 0.03 7 1 6.14 7 262 0 0.04 10 2 6.14 Shallow ittin . 8 303 0 0.03 7 1 6.11 9 345 0 0.03 8 2 6.16 Shallow ittin . 10 386 0 0.03 7 2 6.14 11 427 0 0.04 9 2 6.14 Shallow iltin . 12 466 0 0.04 9 1 6.13 Shallow ittin . 13 507 0 0.03 7 1 6.13 14 548 0 0.04 9 2 6.15 Shallow ittin . 15 588 0 0.03 8 2 6.15 Shallow ittin . 16 629 0 0.03 7 2 6.14 17 671 0 0.03 7 1 6.13 18 712 0 0.04 9 1 6.15 Shallow ittin . 19 753 0 0.04 9 2 6.16 Shallow ittin . 20 795 0 0.03 7 1 6.13 21 835 0 0.04 9 2 6.16 Shallow ittin . 22 877 0 0.03 7 2 6.15 ~ 23 918 0 0.04 9 2 6.14 Shallow ittin . 24 959 0 0.03 8 1 6.13 Shallow ittin . 25 1000 0 0.03 7 2 6.13 26 1040 0 0.03 7 1 6.14 27 1082 0 0.03 8 2 6.14 Shallow ittin . 28 1123 0 0.03 7 2 6.14 29 1164 0 0.03 8 2 6.15 Shallow ittin . 30 1205 0 0.04 9 2 6.13 Shallow ittin . 31 1246 0 0.03 7 1 6.15 32 1287 0 0.03 7 1 6.13 33 1328 0 0.03 7 1 6.12 34 1369 0 0.03 7 1 6.14 35 1410 0 0.03 7 2 6.15 36 1452 0 0.03 7 1 6.14 37 ~ 1492 0 0.03 7 2 6.12 38 1533 0 0.03 8 1 6.14 Shallow ittin . 39 i 1573 0 0.03 6 1 6.13 40 ' 1614 0 0.03 7 1 6.14 41 1655 0 0.03 8 1 6.14 Shallow ittin . 42 1696 0 0.03 7 1 6.13 i 43 1737 0 0.03 7 1 6.13 44 1777 0 0.03 8 1 6.14 Shallow ittin ~ 45 1819 0 0.03 7 1 6.11 46 1860 0 0.02 6 1 6.12 47 1901 0 0.02 6 0 6.11 48 1942 0 0.03 7 1 6.14 ~ 49 1982 0 0.03 7 1 6.14 Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 29.0 ppf L-80 Well: GNI-03 Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: May 26, 2010 Joint No. )t. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 50 2024 0 0.02 6 1 6.11 ' 51 2064 0 0.03 7 1 6.14 52 2105 0 0.04 9 1 6.14 Shallow ittin . 53 2146 0 0.03 8 1 6.13 Shallow ittin . 54 2187 0 0.03 7 1 6.13 55 2228 0 0.03 7 1 6.14 56 2270 0 0.03 7 1 6.14 57 2310 0 0.02 6 1 6.12 58 2350 0 0.02 6 1 6.12 59 2392 0 0.03 7 1 6.13 60 2433 0 0.03 7 1 6.13 61 2475 0 0.03 7 1 6.13 62 2517 0 0.03 7 1 6.13 63 2557 0 0.03 7 ~ 1 6.14 64 2598 0 0.01 4 1 6.14 65 2640 0 0.02 6 1 6.12 66 2681 0 0.03 8 1 6.15 Shallow ittin . 67 2723 0 0.01 3 0 6.12 68 2 764 0 0.02 6 1 6.13 69 2806 0 0.03 7 1 6.15 70 2846 0 0.03 7 1 6.15 ~ 71 2886 0 0.02 6 1 6.12 72 2927 0 0.00 1 0 6.13 73 2969 0 0.03 7 1 6.14 74 3010 0 0.02 6 0 6.12 75 3051 0 0.03 6 1 6.11 76 3092 0 0.03 7 1 6.12 77 3133 0 0.03 6 1 6.13 78 3175 0 0.03 7 1 6.14 79 3216 0 0.02 6 0 6.11 80 3256 0 0.02 6 1 6.13 81 3297 0 0.03 7 1 6.11 82 ~ 3338 0 0.02 6 1 6.11 83 3379 0 0.03 7 1 6.12 84 I 3421 0 0.03 7 1 6.13 85 3462 0 0.02 6 0 6.11 86 3504 0 0.03 7 1 6.14 87 3545 0 0.03 7 1 6.14 88 3586 0 0.03 6 1 6.14 89 3628 0 0.03 7 1 6.13 90 3669 0 0.03 7 0 6.12 91 3710 0 0.02 6 0 6.14 92 3751 0 0.03 7 1 6.12 93 3793 0 0.02 5 0 6.12 94 3834 0 0.00 1 0 6.12 95 3872 0 0.02 6 1 6.13 96 3914 0 0.01 3 0 6.13 97 3955 0 0.01 2 0 6.10 98 3996 0 0.00 1 0 6.12 99 4037 0 0.01 3 0 6.12 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 7, in 29.0 ppf L-80 Well: GNI-03 Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: May 26, 2010 Joint No. )t. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 100 4077 0 0.01 3 0 6.12 101 4119 0 0.01 2 0 6.11 102 4160 0 0 0 0 6.11 103 4200 0 0.02 6 1 6.12 104 4241 0 0.03 6 1 6.12 105 4282 0 0.03 7 1 6.12 106 4324 0 0.03 7 1 6.11 107 4365 0 0.03 7 1 6.11 108 4406 0 0.03 6 1 6.14 109 4446 0 0.03 6 1 ~ 6.12 110 4488 0 0.02 6 1 ' 6.11 111 4529 0 0.03 7 1 6.13 112 4570 0 0.01 2 0 6.13 113 ~ 4611 0 0.03 7 1 6.14 114 ' 4652 0 0.03 6 1 6.12 115 4694 0 0.03 6 0 6.11 116 4735 0 0.02 6 1 6.13 117 4777 0 0.02 6 1 6.13 117.1 4818 0 0.03 7 1 6.15 PUP 117.2 4828 0 0.03 9 1 6.23 PUP Shallow ittin . 117.3 4837 0 0 0 0 5.96 7" 26# HES R NIPPLE 117.4 4839 0 0.03 9 1 6.24 PUP Shallow ittin . 117.5 4849 0 0.02 6 1 6.13 i PUP 117.6 4858 0 0.01 2 0 6.12 PUP 117.7 4868 0 0 0 0 6.00 9.625" x 7" Baker S-3 PACKER 117.8 4873 0 0.01 2 0 6.13 PUP 117.9 4883 0 0.02 6 0 6.15 PUP 118.1 4892 0 0.03 8 1 6.25 PUP 118.2 4901 0 0 0 0 ! 5.77 7" 26# HES RN NIPPLE 118.3 4904 0 0.03 9 1 6.23 PUP Shallow ittin . 119 4914 0 0.00 1 0 6.11 119.1 4955 0 0.01 2 0 6.13 PUP 119.2 4970 0 0 0 0 6.28 WLEG Penetration Body Metal Loss Body Page 3 • S Maximum Recorded Penetration Comparison To Previous Well: GNI-03 Survey Date: May 26, 2010 Field: Prudhoe Bay Prev. Date: April 13, 2009 Company: BP Exploration (Alaska), Inc. Tool: UW MFC 40 Ext. No. 218451 Country: USA Tubing: 9.625" 471b L-80 Ct~s'c Overla Max. Rec. Pen. (mils) 0 100 200 300 400 18 I 28 38 L G 3 Z .~ 48 C 'p I 58 i 68 ~? May 26, 2010 ^ April 13, 2009 Difference Diff. in Max. Pen. (mils) -100 -50 0 50 100 e: 26 I 38 E ~` C Z Ir 48 C ~O ~a ~ it I w ii bg I -89 -45 0 45 8~> Approx. Corrosion Rate (mPY) PDS Report Overview ~M Body Region Analysis Well: GNI-03 Survey Date: May 26, 2010 Field: Prudhoe Bay Tool Type: UW MFC 40 Ext. No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 47 f L-80 8.681 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) t,: penetration body ;; metal loss body 60 _ 40 'I i 20 - i 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of oints anal sed total = 59 pene. 0 0 0 57 2 0 loss 0 0 9 50 0 0 Damage Configuration (body ) 60 40 20 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of oints dama ed total = 59 0 59 0 0 0 Damage Profile (% wall) ~, penetration body ~ metal loss body 0 50 18 38 Bottom of Survey = 76 100 58 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 47.0 ppf L-80 Well: GNI-03 Body Wall: 0.472 in Field: Prudhoe Bay Upset Wall: 0.472 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 8.681 in Country: USA Survey Date: May 26, 2010 Joint No. i Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (Ins.) i 0 50 100 18 4975 0.14 0.15 33 22 8.77 A arent Erosion. 19 5004 0.13 0.15 33 21 8.78 A arent Erosion. 20 5045 0.12 0.15 33 20 8.77 A arent Erosion. 21 5086 0.14 0.16 35 22 8.80 A arent Erosion. 22 5125 0.14 0.15 32 21 8.79 A arent Erosion. 23 5165 0.13 0.14 31 21 8.77 A arena Erosion. 24 5203 0.13 0.16 34 22 8.80 A arent Erosion. 25 5242 0.13 0.16 34 22 8.79 A arent Erosion. 26 5281 0.14 0.17 36 24 8.79 A arent Erosion. 27 5321 0.12 0.15 32 20 8.78 A arent Erosion. 28 5362 0.14 0.17 36 22 8.76 A arent Erosion. 29 5403 0.15 0.16 35 23 8.79 A arent Erosion. 30 5444 0.14 0.16 35 22 8.79 A arent Erosion. 31 5485 0.14 0.17 37 23 8.77 A arent Erosion. 32 5526 0.15 0.17 36 23 8.79 A arent Erosion. 33 5567 0.12 0.14 31 21 8.79 A arent Erosion. 34 5608 0.12 0.14 31 20 8.78 A arent Erosion. 35 5649 0.14 0.17 36 22 8.78 A arent Erosion. 36 5689 0.12 0.14 31 20 ~ 8.79 A arent Erosion. 37 5731 0.13 0.17 36 23 8.78 A arent Erosion. 38 5772 0.14 0.16 35 23 8.80 A arent Erosion. 39 5813 0.14 0.14 31 20 8.76 A arent Erosion. 40 5854 0.13 0.14 31 20 8.77 A arent Erosion. 41 ~ 5895 0.14 0.16 34 21 8.78 A arent Erosion. 42 5936 0.13 0.15 33 22 8.77 A arent Erosion. 43 5977 0.13 0.15 32 21 8.80 A arent Erosion. 44 6015 0.13 0.16 34 22 8.79 A arent Erosion. 45 6056 0.14 0.16 34 22 ! 8.80 A arent Erosion. 46 6096 0.14 0.16 34 22 8.79 A arent Erosion. 47 6137 0.14 0.16 35 20 8.76 A arent Erosion. 48 6177 0.13 0.16 34 21 8.78 A arent Erosion. 49 6217 0.15 0.18 38 23 8.78 A arent Erosion. 50 6258 0.12 0.15 33 21 8.76 A arent Erosion. 51 6296 0.13 0.16 34 21 8.79 A arent Erosion. 52 6337 0.13 0.17 36 23 8.78 A arent Erosion. 53 ~ 6378 0.14 0.16 33 22 i 8.77 A arent Erosion. 54 6416 0.14 0.16 34 22 8.79 A arent Erosion. 55 6454 0.14 0.16 34 23 8.80 A arent Erosion. 56 6492 0.12 0.15 32 22 8.79 A arent Erosion. 57 6533 0.13 0.14 31 19 8.78 A arent Erosion. 58 6574 0.13 0.17 35 22 8.79 A arent Erosion. 59 6615 0.15 0.16 34 22 8.80 A arent Erosion. 60 6656 0.12 0.15 33 21 8.78 A arent Erosion. 61 6697 0.12 0.16 34 22 8.77 A arent Erosion. 62 6738 0.14 0.16 35 22 8.79 A arent Erosion. 63 6779 0.14 0.15 32 21 8.78 A arent Erosion. 64 6817 0.13 0.15 33 22 8.80 A arent Erosion. 65 6857 0.13 0.16 35 22 8.78 A arent Erosion. 66 6897 0.13 0.18 38 23 8.82 A arent Erosion. ~~ 67 6937 0.15 0.18 38 23 8.79 A arent Erosion. Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 47.0 ppt L-80 Well: GNI-03 Body Wall: 0.472 in Field: Prudhoe Bay Upset Wall: 0.472 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 8.681 in Country: USA Survey Date: May 26, 2010 Joint No. )t. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. I.D. (Ins.) Damage ProFile Comments (% wall) 0 50 100 ~ 68 6976 0.14 0.17 36 23 8.78 A Arent Erosion. 69 701 7 0.14 0.1 7 36 21 8.77 A Arent Erosion. 70 7058 0.13 0.20 42 21 8.81 A Arent Erosion. 71 7099 0.15 0.20 42 22 8.81 A Arent Erosion. 72 7138 0.18 0.18 39 23 8.81 A Arent Erosion. 73 71 79 0.14 0.1 7 36 21 8.79 A Arent Erosion. ~ 74 7220 0.13 0.16 34 22 8.79 A Arent Erosion. 75 7260 0.13 0.16 33 21 8.79 A Arent Erosion. 76 7302 0.13 0.14 29 19 8.79 A Arent Erosion. Penetration Body Metal Loss Body Page 2 .~ ,,. PDS Report Cross Sections Well: GNI-03 Survey Date: May 26, 2010 Field: Prudhoe Bay Tool Type: UW MFC 40 Ext. No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 47 ppf L-80 _ __ Analyst: C. Lucasan Cross Section for Joint 70 at depth Tool speed = 43 Nominal ID = 8.681 Nominal OD = 9.625 Remaining wall area = 79 Tool deviation = 36 ° 7079.58 ft CJ i Finger 1 1 Penetration = 0.2 ins Apparent Erosion 0.20 ins = 42% Wall Penetration HIGH SIDE = UP Cross Sections page 1 S ,,. Well: GNI-03 Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Tubing: 9.625 ins 47 ppf L-80 PDS Report Cross Sections Survey Date: May 26, 2010 Tool Type: UW MFC 40 Ext. No. 218451 Tool Size: 2.75 No. of Fingers: 40 Cross Section for Joint 71 at depth 71 12.49 ft Tool speed = 43 Nominal ID = 8.681 Nominal OD = 9.625 Remaining wall area = 78 Tool deviation = 36 ° Finger 36 Penetration = 0.2 ins Apparent Erosion 0.20 ins = 42% Wall Penetration HIGH SIDE = UP r~ U • Cross Sections page 2 S ,,, Well: GNI-03 Eield: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Tubing: 9.625 ins 47 ppf L-80 PDS Report Cross Sections Survey Date: May 26, 2010 Tool Type: UW MFC 40 Ext. No. 218451 Tool Size: 2.75 No. of Fingers: 40 Analyst: C. Lucasan Cross Section for Joint 26 at depth 5285.08 ft Tool speed = 43 Nominal ID = 8.681 Nominal OD = 9.625 Remaining wall area = 76 Tool deviation = 40 ° Finger 12 Penetration = 0.169 ins Apparent Erosion 24% Cross-Sectional Wall Loss HIGH SIDE = UP • Cross Sections page 3 ~.~,,. Well: GNI-03 Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA ___ Tubing: _ 9.625_ins 47 ppf L-80 Cross Section for Joint 52 at depth 6371.16 ft Tool speed = 43 Nominal ID = 8.681 Nominal OD = 9.625 Remaining wall area = 77 Tool deviation = 37 ° PDS Report Cross Sections Survey Date: May 26, 2010 Tool Type: UW MFC 40 Ext. No. 218451 Tool Size: 2.75 No. of Fingers: 40 Analyst: C. Lucasan I • Finger 12 Penetration = 0.17 ins Apparent Erosion 23% Cross-Sectional Wall Loss Cross Sections page 4 HIGH SIDE = UP TREE _ 6-3/8" CALICO WELLHEAD= FMC ACTUATOR= AXELSON KB. ELEV = 50.4' BF. ELEV = 23.0' KOP = 2450' Max Angle = 36 @ 5628' Datum MD = 6662' Datum TV D= 6000' SS ~ GNI-0 13-3/8" CSG, 6a#, L-80, ID = 12.415" i--i 2so9 Minimum ID = 5.77" @ 4907' 7" HES RN NIPPLE 13-3/8" CSG, 72#, L-80, ID = 12.347" 4154' 7" TBG, 29#, L80, .0371 bpf, ID = 6.184" H 4977' 4168' I-19-5/8"HES TYPE "H" ES CBNEnfTER 4$43' -~ 7" (26#) HES R NIPPLE, ID = 5.963" 4874' 9-5/8" X 7" BKR S-3 PKR ID = 6.00" 4907' ~~ 7" (26#) HES RN NIPPLE, ID = 5.77" PERFORATION SUMMARY REF LOG: SWS ARRAY INDUCTION LOG 05/07/98 A NGLE AT TOP PERF: 33 @ 7315' ~, Note: Refer to Production DB for historical perf data i SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 7315 -7335 O 11/28/98 4-1/2" 5 7620 - 7640 C 06/06/98 PBTD 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-1 7822• ~ 7s4o' SAFETY NOTES:*** 3/8" SS OPEN ENDED 3 CONTRO INE STRAPPED OUTSIDE OF 7" TBG DOWN T ING #23 (USED 28-SS BANDS) 1010'. 2 PUP JTS ABOVE & 2 BELOW PKR ARE 7" 26" L-80 1010' ~ 3/8" SS OPEN-ENDED CONTROL LINE FOR NfTROGEN BLANKET 4977' -i7" WLEG, ID = 6.276" i 4971' ELMD LOGGED (12125/09) 7550' I-iTOP OF FILL (12/13/09 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/06/98 ORIGINAL COMPLETION 09/21/01 MB/KAK CORRECTIONS 12/17/09 D18 12W0 12/17/09 SV DRLG DRAFT 01/04/10 BSE/PJC PULL PRN PLUG (12/24/09) 02/23/10 MLB/SV TBG CORR & ELMD (12/25/09) PRUDHOE BAY UNIT WELL: GNI-03 PERMIT No: 1971890 API No: 5002922820-00 Sec. 25, T11 N, R15E, 2845.96 FEL 695.93 FNL BP 6cploration (Alaska) Proposed Schedule for 2010 Mechanical Integrity Testing ~~_ `~ Class I Well (s) MIT Deadline Proposed MIT Flexibility Fluid Movement test date in test Logs Planned after date? MIT? Milne Point By April 6, 2010 Late March/Early Fluid movement logs MPB-50 April 2010 are not required till ~a- l7 2011. Badami B1-01 By September Late July 2010 Weather Fluid movement logs 15, 2010 permitting are required in 2010 because of the scheduled drilling program and are planned during the ~.etg..1 ~, 5 ~.,.~ summer barge season. Northstar NS10 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer a~~` ~~~ bar a season. Northstar NS32 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer ~®~-\S~ bar a season. Liberty CRI Well N/A September 2010 All logs required to complete the well will ~®~- ~ r~~ ~. c1 ~ ~ ~- 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 ~ ®,~ ~. ~ ~ ~ and NW wells 2010 with MIT's. and by Caliper logs in s a-~ ~ 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 forGNI- /Early October, Logs and/or Water 03 ,and GNI-04 02A, GNI-03 and 2010 Flow Logs planned for ~UCo- t \~ GNI-04. summer 2010. Caliper logs in 1 R _ ~ summer/fall 2010. 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 Ad". / ! A. I a. C~ BP Exploration 1/Alaska) Inc. P 0. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 Direct 907 561 5111 Phone: (907) 564-4838 Email: Alison.CookeC~?bp.com Web: www.bp.com F~,~ ~4' ~~~ ~ 4 201r ~IOiI& Cat~)1,,. RE: Mechanical Integrity Test Notifications Badami Class 1 Iniection WelI..UIC Permit AK-11001-A, Disposal Iniection Order No. 12 General Wastewater Permit No. 2005DB001-0010 Northstar Class 1 Injection Wells UIC Permit AK-11002-A General Wastewater, Permit No. 2005DB001-0020 Milne Point Iniection Well. UIC Permit AK-11005-A General Wastewater Permit No. 2005DB001-0001 Pad 3 Iniection Wells. UIC Permit AK-1!004-A Wastewater Disposal Permit No. 2005DB0001-0021 Grind and Iniect Injection Wells UIC Permit AK-11008-A Area Iniection Order No. 4E Genera! Wastewater Permit No 2005D6001-0012 Libertv Class 1 Iniection Well, UIC Permit AK-11013-A General Wastewater Permit No. 2005DB001-0025 Mechanical Integrity Test Notification -= February 23, 2010 Page 2 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) the annual Mechanical Integrity Test (MIT) and fluid movement test that is required every other year at the Badami Class 1 well to meet the permit requirement in UIC Permit AK-11001-A; 2) the MIT and fluid movement tests at the Northstar NS10 and NS32, Class 1 wells to meet the annual permit requirement in UIC Permit AK-11002-A; 3) the MIT and fluid movement test that is required every three years at the Milne Point Class 1 well to meet the permit requirement in UIC Permit AK-11005-A; 4) the MIT and fluid movement tests at the Pad 3 Class 1 wells in the Prudhoe Bay Unit to meet the annual permit requirement in UIC Permit AK 11004-A; 5) the MIT and fluid movement tests at the Grind and Inject Facility, in the Prudhoe Bay Unit to meet the annual permit requirement in UIC Permit AK-11008-A; and 6) the MIT and fluid movement test that is required at the Liberty Class 1 well to meet the permit requirement in UIC Permit AK-11013-A. By this letter BPXA is providing the written notification required by the aforementioned permits. In addition, BPXA staff will be coordinating the timeframes for these MIT and fluid movement tests with Mr. Thor Cutler of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA inspector, so that multiple tests of Class 1 wells can be witnessed in one trip to the North Slope. A summary of the proposed annual testing is presented in the attached table. The fluid movement test procedures that require EPA approval have been or will be sent under separate cover or by e-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 MEMORANDUM Toy Jim Regg ~ P.LSupervisor ~~~~ (~z~~~D FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 22, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC GNI-03 PRUDHOE BAY UN UGN GNI-03 Src: Inspector NON-CONFIDENTIAL C~ Reviewed By: P.I. Suprv .,~~ 1 ~.,T ]O Comm Well Name: PRUDHOE BAY UN UGN GNI-03 API Well Number: 50-029-22820-00-00 Inspector Name: John Crisp Insp Num: mitJCr100121072650 Permit Number: 197-189-0 Inspection Date: 1/16/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. GNI-03 4589 Well Type Inj. ~' TVD 1971890 ~ SPT 1500 P.T.D ypeTest Test pst J IA 190 ~ ~ __ Q~0 200 i _ 1680 200 _ 1680 "~ 200 ~~ __ Interval I~T^I- P/F P ~ Tubing~_ ]]so L tlso ]]so ]]so Notes' No problems witnessed ,~ Friday, January 22, 2010 Page 1 of I STATE OF ALASKA ALAS~JIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~~~ Cl~ss~l [~i~d~sal Well 1. Operations Performed: X1851';: uli ~ (:~':~ COCA. ~Otril111SS10 ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other "~ `"~ `' *~'~'~8 ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Cleanout 2. Operator Name: 4. Well Class Before Work: :Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 197-189. 3. Address: ®Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22820-00-00 7. Property Designation: ~ 8. Well Name and Number: ADL 028324 PBU GNI-03 9. Field./ Pool(s): ~ Prudhoe Bay Field / Prudhoe Undefined Waste Disposal 10. Present well condition summary Total depth: measured ` 7840' feet true vertical \M 7036' feet Plugs (measured) 7550' (Fill) Effective depth: measured 7740' feet Junk (measured) None true vertical 6952' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 4132' 13-3/8" 4161' 398T '" ~ 4930 2270 Intermediate Production 7794' 9-5/8" 7822' 7021' 6870 4760 Liner Perforation Depth: Measured Depth: 7315' - 7640' True Vertical Depth: 6597' - 6869' Tubing (size, grade, measured and true vertical depth): 7", 29# L-80 4977' 4674' Packers and SSSV (type, measured and true vertical depth): 9-5/8" x 7" Baker'S-3' packer 4874' 4589' em 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run 4. Well Class after work: ^ Exploratory ^ Development ®Service erations ® Dail Re ort of Well O y p p ® Well Schematic Diagram -Well Status after work: ^ Oil ^ Gas ~ ®WDSPL = ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 309-235 Printed Name Terrie Hubble Title Drilling Technologist NM~ Prepared By Name/Number Vl Signature Phone 564-4628 Date ~7 /~ Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 RBDMS JAH - $ 10 W ~ ,,~- ~ ~ Submit Original Only • GNI-03, Well History (Pre Rig Workover) Date Summary 4/13/2009 WELL S/I ON ARRIVAL. DRIFT W/4.5" CENT,TEL & SAMPLE BAILER TO 7301' CORRECTED TO ELM - SAMPLE RECOVERED - 14' OF FILL ABOVE TOP PERF. CALIPER FROM TAG DEPTH TO SURFACE (7288'SLM) TO SURFACE -GOOD DATA. TURN WELL OVER TO GNI -LEFT WELL SHUT IN PANEL IN SERVICE. 5/13/2009 MIRU CTU MU 2.25" DJN BHA and RIH. Tag fill ~ 7235' clean out to 7374' (top perfs at 7315' - 7335). Switch to backside and pump at maximum rate 6.0 bpm with 510 psi WHP. RBIH to re-confirm depth and tag at 7374'. POOH. 5/14/2009 At surface, freeze protect tubing with 92 bbls of 50/50 meth. Pressure test tree cap to 3,000 psi. RDMO coil. Inform DSO of well status. Job Complete. 6/14/2009 WELL S/I ON ARRIVAL. CURRENTLY RIGGING UP SWCP 4516 TO RUN A DRIFT, THEN A SLB GR/CCL LOG. 6/15/2009 TAGGED STICKY BTM C~3 7,313' SLM W/ 3.50" CENT, S-BLR. RAN SLB MEMORY TEMP / PRES / GR / CCL FROM 7,308' SLM TO SURFACE (good data). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 7/10/2009 WELL S/I ON ARRIVAL. TAGGED ICE PLUG ~ 65' SLM W/ 4.50" CENT, S-BLR (recovered -2-1/2 cups of ice). INSTRUCTED BY REP TO RDMO. COIL TBG WILL DO A THAW OUT PRIOR TO FCO. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 7/16/2009 MIRU. RIH with 2.0" down jet nozzle. Tag ice plug at 87' ctmd. Jet ice plug with 50/50 methanol while spotting neat methanol pills and taking returns to surface while holding 600 psi backpressure on wellhead. Well head pressure dropped off to 250 psi at 540' ctmd. Returns stop, well taking all fluid. SI choke and continue to RIH to tubing tail. No obstructions observed. POOH. MU and RIH with 2" JSN for FCO. Sit down at 7322'. Pump 10 Bbl gel sweep and cleanout to 7350'. PUH and pump down backside to stuff fill back into perforations. Park coil C~ 6997' pumped 50 bbls ~ 50 bpm. POOH. At surface. PU 2.25" SJN. RIH. Tagged fill ~ 7357', - 27' below bottom perforations. Side jet wash across perforations. PUH to 7000'. Pump 40 bbls: C~1 4 bpm/ 445 psig, 6 bpm/ 565 psig. POOH with coil. 7/17/2009 Continue POOH with coil. At surface. FP with 50/50 down back side to 3100'. Close swab valve. RD unit. Job Complete. 11/1/2009 T/I/0=220/150/150, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL), pre RWO. Stung into test port (150 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. Stung into test port (50 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 500 psi in 15 min. Bled void to 0 psi. Re-functioned and torqued LDS (450 Ib/ft). Pressured test void to 3500 psi, lost 500 psi in 15 min (FAIL). Bled void to 0 psi. 11/17/2009 WELL S/I ON ARRIVAL. DRIFT W/ 4.50" CENT. TEL, S. BAILER (SAMPLE OF G & I MATERIAL). TAG TT @ 4259' SLM / 4273' ELMD (14' CORR. TO ELMD). TAG BTM ~ 7304' SLM (7318' CORR. ELMD) (322' OF FILL). FWHP-T/I/0= 300/150/150 LEFT WELL S/I, NOTIFY DSO. 11/18/2009 T/I/0= 350/120/150. Temp= SI. Assist WH tech w/ IC leak path eval. IA FL C~1 260' (6.7 bbls). OA FL near surface. Increased IAP from 120 psi tp 350 psi with 4 LP bottles N2. Increased OAP w/ N2 from 150 psi to 680 psi. IC void = 0 psi. CAM increased IC void pressure to 3500 psi. IC void decreased 1700 psi in 10 minutes. Bled IAP to BT from 350 psi to 150 psi in 5 minutes. Bled OAP from 575 psi to 0 psi in 3 minutes. 30 minute monitor. WHP's unchanged. Final WHP's= 350/150/0. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. fLu Page 1 of 2 C~ GNI-03, Well History (Pre Rig Workover) Date Summary 11/18/2009 T/IA/OA= SI/120/150 Temp=cold PPPOT-IC (FAIL) (Leak path eval) DHD pressured up OA with N2 to 680 psi, no increase in void. RU N2 to IA pressured to 350 psi, 0 increase in void. PPPOT-IC RU 2 HP BT onto IC test void, 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3000/ 15 minutes, 2000/ 60 minutes. Bled void to 0 psi, RD test equipment. Did not cycle LDS "ET style". All were in good visual condition. Cycled previous POT. The test pressure held at 2000 psi for 1 hour, which is higher then maximum allowable annuli pressure which indicates the communication is not across the wellhead. 11/20/2009 MIRU CT Unit. MU and RIH with PDS memory GR/CCL. RIH and tagged at 7315' (top perf). Jet through bridge and drifted to 7350'. PUH and BH 5 bbls and tagged 7350'. Log up from PU WT to 4200' Painting flag at 7250'. 11/21/2009 Continue POOH. OOH with good data, correct depth -2'. MU Sand Dump BHA and RIH to flag and correct depth. At flag correct depth then tagged hard bottom at 7345' corrected depth. Displaced well with 1 % KCL and loaded backside with diesel for freeze protect while displacing Sand &CMT Plugs. Batch mix 32 bbl slurry of 6ppg 20/40 river sand and prep to pump. Lay in 32 Bbls 20/40 river sand/HEC gel slurry starting from PBTD at 7345'. Allow sand to settle out of gel. Tag sand top at 7273' corr -all perforations covered. After several tags and pumping down backside final tag C~ 7192' corrected depth. aint flag and POOH to PU Pig Shear nozzle. 11/22/2009 Continue POOH. MU and RIH with Pig Shear Nozzle. Correct to flag and tag at 7191'. Pumped 4 bbl 15.8ppg CMT Plug through Pig Shear Nozzle from 7187'. PUH and sheared nozzle at 7100'. POOH. ,/Estimated cement cap top at 7136'. Freeze protect well from 2500' with 38 Bbls 60/40 McOH. RDMO. Job Complete. 11/24/2009 WELL S/I ON ARRIVAL. DRIFT W/ 5.74" CENT, 2' 1-7/8" STEM, S-BAILER TO 7100' SLM. (1/2 GAL CEMENT RETRIEVED) P!T TUBING TO 1000# FOR 10 MIN. PRESSURE HELD. FWHP=100/0/0 WELL LEFT S/I, DSO NOTIFIED. 11/25/2009 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 0/175/90. SSV = O, MV = O, WV = C, IA/OA = OTG, SV = C. RIH WITH 1.6875" X 30' TOOL STRING. SHOT MEDIUM TUBING PUNCHER AT 4153' - 4155'. E- LINE RIGGED OFF OF WELL HEAD, LRS RIGGED UP FOR CIRC-OUT. 11/26/2009 T/I/O 0/140/0 LRS FINISHED CIRC-OUT. SHOT STRING SHOT FROM 4165' - 4175.5'. LRS MIT TXIA TO 1000#. SHOT CHEMICAL CUTTER AT 4180'. CHEMICAL CUTTER SEVERING HEAD SPLIT WHILE CUTTING. ,LEFT LOWER HALF OF SEVERING HEAD AND BOTTOM CENTRALIZER IN HOLE. LENGTH OF FISH 27.5" A 5.5" OD SECTION OF COPPER LOOKINC~R~PECCCEFT-5R1JT'fiFAND TURNED OVER TO LRS. FINAL T/I/O 0/0/0 JOB COMPLETED. 11/27/2009 WELL S/I ON ARRIVAL. RAN 5.48" LIB TO 7092' SLM (impression of washed out cutter ports facing up). FINAL T/I/O = 400/100/0 11/28/2009 RECOVERED LOST CHEMICAL CUTTER JUNK & BOW SPRING CENT. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF VALVE POSITIONS. 12/4/2009 T/I/O=SSV/130/58. Temp=Sl. Bleed WHP's to 0 psi. (pre-RWO). IA FL C~3 Surface. SSV closed & no ladder access to well head platform but TBG is cut C~ 4155' so bleeding IAP to 0 psi should bring TP to 0 psi. Bled IAP from 130 psi to 0 psi in 1 hour 30 minutes. Bled OAP from 58 psi to 0 psi in 30 minutes. Monitor for 30 minutes. No change in IAP or OAP during monitor. Final W HP's=SSV/0/0. SV, SSV, WV & MV =CLOSED. IA & OA = OTG. NOVP. Page 2 of 2 BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: I I Date From - To Hours Task Code NPT Phase ~ Description of Operations 12/7/2009 00:00 - 03:30 3.50 MOB P PRE REMOVE DRAG CHAIN. MOVE MODULES. BRIDLE UP 03:30 - 04:00 0.50 MOB P PRE MOVE OFF WELL AND SPOT IN CENTER OF PAD 04:00 - 05:30 1.50 MOB P PRE REMOVE BOP. INSTALL REAR BOOSTER TIRES. LD DERRICK 05:30 - 07:30 2.00 MOB P PRE WAITING ON SECURITY DUE TO CHANGEOUT 07:30 - 10:00 2.50 MOB P PRE BEGIN MOVING FROM P-PAD TO U-PAD ACCESS ROAD 10:00 - 14:30 4.50 MOB P PRE WAIT ON COMPOSITE MATS TO BE PLACED OVER UTILIDOORS 14:30 - 00:00 9.50 MOB P PRE CONTINUE MOVING FROM U-PAD ACCESS ROAD TO LANDFILL ON OXBOW TOWARD GNI-03 12/8/2009 00:00 - 05:30 5.50 MOB P PRE CONTINUE TO MOVE RIG FROM CURRENT LOCATION AT LANDFILL ON THE OXBOW TO GNI-03. 05:30 - 16:30 11.00 MOB P PRE SPOT RIG IN CENTER OF PAD -RD BOOSTERS. -RU DRAG CHAIN. -CHANGE BOP CONFIGURATION TO ANNULAR, 3-1/2" X 6" VBRS FLOW CROSS BLIND RAMS 4-1/2" X 7" VBRS. 16:30 - 18:00 1.50 RIGU P PRE PJSM TO SPOT RIG OVER WELL. CALL PAD OPERATOR TO GIVE HIM OPPORTUNITY TO OBSERVE THE MOVEMENT OF THE RIG OVER THE WELL. THE G&I PLANT OPERATOR ARRIVED TO OBSERVE. POSITION THE RIG OVER THE WELL AND PREPARE TO STEAM THE CONDUCTOR TO CENTRALIZE THE PRODUCTION CASING BY LOWERING THE FLUTED CENTRALIZER INSIDE THE TOP OF THE CONDUCTOR. -1630•HRS, 20-GALLONS OF POTABLE WATER WERE RELEASED THROUGH THE OVERFLOW ON THE ANNEX QUARTERS HOLDING TANK, MOST OF WHICH WAS CAUGHT IN SECONDARY CONTAINMENT. NON-EMERGENCY SPILL REPORTING HOTLINE WAS CALLED AND THEY CONFIRMED IT WAS A NON-REPORTABLE INCIDENT. A TRACTION REPORT WILL BE COMPLETED. 18:00 - 20:00 2.00 RIGU P PRE SPOT SLOP TANK -RU STEAM HOSES TO THAW CONDUCTOR. -OA PRESSURE = 0-PSI, IA = 0-PSI, TUBING = 0-PSI 20:00 - 21:00 1.00 RIGU P PRE MADE DECISION AND CALLED TOWN TO OK PLAN TO RU AND CIRCULATE OUT THE DIESEL FREEZE PROTECT AND THE WELL WITH 120-DEGREE SEAWATER TO ASSIST IN THE THAWING PROCESS OF THE CONDUCTOR. -RU CIRCULATING LINES IN THE CELLAR *******ACCEPTED RIG AT 2100-HRS ON 12/8/09********* 21:00 - 22:00 1.00 WHSUR P DECOMP PRESSURE TEST CIRCULATING LINES TO 3500-PSI. -SILICONE THE DRAG CHAIN SEALS TO PREVENT LEAKS. -FMC CALLED TO PRESSURE UP AND OPEN THE SSV. 22:00 - 00:00 2.00 WHSUR P DECOMP CIRCULATE 92-BBL OF 120-DEGREE SEAWATER DOWN THE IA TAKING DIESEL RETURNS FROM THE TUBING TO THE SLOP TANK. -PUMPING THROUGH THE IA AT 5-BPM WITH 340-PSI PUMP PRESSURE -CHANGE OVER AND PUMP AN ADDITIONAL 248-BBLS OF 120-DEGREE SEAWATER. CIRCULATE OUT 64-BBLS OF Printed: 12/28/2009 8:45:31 AM BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date ~ From - To Hours Task Code NPT 12/8/2009 22:00 - 00:00 2.00 WHSUR P 12/9/2009 00:00 - 00:30 0.50 WHSUR P 00:30 - 01:00 0.50 WHSUR P 01:00 - 03:00 2.00 WHSUR P 03:00 - 09:30 6.50 BOPSU P 09:30 - 12:30 3.00 BOPSU P 12:30 - 13:00 0.50 BOPSU P 13:00 - 16:30 3.50 WHSUR P Spud Date: 2/2/1998 Start: 12/7/2009 End: 12/17/2009 Rig Release: 12/17/2009 Rig Number: Phase Description of Operations DECOMP DIESEL AND 184-BBLS OF SEAWATER. CIRCULATED TILL SEAWATER RETURNS WERE CLEAN -PUMPING THROUGH TUBING AT 5-BPM WITH 180-PSI PUMP PRESSURE -USE COME-ALONG TO CENTRALIZE THE WELLHEAD. FMC RELEASED THE SNAP RING AND LOWERED THE FLUTED CENTRALIZER INSIDE THE TOP OF THE CONDUCTOR. DECOMP MONITOR WELL. NO FLOW -BLOW DOWN LINES. DECOMP JACK UP RIG AND SHIM UNDER RIG TO LEVEL RIG DECOMP PJSM FOR ND TREE AND ADAPTOR FLANGE, NU BOP -BLEED OFF CONTROL LINE AND TUBING HANGER VOID. -ND TREE AND ADAPTOR FLANGE. -ND TREE WITH SINGLE BARRIER DISPENSATION: CEMENT PLUG ~ 7136' -SET TREE AND ADAPTOR FLANGE ASIDE TO BE NORM TESTED AND SENT FOR INSPECTION -FILL PITS WITH 120-DEGREE SEAWATER DECOMP NU BOPE STACK AND INSTALL 3-1/2" X 6" VBRS BLIND RAMS. DECOMP PU DOUBLE GRAPPLE SPEAR FOR 7", 29# TUBING, DRESSED WITH 6.095" GRAPPLES WITH GRAB RANGE OF 5.895" TO 6.297". -MAKE CREW CHANGE AND HOLD PJSM TO SET GRAPPLES. -RIH TO SET GRAPPLES IN TUBING, BUT TOP GRAPPLES PULL FREE OF TUBING. TRY AGAIN AND DECIDE TO POH AND REPLACE WITH GRAPPLES DRESSED FOR 6.220", GRAB RANGE OF 6.020" to 6.423". -RIH AND GRAPPLES ENGAGE WITHIN 3-4" OF PULL. SLACK-OFF TO CONDUCT BODDY TEST ON BOP STACK. -CLOSE HYDRIL ANNULAR PREVENTOR TO TEST BODY WITH AOGCC APPROVAL TO 1000-PSI FOR 5-MIN CHARTED. THIS IS DUE TO INABILITY TO SET A TWC IN / HANGER. 4/ -AOGCC INSPECTOR JEFF JONES WAIVED WITNESS ~ 0630 ON 12/8/09. DECOMP PERFORM BODY TEST TO 1000-PSI, RECORDED ON CHART FOR A ROCK SOLID TEST. -FMC TECHNICIAN BOLDS. DECOMP HOLD PJSM ON RIG FLOOR TO DISCUSS PULLING THE HANGER TO THE FLOOR AND CIRCULATING FULL W ELLBORE TO THE CUT AT 4180' OF _262-Bbis. CLEAR RIG FLOOR. -PULL TO 130K-Ibs AND HANGER MOVES. CONTINUE TO 150K-Ibs AND THE GRAPPLES POPPED FREE. -FMC RUN IN 4 LDS. -POH AND CHANGE OUT TO 6.470" GRAPPLES THAT HAVE A GRAB RANGE OF 6.270" TO 6.673". -1430-Hrs---CHANGEOUT THE GRAPPLES, ADD ANOTHER SPEAR EXTENSION TO GET BELOW PREVIOUS GRAB AREAS, AND RIH TO ENGAGE IN THE TUBING. Printetl: 12/292009 8:45:37 AM BP EXPLORATION Page 3 of 1 s Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date From - To ~ Hours ~I Task Code NPT Phase Description of Operations 12/9/2009 13:00 - 16:30 3.50 WHSUR P DECOMP -FMC TECHNICIAN BOLDS. -P/U TO 130K-Ibs AND HANGER EASILY COMES UPHOLE; CONTINUE PULLING TO 170-K-Ibs AND MAKE NO HEADWAY. SET BACK DOWN IN TUBING HEAD. P/U TO 270K-Ibs AND MAKE NO HEADWAY. REPEAT TWO MORE TIMES AND MAKE NO PROGRESS. 16:30 - 17:00 0.50 WHSUR P DECOMP FMC RILDS. -RELEASE SPEAR. -LD SPEAR AND RD POWER TONGS. THE TOP SEGMENT OF GRAPPLES HAD THREE BROKEN SEGMENTS, BUT ALL PIECES WERE INTACT ON THE BHA. IT IS LIKELY THAT THE INCREASED ID OF THE 7", 29# PIPE CUSED THE DISTORTION OF THE GRAPPLES, WHICH WERE PROBABLY FRACTURED WHEN THE BHA WAS REMOVED THROUGH THE HANGER. -CALL ADW RWO ENGINEER AND DISCUSS ALTERNATIVES FOR BOP TESTING AND RECUTTING THE 7" TUBING. THE 6.470" NOMINAL GRAPPLES ENGAGED THE 7", 29#, WHEREAS THE 6.220" GRAPPLES WHICH HAVE A MAX GRAB OF 6.423" WERE NOT ABLE TO GRAB INSIDE THE TUBING. -P/U ON DP TO 150K (WT OF STRING IN SEAWATER = WT OF TOPDRIVE/BLOCKS = 5K OVERPULL), MAKE A MARK ON THE DP. P/U ANOTHER 50K-LBS, MAKE ANOTHER MARK ON DP, MEASURE 13.8" OF STRING STRETCH. CALCULATE STUCK POINT BASED ON 7", 29# AT 5829' VERSUS PACKER SET AT 4203'. NOTE: A SIMILAR CALCULATION USING 7", ~~# PuT~ TH D PTH AT 4~+q2'_ 17:00 - 00:00 7.00 WHSUR P DECOMP WAIT FOR SCHLUMBERGER TO ARRIVE WITH CHEM CUTTER. -GENERAL HOUSEKEEPING ON RIG. -SERVICE RIG FLOOR EQUIPMENT. -PERFORM DERRICK INSPECTION. -RU DUTCH RISER. -FINISH TALLY DRILLPIPE -TEST MUD PUMP #2 TO 3500-PSI, CLEAN SUCTION SCREENS ON BOTH PUMPS. -PREP PAD AREA FOR SCHLUMBERGER UNIT. 12/10/2009 00:00 - 10:30 10.50 WHSUR P DECOMP CONTINUE WAITING FOR SCHLUMBERGER TO ARRIVE WITH CHEM CUTTER. -GENERAL HOUSEKEEPING ON RIG. -LOAD 12 - 6-1/4" DRILL COLLARS IN THE PIPE SHED AND TALLY. -0830-Hrs--WSL, TOOLPUSHER, AND SHCLUMBERGER LEAD REVIEW THE SITE PREPARATIONS MADE FOR THE SCHLUMBERGER TRUCKS AND DECIDE TO MODIFY THE MAT LAYOUT. FORKLIFT OPERATOR REMOVED THE TRIPLE MATS, REDISTRIBUTED THE GRAVEL AND LAYED DOWN A SINGLE LAYERS OF MATS. 10:30 - 13:00 2.50 PULL P DECOMP SCHLUMBERGER MOVE IN VAN AND WHALE TO SPOT ON RIG MATS AT EDGE OF PAD. -1130-Hrs--PJSM TO DISCUSS P/U AND R/U SCHLUMBERGER LUBRICATOR, EXTENSION AND BOPs. rnntea: 7u~su~uua 0:45::71 HM BP EXPLORATION Operations Summary .Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Event Name: WORKOVER Start: 12/7/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Page 4 of 16 ~ Spud Date: 2/2/1998 End: 12/17/2009 Date From - To Hours Task ~ Code NPT ..Phase Description of Operations 12/10/2009 10:30 - 13:00 2.50 ~ PULL P 13:00 - 15:30 I 2.501 PULL I P 15:30 - 17:00 i 1.501 PULL ~ P 17:00 - 19:00 2.00 PULL ~ P 19:00 - 20:30 1.50 PULL P 20:30 - 22:30 2.00 PULL P 22:30 - 23:30 I 1.001 PULL I P DECOMP -LOAD IN AND M/U SCHLUMBERGER FULL PRESSURE CONTROL EQUIPMENT. DECOMP LOWELL CRANE AND JIM WILLINGHAM, ADW RWO MANAGEMENT TEAM, HELD A DOGHOUSE SAFETY MEETING WITH RIG CREW, WSL AND ANDREW HONEA, DOYON SUPERINTENDENT. THEY SHARED WITH THE DOYON 16 CREW BP's APPRECIATION FOR THE EXCELLENT SAFETY AND RWO PERFORMANCE OF DOYON 16 OVER THE PAST 12-MONTHS. A QUESTION AND ANSWER SESSION AT THE END THAT COVERED A RANGE OF TOPICS FROM SAFETY IMPROVEMENT OPPORTUNITIES SUCH AS DROPPED OBJECTS, EQUIPMENT REPLACEMENT AND AN MAJOR EMPHASIS ON NEAR MISS REPORTING. -SCHLUMBERGER MADE UP THEIR WIRELINE SPLICE DURING THE MEETING AND ALSO WIRED UP THE FIRING HEAD. -1430-Hrs--PJSM WITH JIM WILLINGHAM, SCHLUMBERGER CREW, ANDY HONEA, AND WSL TO DISCUSS THE CHEMICAL CUTTER OPERATION FROM R/U TO RIH. ONLY THE DRILLER WILL BE ALLOWED NEAR THE RIG FLOOR DURING THE ARMING OF THE CHEMICAL CUTTER AND UNTIL THE ASSEMBLY IS 200' BELOW THE RIG FLOOR. DECOMP PRESSURE TEST THE LUBRICATOR TO 700-PSI. BREAK OFF LUBRICATOR AND M/U SCHLUMBERGER CHEMICAL CUTTER AND CCL ASSEMBLY W ITH ONLY THE DRILLER STANDING BY WAITING FOR INSTRUCTIONS FROM SCHLUMBERGER. DECOMP M/U LUBRICATOR WITH CHEMICAL CUTTER AND CCL ASSEMBLY INSIDE. STAB ONTO WIRELINE BOPS, AND GET READY TO RIH. -1720-Hrs---BEGIN RIH WITH CHEMICAL CUTTER. -1725-Hrs---START CHARGE PUMP AND GET RETURNS ALMOST INSTANTLY ACROSS THE SHAKERS. -1845-HRS---ON BOTTOM. MAKE SEVERAL PASSES LOGGING UP FOR TIE-IN POINT. -1855-HRS---FIRE CUTTER. WAIT 2-MIN TO OFF GAS. LOST 100-PSI TENSION. DECOMP BEGIN PULLING OUT OF HOLE WITH E-LINE. POH TO 200' DECOMP PJSM WITH SCHLUMBERGER, RIG CREW, WSL ON RD E-LINE EQUIPMENT AND HAZARDS OF THE CHEMICAL CUTTER. -POH AND LD CHEMICAL CUTTER AND CCL ASSEMBLY. -LD E-LINE BOP, LUBRICATOR ON RIG FLOOR. -RD DUTCH RISER. -VAC OUT BOP STACK. DECOMP HOLD PJSM ON RIG FLOOR TO DISCUSS PULLING THE HANGER TO THE FLOOR AND CIRCULATING FULL WELLBORE TO THE CUT AT 4185' OF -262-Bbls. CLEAR RIG FLOOR. -2350-hrs---RIH WITH 6.470" GRAPPLES THAT HAVE A GRAB RANGE OF 6.270" TO 6.673". Printetl: 12/28/2009 8:45::11 AM i BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: - ~ t'~ `''P Date From - Ta 'Hours Task Code NPT Phase Description of Operations .~ 12/10/2009 22:30 - 23:30 1.00 PULL P DECOMP -RIH TO ENGAGE IN THE TUBING. -FMC BOLDS 11 K-I s AND HANGER EASILY COMES UPHOLE; CONTINUE PULLING AT 115-K-LBS. PULL HANGER TO RIG FLOOR. SET TUBING IN SLIPS 23:30 - 00:00 0.50 PULL P DECOMP RELEASE AND LD SPEAR. -LD TUBING HANGER. 12/11/2009 00:00 - 00:30 0.50 PULL P DECOMP RELEASE AND LD SPEAR. -LD TUBING HANGER. -RU XO TO TUBING. 00:30 - 01:30 1.00 PULL P DECOMP -CIRCULATE BOTTOMS UP AT 4-BPM WITH 105-PSI PUMP PRESSURE. RETURNS WERE CLEAN ACROSS THE SHAKERS. -RD SCHLUMBERGER E-LINE EQUIPMENT -CLEAR RIG FLOOR OF FISHING SPEAR TOOLS 01:30 - 03:00 1.50 WHSUR P DECOMP RU 7" TUBING HANDLING EQUIPMENT (ELEVATORS, POWER TONGS). -LD 1-JT OF 7" TUBING DUE TO EXTENDED LENGTH OF NEW TUBING HANGER. THE INTERIOR OF THE TUBING IS COVERED WITH SMALL CIRCUMFERENTIAL CORROSION PITS THAT HAVE BEEN WELL SCOURED BY EROSION FROM THE INJECTION OF DISPOSAL FLUIDS. THE PIN ID INSIDE THE COLLAR HAS BEEN REDUCED NEARLY INTO THE THREADS. THE PIN END OF THIS JOINT WAS DAMAGED BY THE RIG TONGS---WILL USE THE POWER TONGS TO BREAK OUT THE REMAINING JOINTS WHEN POH AND L/D THE 7" TUBING. i~~n -LAND NEW 12" X 7"TUBING HANGER WITH TWC IUD Y INSTALLED. -FMC RILDS. 03:00 - 03:30 0.50 BOPSU P DECOMP BLOW DOWN TOP DRIVE AND LINES. -RU TEST EQUIPMENT -TEST TWC FROM BELOW TO 1000-PSI FOR 5-MIN CHARTED. GOOD 03:30 - 04:30 1.00 BOPSU P DECOMP PJSM FOR TEST BOPE. SAFETY MEETING WITH ADW RWO SUPERINTENDENT, JIM WILLINGHAM, TOOLPUSHER, RIG CREW, WSL ~~Q 04:30 - 09:00 4.50 BOPSU P DECOMP TEST BOPE -HOLD ALL TESTS 250-PSI LOW AND 3500-PSI HIGH AND CHART FOR 5-MIN EACH. -TEST 3-1/2" X 6" VBR WITH 4" TEST JOINT. TEST 4-1/2" X 7 VBR WITH 7" TEST JOINT. -TEST THE ANNULAR WITH 4" TEST JOINT. -TEST WITNESSED BY WSLs AND TOUR/TOOLPUSHERs. -AOGCC INSPECTOR, JEFF JONES, WAIVED STATE'S RIGHT TO WITNESS TEST. 09:00 - 09:30 0.50 BOPSU P DECOMP R/D BOP TEST EQUIPMENT. 09:30 - 10:30 1.00 BOPSU P DECOMP PJSM TO BREAK RIME ICE OUT OF DERRICK. DISCUSS POTENTIAL DROPPED OBJECTS SUCH AS HARD HAT, RUBBER HAMMER, GOGGLES, RADIO, AND HOW THESE ITEMS WERE GOING TO BE RESTRAINED. -FILL OUT MANRIDER PERMIT AND OVERHEAD TOOL LOG ON THE PJSM MINUTES. Printed: 12/28/2009 8:45:31 AM BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date '~ From - To Hours Task 'Code NPT .Phase Description of Operations 1 12/11/2009 09:30 - 10:30 1.00 BOPSU P DECOMP -DERRICKMAN WENT UP INTO DERRICK AND KNOCKED MOST OF THE ICE OUT. HE REPORTED THAT HE WOULD NEED TO GO UP TO THE CROWN. BRING DERRICKMAN DOWN. -DERRICKMAN CLIMB THE DERRICK TO KNOCK RIME ICE OFF THE CROWN CLUSTER AND RAILINGS. 10:30 - 12:00 1.50 BOPSU P DECOMP INSTALL DUTCH RISER, P/U AND M/U DSM LUBRICATOR. TEST DUTCH RISER TO 500-PSI. -RUN IN WITH TWC PULLING TOOL, M/U TO TWC, SEE NO PRESSURE UNDER THE TWC. -PULL TWC UP INTO DUTCH RISER. REMOVE LUBRICATOR AND UD TWC AND LUBRICATOR. -PULL AND UD DUTCH RISER. 12:00 - 13:30 1.50 PULL P DECOMP PJSM. -SUCK OUT STACK. -BRING SCHLUMBERGER CAMCO SPOOLER TO RIG FLOOR AND CHAIN OFF TO IRON ROUGHNECK. -M/U LANDING JOINT TO CROSSOVER AND RIH TO M/U IN HANGER. -FM BOLDS. -PULL HANGER TO RIG FLOOR WITH 115K-Ibs PULL. -CONNECT OPERATING LINES TO SPOOLER. CONNECT 1/4" CONTROL LINE TO SPOOLER AND PREPARE TO POH AND UD 7" TUBING. 13:30 - 17:30 4.00 PULL P DECOMP POH AND UD 7' TUBING. -1420-Hrs--JOINT #15 UD; 1450-Hrs--JOINT #30; 1550-Hrs--Jt #60; 1630-Hrs--Jt #75; 1700-Hrs-- JT#95. -CUTOFF LENGTH = 35.54' -ORIGINAL CHEMICAL CUT WAS 5.5' ABOVE THE FINAL CUT. ONLY THREE SMALL HOLES AT THE ORIGINAL CUT SITE. -TUBING PUNCH LOCATED 4' BELOW THE TOP COLLAR ON THE CUTOFF JOINT -53-SS BANDS RECOVERED AND 1 CENTRALIZER HOLDING THE CONTROL LINE -TOTAL 100 FULL JOINTS AND 1 CUT JOINT OF 7" 26# L80 TUBING 17:30 - 18:30 1.00 PULL P DECOMP CLEAR AND CLEAN THE RIG FLOOR. PREPARE TO RIH AND RELEASE K-ANCHOR -SET 9" WEAR RING. 18:30 - 19:30 1.00 PULL P DECOMP MU BHA TO RECOVER K-ANCHOR -5-3/4" TRI-STATE TYPE B SPEAR DRESSED WITH GRAPPLES TO HANDLE 5.820" TO 6.534" FOR 7" 29# TUBING, BUMPER SUB, OIL JARS, PUMP OUT SUB, 12-EA 6-1/4" COLLARS. 19:30 - 22:30 3.00 PULL P DECOMP RIH ON 4" DP FROM 404' AND TAG AT THE CUT AT 4208' -NO GO AT 4213'. 9' ON JOINT 121 OF DRILL PIPE. -PU = 118K-LBS, SO = 110K-LBS. -ROTATING AT 20-RPM WITH 2K FREE TORQUE, ROT = 115K-LBS. -VERIFY DEPTH TAG 2-TIMES. 22:30 - 23:00 0.50 PULL P DECOMP LATCH SPEAR INTO TUBING AND PU 175K-LBS -WORK PIPE UP AND DOWN SEVERAL TIMES ROTATING rnntea: ~uenieuua o:vaai nevi BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 .Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 ,Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours -Task Code NPT Phase Description of Operations 12/11/2009 22:30 - 23:00 0.50 PULL P DECOMP PER BAKER FISHERMAN TO RELEASE K-ANCHOR. -PIPE CAME FREE WITH 12K-TORQUE, 15-TURNS TO THE RIGHT. 23:00 - 00:00 1.00 PULL P DECOMP CIRCULATE BOTTOMS UP -CIRCULATE AT 8.5-BPM WITH 630-PSI PUMP PRESSURE. -DIRTY WATER SEEN ACROSS SHAKERS WHEN RECOVERED BOTTOMS UP. 12/12/2009 00:00 - 01:00 1.00 PULL P DECOMP LD EXTRA JOINT OF DP PICKED UP. -MONITOR WELL. NO FLOW. -CLEAR RIG FLOOR. -KNOCK AND CHIP ICE OUT OF DERRICK TO PREVENT THE HAZARD OF FALLING ICE. -PREPARE TO POH RACKING BACK 4" DP. 01:00 - 02:00 1.00 PULL P DECOMP POH RACKING BACK DP. -POH FROM 4200' TO 404' WITH 4" DP 02:00 - 03:30 1.50 PULL P DECOMP POH RACKING BACK 4-STDS DC FROM 404' TO 36' -LD K-ANCHOR, CASING PUP JOINT, 6.44' CUT JOINT. TOTAL LENGTH 20.41' -LD SPEAR, STOP SUB, AND XO OF THE BHA. 03:30 - 04:00 0.50 PULL P DECOMP CLEAR RIG FLOOR. PREPARE TO MU PACKER MILLING BHA 04:00 - 04:45 0.75 PULL P DECOMP PJSM ON MU BHA AND RIH. -MU PACKER MILL BHA. -4-1/2" MILL, 4-EA BOOT BASKET, BIT SUB, BUMPER SUB, OIL JAR, PUMP OUT SUB, XO, 12-EA DCS, XO -TOTAL LENGTH 416.23' 04:45 - 06:30 1.75 PULL P DECOMP RIH WITH 40-STANDS AND 1-JT OF 4' DP FROM 416' TO 4228'. KER AT 4228'. -PARAMETERS: P/U wt 120K-Ibs; S/O wt 112K-Ibs; ROT wt 116K-Ibs AT 80-RPM; 4K-Ib-ft-FREE TORQUE; 8-BPM AT 630-PSI. 06:30 - 09:30 3.00 FISH P DECOMP MILL ON PACKER. 80-RPM. 5-6K-Ib-ft TORQUE, 6-7K-Ibs WOB, 8-BPM AT 640-PSI. -VARY THE RPMS DOWN TO 10-RPM, THEN BACK UP TO 80-RPM WHEN DP STARTS TO DANCE AROUND INSIDE THE 9-5/8", BUT KEEP WOB AT 6-7K-Ibs. -PACKER FALLS FREE AT 0930-Hrs. 09:30 - 10:30 1.00 FISH P DECOMP CIRCULATE FULL WELLBORE , 12-BPM at 1210-psi. GET A SMALL AMOUNT OF CRUDE OIL SHEEN FOR A SHORT TIME AND BITS OF RUBBER AND METAL SHAVINGS IN THE RETURNS ACROSS THE SHAKERS. 10:30 - 13:00 2.50 FISH P DECOMP PJSM TO P/U DP FROM THE PIPE SHED. -RIH P/U DP FROM PIPE SHED TO CHASE THE PACKER REMAINS DOWN TO THE CEMENT PLUG. -SET DOWN WHILE PUSHING WITHOUT CIRCULATING. P/U, START PUMPING, AND RIH TO STOP ON THE REMAINS AT THE SAME DEPTH. -THE TOP OF THE PACKER IS AT 7069', AND THE BOTTOM OF THE TAILPIPE IS AT 7125', WHICH SHOULD BE THE TOP OF THE CEMENT PLUG. 13:00 - 14:00 1.00 FISH P DECOMP CIRCULATE BOTTOMS UP, 12-BPM, 1920-psi FOR 470-Bbls (BU Vol = 410-Bbls). AT BU, A SLUG OF BLACK COLORED, rnnrea: iuew~uua n:ao:ai nm BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date ' From - To Hours Task M Code NPT Phase ~ Description of Operations 12/12/2009 13:00 - 14:00 1.00 FISH P DECOMP FOUL SMELLING VISCOUS FLUID CAME TO THE SURFACE, BUT ONLY LASTED FOR A FEW MINUTES. DECIDED TO PUMP ANOTHER 50-Bbls, BUT SAW NO MORE EVIDENCE OF THE FOUL SMELLING FLUID. 14:00 - 17:00 3.00 FISH P DECOMP RIG FLOOR PJSM. POH AND S/B DP AND DCS IN DERRICK. -1615-Hrs--S/B STAND #65. 17:00 - 17:30 0.50 FISH P DECOMP M/U PACKER PLUCKING BHA. -ITCO SPEAR DRESSED WITH 6.095 GRAPPLE, STOP SUB, BUMPER SUB, OIL JAR, PUMP OUT SUB, 12-EA COLLARS. TOTAL LENGTH = 402.89' 17:30 - 18:00 0.50 FISH P DECOMP CLEAR RIG FLOOR -BOOT BASKETS FILLED WITH 2 TO 3 -GALLONS OF METAL CUTTINGS. 18:00 - 20:30 2.50 FISH P DECOMP RIH WITH 4" DP FROM 402' TO 7071'. PU = 160K-LBS, SO = 135K-LBS. PUMP 1 AT 5.5-BPM WITH 200-PSI PUMP PRESSURE. -PLUCK PACKER REMAINS AT 7071'. PU = 162K-LBS WITH PACKER FISH 20:30 - 21:15 0.75 FISH P DECOMP CIRCULATE BOTTOMS UP WITH BOTH PUMPS PUMP AT 10-BPM WITH 1140-PSI PUMP PRESSURE. AT BU, A-20-BBL SLUG OF BLACK COLORED, FOUL SMELLING FLUID CAME TO THE SURFACE, NOTICED A SMALL AMOUNT OF CUTTINGS ACROSS THE SHAKERS FOR A FEW MIN. ~ 21:15 - 23:30 2.25 FISH P DECOMP PREPARE TO POH WITH FISH. ~~ -PUMP 20-BBL WEIGHTED SLUG -BLOW DOWN TOP DRIVE. -POH FROM 7071' TO 402' RACKING BACK 4" DP. 23:30 - 00:00 0.50 FISH P DECOMP POH FROM 402' RACKING BACK 4-STANDS OF COLLARS. 12/13/2009 100:00 - 00:30 ~ 0.50 ~ FISH P 00:30 - 01:00 0.50 FISH P 01:00 - 02:15 1.25 WHSUR P 02:15 - 02:45 ~ 0.50 ~ WHSUR ~ P 02:45 - 04:30 ~ 1.75 ~ WHSUR ~ P DECOMP LD PACKER PICKING BHA. -LD PACKER AND 7" PUP JOINTS BELOW THE PACKER. TOTAL LENGTH = 57.76' DECOMP CLEAR AND CLEAN RIG FLOOR. DECOMP PJSM ON PULLING PACKOFF WITH RIG CREW, WSL, TOOL PUSHER, FMC. -CHECK PRESSURE ON OA = 0-PSI. -VAC OUT STACK. -PULL WEAR RING. -PU RUNNING TOOL. -FMC TECH BOLDS. -PULL PACKOFF. DECOMP INSTALL NEW PACKOFF. -LD RUNNING TOOL AND OLD PACKOFF. -FMC TECH RILDS. DECOMP RU TEST EQUIPMENT. -TEST THE CASING HANGER VOID AND PACKOFF TO 5000-PSI FOR 30-MIN. TEST GOOD. -CLOSE BLIND RAMS AND PRESSURE TEST THE , WELLBORE TO 3500-PSI FOR 30-MIN CHARTED. TEST Printed: 12/28/2009 8:45:31 AM BP' EXPLORATION Page 9 of 16' Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2009 02:45 - 04:30 1.75 WHSUR P DECOMP -RD TEST EQUIPMENT. 04:30 - 05:30 1.00 CLEAN P DECOMP PJSM ON MU CLEANOUT BHA AND RIH. . MU CLEANOUT BHA. -8-1/2" BLADED JUNK MILL, SMOOTH GROUND STRING MILL. 4-EACH BOOT BASKETS, BIT SUB, BUMPER SUB, OIL JAR, PUMP OUT SUB, 12-EACH COLLARS. TOTAL LENGTH = 420.02' 05:30 - 09:30 4.00 CLEAN P DECOMP RIH FROM 420' TO 7040' ON 4" DP; INCLUDED SINGLING IN WITH 20-JOINTS OF DP FROM PIPE SHED. -TAG CEMENT PLUG AT 7117', AND FELT SOFT. -P/U ONE JOINT TO PREPARE FOR FLUID SWAP TO 9.2-PPG BRINE. 09:30 - 11:30 2.00 CLEAN P DECOMP PJSM. -MIX AND PUMP 20-Bbl Hi-Vis SWEEP, FOLLOW WITH 540-Bbls OF 9.2-ppg BRINE AT 8-BPM AND 730-PSI. 11:30 - 12:00 0.50 CLEAN P DECOMP MONITOR WELL AND SLOWDOWN TOPDRIVE. 12:00 - 13:00 1.00 CLEAN P DECOMP PJSM. SLIP AND CUT DRILLING LINE. 13:00 - 15:30 2.50 CLEAN P DECOMP PJSM. -GET PARAMETERS: P/U WT 162K-Ibs, S/O WT 135K-Ibs, Rot Wt 145K-Ibs, 80-RPM, FREE TORQUE 5K-Ib-Ft, 6-BPM, 450-psi. -START DRILLING AT 7117' AND MAKE 10' IN 5-MINUTES. DRILL DOWN THE NEXT FULL JOINT TO -7159' AT 1345-Hrs. -1420-Hrs--TAKE NEXT FULL JOINT TO TMD OF 7190' WITH VERY LITTLE RESISTANCE TO DRILLING AHEAD. STOP AND CBU 12.7-BPM AT 2500-PSI TO ENSURE CLEAN WELLBORE BEFORE MAKING UP NEXT JOINT WHICH SHOULD TAKE US THROUGH THE ESTIMATED BOTTOM OF THE CEMENT PLUG. -1520-Hrs--BREAK THROUGH CEMENT PLUG AT 7210' TMD. 15:30 - 20:30 5.00 CLEAN P DECOMP THEN CONTINUE TO 7222' TMD FOR THE BOTTOM OF , THE DP JOINT~CIRCULATING AT 12-BPM, 1920-psi, 80-RPM. GET LOTS OF SAND AND CEMENT FINES ACROSS THE SHAKER SCREENS. -1530-Hrs--M/U ANOTHER SINGLE AND CONTINUE QUICKLY TO BURY THE JOINT TO 7253' TMD. -1550-Hrs--M/U ANOTHER SINGLE, PUMP Hi-Vis SWEEP AND CIRCULATE 11.5-BPM, 1900-PSI, 80-RPM AND BURY IT AT 7285' at 1605-Hrs. -CBU 12-BPM, 2190-psi, 80-RPM TO GET THE SAND OUT OF THE WELLBORE. GET LOTS OF SAND IN THE RETURNS ACROSS THE SHAKERS. -1650-Hrs--M/U ANOTHER SINGLE AND RIH CIRCULATING 8.5-BPM, 1200-psi, 80-RPM. -CONTINUE TO RIH TO 7310'. LOST RETURNS BUT SHORTLY GOT BACK RETURNS. INITIAL LOSS RATE 262-BPH -PU TO 7285'. SLOWED PUMP RATE TO 5.5-BPH. TALK WITH TOWN ABOUT LOSS RATE PROBLEMS. SINCE WE STILL HAR RETURNS DECIDED TO CONTINUE IN HOLE. -1800-Hrs--TORQUING UP TO 10K. APEARED TO NOT BE rnntea: mzwzuua ts:aa:a ~ rtnn • BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours i Task Code NPT Phase Description of Operations 12/13/2009 15:30 - 20:30 5.00 CLEAN P DECOMP CLEANING HOLE. BROUGHT PUMPS UP TO 9.4-BPM. TORQUE DROPPED OFF AND CONTINUED IN HOLE. -1900-Hrs--CONTINUED TO WASH FROM 7280' TO 7379'. 9-BPM, 1220-PSI. 70-RPM. 120-BPH LOSS RATE. DECIDED TO PUMP 20-BBL HI VIS SWEEP EVERY TWO JOINTS TO MAKE SURE HOLE WAS BEING CLEANED. 20:30 - 21:30 1.00 CLEAN P DECOMP WHILE CIRCULATING PIT LEVEL, DECREASED. SLOWED PUMPS TO 4.6-BPM AT 375-PSI. LOSS RATE SLOWED TO 90-BPH. SLOWED PUMP RATE TO ALLOW FOR VAC TRUCKS TO ARRIVE. MIXED 100-BBL OF FRESH WATER TO 9.2-PPG TO MAINTAIN FILL. 21:30 - 00:00 2.50 CLEAN P DECOMP AFTER PITS FILLED, INCREASED PUMP SPEED TO 9-BPM AT 1275-PSI, 80-RPM, 5K-TQ. LOSS RATE 120-BPH. CONTINUE IN HOLE FROM 7379' TO 7453'. CIRCULATE 20-BBL HI VIS SWEEP EVERY 2 JOINTS. SHAKERS ~~ COMPLETELY LOADED WITH SAND EVERY TIME SWEEP RETURNS. 12/14/2009 00:00 - 02:30 2.50 CLEAN P DECOMP T WASH DOWN FROM 7453' TO 7550' AT _ ,~ 0030 Hrs PUMP 2 20 BBL HI VIS SWEE S C U AT 9-BPM AT 1260-PSI. 02:30 - 03:30 1.00 CLEAN P DECOMP LD ONE JOINT. BEGAN TO PULL 200K-LBS. DECIDED TO CIRCULATE ANOTHER SWEEP. PUMPED 20-BBL HI VIS SWEEP. CIRCULATE AT 12-BPM AT 1830-PSI, 80-RPM TO MAXIMIZE HOLE CLEANING. SWEEP LOADED SHAKERS WITH SAND WHEN IT RETURNED. 03:30 - 04:30 1.00 CLEAN P DECOMP PUMP OUT OF HOLE RACKING BACK 3-STANDS FROM 7537' TO 7253'. -ONCE ABOVE PERFS ABLE TO PULL DP WITH NO OVERPULL. -BLOW DOWN TOP DRIVE. 04:30 - 12:00 7.50 CLEAN P DECOMP POH LD 4" DP FROM 7253'. MAINTAIN HOLE FILL WITH 20-BPH LOSS RATE. -0700-Hrs--VD JOINT #101; 0730-Hrs--#121; 1000-Hrs--AT DRILL COLLARS; 1130-Hrs--CLEAN OUT JUNK BASKETS. 12:00 - 14:00 2.00 BUNCO RUNCMP CLEAR AND CLEAN RIG FLOOR. -R/U TO RIH WITH NEW 7", L-80, 29#, BTC-M TUBING STRING. -PJSM WITH BAKER COMPLETIONS TECHNICIAN, RIG CREW, AND WSL TO DISCUSS DROPPED OBJECTS FROM THE PERSPECTIVE OF EACH PERSON'S JOB WHILE RIH WITH 7". FLOORHANDS WERE CONCERNED ABOUT THE ELEVATORS, TOPDRIVE, AND ICE IN THE DERRICK. THE DERRCIKMAN WAS CONCERNED THAT A JOINT OF PIPE COULD BE DROPPED DOWN THE CATTLE CHUTE, AND THE ROUSTABOUTS IN THE PIPE SHED FOCUSSED ON DROPPING JOINTS OFF THE PIPE SKATE WHEN MOVING THEM FROM THE ELEVATOR TO THE PIPE SKATE. 14:00 - 19:30 5.50 BUNCO RUNCMP BRING ALL JOINTS UP THE PIPE SKATE USING A DONUT TO PROTECT THE PIN ENDS. -P/U WLEG AND RIH. M/U JOINT "A" AND BAKERLOK IT TO THE WLEG ASSEMBLY; TORQUE IT TO THE BTC-M STAMP. P/U RN-NIPPLE ASSEMBLY, BAKERLOK IT TO JT 80-RPM, 7K-TQ. V - - P IBC LAT rnrnea: iuzeuzuva o:ca:~i Nm i ~ BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 12/14/2009 14:00 - 19:30 5.50 BUNCO 19:30 - 20:00 0.50 BUNCO 20:00 - 23:30 3.50 BUNCO 23:30 - 00:00 0.50 BUNCO 12/15/2009 00:00 - 01:00 1.00 BUNCO 01:00 - 02:00 1.00 BUNCO 02:00 - 04:30 2.50 BUNCO Spud Date: 2/2/1998 Start: 12/7/2009 End: 12/17/2009 Rig Release: 12/17/2009 Rig Number: Phase Description of Operations RUNCMP "A", AND M/U TO STAMP. P/U BAKER S-3, 7" X 9-5/8" PACKER, INSPECT IT , BAKERLOK IT TO THE RN ASSEMBLY AND TORQUE IT TO THE STAMP. M/U THE R-NIPPLE ASSEMBLY TO THE BAKER PACKER ASSEMBLY AND RIH. -M/U ALL SUBSEQUENT JOINTS USING BEST-O-LIFE THREAD COMPOUND. 6400-Ib-ft, AVERAGE TORQUE TO M/U TO STAMP. -1540-Hrs--JOINT #20 RIH FOR 20-FULL JOINTS PER HOUR. -1610-Hrs--JT #30 -RUN IN HOLE FROM JOINT #30 TO #94 (3966' ). RUNCMP PJSM ON RU CONTROL LINE SPOOL AND RUNNING 3/8" SS CONTROL LINE. - RU SPOOL EQUIPMENT. -INSTALLED DUAL IN-LINE SWAGELOK CHECK VALVES AT THE LOWER END OF THE CONTROL LINE. VERIFIED VALVES WERE INSTALLED SO THAT THEY ALLOW FLOW FROM SURFACE TO THE IA. RUNCMP CONTINUE RUN IN HOLE WITH 7", L-80, 29#, BTC-M TUBING STRING. -RIH FROM 3966' TO 4977'. -SECURE CONTROL LINE WITH METAL BANDS, 1-PER JOINT. - TOTAL METAL BANDS = 28. TOTAL SS 3/8" CONTROL LINE = 1051' -MU TUBING HANGER. -PRESSURE TEST CONTROL LINE CONNECTION TO 5000-PSI FOR 10-MIN. -CONTINUE MAINTAIN HOLE FILL WITH 40-BPH LOSS RATE. RUNCMP CLEAR RIG FLOOR. -RD 7" TUBING RUNNING EQUIPMENT. RUNCMP CLEAR RIG FLOOR. -RD 7" TUBING RUNNING EQUIPMENT. -FMC TEST CONTROL LINE CONNECTIONS TO 5000-PSI FOR 10-MIN. TEST GOOD. -LAND 7" TUBING. -FMC TECH RILDS. RUNCMP PJSM WITH LRS, RIG CREW, TOOLPUSHER, BAKER COMPLETIONS, WSL. -RU LRS SO THAT THEY ARE ABLE TO PUMP DOWN TUBING AND IA. -PRESSURE TEST LINE TO 3500-PSI. RUNCMP REVERSE CIRCULATE 125-BBLS OF CORROSION INHIBITED 9.8-PPG BRINE DOWN THE IA. PUMP 3-BPM AT 37-PSI. RECEIVED RETURNS THROUGHOUT CIRCULATION. -0300-Hrs--PUMP 200-BBLS OF 9.8-PPG BRINE DOWN TUBING. PUMP 3-BPM AT 28-PSI.AT 198-BBL AWAY, RECEIVED -2-BBL RETURNS FROM IA. -0422-Hrs--DROP BALL AND ROD. -PUMP 25-BBLS DIESEL PUMP AT 2-BPM. SWITCHED Printetl: 7Z/2W2VV9 8:4b:31 AM . ! • BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date Fram,- To Hours ~ Task Code NPT 'Phase Description of Operations 12/15/2009 102:00 - 04:30 2.50 BUNCO RUNCMP OVER TO RIG AND PUMPED 90-BBL BRINE 04:30 - 11:00 6.50 BUNCO RUNCMP 11:00 - 13:00 2.00 BUNCO RUNCMP 13:00 - 13:30 0.50 BUNCO RUNCMP 13:30 - 14:30 1.00 BUNCO P RUNCMP -PUMPED FLUID ON LOCATION. BALL AND ROD DID NOT SEAT. SHUT IN WELL, WAITING ON FLUID. SHUT IN THE WELL. SHUT THE TUBING AT THE CIRCULATING MANIFOLD SO THAT PRESSURE CAN BE MONITORED. SHUT IN THE IA AT THE MANIFOLD IN THE CELLAR SO THAT THE PRESSURE CAN BE MONITORED. -TUBING = 0-PSI, IA = 0-PSI. CALL AOGCC TO INFORM THAT WE S/I THE WELL. -CHANGEOUT BALES ON TOPDRIVE TO LONGER ONES TO ENABLE MOVING THE TUBING WHILE CONNECTED TO THE CIRCULATING MANIFOLD. -WAITING ON 3-TRUCKLOADS OF 9.2-PPG BRINE. -CALL ADW RWO ENGINEER AND SUPERINTENDENT AND DISCUSS OPTIONS. WILL WAIT ON 9.2-PPG BRINE FROM MI. FIRST TRUCK ARRIVED AT 0930-Hrs. -0930-Hrs--HOLD H2S DRILL. ALL CREW, TWO CH2MHILL DRIVERS, TWO FMC TECHS, ONE BAKER TECH AND WSL ACCOUNTED FOR. -1000-Hrs--TAKE ON FLUID FROM FIRST TRUCK. -1030-Hrs--WELL PRESSURES: TUBING 0-PSI, IA 0-PSI. CALL DOWNHOLE DIAGNOSTICS AND ARRANGE FOR FLUID LEVEL SHOTS FOR THE IA. WAIT ON DOWNHOLE DIAGNOSTICS TO PERFORM FLUID LEVEL SHOTS. TUBING 0-PSI, IA 0-PSI. CANNOT GET A FLUID LEVEL PAST THE CENTRALIZER USED FOR THE BOTTOM OF THE 3/8" SS LINE AT 1000'. -R/U ECHOMETER UNIT ON THE TUBING, BUT DO NOT GET A DEFINITIVE FLUID LEVEL. DHD TECH THOUGHT THAT THE FLUID LEVEL IN THE TUBING MAY BE AT -600'. -R/D ECHOMETER EQUIPMENT AND R/U CIRCULATING LINE TO TUBING TO PREPARE TO PUMP 9.2-PPG BRINE DOWN TUBING. CLOSE IA AND PUMP DOWN TUBING WITH 9.2-PPG BRINE AND CATCH FLUID AT -500' TO 600'. PUMPING 3-BPM AT 40-PSI. PUMP 50-Bbls AND PRESSURE INCREASES TO 78-PSI. PJSM TO DISCUSS THE PIPE MOVEMENT TO ATTEMPT PTO JAR THE BALUROD DOWN ONTO THE RHC-M PLUG 'SEAT. ASKED FLOORHANDS TO GET OFF THE RIG FLOOR, BUT GET IN A POSITION TO BE ABLE TO WATCH THE TOP OF THE TIW VALVE TO ENSURE FLUID DOES NOT SPILL OVER IF THE YO-YO OPERATION CASUES FLUID TO MOVE UP THE TUBING. -FMC BOLDS. PULL TUBING HANGER TO RIG FLOOR WITH SAME COMPLETION P/U WEIGHT OF 165K-Ibs. -BRING HANGER 20' ABOVE RIG FLOOR AND ALLOW THE STRING TO DROP IN 5' INCREMENTS AND APPLYING THE BRAKES. REPEAT ONE MORE TIME TO 20' ABOVE RIG FLOOR. THEN P/U TO 30' ABOVE RIG FLOOR AND APPLY BRAKES SEVERAL TIMES ON THE WAY BACK DOWN TO RIG FLOOR FOLLOWING DIRECTIONS FROM BAKER COMPLETIONS TECH AND WSL. Printed: 12/28/2009 8:45:31 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Event Name: WORKOVER Start: 12/7/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1.7/2009 Rig Name: DOYON 16 Rig Number: Page 13 of 16 ~ Spud Date: 2/2/1998 End: 12/17/2009 Date ~ From - To Hours' Task I Gode NPT Phase I Description of Operations 12/15/2009 13:30 - 14:30 1.00 BUNCO RUNCMP -FMC TECHS EXAMINE SEAL ON HANGER AND SEE THAT IT WAS DAMAGED WHEN PULLING OUT OF THE HANGER. -1400-Hrs--BREAK OUT XO FROM HANGER -1405-Hrs to 1415-Hrs--FMC TECHS REPLACE HANGER SEAL. M/U XO TO HANGER AND RIH TO SEAT IN TUBING SPOOL. 14:30 - 16:00 1.50 BUNCO RUNCMP ENSURE IA IS CLOSED AND BEGIN TO BULLHEAD DOWN TUBING AT 2-BPM, 30-40-psi. APPEAR TO HIT FLUID AT -500'. -INCREASE PUMP RATE TO 3-BPM: 49-Bbls PUMPED, TBG 100-psi, IA 0-psi; 71-Bbls, Tbg 134-psi, IA O-psi; 81-Bbls, Tbg 138-psi, IA 50-psi. -INCREASE PUMP RATE TO 5-BPM: 102-Bbls, Tbg 190-psi, IA 50-psi; 110-Bbls, Tbg 220-psi, IA 50-psi; 119-Bbls, Tbg 230-psi, IA 50-psi; 127-Bbls, Tbg 240-psi; 145-Bbls, Tbg 247-psi, IA 50-psi. -CALL ADW RWO ENGINEER AND DECIDE TO R/U SLICKLINE. SLICKLINE HAD A UNIT THAT WAS ON THE HOOK VIA AN EARLIER CALL AND THEY BEGAN TO ROLL TO OUR LOCATION AT 1545-Hrs. -START BLEEDING OFF CIRCULATING LINE AT 1545-Hrs. 16:00 - 19:30 3.50 BUNCO RUNCMP WAIT ON SLICKLINE AND USE CONSTANT HOLE-FILL OF -1-BPM. -CONTINUE BLEEDING OFF CIRCULATING LINE AND GET BACK 30-Bbls AT 1630-Hrs WHEN IT FINALLY QUIT. 19:30 - 22:00 2.50 BUNCO RUNCMP PJSM -RIG UP SLICKLINE. DISCUSSING HAZARD INVOLVED AND DROPPED OBJECTS. -PICK UP SLICKLINE TOOLS TO RIG FLOOR. -R/U TOOLS. 22:00 - 23:00 1.00 BUNCO P RUNCMP PSI TEST FULL WELL CONTROL EQUIPMENT TO 500 PSI. -B/D CHOKE. -FILL HOLE AT 1 BPM TAKING 11 BBLS TO FILL. -RIH WITH LIB AND TAG FISH AT 4900' SLICK LINE MEASUREMENT. -BUMP FISH 3 TIMES AND FISH DID NOT MOVE. HOLD SLICK LINE WT ON FISH AND ATTEMPT TO PRESSURE U P. -PUMP AT 2.5 BPM WITH A MAX PSI OF 85. PUMP 15 BBLS AND HAD SWS BUMP FISH 3 MORE TIMES WHILE PUMPING WITH NO PSI INCREASE. -PUMPED A TOTAL OF 25 BBLS ATTEMPTING TO PRESSURE UP. 30 PSI NOTED TO BE ON IA AFTER PUMPS SHUT OFF. -BLEED BACK 11 BBLS AFTER SHUT DOWN. HOLE WAS STATIC. 23:00 - 00:00 1.00 BUNCO RUNCMP POH WITH LIB FROM 4900' TO SURFACE. -NOTED PIN END ON IMPRESSION BLOCK. 12/16/2009 00:00 - 00:30 0.50 BUNCO RUNCMP BLOW DOWN KILL LINE. -L/D LIB. -M/U 5.07" BELL GUIDE WITH 2.5" JUC. -9 BPH LOSS RATE. 00:30 - 02:00 1.50 BUNCO RUNCMP RIH WITH SWS TO RETRIEVE BALL AND ROD. -POH WITH BALL AND ROD. Printed: 12/28/2009 8:45:31 AM • BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: ' ~ Date From - To Hours Task Code NPT Phase Description of Operations 12/16/2009 00:30 - 02:00 1.50 BUNCO RUNCMP -BALL AND ROD IN GOOD SHAPE. RING ON BALL GIVING INDICATION IT WAS ON SEAT. SMALL FLAT SPOT ON BALL ABOVE RING. -SPOKE WITH TOWN ENGINEER ABOUT CONDITION OF BALL AND ROD. DISCUSSED OPTIONS OF PULLING RHC PLUG AND AGREED TO RIH WITH PRN PLUG (SOLID PLUG). 02:00 - 03:00 1.00 BUNCO RUNCMP R/U TOOLS TO PULL RHC PLUG. -P/U 7" HWGS AND TOOLS. 03:00 - 08:00 5.00 BUNCO RUNCMP RIH TO 4903' SLM. 08:00 - 12:00 4.00 RU 12:00 - 12:30 0.50 RU 12:30 - 13:00 0.50 13:00 - 14:00 1.00 14:00 - 14:30 0.50 R 14:30 - 15:20 0.83 R 15:20 - 16:00 I 0.67 -POH WITH RHC. RHC-M PLUG HAD MARKS ON THE DOGS APPROPRIATE TO BEING SET CORRECTLY. -RIH AND USE RIG PUMP TO PUSH THE PRN PLUG THROUGH THE R-NIPPLE. -CONTINUE RIH AND HANG PRN PLUG BETWEEN THE PACKER AND THE RN NIPPLE AT 4888'. USE HOLE FILL TO KEEP TUBING FULL. -CALL OUT LRS TO BRING 150-Bbls OF DIESEL FOR PACKER SETTING AND FREEZE PROTECTION. RUNCMP WAIT ON LRS. RUNCMP PJSM WITH SCHLUMBERGER SLICKLINE CREW, LRS CREW AND PE, BAKER COMPLETIONS TECH, RIG CREW, TOOLPUSHER, AND WSL TO DISCUSS THE OPERATIONS REQUIRED FOR FREEZE PROTECTING THE TUBING, SETTING THE PRN PLUG, SETTING THE PACKER, AND TESTING THE TUBING AND IA. RUNCMP R/U LRS AND PRESSURE TEST THEIR LINES TO 4000-psi. RUNCMP LRS BULLHEAD 26-Bbls OF DIESEL WITH INITIAL TEMP OF 100-F INTO THE TUBING AT 1-BPM, 0-psi. SEE PRESSURE CLIMB TO 400-psi. SCHLUMBERGER SET PRN PLUG DOWN ONTO THE RN-NIPPLE AND ATTEMPT TO ENGAGE. HAVE LRS START PUMP AND TRY TO HELP SET THE PLUG WITH 2-BPM AT 400-psi. -WSL S/D LRS AFTER ADDITIONAL 20-Bbls PUMPED. TOTAL DIESEL PUMPED INTO TUBING 46-Bbls. -SCHLUMBERGER KEEP TAPPING DOWN ON PLUG, LATCH AND SHEER OFF AT 1400-Hrs. RUNCMP POH WITH SLICKLINE. RUNCMP M/U PRONG AND RIH AND ENGAGE IN PRN PLUG. -1515-Hrs--LRS PRESSURE UP ON TUBING TO 500-psi TO CONFIRM THE MECHANICAL INTEGRITY OF THE PRONG AND PLUG. HOLDING ROCK SOLID. -POH WITH SLICKLINE. -CLOSE BLINDS. BREAK LUBRICATOR OFF SLICKLINE BOP. BREAK BOP OFF DUTCH RISER SET IT ASIDE. CAP THE DUTCH RISER. -SUCK FLUID OFF THE TOP OF THE BLINDS. RUNCMP LRS START PRESSURING UP THE TUBING WITH DIESEL. PUMP 2.2-Bbls TO REACH 3600-psi ON THE CHART. PRESSURE SLOWLY DROPPED TO 3500-psi AND HELD STEADY AT 3500-psi FOR THE LAST 20-MINUTES OF A Printed: 12/28/2009 8:45:31 AM '~ . • BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date.. From - To Hours Task Code NPT- Phase Description of Operations 12/16/2009 15:20 - 16:00 0.67 BUNCO RUNCMP TOTAL CHARTED TEST TIME OF 35-MINUTES. 16:00 - 18:00 2.00 BUNCO P RUNCMP BLEED TUBING TO 1500-psi. -MOVE SCHLUMBERGER SLICKLINE EQUIPMENT OUT OF THE RIG THROUGH BEAVALATOR AND PIPE SHED. -LRS START PUMPING INTO IA. PUMP 10.3-Bbls TO GET TO 500-psi. -BLEED OFF AIR IN IA. REPLACE PRESSURE SENSOR ON IA LINE. -LRS BUILD PRESSURE IN IA TO 500-psi, TAKES 4.8-Bbls TO GET TO 500-psi. -BLEED OFF IA TO 0-psi. -LRS BUILD PRESSURE IN IA TO 500-PSI, BUT PRESSURE BUILT AS SOON AS THE PUMP STARTED UP, SO CONTINUE TO BUILD TO 3500-psi. TOOK 2.5-Bbls TO REACH 3500-psi. TOTAL IA FILL IS 17.6-Bbls OF DIESEL. -CONTINUE TO HOLD AND CHART PRESSURES OF 3600- si ON IA 2200- si ON TUBING, AND 100- si ON OA FOR 30 MIN. -GOOD TEST. -TUBING HAS 46 BBLS DIESEL DOWN TO 1,238' WITH 9.2 PPG BRINE BELOW. -IA HAS 17.6 BBLS DIESEL DOWN TO 687' WITH 9.8 PPG BRINE BELOW. -ALL TEST WITNESSED BY WSLS AND TALIB SYED, CONSULTANT FOR EPA. AOGCC REP LOU GRIMALDI WAIVED STATES RIGHT TO WITNESSED. 18:00 - 19:00 1.00 BUNCO RUNCMP BLEED OFF ALL PSI. -L/D DUTCH RISER. -SET TWC WITH FMC. -TEST TWC FOR 10 CHARTED MIN. FROM ABOVE TO 3500-psi WITH LRS. -GOOD TEST. -BARRIERS ARE: TESTED TWC AND PRN PLUG AND PRONG. 19:00 - 20:00 1.00 BUNCO RUNCMP R/D B/D ALL CIRCULATION EQUIPMENT. -R/D LITTLE RED. 20:00 - 00:00 4.00 BOPSU P WHDTRE PJSM FOR N/D STACK. -DRAIN STACK. -REMOVE PIPE AND BLIND RAMS. -CLEAN SAND AND DEBRIS OUT OF RAM CAVITIES. -R/D MUD MANIFOLD AND #2 MUD PUMP. -BREAK BOLTS ON STACK AND RACK ONTO PEDESTAL. -CLEAN UP WELL HEAD AND BRING IN ADAPTER FLANGE. 12/17/2009 00:00 - 06:00 6.00 WHSUR P WHDTRE PJSM N/U ADAPTER FLANGE AND REMOVE ICE FROM THE DERRICK. -TERMINATE 3/8" CONTROL LINE. -N/U ADAPTER FLANGE. CAN NOT GET TO HOLD PRESSURE. PUMP UP TO 5000 psi AND DROPS INSTANTLY. NO VISIBLE SIGNS OF LEAKS. RETOROUE LOCK DOWN SCREWS AND ATTEMPT TO TEST WITHOUT SUCCESS. IT APPEARS TO BE LEAKING AROUND CONTROL LINES. DISCUSS PULLING ADAPTER FLANGE OFF AND PLACING A SWEDGE ON CONTROL LINE ON TOP OF HANGER. FMC ~~ ib~ r ~~ Pfintetl: 7LLtf/2UV9 tl:45:37 AM • • BP EXPLORATION Page 16 of 16 - Operations.. Summary Report Legal Well Name: GNI-03 Common Well Name: GNI-03 Spud Date: 2/2/1998 Event Name: WORKOVER Start: 12/7/2009 End: 12/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task... Code NPT Phase Description of Operations 12/17/2009 00:00 - 06:00 6.00 WHSUR P WHDTRE CHANGE TEST GAUGES AND WHEN PRESSURED UP TO 5300-psi IT SLOWLY DROPPED TO 5100-psi. NOTICED A SMALL VOLUME LEAKING OUT OF CONTROL LINE VALVE SO PULLED VALVE TO TIGHTEN UP SWEDGE. -REMOVE ICE FROM DERRICK. -TEST ADAPTOR SPOOL TO 5000-psi FOR 30-MINUTES, SUCCESSFULLY. 06:00 - 07:00 1.00 WHSUR P WHDTRE PJSM. N/U TREE 07:00 - 10:00 3.00 WHSUR P WHDTRE FILL TREE WITH DIESEL. DIESEL TRANSFER PUMP FAILED. -PJSM TO DETERMINE SAFEST WAY TO GET DIESEL INTO TREE. TRANSFER DIESEL BY HAND AND POUR INTO TOP OF TREE WITHOUT ANY SPILLS OR MISHAPS. -PRESSURE TEST TREE TO 5000-psi FOR 10-MINUTES FOR SOLID TEST. DRAIN TREE AND R/D TEST EQUIPMENT. 10:00 - 12:00 2.00 WHSUR P WHDTRE PJSM. INSTALL DSM LUBRICATOR AND TEST TO 500-psi. PULL TWC AND IN TALL -RELEASE RIG AT 1200-Hrs. Printed: 12/28/2009 8:45:31 AM • ' ~ GNI-03, Well History (Post Rig Workover) Date Summary 12/23/2009 WELL S/I ON ARRIVAL. PULL P-PRONG FROM 4879' SLM. UNABLE TO LATCH PLUG BODY ON FIRST ATTEMPT TO PULL ~ 4882' SLM / 4907' MD. FW HP=150/0/0 12/24/2009 PULL 7" PRN PLUG BODY FROM 4882' SLM / 4907' MD. DRIFT W/ 4.60" CENT, 3" S-BAILER TO 7488' SLM/7513' MD. FWHP=150/0/0 WELL L ,DSO NOTIFIED. 12/25/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 80 / 0 / 0 PSI. RUN JEWELERY LOG FROM TD TO SURFACE. TAGGED TD AT 7511'. FINAL T/I/O = 80 / 0 / 0 PSI. WELL LEFT SHUT IN. JOB COMPLETE. Page 1 of 1 TREEr 6-3/8" CALICO WELLHEAD= FMC ACTUATOR= AXELSON KB. ELEV - 50.4' BF. ELEV..- 23.0' KOP - 2450' Max Angle = 36 @ 5628' Datum MD = 6662' Datum TV D= 6000' SS ~' T' SAFET ES: 3/8" SS OPEN ENDED CONTROL LINE G ~ I -O ~ STRAPPED TO OUTSIDE OF 7"TBG DOWN TO JOINT #23 (USED 28-SS BANDS) 1010'. 1010' ~ 3/8" SS OPEN-ENDED CONTROL LINE FOR Nff'ROGEN BLANKET 13-3/8" CSG, 68#, L-80, ID = 12.415" 2609' TOP OF 13-3/8", 72" CSG 2609' Minimum ID = 5.963" @ 4238' HES R NIPPLE 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 4154' 4168 I-I HES TYPE "H" ES CEMENTER 4$43' ~ 7" HES R NIPPLE, ID = 5.963" I 4874' 9-5/8" X 7" BKR S-3 PKR, ID = 6.00" 17" TBG, 26#, L80, .0382 bpf, ID = 6.276" I PERFORATION SUMMARY REF LOG: SWS ARRAY INDUCTION LOG 05/07/98 ANGLE AT TOP PERF: 33 @ 7315' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 7315 -7335 O 11/28/98 4-1/2" 5 7620 - 7640 C 06/06/98 PBTD I~ 7740' 9-5/8" CSG, 47#, L-80, ID = 8.681" 7822' TD 7840' - 490T --~ 7" HES RN NIPPLE, ID = 5.77" ' ~ Iled „ 2Zydg 4977' 7" WLEG 7550' ~TOPOF FILL (12/13/09) FG v w~ w~ S ~ 7SS8 ~ ~`` °. U y[~ 1•/G jo DATE REV BY COMMENTS DATE REV BY COMMENTS 06/06/98 ORIGINAL COMPLETION 09/21/01 MB/KAK CORRECTIONS 12/17/09 D16 RWO 12/17/09 SV DRLG DRAFT PRUDHOE BAY UNff WELL: GNI-03 PERMff No: 1971890 API No: 5002922820-00 Sec. 25, T11 N, R15E, 2845.96 FEL 695.93 FNL BP Exploration (Alaska) ' GNI-03 : Sundry 309-235 ~ ~ Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 20, 2009 10:39 AM To: 'Nadem, Mehrdad' :' T'D / ~ - ~g . ;~. ~ l,~ ,~. ~,~ Subject: RE: GNI-03 : Sundry 309-235 ~ ~` ~ ~ ~~' ~ _ __...._ ~' As per our conversation , please add a 1000 psi BOP body test before pulling the hanger to floor. This will ensure a tested system in case something unforeseen happens when pulling the hanger. As you stated , you will replace the hanger and perform full BOP test before pulling the rest of the completion. ! will add this to the procedure below (will handwrite this in step two - proposed rig procedure ) and file it along witli the sundry. . , . . .. _ ., '.~" Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) `~i~~~~{ ~~ ~.~`~l ~~; ~ ~(~~~ 444-3433 (cell) From: Nadem, Mehrdad [mailto:NademM@BP.com] Sent: Friday, November 20, 2009 10:04 AM To: Schwar~, Guy L (DOA) Subject: RE: GNT-03 : Sundry 309-235 Guy: thank you for your comments, please review the revised steps below. I look forward to hearing from you. Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cel I: 907/440-0213 Emnil: nademmC~bp.com Guy, This is to request AOGCC's approval to modify the GNI-03 RWO program. We propose to change the existing tubing hanger with a new tubing with TWC installed in prior to testing the BOPs. The BPV profile in the existing tubing hanger and the 7" tubing is eroded. The condition of the tubing would render setting a barrier a risky endeavor. GNI-03 perforations will be secured with ~60' of river sand and 50' of cement cap. The cement plug will be pressure tested to 1,000 psi. Please review the proposed changes both for pre-rig prep work and RWO procedure. GNI-03 in a slurry injector, as such, the potential for a gas kick does not exist. The estimated time to change out the tubing spool is three hours. I am availabie to provide you with additional information. Regards, 11 /20/2009 ` GNI-03 : Sundry 309-235 ~ ~ Page 2 of 2 Mehrdad Nadem Phone:907/564-5941 Ce) I: 907/440-0213 Pre-Rig Pree~Work: 1. A. RIH and tag top of fill. Bottom was tagged at ~,313' MD on June 15, 2009. B. Place 60' of 20/40 mesh river sand on top of the fill. The intent is to have ~60' of sand above the top perF interval a# 7,315' MD. C. Place 50' of 17 ppg Class G cement on top of the river sand plug placed in the welibore. D. Pressure test the cement plug to 1,000 psi for 10 minutes after cement reaches 500 psi compressive strength. It would take 12 hours for cement to reach 500 psi compressive strength per Schlumberger. Temperature at 7,300' MD is 83 F. ~4 bbl of cement is required for placing a 50' cement plug. 2. Drift tubing for chem cut. 3. Chemical cut the 7" in the upper 10' of the first full joint above the packer at 4,180' MD. Reference tubing tally dated 5/12/98. 4. Circulate well with kill weight fluid and diesel thru the cut. 5. Pressure test T x IA to 1,000 psi to establish that the cement plug is holding. OA shoe is open - no MIT- OA test 6. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage. Proposed Procedure / , j ,, li•t.-G~',~ ~ ~ ~~ 1. MIRU Workover Rig. Circulate out freeze protection fluid and circulate the well to clean seawater. 2. ND the tree. NU BOPE with 3-1/2" x 6" and 4-1/2" x 7" VBRs, ~~.~ ~~rF~ i c~o~=~ ~ S~. 4 a~~ «s'~" °''' ~U~' 3. PU spear and spear the tubing below the hanger. 4. Pull the tubing hanger to the floor. LD the tubing hanger. LD one joint. 5. MU a new tubing hanger with a TWC on a landing joint. 6. Land the tubing hanger. LD the landing joint. 7. Test BOPE with 3-1/2" x 6" and 4-112" x 7" VBRs. Pressure test to 250 psi low, 3,500 psi high with 4" and 7" test joints. 8. Pull and LD 7" tubing string to the cut. 9. Mill the 9-5/8" x 7" packer. 10. RIH and spear the packer and tubing tail. 1l. RU and RIH with 9-5/8" scraper. 12. Pressure test the 9-5/8" casing against the cement plug to 3,500 psi for 30-charted minutes. 13. PU clean-out BHA. RIH and drill out the cement plug and clean out the debris and fill to 7,550' MD. 14. Run 7" 29# L-80 completion with Baker S-3 packer and RRN plug on seat. Run 3/8" open-ended control line to 1,000' on T' tubing. Position packer at ±4,850' MD (near SV1 marker). 15. Freeze protect the tubing and IA. Pressure up and set the packer. 16. Test tubing and IA to 3,500 psi. 17. Set BPV. ND BOPE. NU and #est tree. RDMO. 11 /20/2009 • s ~~ ~ ~ ~ ~ ~ ~~ ~ ~R~ ~ € i ~F ~ ~~ ~~~~~;~ ~ a 4=~ ~ ~ " ~ ~ ~~ ~ ~ r ,` ~ ~. ' SARAH PALIN, GOVERNOR ~ ~~ :~~.,~ ~,~ ~ °~~ L~ F ~~~ ~ ~~ ~~ ~ i,~ ~ 6~ y' ~S'~A Quj A~D ~S ~i'~ 333 W. 7thAVENUE, SUITE 100 CO1~T5ERQATIOI~T COrII-IISSIOrT / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. David C. Reem Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99516-6612 ~~: .~~''~`~~' ~ ~ +.~ L ~ ` ~ ~ ~ ~ ~ .~~ ~~~ Re: Prudhoe Bay Field, Prudhoe Undefined Gas, PBU G1VI-03 ~ / Sundry Number: 309-235 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Comrnission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Corrunission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the ne~rt worl~ng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Corrunission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ,~~day of July, 2009 Encl. ~ ~~p ',~, . (J~"' .0~ STATE OF ALASKA ~~f'm~I~~~ ~-~~ ,~.1~ ALA~OIL AND GAS CONSERVATION COM~ION ~~"~ ` APPLICATION FOR SUNDRY APPROVAL~ JUL 0~~~0~ 20 AAC 25.280 ~t,3 Class I Disposal Well 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ~ ~~ n~~• ~~ f~~~~ ^ Alter Casing ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Sus~~~~~~ ~~II ^ Change Approved Program ~~ Pull Tubing ^ PerForate New Pool ^ Waiver ;~ Other ~~~~p~ 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 197-189 ~ 3. Address: ,~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22820-00-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU GNI-03 ~ Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 1 Q. KB Elevafion (ft): 11. Field / Pool(s): '~ ~~. S ADL 028324 • 50.9' ~ Prudhoe Bay Field / Pr~ttli hAe 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7840' - 7036" 7740' 6952' None None in Len h Siz MD TVD Burst Colla se Structural n t r 11 ' " 11 ' 110' 1 30 20 Surface 4132' 1-3/8" 4161' 3987' 4930 2270 Interme ia e Pr cti n 77 4' -/" 7 22' 7021' 70 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7315' - 7640' 6597' - 6869' 7", 29# x 7", 26# L-80 4263' Packers and SSSV Type: 9-5/8" x 7" Baker'SABL-3' Hydro-Set packer Packers and SSSV MD (ft): 4203' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ^ Development ~ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 15, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ~ WDSPL ~ Commission Representative: , 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Nam avid Reem Title Engineering Team Leader Mike Bil1, 564-4692 Prepared By Name/Number: Signature r,-L~- Phone 564-5743 Date ~~a ~ Terrie Hubble, 56a-a628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~ ~,~~ ^ Plug Integrity ~OP Test ~Mechanical Integrity Test ^ Location Clearance Other: ~ J°'rQ d@Se \ C"c~.'r'.:~;5~- C a~~ ~,pS' i•n~~+~\ ~.V i"~Q~~~~G~ ~ S~ \- Subsequent Form Required: ~-~, APPROVED BY `7 /L~ A roved B: COMMISSIONER THE COMMISSION Date //~ Form 10-403 Re~ed 06/2006 ~RIGINAL ~ ~~~.~~~~ ~~~o~~ >~ Submit In Duplicate .~ ~s .r ~^ - ~\\n„~ ~~ r ~~~~~~ ~ ~~~~J • • ~ ~ ~P ~ ~~~~ ~ `~~a~ Y~' r GNI-03 Rig Workover Scope of Work: Pull 7" completion. Mill 9-5/8" x 7" S-3 injection packer. Run a new string of 7" completion. GNI-3 is part of the Grind & Inject project. The well is permitted by the EPA (AK-11008-A) for Class I disposal and by the AOGCC for Class II injection (AIO-4E). There is no indication of TxIA or IAxOA communication or production casing leaks. A caliper log was run 04/13/09 showing significant tubing " erosion/corrosion damage: up to 52% general wall loss, reducing the collapse to 1040 psi. Casing below the tubing tail is in fair condition with up to 20°/a general wall loss and 33% max wall penetration. Well Type: Injector Estimated Start Date: September 15, 2009 Staff Engineer: Mike Bill Intervention Engineer: Mehrdad Nadem Pre-Ria Work Reauest: C 1 A. RIH and tag top of fill. Bottom was tagged at 7,313' MD on June 15, 2009. B. Place 60' of 20/40 mesh river sand on top of the fill. The intent is to have ~60' of sand above the top perf interval at 7,315' MD. C. Place 50' of 17 ppg Class G cement on top of the river sand plug placed in the wellbore. D. Pressure test the cement lu to 1,000 si for 10 minutes. ~ E. 2 Chemical cut the 7" in the upper 10' of the first full joint above the packer at 4,180' MD. Reference tubin tall dated 5/12/98. IBP at 500' MD. Pressure up IA to 1,500 psi when testing the IBP. This is to tubing ur tin the IBP - 7" tubing is eroded. e aliper log dated 11 /13/2008. F 4 A. Pressure test the IB , i. he ma ~' tion pressure on GNI-03 could not exceed .,400 psi is 1.2 times the maximum possible in~e ' re in GNI-03. . irculate well with kill wei ht fluid and diesel thru the cut. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time . PPPOT-T & IC. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proaosed Procedure 1. MI kover Rig. ND tree. NU and test BOPE wi x 6" and 4-1/2" x 7" VBRs. Pressure test to 250 p 3,400 psi high with 4" a " st joints. Circulate out freeze protection fluid and circulate the well to c eawat 2. RU slick line and retriev . 3. Pull and LD " ' g string to the cut. ~~~ ~~_~,,` 4. Mi -5/8" x 7" packer. ~ . , • ~~~~~~~~~~ ~ ~t ~ ~; ~~ . nd spear the packer and tubing tail. ~--~ - 6. RU an ' 9-5/8" scraper. 7. Pressure test the -" ing against the cement plug to 3 si for 30-charted minutes. 8. PU clean-out BHA. RIH and ri e cement pl clean out the debris and fill to 7,550' MD. 9. Run 7" 29# L-80 completion with Baker - r. Run 3/8" open-ended control line to 1,000' in tA. Position packer at ±4,850' MD (n 1 marker). 10. Displace the IA to packe ' corrosion inhibitor brine and diese eze protect). Drop ball and rod and set the er. 11. Test t~ and IA to 3,400 psi. Freeze protect with diesel to 2200' MD. 1 PV. ND BOPE. NU and test tree. RDMO. • • Page 1 of 2 Maunder, Thomas E (DOA) From: Nadem, Mehrdad [NademM@BP.com] Sent: Monday, July 13, 2009 4:04 PM To: Maunder, Thomas E (DOA) Cc: Reem, David C; Bill, Michael L(Natchiq); Regg, James B(DOA) Subject: RE: GNI-03 (197-189) Tom: I added the requested verbiage to Step 3- please let me know if there are any other questions. Mehrdad Nadem Phone:907/564-5941 Cel I: 907/440-0213 Emnil: nademmC~bp.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Gents, Looking at the new procedure versus the prior, no back-up pressure is planned on the IA when the tubing is tested in step 3 of the new procedure. Is any backup pressure required? Thanks in advance. Tom Maunder, PE AOGCC Proposed Procedure 1. MIRU Workover Rig. 2. Circulate out freeze protection fluid and displace it with clean seawater. 3. RU E-line. RIH and install 7" IBP through the tree at -500' MD. Pressure test the IBP to 3,400 psi for 10 minutes while applying 1,500 psi to IA.. 4. ND tree. NU and test BOPE with 3-1/2" x 6" and 4-1/2" x 7" VBRs. Pressure test to 250 psi low, 3,400 psi high with 4" and 7" test joints. 5. RU slick line and retrieve the IBP. 6. Pull and LD 7" tubing string to the cut. 7. Mill the 9-5/8" x 7" packer. 8. RIH and spear the packer and tubing tail. 9. RU and RIH with 9-5/8" scraper. 10. Pressure test the 9-5/8" casing against the cement plug to 3,400 psi for 30-charted minutes. 11. PU clean-out BHA. RIH and drill out the cement plug and clean out the debris and fill to 7,550' MD. 12. Run 7" 29# L-80 completion with Baker S-3 packer. Run 3/8" open-ended control line to 1,000' in IA. Position packer at ±4,850' MD (near SV1 marker). 13. Displace the IA to packer fluid (corrosion inhibitor brine and diesel for freeze protect}. Drop ball and rod and set the packer. 14. Test tubing and IA to 3,400 psi. Freeze protect with diesel to 2200' MD. 15. Set BPV. ND BOPE. NU and test tree. RDMO. I am available to further discuss details of the planned GNI-03 operations. Mehrdad Nadem 7/13/2009 Page 1 of 2 ~ Nlaund~+r, Thamas ~ {QC~Aj Fr+~m: Nadem, Mehrdad [MademM(~iBP.com] S~en#: Monday .~ufy 13, 2~Q9 1:1~ PM To; Maunder, Thpmas E (~OA) Cc; R~em, Qavid ~; Bitl, Michae{ L(Natchiq); Regg, Ja~tes B(QQA) Subject: R~: GI~1-Q3 {197-189) Tom, ~ Th~nk yc~u far your comm~nts anti qu~sti4nS reg~arding GNi-03. Below, please fin~i the respon~ tp your questions. 1. Wha~t i~ th~ basis far ortiy a 40 mtnufie t~st time far the 1QRQ p~si pressure test in sts~p 4p'~ T~ estabtish the cement piug as a barrier. 2. !t app~ars th~t step 48 ma~l be mi~placed or that th~ IBP nesd~ to be remo~-+~ ~sa ~ircu~~#ion i~ pos~ible. We now plan to install the 1BP when rig is on the well. We will circuiate out the diesel and then install the IBP through #he tree We will pressure fiest the ISP before nippiing down the tree. 3. 1Nhat i~ the ne~d for th~ prs~~u~e t~st in st~p 4A? At thi~ point no communicaki4n with the ~tis~pc~,sai interva! ~t~ould exist and if the tubing is eut, it wouid seem that a CMlT w~~ld bs valid to 1000 p~i w~uid veriijf the cc-nditi4n ~s#~blish~d in ste~p 'tD. This ~ri!! be a n~n-issue since iBP wi11 be placsd in fhe 7" snjection tubing when the rig is on the weil. 4. YY~uld you ~~ment on the 28~i0 ~i limit ~ns! how tha# is u~ed tc~ dstermine th~ 340U psi pr~ssure test vaiue? if the tubing Mas besr~ eroded, l can underst~nd dsraxin~ t~ ~stabli+~h ths pre~sure valus however that eroded tuk~ing is ta b~ replacg+tl. It does not s~m that the ~8t?a F-s1 pr~ssure limit would apptY. T±~~ maximum injection pressure in GNI-03 is 2,400 psi. High level alarm is set at 2,400 psi to alert the operator to take corrective measures. Ths high pressure pumps wilf shui off in an event pressure reaches 2,8d0 psi. 3,4i70 psi is 92 times the maximum possible injection pressure in GN!-03. Pro~e~__P._r~~r~l~re ~. ~~~ ~/fJl'~COV~f f~lt~. 2. Cir e out freeze proteCtiqn fluid and displace it with ele~n seawa#er. 3_ RU E-(ine, ar~d instaitt 7" IBP through fihe tree ~t ~50f}' MQ. Prt~~ure tesfi the l~P tQ ~,40(~ psi fo~ 1t~ Ctltllllt~.'8. 4. ND tree. I~U and te~ PE with 3-1/2„ x 6,' and 41/2° x"~" VSRs. Pr~ssur~; test tQ 2~Q p~i i~rw, 3,4Q0 psi i~igh ~nrith 4" and 7" te~t jc~in . ~ 5. RU sliek line and retrieve thE t~ . ~. Putf and L~ 7" tubing steir~g to the cut. 7. Mill the 9-5/8" x 7" packer. ~. RIH and sp~ar ths packer and tubing kai). 9. RU and RIH with 9,5E8n $Cfi~~?@f. 10. Pressur~ tes# the 8-5/8" casing agai~st the cet'nent plug to 3,~ i for 30-charted Fninute~, 11. PU ~1ean-out BH~A. R1M and drill out the eerr~er~t plug and clean put ebri~ and f~lt tp 7,55U' Mp. 12. Run 7" 29# L-8U completion with $aker S-3 packer. Run 3/8" op~n-ended ol line to 1,~00' in iA. Rositipn pacl~~r at ±4,E~5Q' M~ (near SV1 mark~r). 13. Qis~lace the t~ to packee fluid (corrosi4n inhit~itor brine and diesel fc~r fr~ez~ Rrotect). balt and ead and set tMe paCl~~r. 14. T~st tubing and IA to 3,4Q0 pri. Freeze protect with diesel to 220U' M~. 15. Sefi BPV. ND ~QF~E. NU and test tree. RpM4. 7/13/2009 ~ TR~= ~ 6-3/8" CALICO W~LLHEAD= FMC ACTUATOR= AX~SON KB. ELEV = ~ 50.4' BF. ELEV = 23.0' KOP = 2450' Max Angle = 36 @ 5628' Datum 11~ = 6662' DatumND= 6000'SS 13-3/8" CSG, 68#, L-80, ID = 12.415" 2609' TOP OF 13-3/8", 72" CSG 2609' Minimum ID = 5.963" @ 4238' HES R NIPPLE ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 4154' 7" TBG, 29#, L80, .0371 bpf, ID = 6.184" 4203' 7" TBG, 26#, L80, .0382 bpf, ID = 6.276" 4263' REF LOG: SWS ARRAY INDUCTION LOG 05/07/98 ANGLE AT TOP PERF: 33 @ 7315' Note: Refer to Production DB for historical perf data SIZE SPF IMB~VAL Opn/Sqz DATE 4-1/2" 5 7315 -7335 O 11/28/98 4-1/2" 5 7620 - 7640 O O6/06/98 SAFETY I~TES: 1/4" SS OPBV ENDm CONTROL LINE ~ G N I~O 3 53 (l7~ 53 S BANDS~ 205'p AB 30 IWOWN AS O4,-63 IN PBAS PBTD ~-I 7740' 9-5/8" CSG, 47#, L-80, ID = 8.681" 7$22' TD 7~0~ 1 /4" SS OPBV-ENDm COMROL LINE FOR NITROGEN BLANKEf 4168' ~ HES rrPE "H" Es CEnne~rrER ~ 4203' 9-5/S" X 7" BKR SABL-3 HYDRO SE7 PKR, ID = 6.000" 4238~ 7" HES "R" NIPPLE, ID = 5.963" 4263' ~" w~~c 42~ ~MD TT - LOGG~ O6/06l98 DATE REV BY COMMENTS DATE REV BY COMMENTS O6/06/98 OWGINAL COM PLETION 07/19/08 DSMISV TREE C!O (07/18/08) 09/21/01 MB/KAK CARRECTIONS 06/14/09 MLB/TLH 7" ID & SFTY NOTE CORRECTION 07/31/05 GJB/TLH TWO IBPS SET 08/23/05 TLWTLH TBG CORRECTIONS 08/27/OS EZUTLH LOW821A MAASP 05/09/07 DAV/PA PULL FISH @ 4373' (07/11/O6) PRUDHOE BAY UNIT WE1L: GNI-03 PERMIT No: 1971890 API No: 5002922820-00 Sec. 25, T11 N, R15E, 2845.96 FE1695.93 FNL BP Exploration (Alaska) ~~_ ~ ~-3/8" CALICO WEILHEAD= FMC ACTUATOR= AXFISON KB. ELEV = 50.4' BF. ~EV = 23.0' KOP = 2450' Max Angle = 36 @ 5628' Datum MD = 6662' DatumND= 6000' SS - ~~`~ ~ l ~~ GN ~3 P ro o s e d SAF OTES: ~,l4"' SS OPEN ENDm CONTROL LINE ~ ST~m TO OUTSIDE OF 7" TBG DOWN TO JOINT #XX (USm XXSS BANDS) XXXX'. i 1000~ ~ 3!8" SS OPBV-ENDm CONTROL LINE FOR NffROGEN BLANKEf 13-3/8" CSG, 68#, L-80, ID = 12.415" ~ 2609~ TOP OF 13-3/8", 72" CSG 2609~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 4154~ ~ 4168' HES Tr~~~H,~ Es cFrn~rvr~ 4923` 7" HES R NIP, ID=5.963" 9-5/8" x 7" L-80 BKR S-3 Packer 4853` 4983` H 7" HES RN NIP, ID=5.770" 7" TBG, 29#, L80, .0371 bpf, ID = 6.184" 4913~ 4923' I~~" WLEG REF LOG: SWS ARRAY INDUCTION LOG 05/07/98 ANGLE AT TOP PERF: 33 @ 7315' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 7315 -7335 O 11/28/98 4-1/2" 5 7620 - 7640 O O6/06/98 PBTD 9-5/8" CSG, 47#, L-80, ID = 8.681" 7840' DATE REV BY COMMEIYTS DATE REV BY COMMINTS 06/O6/98 OPoGINAL COM PLETION 07119/08 DSIWSV TREF C!O (07J18/08) 09/21/01 MB/KAK CORRECTIONS 07/31/05 GJBlTLH TWO IBPS SET 08/23/OS TLWTLH TBG CORRECTIONS 08/27/05 EZLlTLH ~OWER IA MAASP OS/09/07 DAVIPAG PULL FISH @ 4373' (07/11/06) PRUDHOE BAY UNff WElL: GNI-03 PERMIT No: ~1971890 API No: 5002922820-00 Sec. 25, T11 N, R15E, 2845.96 FEl. 695.93 FNL BP 6cploration (Alaska) i s ~chf~n~ber~er NO. 5297 Alaska Da4a & Consulting Services }n t ~,,~ i~ ~:-$ ~Q~~ Company: State of Alaska 2525 Gambell Stree4, Suite 400 :~~^~~,~~~~ ~ AlaskB Oil & Gas Cons Comm /Anchorage, AK 99503-2838 Attn: Christine Mahnk2n 1~TTN: Beth 333 West 7th Ave, Suitr, 100 Anchorage, AK 99501 dVell Job # Log Description Date BL Color CD 07/06/09 Z-06 AYTO-00035 GlS/PRODUCTION PROFILE 05/1?J09 1 1 07-336 B4C4-00003 SCMT 05/30/09 1 1 17-14 AVY5-00049 PRODUC ION PRO !lE ~./- 05/31/09 1 1 12-01 AYTU-00039 PRODUC710N PROFILE - O6/01l09 1 1 04-43 AXWS-00011 IBP/CROSS FLOW CHECK - - '~. 06/02/09 1 1 D-13A B04C-00059 USIT O6/03J09 1 1 Z-112 62WY-00011 MEM PROD PROFILE '~ p 06/03/09 1 1 06-05 B04C-00061 USIT 06/04/09 1 1 12-i8 AV1H-00014 PRODUCTION PROFILE O6/OM09 1 1 A-35 AY3J-00026 USIT V a(p ~ O6/OM09 1 1 12-22 AXWS-00013 PROD PROF/GLS O6/05/09 1 1 12-16A AXWS-00014 PRODUCTION PROFILE -~ 06/05/09 1 1 18-298 B04C-00062 PSP XY-CALIPER LOG O6/O6/09 1 1 C°12A AXWS-00015 SCMT ~. ~ 06/O6/09 1 1 B-27A AXBD-00028 MEM PROD PROFILE 06/11/09 1 1 L2-13A AWJI-00036 MEM CNL & INJ PROFILE 06/17/09 1 1 L2-13A AWJI-00036 MEM PROD PROFILE ~ 06/17/09 1 1 07-at 614B-00064 LDL O6/20/09 1 1 17-01A AYQQ-00030 SBHP SURVEY - O6/11/09 1 1 01-25 AP3Q-00041 LDL O6/15/09 1 1 I~°202 62WY-00010 MEM PROO PROFILE ~- <,/ O6/02/09 1 1 I~-103 AXBD-00027 MEM INJ PROFILE 06/04/09 1 1 GIVI-03 AWJI-00034 MEM PRESS & TEMP SURVEY ~'}.- 06N5/09 1 1 Ca-316 AWJI-00027 MCNL _~"3 04/30/09 1 1 15-296PB1 09AKA0143 OH MWD/LWD EDIT - ~f ~~ OS/11/09 2 1 • d~~-~-~-~~...e~..~~.+..~..~..~~~. u~ .a~aa~.~naan~~uf1GIV1'11Y1ryV VIYGI~VrT cra,n ~v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. f ; a ~ ~ ' ~ ~~,._ ~..- .-.. ~.- __,r ~ ~ ~ :~ Alaska Data & Consulting Services 2525 Gambell Sireet, Suite 400 Anchorage, AK 99503-2838 STATE OF ALASKA ALF~ OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS ~~~~~~~~ o~~ JUN 2 5 2~D9 Class 1 Disposal Well 1. Operations PerFormed: ~ ~ ~ i~t~k"~SSS~t3~ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-~fl~`~~l~ended Well ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown Change Well Status to ^ Perforate ^ Time Extension WDSP1 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 197-189 3. Address: ~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22820-00-00 7. KB Elevation (ft): 50 9, 9. Well Name and Number: PBU GNI-03 8. Property Designation: 10. Field / Pool(s): ADL 028324 Prudhoe Bay Field / Prudhoe Bay Oi! Pool 11. Present well condition summary Totat depth: measured 7840' feet true vertical 7036' feet Plugs (measured) None Effective depth: measured 7740' feet Junk (measured) None true vertical 6952' feet Casing Length Size MD TVD Burst Collapse Structura! . Conductor 110' 20" 110' 110' 1530 520 Surface 4132' 13-3/8" 4161' 3987' 4930 2270 Intermediate Production 7794' 9-5/8" 7822' 7021' 6870 4760 Liner ~ I~ i` ~; ~ ~t~}~~ ~s~~~'~~~~? „ v ~ Perforation Depth MD (ft): 7315' - 7640' PerForation Depth ND (ft): 6597' - 6869' 7", 29# x 7", 26# L-80 4263' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9'S/8" x 7" Baker'SABL-3' Hydro-Set packer 4203' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Change status to Class I Disposal Well in accordance with EPA Class I permit AK-11008-A, Authorization to Inject, Dated: January ~ _ 18 2008. Correct tubin information to accuratel reflect what was ran 29# and 26# See attached Tubin Summa 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class afterwork: ^ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Bill, 564-4692 N/A Printed Name Mike Bill Title Staff Engineer ~~ ~ ~ Signature =°%~~-~~7 v~-'~,~--~~' Prepared By Name/Number Phone 564-4692 Date ~ ~~~ Terne Hubble, 564-4628 :/ Form 10-404 Revis ~ ~~ Submit Original Only ~~il~~~l14~ ~l„ ~ u ~ l. 4 ? QD9 ~'` ~ ~, ~ ~..~ 1 9 ~ ~`_„~ ~ ~-G ~~ ~`\o~ la S 5 • • Page 1 of 1 Bill, Michael L (Natchiq) From: Maunder, Thomas E (DOA) [tom.maunder@alaska.gov] Sent: Tuesday, June 23, 2009 12:13 PM To: Bill, Michael L (Natchiq) Cc: Colombie, Jody J(DOA); Fleckenstein, Robert J(DOA); Regg, James B(DOA) Subject: RE: GNI-03, et al All, I have spoken about this point with Jim. On the 404s submitted to change from WDSP2 to WDSP1, the date when EPA approved the change should be noted. Tom From: Regg, James B (DOA) Sent: Tuesday, June 23, 2009 12:09 PM To: Bill, Michael L (Natchiq) Cc: Colombie, ]ody J(DOA); Maunder, Thomas E(DOA); Fleckenstein, Robert J(DOA) Subject: GNI-03 Thank you for the time this moming to discuss GNI wells. After checking with others here, 2 items need follow-up: 1) Our records show only GNI-04 as Class I disposal; all others (GNI-01, -2A, and -03) still carry WDSP2 (Class II-D); I understand from our conversation that GNI-01 is SI and if operated, would only accept Class II wastes due to tubing integrity issues; GNI-2A and GNI-03 should be reclassified as WDSP1 (Class I) since they are injecting Class I fluids in accordance with EPA Class I permit AK-11008-A; we will need 10-404s for GNI-2A and -03 to change the well status. 2) Our well records for GNI-03 -- particularly the well completion report (10-407), sundry notices (10-403) and reports of sundry ops (10-404) -- all reference the tubing as 7" L80, 26ppf; tubing is actually 29ppf to the packer with a 26ppf tubing tail; best way to correct this is sending 10-404 with corrected data and attach the tubing talley (suggest combining this 10- 404 with the one that changes well status to Class I disposal). Paperwork should be sent to Commission as normal. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Mchorage, AK 99501 907-793-1236 6/23/2009 • • ~sur~, UNITED STATES EN~RONMENTAL PROTECTIONAGENCY ~ A ~ REGION 10 `i~ ~ 1200 Sixth Avenue ~ ~ Seattie, WA 98101 Pao~°~ .1A~ 1 ~; ~' Reply To Attn Of: Suite 900, OCE-127 CERTIFIED MAIL - RETURN RECEIPT REQUESTED Neil Dunn BP Exploration (Alaska) Inc. 900 East Benson Blvd. Post Office Box 196612 Anchorage, Alaska 99519-6612 ~ ~- ' 17,~2/ Y ~~ ~Z - ;:~f{,,;~i I-f~il.,~C;~,y~ r , . r; ~tk,~ r c ~ r ~ L~ L.r~C~~,'~ l.~iJC~IC c~.- Re: Underground Injection Control Program Class I Grind and Inject Permit AK-1I008-A Approval to Commence Class I Injection Activities at Wells GNI-02A and GNI-03 Greater Prudhoe Bay, North Slope, Alaska. Dear Mr. Dunn: The U.S. Environmental Protection Agency (EPA) Region 10 has received and reviewed the Class I Well Completion Report for the Grind arid Inject Project Permit Number AK-1I008-A submitted by BP Exploration (Alaska) Inc. Based on the review of the completion report received January 7, 2008, EPA authorizes BP Exploration (Alaska) Inc. to commence Class I injection activities at the Grind and Inject Project, and specifically, for the Gl~]I-02A and GrTI-03 wells to process and inject Class I materials. Your continued efforts to coordinate the scheduling of tests are appreciated. If you have any questions, or need further information, please ca11 Thor Cutler at (206) 553-1673. Sincerely, / //~~ ~~l ~ Michael A. Bussell, Director Office of Compliance and Enforcement cc: Jim Regg, AOGCC, Anchorage Susan McNeil, ADEC, Anchorage ~, . Z9 " -~ ITEM ID OD LEN GTH TOP BOTfO M 7" WLEG 6.~0 7.670 1.74 _ . _ _ __ __. 4~b~::QA~ ;: __. _ _ _ 4262.78 7" 2611 L80 nscc Pu Joint 6.312 7.625 20.86 _.._ .. ____ . 4~ ~~ ... . .. __ .__ d~![~E14 ;. 7" H.E.S. 'R' Nipple w/ RBX insert & 4- 1/2" RHC lu installed 5.963 7.750 1.69 42~49 4~44t):T8 7" 26# L80 nacc Pu Jolnt 6.312 7.625 4.83 ~3~.6~ 42~:~4~- 7" 26# L80 nscc Pu Joint 6.312 7.625 4.91 4~2#~~5 __ _ d~:6d __ __ _ >:4~^s8 75 _.. __ ._ _.__ _ _ . __ . . ;4~8.75 _ .___ __ _ _ ._;. 7" 26# L80 nscc Pu Joint 6.312 7.688 20J6 ~t207:~ ~8 T~ Baker'SABL-3' H dro-Set Packer 6.000 8.250 4.61 4203.38 4~Q~.-9 Baker model 190 FA Anchor 6.063 8.0~ .95 4Z~2.43 ! 4~Q3.36 T' 29# L80 BTC X NSCC XO Pu Joint 6.188 7.688 1.91 ~20D.~2 . I 42t~t d.3 ' 7" 29# L80 BTC Pu Joint 6.188 7.688 10.15 4t9C~ 37 ___ __ :~.~Z.. _ _ _ ___ _ _ _ ~:t9f~ 37 _ _ _ _ _ _ < 4]`90 ~I. < _ __ _ 101 Jt (#1-101) 7" 29# L80 BTC Tubin 6.184 7.656 4161.59 ~8r78 419D ~7 2$:i8 28:78 7" 29# L80 BTC Pu Joint 6.188 7.688 1.34 ~7;4+1:. 28<~8 Tubfn Han er 2.10 __ . __ ~5:3A _ _ _ _ ~7~A4. 25:34 25:3~ Rofarv Table to Tubina Scool 25.34 . _ 25:3~t .,. I Ktt = b-3R5-- I,NLR.V WELLHEAD= FMC ACTUAI~OR= AXELSON KB: ELEV = 50.4' BF. ELEV = 23.0' KOP = 2450' Max Angle = 36 @ 5628' Datum MD = 6662' Datum TV D= 6000' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" TOP OF 13-3/8", 72" CSG ~ G N I~O ~ ST' " Pm TO OUTSIDE OF 7" TBG DOWN TO JOIM # 53 53SS BANDS) 2205'. ALSO KNOWN AS O4-63 IN PB S 22U5~ ~~ 1/4" SS OPEN-ENDm CONTROL LINE FOR NffROGEN BLANKET 2609' Minimum ID = 5.963" @ 4238' HES R NIPPLE ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 4154~ ~ 4168~ HES TYPE "H" ES CEMENTER 7" TBG, 29#, L80, .0371 bpf, ID = 6.184" 4203' 4203~ 9-5/8" X 7" BKR SABL-3 HYDRO SET PKR, ID = 6.000" 4238~ 7" HES "R" NIPPLE, ID = 5.963" 7" TBG, 26#, L80, .0382 bpf, ID = 6.276" 4263' 4263~ 7" WLEG 4273~ ELMD TT - LOGGm 06/06/98 PERFORATION SUMMARY REF LOG: SWS ARRAY INDUCTION LOG 05/07/98 A NGLE AT TOP PERF: 33 @ 7315' Note: Refer to Production DB for historicai perf data SfZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 7315 -7335 O 11/28/98 4-1/2" 5 7620 - 7640 O 06/06/98 PBTD I~ 7740' L 9-5/8" CSG, 47#, L-80, ID = 8.681~-j 7822~ TD ~7840' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 06/O6/98 ORIGINALCOMPLETION 07/19/08 DSNUSV TREEC/O(07/18/08) WELL: GNI-03 09/21/01 MB/KAK CORRECTIONS 06/14/09 MLB/TLH 7" ID & SFIY NOTE CORRECTION PERMff No: 1971890 07/31/05 GJB/TLH TWO IBPS SET API No: 5002922820-00 08/23/05 TLFUTLH TBG CORRECTIONS Sec. 25, T11N, R15E, 2845.96 FEL 695.93 FNL 08/27/05 EZL/TLH LOWER IA MAASP 05/Q9/07 DAV/PAG PULL FISH (cr~. 4373' (07/11/06) BP Exploration (Alaskal by ~ Certified Mail: 7008 3230 0000 2489 0350 • :; t ~s~~~.% . ~ fit: ~~~ May 15, 2009 Mr. Edward J. Kolawski Director, Office of Compliance and Enforcement (OCE•167) U.S. Environmental Protection Agency 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 /9%/Y9 UN, o3 BP Exploration (Alaska) Inc. P. 0. Box 196612 900 East Benson Boulevard Anchorage, AK 99519-6612 Re: Demonstration of Mechanical Integrity, Prudhoe Bay Grind and Inject, UIC Class I Permit AK-11008-A Dear Mr. Kowalski: This letter is to submit the results of a recent tubing inspection log in UIC Class I well GNi-03 located at the Prudhoe Bay Grind and Inject project operated by BP Exploration (Alaska), Inc (BPXA). The test is specified as part of the demonstration of mechanical integrity under Part II, C.3 b of EPA UIC Class !permit AK11006-A. The enclosed descriptive and interpretive report contains the results for the #ollowing logs and tests as required under Part li, C.3.c(1) of the permit: - Tubing Inspection Log: GNI-03 (Page 16, Part I1, C.3.b(3)) There was no indication of a loss of well integrity. I certify under penalty of law that 1 have personally examined and am familiar with the information su miffed in this document and all attachments and that, based on my inquiry of those individu !s immediately responsible for obtaining the information, I believe that the information is rue, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. I# the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, ~_ ~ ~~ Janice Vosika, Greater Prudhoe Bay Field Manager Attachments • Cc: Thor Cutler, EPA Region 10 (letter and report) Talib Syed, EPA Consultant (letter and report) Jim Regg, AOGCC (letter and report) Shawn Stokes, ADEC (letter and report) • EPA permit AK-1I008-A effective 09/01/07 requires a tubing inspection log in the Prudhoe Bay Unit Class I Grind & Inject wells each calendar year. Approved tubing inspection logs (Part II C 3 b (3)) include pipe analysis logs, caliper logs or other equivalent tests. Below are the results of this log in well GNI-03. Tubing ~spection Logs A memory caliper log was run in well GNI-03 on April 13, 2009. The 40 arm caliper logging tool, supplied by PDS (ProActive Diagnostic Services), was run on slickline to inspect the interior surface of both the tubing and the casing. The tubing inspection indicated the GNI-03 tubing is in poor condition with significant erosion/corrosion. The casing below the tubing tail is in fair condition. These results are similar to those observed in PDS caliper logs run on November 13, 2008 and March 14, 2008. Enclosed is a copy of the PDS Memory Multi-Finger Caliper, Log Results Summary. Below are the observed maximum metal loss in the tubing and casing from the caliper log. Well Date Maximum Pit Penetration Max Cross-Sectional Wall Loss GNI-03 Tubing 04/13/09 60% 52% GNI-03 Casing 04/13/09 33% 20% Tubing strength calculations indicate the de-rated burst strength is 3600 psi, well above the anticipated injection pressure. BP intends to continue to use the well for Class I ~~~ disposal injection, but will continue to closely monitor the tubing condition. L de- rte,}; Overall Conclusions '~ 1'~~' ~Z`~Ps` The GNI-03 caliper log indicates the tubing has significant erosion/corrosion damage, but _ it is suitable for continued injection. ~..1 Michael L. Bill May 15, 2009 U ~~ T~bi J ~ti~1 ~s Z~ ~ Lip ~SP_~ ~~ Q~ Se 'c • Memory Multi-Finger Caliper L©g Results Summary ,,. Company: BP Exploration (Alaska), Inc. Well: GNI-03 Log Date: Apri113, 2009 Field: Prudhoe Bay Log No.: 7314 State: Alaska Run No.: 7 API No.: 50-029-22820-00 Pipet Desc.: 7' 29 Ib. L-80 ' Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvll.: 4,273 Ft. (MD) Pipet Desc.: 9.625" 47 Ib. L-80 Top Log Intvl1.: 4,273 Ft. (MD) Pipet Use: Casing Bot. Log Intvl1.: 7,286 Ft. (MD) Inspection Type : Corrosion and Erosion Monitoring Inspection COMMENTS This caliper data is tied into the WLEG @ 4,273' (FEND). This log was run to monitor changes in the condition of the 7" tubing and 9.625" casing with respect to corrosive, erosive and mechanical damage as a result of sustained solids injection. A significant amount of wall loss due to apparent erosion is recorded throughout the tubing and casing logged. The caliper recordings indicate the 7" tubing is in poor condition, with a maximum recorded wall penetration of 60% recorded in an area of apparent erosion in joint 1 (5') and pup joint 101.7 (4,251'). Wall penetrations ranging from 31 % to 60% wall #hickness are recorded throughout the 7" tubing. Cross-sectional wall loss of 52% is recorded in joint 1 (5'). No significant I.D. restrictions are recorded. The caliper recordings indicate the 9.625" casing logged is in fair condition, with a maximum recorded wall penetration of 33% recorded in an area of apparent erosion in joints 55 (6,474'), 21 (5,120`), 31 (5,512'), and 45 (6,074'). Wall penetrations ranging from 25% to 33% wall thickness are recorded throughout the 9.625" casing logged. Cross-sectional wall loss of 20% is recorded in pup joint 0.1 (4,273'). Although no significant I.D. restrictions are recorded throughout the 9.625" casing logged, the presence of intermittent deposits may mask areas of additional cross-sectional wall loss. This is the sixth time a PDS caliper has been run in this well and the 7" tubing has been logged. A comparison between the current and previous log (November 13, 2008) indicates an increase in erosive/corrosive damage during the time between logs. A comparison graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis is included in this report. This is the sixth time a PDS caliper has been run in this well and the fifth time the 9.625" casing has been logged. A comparison between the current and previous log (November 13, 2008) indicates an increase in erosive/corrosive damage during the time between logs. A comparison graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis is included in this report. T" TUBING -MAXIMUM RECORDED WALL PENETRATIONS Apparent Erosion (60%) Jt. 1 @ 5 Ft. (MD) Apparent Erosion (60%) Jt. 101.7 @ 4,251 Ft. (MD) Apparent Erosion (59%) Jt. 3 @ 126 Ft. (MD) Apparent Erosion (57%) Jt. 4 @ 168 Ft. (MD) Apparent Erosion (57%) Jt. 101.5 @ 4,245 Ft. (MD) ProAdive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281} 565-1369 E-maiP: PDS~a memorylog.com Prudhoe Bay Field Offce Phone: (907) 659-2307 Fax: (907) 659-2314 7" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Apparent Erosion (52%) Jt. 1 @ 5 Ft. (MD) Apparent Erosion (51 %) Jt. 3 @ 121 Ft. (MD) Apparent Erosion (50%) Jt. 4 @ 136 Ft. (MD) Apparent Erosion (50%) Jt. 2 @ 61 Ft. (MD) Apparent Erosion (50%) Jt. 5 @ 182 Ft. (MD) 7" TUBING -MAXIMUM RECORDED IO RESTRICTIONS No significant I.D. restrictions are recorded. 9.625" CASING -MAXIMUM RECORDED WALL PENETRATIONS Apparent Erosion (33%) Jt. 55 @ 6,474 Ft. (MD) Apparent Erosion (33%) Jt. 21 @ 5,120 Ft. (MD) Apparent Erosion (33%) Jt. 31 @ 5,512 Ft. (MD) Apparent Erosion (33%) Jt. 45 @ 6,074 Ft. (MD) Apparent Erosion (32%) Jt. 43 @ 5,999 Ft. (MD) 9.625" CASING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Apparent Erosion (20%) Jt. 0.1 @ 4,273 Ft. (MD) Apparent Erosion (19%) Jt. 45 @ 6,092 Ft. (MD) Apparent Erosion (19%) Jt. 68 @ 7,016 Ft. (MD) Apparent Erosion (19%) Jt. 52 @ 6,374 Ft. (MD) Apparent Erosion (19%) Jt. 55 @ 6,487 Ft. (MD) 9.625" CASING -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the 9.625" casing logged. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: D. Vanble ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: {281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax; (907) 659-2314 • Correlation of Recorded Damage to Borehole Profile Pipe 1 7. in (5.1' - 4273.2') Well: GNI-03 Pipe 2 9.625 in (4273.2' - 7264.4') Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: April 13, 2009 ~~ ~'__ Approx. Tool Deviation . Approx. Borehole Profile ~ 1 5 25 50 75 r ~ z 1 ~ 100 'o 1 ~5 ~ t~ 25 50 75 0 1004 2031 3075 0 4119 a v 4284 5244 6261 7264 50 100 j Damage Profile (% wall) / Tool Deviation (degrees) ~' Bottom of Survey = 75 Maximum Recorded Penetration ~--- ~. Comparison To Previous Well: GNI-03 Survey Date: April 13, 2009 Field: Prudhoe Bay Prev. Date: November 13. 2008 Company: BP Exploration (Alaska), Inc. Tool: UW MFC 40 Ext. No. 217958 Country: USA Tubing: 7" 291b L-80 Overlay Max. Rec. Pen. (mils) 0 100 200 30 0 1 11 - 21 31 41 a ~ 51 i z c 61 i 71 ~~ 81 91 101 r April 13, 2009 ~ November 13, 2008 ~ Difference -1 Diff. in Max 00 50 0 . Pen. (mils) 50 10 0 i I i I 11 21 I 31 'I I 41 I '~ E ~ 51 z ~ i 61 I 71 i 81 ~, 91 101 I -2 42 -121 0 121 2 42 Approx. Corros ion Rate (mpy) • PDS Report Overview s Body Region Analysis Well: GNIA3 Survey Date: April 13, 2009 Field: Prudhoe Bay Tool Type: UW MFC 40 Ext. No. 217958 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 29 f L-80 6.184 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) s~ penetration body ~ metal loss body 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% N_um_ ber ofjoints anal s ed total = 10~_ _ pene. 0 0 0 0 106 0 loss 0 0 0 59 47 0 Damage Configuration (body ) 150 ~ 100 50 l o er of~oints d_ amazed total = 106 __ _ 106 0 0 0 Analysis Overview page 2 0 isolated general Bne ring hole / poss pitting corrosion corrosion corrosion ible hole Damage Profile (% wall) t~ penetration body otitis metal loss body 0 50 100 1 - - PDS REPORT JOINT TABI. Pipe: 7. in 29.0 ppf L-80 Well: Body Wall: 0.408 in Field: Upset Wall: 0.408 in Company: Nominal I.D.: 6.184 in Country: Survey Date: • ILATION SHEET GNI-03 Prudhoe Bay BP Exploration (Alaska), Inc USA April 13, 2009 j Joint No. ! Jt. Depth (Ft.) Pen. Pen. ;Pen. ;Metal Upset ' Body ~ % ~ Loss (Ins.) ! (Ins.) % Min. 'Damage Profile LD. Comments (% wall) (Ins.) '.0 50 100 1 5 0.26 0.24 ' 60 52 6.48 ~~ A arent Erosion.r~ ~__ 2 47 0.20 0.23 i 56 50 6.53 A arent Erosion. i ~ i ! 3 88 0.22 0.24 S9 51 + 6.52 A arent Erosion. 4 130 0.21 0.23 I 57 50 6.54 A arent Erosion. i ~ S 173 0.22 0.23 S6 ~ 50 6.52 ' A arent Erosion. 6 __ 214 __ _ 0.20 0.22 55 _! 50 6.51_ _~parent Erosion. __ ~ I ! 7 _ 256 0.20 0.22 ' S5 48 _ __ _ 6.51 ' Apparent Erosion. i I 8 298 0.21 0.22 ' S3 4 _ _____ . . ~parent Erosion. ~ ~ 9 _ 339 _ 0.20 0.22 i 53 48 ~ _ _ _ __ 6.51 ~ Apparent Erosion. _ 10 _ 381 _ 0.22 0.23 I 56 _ _ _ 49 _ _ __ _ F 6.54 Apparent Erosion__ _ 11 423 0_21_ 0.23 55 _ r 49 I __ _ A pparent Erosion 6.50 ~I I _ 12 _ 465 0.22 0.22 55 : 48 ~ _ _ _ __ __ 6.46 T~parent Erosion. I ; _ ~ 13 _ __ _ 507 _ 0.21 _ 0.22 ! 55 48 . _ __ ___ _ x_6._50 __ Apparent Erosion. _ __ I 14 __547 0.19 0.22 S3 _~ 47 6.51 _ __ Apparent Erosion. I i 15 590 0_21 0.22 54 I 48 6.51 _ A~Qaren_t Erosion. ~ ~ 16 632 _ 0.21~0.22~ 53 47 - - 6.51 T Apparent Erosion. ~_17 _ _ _ 674 _ _ 0.21 ~ 0.21 ; 52 __ 46 _ _ - - - 6,51 .; Apparent Erosion. i 18 715 _ _ 0.20 ~ 0.22 i 53 __ __ 46 .. ___ _ ______ _ 6.52 A arent Erosion. I 19 756 0.20 0.21 52 I 46 6.52 A arent Erosion. 20 797 0.20 0.21 ~ 52 46 6.51 ' A arent Erosion. I 21 839 0.20 0.21 52 46 6.47 A arent Erosion. ~ i 22 879 0.20 0.21 51 I 45 6.50 A arent Erosion. , ~ 23 920 0.19 0.21 ! 52 46 6.49 A arent Erosion. i i 24 962 0.19 0.21 ~ 52 45 6.47 I A arent Erosion. I 25 1004 0.18 0.21 ! 51 45 6.50 A arent Erosion. ~ i i 26 1046 0.18 0.20. 50 45 6.47 A arent Erosion. ~, ' 27 1088 0.19 0.22 S3 45 I 6.49 ~ A arent Erosion. i 28 __ 1 130 0.19 0.20 ! 50 __ 45 6.50 A parent Erosion. _ , I 29 _ 1172 0.19 0 1 51 44 _ _6.50 _ Apparent Erosion. __ __ i i ~ 30 121 1 0.19 ~ I 0.20 50 _ 44 _ 6.50 Apparent Erosion. __ I ~' 31 _ 1253 - 0.20 i - 0.21 51 - 45__ _ 6.50 Apparent Erosion. ____ ,. _ i ~ I 32 _ 33 _ 1295 1337 0.17 0.19 0.20 __ 50 __ 43 0.20 ' S0 i 43 _ 6.46_ ._~parent_Erosion_ __ i 6.49 i Apparent Erosion. _ X34 _ _ _ 1377 0.19 0,20 ! 50 _ ! 43 _ __ 6.46 _~ _A~parent Erosion. __ _ I 35 __ 36 __ 1415 1454 i 0.19 __, 0.20_ ~ 50 T__ 43 0.16 0.20 4 43 6.46 ~__Apparent Erosion_ ___ 'I 6_45 Apparent Erosion. i -37 _ 1496 0.19 0.20! 49_~ 43_ . . ___ - __ _ 6.46 A.pparent_ Erosion__ j x I .i8 1537 0.18 ! 0.19 ' 48 I 42 Apparent Erosion. 6.47 _ 39 _ 1580 0.19 'T 0.20 49 r 42 _ _ _ 6.46 A arent Erosion. 40 1620 0.19 0.19 ~ 47 42 6.46 ' A arent Erosion. I 41 1660 0.19 ~ 0.19 48 41 6.47 ~ A arent Erosion. 42 1 701 0.18 0.19 47 41 6.47 I A arent Erosion. I I 43 1 741 0.17 i 0.20 49 42 6.46 ~, A arent Erosion. ~ i I i 44 1783 0.18 0.19 I 46 41 6.44 A arent Erosion. i ~~ ; ! ' 45 1825 0.18 0.20 49 ~ 42 6.44 I A arent Erosion. '~ I , i 46 1866 0.15 ' 0.19 46 40 6.44 ' A arent Erosion. j ' 47 1909 0.17 ' 0.19 ' 47 39 6.45 A arent Erosion. ~ ~ I 48 1951 0.1 7 0.18 45 39 6.44 A arent Erosion. I 49 __ __1990 0.18 0.18 X45 39 __ _ 6.45 _ _A_pparent Erosion. ____ ___ __ _ _ ~ 50 _ __ 2031 0.17 __ 0.18 45 39 _ 66 44 __ .Apparent. Erosion.___ _____ ___ Penetration Body Metal Loss Body Page 1 • s PDS REPORT JOINT TABULATION SHEET Pipe: 7, in 29.0 ppf L-80 Well: GNI-03 Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska-, Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: April 13, 2009 ~ Joint No. Jt. Depth (Ft.) Pen. ~ Pen. it Pen. Upset ' Body ', % (Ins.) (Ins.) ~~~ Metal Loss % Min. ~ Damage LD. Comments ~ (% w~ (Ins.) ~0 50 51 2073 0.18 0.19 46 40 6.42 A Arent Erosion. 52 2112 0.16 0.18 ' 44 38 6.42 ' A Arent Erosion. S3 2154 0.17 ! 0.18 45 38 6.44 A Arent Erosion. S4 2196 0.15 1 0.18 ~ 44 37 6.42 A Arent Erosion. S5 2237 0.17 0.18 45 38 6.44 A Arent Erosion. 56 __2279 _ 0.17 ! 0.18 __ 44 ; 38 6.44 ~ Apparent E r osion. 57 58 _. 2320 2360 _ _ 0.17 018 44 ___0.16 0.18_{'- 44 _ __ _ 38 _ 37 _ _ _ _ _____ _ __ 6.35 _T _Appare_nt_Erosion. ___ ____ ._6.42 Erosion. I Apparent 59.__ __ 2402 _ _ 0.15 0.18 _ I _44 _ 36 _ _ _ _ Apparent Erosion _ 6.40 , _ 60 2443 0.1 7 I 0.18 '_ _ 44 _ 37 _ _ _ ____ __ 6.41 _ ~ Apparent Erosion. 61 2485 0.16 0.17 ; 43 37 _ __ 6.42 Apparent Erosion. 62 _ 2527_ _ _ 0.15 0.17 42 5~ _ _ _ _ ___ 6.37 _ Apparent Erosion. 63 2569 ~. _L_ _ i 0.17 0.18 45 ~ 37 ~ _ _ __ __ _ _ 6.43 Apparent Erosion. , 64 2611 0.18 0.18 45 i 36 _ _ _ _ . 6.42 ; Apparent Erosion. 65 2653 _ 0.16 0.19 I 46 I 36 _ . ____ _ 6.40 Apparent Erosion. 66 _ 269.5__._ _ 0.17-0.1 48 5~ _ _ _ _.._ __.__ _6.42_ __~ _ Apparent Erosion. _ ____ _______ ~ 67 2738__ 0.18 0.19 ~ 46 36 ~parent Erosion. 6.39 . __ 68 2780 0.1~-0.18 I 44 36 __ _ ----- - - 6.38 A Arent Erosion. 69 I 2822 0.1 7 0.17 42 i 36 6.40 A Arent Erosion. 70 I 2864 0.17 10.17 41 35 6.40 A Arent Erosion. 71 I 2906 0.14 0.17 42 35 6.38 A Arent Erosion. 72 ~ 2948 0.16 ~ 0.1 7 I 43 ~ 35 6.40 A Arent Erosion. 73 2991 0.14 0.18 ' 44 34 6.38 ' A Arent Erosion. 74 3033 0.17 10.18 44 34 6.38 ~ A Arent Erosion. 75 3075 0.18 10.18 ~ 45 35 6.37 A Arent Erosion. 76 31 16 0.16 0.17 43 35 6.40 ! A Arent Erosion. 77 3157 0.18 I 0.22 i 53 34 6.40 ! A Arent Erosion. 78 3199__ 0.19 0.20 x_50 T 34 6.34 __+ A~parent Erosion. __ 79 _ 3241 0.15 ! 0.18 _ 44 33 _ Apparent Erosion. 6.36 ; _ ~ 80 3283 0.18 ~ 0.21 ~ 52 _ 33 _ _ _ __ __ Apparent Erosion. 6.38 ! _ 81 3325 0.17 0.20 I 49 34 _ 6.32 ~ A parent Erosion. 82 3367 0.17 0.22 54 33 6.33 _Apparent Erosion_ 83 3408 0.19 0.22 53 34 _ _ __ 6.34 . App arent Erosion. 84 3451 _ _ 0.18 X0.21 ~ 51 _ 33 __ _ _ ___ __. _ 6.34__ I Appar ent Erosion. ------ ' _ _ A~~arent Erosion. _ 86 3534 0.19_ 0.22 55 35 _.____ _ A~parent Erosion. _ __ 6.38 87 __ __3576 0.18 i 0.21 S2 32 __ 6.34_'x_ Apparent Erosion. 88 __ 3618 0.19 0.22 54 32 Apparent Erosion. ___ 6.36_ 89 3661 0.19 0.22 53 ' 32 _ 6.36 A Arent Erosion. 90 3702 0.20 0.22 53 32 6.34 '~ A Arent Erosion. i 91 3741 0.19 0.20 ' 49 31 6.32 A Arent Erosion. ~ 92 3784 0.18 0.20 49 32 6.37 A Arent Erosion. 93 3825 0.20 0.21 S1 32 6.34 A Arent Erosion. 94 3867 0.19 0.20 I 50 32 6.33 A Arent Erosion. 95 3910 0.21 0.23 ! 55 32 6.34 A Arent Erosion. 96 3951 0.20 ! 0.23 ~ 57 33 6.36 A Arent Erosion. 97 3993 0.18 '~ 0.22 S3 31 6.33 A Arent Erosion. 98 4035 0.16 0.21 ~ 51 32 6.34 ' A Arent Erosion. I 99 4078 0.19 0.21 ~ 52 31 Apparent Erosion. 6.32 ', 100____ _ 41,19 0.21 ~I 0.22 i 53 31 _ _ 6.36 ' Ap Arent Erosion. 'rofile III) 100 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 29.0 ppf L-80 Well: GNI-03 Body Wall: 0.408 in Field: Prudhoe Bay Upset Wall: 0.408 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.184 in Country: USA Survey Date: April 13, 2009 Joint No. Jt. Depih (Ft.) Pen. '; Upset i (Ins.) r Pen. ~ Body (Ins.) -- Pen. % Metal ~ Loss ~ % Min. '. LD• (Ins.) 'Damage Comments (% w. 'i0 50 101 4159 0.19 0.22 53 32 6.36 i A arent Erosion. 101.1 4201 0.19 0.19 48 32 6.38 PUPA arent Erosion. 101.2 4212 0 0 0 0 6.13 Baker SABL-3 H dro Set Packer. A .Erosion. i 101.3 4219 0.21 0.22 54 i 41 6.41 PUPA arent Erosion. 101.4 ~ 4240 0.21 ~ 0.23 56 ' 38 6.41 PUPA arent Erosion. __101.5_ '~ _ 101.6 ~ _ 4245_ _ .4249 0.23__' 0 ~ __0 23 S7 0 f 0 37 ~ 0 ` 6.40 5.99 , PUP Apparent Erosion. ___ 7" HES R-Nipple• Apparent Erosion. i I _ 101.7 __ __ 4251 _ _ 0.25 __ __ ~0.2~4 __ 60 44 __ _ _ 6.45 ____ PUP Apparent Erosion. 101.8 4273 0 __ L_ 0 _' _ 0 _ 0 _ _ _ ___ NSA _ 7" WLEG __ ______ ~ Profile 1 all) 100 i,~ ~~L !! Penetration Body Metal Loss Body Page 3 ~ ,~ Well: GNI-03 Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Tubing: 7 ins 29 ppf L-80 PDS Report Cross Sections Survey Date: April 13, 2009 Tool Type: UW MFC 40 Ext. No. 217958 Tool Size: 2.75 No. of Fingers: 40 Analyst: C. Waldrop Cross Section for Joint 1 at depth 5.44 ft Tool speed = 43 Nominal ID = 6.184 Upset OD = 7.000 Remaining wall area = 48 In upset region ~ Tool deviation = 1 ° • Finger 21 Penetration = 0.258 ins Apparent Erosion 0.24 ins = 60% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ~ ,. Well: GNI-03 Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Tubing: 7 ins 29 ppf L-80 PDS Report Cross Sections Survey Date: April 13, 2009 Tool Type: UW MFC 40 Ext. No. 217958 Tool Size: 2.75 No. of Fingers: 40 _ Analyst: _ C. Waldro~__ Cross Section for Joint 101.7 at depth 4251.37 ft Tool speed = 43 Nominal ID = 6.184 Upset OD = 7.000 Remaining wall area = 56 In upset region Tool deviation = 33 ° Finger 12 Penetration = 0.245 ins Apparent Erosion 0.24 ins = 60% Wall Penetration HIGH SIDE = UP • • Cross Sections page 2 • • Maximum Recorded Penetration ~-.---: ~' Comparison To Previous Well: GNI-03 Survey Date: April 13, 2009 Field: Prudhoe Bay Prev. Date: November 13, 2008 Company: BP Exploration (Alaska), Inc. Tool: UW MFC 40 Ext. No. 217958 Country: USA Tubing: 9.625" 471b L-80 Overlay 0 M 5 ax. Rec. Pen. (mils) 0 100 150 20 0 0.1 I i 10 20 30 I d 2 c 40 ' o 50 I 60 I 70 e April 13, 2009 ~ November 13, 2008 Difference Diff. in Max. Pen. (mils) -50 ~25 0 25 50 I 10 I I I I 20 i 30 ~ d E ~ ~~ I 2 i c 40 ~ ~ I I ~ ~ ~I 50 i 6 I 70 I I 1 21 -60 0 60 1 21 Approx. Corros ion Rate (mpy) • • PDS Report Overview ~ Body Region Analysis Well: GNI-03 Survey Date: April 13, 2009 Field: Prudhoe Bay Tool Type: UW MfC 40 Ext. No. 217958 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 47 f L-80 8.681 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ti penetration body ti metal loss body 80 60 40 zo 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Num_b_er_of joints ana~sed~otal = 76~ _ __ __ pene. 0 0 0 76 0 0 loss 0 0 76 0 0 0 Damage Configuration (body ) 80 60 40 20 0 isolated general Gne ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oil nts dammed Vital = 76) _ _ 0 76 0 0 0 Damage Profile (% wall) ~ penetration body t~ metal loss body 0 50 100 0 ~-~ ---f -~-- i ----, - C~'--r~''~~'' I II ~I I!~ I I I I - IIj i ~i ;I I 20 I~~~i! ~ i l ~_ ~~ ~. .. ~ i I ! I ~ i ~ 40' I ~ I I i I i ~ j i ''I ~i I 60 ', ~ ~i ~ ' I ~ ~, i I ~ ~I i Bottom of Survey = 75 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 47.0 ppf L-80 Well: GNI-03 Body Wall: 0.472 in Field: Prudhoe Bay Upset Wall: 0.472 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 8.681 in Country: USA Survey Date: April 13, 2009 Joint No. Jt. Depth (Ft.) Pen. I, Pen. i Pen Upset I, Body % (Ins.) ~, (Ins.) ', Metal Loss % Min. ', i LD. Comments ~ (Ins.) 0 Dam (' .1 4273 0.29 ' 0.14 30 20 8.77 ~ PUPA Arent Erosion. i 1 4284 0.10 0.14 ' 31 17 8.75 I A Arent Erosion. 2 4325 0.12 ~ 0.14 30 19 8.76 A Arent Erosion. 3 4363 0.13 0.14 30 17 ~ 8.73 A Arent Erosion. 4 4403 0.12 0.14 30 ~ 17 8.73 ! A Arent Erosion. 5 _ 4443 __ _ 0.1.4 __ _'. _0_15 31 I 17 8.73 '~ Apparent Erosion. __ __ _ 6 _ _ _ 4482 __ . 0.12 _ 0.14 ', 29 17 __ _ 8.76 ~_ Apparent Erosion. _ 7 _4522___ __0._11 0.14 ! 29 ~_ 16 8.73 ; .Apparent Erosion. _ ~ 8 4563 0.1 ~ i 0.13 i 28 I 17 __8.75 Apparent Erosion,-- ____ __ _ ~_ 9 4603 0.12 ~ 0_14 I 29 6 _ 8.72 _ Apparent Erosion. _ ___ ~10 4643 __ _0.13 I _0.15 32 18 _ 8.71 ~ ApparentErosion._ _ 1 1 _ 4684 _0.1 1 _ 0.13 28 7 17 _ __ 8.74 --Apparent Erosion. ~_ 12 4723 0.10 0.13 27 15 8.71 At~~arent Erosion. ___ 13__ _ 4762_ __0.11 0.13 27 16 8.71 Apparent Erosion. _ 14 _ _ 4803 0.10 0.12 26 16 _ 8.71 _ Apparent Erosion. _ _ i 15 _4843_ 0.12_ 0.12 26 ~16 8 74 Apparent Erosion. - 16 _ 4884 __ .0.13. . _t_ 0.15 31_) _ 17 - -- - 8 71 Apparent Erosion._____ 17 4925 ' 0.11 0.13 28 16 8.72 A Arent Erosion. 18 4966 0.12 0.13 28 17 8.74 A Arent Erosion. 19 5005 0.11 0.13 28 16 8.72 A Arent Erosion. 20 5047 0.1 1 0.12 26 I 15 8.74 A Arent Erosion. ' 21 5088 0.12 ' 0.15 i 33 i 18 8.72 A Arent Erosion. ' 22 5127 0.13 0.14 ~ 29 17 8.72 A Arent Erosion. 23 5166 0.12 0.13 28 16 8.72 A Arent Erosion. 24 5205 0.13 0.15 I 32 18 8.75 A Arent Erosion. 25 5244 0.12 i 0.14 i 30 17 8.73 A Arent Erosion. 26 5283 0.12 0.14 I 29 ~ 19 8.77 ~ A Arent Erosion. 27 _ 5323 _ 0.10 ~0 12 25 ~ 16 8.75 Apparent Erosion. __ 28 _ 5364 _ 0.13 _ I _ ___0.15 ~: 32 17 8.72 1,_~parent Erosion. _ 29 5405 _ 0 14 LO 15 32 19 8.76 ~~ Apparent Erosion. ____ 30 _ 5446 . 0.12 ~ 0.15 ! 32 _ 19 _ _ ,I 8.74 Apparent Erosion. 31 _ _ __5487 0.12 1 0.15 33 18 _ . 8.74 i Apparent Erosion. Bend _ 32 _ 5528 ___ ,. 0.12 _ 0.15 I 32 18 _ - 8.75 Apparent Erosion. ~~ 33 _ _ .5569.__ 0.11 1 0.14 I 30 ~ 16__ 8,75__!. Apparent Erosion. 34 i 5610__ 0.12 i 0.14 a 31 I 16 . 8.73 Apparent Erosion. _ ~; 35 _ 5651 0.14 _ __ 0.15 '~ 31 i _ 19 __ _ 8.75 _ Apparent Erosion. __ I 36 __ _ 5692 _0.12__!.0,14 ' 29 I 16 _ _ _ _ 8.71 ! Erosion. _ Ap ap rent r 37 5733 0.13 0.15 ~' 32 ~ 19 _ _ _ 8.75 Apparent Erosion. 38 5774 0.13 r 0.15 ~ 32 ~ 19 _ __ 8.76 A Arent Erosion. 39 5815 0.14 1 0.14 ' 30 I 15 8.70 A Arent Erosion. 40 5856 0.12 0.14 '~ 30 ~ 15 8.73 ~ A Arent Erosion. 41 5897 0.13 0.15 ! 31 17 8.73 '~ A Arent Erosion. 42 5938 0.11 0.14 30 17 8.76 I A Arent Erosion. 43 5980 0.14 0.15 32 17 8.74 A Arent Erosion. 44 6018 0.12 0.14 30 ~ 18 8.74 A Arent Erosion. 45 6059 0.13 0.15 ~I 33 19 8.76 A Arent Erosion. 46 6099 0.13 0.14 I 30 ! 19 8.76 A Arent Erosion. 47 6140 0.12 ~ 0.14 29 16 8.72 I A Arent Erosion. 48 __ 6180. _ 0.14 ' ~_._ 0.14 i 30 i ,_ 17 _ ,--Apparent Erosion. _____ _ 8 75_' I 49 6221__ 0.14 0.14 I 30 I 19 L 8'73 , _Appa_rent Erosion. ~ age Profi a 'I i° wall) 50 100; Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 47.0 ppf L-80 Well: GNI-03 Body Wall: 0.472 in Field: Prudhoe Bay Upset Wall: 0.472 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 8.681 in Country: USA Survey Date: April 13, 2009 Joint No. Jt. Depth (Ft.) Pen. I Pen. ~ Pen. i Metal ~ Upset '~, Body ~ % I Loss (Ins.) (Ins.) ~ % Min. Damag LD• Comments ~ (%' (Ins.) i O 5i 50 6261 0.12 0.13 I 27 17 8.73 '~ A Arent Erosion. ~'~ 51 6299 0.13 0.14 30 i 17 8.75 A Arent Erosion. ~ 52 6340 0.14 ' 0.15 ! 31 ~ 19 8.76 '. A Arent Erosion. 53 ! 6381 0.13 ~ 0.14 ! 30 17 8.70 '~ A Arent Erosion. 54 ! 6419 0.15 I 0.15 31 18 8.76 A Arent Erosion. 55 6457 0.15 _ 0.16 33 19 Apparent Er osion_ 8.74 _. ~ 56 __ ___ 6495 _ __ _._ 0.13 ~ 0.1~ 30 18 _ __ _ _ __ Erosion. 8.75 Apparent 57 .. 6536 _ 0.10 1 28 15 . __ Apparent Erosion. 8.74 58 6577 _ _ 0.1 3_ 10.14 __ 30 ~ 18_ ~_ . _ 8.77__, Apparent Erosion. __ - 59 __ I 6619 _ , 0.14 0 1515 32 18 Apparent Erosion. 8.76 : 60 . 6660 _ _ _ 0.12 0.13 28 17 _ Apparent Erosion. 8.76 i 61 ~ _ _ 6701 ._ 0.11 ~0.14~ 3~ 18 . Apparent Erosion. _ 8.65 y _ 62 6742 _ 0.13 ~ 0.15 31 ~ _ 18 ___ _ 8.75_ ',_ ~~arent Erosion. _ _ _ I 63 ~ 6783 0.13 ~ 0.15 32 i 17 Apparent Erosion. 8.73 64 ~ _ 6821 0.13 ~0.14 ~1 _ 18 _ _, Apparent Erosion. 8.77 ' 65 ~ 6861 _ _a 31 y 0.12 h14 19 .,_ Apparent Erosion. 8.76 ~ 66 __ r 6902 _~_ 0.14 0.14 ! 30 _ _ 19 t _ . _ , 8.77 Apparent Erosion_ i ^_ __ 67 ! 6941 __ _ 0.12 ~ 0.14 ~ 30 _ _ 19 _ .____ _ 8.75 A Arent Erosion. 68 ~ 6980 0.12 0.14 i 30 ~ 19 8.77 A Arent Erosion. ' 69 ' 7021 0.12 10.14 31 ~ 18 8.76 A Arent Erosion. 70 7062 0.1 3 0.14 ' 31 17 8.76 ' A Arent Erosion. 71 7104 0.12 0.14 i 29 18 8.76 A Arent Erosion. ' 72 7143 0.13 ~ 0.15 31 ! 18 8.76 A Arent Erosion. ~ II 73 ~ 7184 0.12 ! 0.14 29 18 18.74 A Arent Erosion. ' 74 ! 7224 0.13 i 0.14 29 17 8.75 A Arent Erosion. 75 - , _ 7264 0.12 0.13 28 '_ 17_ i 8.77 Apparent Erosion. __ __ ! _ Profile !, vall) I 100; -~ ~ l~ I i ~' i !i~ lil Penetration Body Metal Loss Body Page 2 ~ PDS Report Cross Sections ,,. Well: GNI-03 Survey Date: April 13, 2009 Field: Prudhoe Bay Tool Type: UW MFC 40 Ext. No. 217958 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 47 ppf L-80 _ Analyst: C. Waldrop Cross Section for Joint 55 at depth 6474.273 ft Tool speed = 43 Nominal ID = 8.681 Nominal OD = 9.625 Remaining wall area = 81 % ~ I Tool deviation = 36 ° i Finger 15 Penetration = 0.156 ins Apparent Erosion 0.16 = 33% Wall Penetration HIGH SIDE = UP Cross Sections page 1 C~ • ~~,, PDS Report Cross Sections ,,. Well: GNI-03 Survey Date: April 13, 2009 Field: Prudhoe Bay Tool Type: UW MFC 40 Ext. No. 217958 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 47 ppf L-80 _ Analyst C. Waldro Cross Section for Joint 21 at depth 5120.343 ft Tool speed = 43 Nominal ID = 8.681 I Nominal OD = 9.625 Remaining wall area = 82 Tool deviation = 38 ° Finger 14 Penetration = 0.154 ins Apparent Erosion i 0.15 ins = 33% Wall Penetration HIGH SIDE = UP ~~ i • Cross Sections page 2 TREE= 6-3/8" CALICO LHEAD= FMC ACTUATOR= AXELSON KB. ELEV = 50.4' BF. ELEV = 23.0' KOP = 2450' Max Angle = 36 @ 5628' Datum MD = 6662' Datum TVD= 6000' SS SAF TES: 1/4" SS OPEN ENDED CONTROL LINE STRA TO OUTSIDE OF 7" TBG DOWN TO JOINT # 53 (USED 53SS BANDS) 2205'. ALSO KNOWN AS 04-63 IN PEAS "*'LOWER® OPERATING PRESSURE, MAX IAP =1000 PSI, MAX OAP = 1000 PSI (SEE 08/25/05 NOTICETO CHANGE)"""` ~ GNI-03 2205' ~ 1/4" SS OPEN-ENDED CONTROL LINE FOR NffROGEN BLANKET 13-3/8" CSG, 68#, L-80, ID = 12.415" 2609' TOP OF 13-3/8", 72" CSG 2609' Minimum ID = 5.963" @ 4238' HES R NIPPLE 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 4154' ~ 4168' HES TYPE "H" ES CEMENTER 7" TBG, 29#, L8 .0371 bpf, ID = 6.184" 4203' 4203' 9-5/8" X 7" BKR SABL-3 HYDRO SET PKR, ~ = 6.000" 4238' 7" HES "R" N~PLE, ID = 5.963" 17" TBG, 26#, LSO, .0371 bpf, ID = 6.184" I PERFORATION SUMMARY REF LOG: SWS ARRAY INDUCTION LOG 05/07/98 ANGLE AT TOP PERF: 33 @ 7315' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1 /2" 5 7315 -7335 O 11 /28/98 4-1/2" 5 7620 - 7640 O 06/06/98 PBTD I-I 7740' 9-5/8" CSG, 47#, L-80, ID = 8.681" 7822' rTD 7840' DATE REV BY COMMENTS DATE REV BY COMMENTS 06!06198 ORIGINAL COMPLETION 07/19!08 DSM/SV TREE GO (07/18108) 09/21/01 MB/KAK CORRECTIONS 07/31/05 GJB/TLH TWO IBPS SET 08/23/05 TLH/TLH TBG CORRECTIONS 08/27/05 EZLITCH LOWER IA MAASP 05/09/07 DAV/PAG PULL FISH @ 4373' (07/11/06) PRUDHOE BAY UNIT WELL: GNF03 PERMIT No: 1971890 API No: 5002922820-00 Sec. 25, T11 N, R15E, 2845.96 FEL 695.93 FNL BP Exploration (Alaska) 4{ 263' I 7" WLEG 4273' ELMD TT -LOGGED 06/06/98 I 4263' I GNI-03 (PTD #1971890) Notificati~of OA Overpressure Event Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, January 26, 2009 11:43 PM ,~~ 1~~"l 1?ti'', To: Regg, James B (DOA) ~, Cc: GPB, Environ Advisor (Services); Engel, Harry R; NSU, ADW Well Integrity Engineer; NSU, Equip Svcs Proj Supv; Bill, Michael L (Natchiq); GPB, Waste G&I Plant (AES) Subject: GNI-03 (PTD #1971890) Notification of OA Overpressure Event Attachments: GNI-03 Plot.doc Hi Jim, J This is a notification of an OA overpressure event on well GNI-03 (PTD #1971890) that occurred on 1/24/09. Due to changing injection fluids from seawater to produced water injection, the injection fluid temperature increased from approximately 60 to 125 degrees. This increase in tem erature caused the OA re ure to incre rma uid expansion. The alarms that normally soun an help warn of high pressure did not sound. Due to a frozen bleed hose, there was trouble bleeding the OA pressure before it increased to 1614 psi. Once another hose was attached, the pressure was bled immediately. Proper notifications have been made to the EPA. Additionally, the alarms have been properly set to prevent a reoccurrence of this event. A TIO plot has been included for reference. «GNI-03 Plot.doc» Please contact us if there are any questions. Thank you, ,,~nna ~Du6e, ~P. E. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: {907} 659-5100 x1154 1 /27/2009 i Q Qo ~ ~ doo c ~, ~QOOOo ~~~ ~~ _O ~_ H O D H M Q Z • ~~ d' v ~ 5 ~ p, 9~ '~' V ~ 0 0 0 V [~'? N r lvii i roans ror ~rti ~,ompiiance: lvor~nstar, rsaaami, raa 3, ~i~i rage i or i • • Regg, James B (DOA) ~ (`~7_ (cg9 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, October 17, 2008 9:45 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; Younger, Robert O; Bill, Michael L (Natchiq) Subject: MIT Forms for EPA Compliance: Northstar, Badami, Pad 3, GNI Attachments: MIT ACT NS10 10-11-08.x1s; MIT ACT NS32 10-11-08.x1s; MIT BAD B1-01 10-09-08.x1s; MIT PBU GNI-02A, 03, 04 10-07-08.x1s; MIT PBU OWDW-NW, SE, SW 10-08-08.x1s Jim, Tom and Bob, Please see the attached MIT forms for the following wells for annual EPA compliance testing: NS10 (PTD #2001820): MIT-IA witnessed by Thor Cutler. NS32 (PTD #2031580): MIT-IA witnessed by Thor Cutler. 61-01 (PTD #1971570): MIT-IA witnessed by Thor Cutler and Talib Syed. GNI-02A (PTD #2061190): MIT-IA witnessed by Thor Cutler and Talib Syed. ,GNI-03 (PTD #1971890): MIT-IA witnessed by Thor Cutler and Talib Syed. GNI-04 (PTD..#2071170): MIT-IA witnessed by Thor Cutler and Talib Syed. OWDW-NW (PTD #1002400): MIT-IA witnessed by Thor Cutler and Talib Syed. OWDW-SE (PTD #1002390): MIT-IA witnessed by Thor Cutler and Talib Syed. OWDW-SW (PTD #1002380): MIT-IA witnessed by Thor Cutler and Talib Syed. «MIT ACT NS10 10-11-08.x1s» «MIT ACT NS32 10-11-08.x1s» «MIT BAD B1-01 10-09-08.x1s» «MIT PBU GNI-02A, 03, 04 10-07-08.x1s» «MIT PBU OWDW-NW, SE, SW 10-08-08.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~- ~.i~ ~ ~ r ~F-~~ ;:%:.r~'`~~~~~:k. _ _ a'; afire, 10/17/2008 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 FlELD // UN T /PAD: Pu dhoeOBay / PBIU / GNI nc ~ I "1 z~ DATE: 10/07/08 OPERATOR REP: Andrea Hughes AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well GNI-02A Type Inj. N TVD 4537 Tubing 350 350 350 350 Interval O P.T.D. 2061190 T pe test P Test psi 1500 Casing 10 1530 1490 1480 P/F P Notes: MIT-IA to satisfy pending Class 1 permit. OA 0 0 0 0 Witnessed by Thor Cutler and Talib S ed. Well GNI-03 Type Inj. D TVD 4022 Tubing 1250 1250 1250 1250 Interval O P.T.D. 1971890 T pe test P Test psi /1500 Casing 650 .1550 1530 1530 P/F P Notes: MIT-IA to satisfy pending Class 1 permit. OA 400 420 420 420 Witnessed by Thor Cutler and Talib S ed. Well GNI-04 T pe Inj. N ND 4,461' Tubing 450 450 450 450 Interval O P.T.D. 2071170 T pe test P Test si 2000 Casing 130 2000 1950 1940 P/F P Notes: MIT-IA to satisfy pending Class 1 permit. OA 350 620 620 620 Witnessed by Thor Cutler and Talib S ed. 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 Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test i INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 911/05 MIT PBU GNI-02A, 03, 04 10-07-08.x1s 07/03/08 r N0.4768 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ., ~ ~~~U Anchorage, AK 99503-2838 ~~~~~~ JUL .~ ~- Lu Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~~?- ~ffl Well .Inh !F 1 .... no ..r:.. n_._ MPB-50 11999019 RST WFL - ~ 06/13/08 1 1 M-04 11962601 PRODUCTION PROFILE 06/21/08 1 1 Pi-24 12066527 MEM LDL (p 6° f 06/18/08 1 1 04-11A 11975778 LDL ~9, -- / 06/24/08 1 1 M-04 11962601 PRODUCTION PROFILE ~ _ 06/21/08 1 1 12-03 12071857 USIT t ~ -- j . ~(~ 06/21/08 1 1 GNI-03 12066530 MEM PRESS/TEMP LOG ~ L 06/20/08 1 1 E-106 40016750 OH MWD/LWD EDIT 04/05/08 2 1 18-13B 11972960 MCNL v-'~s (o ~ 12/07/07 1 1 18-13B 12021159 MCNL U _ 05/18/08 1 1 .-.-r..-.... ..v.~.~v •-rrv~nr ~~rvr,~ 1 vl VIMI~II~bI I~IYY fIGl VfllYllYt1 VIYG liVrt CNVf11V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ATTN: Beth / '~ / /~ Received by: u • i~~~' ~ • MEMORANDUlV1 To: Jim Regg '~ P.LSupervisor ~~~~ ~ ~G>~LU~O~~ FRO':YI: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 10, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC GNI-03 PRUDHOE BAY L"vIT GNI-03 Src: Inspector NnN_f'(lNFT1)TZNTTAi, Reviewed By: P.I. Suprv_~' Comm Well Name: PRUDHOE BAY UNIT GNI-03 API Well Number: so-029-z282o-00-0o Inspector Name: Bob Noble Insp Num: mitRCN0 7 1 008 1 80042 permit Number: 197-189-0 Inspection Date: 10/8/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~'i GNI-°3 'TYpeInj. ~ w TVD '~ aoz2 IA 330 ls9o - i i lsbs ls6s P.T. 1971890 T~'peTe5t SPT ~ TeSt pSi j li90 ~ ~A 1 400 520 ~ 520 ~ 520 ~ ~, Interval OTHER pig P ~ Tubing _ 1300 '_ 1300 1300 1300 i • EPA;AOGCC witnessed for pending Class 1 perrnit. Notes. a~~ ~~1~~ ~ ~ ~~~~ • .Nisw~~jy~11U1M' Wednesday, October 10, 2007 Page t of 1 ¡':' '."" 12 ') U·"\ :0 7. ,J ¡-~ v L ! i BP Exploration (Alaska I Inc. n .. PO Box 196612 J....DimmIS,')î!:]!9oo East Benson Boulevard Anchorage, AK 99519-6612 /97117 0 bp . ,\ rr;:. "! ~ \f"":15' .~ By Certified Mail to EPA only #700707100001 86209275 August 22, 2007 Mr. Michael Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue --Sea~!@-w~tOJ -,_.._--_....~.- -_._~~..- ---_..~_. Mr. Trevor Fairbanks Department of Environmental Conservation SCANNED SEP 1 1 2007 555 Cordova St. Anchorage, Alaska 99501 Mechanicallntegritv Test Notification and Log Transmittal Prudhoe Bay, Pad 3 and Grind and Inject UIC Permit Number AK-11004-A UIC Permit Number AK-11008-A Wastewater Disposal Permit No. 2004-DB0084 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notification to meet the requirements in Part II, C, 3, c, (3) for conducting Mechanical Integrity Tests (MITs) at the Prudhoe Bay Pad 3 and Grind and Inject Class I Injection Well Facilities (Permits AK-11004-A and AK-11008-A). In addition to the MIT at Pad 3, the annual fluid movement logging will also be conducted. The annual surveillance procedure will be sent electronically to Mr. Thor Cutler for his approval. . . MIT Notification August22,2007 Page 2 The MITs and fluid movement logs are currently scheduled for the first week of October. BPXA will notify your staff when a better estimate of the timing is known. Also included as attachments are copies of the shut-in temperature logs run on the Grind and Inject wells and copies of a descriptive report as required by Part II, C, 3, b, (2) and Part II, C, 3, c, (1) of Permit AK-11008-Ä. The second copy of the logs and descriptive report is being sent to Mr. Talib Syed. If you have any questions, please contact Ms. Alison Cooke at (907) 564-4838 or Mr. Mike Bill at (907)-564-4692. ~-------'-------~"-~'-----------'--------'._'--~-~- ^-.--...,..-...- Sincerely, ~. . I\¡ "J" j1 , /"", /./ .' - ~/. \' ¡ J -' '.' .~ ." . I f/ /1- ." ~f-v-t'----- Ne)1 Dunn NSU Infrastructure Manager Attachments cc: Thor Cutler, EPA Region 10 (descriptive report only) Talib Syed, EPA Consultant (logs and descriptive report) Jim Regg, AOGCC (descriptive report only) Pro! Bay Unit, EPA mc Permit: AK!IoS-A Grind & Inject Well Surveillance: Shut-In Temperature Logs Background EPA permit AK-1I008-A effective 09/01/07 requires a fluid movement test in Class I Grind & Inject wells each calendar year, Part II C 3 b (2). Approved fluid movement tests include tracer surveys, temperature logs, noise logs, oxygen activation/water flow logs, borax pulse neutron logs, or other logs. Tests (and fill depth tags) performed within one year prior to the effective date of the permit may be accepted as meeting the permit requirements. Shut-in temperature logs were run in the three Grind & Inject (GNI) wells in May, June and July 2007. The GNI wells normally inject cold slurry or cold water at 50-70 degrees F. The original formation temperature of the target disposal formation was about 115 deg F. The wells were shut-in for 12 to 23 days prior to running the logs. This technique is commonly used for cement channel detection in injection wells on the North Slope of Alaska. _ Wellbore teml2eratures are affected by the temperature of the injected fluids by either by conduction or by convection. When the well is injecting fluids, the wellbore and the formation adjacent to it reaches a temperature near the injection fluid temperature due to conductive heat transfer. When injection ceases, the well bore temperature will begin to return toward its original temperature. The rate of temperature change of the shut-in well will depend on the original formation temperatures, the injection fluid temperature and the volume of injection. In the G&I wells, the injected fluids are colder than the formation temperatures below about 4000 to 4500 ft TVD. In areas where the injected fluids enter the formation, both conduction and convective heat transfer are involved. The amount of rock cooling is much larger and the rate of temperature change after shut-in will be much slower. Channeling adjacent to the wellbore is evident because cooler injected fluids leak off into formations throughout the length of the channel. Several types of logging tools are available to be used to record the temperatures of the wellbore fluids: surface reading tools run on electric line and memory tools run on slick line. The results from both instruments are presented in the enclosed log of borehole temperature and pressure versus measured depth. Shut-In Temperature Survey Procedure EPA permit AK-1I008-A requires tracer surveys to "... be conducted at injection pressure at least equal to the average continuous injection pressure observed in the previous 6 months." Injection is cycled into the GNI wells on a rotating basis, with one well injecting at a time. Prior to the Class I permit effective date, the average and maximum injection pressures were been reported to the AOGCC on form 10-406. Average daily injection pressures in the three wells over the 6 months prior to the surveys were: GNI-Ol 1137 psi, GNI-02A 1406 psi, and GNI-03 1105 psi. Average wellhead pressures were equal to or in excess of these pressures for the injection cycle completed prior to the surveys. In each well, the survey procedure involved the following steps: Inject a significant volume of water at the required pressure. Shut-in and freeze protect the well after an injection cycle. After at least 5 days, rig up logging tools, pressure test lubricator. Confirm depth control by comparing to the tie-in log on record. Run the shut-in temperature/pressure survey. Rig down and move off. Page I of 5 pm!e Bay Unit, EPA mc Pennit: AKlos-A Grind & Inject Well Surveillance: Shut-In Temperature Logs GNI-Ol Shut-In Temperature Survey Results - reference GNI-Ol PDS Temp/Pressure Survey, 28-May-2007. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: gamma ray (API units), casing collar locator, Temperature and Pressure. The last injection cycle before logging took place between 04/29 and 05/05/07. The shut-in temperature trace indicates uniformly increasing temperatures with depth to at least 7350 feet measured depth (MD) or 6054 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 7700' MD, 6296' TVD. Below that point, the temperature declined until the fill level is reached, near the top of the active perforations. Based on this data, there is no evidence of injected fluid movement above about 6050' TVD and it is unlikely there is any significant injected fluid movement near the wellbore above 6300' TVD. --'.._'._~.~- . Aplot of the temperature log data from 2005,2006 and 2007 along with the original baseline~._ temperature survey is included below. GNI-01 Temperature Logs 130 I I I I 120 I i ... .. ... , .. 70 !.. . . . !. . . . ! · 07112105 5 day 81 I I I I I I · Perfs/Jewelry - 2/28/98 BL i I 110 I I, I I I U. I .. 100 I ~ ¡ '" ; a. ~ 90 ¡ I- i ¡ I I 80 I · 06/23106 7 day 81 ---.- OS/28/07 23day 81 4500 5000 6000 - 6500 ~ I 60 LtI 4000 5500 True Vertical Depth feet 7000 Page 2 of 5 pro!e Bay Unit, EPA mc Permit: AK.tS-A Grind & Inject Well Surveillance: Shut-In Temperature Logs GNI-02A Shut-In Temperature Survey Results - reference GNI-02 Schlumberger Static Bottom Hole Pressure survey, Press / Temp / GR / CCL, 14-Jul-2007. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: gamma ray (API units), casing collar locator, Temperature and Pressure. The last injection cycle before logging took place between 06/26 and 07103/07. The shut-in temperature trace indicates uniformly increasing temperatures with depth to at least 7550 feet measured depth (MD) or 6143 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 7875' MD, 6354' TVD. Below that point, the temperature declined until the fill level is reached, near the top of the active perforations. Based on this data, there is no evidence of injected fluid movement above about 6140' TVD and it is unlikely there is any significant injected fluid movement near the wellbore above 6350' TVD. --,---- A plot of the temperature log data from 2007 along with both the GNI-02A baseline and the original GNI-02 the baseline temperature survey is included below. GNI-02A Temperature Logs 130 I I 120 i ! ·ooG-fb 110 i i L1. ì ø 100 i :; I 1ií à3 ) c. I E i ~ 90 ¡ I I i I 80 I . Jewelry/Perts o 2 02-28-98 BL -2A12-24-06 BL --+-2A 07-14-07 I 60 ' 4000 -- 4500 . 5000 5500 True Vertical Depth It 6000 6500 7000 Page 3 of 5 pru!e Bay Unit, EPA mc Permit: AKAs-A Grind & Inject Well Surveillance: Shut-In Temperature Logs GNI-03 Shut-In Temperature Survey Results - reference GNI-03 Schlumberger Pressure / Temperature Survey, 06-1un-2007. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: gamma ray (API units), casing collar locator, Temperature and Pressure. The last injection cycle before logging took place between 05/16 and OS/25/07. The shut-in temperature trace indicates uniformly increasing temperatures with depth to at least 6750 feet measured depth (MD) or 6124 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 7000' MD, 6332' TVD. Below that point, the temperature declined until the fill level is reached, near the top of the active perforations. Based on this data, there is no evidence of injected fluid movement above about 6125' TVD and it is unlikely there is any significant injected fluid movement near the wellbore above 6330' TVD. -~_._------ .-' A plot of the temperature log data from 2005, 2006 and 2007 along with the original baseline temperature survey)s included below. ----_..~---- -~--------- GNI-03 Temperature Logs 130 70 -6/6/98 Baseline 120 · Perfs/Jewelry 110 · 06/22/05 5 day 51 · 06/29/06 5 day 51 ""!I' 100 _ -k-06/06/07 12day 81 " 10 0; a. ~ 90 ~ 80 60 . 4000 . . 4500 5000 5500 True Vertical Depth feet 6000 6500 7000 Page 4 of 5 pru!oe Bay Unit, EPA VIC Permit: AKtOS-A Grind & Inject Well Surveillance: Shut-In Temperature Logs Overall Conclusions 1. There is no indication of channeling upho1e in any of the GNI wells above about 6050' TVD. This is significantly below the top of the injection zone at about 4500' TVD. 2. Most of the injected fluid was confined below about 6300' TVD. Michael L. Bill August 21, 2007 --,-------~-~-----_.-._.~---_._._-_.~-_._----_._-- ~------~--~.-._----_._~-_._-~_._-_..__._..._------ Page 5 of 5 sCANNED JUN 2 1 2007 Schlumberger NO. 4306 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 11fC1 UI~ lez--=l-J(ab Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Prudhoe Bay l CI CD D t BL Well Job# OQ Description ae o or L3-12 11695062 PRODUCTION PROFILE 06/06/07 1 GNI-03 11637128 PRESSITEMP SURVEY 06/06/07 1 Y-11C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDl 06/01/07 1 13-29L 1 11686753 LDl 05/28/07 1 Y-05A 11628778 MEMORY INJECTION PROFILE 05/28/07 1 l5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROFIIPROF 06/05/07 1 Y-35A 11661152 MEMORY PROD PROFilE 06/03/07 1 N-15 11637129 PRODUCTION PROFilE 06/13/07 1 01-07A 11626098 PRODUCTION PROFILE 05/28/07 1 13-29L 1 11686753 LDl 05/28/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDl 06/13/07 1 G-23A 11638639 LDL 06/03/07 1 14-05A 11813055 PPROF WIRST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFilE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K·39 11813054 INJECTION PROFILE 06/08/07 1 3-41/K-39 11813054 INJECTION PROFilE 06/09/07 1 Z-29 11686758 PRODUCTION PROFilE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWD/lWD 09119/05 2 1 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 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: ,Ii H\¡ 1',0 .lOlrf Received by: /")[1 k:t1 06118/07 . . GNI-03 (PTD# 1971890), and M-29A (PTD# 2000990) MIT Forms . Jim, Tom & Bob, Please see the attached MIT forms for GNI-03 (PTD# 1971890) and M-29A (PTD# 2000990). GNI-03 was tested for 2-year compliance and M-29A was tested for 4-year compliance. As requested, I have included the TIO plot for the last 90 days on M-29A. Please call with any questions. Thank You, Donald Reeves (filling in for Anna Dube) Well Integrity Coordinator 907 -659-51 02 907 -659-5100 x1154 pgr sCANNED MA'f ·2 9 2007 «MIT PBU GNI-03 12-24-06.xls» «MIT PBU M-29A 02-27-06.xls» «M-29A TIO Plot.ZIP» Content-Description: MIT PBU GNI-03 12-24-06.xls PBU GNI-03 12-24-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU M-29A 02-27-06.xls MIT PBU M-29A 02-27-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 M-29A TIO Content-Description: M-29A no Plot.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 1 of 1 5/23/20073:34 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test \Z4 c; P31 Ò? Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.US;Jim_Regg@admin.state.ak.us;Tom_Mafntr@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well P.T.D. Notes: Well PTD. Notes: Well P.T.D. Notes: TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / GNI 12/24/06 Jack Winslow Interval P/F Interval P/F o P TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUNey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) 2006-1224_MIT _PBU _ GNI-03.xls '\ STATE OF ALASKA '\ ALA~ _~ OIL AND GAS CONSERVATION COMrvl.....~ION REPORT OF SUNDRY WELL OPERATIONS Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing pressure o 7798 100 700 o 1438 0 350 I 15. Well Class after croposed work: t Exploratory r , D, evelopment r, Service Pft.1), \?J, (» 16. well,S,t,atus after proposed work:, ' -./ 11' v>r:1/ Oil r Gas r WAG r GINJ r WINJ ^ WDSPL rI7' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 50.9 KB 8. Property Designation: ADL-028324 11. Present Well Condition Summary: Total Depth measured 7840 true vertical 7035.66 Effective Depth measured 7740 true vertical 6952.41 Casing Conductor Surface Production Length 80 2580 7794 Size 20" 94# H-40 13-3/8" 68# L-80 9-5/8" 47# L-80 Perforation depth: Measured depth: 7315 - 7335 True Vertical depth: 6596.59 - 6613.39 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Contact Sharmaine Vestal Printed Name Sharmaine Vestal __ . )"" ' Signat~ '1~~ Form 10-404 Revised 04/2004 AUG :1 0 2005' Stimulate 0 ~!@~'?(IJ~¡';il Waiver 0 Time Extensiòri t:r' Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory [] 197-1890 Service R)' 6. API Number: 50-029-22820-00-00 Plug Perforations [] Perforate New Pool 0 Perforate 0 4. Current Well Class: Development ID! Stratigraphic D 9. Well Name and Number: GNI-03 10. Field/Pool(s): Field/ Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 30 - 110 29 - 2609 28 - 7822 TVD 30 - 11 0 29 - 2601.19 28 - 7020.67 Burst 1490 4930 6870 Collapse 470 2270 4760 "~f' [~ I~ ï ~\¡ v:: ~-) ('j¡' E·, \Oli~' n 'J Z 0 U 5 ~,:;~'V.:l·~a·"b ~ '\J~"~~~I':~' ~,,,_, . e"O". 7620 - 7640 6852.35 - 6869.05 7" 26# L-80 25 - 4263 7" 26# L-80 Baker Sabl-3 Hydro-Set 4203 RBDMS BFL AUG '3 1 2005 Title Data Mgmt Engr Phone 564-4424 Date 8/29/2005 , " ,,': "I,_.i L" '\....i i .. ~ '","", . ~ ~ ¡ \ Submit Original Only ) ') ~~ G N 1-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDA TE I SUMMARY 7/27/2005 SET IBP PLUGS AT 2430 FT AND 2350 FT 7/29/2005 TIO=40/40/140 TEST IBP MIT TBG PASSED 2400 PSI TEST PUMPED 1.3 BBLS OF 65* DIESEL BLEED BACK 1 +BBLS TIO=40/40/140 7/31/2005 T/I/O=20/30/160 Temp=S/1 Bleed WHP's to 0 psi (pre Tree c/o) Fluid levels near surface. T/I/O pressures bled to 0 psi in < 10 min. each - all gas. Final T/I/O=O/O/O+ 8/4/2005 T/I/O=0/20/160 MIT TBG to 3500 psi (Post Tree C/O) (PASSED) Pressured up TBG w. 1.6 bbls DSL, TBG lost 150 psi in first 15 min and 70 psi in second 15 min for a total pressure loss of 220 psi over 30 min, Bled TBG presure. Final WHP's= 0/30/160 8/6/2005 ***WELL S/I ON ARRIVAL *** (post tree change) PULLED 3 3/8" x 7" BRIDGE PLUG FROM 2328' SLM. PULLED SECOND 3 3/8" x 7" BRIDGE PLUG FROM 2408' SLM. ALL RUBBERS RECOVERED. ***RETURNED WELL TO GNI FOR INJECTION*** FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL TO: Jim Regg :J P.I. Supervisor )"(fI11 ) 5/'a(o~ State of Alaska Alaska Oil and Gas Conservation Commþ DATE: Wednesday, May 04, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC G&I-03 PRUDHOE BAY UNIT G&I-03 '\" \coq \0\ \ MEMORANDUM FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv 3~ Comm Well Name: PRUDHOE BAY UNIT G&I-03 Insp Num: mitCS050501l24354 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-22820-00-00 Permit Number: 197-189-0 Inspector Name: Chuck Scheve Inspection Date: 4/30/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G&I-03 Type Inj. N TVD 4203 IA 70 1570 1540 1530 P.T. 1971890 TypeTest SPT Test psi 1050.75 OA 180 230 240 240 Interval OTHER P/F P Tubing 340 400 400 400 Notes: Well on a two year MIT schedule SG.ANNED'MAY 3 1 2005 Wednesday, May 04, 2005 Page 1 of 1 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 08/27/03 NO. 2952 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 9950'1 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. 6-28A ~.~(~ ~ -.- I ~ LDL 08/17/03 L1-16 ~,-~ c~ -I ~ ~"~.. RST-G~VEL PACK 08/20/03 G"I'03 ~ ~ ~ ~ ~ ~ SHUT'IN TEMP SURVEY 08/~ 8/03 NK-62 ~ ~~ ~ PROD PROFILE/DEFT 05/30103 4-081P-27-- ~ ~ ~ ~~ INJECTION PROFILE 08~20~03 2-6~Q-17 ~[~'l ~ LDL 08/17/03 2-3~SN-03 ;~ ~ ~ ~ ~ LDL 08118103 , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. . '~ '~. ,,., ,~ ~'~.~ :,, '~ ,~ ".~="- ~ .~ Anchorage, Alaska 99508 ~ ..,_..L,~=, ~, = ..... '- ~ ' Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth FYI: G~I-03 MIT Form Subject: Date: From: To: CC: FYI: GNI-03 MIT Form Fri, 25 Apr 2003 14:26'52 -0500 "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegfityEngineer@BP.com> "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us>, "AOGCC Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak.us>, "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin. state.ak.us> "Rossberg, R Steven" <RossbeRS~BP.com>, "Engel, Harry R" <EngelHR~BP.com>, "AOGCC Chuck Sheve (E-mail)" <Chuck_Sheve~admin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe Bay~admin.state.ak.us>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Bill, Michael L (Natchiq)" <Michael.Bill~BP.com> l~l~~~t~;t~ineer@ bp.com ~t~lcllrd~l~itt~m~in'~t~ltll]~'~if~r,(~~)l~lq~ssed it's 2-year MITIA. Let me know if you have any ~a~tJ(9~.) 659-5102 Mobil: (907) 943-1154 Joe ["~MIT PBU GNI-03 04-25-03.xls Name: MIT PBU GNI-03 04-25-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 l ofl ~.~~ JUN J. 6 .003 5/8/2003 4:23 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay' / PBU / GNI 04/25/03 Joe Anders Chuck Scheve Packer Depths (ft.) Pretest Initial 15Min. 30 Min. WelIIGNI-03 Type Inj. P.T.D. I1971890 Notes: 2-year MITIA WellI Type Inj. P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: P.T.D.I Notes: Type l~. Typel~. Type l~. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-0425_M IT_PBU_GN 1-03.xls MEMORANDUM TO: THRU: FROM: Randy Ruedrich Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 25, 2003 Jim Regg 5~'~d~ '51'~/b-sSUBJECT:BPxMechanica' IntegrityTest P.I. Supervisor Surfcoat Pad GNI-03 Chuck Scheve PBU Petroleum Inspector NON- CONFIDENTIAL , Packer Depth Pretest Initial 15 Min. 30 Min. I w~,,I ~N,-O~ IType,nj.IN I~.v.~.l ~o~ IT~,,~I ~o I ~o I ~o I ~o I,nt~rv~,l OI P.T.D.I 197-189 ITypetestl P ImestpsiI 1006 I Casingl 0 I 1540 I 1500 I 1490 I P/F I P I Notes: 2 Year test as required Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well Notes: Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P'- Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Surfcoat Pad and witnessed the 2 year MIT on well GNI-03. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Number of Failures: 0 Attachments: Total Time during tests: '1 hour cc: MIT report form 5/12/00 L.G. MIT PBU GNI-03 4-25-03 CS.xIs 5/7/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~_ \.,%\b\ DATE: April 10. 2001' Commissioner ~'~' \.~__ ~',x~,l .,~.0-~.~UBJECT: Mechanical Integrity Tests THRU: P.i. SuOervisor/.~,, ~.~..- ,,-,"' '" 0'~0 \ BPX Tom Maunder ~-~ ~' ( _ GNI #3 FROM: John H, SpaUlding Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay NON- .C. ONFIDENT!AL Packer DePth Pretest Initial 15 Min. 30 Min. WellJ GNi~03.~Type'Inj.i * t~.V.D. ! 4002'lTubingl 300I310I300I300 [Intervali * :,::~P.¥.Oi'J.-i97:l~;JYypet~tl ~ ITestpsil 15~0' I Casingi lo ! ~5so' I' ~5oo I ~o I P/FI P' Notes: * In'ectin 9 5-9 9 seawater/ ravel slurry Interval* 2 year schedule for monitoring weh] J'9 ,..PPg ..... g . . . ' I Typ, ~nj. I I T.V.D. !i Tu~n~ I I I I I~nterva~! P.T.D.I , .lTypet~t.! . ITe~t'P,~l "'.'l'C~"~n~! . , '1' .'1 I' .'1 F'/F I ' ' Notes: Well] [~.,'~.O.j ~.,T.D.! ~ot~: J TypelnJ. I' !T.V.D.I 1 TubingI" I ....i ' '1 I lnte~alJ .... 'JType~:estJ "JT,es, tpsiJ ' J C~sir~gJ I " I, I ' I P/~ ! . J TYpe Inj. I I :l':~/.O. J J Tubing j J I t' J lntervalJ TypetestI J Test psi J icasi~'gI' I I I' I "/~ I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS IN J, S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Te~'s Details As noted in the above report, no failures or problems were observed. The Grind and injection wells are on a 2 year monitoring schedule. M.I.T.'s performed: 1_ Attachments: Number of Failures: 0_. Total Time during tests: 1 hr, qc: MIT report form 5/12/00 L.G. 010411-MIT GNI-js 4/13/01 Well Compliance Report File on Left side of folder 197-189-0 MD 07840 TVD 07036 PRUDHOE BAY UNIT Completion Date: G&I-03 50- 029-22820-00 Completed Status: WDSPL ARCO Current: Name D 8892 L CBL L GR-MD L GR-TVD L PEX-AIT L PEX-HALT L PEX-LDT/NT L PEX-MCFL L PRES/TEM SRVY L STEP RATE TEST L TEM SRVY L TEMP-PRES/GR jlnterval Sent Received ~ SCHLUM GR OH 3/11/99 3/18/99 ~AL 4000-7730 CH 5 6/15/98 6/24/98 ~AL 4150-7787 OH 3/11/99 3/18/99 "~AL 4000-6990 OH 3/11/99 3/18/99 6~AL 4152-7830 OH 3/17/99 3/18/99 FINAL 4152-7810 OH 3/17/99 3/18/99 / AL 4152-7830 OH 3/17/99 3/18/99 (.~tlqAL 4152-7830 OH 5 3/17/99 3/18/99 ~I~L 4150-7732 '~ ~ {qq,~ CH 2 11/30/98 12/3/98 ~ 4300-7660 CH 5 3/10/99 3/11/99 ~'~AL 50-7320 CH 5 6/18/99 6/23/99 ~I~~ 100-7726 · ~ t',*,- '~- '~ r:~q ~ CH 5 7/1/98 7/2/98 OH 10/22/98 10/22/98 OH 3/17/99 3/18/99 T/C/D R SRVY RPT ~~HLUM 0-7840. T 9026 ~ SCHLUM PEX-AIT/BHC/PDC Daily Well Ops ~/~4¢~ -- ~; ?~ Are Dry Ditch Samples Required? yes Was the well cored? yes ~ Analysis Description ~ no ~ Sampl(~ . Comments: Tuesday, May 30, 2000 Page 1 of l 6/18/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 All'N: Sherrie NO. 12659 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Sepia CDR D.S. 9-33~ot9~-~ 99220 RST 990513 1 ] , , GNI #3 41 (~ TEMPERATURE SURVEY 990519 ] 1 D.S. 3-07 C~, ~-- INJECTION PROFILE 990529 1 1 D.S. 3-09 PROD. PROFILE W/DE~ 990515 D.S. 3-10 ~(~ INJECTION PROFILE 990514 1 ] D.S, 3-35 PROD, PROFILE W/PSP 990525 ] 1 D.S. 9-08 ~l~ INJECTION PROFILE 990514 1 ] D.S, 11-16 PROD, PROF. PSP/DE~/GHOST 990606 1 1 D.S, 16-10 ~ ~[~ INJECTION PROFILE 990605 1 ] D.S. 16-15 DE~ W/PSP 990516 1 1 D.S. 16-29A PROD. PROF. W/GAS LI~ SURVEY 990603 1 1 DATE: ,.![JN 2 3 '19 Oil&c as" '"' "' Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 51 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service~X Prudhoe Bay Unit '. 4. Location of well at surface 8. Well number 888' FNL, 398' FEL, Sec. 26, T11 N, R15E, UM GNI-03 At top of productive interval 9. Permit number / approval number ~: j~ '~ ~' ~,r: 4576' FSL, 2200' FWL, Sec. 25, T11N, R15E, UM 97-189 At effective depth 10. APl number 50-029-22820 At total depth 11 Field / Pool .. · 696' FNL, 2846' FEL, Sec. 25, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 7840 feet Plugs (measured) ClBP @ 7680' MD (11/27/1998) true vertical 7036 feet Effective depth: measured 7680 feet Junk (measured) true vertical 6902 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 10' 20" 260 Sx ArcticSet 1 10' 110' Surface 4132' 13-3/8" 153o Sx CS III & 449 Sx Class G 4161' 3987' Production 7812' 9-5/8" 1816 sx C~ass G 7840' 7036' Perforation depth: measured 7315' - 7323'; 7325' - 7335'; 7620' - 7640'. true vertical 6597' - 6603'; 6605' - 6613'; 6852' - 6869'. 0RJGJ / L Tubing (size, grade, and measured depth) 7" 26#, L-80 ']'bg @ 4263' MD. Packers & SSSV (type & measured depth) 9-5/8" x 7" Baker SABL-3 Packer @ 4203' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - 27360 2410 Subsequent to operation - - 28800 2000 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil __ Gas m Suspended _ Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ /~. ~ Title Arco Engineering Supervisor Date Z/~.., ,~¢_/~ ¢' Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE GNI-03 DESCRIPTION OF WORK COMPLETED ADD PERFORATION Date Event Summary 11/27/1998: 11/28/1999: 11/30/1999: RIH & tagged PBTD @ 7680' MD. RU ELU. PT'd BOPE to 3000 psi. RIH w/perf guns & shot 18' of Add Perforations @: 7315' - 7323' (Ugnu Zone) Ref Log: Array Induction Tool 5/10/1998 7325' - 7335' (Ugnu Zone) Attempted to POOH w/guns - lost one gun as fish. ASF. Used 4-1/2" carriers. All shots @ 5 SPF, 60° phasing, random orientation, & balanced press. RD. Successfully fished perf gun from wellbore. Returned well to injection & obtained a valid injection rate. AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS 97-189 TEMP-PRES/GR L 100-7726 97-189 CBL L 4000-7730 lO-4O7 ~ CO~ZT~O~ O~TZ / / / ~a~Y WZ~ 0~S ~ / / / TO / / / Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS Page: 1 Date: 11/17/98 RUN RECVD FINAL 07/02/98 FINAL 06/24/98 / / / / / / ye s no yes no T MEMORANDUM TO: -~3avid ,, Chairman State of Alaska ATaSka oir~ndG'a-s C~nse'rvatFOn ~Commission THRU' Blair Wondzell, ~ P. I. Supervisor ,,¢7~¢ FROM' Larry Wade, ~-~ SUBJECT: Petroleum Inspector FILE NO: .DOC BOP Test Nabors 2ES PBU GNI #3 PTD 97-189 April 30,1998: i traveled to Surfcote pad to witness a BOP test on Nabors 2ES. They had to change a grease fitting on a valve in the choke manifold and change the lower set of VBR's in the BOP when they wouldn't pass the pressure test. The crew was knowledgeable and the test went smooth despite the problems. SUMMARY: BOP test on Nabors 2ES. 1 failure 7 hours Attachments: afmgd4fe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover:~ DATE: April 30,1998 Drlg Contractor: Nabors Rig No. 2ES PTD# 97-189 Rig Ph.# 659-4835 Operator: ARCO Rep.: Sheridan Whipp Well Name: GNI #3 Rig Rep.: Charles Henley Casing Size: 13 3/8 Set @ 4,156 Location: Sec. 26 T. lIN R. 15E Meridian Test: Initial Weekly Other Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gert) PTD On Location X Standing Order Posted X Well Sign X Drl. Rig X Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 250/5,000 250/5, O00 250/5,000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams 1 Blind Rams Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve I Quan. Test Press. 1 250/2500 I 250/5,000 250/5,000 250/5,000 250/5,000 250/5,000 250/5,000 P/F P P P P P P P P MUD SYSTEM: Visual Alarm Trip Tank X x Pit Level Indicators X x Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/5,000 P 34 250/5,000 Func#oned Functioned P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4(~2100 3000I 1600 minutes 33 minutes 34 Remote: Psig. sec. sec. x Number of Failures: f ,Test Time: 7.0 Hours. Number of valves tested 17 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Bottom VBR's would not test. Changed ram packers and seals, retested ok. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12294) afmgd4fe~ds 3/10/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 12416 Company: Alaska Oil & Gas Cons Comm ( Attn: Lori Taylor E 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 2-34A~1~ ~ 99106 MCNL (PDC) 990115 1 I 1 D.S. 4-31 ~[-~O?.*~ 99115 EST 980816 1 1 1 D.S. 14-01A~ ~OZ~ 99101 EST-SIGMA 990223 1 1 1 D.S. 1-26 99112 USIT 980706 GNI ~3 STEP RATE TEST 990306 1 1 , ~ , SIGNED~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521 ,~t~u. 3/11/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 12421 Company: Alaska Oil & Gas Cons Comm , Attn: LoriTaylor I 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape GNI #3 (.iL% C.- 99105 MWD GR/ROP~~. 980506 1 GNI #3 ~ 99105 MWD GR/ROP 980506 1 1 GNI #3 99105 MWD GR/ROP TVD 980506 1 1 i~~ !.,JAR 1 8 1999 SIGNE DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thanked.01'~ RE(;EIVED AI~ ~ & Ga~ C~s. Commi~i~n 3/17/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A1TN: Sherrie NO. 12439 Company: Alaska Oil & Gas Cons Comm O Attn: LoriTaylor D 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape 99104 P~x-Az? 98oso7 i 1 99104 P~×-McFL 980507 1 1 99104 PEX-TDD LZTHODENSZT¥/bTE~UTRON 980507 1 1 99104 ~HC SO~ZC 98o5o7 1 1 SIGN Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: biAR 1 8 1999 ~ Oil & Gas Cons. Commission 11/30/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12105 Compan~ Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape GNI #3 PRESS/TEMP SURVEY 980803 1 1 D.S. 1-14 PRODUCTION PROFILE 980907 1 1 D.S. 07-34 PRODUCTION PROFILE 980924 1 1 D.S.11-01A RST-SIGMA 980609 1 1 D.S. 12-09 PRODUCTION PROFILE W/DEFT 980806 1 1 D.S. 12-19 L,~,,~ Oj INJECTION PROFILE 980913 1 1 ,D.S. 12-23 I~l~.~ INJECTION PROFILE 980922 1 1 !D.S. 13-01 PRODUCTION PROFILE W/DEFT 980818 1 1 ID.S. 13-22 l,eio INJECTION PROFILE 980810 1 1 !D./S. 13-32 ~(~ INJECTION PROFILE 980804 1 1 !D.S. 14-21 Lk~O INJECTION PROFILE 980811 1 1 'D.S. 16-04A PRODUCTION PROFILE 980923 1 1 D.S. 17-15 ~ INJECTION PROFILE 980828 1 1 D.S. 17-19~ PRESSURE & TEMPERATURE SURVEY 980601 1 1 SIGNE DA .~,u~,~ 0ii & ~a~ ~O~i~,. Ou~'~.~ Please sign and return o py of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 'ln~ ,~ WELL COMPLETION OR RECOMPLETION REPORT AI~,I,,OG 1. Status of Well Classification of Servic~i,~/~,~'~,~ u~171~i$$1~ r~oil I--IGas F-JSuspended I--IAbandoned [~Service Class II Cretaceous Disposal W~II 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-189 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22820 4. Location of well at surface 9. Unit or Lease Name 4390' NSL, 397' WEL, SEC. 26, T11N, R15E, UM ~ ~ Prudhoe Bay Unit At top of productive interval /~..~'~"~'"~""~ '~'~ !~ 10. Well Number 4576' NSL, 2200' EWL, SEC. 25, T11 N, R15E, UM ~' ~ ~ - · , . . ~ , GNI-03 At total depth ~ ~"- k 11. Field and Pool 4582' NSL, 2433' EWL, SEC. 25, T11 N, R15E, UM ~"-*~~~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and S~r~ai'No. Pool KBE = 50.90'I ADL 028324 12. Date Spudded4/24/98 113' Date T'D' Reached t 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °ffsh°re I16' N°' °f c°mpleti°ns5/6/98 6/6/98 / N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 7840 7036 FTt 7740 6952 FTI []Yes [~ NoI None MD I 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIP, GR, SP, Caliper, RES, Sonic, DEN, NED, USIT, CBT !23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 13-3/8' 68# / 72# L-80 29' 4161' 16" 1530 sx CS III, 449 sx Class 'G' 9-5/8" 47# L-80 28' 7840' 12-1/4" 1816 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SizE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 7", 26#, L-80 4263' 4203' MD TVD MD TVD 7620' - 7640' 6852' - 6869' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 142 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I I ~J/--~ October 12, 1998 I Class II Cretaceous Disposal Well Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure :CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate r 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. SV3 4105' 3940' SV2 4307' 4111' SVl 4850' 4569' Ugnu 4 5597' 5178' Ugnu 1 6720' 6099' West Sak 2 7343' 6620' West Sak 1 7416' 6681' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fore~l~ng is true and correct to the best of my knowledge Signed ~_.~_2~__ .~,~. ~___~~--~ .) .)_..)./' q, -:~.~ DanStone Title Engineering Supervisor Date ~"), ~ GNI-03 97-189 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Operator ARCO Performance Enquiry Report Date 19:45, 03 Jun 98 GNI-03 Formation Integrity Test Page The analysis is from - 01:30, 02 May 98 - to - 01:30, 02 May 98 Programs in Result Table: GNI-03 Drill & Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) GNI-03 Event 01:30, 02 May 98 01:30, 02 May 98 0 hr 0 min Obtained leak off 11.7 Depth MDR Hole Size MDR 12-1/4 Facility Date/Time 22 Apr 98 23 Apr 98 24 Apr 98 25 Apr 98 26 Apr 98 27 Apr 98 28 Apr 98 29 Apr 98 30 Apr 98 PB Surfcote Progress Report Well GNI-03 Rig Nabors 2ES Page Date 22:00-06:00 06:00-09:00 09:00-14:00 14:00-20:30 20:30-00:00 Duration 8hr 3hr 5hr 6-1/2 hr 3-1/2 hr Activity Rig moved 50.00 % Rig moved 100.00 % Installed Rig services Rigged up Drillfloor / Derrick Rigged up Rig services 00:00-06:00 06:00-10:00 10:00-12:00 12:00-16:00 16:00-00:00 00:00-06:00 06:00-12:00 12:00-00:00 00:00-03:30 03:30-04:00 04:00-06:00 06:00-12:00 12:00-00:00 00:00-06:00 06:00-12:00 12:00-17:00 17:00-18:00 18:00-19:00 19:00-20:00 20:00-00:00 00:00-01:30 01:30-03:30 03:30-06:00 06:00-07:00 07:00-07:30 07:30-10:30 10:30-14:00 14:00-15:00 15:00-16:00 16:00-16:30 16:30-18:00 18:00-19:00 19:00-00:00 00:00-06:00 06:00-09:30 09:30-12:30 12:30-13:30 13:30-16:30 16:30-20:30 20:30-21:00 21:00-22:00 22:00-22:30 22:30-23:15 23:15-23:45 23:45-00:00 00:00-00:30 00:30-01:30 01:30-04:00 04:00-06:00 6hr 4hr 2hr 4hr 8hr 6hr 6hr 12hr 3-1/2 hr 1/2 hr 2hr 6hr 12hr 6hr 6hr 5hr lhr lhr lhr 4hr 1-1/2 hr 2hr 2-1/2 hr lhr 1/2 hr 3hr 3-1/2 hr lhr lhr 1/2 hr 1-1/2 hr lhr 5hr 6hr 3-1/2 hr 3hr lhr 3hr 4hr 1/2 hr lhr 1/2 hr 3/4 hr 1/2 hr 1/4 hr 1/2 hr lhr 2-1/2 hr 2hr Rigged up Rig services Made up BHA no. 1 Tested Divertor Made up BHA no. 1 Drilled to 370.0 ft Drilled to 730.0 ft Drilled to 1100.0 ft Drilled to 1744.0 ft Drilled to 1997.0 ft Circulated at 1997.0 ft Pulled out of hole to 200.0 ft Drilled to 2358.0 ft Drilled to 2987.0 ft Drilled to 3400.0 ft Drilled to 3500.0 ft Drilled to 3970.0 ft Circulated at 3970.0 ft Drilled to 4023.0 ft Circulated at 4023.0 ft Drilled to 4161.0 ft Circulated at 4161.0 ft Pulled out of hole to 2000.0 ft Circulated at 4161.0 ft Circulated at 4161.0 ft Dropped EMMS survey barrel Pulled out of hole to 4161.0 ft Pulled BHA Singled in drill pipe to 560.0 ft Installed Casing hanger running tool Held safety meeting Rigged up Casing handling equipment Repaired Casing handling equipment Ran Casing in stands to 656.0 ft Ran Casing in stands to 2200.0 ft Ran Casing to 4152.0 ft (13-3/8in OD) Circulated at 4154.0 ft Laid down 45.0 ft of Riser Ran Drillpipe in stands to 4066.0 ft Circulated at 4161.0 ft Pumped Water spacers - volume 70.000 bbl Mixed and pumped slurry - 523.000 bbl Investigated pressure change Mixed and pumped slurry - 92.000 bbl Displaced slurry - 70.000 bbl Functioned Float collar Held safety meeting Circulated at 4060.0 ft Pulled Drillpipe in stands to 4060.0 ft Rigged down Divertor 1 03 June 98 Facility PB Surfcote Progress Report Well GNI-03 Rig Nabors 2ES Page Date 2 03 June 98 Date/Time 01 May 98 02 May 98 03 May 98 04 May 98 05 May 98 06:00-07:00 07:00-10:00 10:00-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-16:00 16:00-17:30 17:30-19:00 19:00-19:30 19:30-20:30 20:30-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:00-12:00 12:00-13:30 13:30-14:00 14:00-20:00 20:00-21:30 21:30-01:30 01:30-06:00 06:00-12:00 12:00-12:30 12:30-21:00 21:00-21:15 21:15-00:00 00:00-00:30 00:30-06:00 06:00-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-16:45 16:45-19:30 19:30-22:00 22:00-22:45 22:45-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-02:00 02:00-02:15 02:15-06:00 06:00-12:00 12:00-12:30 12:30-13:00 13:00-14:15 14:15-15:00 15:00-00:00 Duration lhr 3hr 2hr 1/2 hr 1/2 hr lhr 2hr 1-1/2 hr 1-1/2 hr 1/2 hr lhr 4-1/2 hr lhr 2-1/2 hr 1-1/2 hr 6hr 1-1/2 hr 1/2 hr 6hr 1-1/2 hr 4hr 4-1/2 hr 6hr 1/2hr 8-1/2 hr 1/4 hr 2-3/4 hr 1/2 hr 5-1/2 hr 4-1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 2-3/4 hr 2-3/4 hr 2-1/2 hr 3/4 hr 1-1/4 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 3-3/4 hr 6hr 1/2 hr 1/2 hr 1-1/4 hr 3/4 hr 9hr Activity Rigged down Divertor Installed Casing head Rigged up BOP stack Held safety meeting Rigged up BOP stack Installed BOP test plug assembly Tested BOP stack Rigged up Bottom ram Tested BOP stack Retrieved BOP test plug assembly Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Serviced Block line Made up BHA no. 2 Made up BHA no. 2 (cont...) R.I.H. to 4069.0 ft Tested Casing Drilled cement to 4181.0 ft Circulated at 4181.0 ft Performed formation integrity test Drilled to 4424.0 ft Drilled to 4743.0 ft (cont...) Held safety meeting Drilled to 5100.0 ft Held drill (Kick while drilling) Drilled to 5217.0 ft Held safety meeting Drilled to 5446.0 ft Investigated pressure change Drilled to 5473.0 ft Pulled out of hole to 4500.0 ft Held safety meeting Pulled out of hole to 700.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 4100.0 ft R.I.H. to 5473.0 ft Drilled to 5560.0 ft Held safety meeting Drilled to 5777.0 ft Drilled to 5777.0 ft (cont...) Held safety meeting Drilled to 6479.0 ft Held safety meeting Drilled to 6605.0 ft Held drill (Kick while drilling) Drilled to 6700.0 ft Drilled to 6955.0 ft (cont...) Held safety meeting Drilled to 6986.0 ft Pumped out of hole to 5400.0 ft R.I.H. to 6986.0 ft Drilled to 7306.0 ft Facility PB Surfcote Progress Report Well GNI-03 Rig Nabors 2ES Page Date 3 03 June 98 Date/Time 06 May 98 07 May 98 08 May 98 09 May 98 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-17:30 17:30-19:00 19:00-21:30 21:30-22:00 22:00-23:30 23:30-00:00 00:00-00:30 00:30-02:30 02:30-06:00 06:00-09:30 09:30-09:45 09:45-10:30 10:30-16:30 16:30-19:30 19:30-20:00 20:00-22:30 22:30-23:00 23:00-23:30 23:30-00:00 00:00-00:30 00:30-05:30 05:30-06:00 06:00-07:00 07:00-08:30 08:30-10:00 10:00-10:30 10:30-14:30 14:30-15:00 15:00-17:00 17:00-17:30 17:30-19:00 19:00-19:15 19:15-20:00 20:00-21:00 21:00-22:00 22:00-23:00 23:00-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-15:00 15:00-16:00 16:00-18:00 18:00-19:00 19:00-19:15 19:15-20:30 20:30-22:00 Duration 1/2 hr 5-1/2 hr 6hr 1/2 hr 5hr 1-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2hr 3-1/2 hr 3-1/2 hr 1/4 hr 3/4 hr 6hr 3hr 1/2 hr 2-1/2 hr 1/2 hr 1/2hr 1/2 hr 1/2 hr 5hr 1/2hr lhr 1-1/2 hr 1-1/2 hr 1/2hr 4hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 1/4 hr 3/4 hr lhr lhr lhr 3hr 1-1/2 hr 1-1/2 hr lhr 5hr lhr 1/2 hr 2-1/2 hr lhr 2hr lhr 1/4 hr 1-1/4 hr 1-1/2 hr Activity Held safety meeting Drilled to 7500.0 ft Drilled to 7657.0 ft (cont...) Held safety meeting Drilled to 7840.0 ft Circulated at 7840.0 ft Pulled out of hole to 4100.0 ft Serviced Block line R.I.H. to 7840.0 ft Circulated at 7840.0 ft Held safety meeting Circulated at 7840.0 ft Pulled out of hole to 720.0 ft Pulled BHA Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Rigged up Top ram Installed Casing hanger Rigged up Casing handling equipment Installed Float shoe Held safety meeting Ran Casing to 3700.0 ft (9-5/8in OD) Installed Completion equipment Ran Casing to 4100.0 ft (9-5/8in OD) Circulated at 4100.0 ft Ran Casing to 5000.0 ft (9-5/8in OD) Held safety meeting Ran Casing to 7800.0 ft (9-5/8in OD) Installed Casing hanger Circulated at 7822.0 ft Held safety meeting Circulated at 7822.0 ft Held safety meeting Pumped Gas spacers - volume 70.000 bbl Mixed and pumped slurry - 372.000 bbl Displaced slurry - 583.000 bbl Functioned DV collar Circulated at 4168.0 ft Removed Casing hanger running tool Installed Seal assembly Serviced Top ram Tested BOP stack Made up BHA no. 4 Held safety meeting Made up BHA no. 4 R.I.H. to 4152.0 ft Circulated at 4168.0 ft Reverse circulated at 4168.0 ft Functioned downhole tools at 4168.0 ft Tested Casing - Via string Drilled installed equipment - DV collar Facility PB Surfcote Progress Report Well GNI-03 Page 4 Rig Nabors 2ES Date 03 June 98 Date/Time 10 May 98 11 May 98 12May98 22:00-00:00 00:00-00:30 00:30-02:30 02:30-05:00 05:00-06:00 06:00-08:30 08:30-09:30 09:30-10:30 10:30-11:30 11:30-12:00 12:00-12:30 12:30-18:30 18:30-19:00 19:00-19:30 19:30-20:30 20:30-22:00 22:00-00:00 00:00-00:30 00:30-01:00 01:00-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-12:00 12:00-12:30 12:30-15:45 15:45-16:30 16:30-18:00 18:00-19:00 19:00-00:00 00:00-00:30 00:30-02:30 02:30-03:00 03:00-05:15 05:15-06:00 06:00-06:30 06:30-09:00 Duration 2hr 1/2 hr 2hr 2-1/2 hr lhr 2-1/2 hr lhr lhr lhr 1/2 hr 1/2 hr 6hr 1/2 hr 1/2 hr lhr 1-1/2 hr 2hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2hr lhr 4-1/2 hr 1/2 hr 3-1/4 hr 3/4 hr 1-1/2 hr lhr 5hr 1/2hr 2hr 1/2 hr 2-1/4 hr 3/4 hr 1/2 hr 2-1/2 hr Activity R.I.H. to 7645.0 ft Held safety meeting Drilled cement to 7740.0 ft Circulated at 7740.0 ft Tested Casing - Via string Pulled out of hole to 4000.0 ft Serviced Block line Pulled out of hole to 1200.0 ft Pulled BHA Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Rigged down Logging/braided cable equipment Held drill (Abandonment) Made up BHA no. 4 R.I.H. to 4908.0 ft Laid down 2100.0 ft of 5in OD drill pipe Held safety meeting Laid down 1600.0 ft of 5in OD drill pipe Pulled BHA R.I.H. to 3435.0 ft Laid down 3435.0 ft of 5in OD drill pipe Laid down 3435.0 ft of 5in OD drill pipe (cont...) Rigged up Tubing handling equipment Ran Tubing to 2000.0 ft (7in OD) Held safety meeting Ran Tubing to 4262.0 ft (7in OD) Installed Tubing hanger Freeze protect well - 142.000 bbl of Diesel Installed Tubing hanger Rigged down BOP stack Held safety meeting Rigged up Surface tree Rigged up High pressure lines Set packer at 4203.0 ft with 4000.0 psi Tested Permanent packer Tested Permanent packer (cont...) Installed Accessories GNI-03 DESCRIPTION OF WORK COMPLETED PERFORATION SUMMARY 6~2~98: RIH w/3-1/2" dummy gun & tag TD @ 7726' MD. 616198: MIRU. Tagged PBTD @ 7732' MD. RIH w/perforating guns & shot 20' of initial perforations as follows: 7620' - 7640' MD Ref. Log: AITH-SP-GR 5/7/98. Used a 4-1/2" carriers & shot 5 SPF @ 60 degree phasing w/balanced pressure. Orientation was random. Noted guns fired. POOH w/perforating gun. RD. SURVEY REPORT Client: ARCO Alaska inc. Field: Prudhoe Bay Well Name: GNI ~3 APl numbe~, 50-029-22820 Job number:. 40002446 Rig: Nabom 2ES County;. NSR State: AK Survey Calculations Calc method for ~ Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum MSL 0.03 FT Depth reference KB 50.90 FT GL above Permanent 21.00 FT KB alx~ve Permanent 50,90 FT DF above Permanent 49.50 FT Vertical section odgin Latidude (+N/S-): 0 FT Departure (+E/W-): 0 FT Azim from rotary table to large{: 84.47 degrees Schlumberger ANADRILL Survey Report Spud Date: 24-Apr-98 Last survey date: 6-May-98 Total accepted surve~ 84 MD of first survey: 0 FT Geomagnetic data Magnetio Model: BGGM 1996 Version Magnetio Date: x Magnetic field strengt~ 1147 HCNT Megne~ dec (+E/W-) 28.5O3 degrees Magnetic Dip: 80.76 degrees IVNVD Survey Reference Criteria Reference G: 1002.68 milliG Reference H: 1147 HCNT Reference Dip: 80.76 degrees Tolerance G: 4 milliG Tolerance H: 6 HCNT Tolerance Dip: 0.3 degrees Magnetic dec (+E/W-) 28.503 degrees Gdd convergence (+;=, 0 degrees Total az corr (+E/W-): 28.503 degrees RECEIVED HAY 2 0 1998 BPXA PDC I Seq Measured Incl Azimuth Course 'I'VD Vertical Displacement Total at Azm DLS Srvy Tool I # Depth angle angle length depth section +N/S- +ENV- lisplacement (deg/ looi quality I (ff~ (deg~ (deg) (fi) {fi) (ff~ Ifil {ff~ {;ffl (de~ 100D t~q)e type 1 0.00 0.00 0.00 0.08 0.00 0.00 0.00 0.00 0.08 0.00 0.00 TIP 2 168.30 0.19 37.76 168.30 168.30 0.19 02.2 0.17 028 37.80 0.11 MWD 6-axis 3 247.97 0.11 357.53 79.70 248.00 0.28 0.40 0.24 0.47 31.00 0,17 IVlVVD 6-a)ds 4 338.14 0.09 22.61 90.10 338.10 0.30 0.55 02.6 0.61 24.83 0.08 MWD 6-ax~s 5 425.83 0.09 44.52 87.70 425.80 0.39 0.66 0.33 0.74 26.41 0.04 MWD 6-axis 6 517.62 0.06 90.32 91.80 517.60 0.49 0.72 0.43 0.83 30.92 0.07 MWD 6-axis 7 607.40 0.15 17.16 89.80 607.40 0.68 0.83 0.51 0.97 31.66 0.16 MWD 6-axis 8 699.41 0.12 348.80 92.00 699.40 0.62 1.04 0.53 1.16 26.95 0.08 MWD 6-axis 9 795.90 0.14 357~2 95.50 795.90 0.61 12.5 0.50 1.35 21.81 0.03 MWD 6-axis 10 890.68 0.19 342.99 94.70 890.60 0.68 1.52 0.45 1.58 16.50 0.07 MWD 6-axis 11 986.53 0.26 6.69 95.90 986.50 0.60 1.89 0.43 1.94 12.81 0.12 MVVD 6-a)ds 12 1081.67 02.7 0.32 952.0 1081.70 0.68 2.33 0.46 2.37 11.08 0.03 MWD 6-axis 13 1178.08 0.40 222.1 95.40 1178.09 0.84 2,87 0.58 2~2 11,52 0.19 MVVD 6-axis 14 12722.5 0.41 322.5 94.20 1272.29 1.19 3.45 0.89 3.57 14.42 0.08 MWD 6-axis 15 1357.17 0.45 45.03 94.90 1367.19 1.69 4.01 1.34 42.3 18.45 0.11 MWD 6-axis 16 1463.12 0.61 4424 95.90 1463.09 2.37 4.65 1.97 5.95 22.93 0.16 · MWD 6-axis 17 15582.3 0.70 32.72 95.10 1558.18 3.12 5.50 2.63 6.10 25.59 0.17 MWD 6-axis 18 1651.33 0.54 46.80 93.10 1651.27 3.81 628 32.6 7.08 27.44 0.24 MVVD 6-a)ds 19 1746.19 0.65 61.20 94~0 1746.17 4.65 6.65 4.06 7.96 30.65 0.19 MWD 6-axis 20 1841.62 0.90 74.72 95.40 1841.56 5.89 7.30 526 9.00 35.74 0.32 MWD 6-axis 21 1936.39 1.83 106.93 94.80 1936.33 8.02 7.06 7.42 1024 46.43 124 MWD 6-axis 22 2033.45 4.03 99.86 97.00 2033.20 12.75 6.02 12.26 13.56 53.84 22.9 MVVD 6-axis 23 2129.40 6.50 98.74 98.03 2128.79 21.29 4.62 20.96 21.46 77.56 2.68 MWD 6-axis 24 2223.83 8.01 95.08 94.40 '~'~ .43 32.95 3.23 32.79 32~5 84.38 1.67 MWD 6-axis 25 2319.92 9.04 98.03 95.10 2317.47 46.95 t .84 46.97 47.01 87.75 1.08 MWD 6-ax~s 26 2416.20 9.62 91.73 98.30 2412.51 622.8 0.82 62.45 62.46 89.25 0.68 MWD 6-axis 27 2511.56 11.64 87.61 95.50 2506.38 79.74 0.99 79.98 79.98 89.29 2.35 MVVD 6-axis 28 2687.20 14.23 89.33 95.50 2599.45 101.07 1.53 101.34 t01.35 89.13 2,74 MWD 6-axis 29 2702.51 15.59 68.80 95.30 2691.54 125.53 1.94 125.86 125.87 89.11 1.43 MWD 6-ax~s 30 2798.58 t6.99 8522. 96.10 2783.78 152.45 3.39 152.76 152,80 58.73 1.80 MWD 6-axis Page 1 ORIGINAL ~h_. lumben~er ANADRILL Survey/Report I Secl __l~e~__ _~_red Incl Azimuth Course TVD Vertical Displacement Total at Azm DLS Srvy Tool # Deplh angle angle length depth section +N/S- +E/W-lisplacement (deg/ tool quality {;fl) (oleg) (deg,) (ff~ (ft) (ftC) (ftC) ~) (ff~) (dwi) 103f~ t~pe type 31 2894.52 18.56 84.44 95.90 2875.10 181.73 6.05 181.92 182.02 88.09 1.66 MWD 6-axis 32 2989.77 20.38 85.48 95.30 2964.95 213.49 8.83 213.56 213.74 87.63 1.95 MWD 6-axis 33 3085.86 22.18 85.95 95.10 3054.49 248.36 11.41 248.34 248.60 87.37 1.88 MWD 6-axis 34 3182.35 24.19 85.89 96.50 3143.19 286.35 14.10 256.23 286.58 87.18 2.98 MVVD 6-axis 35 3275.37 26.52 85.50 93.00 3227.23 326.16 17.09 325.94 326.39 87.00 2.51 MWD 6-axis 36 3370.23 28.21 85.71 94.80 3311.42 369.73 20.43 369.39 369.95 86.63 1.79 MWD 6-axis 37 3466.66 28.96 84.87 96.50 3396.15 415.90 24.22 415.40 416.11 86.66 0.87 MWD 6-axis 38 3562.28 30.43 85.57 95.60 3479.20 463.26 28.13 462.60 463.45 86.52 1.58 MWD 6-axis 39 3658.38 30.43 86.42 96.10 3562.06 511.92 31.53 511.15 512.12 86.47 0.42 NNVD 6-axis 40 3753.42 32.16 86.11 95.00 3643.23 561.25 34.76 560.39 561.47 86.45 1.83 MWD 6-axis 41 3849.10 32.47 86.55 95.70 3724.11 612.39 38.06 611.44 612.62 88.44 0.39 MWD 6-axis 42 3944.17 32.22 86.76 95.10 3804.46 663.25 41.03 662.23 663.50 86.45 0.31 MWD 6-axis 43 4038.44 33.10 86.14 94.20 3883.76 714.05 44.18 712.97 714.34 88.45 1.02 MWD 6-axis 44 4099.90 32.63 85.57 61.50 3935.36 747.52 48.60 746.35 747.80 86.43 0.62 MVVD 6-axis 45 4204.79 32.05 86.27 104.90 4023.89 803.78 50.56 802.47 804.07 86.39 0.83 MWD 6-axis 48 4302.96 31.82 86.46 98.20 4107.23 855.7t 53.84 854.31 856.01 86.39 0.26 MWD 6.-axis 47 4398.45 31.90 56.34 95.40 4188.25 906.94 57.01 904.57 906.37 56.39 0.14 MWD 6-axis 48 4495.29 31.95 86.43 96.9 4270.49 957.28 50.27 955.72 957.61 86.39 0.08 MWD 6-axis 49 4590.11 32.30 55.00 94.80 4350.78 1007.69 64.05 1005.99 1008.93 86.36 0.86 MWD 6-axis 50 4684.52 32.67 83.31 94.40 4430.41 1058.38 69.22 1056.42 1058.69 86.25 1.04 MWD 6.-axis 51 4779.28 33.41 86.67 94.80 4509.88 1110.05 73.71 1107.89 1110.34 86.19 2.11 MWD 6-axis 52 4874.68 33.55 85.17 95.40 4589.46 1162.66 77.43 1160.39 1162.97 86.18 0.88 MWD 6-axis 53 4970.51 34.74 85.95 95.80 4668.74 1216.43 81.59 1213.99 1216.73 86.15 1.31 MWD 6-axis 54 5065.95 35.33 87.30 95.50 4745.94 1271.22 84.84 1268.72 1271.55 86.17 1.94 MWD 6--axis 55 5158.25 35.92 84.26 92.20 4821.89 1324.91 88.78 1322.26 1325.24 86.16 2.00 MVVD 6-axis 58 5254.24 35.01 63.35 95.00 4899.59 1381.28 94.82 1378.32 1381.58 86.05 0.56 MWD 6-axis 57 5350.78 35.78 84.31 98.50 4977.84 1437.90 100.89 1434.63 1438.17 55.98 0.60 MWD 6-axis 58 5437.98 35.74 84.6t 87.20 5048.60 1488.86 105.82 1485.35 1489.11 85.92 0.21 MWD &-axis 59 5533.28 35.30 85.51 95.30 5126.17 1544.23 110.50 1540.51 1544.47 85.59 0.72 MWD 6-axis 60 5627.72 35.02 83.20 94.40 5202.87 1599.25 116.03 1595.26 1599.48 85.84 1.61 MWD 6-axis 61 5723.33 35.71 62.76 95.60 5280.35 1655.23 122.55 1650.85 1655.42 55.74 0.41 MWD 6-axis 62 5819.02 35.50 63.07 95.70 5358.15 1710.91 129.69 1706.15 1711.07 85.55 0.29 MWD 6-axis 53 5913.71 35.67 82.75 94.70 5435.17 1755.99 136.46 1760.84 1755.12 85.57 0.26 MWD 6-axis 54 6000.92 35.62 83.59 86.30 5~35.30 1816.25 142.63 1810.75 1816.35 55.50 0.21 MWD 6-axis 55 6101.42 35.05 63.86 101.40 5588.02 1874.88 149.27 1869.02 1874.97 85.43 0.72 MWD 6-axis 56 6197.20 34.56 83.76 95.80 5,~,,,.68 1929.55 155.13 1923.38 1929.63 55.39 0.51 MWD 6-axis 67 6293.16 34.08 55.45 98.00 5745.97 1983.67 160.23 1977.27 1983.75 85.37 1.05 MWD 6-axis 68 __~'Z~_9.34 33.88 68.27 96.10 5625.68 2037.37 154.11 2030.63 2037.45 55.38 0.56 MWD 6-axis 59 6485.33 33.95 55.47 96.00 5905.33 2090.92 167.48 2084.29 2091.01 85.41 0.14 MWD 6-axis 70 6879.84 34.35 87.55 94.50 5983.53 2143.92 170.16 2137.27 2144.03 85.45 0.83 MWD 6-axis 71 5576.18 34.30 87.14 98.40 6063.15 2198.23 172.62 2191.57 2198.36 55.50 0.35 MWD 6-axis 72 6771.00 34.39 55.99 94.80 6141.42 2251.67 175.38 2244.99 2251.82 85.63 0.11 MWD 6-axis 73 6864.21 33.19 87.50 93.20 6218.87 2303.46 177.87 2296.76 2303.53 85.57 1.32 MWD 6-axis 74 6959.63 33.35 88.40 95.60 6298.80 2355.83 179.74 2349.17 2356.03 55.62 0.54 MWD 6-axis 75 7055.59 33.06 68.85 95.90 6379.05 2408.23 180.98 2401.67 2408.48 55.69 0.42 MWD 6-axis 76 7151.42 33.03 88.67 95.70 6459.28 2460.27 182.07 2453.82 2460.57 55.76 0.13 MWD 6-axis 77 7247.95 32.90 8.5.67 95.70 6539.59 2512.21 183.25 2505.86 2512.55 85.82 0.10 MWD 6-axis 78 7343.14 32.87 68.24 95.00 6620.20 2564.23 184.66 2557.97 2564.62 85.87 0.28 MVVD 6-axis 79 7438.81 32.85 88.46 95.70 6700.59 2616.06 186.16 2609.87 2616.50 55.92 0.17 MWD 6-axis 80 7534.90 33.15 68.10 95.10 6781.19 2668.31 187.71 2662.19 2668.80 85.97 0.39 MWD 6-axis 81 7630.38 33.35 68.86 95.50 6861.05 2720.56 189.98 2714.53 2721.11 86.02 0.50 MWD 6-axis 82 7724.89 33.68 88.61 94.50 6939.85 2772.61 190.22 2756.68 2773.21 86.07 0.37 MWD 6-axis 83 7779.98 33.54 68.77 55.10 6985.72 2803.07 190.91 2797.21 2803.71 86.10 0.20 MWD 6-axis 84 7840.00 33.64 68.77 60.00 7035.67 2836.23 191.61 2830.44 2836.91 86.13 0.00 Extrapolated Page2 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11312 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/1/98 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Disk LIS Tape ~iNI #1 TEMPERATURE LOG W/PRESSURE 9 80606 1 1 GNI #2 TEMPERATURE/PRESSURE LOG 98 051 2 I 1 GNI #3 PRESSURE TEMPERATURE LOG 9 8060 6 I 1 D.S. 2-25 PRODUCTION PROFILE LOG 98051 I I 1 D.S. 3-22 PRODUCTION LOG 980531 I 1 D.S. 3-24A GR/CCL LOG 980529 I 1 D.S. 3-31 STATIC PRESSURE SURVEY 980514 1 1 D.S. 9-44 PRODUCTION PROFILE LOG 98051 1 I 1 D.S. 11-2 INJECTION PROFILE LOG 98051 3 I 1 D.S. 11-05A PRODUCTION PROFILE 980527 I 1 D.S. 11-6 PRODUCTION PROFILE 980522 I 1 D.S. 11-24A PRODUCTION LOG & GAS LIFT SURVEY 9 80 531 I 1 D.S. 12-33 b[I (-~ INJECTION PROFILE 980528 I 1 D.S. 14-36 ~ I ~ INJECTION PROFILE LOG 980604 I 1 O.S. 17-19A STATIC PRESSURE SURVEY 98051 4 I 1 D.S. 17-19A PRESSURE & TEMPERATURE SURVEY 980601 1 I S I G N E D :'~.~_ ~ ~ DATE: LJ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. jul ,. 6/15/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11255 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job if Log Description Date 131. RF Sepia Disk Tape p.s. 15-4~q 9820e ~r~ 97~2e I I 1 c~uz #1 ~:~~~ 980423 1 I , ~ ~ #2 b-"'Z'J~:~1:t~rl'~'I'Y_..%-'~ 980417 I 1 ~ ~3 ~ 980510 I 1 D.S. 2-23 ~I~~~ 980506 I 1 D.S. 6-16 ~~~W/P~ 980501 I 1 D.S. 7-33 ~I~~~ 980418 1 1 D.S. 11-16 ~1 ~~~~ 980426 I 1 D.S. 15-094 ~I~~~ 980509 I 1 D.S. 18-11 ~I~~~ 980501 1 I SIGNED: ~~ DATE: ~ .. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 23, 1998 Dan Stoltz Senior Drilling Engineer ARCO Alaska Inc. P O Box 196612 Anchorage, AK 99519-6612 Rc~ Pmdhoe Bav Unit GNI #3 ARCO Alaska. Inc. Permit No. 97-189 Sur Loc: 4390'NSL. 397'WEL, Sec. 26. TI IN. R15E. UM Btmholc Loc: 4649'NSL. 2779'WEL. Scc. 25. TI 1N. R15E. UM Dear Mr. Stoltz: Encloscd is the approvcd revised application for permit to drill thc above referenced well. The provisions of thc original approved permit datcd Octobcr 7. 1997. arc in cffcct for this · . DavidW. Johnston -- / ~ .... Chaim~an ---- BY ORDER OF THE COMMISSION dlf/Enclosurcs Dcpartmcnt of Fish & Game. Habitat Section W/o cncl Department of Environmental Conservation w/o cncl ..... STATE OF ALASKA ' __, ALA,-,,,A OIL AND GAS CONSERVATION ,.,OMMISSlON PERMIT TO DRILL 20 AAC 25.005 REVISED: 12/23/97 la. Type of work l~] Drill DRedrill Ilb. Typeofwell •Exploratory [--I Stratigraphic Test I--I Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 50.7' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028324 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4390' NSL, 397' WEL, SEC. 26, T11 N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 4605' NSL, 3275' WEL, SEC. 25, T11 N, R15E, UM GNI #3 At total depth 9. Approximate spud date Amount $200,000.00 4649' NSL, 2779' WEL, SEC. 25, T11N, R15E, UM 01/20/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028323, 631'I No Close Approach 2560 7897' MD / 7031' TVD 16. To be completed for deviated wells il 7. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 2000' Maximum Hole Angle 35.22° Maximum surface 2650 psig, At total depth ('rVD) 7000' / 3350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 16" 13-3/8' 72# L-80 BTC 4139' Surface Surface 4139' 3961' 2465 sx CS, 610 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 BTC-Mod 7897' Surface Surface 7897' 7031' 1580 sx Class 'G' i19. To be for Redrill, and completed Re-entry, Deepen Operations. Present well condition summary ORIGINAL Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate ~n°edructiOn R E C E IV E D BEC 24. 1997 Perforation depth: measured A~a$~(a 0il & 8as C0rls. C01firllJssiort true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Da~amura, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that thpore,~ng is/~u~ ar~ correct to the best of my knowledge % ,'z. ~.-~ I,~-'1 . Signed . I / ~ ..... ~/~__ //~ Dan Stoltz /[.~-~"~'~ ~ Title Senior Drilling Engineer Date // --3 Commission Use Only Permit Number APl Number Approval Date I See cover letter ¢ . ¢- --,,.. .---- - ~'__ for other requirements I Conditions of Approval: Samples Required []Yes [~ No Mud Log Required []Yes ,]~No Hydrogen Sulfide Measures []Yes J~'No Directional Survey Required []Yes [] No Required Working Pressure for BOPE []2M; J~,3M; []5M; •10M; []15M Other: Oi'iglFi8.! S~.qp,~:u o~, by order of /: Approved By FIRvid W, d0hgston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I GNI #3 (Surfcote Pad East) J Type of Well' Revised Injection Well Summary I lnject°r Surface Location· Target Location: BHL: 4390'FSL 397'FEL, S26 T11N R15E UM 4605' FSL 3275' FEL, S25 T11N R15E UM 4649' FSL 2779' FEL S25 T11N R15E UM I AFE Number: 14J0366 I Estimated Start Date: I MD: 17897' 11/20/98 Il'VD: Rig: Nabors 18E I Operating days to complete:118 17031' I KB E ev. 150.70' I Well Design: I Big Bore Injector Objective · Three new Class II Cretaceous disposal wells are planned in support of EOA Reserve Pit Close Out Grind and Inject operations. These wells will be located at the east end of the Surfcote Pad, between DS-4 and L-4. Long term reserve pit injection is expected to be re- quired by the NRDC lawsuit settlement; these wells will be used as long as possible for dis- posal of reserve pit and other Class II wastes. Disposal wells will be in highly erosive serv- ice, accepting mud and cuttings slurries. No chrome alloys are required and H2S fluids in- jection is unlikely. Dipole sonic and RFT are required in one well. Bond logs are required in each well. AFE justification is based on the NRDC Settlement Agreement. Formation Markers Formation Tops MD TVD Base Permafrost 1851' 1851' SV5 3533' 3461' SV3 4126' 3951' UG4 5546' 5111' UG1 6728' 6076' WS2 7340' 6576' CM3 7897' 7031' TD 7897' 7031' Casing/Tubing Program Hole Size Tubular Wt/Ft Grade T Conn - Length~ Top Btm O.D. MD/TVD MD/TVD 30" 20" 94# H-40 Weld 80' Surface 110'/110' 16" I 13-3/8" I 72# I L-80 I BTC ] 4139' I Surface I 4139'/3961' 12-1/4" I 9-5/8" I 47#I L-80 I BTC-MOD I 7897' I Surface I 7897'/7031' Pr°ducti°n Tubing I I I NA I 7" 29# L-80 BTC-MO D 4371' Surface 4371 '/4151' Open Hole Logs' 16" Hole: 12-1/4" Hole: Logging Program MWD Directional MWD Directional/GR; E-Line GR/SP/CalipedResistivity/Sonic/Density/Neutron Cased Hole Logs 16" Hole: GR/USIT 12-1/4" Hole: GR/USIT/CBT I KOP: 12000' IMaximum Hole Angle: Rig Move Close Approaches: Drilling Close Approaches: Directional 35.22° None None Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments Cold Set Lead to surface (350% excess through perma- 13-3/8" 2465/12.2/1.92 610/15.8/1.15 frost, 100% excess totop tail); Class G Tail (750' MD with 100% excess; Pump time=4+ hr.; TOC = Surface Class G Tail (50% excess to surface casing shoe); Pump 9-5/8" N/A 1580 / 15.8 / 1.14 time=4+ hr.; TOC = Surface Casing Shoe Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Mud Proqram Surface Section: Spud Mud I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss Initial 9.6 _ 300 35-50 25-45 50-80 9-10 15-20 Final 9.6 - 9.8 300 20-40 15-30 30-50 9-10 15-20 Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning. Intermediate Section: LSND I Density, ppg I FunnelVis, secI LSRYPI Gels I pHI 9.4 - 10.0 40 - 60 8 - 13 15-25 / 20-35 9 - 10 Hazards/Concerns I Potential high torque could require lubricant use. I Be alert for lost circulation, differential stickinq due to higher MW. HPHT FL, cc <10 Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre- venter will be installed and is capable of handling maximum potential surface pressures. Di- verter, BOPE and mud fluid system schematics on file with AOGCC. · Maximum anticipated BHP: 3350 psi @ 7000' TVDss (9.2 ppg EMW) · Maximum surface pressure: 2650 psi @ 7000' TVDss (based on BHP and a full column of gas from TD @ 0.10 psi/fi) F:~' ,j-~ ~.. .. 2 ~'~ ~.. C ,. ~ ~. Drillinc~ Riq Procedure 1. 10. 11. 12. 13. 14. 15. 16. Operations Summary Pre-rig: Set and cement 80' of 20" conductor. Install cellar ring. 2. MIRU Nabors 18E. NU and function test diverter. 3. Drill 16" hole to _+4139' MD (+_3961' TVD) per directional plan. Hold diverter drill while drilling surface hole. 4. Run and cement 13-3/8", 72 #/ft, L-80 casing to TD. Will cement 13-3/8" casing with two stage job (ES Cementer set at +_2051' MD - 200' MD below the Base of Permafrost). En- sure that cement reaches surface. 5. Test 13-3/8" casing to 3,000 psi for 30 minutes. Run GR/USIT (cement evaluation log) in 13-3/8" casing. Drill shoe joint and 20' of new formation. Perform and record LOT. 6. Drill 12-1/4" hole directionally to +_7897' MD (7031' TVD). 7. Log well with GR/SP/CalipedResist/Sonic/Density/Neutron. 8. Run and cement 9-5/8" casing to TD. TOC to 13-3/8" casing shoe. RU and establish in- jection down 9-5/8" x 13-3/8" annulus. 9. Test 9-5/8" casing to 4000 psi for 30 minutes. Log 9-5/8" with GR/USIT/CBT (cement evaluation log). Run 7" L-80 completion with packer at _+4371' MD. Have AOGCC representative witness annulus test. Freeze protect well, set packer. Set BPV, ND B©PE. NU and test tree. RDMO. Post rig: Perforate'9-5/8" casing. _ . i i i i i i ii ii ' ' GNI#3 (P7)Surfcote Easi-' i VERTICAL SECTION VIEW 400- -- - ...... Sec[ion at: 84.87 TVD Scale.' ~ inch = 800 feet 800 ,, Dep Scale.' I ~nch : 800 feet Drawn · 22 Dec ~.997 ~oo ........... i.. Anadr~ ]] Sch]umberger, :~600 ,, Marker Identification MO BKB SECTN INCLN~: A) KB 0 0 0 O. O0 B) KOP BUILD 2/tOD 2000 2000 0 0.00', DA~'~mqAi'~f'~¢~ C) END 2/I00 CURVE 3761 36§2 524 35.221 2.000 B ) ...... O) 13-3/8' CSG PT 4~39 3961 742 35.22i E) TARGET t**~~ 7034 6386 24~2 35,,?.2i F! ?O 9-5/8' CSG PT<II > 7897 703~ 8gog 35.221 2400 L ....... i.. ............. ~800 .... ~ ~" N~)RILL AK,~,-DPC i AppR( VF, D I 3§00' !_ Obi ,,-/,j_...., j. , . .......... : ...... -:'::'. .......................... , I ":"i 4000 -~- -~a~r ........... .. 's~' '~ t'4~' ...................... i I 4400 - ........ '~,- ',~r,, I 4800 'i ..... ,, I J 5~oo_-¢,r-~r~ ..... ~ ._. , ...... . ,, _ ~' 5600 ...... i 6000 ........... 'l~'t' '~i~' ..... ] ...................... " - \ - -~T~- -¢'~¢ --k-- ............ 68~0 -.;~- -~?:~P .... ' ........ ~ "- -. ""~ .... ~- "/~1 ~j~ - ' 7200 ...... F , 0 400 800 1200 ].800 2800 8.400 2800 3200 3600 4000 4400 4800 Section Oe.panture . i ii i . iiiiiii /nadrJ ] ] Schlumberger i i i il .. l, II IIII i iii i i · mil 3NI#3 (P7) SuPfcote East PLAN VIEW i i i . i ii ii_ iii i ii ii · i i i i i i . SERVZ'bES D ZEL'iNG i i i i .. i i ii ! ii ._. i ]LOSURE ' 2909 feet at Azimuth 84 B7 ....... i ..................................... -~-~- r~.~,.A-D~',C ~ ]ECLZNAT[ON.' +28.503 (E) ..... ]RAWN ' 22 Dec ~997 ............ ¢ ~LAI .... =:_., f3-3/B' 696 Pl 4139 66 N 739 E ........ :) TA~GE~ ~~ 7034 216 N 2402 E ') ~D 9-5/8" CS~ PT<I [ > 7897 260 N 289B E Target (fladius 2(~ feet ) .... · · ~ r ~ · ............. _.. ...... . , . ~ , , ~ ..... , ..... -- . I ......................... ~ ..................... .x :...': ..... .~:m .............. U.i ._~-~ ........ :::;: ~: ~ L:'.: q ~'~: u.~... GUU 3 ~'~ i ~¥ i qrG ~ o~ i ~- ~G¢'G ........ c~uu couu [~0 500~ a~U 3460 <- ~¢EST · EAST -> i iii . i iii . i iii i _ _ i i i .... ii i i i . . adnf]] (cl97 ~[3P/ ~,Eb.5 BOO ~'P] ~> Z z~ ~0 ( m A~adrill Schlumberger Alaska District 111[ East 80th Avenue Anchorage, AK 99518 490V) 349-4511 Fax 344-2160 DIRECTIONAL ~ELL PLAN for SHARED SERVICES DRILLING Well ......... : (INI93 (PT} Surfcote East Field ........ : Prudhoe Bay, Surfcote-Pad Ccalputatlon..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.28350970 N Surface Long.: 148.23904777 W AegaI Description Surface ...... : 4389 FSL 397 FEL S26 TLLR R15E U~ Target ....... : 4605 FSL 3275 FEL S25 TIL~ R15E UM LOCATIONS - ~KA X-Coord 717580.24 719975.00 720469.~8 4 Y-Coord ~906399.78 5956685.08 5956743.$6 PRO~OSE~ WELL STATION MEASURED INCL~ DIRECTION IDEI~T~FICATIDN DEPTH AI~LE AZII~t3TH [<38 O . 0 0 0 . O0 0 . O0 BASE PERMA~R0ST 1850.?0 0.00 k"gP BUII~D 2/100 2000.00 0,00 0.00 2100.00 2.00 2200.00 4.00 84.87 VERTICAL- DEPTHS TVD SU~-SEA 0.00 -50.70 1850.70 1800 .OD 2000.00 ~969 .~0 2099.98 204~.28 2~99.84 Prepar~ ..... : 22 Dec ~997 Vert sect az.: 84.87 KB elevation.: 50.70 ft Ma~oet£c Dcln: +28.503 (E) Scale Factor.: 0.99995378 Convergence..: +1.65~77328 ANADRILL APPROVED FOR PERMITTING AKA~DPC ALASKA Zone 4 TOOL X ~ FACE 100 717580.24 5956399.78 BS 0.OO 717580.24 5956399.~8 KS 0.00 717H80,24 5956399.~8 8SR 0.00 717581.97 59~6399.~9 ~5~ 717587.17 5956~00.61 85R 2.00 r-.:. m.m:mm m m: -~...n DEPART I~HLLkIKAD m~:~: =mm.m m:x:----- ---- ~-~ mm mmm :m m mm mmm: m,:: ~.?. _-- ::~ mm~ 0.00 o.oa N 0.00 O.00 0·0O N 0.00 O.00 0.O0 N 0.00 1.75 0.~6 N 1.74 6.98 0.62 N 6.95 2300.00 6.00 84.87 2400.00 8.00 84.67 2500-00 10.00 84.87 2600.00 12.00 84.87 2700.00 14.00 8~.87 2299.45 2248.75 2398.70 2348.00 2497.47 2446.77 2595.62 254~.92 2693.06 2642.36 2800.00 16.00 2900.00 1B.O0 84.87 2789.64 2738.94 84.87 2885.27 2834.57 15.69 27.88 43.52 62.60 85.10 1.40 N 15.63 E 717595·82 5956401.6~ HE 2.00 2.&9 N 27.77 E 717607.92 5956403.08 ~{S 2.00 3.89 N 43.35 E 717613.46 5956404.93 F~S 2.00 5.60 N 62.35 E 7L7642.40 5956407.18 HS 2.00 7.62 N 84.76 E 717664.7~ 5956409.8~ RS 2.00 110.~8 9.93 N LL0.53 H 717690.43 5956412.90 HS 2.00 140.21 12.$5 ~ 139.65 E 717719.t6 5956416.36 HS 2-00 · u'-) G~I~3 (P7) ~urfcote East S~ATIO~ I DENT [ FI CATION EA!D 2/100 CURVE SV3 13-3/8' CSG PT SV2 UG~A UG1 TA/~GE"J~ WS2 WS1 CM3 ~ 9-s/a. cso ~<11, ~fEASURED DEPTH 3000. O0 3100,00 3200,0'0 3300.00 3400.00 3500.00 3532.79 3600.00 3961,01 4L26.42 4138.66 4358.99 %873.11 5546.35 6727.58 ?033.60 7~39.62 7596,68 7896.58 7896.58 INCLN ANGLE 20,00 22,00 2~.00 26.00 28.~0 PROPOSED WELL PROFILE DIRECTrON VERTICAL-DEPT~Lg ASIMUTH TVD 8~ .$? 2979.82 2929,12 8~,87 3073.17 3022,47 8~ ,67 3165.21 313~ .51 8~,87 3255.8~ 3205,14 8~.87 3344.9~ 329(.24 SECT/ON DE PART 172.77 208.60 247.67 289.93 335.33 22 DeC 1997 Page 2 C00RD~I~IATSS-FROM ALASKA Zone 4 WELLHFJ~D X ¥ 15,46 N 172.07 ~ 717751,79 5956420,21 18.67 N 20~.77 E ?17787,37 595642~,45 22.16 N ~46.68 ~ 717826.16 595642~.07 25,95 N 28~.7~ E 717868,13 595643{.07 38.01 N 333.99 E 717913,20 5956459.44 30.00 84.87 3432.39 3381.69 383.81 34.35 30.66 84.87 3460.70 3410.00 400.37 35.83 32.00 84.87 3518.11 3467.41 435.31 38.96 3~.00 84.87 3601,97 3551.27 489,77 43.8~ 35.22 84.87 3652.18 3601.48 52~,42 46.93 35.22 35.22 35.22 35.22 35-22 8{,$? 3950.90 3900,00 735.16 8{.87 3960~70 3910,00 742.22 8~.87 ~140.70 4090.00 869.2~ 84.87 ~560.70 45Z0.00 1165.79 84.87 5110.70 5060.00 1554.07 84.87 6075.70 6025-00 2235.31 84.87 6325.70 6275.00 2411,80 84.87 6575.70 6525.00 2588,25 84.87 67S5.70 6?35.00 2736.53 84.87 7030.70 6980,00 2909.49 8~.87 7030.70 6980.00 2909.49 35.22 35,22 35,22 35.22 35.22 35.22 (Anadrill (c) 97 GN/3P7 3,2b.5 5:53 PM P) 'i~L DL/ FACE 100 I-[,S 2.0O ~ 2 .DO HS 2.00 ItS 2.00 ~ 2.00 382.2? E 717961.34 5956445.17 HS 2.00 398.76 E 717977.78 5956447.13 85 2.00 433.56 E 718012.48 5956~5~.26 ~S 2.00 487.81 E 718066.55 $956457.70 B~ 2-00 522.32 H 718100.96 ~956461.~0 H~ 2.00 65.79 N 732.21 E 66.42 N 739.2~ E 77.79 N 865.B~ B 104.33 N 1161.[~ E 139.07 N 15&7.83 E g~8310,21 5956486,72 ~9 0-00 7X8317,22 59~6487.$6 I{S 0.00 7184~3.39 5956502.58 HS 0.00 718737.80 5956537.65 }tS O.O0 719X23.33 5956583.56 HS 0.00 200.0~ N 2226,34 215.83 N 2402.12 231.62 N 2577.~0 264.~9 N 2725.55 260.37 N 2597.82 719799.?6 5956664.13 B$ 0.O0 719975.0~ 5956685.00 KS 0.00 720150.24 5956705.~? AS 0.00 ?20297.44 5956723.40 H8 0.00 720%69,~8 5956?43.86 0.OO 260.37 N 2897.82 E 720469.18 5956743.86 0.00 ANADRILL AKA-DPC APPROVED FOR Pt RMiTTI NG ONLY ,.-.--_'~_:, :..;::.:.'_ .'~::,-=t:~.'--.,.L...~_= ..~ --.~¢.=.~-.~-., ....... _~..~ TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 (907) 276-7542 October 7. 1997 Tim A Burns Senior Drilling Engineer. Acting BP Exploration I Alaska). Inc. POBox 196612 Anchorage. AK 99519-6612 Re: Prudhoe Bav Unit G & I #3 BP Exploration (Alaska). Inc. Permit No. 97-189 Sur. Loc. 4390'NSL. 398'WEL. Sec. 26. T! IN. R1 SE. UM ' 'N 29 ' " Btmnhole Loc. 46~4 ~'SL. 51 WEL. Sec. _5. TI 1N. R15E. L'M Dear Mr. Bums: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A step-rate test and temperature baseline log is required prior to disposal. _5.0~5 The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC '~ ' · and the mechanical integriu, {MI) of the injection wells must be demonstrated under 20 AAC ~5 412 and 20 ~- ' ' · ->.0-~0(g)O). Sufficient notice (approximately 24 hours) of the MI test belbre operation, and of the BOPE test pertbrmed before drilling below the surface casing shoe. must be given so that a representative of the Commission max.' witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF COMMISSION dlf/Enclosures Department ofFish & Game. Habitat Section xv/o encl. , Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork C~Drill [-IRedrill Ilb. Typeofwell [-I Exploratory DStratigraphicTest DDevelopment Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 54.4' Prudhoe Bay Field/,prudhRe 3. Address 6. Property Designation Bay Pool - P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028324 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4390' NSL, 398' WEL, SEC. 26, TllN, R15E, UM (As Staked) Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 4605' NSL, 3275' WEL, SEC. 25, TI 1N, R15E, UM G &l #3 At total depth 9. Approximate spud date Amount $200,000.00 4634' NSL, 2951' WEE, SEC. 25, T11 N, R15E, UM 10/10/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028323, 646'I No Close Approach 2560 7820' MD / 7000' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 2o AAC 25.035 (e) (2)} Kick Off Depth 2000' Maximum Hole Angle s3° Maximum surface 3300 psig, At total depth ('rVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 16" 13-3/8' 72# L-80 BTC 4079' 29' 29' 4108' 3890' 2915 sx CS, 610 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 BTC-Mod 7792' 28' 28' 7820' 7000' 1360 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Liner :~-:~ ~-" ,~ '~ ~! ?;./7 ii'" :!% Perforation depth: measured ,_' :_ t ,,/'/ true vertical ~i~.~;!~)---~ ""i~ ~' ' .... : L;;Ji¥--.;; ~,,JA .,"b z..~..,,.' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] u~verter-,~Ketcn ~ Drilling Program [] Drilling Fluid Program .E]~ime vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements OontactEngineerName/Number: Win~nAube¢,.,6..~-,¢25" ' PreparedByName/Number: ,errieHubble, 564-4628 21. I hereby certify that_the~regoin~is,/t~ and correct to the best of my knowledge Signed--*"''~- -- --~, "/.~ ,,/J TimA. Burns ~NJ'~'v' ~'~%,~1~¢f/'- Title SeniorDrillin~En~ineer, Actin~l Date Commission Use Only Permit Number APl Number I Approva,'Date ] See coverletter o ,oro,,orr s Conditions of Approval: Samples Required [] Yes [] No Mud Log Req [] Yes .~ No Hydrogen Sulfide Measures []Yes ]~lNo Directional Survey Required ~Yes [] No Other: oavid W. ,,J0~lris'~0rl by order of ^,,roveO,¥ Comm,ss,on r t, co m,ssion Form 10-401 Rev. 12-01-85 Submi ~ dicate I wen Name: I G&I #3 Injection Well Summary I Type of Well: I lnject°r I Surface Location: 4390' FSL, 398' FEL, S26, T1 IN, R15E, UM Target Location: BHL: 4605' FSL, 3275' FEL, S25, T1 IN, R15E, UM 4634' FSL, 2951' FEL, S25, TllN, R15E, UM I AFE Number: 1 4J0366.0 I Estimated Start Date: [ 10/10/97 IUD: 17820' I Rig: [Nabors 2ES Operating days to complete: I 18 TVD: 17000' ss I I KB Elev. I 54.4' ]Well Design: [Big Bore Injector Objective: Three new Class II Cretaceous disposal wells are planned in support of EOA Reserve Pit Close Out Grind and Inject operations. These wells will be located at the east end of the Surfcote Pad, between DS-4 and L-4. Long term reserve pit injection is expected to be re- quired by the NRDC lawsuit settlement; these wells will be used as long as possible for dis- posal of reserve pit and other Class II wastes. Disposal wells will be in highly erosive serv- ice, accepting mud and cuttings slurries. No chrome alloys are required and H2S fluids in- jection is unlikely. Dipole sonic and RFT are required in one well. Bond logs are required in each well. AFE justification is based on the NRDC Settlement A[Ireement. Formation Markers Formation Tops SV5 SV3 SV2 UG1 CM3 MD Pilot 3298' 4O96' 4347' 6626' 7820' TVD (ss) 3200' 3880' 4090' 6000' 7000' Casing/Tubing Program Hole Size Tubular Wt/Ft Grade Conn Length Top Btm O.D. MD/TVD MDfrVD 30" 20" 944t H-40 Weld 80' 30'/30' 110'/110' 16" I 13'3/8" 172#1 L-80 I BTC I 4079' I 29'/29' 14108'/3890' 12-1/4" I 9-5/8" I 47# I L-80 I BTC-MOD I 7792' I 28'/28' I 7820'/7000' Production Tubing ] I NA I 7" 29# L-80 BTC-MOD 4214' 26'/26' 4240'/4000' Logging Program Open Hole Logs: 16" Hole MWD Dir/GR 12-1/4" Hole MWD Dir/GR; GR/SP/Cal/Res/Den/Neutron; RFT Cased Hole Logs: 16" Hole GR, CBL 12-1/4" Hole GR, CBL ]KOP: ]2000' MD Maximum Hole Angle: Rig Move Close Approaches: Drilling Close Approaches: Directional 33° None None Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments Cold Set Lead to surface (400% excess through perma- 13-3/8" 2915 / 12.2 / 1.92 610 / 15.8 / 1.15 frost, 100% excess to TD); Class G Tail; Pump time=4+ hr.; TOC - Surface CI G; Tail FW=0; 9-5/8" N/A 1360 / 15.8 / 1.14 30% excess; Pump time-4+ hr.; TOC - -+4108' MD (surface cs9 shoe) Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Mud Program Surface (12-1/4" hole) Section: Spud Mud I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 9.6 _+ 300 35-50 25-45 50-80 9-10 15-20 Final 9.8 300 20-40 15-30 30-50 9-10 15-20 Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning. Intermediate (8-1/2" hole) Section: LSND I Density, ppg [ FunnelVis, sec I LSRYP[ Gels [ pH] 10.0 - 10.2 40 - 60 8 - 13 15-25 / 20-35 9 - 10 Hazards/Concerns Potential high torque could require lubricant use. Be alert for lost circulation, differential sticking due to higher MW. HPHT FL, cc <10 Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre- venter will be installed and is capable of handling maximum potential surface pressures. Di- verter, BOPE and mud fluid system schematics on file with AOGCC. Operations Summary Drilling Rig Procedure 1. Pre-rig: Set and cement 80' of 20" conductor. Install cellar ring. 2. MIRU Nabors 2ES. NU and function test diverter. , , Drill 16" hole to +4108' MD (+3890' TVD) per directional plan. drilling surface hole. , , , , , 10. 11. 12. 13. 14. 15. 16. 17. Hold diverter drill while Run and cement 13-3/8", 72 Cf/fi, L-80 casing to TD. Ensure that cement reaches sur- face. Test 13-3/8" casing to 3,000 psi for 30 minutes. Drill shoe joint and 20' of new formation. Perform and record LOT. Repeat LOT two additional times (three LOTs total). Drill 12-1/4" hole directionally to _+7820' MD (7000' TVD). Log well with GR/SP/Cal/Res/Den/Neutron. Run RFT. Run USIT (cement evaluation log) in 13-3/8" casing. Run and cement 9-5/8" casing to TD. TOC @ 13-3/8" casing shoe. RU and establish injection down 9-5/8" x 13-3/8" annulus. Test 9-5/8" casing to 4000 psi for 30 minutes. Log 9-5/8" with CBL. Run 7" L-80 completion with packer @ _+4240' MD. Have AOGCC representative wit- ness annulus test. Freeze protect well, set packer. Set BPV, ND BOPE. NU and test tree. RDMO. Post rig: perforate 9-5/8" casing. Anadr£11SchZumberger' .LLt! East 80th Avenue . Anchorage,. AK 99518 (907) 3{9-45LL: Eax 344'4160 . , D'£PJCTIONAL Will./. P~AN ~or ERA.I~D SSRV:C~$ DRiLL~N~ ,. 4 X;Coord.. 'y,O°ord gL7580,00 S956400.00 ~£99.75.00 59~6685.00.. .~20298.31 ~956723.47. IX)CATIONS - ALASKA Zone: Legal'Descrip':lon SLucface ...... : 4390 PSL 398 ~h S26.711N RL5E UM' T~LrcJet ....... : 4605 PSL 329~ FHL S25 711N RI~E tim BHL .......... : 4634 ~SL'7951 ~HL S25 T'11N RI~E UM' INCLN 0,Q0 0.00 o.0o 2..00 4.00 .......... ., 2300.00 6.00 2400.00 8.00 ~ .i. ~, 2500 O0 LO,O0 2600.00 £2.00 L4.00 2800.00 L6 .O0 A:~ri4TJTH m ~ m,.m~ m 0.00 0,00 0.00 84.87' 84.87 84.87 84.87 84.87 84.87 84.87 84.87 84.87 V~RT]CA~-DEPTHS 0.00 -54.40 1939.40 1885.00 2000.00 1945.60 2099.98 2045.'58 2399.84 2145,44 Prepared'. ..... : '03 Jul 1997 , . Vert sect az.: 84.87 m mll~ m mm malmm ~-/m Imm m Inll{ { ~ t~ll I ! m STAT ION M~ED Z~l P3 ~TI 0~ D~ 0,00 . Ko~ / BUILD 2/100 2000.00 2100.00 '=:;; 2200.00 ..... , .~. ... KB elevation,: 54..40 :t Magnetic OCLn~ +28.587 (E) ScaLe ~ac. tor.~ 0.9999~3~8 ' J ANADRILL ' - A:<;.k., '.. IFEAs'I B, ILI'FY' PLAN "J N'O'T AppRovED FOR ['' EXE£UTION , ... · COORD £IfATHS- FROM ALASKA ~one 4 ' 0.00 N 0.00 ~ 917580,00 S956400.00 0.00 0.00 N Q.00 R 717580,00 5956400.00 0.00 1.75 0.00 N 0.00 ~ ,717580.00 5956400.00 0.16 N 1.94 H 71758L,73 5956400.21 6.98 0.62 N 6,95 B 717586.93 5956400.82 22'99.45 2245.05 15.69 L,40 N 15,62 2398.70 2344.30 27.88 2.49 N 27.77 2497.47 2443.07 43.52 3.89 N 43,35 2595.62 2541.22 62.60 5,60 N 62.35 26~3.06 2638.66 85.L0 7.61 ~ 84.76 2789,64 2735.24 288S.27 2830.87 717595.58 595640L.65 717607.68 5956~03,29 717623.22 5956405,14 717642.16 5956407,~0 717664.50 59564~0.06 110.98 140.2L 9.92 N 110.53 E 7L7690.19 5956413.31 12.53 ~ L39.65 E 7L7719,22 59564~6.67 emmm milmm FAC~ LO0 mmmm mmmm BS 0.00 H$ 0.00 B~R 0.00 BSR 2.00 BS~ 2.00 HS 2.00 HS 2.0O H$ 2.00 lis 2.00 lis 2.00 ES 2.00 HS 2.00 "U I> C' I-- "U 0 (Anadrill (c)97 GI3P03 3.0C 11:03 AH P) wmm~lll~mm~m'mmmm~mNmmm ~?IO~ ' ImUTX~rCATXO~ SVS e~ 2/,o° Buxu~ SV3 DI~PTH 3000.00 .. .. 3.~. oo. oo' 3200. O0 3298,'40 3300,00 20.00 ..22,.00 24.00 25.9?.. 26,00 3400.00 28,00 3~oo.oo '~o.oo ~6oo,o0 3653.65 33,07 4096.~6 33.07 4108.39 6626.37 7223 .O4 : 7819.72 ' 3'3,07 33.07, 33.07 33'.09' 33.09 01'd'uL 1997 Page 2 AZIMUT~ 84.87 ,84 84.87 84.89 . 1"VD S~B-SEA DEPART 2979.82 2925,42 172,77 3073.17 3018.?? 208,60, 3165.21 3~10.81 24~,6~ 3284.~o ~=oo.oo 28~.~3 , ,, COOP. DX'NATES-FROM WHLL~{EAD ~e.~s ~ 207.77 22'.L4 ~' 246~68 25,85 N 25,92 N ALASKA Zone 4 717751.55 5956420,4l HS 717787.13 5956424.65 RS 717825,93 5956429.~6 HS 288,07 H 7X~867,19 5956434.~8 HS '288,77 H 737867.89 ~986434.26 89 mm{sm TOOL FACH 100 2.00 2.00 2.00 2.00 2.00 84.87. 84.89 84.a~ 84.87 84.87 84.87 184'.8? , . 84'.8'7 84.87 84.87 3344.94 3432.39 35~9.11 3563.34 3934.40 3'290.54 33'77.99 3463.71 3~08.94 3880.00 3'944.40 3890.00 6os~.4o 6000.00 688~.4o e~Oo.°o 7064,40' 7000.00 7054.40 '7000.00' ,335.33 383.81 464,16 705.8i 29.97 38.91 41.49 63.09 333.99 g 717912,97 5956439.62 382.27 E 71796L,10 595644S.35 433.57 E 7180L2.24 595649L.44 462.31 E ?[8040.89 59~6&54.85 702.98 B ?£8280.83'5956485.40 'V12,32 63.67 N '~09.47 H '718287.30 5956484.~7 ,. 2086.~0 ' 186.50,N 2oTe.os,~ .?~965~,69 59566¢6.53 , , 2412,0£ 215.60 N 2402,35, H 919975.00 S956685.00 , 2737.62 .' '244.71 N. 2726.66 H 720298.31 $956723.47 2737.62 244.71 ~ 2726,66 ~ '720298.31 $956723,4'7 HS 2,00 H8 2.00 ES 2.00 HS 2.00 RS 0,00 HS 0, oo RS 0 .o0 HS O. O0 0.00 0.00 ., . ANADRILL ' AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION · LAN .-,,. (Anadrtll (c) 97 GriP03 3.0C ~2~03 AM P) 07/01/i987 11:27 .907-344- ~g AN~DRILL DPC PAGE 84 · · I .....Si-IARED SERVZCES DRILLZNG '-i , , ,-- Plan 03 VERT]:OAL SECTION V]:E~I 4oo-- Section at: 84.87 fVO Scale ' 1 inch = 800 feet 800 ...... Oep Scale.' ! inch : 800 feet Drawn ..... ' 0~. Jul 1997 1200 /nadrJ ]] Schlumberger' · Harker Identification HD BKB SECTN INCLN $600~ ' A] KB 0 0 '0 '0.00 B] KOP / BUILD 2/~.00 2000 2000 0 0.00 'C] END ~/~.00 BUILD 3654 3563 464 33.07 2000-- ~B '~~'~T't~ D] :13-3/8" CASING PT 4108 3944 7i2 33.07 E) TARGET ~,~,~N~,~ 7223 6554 2412 33.07 T Fi TI)-/ 9-5/8' CSNG .PT 7820 7054 2738 33,07 V 2400 '. ..... ~D ~ -, ~800- . .. · . AN/:,DRILL AKA-[ }PC ~oo. _ - .. ..,. - · FrFAS BILlFY FLAN ' ' "~' ........ "~"~ N~3T ),PPROVE!) FOP, · ~oo----, ~'.._~."" ' - PL/,N - . 4000 "s~']' "~4-~ ! ...... ~ ......... ,,, ' ........ \ X · 118o0 '' X ' - ' " '' - ~ ..!X '' .. . _ . · : ~00 I. ' , ' · : . . · · . . ~ooo '~,i"'~ - '~ ~ ........... 6400 .......... 6800- ' '0~3- '~ ...... 7200. F, 0 400 BOO ~200 :~600 2000 2~00 2800 3200 3600 4000 4400 4800 5200 · .._ S,e¢~on Departure .. Illin I III i i~lm [ ~ _l Anadr ~ ] ] $ch ]u~be~ger ! i GgI#x Plan 03, PLAN VIEN, CLOSURE · 2738 feet', at Azirnuth 64,'87 DECLINATION.' +28.587 (E). SCALE. ' 1 inch : 400 feet,' : DRA~N ' O1 Jul J997 '" iI i ii i iiiiii i "'SHARE'D' SERVI'd'E. S '2000 3654 .4108 7223 7820 i iii i i i N/S E/W ON OE ON OE 4) N 462 E 64 N 709 E 216 N 2402 E 245 N 2727 E DRTLLI'NG m __ i ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR 'EXECUTION ~'LAN ¢¢ ~ lar§eL.~(~ :adius 2( O I~eel~ ) · 200 0 ;~00 400 '600 BO0 ' lO00 t200 1400 1600 lBO0 2000 2200 2400 2~00 2800 3000 3200 3400 <- ~Sf' EAST-> IAnadr)l] lc)97 GIIP03 3.0C ti: 08 ~N PI · PAGE Alaska Dis[ric~ Directional Well Planning Depac[ment ANADRILL AKA-DPC FEASIBILITY PL~N NOT APPROVED FOR EXECUTION PLAN .~ _~ 900~ 10~ ~0~ 6000 04-~A L4--16 -4oo -2oo o 200 ~o 6~ 8oo ~ ooo ~ ~oo ~ 4oo ~ 6oo ~ 8oo 2000 NORMAL PLANE SEPARATION (1~ = 400 h) I 1 I I Eas[ 80th Avenue - Anchorage, Ala3ka 99518 · Telephone: {907~ 349~4~ 1 I - FAX_- PAGE ~1['"~ ~] ~H ~ ] 'r~ j4 Iq J Anadrill Alaska District Oir~tional Well Planning Department NORMAL PLANE TRAVELLING CYLINDER RESULTS WITHOUT ELLIPSES OF UNCERTAINTY Oien~ ............. : ARCO A~SKA INC Planned Well Su~ay Program De~ Cal~ula~d ..... : 07/01/97 11:05 Wee Name ....... : G&I-J (PO3) S=en ~ Ty~ In~el Date ~o=d .......... : 07101/97 11:10 Reid ................ : PRUDHOE BAY 0 7820 MEWD 93 KBE ..................... : ~.~ ~,~ I Sta~.,: BEECHEY POINT, A~SKA GHd X .................. : 717580,00 API~ ................ : 50-029-97053-00 ~drili ID~ ...... : 500299705300P0303 Grid Y ..... : ............ : 5956~0,00 Grid Zone ............. : ASP ZONE 04 MIN. FLOWING PLUGGED ENTER ENTER EXIT EXIT CLOSE OFFaE'r WELL FLOWING ELLIPSE SURVEY 8APE'FY SAFETY PLUG NO DRILl. NO DRILL PLUG APPROACH SAFE-fY 8EP, SEP. MD TVD DI~T. Dl.,%*'r. ZONE ZONE ZONE ZONE STATUS SEP. MD MO MD MD . 'G&[ ~2(P02). 26e.7 298.1 2S1~.1 2091 2081 31,4 5.~ FLOW G&I ~3{P02) 564,5 S94.8 594,8 2021 '2021 ' 30.3 6.1 FLOW 04-3~, 121 ?.7 1267,7 1267,7 7798 7038 50.0 19.5 FLOW 04,-34A 1222.0 1272.0 127;2,0 7810 7046 50.0 ' 19.5 . FLOW L4-15 1916.5 ' 1966.5 1966,5 7256 8582 50,0 18,1 FLOW 04-~3 2127.1 2177.1 2177.1 8923 S465 -. 50.0 14.8~ FLOW LZl-31 1921..3 1971.3 1971.3 7812 7048 50.0 19.5 FLOW 04-27 1954.7 200z~.7 200~,7 7800 .- 70;38 50.0 19.5 FLOW 0zl~6 2498,8 264~.8 2548.8 7810 7046 50.0 19.5 FLOW 04-36 . :3991.2 404~.1. 40~,1.1 - 3330 - 3282, ~9:9 8.3 FLOW 04-26 3984.8 4034.B 4034, B 6739 5311 50.0 14.:3 FLOW L4-36 I- 35eSl .~- 3611.6 3611.8 75;77 6851 50.0 18.9 FLOW L~-32 3680.4 37~30,4 3730.4 781 I 7047 50.0 04-26 409:2,0 41~2.0 z~142-0 6770 6180 !50-0I 10,9 I FI. OW -. ' FLOW . ANAl)RiLL AK~-DpC F :AS I ? L lTh' PL ,N NC T PR.© IED F:OFL EX[iCUTION · ~ .'-- ___ ~_~ _..- ___ -. . . [. . . · . i' . - I : .. . .. , · . · · . : . All deptha aJ'e referenced from well G&I #1(P03) Ig y 1111 East GOth Avenue o Anchorage, Alike 99518 - Telephone: (907) 3~9-¢511 o FAX: (907) 34~-2160 I. GNI TREE: FMC WELLHEAD: FMC Bi.q BoreProposed Completion Design ......~v= ~0.~, 20", 94#, H-40 @ 110' MD 7" L-80 Tubing 13-3/8", 72#, L-80 a k @ 4139' MD I I 7"x 9-5/8" Packer I 'XN' nipple, WLEG Cretaceous G&I Perforations 9-5/8", 47 #, L-80 @ 7897' MD DATE REVISED BY COMMENTS PRUDHOE BAY UNIT WELL: GNI #3 12/24/97 D. Nakamura Grind and Inject #3 , APl NO 50-029-22820 i SEC 26; TllN; R15E i BP Exploration (Alaska) DATE REVISED BY COMMENTS PRUDHOE BAY UNIT WELL: GNI #3 12/24/97 D. Nakamura Grind and Inject #3 APl NO 50-029-22820 SEC 26; T11N; R15E BP Exploration (Alaska) · WELL PERMIT CHECKLIST COMPANY /,'-d%. o. _WELLNAME_/'~'~/'~ B _~ PROGRAM:exprqdevL-]redrlll-lserv~wellboreseg['ann. disposalparareq[i FIELD & POOL .... ~_~'~_O_~ .3 _{_O INIT CLASS .Z0,/'.~,~,:~ / GEOL AREA ~" 74:~ UNITfl ///,~ ,_~'"~d2 ON/OFF SHORE __.~ ............. ADMINISTRATION 1 1 1 '1 APPR D~T'E. ENGINEERING 1. Permit fee attached ....................... ' N 2. Lease number appropriate ................... ' N 3. Unique well name and number .................. ' N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unil boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included .............. , N 9. Operator only affected party ................. N 0. Operator has appropriate bond in force ............ N 1. Permit can be issued without conservation order ........ N 2. Permit can be issued without administrative approval ...... N 3. Can permit be approved before 15-day wait .......... N REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22 23. 24, 25, 26, 27, 28. 29. Conductor string provided .................. (~) N Surface casing protects all known USDWs ........... ~, N CMT vol adequate to circulate on conductor & sud csg ..... (:) N CMT vol adequate to tie-in long string to surf csg ........ ! ) N CMT will cover all known productive horizons .......... ( ) N Casing designs adequate for C, T, B & permafrost ...... (~ ~)N Adequate tankage or reserve pit ................ ~)N I1 a re-dlill, has a 10-403 for abandonmenl been approved... Y N ~ Adequate wellbore separation proposed ........ ~ N ................................................................................................................................................................... If diverter required, does it meet regulations ........ (~ N ~ / Drilling fluid program schematic & equip list adequate .... N BOPEs, do they meet regulation ...... BOPE press rating appropriate; test to ~¢8,,,,~' ' ' Ps;~g . Choke manifold complies w/APl RP-53 (May 84) ........ (~ Work will occur without operation shutdown .......... Is presence of H:,S gas probable ............... __ GEOLOGY ............................................................... ~ 30. Permit can be issued w/o hydrogen sulfide measures . Y/~/' 31. Data presented on potential overpressure zones ..... //t" N//D/' , z//-J , 32. Seismic analysis of shallow gas zones ........... ~ Y N 33. Seabed condition survey (if off-shore) ........... /,,,d Y N AI~R D~TE 34 Contact name/phone for weeklyprogress reports . . . ./4r . . Y N ~,/,¢"c."~~ ~, ~/,,/~',~ [exploratory only] ENGINEERING JDH~ COMMISSION. DWJ ~ RNC CO Cc, '/~ z.. Comments/Instructions' H 12 5'9 7 0 ........ os/o4/~ oo~=~'~oI VENDOR AL/~SK~ST i 4 00 DATE )NVOICE / CREDKF UEMO DEDCRIPT(ON GRO$8 DISOOUNT NET 07.3-' i 97 CF, O73 ~ ?7 t i 00. O0 _i OO. OO ,H~-NDt,,. _,_~N¢-:.~ INST: s/h. te~'T'i~_ bubble x 4628 ITEMS DE~RIBED ABOVE, ~ ~_ OO OO i OO OO THE A~ACHED CHECK IS IN PAYME~ FOR FIELD & POOL ADMI'N'I'STRATION WELL PERMIT CHECKLIST COMPANY WELL NAME ~ ~ ~..~ N Y'N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N _ ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... / 10. Operator has appropriate bond in force ............ 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~Y~ N 17. CMT vol adequate to tie-in long string to surf csg ........ Y(~ 18. CMT will cover all known productive horizons .......... (~)N 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. (~) N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation ................ (~N 26. BOPE press rating appropriate; test to ,_.._~--<~ psig. 27. Choke manifold complies w/APl RP-53' (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. PROGRAM: exp [] dev [] redrll [] serv"~wellbore seg El ann. disposal ~q [] ~ UNIT# //-~,~'"" ON/OFF SHORE REMARKS GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ........ 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ........... ./. Y N 34. Contact name/phone for weekly,progress reports . . . .,/¢... Y N lexploratory only] GEOLOGY: ENGINEERING: COMMISSION' DWJ ") ,,¢ JDH ~ .¢--~' RNC~ CO 60 HOW/Ijt - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : GNI 3 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292282000 REFERENCE NO : 99104 RECEIVED ,~':IAR 1 8 1999 AI~a Oil & Gas C, ons. Co~mission LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 99/03/11 ORIGIN : FLIC REEL NAME : 99104 CONTINUATION # : PREVIOUS REEL : CO~4~IENT : ARCO ALASKA, GNI #3, PRUDHOE BAY, API #50-029-22820-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/11 ORIGIN : FLIC TAPE NAME : 99104 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~ENT : ARCO ALASKA, GNI #3, PRUDHOE BAY, API #50-029-22820-00 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN 1 99104 PALMER WHIP SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING GNI 3 500292282000 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES lO-MAR-99 RUN 2 RUN 3 26 liN 1SE 4389 397 50.40 50.40 25.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.325 4154.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED OPEN HOLE PEX, AIT, AND BHC DATA AQUIRED ON ARCO ALASKA'S GNI #3 WELL. THIS LOG IS THE PDC. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE H~ER FILE1VUMBER: 1 EDITED MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SU~k~RY LDWG TOOL CODE AIT CNT SDN BCS $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 7830.0 4154.0 7816.0 4126.0 7826.0 4154.0 7771.0 4154.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: THIS FILE CONTAINS THE EDITED DATA. THE CURVES ARE CLIPPED AT FIRST AND LAST VALID READING. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... AIT CNT SDN BCS RUN NO. PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-MAR-1999 11:10 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 104 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 SP BCS MV 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 TENS BCS LB 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 DEV BCS DEG 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 TNPH CNT PU-S 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OH~Mll16988 O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN 0H~11116988 O0 000 O0 0 1 1 1 4 68 0000000000 ~!NOR SDN OIff4Mll16988 O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT OH~M 1116988 O0 000 O0 0 1 1 1 4 68 0000000000 AF20 AIT OH~Mll16988 O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT OH~Mll16988 O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT 0H~41116988 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 PAGE NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) AF90 AIT 0H~1116988 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/FIll6988 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7837.000 GR.BCS -999.250 SP.BCS -999.250 TENS.BCS DEV. BCS -999.250 CNTC. CNT -999.250 CFTC. CNT -999.250 FCNT. CNT NCNT. CNT -999.250 CRAT. CNT -999.250 NRAT. CNT -999.250 NPHI.CNT TNPH. CNT -999.250 CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN RHOB.SDN -999.250 MSFL.SDN -999.250 MINV. SDN -999.250 ~NOR.SDN AFiO.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT AF90.AIT -999.250 DT. BCS -999.250 DEPT. 4126.000 GR.BCS -999.250 SP.BCS -999.250 TENS.BCS DEV. BCS -999.250 CNTC. CNT 1665.294 CFTC. CNT 383.628 FCNT. CNT NCNT. CNT 1611.026 CRAT. CNT 4.456 NRAT. CNT 4.675 NPHI.CNT TNPH. CNT 56.159 CAL1.SDN -999.250 DRHO. SDN -999.250 PEF. SDN RHOB.SDN -999.250 MSFL.SDN -999.250 MINV. SDN -999.250 ~NOR.SDN AFiO.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT AF90.AIT -999.250 DT.BCS -999.250 4884.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 410.503 0.566 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 PAGE: 5 FILENUMBER 2 RAW MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed byfiles for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O . 1667 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH ........................... PEX 7848.0 AIT 7848.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 4046.0 4046.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR CNT BHC MCFL SDN AIT $ GA~ff4A RAY COMPENSATED NEUTRON SONIC MI CROCYL INRI CAL DENSITY ARRAY INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~I) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 07-MAY-98 8C0-609 0000 07-MAY-98 1230 07-MAY-98 7840.0 7840.0 4130.0 7840.0 TOOL NUMBER HGR HCNT SDT- C MCFL HRDD AIT-H 12.250 4154.0 4152.0 LSND 9.70 47.0 9.3 4.6 140.0 2. 180 67.0 1 . 910 54.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 PAGE: MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): 2.270 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: FIRST OPEN HOLE LOG RAN IN THIS WELL PRIMARY DEPTH CONTROL APPLIED USING MARKED LINE AND STRETCH CORRECTION OF 6 FT INDUCTION AND SONIC RAN WITH 1.5" STANDOFFS. DENSITY AND NEUTRON RAN EXCENTRALIZED WITH CALIPER AND BOWSPRING . INTEGRATED CEMENT VOLUMES CALCULATED WITH 9 5/8" CASING OD MCFL NOT VALID DUE TO LOW BOREHOLE SALINITY SONIC AFFECTED BY LARGE BOREHOLE AND SLOW FORMATION =>LOW/SIGNAL NOISE RATIO SECTION 6850 - 6000 REPEATED DUE TO POOR SONIC DATA. THIS FILE CONTAINS THE RAW DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 164 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 2 1 1 4 68 0000000000 DEPT FT 1116988 TENS BHC LB 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 SP PEX MV 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 TNRA PEX 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 GR BHC GAPI 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 RTNR PEX 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 RCNT PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 DEVI PEX DEG 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI PEX 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH PEX PU 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 NPOR PEX PU 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 HDRA PEX G/C3 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 PEFZ PEX 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 RHOZ PEX G/C3 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 H~IN PEX 0I~4~ 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 tff4NOPEX Ot~/~l1116988 O0 000 O0 0 2 1 1 4 68 0000000000 RXOZ PEX OH~ff41116988 O0 000 O0 0 2 1 1 4 68 0000000000 RX08 PEX Otfl~M1116988 O0 000 O0 0 2 1 1 4 68 0000000000 HCNT PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 HCFT PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 HGR BHC GAPI 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 RHFT PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 Rt{NT PEX CPS 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 DPHZ PEX PU 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 HTNP PEX PU 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 HNPO PEX PU 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 HCAL BHC IN 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 CALI BHC IN 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 AFiO AIT OHMM 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 AF20 AIT 0tfl~Ii116988 O0 000 O0 0 2 1 1 4 68 0000000000 AF30 AIT OH~M 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 AF60 AIT Otff4Mll16988 O0 000 O0 0 2 1 1 4 68 0000000000 AF90 AIT OH~Mll16988 O0 000 O0 0 2 1 1 4 68 0000000000 DT BHC US/F 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 TT3 BHC US 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 TT4 BHC US 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 TT1 BHC US 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 TT2 BHC US 1116988 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7848.000 TENS.BHC 3244.000 SP. PEX 0.000 CNTC. PEX 2652.379 CFTC. PEX 1038.362 TNRA. PEX 2.598 GR.BHC 148.397 RTNR.PEX 2.726 RCFT. PEX 942.533 RCNT. PEX 2466.715 DEVI.PEX -999.250 NPHI.PEX 0.322 TNPH. PEX 25.459 NPOR.PEX 25.059 HDRA.PEX -999.250 PEFZ.PEX -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center RHOZ.PEX -999.250 P~4IN. PEX RX08. PEX 2. 796 HCNT. PEX RH FT . PEX 942. 533 RHNT. PEX HNPO. PEX 25. 059 HCAL. BHC AF20.AIT 2. 822 AF30.AIT DT. BHC 92. 000 TT3. BHC TT2. BHC 402. 000 DEPT. 4046.333 TENS.BHC CFTC. PEX 374.354 TNRA. PEX RCFT. PEX 249.272 RCNT. PEX TNPH. PEX 56.355 NPOR . PEX RHOZ.PEX -999.250 P~4IN. PEX RX08 . PEX -999. 250 HCNT. PEX RHFT. PEX -999. 250 RPZNT. PEX HNPO.PEX -999.250 HCAL.BHC AF20.AIT -999.250 AF30.AIT DT. BHC -999. 250 TT3. BHC TT2. BHC -999. 250 il-MAR-1999 11:10 2.584 HMNO.PEX 2652.379 HCFT. PEX 2466.715 DPHZ.PEX 4.000 CALI.BHC 3.134 AF60.AIT 569.600 TT4.BHC 3099.000 SP.PEX 4.551 GR.BHC 1298.500 DEVI.PEX 56.447 HDRA.PEX -999.250 HMNO.PEX -999.250 HCFT. PEX -999.250 DPHZ.PEX -999.250 CALI.BHC -999.250 AF60.AIT -999.250 TT4.BHC 2.315 RXOZ.PEX 1038.362 HGR.BHC 60721.211 HTNP.PEX 4.000 AFiO.AIT 3.371 AF90.AIT 385.600 TT1.BHC 69.438 CNTC. PEX 37.430 RTNR.PEX 32.803 NPHI.PEX -999.250 PEFZ.PEX -999.250 RXOZ.PEX -999.250 HGR.BHC -999.250 HTNP. PEX -999.250 AFiO.AIT -999.250 AF90.AIT -999.250 TT1.BHC PAGE: 2.698 148.397 25.459 2.283 3.378 581.200 1627. 625 6.746 O. 583 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE ' 99/03/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUM~ER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: O . 1667 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 PAGE: FILE SU~VcARY VENDOR TOOL CODE START DEPTH PEX 6852.0 AIT 6852.0 BHC 8888.0 $ LOG HEADER DATA STOP DEPTH 5869.0 5869.0 9999.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR CNT BHC MCFL SDN AIT $ GA~ff~A RAY COMPENSATED NEUTRON SONIC MICROCYLINRICAL DENSITY ARRAY INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (?T) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHI~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) '. MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: 07-MAY-98 8C0-609 0000 07-MAY-98 1230 07-MAY-98 7840.0 7840.0 4130.0 7840.0 1800.0 TOOL NUMBER HGR HCNT SDT- C MCFL HRDD AIT-H 12.250 4154.0 4152.0 LSND 9.70 47.0 9.3 4.6 140.0 2. 180 67.0 1. 910 54.0 2. 270 60.0 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-MAR-1999 11:10 PAGE: 10 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.5 REMARKS: FIRST OPEN HOLE LOG RAN IN THIS WELL PRIMARY DEPTH CONTRO USING MARKEDLINEAND STRETCH CORRECTION OF 6 FT INDUCTION AND SONIC RANWITH 1.5" STANDOFFS. DENSITY AND NEUTRON RANEXCENTRALIZED WITH CALIPER AND BOWSPRING. INTEGRATED CEMENT VOLUMES CALCULATED WITH 9 5/8" CASING OD MCFL NOT VALID DUE TO LOW BOREHOLE SALINITY SONIC AFFECTED BY LARGE BOREHOLEAND SLOW FORMATION =>LOW/SIGNALNOISERATIO SECTION 6850 - 6000 REPEATED DUE TO POOR SONIC DATA. THIS FILE CONTAINS THE RAW DATA FOR THE REPEAT PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 164 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 TENS BHC LB 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 SP PEX MV 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center ll-MAR-1999 11:10 PAGE: 11 NANiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CFTC PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 GR BHC GAPI 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI PEX DEG 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 HDRA PEX G/C3 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 PEFZ PEX 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 RHOZ PEX G/C3 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 HMIN PEX OH~ff41116988 O0 000 O0 0 3 1 1 4 68 0000000000 HMNO PEX OHAV~41116988 O0 000 O0 0 3 1 1 4 68 0000000000 RXOZ PEX OHT4Mll16988 O0 000 O0 0 3 1 1 4 68 0000000000 RX08 PEX OH~ff41116988 O0 000 O0 0 3 1 1 4 68 0000000000 HCNT PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 HCFT PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 HGR BHC GAPI 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 RHFT PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 RI~NT PEX CPS 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 DPHZ PEX PU 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 HTNP PEX PU 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 HNPO PEX PU 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 HCAL BHC IN 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 CALI BHC IN 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 AFiO AIT OH~ff41116988 O0 000 O0 0 3 1 1 4 68 0000000000 AF20 AIT OHffff41116988 O0 000 O0 0 3 1 1 4 68 0000000000 AF30 AIT 014~ff41116988 O0 000 O0 0 3 1 1 4 68 0000000000 AF60 AIT 0H~4~1116988 O0 000 O0 0 3 1 1 4 68 0000000000 AF90 AIT 0tff4~II116988 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US~Fill6988 O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BHC US 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BHC US 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BHC US 1116988 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 6852.000 TENS.BHC 3210.000 SP. PEX 0.000 CNTC. PEX CFTC. PEX 524.758 TNRA. PEX 3.372 GR.BHC 54.545 RTNR.PEX RCFT. PE~ 503.221 RCNT. PEX 1605.612 DEVI.PEX -999.250 NPHI.PEX TNPH. PEX 36.413 NPOR.PEX 35.636 HDRA.PEX -999.250 PEFZ.PEX RttOZ.PEX -999.250 t~4IN. PEX 5.340 HNINO. PEX 5.914 RXOZ.PEX RXO8.PEX 10.841 HCNT. PEX 1715.466 HCFT. PEX 524.758 HGR.BHC RHFT. PEX 503.221 RHNT. PEX 1605.612 DPHZ.PEX 60721.211 HTNP. PEX HNPO. PEX 35.636 HCAL.BHC 12.486 CALI.BHC 12.486 AFiO.AIT AF20.AIT 1.905 AF30.AIT 1.664 AF60.AIT 1.501 AF90.AIT 1715.466 3.538 0.367 -999.250 10.833 54.545 36.413 2.699 1.470 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-MAR-1999 11:10 PAGE: 12 DT. BHC 102. 800 TT2. BHC 426. 400 TT3.BHC 618.000 TT4.BHC DEPT. 5869.167 TENS.BHC CFTC. PEX 575.834 TNRA.PEX RCFT. PEX 659.513 RCNT. PEX TNPH. PEX 44.280 NPOR.PEX RHOZ.PEX -999.250 H~IN. PEX RXO8.PEX -999.250 HCNT. PEX RHFT. PEX -999.250 RHNT. PEX t{NPO.PEX -999.250 HCAL.BHC AF20.AIT -999.250 AF30.AIT DT.BHC 105.800 TT3.BHC TT2.BHC -999.250 4012.000 SP. PEX 3.869 GR.BHC 2040.365 DEVI.PEX 45.383 HDRA.PEX -999.250 HMNO.PEX -999.250 HCFT. PEX -999.250 DPHZ.PEX -999.250 CALI.BHC -999.250 AF60.AIT -999.250 TT4.BHC 409. 600 TT1. BHC 42.000 CNTC. PEX 97.250 RTNR.PEX 35.468 NPHI.PEX -999.250 PEFZ.PEX -999.250 RXOZ.PEX -999.250 HGR.BHC -999.250 HTNP.PEX -999.250 AFIO.AIT -999.250 AF90.AIT -999.250 TT1.BHC 629. 200 2177 904 3 321 0 454 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/11 ORIGIN · FLIC TAPE NAME : 99104 CONTINUATION # : 1 PREVIOUS TAPE : COMmeNT . ARCO ALASKA, GNI #3, PRUDHOE BAY, API #50-029-22820-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE . 99/03/11 ORIGIN . FLIC REEL NAME : 99104 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, GNI #3, PRUDHOE BAY, API #50-029-22820-00 * ALASKA COMPUTING CENTER . ****************************** . ....... SCHLUMBERGER . ****************************** COMPANY NAME : ARCO ALASKA WELL NAPiE : GNI #3 FIELD NAIViE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 500292282000 REFERENCE NO : 99105 RECEIVED MAR 1 8 1999 ~. Oil & Gas C, ons. C, of~ion LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-MAR-1999 12:06 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 99/03/ 3 ORIGIN : FLIC REEL NAM~ : 99105 CONTINUATION # : PREVIOUS REEL : COFk4ENT : ARCO ALASKA INC. , PRUDHOE BAY, GNI #3, API #50-029-22820-00 **** TAPE HEADER **** SERVICE NAFiE : EDIT DATE : 99/03/ 3 ORIGIN : FLIC TAPE NAlViE .. 99105 CONTINUATION # : 1 PREVIOUS TAPE : COMMEJVT : ARCO ALASKA INC., PRUDHOE BAY, GNI #3, API #50-029-22820-00 TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA SURFACE LOCATION GNI #3 500292282000 ARCO ALASKA SCHLUMBERGER WELL SERVICES 3-MAR-99 BIT RUN 1 BIT RUN 2 BIT RUN 3 SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 26 llN 1SE 4390 397 50.90 49.50 21.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 15.000 13.375 4155.0 12.250 LIS Tape ~erification Listing Schlumberger Alaska Computing Center 3-MAR-1999 12:06 THIS TAPE CONTAINS THE LDWG FORMATTED LWD GR & ROP DATA AQUIRED ON ARCO ALASKA'S GNI #3 WELL. THE DATA IS AQUIRED IN ~ TIME IN TWO BIT RUNS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 1 EDITED~IERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 7834.0 4144.0 BASELINE DEPTH 88888.0 7762.0 7754.5 7743.5 7732.0 7722 0 7714 0 7693 0 7688 0 7680 5 7676 0 7645 5 7639 0 7631.5 7625.5 7625.0 7591.0 7555.0 7547.5 7461.5 7449.5 7447.5 .......... EQUIVALEiTr UNSHIFTED DEPTH MWD 88886.0 7760.0 7752.0 7742.5 7732.5 7721.0 7713.5 7691.0 7686.0 7678.0 7674.5 7642.0 7635.0 7626.5 7622.0 7621.0 7588.5 7551.5 7544.5 7458.0 7446.5 7443.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7426.0 7424.0 7405.5 7401.5 7396.0 7395.0 7390.0 7377.5 7339.0 7333.5 7325.0 7319.0 7309.0 7304.5 7296.0 7294.5 7287.5 7283.5 7281.5 7278.5 7274.5 7260.5 7257.0 7251.5 7244.0 7235.5 7230.0 7219.0 7213.5 7207.0 7191.5 7184.0 7182.0 7173.0 7164.5 7164.0 7151.0 7147.0 7142.5 7128.5 7124.0 7110.5 7109.5 7100.0 7096.0 7076.0 7072.5 7034.5 7031.0 7023.0 7012.5 7008.5 6997.0 6991.0 6977.5 7423.0 7421.0 7402.5 7398.5 7395.5 7393.0 7384.5 7373.5 7335.5 7329.5 7320.5 7313.5 7302.5 7300.5 7294.0 7291.0 7284.0 7282.0 7278.0 7276.0 7271.5 7257.0 7253.0 7248.0 7239.5 7229.5 7224.0 7214.0 7210 0 7203 0 7189 0 7180 0 7178 5 7169 0 7159.5 7157.0 7148.0 7143.5 7141.0 7127.0 7120.0 7107.5 7105.5 7096.0 7091.0 7072.5 7068.0 7030.5 7026.0 7018.5 7009.5 7005.0 6993.5 6986.5 6975.0 3-MAR-1999 12:06 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6975.0 6970.5 6966.0 6962.0 6960.5 6959.5 6956.5 6955.5 6950.5 6946.5 6945.0 6941.0 6933.0 6928.0 6928.0 6923.0 6925.0 6920.0 6919.5 6916.0 6912.0 6909.5 6894.0 6890.0 6880.0 6875.0 6868.0 6863.5 6857.0 6854.0 6850.5 6847.0 6847.5 6843.0 6843.0 6838.5 6839.0 6833.5 6834.5 6830.5 6822.5 6819.0 6819.5 6815.0 6815.5 6811.5 6800.5 6798.0 6799.0 6794.5 6795.5 6792.0 6791.5 6788.0 6784.5 6780.5 6781.5 6777.5 6775.0 6770.5 6769.0 6763.5 6749.0 6745.5 6736.0 6731.0 6719.0 6714.0 6712.5 6707.0 6709.0 6702.5 6700.5 6695.5 6696.5 6693.5 6690.0 6687.0 6672.5 6666.5 6664.5 6659.5 6652.5 6648.0 6648.0 6643.0 6642.5 6637.0 6638.0 6633.0 6622.5 6617.0 6609.5 6602.5 6591.0 6585.0 6586.0 6580.0 6554.5 6548.5 6531.0 6525.5 6516.5 6512.0 6505.5 6501.5 6505.0 6500.0 6471.5 6465.0 3-MAR-1999 12:06 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6466.5 6458.5 6454.5 6445.5 6442.5 6432.5 6426.0 6420.5 6415.5 6407.0 6402.0 6399.5 6393.5 6385.0 6373.5 6371.5 63 64.5 6353.0 6349.0 6323.0 6322.0 6317.5 6310.5 6307.0 6304.5 6293.5 6288.5 6267.0 6260.0 6251.5 6250.5 6246.0 6228.5 6218.0 6215.0 6210.0 6203.0 6187.5 6173.0 6167.0 6163.5 6152.5 6148.5 6131.5 6120 0 6116 0 6105 0 6102 5 6097 0 6090 0 6088 0 6085.5 6080.0 6073.5 6062.0 6461.0 6451.5 6449.5 6440.0 6437.0 6425.5 6418.5 6414.0 6410.0 6401.5 6396.0 6391.5 6385.5 6378.0 6368.5 6366.0 6358.5 6347.5 6342 5 6318 0 6314 5 6310 5 6303 0 6300 0 6297 5 6288 0 6282 0 6260 5 6253 0 6246 0 6243 5 6239 5 6221 5 6210 0 6208 5 6203 5 6197 0 6181 0 6163 0 6159 5 6156 5 6146.0 6142 0 6124 5 6114 0 6110 5 6098 5 6095 0 6091 0 6085 5 6082 5 6079 5 6074 5 6066 5 6054 0 3-MAR-1999 12:06 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-MAR-1999 12:06 PAGE: 6053.5 6035~5 6026.5 6017~5 6011.0 6010.0 6001.5 5994.5 5988.0 5985.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 6046 5 6030 0 6020 5 6011 0 6005 5 6003 0 5994 0 5988 0 5981 0 5979.0 92.0 BIT RUN NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE EDITED LWD DATA. THE GR IS SHIFTED TO THE BCS GR AQUIRED BY SCHLUMBERGER ON 07-MAY-98. THE SHIFTS ARE CARRIED TO THE ROP CURVE. THE CURVES ARE CLIPPED AT FIRST AND LAST VALID READINGS. NOT ALL SHIFTS ARE DISPLAYED BECAUSE THEIR NUMBER EXCEEDS THE BUFFER SIZE OF THE HEADER PROGRAM. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-MAR-1999 12:06 PAGE: ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 4000244 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000244 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR 4000244 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 4000244 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7834.000 GR.MWD -999.250 ROP.MWD 46.800 GR.BCS DEPT, 4126.000 GR.MWD -999.250 ROP.MWD -999.250 GR.BCS -999.250 35.996 ** END OF DATA ** **** FILE TRAILER **** FILE NACRE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FiLE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-OMBER 2 RAW MWD Curves and log header data for each bi¢ run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUA~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-MAR-1999 12:06 PAGE: LOG HEADER DATA 7840.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~CE) : 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA14~A RAY $ 4150.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: THIS FILE CONTAINS THE RAW LWD DATA. $ LIS FORMAT DATA 06-MAY- 98 5-36 4.0 REAL - TIME 7840.0 4142.0 7838.0 0.0 36.0 TOOL NUMBER MIO 15.000 4155.0 LSND 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-MAR-1999 12:06 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE ~ CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB S~P ELEM CODE (HEX) DEPT FT 4000244 O0 000 O0 0 2 1 1 4 68 0000000000 GR GRRW GAPI 4000244 O0 000 O0 0 2 1 1 4 68 0000000000 GR GRIN GAPI 4000244 O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 LW1 F/HR 4000244 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7840.000 GR.GRRW -999.500 GR.GRIN -999.500 ROP5.LW1 DEPT. 4150.000 GR.GRRW -999.250 GR.GRIN 5.303 ROP5.LW1 37.990 181. 940 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-MAR-1999 12:06 PAGE: 10 **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/ 3 ORIGIN : FLIC TAPE NAME : 99105 CONTINUATION # : 1 PREVIOUS TAPE : COF~fENT : ARCO ALASKA INC., PRUDHOE BAY, GNI #3, API #50-029-22820-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/ 3 ORIGIN : FLIC REEL NAME : 99105 CONTINUATION # : PREVIOUS REEL : COF~F2VT : ARCO ALASKA INC., PRUDHOE BAY, GNI #3, API #50-029-22820-00 Sperry-Sun Drilling Services LIS Scan Utility Mon Dec 08 17:45:25 1997 7 75 Reel Header Service name ............. LISTPE Date ..................... 97/12/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/12/08 Origin ................... STS Date Tape Name ................ UNKNOWN Continuation Numbe~ ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Library. Scientific Scientific Physical EOF Comment Record TAPE HEADER EXPLORATION MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-70310 J. FOLEY M. WHITELEY ¥¢EC 22 '1997 -~i.~,..;.~ Oil ~', '"" ' "'""--*'~ ' ' 500292281900 BP EXPLO~TION (~S~), INC. SPERRY-SUN DRILLING SERVICES 08-DEC-97 MWD RUN 4 MWD RUN 5 AK-MM-70310 AK-MM-70310 J. FOLEY J. FOLEY M. WHITELEY G. W. CRAIG JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 6 AK-MM-70310 J. FOLEY G.W. CRAIGE MWD RUN 6 AK-MM-70310 J. FOLEY G.W. CRAIGE 6 liN 14E 5000 50O 1:3EOc° .._2 & Uas ................. .,"~ .' FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 71.00 68.20 30.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 12.250 9.625 4396.0 3RD STRING 8.500 7.000 12907.0 PRODUCTION STRING 6.000 13282.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 4, 5 AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER ~fgELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4. 4. MEASUREMENT AFTER DRILLING (MAD) DATA IN THE INTERVALS 10980'MD, 7614'TVD TO l1560'MD, 7988'TVD AND l1640'MD, 8041'TVD TO l1850'MD, 8190'TVD WERE AC- QUIRED GOING IN THE HOLE PRIOR TO, AND TRIPPING OUT OF THE HOLE FOLLOWING MWD RUN 4, RESPECTIVELY. MAD DATA IN THE INTERVAL 12946'MD, 9127'TVD TO 13282'MD, 9441'TVD WERE AC- QUIRED WHILE TRIPPING OUT OF THE HOLE FOLLOWING MWD RUN 6. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13282'MD, 9441'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY. 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. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH THE EXTENTION "M" ARE ACQUIRED ON A MAD PASS. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH RPD 7230.5 RPM 7230.5 RPS 7230.5 FET 7231.0 RPX 7231.0 GR 7238.5 ROP 7270.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 7231.0 7243.5 7246.5 7254.5 7265.0 7267.0 7269.5 7283.0 7284.5 7287.5 7289.5 7291.0 7294.5 7298.5 7309.5 7318.5 7322.5 7326.0 7331.0 7336.0 7356.0 7359.0 7368.0 7376.5 7382.0 7385.0 7391.0 7396.0 7422.5 7423.5 7425.0 7432.5 7447.5 7451.0 7462.0 7463.5 7466.5 7468.5 7471.0 GR 7231.5 7244.0 7247.0 7255.0 7266.0 7267.5 7270.0 7283.0 7284.5 7288.0 7290.5 7292.0 7295.5 7302.5 7308.5 7319.0 7323.5 7326.0 7330.5 7335.0 7358.5 7361.0 7368.5 7377.0 7381 5 7384 5 7390 0 7397 5 7422 0 7423 5 7425.0 7431.5 7447.5 7449.5 7462.5 7463.5 7467.0 7467.5 7470.0 all bit runs merged. STOP DEPTH 13243.0 13243.0 13243.0 13243.0 13243.0 13235.5 13288.5 EQUIVALENT UNSHIFTED DEPTH -- ~'£gSL O'ggSL O'gg8L O'OgSL ~'LZSL ~'gZSL ~'LOSL O'~08L ~'§6LL §'~6LL O'~SLL O'08LL O'gLLL ~'69LL O'99LL ~'~9LL O'09LL O'~LL O'g~LL ~'O~LL O'9~LL ~'~LL O'~LL O'~LL O'~gLL o'ggLL ~'~LL ~'~LL O'LOLL O'~OLL ~ '~OLL §'L69L O'g69L 0 '~89L ~'gLgL ~'L99L ~'~99L ~'~99L 0 '699L 0 'O~gL ~'899L 0 'gggL 0 ' ~ggL 0 g6GL ~ 88~L 0 ~8§L 0 08~L 0 9L§L ~ ~6~L O'§6~L O'~6~L O'06~L 0'68~L 0'88~L §'~L~L ~'SL~L ~'gL~L O'~L~L ~'OL~L G'ggSL ~'ggSL O'gD8L O'OgSL 0'StSL G'~8L ~'LOSL ~'~08L ~'~6LL O'~6LL O'£SLL ~'8LLL O'~LLL ~'OLLL O'LgLL g'Z9LL ~'6§LL §'~LL §'g~LL O'Z§LL 0'9~LL §'g~LL ~'Z~LL O'O~LL O'9gLL §'9gLL O'ggLL O'~ZLL ~'LOLL §'~OLL 0 'gOLL 0'669L 0'~69L 0'~89L G'gLgL 0'899L 0'~99L 0'~99L 0'6§9L O'Z§9L 0 '699L ~ '9E9L § '~9L 0 '~6~L ~'68~L O'9@~L ~'~8~L ~'08~L ~'LL~L O'~6~L ~'£6~L 0'£6~L ~'06~L O'06~L ~'LS~L ~'~L~L O'~L~L ~'gL~L O'£L~L §'~L~L 0'g908 S'E908 0'E908 0'£~08 O'g~08 O'E§08 ~'6£08 O'Lg08 ~'g~08 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~'IL98 '8998 'I998 '~§98 '£cj98 0'8~98 §'L£98 0'~98 ' 8~98 '~98 '0~98 '8198 '0198 0'L6~8 ~'~£86 0'~896 ~'0896 ~'~8~6 ~'~8§6 §'6£§6 ~'8£~6 ~'8~6 ~'9~6 ~'t~6 0'9£g6 0'S~S6 S'6~§6 0'6§~6 ~'8~6 ~ '0~56 0 '9~6 0 'II~6 §'£0~6 §'2056 ~'00~6 0'~6£6 §'68~6 0'J£56 0'~£6 0'5£~6 ~'8I£6 O'ERS6 0'8~6 §'I226 §'60E6 ~'6616 §'§@I6 0'E816 ~'W§I6 ~'6~I6 0'~£I6 S'OEI6 S'9EI6 O'EEI6 ~'6II6 0'£II6 0'9II6 ~'III6 ~'6016 ~'8806 0'5806 0'I806 ~'~£06 0'9906 0'§906 §'J906 §'I906 S'8~06 O'IW06 0'5£06 g'It86 S'S896 S'LL96 0'~8S6 0'I8§6 0'8L§6 S'9tg6 0'~996 0'9~§6 0'~£g6 S'I~§6 0'9Eg6 ~'0996 §'8§96 0'0~6 §'0156 ~'~0~6 0'I0~6 0'86£6 §'06£6 0'~8£6 0'6956 S'I~£6 0'£I£6 0'I5~6 0'I~6 O'IIE6 §'8616 0'~816 ~'I816 §'6~I6 §'6~I6 §'~£I6 0'9216 0'I216 §'8II6 0'9II6 ~'5II6 S'III6 0'6016 0'£806 ~'~806 ~'0806 ~'§£06 0'5906 §'~906 0'0906 §'8§06 §'£~06 0'0S06 0'I~06 ~'I206 0'L660I ~'~660I ~'9860I 0'~860I 0'~860I ~'9L60I 0'9~60I ~'~I60I ~'£060I O'I060I ~'6680I 0'£680I 0'~680I 0'~80I g'9~80I 0'~80I 0'0~80I ~'£~80I §'6180I 0'~080I ~'~LOI ~'6~LOI ~'~LOI ~'~gLOI ~'8ILOI ~ '90LOI O'~OLOI ~'L690I 0'9690I ~'~690I 0'0890I g'8§90I ~'~90I ~'I590I 0'8E90I 0'£E90I ~'~L§OI 0'9~0I §'~0I ~'~OI O'O~OI 0'6£~0I ~'0~90I O'I6EOI ~'0~£0I O'OWEOI 0'£9~0I 0'§9£01 ~ ES~OI 0 09EOI 0 ~600I ~ 16001 ~ 68001 0 ~EOOI ~ 8966 0 E886 ~ 0886 0 8£86 W 9£86 0'9660I 0'~660I ~'~860I ~'E860I §'6L60I §'gL60I 0'~60I ~'EI60I ~'8060I §'0060I 0'6680I 0'96801 ~'5680I ~'0~80I §'~80I 0'~80I 0'09801 ~'£~80I 0'~80I 0'~080I 0'£E£0I §'OE£OI 0'9~LOI ~'~£0I 0'8I£0I O'LO£OI 0'~0£0I §'00LOI §'8690I 0'~690I ~'8£90I §'8~90I ~'~§90I 0'I~90I W'6E90I 0'£~90I §'89WOI ~'~WOI §'I~§OI 0'I~90I 0'6~90I W'LESOI W'6190I §'I6~0I O'~OI ~'0§£0I 0'89£01 0'£9~0I §'0~£0I 0'6EEOI O'LE£OI 0'16001 ~'6800I 0'68001 W'6EOOI ~'~566 0'~886 0'8L86 0'9L86 §'£L86 11552.5 11554.0 11555.0 11556.5 11558.5 11560.0 11562.0 11571.0 11577.0 11578.5 11583.0 11586.0 11589.0 11593.5 11594.0 11601.0 11602.0 11603.5 11605.0 11606.5 11608.5 11642~5 11643.5 11645.5 11646.5 11648.0 11652.5 11654.0 11655.0 11658.0 11660.5 11662.0 11665.0 11676.5 11681.0 11696.5 11701.5 11703.0 11704.0 11705.5 11707.5 11718.0 11723.5 11731.5 11733.5 11740.5 11751.5 11755.0 11771.5 11773.5 11776.5 11778.5 11780.5 11782.5 11787.0 11790.0 11792.5 11797.5 11801.5 11803.0 11550.0 11551.5 11552.5 11554.0 11556.5 11559.5 11560.5 11569.0 11574.5 11576.0 11583.0 11585.5 11587.5 11591.5 11595.0 11601.0 11602.5 11603.5 11605.5 11606.5 11608.5 11642.0 11643.5 11645.0 11646.5 11647.5 11648.5 11651.5 11654.0 11657.5 11659.5 11660.5 11663.5 11674.0 11679.0 11695.5 11701.0 11702.0 11703.0 11705.0 11706.0 11717.5 11721.5 11730.0 11731.5 11739.0 11749.0 11752.0 11768.5 11770.0 11772.5 11774.0 11777.0 11779.0 11784.5 11787.0 11790.0 11798.0 11800.5 11801.5 13061.5 13063.0 13066.5 13071.5 13074.5 13080.0 13093.5 13095.0 13102.5 13107.5 13108.5 13112.0 13115.5 13156.0 13158.0 13158.5 13160.5 13162.5 13166.0 13167.5 13168.5 13194.5 13203.0 13211.0 13213.5 13215.5 13222.5 13224.5 13226.0 13229.5 13232.5 13288.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 13057.0 13058.5 13062.0 13065.5 13070.0 13074.5 13089.0 13091.0 13098.0 13103.0 13104.5 13107.5 13111.0 13151.0 13153.0 13154.5 13155.5 13158.0 13160.5 13162.0 13163.0 13191.5 13196.5 13205.5 13207.0 13210.5 13216.0 13217.5 13219.5 13223.5 1322 6.0 13282.0 BIT RUN NO MERGE TOP MERGE BASE 4 7270.0 12132.0 5 12132.0 12916.0 6 12916.0 13282.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Spegification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 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 MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR 1 68 1 68 1 68 1 68 1 68 12 16 20 24 28 Name Min Max DEPT 7230.5 13288.5 ROP 4.6792 6205.08 GR 13.8692 574.737 RPX 0.1506 2000 RPS 0.1313 99.1773 RPM 0.1313 148.797 RPD 0.0849 2000 FET 0.2551 160.105 Mean Nsam 10259.5 12117 104.987 12038 85.3046 11995 3.89752 12025 3.93822 12026 4.11502 12026 4.7971 12026 2.47521 11974 First Reading 7230.5 7270 7238.5 7231 7230.5 7230.5 7230.5 7231 Last Reading 13288.5 13288.5 13235.5 13243 13243 13243 13243 13243 First Reading For Entire File .......... 7230.5 Last Reading For Entire File ........... 13288.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 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 ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 10953.0 RPD 10953.0 RPM 10953.0 RPS 10953.0 STOP DEPTH 13243.0 13243.0 13243.0 13243.0 RPX GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 10953.0 13243.0 10961.0 13236.0 10987.0 13290.0 MAD RUN NO. MAD PASS NO. 4 6 MERGED MAD PASS. $ 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 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 10955.5 12902.5 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD AAPI 4 1 68 RPX MAD OH~M 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 MERGE BASE 11879.5 13284.0 Name Min Max Mean Nsam DEPT 10953 13290 12121.5 4675 RAT 24 4904.3 142.314 2239 GR 16.154 645.669 93.0485 2223 RPX 0.1711 2000 8.85031 2227 RPS 0.2201 67.3783 8.62544 2227 RPM 0.3113 2000 10.7474 2226 RPD 0.2425 2000 12.0515 2226 FET 5.77 46.8208 25.5128 2226 First Reading 10953 10987 10961 10953 10953 10953 10953 10953 Last Reading 13290 13290 13236 13243 13243 13243 13243 13243 First Reading For Entire File .......... 10953 Last Reading For Entire File ........... 13290 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 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 ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Corament Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7231.5 12093.5 RPD 7231.5 12093.5 RPM 7231.5 12093.5 RPS 7231.5 12093.5 RPX 7231.5 12093.5 GR 7239.0 12101.5 ROP 7270.5 12132.5 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 08-NOV-97 5.06 5.46 MEMORY 12132.0 7270.O 12132.0 35.7 55.2 TOOL NUMBER P0870CRG6 P0870CRG6 8.500 8.5 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS4) 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 4 AAPI 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMS4 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 LSND-HT 9.90 59.0 9.3 2450 3.2 1. 600 .000 1.350 1.600 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 136.0 Name Min Max Mean DEPT 7231.5 12132.5 9682 GR 20.4032 316.599 82.791 RPX 0.7447 79.6187 3.80155 RPS 0.7402 112.601 4.06992 RPM 0.7545 232.72 4.32252 RPD 0.8334 108.591 4.43189 ROP 7.0022 6205.08 115.109 FET 0.2551 16.222 0.952278 First Last Nsam Reading Reading 9803 7231.5 12132.5 9726 7239 12101.5 9725 7231.5 12093.5 9725 7231.5 12093.5 9725 7231.5 12093.5 9725 7231.5 12093.5 9725 7270.5 12132.5 9725 7231.5 12093.5 First Reading For Entire File .......... 7231.5 Last Reading For Entire File ........... 12132.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 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 ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 12094.0 12882.5 RPD 12094.0 12882.5 RPM 12094.0 12882.5 RPS 12094.0 12882.5 RPX 12094.0 12882.5 GR 12102.0 12890.0 ROP 12133.0 12916.0 $ LOG HEADER DATA DATE LOGGED: 16-NOV-97 SOFTWARE. SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER {FT) : 12916.0 TOP LOG INTERVAL (FT): 12132.0 BOTTOM LOG INTERVAL (FT): 12916.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 22.0 MAXIMUM ANGLE: 34.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ 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 (OHM}4) 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P0884CRG6 P0884CRG6 8.500 8.5 LSND-HT 10.40 18.0 9.0 1350 4.2 1.100 1.100 1.700 1.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 RPX MWD 5 OHM}4 4 1 68 8 3 RPS MWD 5 OHMM 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD MWD 5 OHMM 4 1 68 20 6 ROP MWD 5 FT/H 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 136.0 First Name Min Max Mean Nsam Reading DEPT 12094 12916 12505 1645 12094 GR 57.399 135.473 104.219 1577 12102 Last Reading 12916 12890 RPX 0.97 4.0699 1.82888 1578 RPS 0.956 3.7437 1.81296 1578 RPM 0.9585 3.5533 1.79236 1578 RPD 0.9821 3.5138 1.8231 1578 ROP 6.7318 1918.96 60.5863 1567 FET 0.788 160.105 9.28195 1578 12094 12094 12094 12094 12133 12094 12882.5 12882.5 12882.5 12882.5 12916 12882.5 First Reading For Entire File .......... 12094 Last Reading For Entire File ........... 12916 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 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 ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 12883.0 13236.5 RPM 12883.0 13236.5 RPS 12883.0 13236.5 RPX 12883.0 13236.5 GR 12890.5 13229.0 FET 12907.0 13236.5 ROP 12916.5 13282.0 $ LOG HEADER DATA DATE LOGGED: 23-NOV-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 13282.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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) : 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 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 12916.0 13282.0 19.7 22.0 TOOL NUMBER P0871SP4 P0871SP4 6.0OO 6.0 LSND-HT 9.70 55.0 9.0 30000 3.3 .O8O .080 .120 .190 183.9 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAP I 4 1 68 4 2 RPX MWD 6 OHMM 4 1 68 8 3 RPS MWD 6 OHMM 4 1 68 12 4 RPM MWD 6 OHMM 4 1 68 16 5 RPD MWD 6 OHMM 4 1 68 20 6 ROP MWD 6 FT/H 4 1 68 FET MWD 6 HOUR 4 1 68 24 28 Name Min Max Mean DEPT 12883 13282 13082.5 GR 13.8692 57.4.737 78.9473 RPX 0.1506 2000 8.62481 RPS 0.1313 22.8945 7.21829 RPM 0.0849 2000 16.8152 RPD 0.05 2000 68.4568 ROP 4.6792 1366.2 39.8828 FET 1.6698 128.967 8.47619 Nsam 799 678 708 7O8 708 708 732 660 First Reading 12883 12890.5 12883 12883 12883 12883 12916.5 12907 Last Reading 13282 13229 13236.5 13236.5 13236.5 13236.5 13282 13236.5 First Reading For Entire File .......... 12883 Last Reading For Entire File ........... 13282 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves aid log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 10955.5 RPD 10955.5 RPM 10955.5 RPS 10955.5 RPX 10955.5 STOP DEPTH 11840.5 11840.5 11840.5 11841.0 11841.0 GR 10963.5 RAT 10988.5 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 11848.5 11879.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMS) 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 08-NOV-97 5.06 5.46 MEMORY 12132.0 7270.0 12132.0 35.7 55.2 TOOL NUMBER P0870CRG6 P0870CRG6 8.500 8.5 LSND-HT 9.90 59.0 9.3 2450 3.2 1.600 ,000 1.350 1,600 136.0 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT RAT GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MAD 4 FT/H 4 1 68 MAD 4 AAPI 4 1 68 MAD 4 OHMM 4 1 68 MAD 4 OHM~ 4 1 68 MAD 4 OHMM 4 1 68 MAD 4 OHMM 4 1 68 MAD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 10955.5 11879.5 11417.5 1849 RAT 27.9885 4904.3 131.215 1567 GR 28.8891 205.938 98.4612 1552 RPX 1.5382 58.296 8.5819 1553 RPS 1.6644 67.3783 9.70234 1553 RPM 1.5575 97.2201 11.1287 1552 RPD 1.7111 98.6898 12.5145 1552 FET 5.72 35.6591 27.0002 1552 First Reading 10955.5 10988.5 10963.5 10955.5 10955.5 10955.5 10955.5 10955.5 Last Reading 11879.5 11879.5 11848.5 11841 11841 11840.5 11840.5 11840.5 First Reading For Entire File .......... 10955.5 Last Reading For Entire File ........... 11879.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5OOO 6 VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 12902 5 12907 0 12907 0 12907 0 12907 0 12907 0 12953 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY QR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13229.5 13236.5 13236.5 13236.5 13236.5 13236.5 13284.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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): EWR FREQUENCY (HZ): 23-NOV-97 5.06 5.46 MEMORY 13282.0 12916.0 13282.0 19.7 22.0 TOOL NUMBER P0871SP4 P0871SP4 6.000 6.0 LSND-HT 9.70 55.0 9.0 30000 3.3 .08O .080 · 120 .190 183.9 .6 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD 6 FT/H 4 1 68 GR MAD 6 AAPI 4 1 68 RPX MAD 6 OHMM 4 1 68 RPS MAD 6 QHMM 4 1 68 RPM MAD 6 OHMM 4 1 68 RPD MAD 6 OHM~ 4 1 68 FET MAD 6 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 12902.5 13284 13093.2 764 RAT 24 305.859 158.636 663 GR 16.154 645.669 81.0677 655 RPX 0.1711 2000 8.39373 660 RPS 0.2201 21.8171 6.58503 660 RPM 0.3113 2000 10.5557 660 RPD 0.2425 2000 11.634 660 FET 6.1712 46.8208 22.114 660 First Reading 12902.5 12953 12902.5 12907 12907 12907 12907 12907 Last Reading 13284 13284 13229.5 13236.5 13236.5 13236.5 13236.5 13236.5 First Reading For Entire File .......... 12902.5 Last Reading For Entire File ........... 13284 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/12/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... I)[C 2..2 199'/ ****************************** COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAi~E : SAM #1 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 50-029-22819-00 REFERENCE NO : 97545 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 97/12/14 ORIGIN : FLIC REEL NA~E : 97545 CONTINUATION # : PREVIOUS REEL : CO~gffF2FT : BP EXPLORATION, SAM #1, PRUDHOE BAY, API #50-029-22819-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 97/12/14 ORIGIN : FLIC TAPE NAME : 97545 CONTINUATION # : 1 PREVIOUS TAPE : COM~iE~Ff : BP EXPLORATION, SAM #1, PRUDHOE BAY, API #50-029-22819-00 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY. BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING RUN1 97545 MORRISON F. RADELLA SAM#1 500292281900 BP EXPLORATION (ALASKA) INC. SCHLUMBERGER WELL SERVICES 13-DEC-97 RUN 2 97545 BARTZ F. RADELLA 6 liN 14E 5000 500 RUN 3 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4441.0 6.000 7.000 12906.0 69. O0 65.78 34.00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE LDWG FORMATTED OPENHOLE DATA ACQUIRED ON BP EXPLORATION'S SAM #1 WELL. RUN #2 HAD THE FOLLOWING LOGS: BOREHOLE COMPENSATED SONIC, COMPENSATED NEUTRON, TRIPLE DETECTOR DENSITY, AND ARRAY INDUCTION TOOL. RUN #1 HAD THE FOLLOWING LOGS: DIPOLE SONIC, COMPENSATED NEUTRON, TRIPLE DETECTOR DENSITY, ARRAY INDUCTION, COMBINABLE MAGNETIC RESONACE TOOL. ALSO ACQUIRED IN CASING WAS THE ULTRA SONIC IMAGING TOOL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMEiTT: 0.5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH AIT 13275.0 DAS 13224.0 SDN 13252.0 CNT 13243.0 ClViR 11936.0 $ BASELINE CURVE FOR SHIFTS: GR.DAS CURVE SHIFT DATA (MEASUREDDEPTH) BASELINE DEPTH 88888.0 13115.5 13111.5 13108.5 13095.0 13074.5 13066.5 STOP DEPTH .......... 4462.0 4452.0 4452.0 4452.0 9280.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... AIT/PEX USIT 88888.5 88887.5 13116.0 13112.5 13109.0 13095.5 13075.0 13067.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 13063.0 13064.0 13051.5 13052.0 13039.5 13040.5 13034.5 13036.0 13029.5 13030.5 13020.0 13021.5 13018.5 13019.5 13011.0 13012.0 13008.0 13009.5 12997.0 12997.0 12981.5 12982.0 12977.5 12976.5 12965.0 12965.5 12946.0 12946.5 12931.5 12931.5 12929.5 12930.0 12915.0 12913.5 12910.5 12910.0 12904.0 12903.0 12889.0 12887.0 12881.0 12879.5 12870.0 12869.5 12095.5 12086.0 12079.5 12075.0 12066.0 12063.0 12056.0 12054.5 12048.0 12047.5 12045.5 12043.0 12036.5 12027.5 12027.0 12021.0 12012.0 12004.5 11986.0 11984.0 11980.0 11976.5 11967.5 11950.5 11937.5 11914.5 11912.5 11894.5 11892.5 11892.5 11889.0 11885.5 11877.5 11871.0 11870.5 11867.5 11862.0 11860.0 12095.0 12087.5 12080.5 12076.0 12066.5 12063.5 12047.5 12045.5 12038.5 12022.0 12013.0 12004.5 11986.5 11984.0 11980.0 11975.5 11968.0 11951.0 11937.0 11916.0 11913.0 11894.0 11890.5 11886.0 11877.5 11869.5 11864.0 11862.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 11855 0 11847 0 11838 5 11837 5 11829 5 11823 0 11810 0 11786.0 11751.5 11723.0 11695.0 11661.5 11653.5 11650.5 11645.5 11637.0 11631.0 11613.5 11609.0 11598.5 11594.0 11581.5 11576.5 11570.0 11568.0 11559.0 11537.5 11516.5 11497.5 11437.0 11414.0 11398.5 11391.0 11367.0 11328.5 11298.0 11284.5 11253.5 11249.0 11242.5 11230.0 11183.0 11132.5 11122.0 11066.5 11025.5 11003.0 10983.5 10840.5 10816.5 10807.5 10762.5 10736.0 10723.0 10693.0 11810.0 11786.5 11751.5 11723.0 11695.0 11662.0 11654.0 11650.5 11644.5 11637.0 11631.0 11613.5 11608.5 11599.0 11594.0 11580.5 11577.5 11571.5 11568.5 11558.5 11539.0 11517.5 11497.5 11437.5 11413.5 11398.5 11390.5 11367.5 11328.0 11297.0 11284.5 11253.0 11250.0 11244.0 11231.0 11182.5 11132.5 11120.5 11066.5 11025.5 11003.5 10983.5 10840.0 10815.5 10807.5 10762.5 10737.0 10723.0 10692.5 11855.0 11848. 0 11839.0 11836.5 11829. 0 11825.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10656.0 10640.5 10598.0 10566.0 10563.5 10552.5 10489.0 10439.0 10392.5 10347.5 10206 0 10141 0 10122 5 10114 0 10050 5 10040 0 9998 5 9947 0 9901 5 9875 0 9798 0 9774 0 9739 0 9680 0 9653 0 9642 0 9638 5 9608 5 9583 0 9557 5 9549 5 9540 0 9529 0 9526.5 9506.5 9473 5 9454 5 9411 5 9409 5 9385 0 9335 0 9306.5 9266.5 9241.5 9216.5 9210.5 9199.5 9185.0 9141.5 9130.0 9110.5 9088.5 9055.0 9032.5 9016.0 10655.0 10640.5 10597.0 10566.5 10562.5 10551.0 10488.5 10438.5 10391.5 10348.0 10205.5 10141.0 10124.0 10114.0 10051.0 10039.0 9998.0 9945.5 9901.0 9874.0 9798.0 9773.0 9738.0 9678.0 9651.5 9641.5 9636.5 9606.5 9581.0 9555.5 9547.5 9538.5 9525.5 9523.0 9505.0 9474.5 9453.0 9411.0 9408.5 9385.0 9335.0 9305.5 9266.5 9241.5 9216.0 9210.5 9198.5 9183.0 9140.0 9129.0 9109.0 9087.5 9052.5 9031.0 9015.0 14-DEC-1997 15:16 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8997.0 8939.0 8916.0 8904.5 8894.0 8874.0 8855.0 8837 0 8815 5 88O4 5 8793 0 8779 0 8769 0 8739 5 8734 0 8721 5 8716.5 8714 5 8712 5 8703 5 8700 5 8689 0 8682 5 8654.0 8637.5 8628.0 8624.5 8620.0 8606.5 8585.0 8582.0 8572.0 8565.5 8542.5 8534.0 8528.0 8522.0 8510.0 8503.0 8498.5 8496.0 8494.5 8480.5 8465.0 8456.5 8449.0 8440.0 8429.5 8410.0 8399.5 8389.5 8372.0 83 63.5 83 60.0 8344.5 8994.5 8937.5 8915.0 8903 5 8893 0 8873 0 8855 5 8837 5 8815 5 8803 5 8792 0 8779 5 8766.5 8737.5 8732.5 8720.0 8716.5 8714 0 8711 5 8702 5 8699 0 8687 5 8681 5 8653 5 8637 0 8628.0 8625.0 8619.5 8605.5 8585.5 8582.0 8571.5 8564.5 8541.5 8531.0 8527.0 8522.5 8510.0 8502.5 8498.5 8496.5 8492.5 8478.0 8463.5 8456.0 8448.0 8440.0 8429.5 8409 5 8398 5 8390 0 8372 0 8364 0 8360 0 8345 5 14-DEC-1997 15:16 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8334.5 8323.0 8317.0 8299.0 8289.0 8276.5 8215.5 8212.5 8198.5 8175.0 8164.0 8161.5 8142.0 8128.5 8124.5 8103.5 8095.0 8081.5 8074.0 8072.5 8061.5 8041.5 8012.5 7983.0 7973.5 7950.0 7927.0 7921.5 7915.5 7895.0 7884.5 7877.5 7869.0 7862.0 7845.0 7833.0 7819.0 7807.0 7784.5 7771.5 7768.0 7760.0 7751.0 7743.5 7742.0 7726.0 7704.5 7702.5 7675.0 7668.5 7665.0 7662.5 7659.5 7648.5 7626.5 8334.0 8322.5 8317.0 8299.0 8290.0 8277.5 8216.0 8212.0 8198.5 8174.5 8164.0 8161.5 8141.5 8128.5 8125.0 8103.5 8095.0 8081.0 8074 0 8072 0 8061 5 8041 0 8012 5 7983 0 7973 5 7950.0 7927 0 7921 5 7915 5 7894 5 7884 5 7878 5 7868 5 7864 0 7845 5 7833 5 7819 5 7807 5 7783 5 7771 0 7767 0 7759 5 7750 5 7744 0 7741 5 7726 0 7704.5 7702.5 7674.5 7668.5 7665.0 7662.0 7659.0 7648.5 7627.0 14-DEC-1997 15:16 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 7580 5 7568 5 75~5 0 7547 5 7490 5 7468 5 7446.5 743 6.5 7422.5 7396.5 7391.0 73 66.0 7334.5 7322.5 7292.0 7286.0 7278.5 7267.0 7251.5 7250.0 723 6.5 7220.5 7181.0 7179.5 7168.5 7154.0 7136.5 7105.5 7101.5 7085.5 7075.0 7062.5 7035.0 7012.0 6992.5 6954.5 6933.5 6904.0 6857.5 6847.5 6826.5 6774.5 6758.0 6746.5 6744.0 6727.0 6718.5 6708.5 6704.0 6696.0 6682.0 6671.0 6649.5 6635.0 6614.5 7580.5 7567.5 7563.0 7547.0 7490.0 7468.5 7447.0 7436.0 7423.0 7396.5 7391.0 73 66.0 7335.0 7322.5 7291.5 7286.5 7278.0 7267.0 7252.0 7249.5 7236.5 7220.5 7181.0 7179.0 7169.0 7153.5 7135.5 7104.5 71 O1.5 7085.0 7076.0 7061.5 7033.5 7011.5 6991.5 6953.5 6933.5 6904.0 6857.5 6847.5 6825.5 6773.5 6757.5 6746.5 6742.5 6726.0 6718.0 6707.0 6702.0 6697.0 6682.5 6672.0 6649.0 6634.5 6614.5 14-DEC-1997 15:16 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6611.0 6610.0 6591 . 0 6590.0 6558.5 6557.5 6539.5 6537.5 6535.0 6532.5 6520. 0 6517 . 5 6450.0 6449.0 6441 . 5 6439.5 6411.5 6411.5 6406.0 6404.0 6368.0 63 67.0 6346.0 6346.0 6340.0 6338.0 6330. 5 6328.5 6315.5 6314.5 6306.5 6305.0 6279.5 6279.5 6267.0 6266.0 6234.0 6234.0 6222.5 6221.5 6215.5 6215.5 6204.5 6204.0 6192.5 6193.0 6172.0 6172.0 6151.0 6151.0 6137.0 6137.5 6128.0 6127.5 6110.0 6110.0 6092.0 6091.0 6059.0 6057.5 6003.0 6002.0 5971.0 5969.5 5965.0 5963.5 5952.0 5950.5 5935.5 5935.0 5921 . 0 5920.5 5919.5 5918.0 5898.5 5897.5 5893.5 5893.0 5884.5 5885.0 5871.5 5871.0 5845.5 5845.0 5806.5 5804.5 5789.5 5787.0 5780.5 5777.5 5751.5 5749.0 14-DEC-1997 15:16 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 164 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NOMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 GR DAS GAPI 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/Fi022704 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US~Fl022704 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 AFIO AIT OH~M1022704 O0 000 O0 0 1 1 1 4 68 0000000000 AF20 AIT 0I~4M1022704 O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT OH~M1022704 O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT OH~M1022704 O0 000 O0 0 1 1 1 4 68 0000000000 AF90 AIT OPiMM1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN OH~M1022704 O0 000 O0 0 1 1 1 4 68 0000000000 f~NOR SDN 0P~4~1022704 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN 0H~1022704 O0 000 O0 0 1 1 1 4 68 0000000000 DEV SDN DEG 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 11 NA~E SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI. dtSS MOD NOlVlB S~'vIP ELI~.I CODE (HEX) T2LMC~I~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 TC24~ ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 KSDR ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 KTIMC?4~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 ClVfi~P ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CMFF ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 BFV ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CFF3 ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CFF4 C~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CFF5 ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 CFF6 ~ 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDAS DEGF 1022704 O0 000 O0 0 1 1 1 4 68 0000000000 14~ES DAS Otflv~f1022704 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13284.000 GR.DAS -999.250 DT.DAS -999.250 DTSH.DAS SCRA.DAS -999.250 AFIO.AIT -999.250 AF20.AIT -999.250 AF30.AIT AF60.AIT -999.250 AF90.AIT -999.250 CNTC. CNT -999.250 CFTC. CNT CRAT. CNT -999.250 NRAT. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT NPHI.CNT -999.250 CPHI.CNT -999.250 CAL1.SDN -999.250 DRHO.SDN PEF. SDN -999.250 RHOB.SDN -999.250 MINV. SDN -999.250 ~INOR.SDN MSFL.SDN -999.250 DEV. SDN -999.250 T2LM. C~R -999.250 TCMR.CMR KSDR.CTVi~ -999.250 KTIM. CT4~ -999.250 C~i~P.~ -999.250 CMFF. CMR BFV. C~4~ -999.250 CFF3.C~i~ -999.250 CFF4.C~i~ -999.250 CFFS.CMR CFF6.C~ -999.250 TENS.DAS 6531.000 TEND.DAS 1194.514 MTEM. DAS Ni~ES.DAS 0.074 DEPT. 4452.000 GR.DAS 30.976 DT. DAS 134.316 DTSH.DAS SCRA.DAS 2.113 AFIO.AIT -999.250 AF20.AIT -999.250 AF30.AIT AF60.AIT -999.250 AF90.AIT -999.250 CNTC. CNT 1485.688 CFTC. CNT CRAT. CNT 4.290 NRAT. CNT 4.384 FCNT. CNT 343.406 NCNT. CNT NPHI. CNT 57.473 CPHI.CNT 54.849 CAL1.SDN 8.632 DRHO. SDN PEF. SDN 9.943 RHOB.SDN 4.189 MINV. SDN 0.179 ~INOR.SDN MSFL.SDN 0.201 DEV. SDN 52.671 T2LM. C~IR -999.250 TCME.CMR KSDR.C~i~ -999.250 KTIM. C~i~ -999.250 C~i~P.~ -999.250 CMFF. CMR BFV. C~ -999.250 CFF3.Clvi~ -999.250 CFF4.CT4~ -999.250 CFFS.CMR CFF6. C~i~ -999.250 TENS.DAS 1928.000 TEND.DAS 936.725 MTEM. DAS M~ES.DAS 1.346 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 181 311 283.791 -999.250 354.352 1515.203 1.296 0.181 -999.250 -999.250 -999.250 75.121 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 12 **** FILE T~ILER **** FILE NAi~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLEMAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~LARY LDWG TOOL CODE DAS CNT $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (FiEASURED DEPTH) START DEPTH STOP DEPTH 4452.0 3908.0 12911.0 4340.0 BASELINE DEPTH 88888.0 13115.5 13111.5 13108.5 13095.0 13074.5 13066.5 13063.0 13051.5 13039.5 13034.5 13029.5 13020.0 13018.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... DAS CNT 88888.5 88887.5 13116.0 13112.5 13109.0 13095.5 13075.0 13067.0 13064.0 13052.0 13040.5 13036.0 13030.5 13021.5 13019.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 13 13011.0 13012.0 13008.0 13009.5 12997.0 12997.0 12981.5 12982.0 12977.5 12976.5 12965.0 12965.5 12946.0 12946.5 12931.5 12931.5 12929.5 12930.0 12915.0 12913.5 12910.5 12910.0 12904.0 12903.0 12889.0 12887.0 12881.0 12879.5 12870.0 12869.5 12095.5 12095.0 12086.0 12087.5 12079.5 12080.5 12075.0 12076.0 12066.0 12066.5 12063.0 12063.5 12056.0 12054.5 12048.0 12047.5 12045.5 12047.5 12043.0 12045.5 12036.5 12038.5 12027.5 12027.0 12021.0 12022.0 12012.0 12013.0 12004.5 12004.5 11986.0 11986.5 11984.0 11984.0 11980.0 11980.0 11976.5 11975.5 11967.5 11968.0 11950.5 11951.0 11937.5 11937.0 11914.5 11916.0 11912.5 11913.0 11894.5 11894.0 11892.5 11892.5 11889.0 11890.5 11885.5 11886.0 11877.5 11877.5 11871.0 11870.5 11867.5 11869.5 11862.0 11864.0 11860.0 11862.0 11855.0 11855.0 11847.0 11848.0 11838.5 11839.0 11837.5 11836.5 11829.5 11829.0 11823.0 11825.0 11810.0 11810.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11786.0 11751.5 11723.0 11695.0 11661.5 11653.5 11650.5 11645.5 11637.0 11631.0 11613.5 11609.0 11598.5 11594.0 11581.5 11576.5 11570.0 11568.0 11559.0 11537.5 11516.5 11497.5 11437.0 11414.0 11398.5 11391.0 11367.0 11328.5 11298.0 11284.5 11253.5 11249.0 11242.5 11230.0 11183.0 11132.5 11122.0 11066.5 11025.5 11003.0 10983.5 10840.5 10816.5 10807.5 10762.5 10736.0 10723.0 10693.0 10656.0 10640.5 10598.0 10566.0 10563.5 10552.5 10489.0 11786.5 11751.5 11723.0 11695 0 11662 0 11654 0 11650 5 11644 5 11637 0 11631 0 11613 5 11608 5 11599 0 11594 0 11580 5 11577 5 11571 5 11568 5 11558 5 11539 0 11517 5 11497.5 11437.5 11413.5 11398.5 11390.5 11367.5 11328.0 11297.0 11284.5 11253.0 11250.0 11244.0 11231.0 11182.5 11132.5 11120.5 11066.5 11025.5 11003.5 10983.5 10840.0 10815.5 10807.5 10762.5 10737.0 10723.0 10692.5 10655.0 10640.5 10597.0 10566.5 10562.5 10551.0 10488.5 14-DEC-1997 15:16 PAGE: 14 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10439.0 10392 5 10347 5 10206 0 10141 0 10122 5 10114 0 10050 5 10040 0 9998 5 9947 0 9901 5 9875 0 9798 0 9774 0 9739.0 9680.0 9653.0 9642.0 9638.5 9608.5 9583.0 9557.5 9549.5 9540.0 9529.0 952 6.5 9506.5 9473.5 9454.5 9411.5 9409.5 9385.0 9335.0 9306.5 9266.5 9241.5 9216.5 921 O. 5 9199.5 9185.0 9141.5 9130.0 9110.5 9088.5 9055.0 9032.5 9016.0 8997.0 8939.0 8916.0 8904.5 8894.0 8874.0 8855.0 10438.5 10391.5 10348.0 10205.5 10141.0 10124.0 10114.0 10051.0 10039.0 9998.0 9945.5 9901.0 9874.0 9798.0 9773.0 9738.0 9678.0 9651.5 9641.5 9636.5 9606.5 9581.0 9555.5 9547.5 9538.5 9525.5 9523.0 9505.0 9474.5 9453.0 9411.0 9408.5 9385.0 9335.0 9305.5 9266.5 9241.5 9216.0 921 O. 5 9198.5 9183.0 9140.0 9129.0 9109.0 9087.5 9052.5 9031.0 9015.0 8994.5 8937.5 8915.0 8903.5 8893.0 8873.0 8855.5 14-DEC-1997 15:16 PAGE: 15 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8837.0 8815.5 8804.5 8793.0 8779.0 8769.0 8739.5 8734.0 8721.5 8716.5 8714.5 8712.5 8703 5 87OO 5 8689 0 8682 5 8654 0 8637 5 8628 0 8624 5 8620 0 8606.5 8585 0 8582 0 8572 0 8565 5 8542 5 8534 0 8528 0 8522 0 8510 0 8503 0 8498 5 8496.0 8494 5 8480 5 8465 0 8456 5 8449 0 8440 0 8429 5 8410 0 8399 5 8389 5 8372 0 8363 5 8360 0 8344.5 8334.5 8323.0 8317.0 8299.0 8289.0 8276.5 8215.5 8837.5 8815.5 8803.5 8792 0 8779 5 8766 5 8737 5 8732 5 8720 0 8716 5 8714 0 8711 5 8702 5 8699 0 8687 5 8681 5 8653 5 8637 0 8628 0 8625 0 8619 5 8605 5 8585 5 8582 0 8571 5 8564 5 8541 5 8531 0 8527 0 8522 5 8510 0 8502 5 8498 5 8496.5 8492.5 8478.0 8463.5 8456.0 8448 0 8440 0 8429 5 8409 5 8398 5 8390 0 8372 0 83 64 0 8360 0 8345 5 8334 0 8322 5 8317 0 8299 0 8290 0 8277 5 8216.0 14-DEC-1997 15:16 PAGE: 16 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8212.5 8198.5 8175.0 8164.0 8161.5 8142.0 8128.5 8124.5 8103.5 8095.0 8081.5 8074.0 8072 5 8061 5 8041 5 8012 5 7983 0 7973 5 7950 0 7927 0 7921 5 7915 5 7895 0 7884 5 7877 5 7869 0 7862 0 7845 0 7833 0 7819 0 7807 0 7784 5 7771 5 7768 0 7760 0 7751 0 7743 5 7742 0 7726.0 7704 5 7702 5 7675 0 7668 5 7665 0 7662 5 7659.5 7648.5 7626.5 7580.5 7568.5 7565.0 7547.5 7490.5 7468.5 7446.5 8212 0 8198 5 8174 5 8164 0 8161 5 8141 5 8128 5 8125 0 8103 5 8095.0 8081.0 8074.0 8072.0 8061.5 8041.0 8012.5 7983.0 7973.5 7950.0 7927.0 7921.5 7915.5 7894.5 7884.5 7878.5 7868.5 7864.0 7845.5 7833.5 7819.5 7807.5 7783.5 7771.0 7767.0 7759.5 7750.5 7744.0 7741.5 7726.0 7704.5 7702.5 7674.5 7668.5 7665.0 7662.0 7659.0 7648.5 7627.0 7580.5 7567.5 7563.0 7547.0 7490.0 7468.5 7447.0 14-DEC-1997 15:16 PA GE: 17 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7436.5 7422.5 7396.5 7391.0 73 66.0 7334.5 7322.5 7292.0 7286.0 7278.5 7267.0 7251.5 7250.0 723 6 5 7220 5 7181 0 7179 5 7168 5 7154 0 7136 5 7105 5 71 O1 5 7085 5 7075 0 7062 5 7035 0 7012 0 6992 5 6954 5 6933 5 6904 0 6857 5 6847 5 6826.5 6774.5 6758.0 6746.5 6744.0 6727.0 6718.5 6708.5 6704.0 6696.0 6682 0 6671 0 6649 5 6635 0 6614 5 6611 0 6591 0 6558 5 6539.5 6535.0 6520.0 6450.0 7436 0 7423 0 7396 5 7391 0 73 66 0 7335 0 7322 5 7291 5 7286.5 7278.0 7267.0 7252.0 7249.5 7236.5 7220.5 7181.0 7179.0 7169.0 7153.5 7135.5 7104.5 71 O1.5 7O85.0 7076.0 7061.5 7033.5 7011.5 6991.5 6953.5 6933.5 6904.0 6857.5 6847.5 6825.5 6773.5 6757.5 6746.5 6742.5 6726.0 6718.0 6707.0 6702.0 6697.0 6682.5 6672.0 6649.0 6634.5 6614.5 661 O. 0 6590.0 6557.5 6537.5 6532.5 6517.5 6449.0 14-DEC-1997 15:16 PAGE: 18 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 19 6441.5 6439.5 6411.5 6411.5 6406.0 6404.0 6368.0 6367.0 6346.0 6346.0 6340.0 6338.0 6330.5 6328.5 6315.5 6314.5 6306.5 6305.0 6279.5 6279.5 6267.0 6266.0 6234.0 6234.0 6222.5 6221.5 6215.5 6215.5 6204.5 6204 . 0 6192.5 6193 . 0 6172.0 6172.0 6151.0 6151.0 6137.0 6137.5 6128.0 6127.5 6110.0 6110.0 6092.0 6091.0 6059.0 6057.5 6003.0 6002.0 5971 . 0 5969 . 5 5965.0 5963.5 5952.0 5950.5 5935.5 5935 . 0 5921.0 5920.5 5919.5 5918.0 5898 . 5 5897.5 5893.5 5893.0 5884.5 5885.0 5871.5 5871.0 5845.5 5845.0 5806.5 5804.5 5789.5 5787.0 5780.5 5777.5 5751.5 5749.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 2O TYPE REPR CODE VALUE 7 65 8 68 O. 5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH USIT GAPI 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DAS GAPI 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 DT DAS US/F 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 DTSH DAS US/F 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 SCRADAS 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DAS LB 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DAS LB 1022704 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13224.000 GRCH. USIT -999.250 GRCH.DAS -999.250 DT. DAS DTSH.DAS -999.250 SCRA.DAS -999.250 CNTC. CNT -999.250 CFTC. CNT CRAT. CNT -999.250 NRAT. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT NPHI.CNT -999.250 CPHI.CNT -999.250 TENS.DAS -999.250 TEND.DAS DEPT. 3880.000 GRCH. USIT -999.250 GRCH.DAS 30.220 DT. DAS DTSH.DAS -999.250 SCRA.DAS -999.250 CNTC. CNT -999.250 CFTC. CNT CRAT. CNT -999.250 NRAT. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT NPHI.CNT -999.250 CPHI.CNT -999.250 TENS.DAS -999.250 TEND.DAS -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 21 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE RUN NUMBER '. TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~VARY FILE HEADER FILE NIIM~ER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 2 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13279.0 12908.0 PEX 13254.0 12908.0 BHC 13234.0 12908.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL NUlviBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 22 AIT PEX BHC $ ARRAY INDUCTION PLATFORM EXPRESS BOREHOLE COMP. SONIC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : AITH HILTB DSLT 6.000 12906.0 12911.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C34R & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW MAIN LOG DATA FOR RUN #2 SAMPLED AT 0.5'. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 TENS AIT LB 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 GR AIT GAPI 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT PEX CPS 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI PEX DEG 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 HTEN AIT LB 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 MRES AIT OH~q1022704 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 MTEM PEX DEGF 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F 1022704 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13308.000 TENS.AIT 3658.000 CNTC.PEX 3627.631 CFTC.PEX TNRA.PEX 1.847 GR.AIT 34.941 RTNR.PEX 1.936 RCFT. PEX RCNT. PEX 3532.673 DEVI. PEX -999.250 HTEN. AIT -3.045 I~RES.AIT NPHI.PEX 19.540 TNPH. PEX 18.695 NPOR.PEX 18.495 MTEM. PEX 1981.317 1809.058 0.074 181.311 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 24 DT.BHC 88.086 DEPT. 12911.000 TENS.AIT TNRA.PEX 3.695 GR.AIT RCNT. PEX 1269.462 DEVI. PEX NPHI.PEX 49.321 TNPH. PEX DT. BHC 64.271 6246.000 CNTC.PEX 80.739 RTNR.PEX 22.093 HTEN. AIT 46.117 NPOR.PEX 1359.642 CFTC. PEX 3.740 RCFT. PEX 1028.287 MRES.AIT 46.042 MTE~.PEX 376.031 359.906 0.058 171.841 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 mATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 2 TOOL STRING NU~BER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13279.0 12908.0 PEX 13254.0 12908.0 BHC 13234.0 12908.0 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 25 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ TOOL NUMBER AITH HILTB DSLT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 6.000 12906.0 12911.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (OH~9~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RU/%/ 2 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/C~R. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW MAIN LOG DATA FOR RUN #2 SAMPLED AT 0.25'. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 2 6 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUAiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1022704 O0 000 O0 0 4 1 1 4 68 0000000000 AIBD AIT IN 1022704 O0 000 O0 0 4 1 1 4 68 0000000000 AFiO AIT OP~4M1022704 O0 000 O0 0 4 1 1 4 68 0000000000 AF20 AIT 0H~4~1022704 O0 000 O0 0 4 1 1 4 68 0000000000 AF30 AIT 0H~1022704 O0 000 O0 0 4 1 1 4 68 0000000000 AF60 AIT 0HN~1022704 O0 000 O0 0 4 1 1 4 68 0000000000 AF90 AIT OHMM1022704 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13308.000 AIBD.AIT 5.508 AFiO.AIT 3.816 AF20.AIT AF30.AIT 4.553 AF60.AIT 4.615 AF90.AIT 3.618 3. 802 ** END OF DATA ** LIS Tape verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 27 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUNff4ARY FILE HEADER FILE NUMBER 5 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 2 1 1 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13279.0 12908.0 PEX 13254.0 12908.0 BHC 13234.0 12908.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOLNUMBER LIS Tape Ve~i'fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 28 AIT PEX BHC $ ARRAY INDUCTION PLATFORM EXPRESS BOREHOLE COMP. SONIC AITH HILTB DSLT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 12906.0 12911.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) '. THERMAL SANDS TOiFE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C~R & CArL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTE~ WITH PEX/C~iR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW MAIN LOG DATA FOR RUN #2 SAMPLED AT O. 1667 ' . $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 29 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1022704 HDRA PEX G/C3 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 PEFZ PEX 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 RHOZ PEX G/C3 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 HMIN PEX OH~4~ 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 H~iNO PEX 0P~41022704 O0 000 O0 0 5 1 1 4 68 0000000000 RXOZ PEX 0H~94 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 RX08 PEX OH~4~ 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 HCNT PEX CPS 1022704 O0 000 O0 0 $ 1 1 4 68 0000000000 HCFT PEX CPS 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 HGR PEX GAPI 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 RHFT PEX CPS 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 RHNT PEX CPS 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 TT1 BHC US 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 TT2 BHC US 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 TT3 BHC US 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 TT4 BHC US 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 DPHZ PEX PU 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 HTNP PEX PU 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 HNPO PEX PU 1022704 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape V~e'~ification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE 3O DEPT. 13308.000 HDRA.PEX -999.250 PEFZ.PEX HMIN. PEX 0.248 H~4NO.PEX 0.365 RXOZ.PEX HCNT. PEX 3627.631 HCFT. PEX 1981.317 HGR.PEX RHNT. PEX 3532.673 TT1.BHC 543.984 TT2.BHC TT4.BHC 374.063 DPHZ.PEX 60721.211 HTNP.PEX -999.250 RHOZ.PEX 1.046 RXO8.PEX 34.941 RHFT. PEX 365.781 TT3.BHC 18.695 HNPO. PEX -999.250 1.045 1809.058 548.203 18.495 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 6 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O. 0833 FILE SU~mL~RY VENDOR TOOL CODE START DEPTH AIT 13279.0 PEX 13254.0 BHC 13234.0 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 12908.0 12908.0 12908.0 24-NOV-97 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 31 SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ TOOL NUMBER ........... AITH HILTB DSLT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 6.000 12906.0 12911.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 192.0 RESISTIVITY (Oh?4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT) '. MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C~IR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/C?4R. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THERAWMAIN LOG DATA FOR RUN #2 SAMPLED AT 0.0833'. $ LIS Tape ~e~fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 32 LIS FOIAV~AT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NURiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 6 1 1 4 68 0000000000 HCAL PEX IN 1022704 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 13308.000 HCAL.PEX 5.508 ** END OF DATA ** LIS Tape ~e~fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 33 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~ff4ARY FILE HEADER FILE NUMBER 7 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12123.0 4456.0 DSI 12112.0 3920.0 PEX 12106.0 4456.0 ~ 11936.0 9280.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE lO-NOV-97 8C0-609 1230 9-NOV-97 1300 12-NOV-97 12132.0 12132.0 3920.0 12123.0 1800.0 TOOL NUM~ER .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 34 AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA C~R COMB. MAGNETIC RESONANCE C~RT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) .. 62.0 MUD PH : 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OHF~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1.530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1.370 MUD CAKE AT (BHT) : 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMzARKS: ************ RUN1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C~R & CArL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEMWITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THERAWMAIN LOGS FOR RUN #1 SAMPLED AT 0.5'. $ LIS FORMAT DATA LIS Tape ~e~ification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 35 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PEX LB 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PEX CPS 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PEX CPS 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PEX 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 GR PEX GAPI 1022704 O0 000 O0 0 7 i 1 4 68 0000000000 RTNR PEX 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PEX CPS 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PEX CPS 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 DEVI PEX DEG 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 HTEN PEX LB 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 MRES PEX OHMM 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 MTEM PEX DEGF 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PEX PU 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PEX PU 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PEX PU 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 GR DSI GAPI 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 DTCO DSI US/F 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 DTSM DSI US/F 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 PR DSI 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 RSHC DSI 1022704 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Ve~i'fication Listing Schlumberger Alaska Computing Center I4-DEC-1997 15:16 PAGE: 36 DEPT. 13308.500 TENS. PEX TNRA.PEX -999.250 GR.PEX RCNT. PEX -999.250 DEVI.PEX MTEM. PEX -999.250 NPHI.PEX GR.DSI -999.250 DTCO.DSI RSHC.DSI -999.250 DEPT. 4452.000 TENS. PEX TNRA.PEX 4.323 GR.PEX RCNT. PEX 1427.382 DEVI.PEX MTE~.PEX 85.964 NPHI.PEX GR.DSI 30.976 DTCO.DSI RSHC.DSI 2.113 -999.250 CNTC.PEX -999.250 RTNR.PEX -999.250 HTEN. PEX -999.250 TNPH. PEX 88.086 DTSM.DSI 2117. 000 CNTC. PEX 33 . 809 RTNR. PEX 52. 694 HTEN. PEX 58.275 TNPH . PEX 134. 316 DTSM.DSI -999.250 CFTC. PEX -999.250 RCFT. PEX -999.250 14RES.PEX -999.250 NPOR.PEX -999.250 PR.DSI 1446.834 CFTC.PEX 3.885 RCFT. PEX 1275.309 lVlRES.PEX 53.483 NPOR.PEX 283.791 PR.DSI -999.250 -999.250 -999.250 -999.250 -999.250 349.708 283.073 1.334 53.139 0.356 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION : O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION : O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files;-Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SDP94ARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape V~fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 37 AIT 12123.0 4456.0 DSI 12112.0 3920.0 PEX 12106.0 4456.0 CMR 11936.0 9280.0 $ LOG HEADER DATA DATE LOGGED: 1 O-NOV-97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 1230 9-NOV-97 TIME LOGGER ON BOTTOM: 1300 12-NOV-97 TD DRILLER (FT) : 12132.0 TD LOGGER (FT) : 12132.0 TOP LOG INTERVAL (FT) : 3920.0 BOTTOM LOG INTERVAL (FT) : 12123.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL 1VUlVZBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA CMR COMB. MAGNETIC RESONANCE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH: 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OPiMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 370 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): THERMAL SANDSTONE 2.65 1.0 70.0 70.0 70.0 LIS Tape Ve-~i'kication Listing Schlumberger Alaska Computing Cen~er 14-DEC-1997 15:16 PAGE: 38 REMARKS: ************ RUN1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C~R & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAWMAIN LOGS FOR RUN #1 SAMPLED AT 0.25'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 8 1 1 4 68 0000000000 AIBD AIT IN 1022704 O0 000 O0 0 8 1 1 4 68 0000000000 AFiO AIT OHNM1022704 O0 000 O0 0 8 1 1 4 68 0000000000 AF20 AIT 0H~941022704 O0 000 O0 0 8 1 1 4 68 0000000000 AF30 AIT 0H~941022704 O0 000 O0 0 8 1 1 4 68 0000000000 AF60 AIT OPff4M1022704 O0 000 O0 0 8 1 1 4 68 0000000000 AF90 AIT OH~4M1022704 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape V~r-~fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 39 ** DATA ** DEPT. 12128.000 AIBD.AIT AF30.AIT 1.493 AF60.AIT 10.825 AFiO.AIT 1.493 AF90.AIT 1.270 AF20.AIT 1.451 1.458 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 9 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O. 1667 FILE SUM~N~Y VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12123.0 4456.0 DSI 12112.0 3920.0 PEX 12106.0 4456.0 CMR 11936.0 9280.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: lO-NOV-97 8C0-609 LIS Tape Verl'~ication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 40 TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 1230 9-NOV-97 1300 12-NOV-97 12132.0 12132.0 3920.0 12123.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA C~R COMB. MAGNETIC RESONANCE C~f~T $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH : 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1.530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 370 MUD CAKE AT (BHT) : 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEMWITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAWMAIN LOGS FOR RUN #1 SAMPLED AT 0.1667'. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 41 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 HDRA PEX G/C3 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 PEFZ PEX 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 PEF8 PEX 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 RHOZ PEX G/C3 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 RH08 PEX G/C3 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 HMIN PEX OH~4M 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 H~NO PEX OH~4M 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 RXOZ PEX OHT4~ 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 RX08 PEX OPff4~1022704 O0 000 O0 0 9 1 1 4 68 0000000000 HCNT PEX CPS 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 HCFT PEX CPS 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 HGR PEX GAPI 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 RHFT PEX CPS 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 RHNT PEX CPS 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 DPHZ PEX PU 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 HTNP PEX PU 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 HNPO PEX PU 1022704 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape V~ification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 42 ** DATA ** DEPT. 12128.000 HDRA.PEX RHOZ.PEX -999.250 RHO8.PEX RXOZ.PEX 1.732 RXO8.PEX HGR.PEX 203.943 RHFT. PEX HTNP. PEX 47.666 HNPO.PEX -999.250 PEFZ.PEX -999.250 HMIN. PEX 1.749 HCNT. PEX 458.558 RHNT. PEX 46.947 -999.250 PEFS.PEX 1.665 HFiNO. PEX 1858.948 HCFT. PEX 1848.273 DPHZ.PEX -999.250 1.435 477.448 60721.211 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION · O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 10 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed byfiles for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 FILE SUMMARY VENDOR TOOL CODE START DEPTH AIT 12123.0 DSI 12112.0 PEX 12106.0 CqvlR 11936.0 $ STOP DEPTH .......... 4456.0 3920.0 4456.0 9280.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 43 LOG HEADER DATA DATE LOGGED: 1 O-NOV-97 SOFTWARE VERSION: 8C0- 609 TIME CIRCULATION ENDED: 1230 9-NOV-97 TIME LOGGER ON BOTTOM: 1300 12-NOV-97 TD DRILLER (FT) : 12132.0 TD LOGGER (FT) : 12132.0 TOP LOG INTERVAL (FT) : 3920.0 BOTTOM LOG INTERVAI~ (FT) : 12123.0 LOGGING SPEED (FPHR): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA ~ COMB. MAGNETIC RESONANCE C~RT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH: 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1.690 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1.530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 370 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL).. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: THERMAL SANDSTONE 2.65 1.0 70.0 70.0 70.0 ************ RUN1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON ~ & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEMWITH PEX/CM~. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THERAWMAIN LOGS FOR RUN LIS Tape V~rhfication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 44 #1 SAMPLED AT O. 0833 '. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NURIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 10 1 1 4 68 0000000000 HCAL PEX IN 1022704 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 12128. 000 HCAL. PEX 10. 825 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 45 **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 11 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUN~4A~Y VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13279.0 12908.0 PEX 13254.0 12908.0 BHC 13234.0 12908.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.O TOOL NUMBER AITH HILTB LIS Tape verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 46 BHC $ BOREHOLE COMP. SONIC DSLT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 12906.0 12911.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (OHI4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CArL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT #2 SAMPLED AT O. 5'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 47 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PEX LB 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 CNTC PEX CPS 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 CFTC PEX CPS 1022704 O0 000 O0 0 1i 1 1 4 68 0000000000 TNRA PEX 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 GR PEX GAPI 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 RTNR PEX 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 RCFT PEX CPS 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 RCNT PEX CPS 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 DEVI PEX DEG 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 HTENPEX LB 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 MRES PEX OHMM1022704 O0 000 O0 0 11 1 1 4 68 0000000000 NPHI PEX PU 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 TNPH PEX PU 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 NPOR PEX PU 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 MTEMPEX DEGF 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 DT BHC US/F 1022704 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 13317.000 TENS.PEX 1912.000 CNTC.PEX 4880.569 CFTC.PEX TNRA.PEX 1.850 GR.PEX 19.966 RTNR.PEX 1.939 RCFT.PEX RCNT.PEX 4744.269 DEVI.PEX -999.250 HTEN. PEX -63.006 NIRES.PEX NPHI.PEX 19.480 TNPH. PEX 18.909 NPOR.PEX 18.760 MTEM. PEX DT.BHC 86.953 DEPT. 12911.000 TENS.PEX 6152.000 CNTC. PEX 1351.921 CFTC. PEX TNRA.PEX 3.510 GR.PEX 96.208 RTNR.PEX 3.337 RCFT. PEX RCNT. PEX 1473.043 DEVI.PEX 22.137 HTEN. PEX 999.837 IZiRES.PEX NPHI.PEX 45.857 TNPH. PEX 41.192 NPOR.PEX 37.395 MTEM. PEX 2643.845 2405.167 0.074 182.653 408.643 412.288 0.060 171.962 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 48 DT. BHC 148.083 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUM~N~Y FILE HEADER FILE NUMBER 12 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 2 1 2 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13279.0 12908.0 PEX 13254.0 12908.0 BHC 13234.0 12908.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) 24 -NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 49 LOGGING SPEED (FPHR): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ TOOL NTIM~ER AITH HILTB DSLT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 12906.0 12911.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (OH~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64. 0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 RE'lARKS: ************ RUN2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEMWITH PEX/C~iR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT #2 SAMPLED AT O. 25 ' . $ LIS FORMAT DATA LIS Tape verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 50 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NTJM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 12 1 1 4 68 0000000000 AIBD AIT IN 1022704 O0 000 O0 0 12 1 1 4 68 0000000000 AFiO AIT 0HFi~I1022704 O0 000 O0 0 12 1 1 4 68 0000000000 AF20 AIT 0H~941022704 O0 000 O0 0 12 1 1 4 68 0000000000 AF30 AIT OHIqM1022704 O0 000 O0 0 12 1 1 4 68 0000000000 AF60 AIT OH~M1022704 O0 000 O0 0 12 1 1 4 68 0000000000 AF90 AIT OHF~q1022704 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 13317.000 AIBD.AIT 5.626 AFiO.AIT 3.965 AF20.AIT AF30.AIT 5.564 AF60.AIT 4.565 AF90.AIT 3.680 5. 790 ** END OF DATA ** LIS Tape V~fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 51 **** FILE TRAILER **** FILE NAME .. EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION .. 001 CO 1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 13 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT.. O. 1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH AIT 13279.0 PEX 13254.0 BHC 13234.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 12908.0 12908.0 12908.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL NUMBER AITH HILTB LIS Tape V~i'fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 52 BHC $ BOREHOLE COMP. SONIC DSLT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 6.000 12906.0 12911.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (0~) AT TEMPERATURE (DEGF) '. MUD AT MEASURED TEMPERATURE (MT): O. 139 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT): MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C~!R & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT #2 SAMPLED AT 0.1667'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 LIS Tape VerSification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 53 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HDRA PEX G/C3 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 PEFZ PEX 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 RHOZ PEX G/C3 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HMIN PEX OH~4M 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HMNO PEX OH~E4 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 RXOZ PEX OH~4~ 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 RX08 PEX OHIO4 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HCNT PEX CPS 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HCFT PEX CPS 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HGR PEX GAPI 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 RHFT PEX CPS 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 RHNTPEX CPS 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 TT1 BHC US 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 TT2 BHC US 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 TT3 BHC US 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 TT4 BHC US 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 DPHZ PEX PU 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HTNP PEX PU 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 HNPO PEX PU 1022704 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 13317.000 HDRA.PEX -999.250 PEFZ.PEX H~IN. PEX 0.322 HMNO.PEX 0.448 RXOZ.PEX HCNT. PEX 4880.569 HCFT. PEX 2643.845 HGR.PEX RHNT. PEX 4744.269 TT1.BHC 546.641 TT2.BHC TT4.BHC 372.969 DPHZ.PEX 60721.211 HTNP.PEX -999. 250 RHOZ. PEX 1. 575 RX08 . PEX 19.966 RHFT. PEX 375. 859 TT3 .BHC 18. 909 HNPO. PEX -999.250 1.578 2405.167 550.000 18.760 LIS Tape Ver~'~fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 54 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMFiARY FILE HEADER FILE NUMBER 14 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 2 1 2 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13279.0 12908.0 PEX 13254.0 12908.0 BHC 13234.0 12908.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 55 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) '. MUD CAKE AT (MT): MUD CAKE AT (BHT) : TOOL NUMBER AITH HILTB DSLT 6.000 12906.0 12911.0 KCL 9.70 55.0 9.1 192.0 0.139 70.0 O. 123 64.0 O. 221 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT #2 SAMPLED AT 0.0833'. $ LIS FORMAT DATA LIS Tape Ve~i'fication Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 56 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 14 1 1 4 68 0000000000 HCAL PEX IN 1022704 O0 000 O0 0 14 1 1 4 68 0000000000 ** DATA ** DEPT. 13317. 000 HCAL. PEX 5. 626 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 57 **** FILE HEADER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 15 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~94ARY VENDOR TOOL CODE START DEPTH AIT 13279.0 PEX 13254.0 BHC 13234.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 12908.0 12908.0 12908.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL NUMBER AITH HILTB DSLT 6.000 12906.0 12911.0 KCL LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 58 MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (OH~ff~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (I4T) : 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) '. THERMAL SA_NDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON ~ & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/C~4~. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT #1 SAMPLED AT 0.5 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 59 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 TENS PEX LB 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 CNTC PEX CPS 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 CFTC PEX CPS 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 TNRA PEX 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 GR PEX GAPI 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 RTNR PEX 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 RCFT PEX CPS 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 RCNT PEX CPS 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 DEVI PEX DEG 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 HTEN PEX LB 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 MRES PEX OH~4~ 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 NPHI PEX PU 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 TNPH PEX PU 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 NPOR PEX PU 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 MTEMPEX DEGF 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 DT BHC US/F 1022704 O0 000 O0 0 15 1 1 4 68 0000000000 ** DATA ** DEPT. 13314.000 TENS.PEX 3316.000 CNTC. PEX 3778.105 CFTC. PEX TNRA.PEX 1.799 GR.PEX 74.335 RTNR.PEX 1.886 RCFT. PEX RCNT. PEX 3678.182 DEVI.PEX -999.250 HTEN. PEX -87.308 MRES. PFJf NPHI.PEX 18.596 TNPH. PEX 17.963 NPOR.PEX 17.776 MTEM. PEX DT.BHC 87.734 2117.393 1931.492 0.083 181.092 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape VerSification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 6O **** FILE HEADER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 16 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUN, VARY VENDOR TOOL CODE START DEPTH AIT 13279.0 PEX 13254.0 BHC 13234.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 12908.0 12908.0 12908.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL NUAiBER AITH HILTB DSLT 6.000 12906.0 12911.0 KCL LIS Tape VerSification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE 61 MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (OIfl~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 139 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 RE~L~RKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON ~ & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CM~. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT #1 SAMPLED AT 0.25'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 25 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 62 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD N73M~ SAMP ELE~ CODE (HEX) DEPT FT 1022704 O0 000 O0 0 16 1 1 4 68 0000000000 AIBD AIT IN 1022704 O0 000 O0 0 16 1 1 4 68 0000000000 AFiO AIT 0HM~1022704 O0 000 O0 0 16 1 1 4 68 0000000000 AF20 AIT OHlV~Vl1022704 O0 000 O0 0 16 1 1 4 68 0000000000 AF30 AIT 0H1~1022704 O0 000 O0 0 16 1 1 4 68 0000000000 AF60 AIT OHFk41022704 O0 000 O0 0 16 1 1 4 68 0000000000 AF90 AIT 0H~941022704 O0 000 O0 0 16 1 1 4 68 0000000000 ** DATA ** DEPT. 13314.000 AIBD.AIT 5.767 AFiO.AIT 3.173 AF20.AIT AF30.AIT 6.453 AF60.AIT 3.828 AF90.AIT 2.667 7.307 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .016 SERVICE · FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .017 SERVICE ' FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14~DEC-1997 15:16 PAGE: 63 FILE HEADER FILE NUMBER 17 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 FILE SO?4MARY VENDOR TOOL CODE START DEPTH AIT 13279.0 PEX 13254.0 BHC 13234.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 12908.0 12908.0 12908.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) '. DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT) '. MUD CAKE AT (BHT) : 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL NUMBER AITH HILTB DSLT 6.000 12906.0 12911.0 KCL 9.70 55.0 9.1 192.0 0.139 70.0 0.123 64.0 0.221 64.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 64 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CArL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CFiR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT #1 SAMPLED AT 0.1667'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 HDRA PEX G/C3 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 LIS Tape verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 65 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) PEFZ PEX 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 RHOZ PEX G/C3 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 HMIN PEX OHMM 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 H~NO PEX OHFk41022704 O0 000 O0 0 17 1 1 4 68 0000000000 RXOZ PEX OHFiM 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 RX08 PEX OH~ 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 HCNT PEX CPS 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 HCFT PEX CPS 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 HGR PEX GAPI 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 RHFT PEX CPS 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 RHNT PEX CPS 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 TT1 BHC US 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 TT2 BHC US 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 TT3 BHC US 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 TT4 BHC US 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 DPHZ PEX PU 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 HTNP PEX PU 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 HNPO PEX PU 1022704 O0 000 O0 0 17 1 1 4 68 0000000000 ** DATA ** DEPT. 13314.000 HDRA.PEX -999.250 PEFZ.PEX -999.250 RHOZ.PEX I~4IN. PEX 0.803 H~iNO.PEX 0.910 RXOZ.PEX 1.403 RXO8.PEX HCNT. PEX 3778.105 HCFT. PEX 2117.393 HGR.PEX 74.335 RHFT. PEX RHNT. PEX 3678.182 TT1.BHC 551.406 TT2.BHC 376.250 TT3.BHC TT4.BHC 370.234 DPHZ.PEX 60721.211 HTNP.PEX 17.963 HNPO.PEX -999.250 1.408 1931.492 546.016 17.776 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .017 SERVICE . FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 66 **** FILE HEADER **** FILE NAME : EDIT . O18 SERVICE · FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 18 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 FILE SUb~IARY VENDOR TOOL CODE START DEPTH AIT 13279.0 PEX 13254.0 BHC 13234.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 12908.0 12908.0 12908.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS BHC BOREHOLE COMP. SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: 24-NOV-97 8C0-609 2100 23-NOV-97 500 24-NOV-97 13282.0 13287.0 12911.0 13275.0 1800.0 TOOL NUMBER AITH HILTB DSLT 6.000 12906.0 12911.0 KCL LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 67 MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 55.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 192.0 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 0.139 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (~Ff) : O. 123 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 221 MUD CAKE AT (BHT) : 70.0 64.0 64.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 2 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/C~IR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FOR RUN #2 REPEAT ~1 SAMPLED AT O. 0833 ' . $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 68 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1022704 O0 000 O0 0 18 1 1 4 68 0000000000 HCAL PEX IN 1022704 O0 000 O0 0 18 1 1 4 68 0000000000 ** DATA ** DEPT. 13314.000 HCAL.PEX 5.767 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .018 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .019 SERVICE ' FLIC VERSION · O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 19 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 69 PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH AIT 12123.0 DSI 12112.0 PEX 12106.0 CMR 11936.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 4456.0 3920.0 4456.0 9280.0 lO-NOV-97 8C0-609 1230 9-NOV-97 1300 12-NOV-97 12132.0 12132.0 3920.0 12123.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA CMR COMB. MAGNETIC RESONANCE CMRT $ 8.500 4441.0 4452.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH: 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1.530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 370 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE 70.0 70.0 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 70 MATRIX DENSITY: HOLE CORRECTION (IN): 2.65 TOOL STANDOFF (IN): 1.0 REFIARKS: ************ RUN 1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CAUL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CFIR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FROM RUN #1 REPEAT PASS #2 SAMPLED AT 0.5 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 0 66 0 73 64 66 1 66 73 65 68 O. 5 65 FT 66 16 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 TENS PEX LB 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 CNTC PEX CPS 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 CFTC PEX CPS 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 TNRA PEX 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 GR PEX GAPI 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 71 NAME SERV UNIT SERVICE API API API API FILE ~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RTNR PEX 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 RCFT PEX CPS 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 RCNT PEX CPS 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 DEVI PEX DEG 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 HTEN PEX LB 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 ~IRES PEX OH~4 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 MTE~ PEX DEGF 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 NPHI PEX PU 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 TNPH PEX PU 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 NPOR PEX PU 1022704 O0 000 O0 0 19 1 1 4 68 0000000000 ** DATA ** DEPT. 11735.000 TENS.PEX 1881.000 CNTC. PEX 2257.889 CFTC. PEX TNRA.PEX 2.862 GR.PEX 117.874 RTNR.PEX 3.022 RCFT. PEX RCNT. PEX 2239.475 DEVI.PEX -999.250 HTEN. PEX 474.758 MRES.PEX MTEM. PEX 153.628 NPHI.PEX 31.848 TNPH. PEX 32.119 NPOR.PEX DEPT. 10666.500 TENS.PEX 1827.000 CNTC.PEX 2546.218 CFTC. PEX TNRA.PEX 2.710 GR.PEX 101.141 RTNR.PEX 3.258 RCFT. PEX RCNT. PEX 2221.493 DEVI.PEX 52.458 HTEN. PEX 1289.239 MRES.PEX MTEM. PEX 142.713 NPHI.PEX 29.570 TNPH. PEX 29.721 NPOR.PEX 798.813 749.547 0.789 31.671 953. 209 691. 552 O. 966 28. 024 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .019 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .020 SERVICE · FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 72 RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUb~U~EY FILE HEADER FILE NUMBER 20 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12123.0 4456.0 DSI 12112.0 3920.0 PEX 12106.0 4456.0 Ct4~ 11936.0 9280.0 $ LOG HEADER DATA DATE LOGGED: 10 -NOV- 97 SOFTWARE VERSION: 8C0- 609 TIME CIRCULATION ENDED: 1230 9-NOV-97 TIME LOGGER ON BOTTOM: 1300 12-NOV-97 TD DRILLER (FT) : 12132.0 TD LOGGER (FT) : 12132.0 TOP LOG INTERVAL (FT) : 3920.0 BOTTOM LOG INTERVAL (FT) : 12123.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA CMR COMB. MAGNETIC RESONANCE CblRT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : 8.500 4441.0 4452.0 LSND 10.40 62.0 8.8 181.0 1.690 70.0 1.530 70.0 LIS Tape verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 73 MUD CAKE AT (MT): MUD CAKE AT (BHT) : 1.370 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 RE,LARKS: ************ RUN 1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTE~ WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FROM RUN #1 REPEAT PASS #2 SAMPLED AT O. 25 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 74 ** SET TYPE ~ CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX) DEPT FT 1022704 AIBD AIT IN 1022704 AFIO AIT OH~M 1022704 AF20 AIT Okk~ 1022704 AF30 AIT OHN~I 1022704 AF60 AIT OH~ 1022704 AF90 AIT OH~t 1022704 O0 000 O0 0 20 1 1 4 68 0000000000 O0 000 O0 0 20 1 1 4 68 0000000000 O0 000 O0 0 20 1 1 4 68 0000000000 O0 000 O0 0 20 1 1 4 68 0000000000 O0 000 O0 0 20 1 1 4 68 0000000000 O0 000 O0 0 20 1 1 4 68 0000000000 O0 000 O0 0 20 1 1 4 68 0000000000 ** DATA ** DEPT. 11735.000 AIBD.AIT 8.500 AFiO.AIT 22.046 AF20.AIT AF30.AIT 72.981 AF60.AIT 75.626 AF90.AIT 61.588 DEPT. 10667.250 AIBD.AIT 8.500 AFiO.AIT 3.500 AF20.AIT AF30.AIT 4.063 AF60.AIT 4.040 AF90.AIT 3.907 76. 922 4. 035 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .020 SERVICE · FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .021 SERVICE · FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 21 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 75 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: O. 1667 FILE SUFk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12123.0 4456.0 DSI 12112.0 3920.0 PEX 12106.0 4456.0 C~R 11936.0 9280.0 $ LOG HEADER DATA DATE LOGGED: 10 -NOV- 97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 1230 9-NOV-97 TIME LOGGER ON BOTTOM: 1300 12-NOV-97 TD DRILLER (FT) : 12132.0 TD LOGGER (FT) : 12132.0 TOP LOG INTERVAL (FT) : 3920.0 BOTTOM LOG INTERVAL (FT) : 12123.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA CMR COMB. MAGNETIC RESONANCE CMRT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH: 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 1.530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 370 MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL 70.0 70.0 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 76 MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C~R & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEMWITH PEX/CFiR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FROM RUN#1 REPEAT PASS #2 SAMPLED AT 0.1667'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 HDRA PEX G/C3 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 PEFZ PEX 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 RHOZ PEX G/C3 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 H~IN PEX OH~ 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 77 NAME SERV UNIT SERVICE API API API API FILE NUI~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) H~INO PEX OHMM1022704 O0 000 O0 0 21 1 1 4 68 0000000000 RXOZ PEX OH~iM 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 RX08 PEX OHId~41022704 O0 000 O0 0 21 1 1 4 68 0000000000 HCNT PEX CPS 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 HCFT PEX CPS 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 HGR PEX GAPI 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 RHFT PEX CPS 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 RHNT PEX CPS 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 DPHZ PEX PU 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 HTNP PEX PU 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 HNPO PEX PU 1022704 O0 000 O0 0 21 1 1 4 68 0000000000 ** DATA ** DEPT. 11735.000 HDRA.PEX -999.250 PEFZ.PEX -999.250 RHOZ.PEX -999.250 H~IIN. PEX 4.138 Pk/iNO.PEX 5.291 RXOZ.PEX 13.526 RXO8.PEX 13.525 HCNT. PEX 2257.889 HCFT.PEX 798.813 HGR.PEX 117.874 RHFT. PEX 749.547 RHNT. PEX 2239.475 DPHZ.PEX 60721.211 HTNP.PEX 32.119 HNPO.PEX 31.671 DEPT. 10667.334 HDRA.PEX HMIN. PEX 5.522 PR4NO.PEX HCNT. PEX 2490.657 HCFT. PEX RHNT.PEX 2278.949 DPHZ.PEX 0.071 PEFZ.PEX 3.000 RHOZ.PEX 2.507 4.611 RXOZ.PEX 5.775 RXO8.PEX 5.775 906.541 HGR.PEX 109.573 RHFT. PEX 717.493 8.668 HTNP.PEX 30.895 HIVPO.PEX 30.513 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .021 SERVICE · FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .022 SERVICE : FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape V$ri~fication Listing Schlumberger Alaska Computing Center 14-DEC-i997 15:16 PAGE: 78 RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUM~La~EY FILE HEADER FILE~BER 22 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12123.0 4456.0 DSI 12112.0 3920.0 PEX 12106.0 4456.0 CMR 11936.0 9280.0 $ LOG HEADER DATA DATE LOGGED: lO-NOV-97 SOFTWARE VERSION: 8C0-609 TIME CIRCULATION ENDED: 1230 9-NOV-97 TIME LOGGER ON BOTTOM: 1300 12-NOV-97 TD DRILLER (FT) : 12132.0 TD LOGGER (FT) : 12132.0 TOP LOG INTERVAL (FT): 3920.0 BOTTOM LOG INTERVAL (FT) : 12123.0 LOGGING SPEED (FPHR): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA CMR COFiB. MAGNETIC RESONANCE CFiRT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) '. MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : 8.500 4441.0 4452.0 LSND 10.40 62.0 8.8 181.0 1. 690 70.0 1.530 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 79 MUD CAKE AT (MT): MUD CAKE AT (BHT) : 1.370 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMJLgKS: ************ RUN 1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON C~R & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/C~R. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FROM RUN #1 REPEAT PASS #2 SAMPLED AT O. 0833'. $ LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 8O ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 22 1 1 4 68 0000000000 HCAL PEX IN 1022704 O0 000 O0 0 22 1 1 4 68 0000000000 ** DATA ** DEPT. 11735.000 HCAL.PEX 8.729 DEPT. 10667.084 HCAL.PEX 9.310 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .022 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .023 SERVICE : FLIC VERSION : O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUNff4ARY VENDOR TOOL CODE FILE HEADER FILE NUMBER 23 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 START DEPTH STOP DEPTH .......... . . LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 81 AIT DSI PEX CMR $ LOG HEADER DATA 12123.0 4456.0 12112.0 3920.0 12106.0 4456.0 11936.0 9280.0 DATE LOGGED: lO-NOV-97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 1230 9-NOV-97 TIME LOGGER ON BOTTOM: 1300 12-NOV-97 TD DRILLER (FT) : 12132.0 TD LOGGER (FT) : 12132.0 TOP LOG INTERVAL (FT): 3920.0 BOTTOM LOG INTERVAL (FT) : 12123.0 LOGGING SPEED (FPHR): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AITH PEX PLATFORM EXPRESS HILTB DSI DIPOLE SONIC DSSTA CMR COlVlB. MAGNETIC RESONANCE CFIRT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH: 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OHt~) AT TEMPERATURE (DEGF) : MUD AT t4~AS~ TE~PERATEFRE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 1.530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1.370 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN1 ************* 70.0 70.0 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 82 1.5" STANDOFF ON AIT, BOWSPRING ON C~R & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FROM RUN #1 REPEAT PASS #1 SAMPLED AT 0.5'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 120 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 TENS PEX LB 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 CNTC PEX CPS 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 CFTC PEX CPS 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 TNRA PEX 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 GR PEX GAPI 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 RTNR PEX 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 RCFT PEX CPS 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 RCNT PEX CPS 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 DEVI PEX DEG 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 HTEN PEX LB 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 MRES PEX OH~ 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 83 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUPIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 O0 O0 O0 O0 O0 O0 O0 T2LMCMR 1022704 KTIMCMR 1022704 KSDR CMR 1022704 MTEM PEX DEGF 1022704 NPHI PEX PU 1022704 TNPH PEX PU 1022704 NPOR PEX PU 1022704 C~RP CMR 1022704 CMFF ClvlR 1022704 O0 BFV C?4R 1022704 O0 TENS DSI LB 1022704 O0 PR DSI 1022704 O0 RSHC DSI 1022704 O0 DTSM DSI US/F 1022704 O0 DT DSI US/F 1022704 O0 MRES DSI 0H~i~1022704 O0 MTEMDSI DEGF 1022704 O0 GR DSI GAPI 1022704 O0 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 000 O0 0 23 1 1 4 68 0000000000 ** DATA ** DEPT. 12150 TNRA.PEX -999 RCNT. PEX -999 T2LM.~VlR -999 NPHI.PEX -999 CMFF. CY4R -999 RSHC.DSI 2 MTEM. DSI 158 000 TENS.PEX 250 GR.PEX 250 DEVI.PEX 250 KTIM. C~R 250 TNPH. PEX 250 BFV. CMR 224 DTSM. DSI 226 GR.DSI DEPT. 11482.000 TNRA. PEX 3.102 RCNT. PBX 28. 578 T2LM. C~R 9. 023 NPHI.PEX 35.929 CMFF. CMR 0.004 RSHC.DSI -999.250 MTEM. DSI -999.250 TENS. PEX GR. PEX DEVI. PEX KTIM. C~R TNPH. PEX BFV. CFiR DTSM. DS I GR. DSI -999.250 CNTC.PEX -999.250 CFTC.PEX -999.250 RTNR.PEX -999.250 RCFT. PEX -999.250 HTEN. PEX -999.250 I4RES.PEX -999.250 KSDR.C~4R -999.250 MTEM. PEX -999.250 NPOR.PEX -999.250 Cl~RP.~ -999.250 TENS.DSI 2914.000 PR.DSI 233.415 DT.DSI 104.957 I~ES.DSI 124.511 1750.000 CNTC.PEX 2149.813 CFTC.PEX 204.296 RTNR.PEX -0.124 RCFT. PEX 47.870 HTEN. PEX 1433.804 MRES.PEX 0.001 KSDR.CFiR 0.012 MTIETq. PEX 36.465 NPOR.PEX 35.860 CivlRP. CMR 0.074 TENS.DSI -999.250 PR.DSI -999.250 DT.DSI -999.250 IViRES.DSI -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.373 0.396 692.462 7.391 0.774 152.843 0.078 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 84 **** FILE TRAILER **** FILE NAME : EDIT .023 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .024 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 24 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUM~LARY VENDOR TOOL CODE START DEPTH AIT 12123.0 DSI 12112.0 PEX 12106.0 CMR 11936.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION STOP DEPTH 4456.0 3920.0 4456.0 9280.0 lO-NOV-97 8C0-609 1230 9-NOV-97 1300 12-NOV-97 12132.0 12132.0 3920.0 12123.0 1800.0 TOOL NUM~ER AITH LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 85 PEX DSI CMR $ PLATFORM EXPRESS HILTB DIPOLE SONIC DSSTA COMB. MAGNETIC RESONANCE C~RT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH: 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1.370 MUD CAKE AT (BHT) : 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CNL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEMWITHPEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FROM RUN #1 REPEAT PASS #1 SAMPLED AT 0.25'. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 86 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 24 1 1 4 68 0000000000 AIBD AIT IN 1022704 O0 000 O0 0 24 1 1 4 68 0000000000 AFiO AIT 0H~94 1022704 O0 000 O0 0 24 1 1 4 68 0000000000 AF20 AIT OH~PI1022704 O0 000 O0 0 24 1 1 4 68 0000000000 AF30 AIT 0H~4~1022704 O0 000 O0 0 24 1 1 4 68 0000000000 AF60 AIT 0P~4~1022704 O0 000 O0 0 24 1 1 4 68 0000000000 AF90 AIT 0H~4~1022704 O0 000 O0 0 24 1 1 4 68 0000000000 ** DATA ** DEPT. 11941.000 AIBD.AIT 8.500 AFiO.AIT 1.983 AF20.AIT AF30.AIT 2.291 AF60.AIT 2.373 AFgO.AIT 2.421 DEPT. 11482.750 AIBD.AIT 8.500 AFiO.AIT 16.634 AF20.AIT AF30.AIT 42.257 AF60.AIT 56.260 AF90.AIT 56.779 2.244 34.218 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 87 **** FILE TRAILER **** FILE NAME : EDIT .024 SERVICE . FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .025 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER 25 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 O. 1667 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12123.0 4456.0 DSI 12112.0 3920.0 PEX 12106.0 4456.0 C?4R 11936.0 9280.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION lO-NOV-97 8C0~609 1230 9-NOV-97 1300 12-NOV-97 12132.0 12132.0 3920.0 12123.0 1800.0 TOOL NUMBER AITH LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 88 PEX DSI C~R $ PLATFORM EXPRESS HILTB DIPOLE SONIC DSSTA COMB. MAGNETIC RESONANCE CMRT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 4441.0 4452.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 62.0 MUD PH: 8.8 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 181.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1.530 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 370 MUD CAKE AT (BHT): 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ************ RUN 1 ************* 1.5" STANDOFF ON AIT, BOWSPRING ON CMR & CArL AIT RUN ECCENTERED, COMPUTE STANDOFF NO SPEED CORRECTION USED. RUN ON WIRELINE TO 9500' THEN ON DRILLPIPE TO BOTTEM WITH PEX/CMR. TOOLS OVERSPEEDED ON REPEAT. THIS FILE CONTAINS THE RAW DATA FROM RUN #1 REPEAT PASS #1 SAMPLED AT 0.1667'. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 89 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ArUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 HDRA PEX G/C3 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 PEFZ PEX 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 RHOZ PEX G/C3 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 HMIN PEX OH~4~ 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 H~NO PEX OH~I 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 RXOZ PEX OHF~q 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 RX08 PEX OH~q 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 HCNT PEX CPS 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 HCFT PEX CPS 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 HGR PEX GAPI 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 RHFT PEX CPS 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 Rt{NT PEX CPS 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 DPHZ PEX PU 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 HTNP PEX PU 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 HNPO PEX PU 1022704 O0 000 O0 0 25 1 1 4 68 0000000000 ** DATA ** DEPT. 11941.000 I{DP~.PEX -999.250 PEFZ.PEX ~999.250 RHOZ.PEX HMIN. PEX 1.625 Pi~INO. PEX 1.897 RXOZ.PEX 2.973 RXOS.PEX HCNT. PEX 1707.846 HCFT. PEX 628.589 HGR.PEX 148.624 RHFT. PEX RHNT. PEX 1700.102 DPHZ.PEX 60721.211 HTNP.PEX 30.425 HNPO.PEX ~999.250 2.984 595.413 29.855 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 15:16 PAGE: 90 DEPT. 11482 . 834 HDRA. PEX HMIN. PEX 3.929 HMNO. PEX HCNT. PEX 2190.062 HCFT. PEX RHNT. PEX 1647.905 DPHZ. PEX O . 022 PEFZ. PEX 3.359 RXOZ . PEX 705.612 HGR.PEX 7. 789 HTNP. PEX 3. 442 RHOZ.PEX 4.174 RX08 . PEX 201. 870 RHFT. PEX 3 6. 452 PZNPO. PEX 2. 521 4.174 424. 928 36. 045 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .025 SERVICE : FLIC VERSION : O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC TAPE NAME : 97545 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, SAM #1, PRUDHOE BAY, API #50-029-22819-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN . FLIC REEL NAME : 97545 CONTINUATION # : PREVIOUS REEL : COMbIENT : BP EXPLORATION, SAM #1, PRUDHOE BAY, API #50-029-22819-00
